oEPA
          United States
          Environmental Protection
          Agency
           Industrial Environmental Research
           Laboratory
           Research Triangle Park NC 27711
EPA-600/7-80-029b
May 1980
EPA Utility FGD Survey:
January-March 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-600/7-80-029b

                                                           May 1980
             EPA  Utility FGD  Survey:
                 January-March  1980
                                 by

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

                         PEDCo Environmental, Inc.
                           11499 Chester Road
                          Cincinnati, Ohio 45246
                          Contract No 68-01-4147
                             Task No. 143
                        Program Element No. INE828
                      EPA Project Officer: Norman Kaplan

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

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

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                              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 re-
port are supplied voluntarily by utility representatives; flue
gas desulfurization  (FGD) system designers and suppliers; regula-
tory personnel; and others.  Neither EPA nor the designated
contractor 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.

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                       USE OF THIS REPORT


     This report is the first 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 perform-
ance data for operational FGD systems contained in Section 3,
this report also contains a number of tables presenting tabula-
tions of some of the key data.  The Executive Summary contains
the number and capacity of FGD systems as of the end of March
1980, future projections (January 1990) of controlled and uncon-
trolled 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 pre-
vious issues.

     Appended to this report is a section containing reported and
adjusted cost data for U.S. FGD systems in which operational  sys-
tems are stressed  (Appendix A).  Also included in the appendices
are definitions and a glossary of units.
                                111

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                             ABSTRACT


     This report  is  the  first  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
information 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 states), utility company, system supplier, process,
waste disposal practice, and regulatory class.   FGD system
economic data, definitions,  and a  glossary of terms are appended
to the report.  Current  data for  operational domestic FGD systems
show 65 systems in operation,  42  systems under construction, and
74 planned systems.  Projected 1990 FGD controlled capacity in
the U.S. is 85,671 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                          7

Design and Performance Data for Operational
FGD Systems                                   38

Alabama Electric
  Tombigbee 2                                 38
  Tombigbee 3                                 40
Allegheny Power System
  Pleasants 1                                 41
Arizona Electric Power
  Apache 2                                    42
  Apache 3                                    43
Arizona Public Service
  Cholla 1                                    44
  Cholla 2                                    45
  Four Corners 1                              46
  Four Corners 2                              47
  Four Corners 3                              48
Big Rivers Electric
  Green 1                                     49
Central Illinois Light
  Duck Creek 1                                50
Central Illinois Public Service
  Newton 1                                    52
Colorado Ute Electric Assn.
  Craig 2                                     54
Columbus & Southern Ohio Electric
  Conesville 5                                55
  Conesville 6                                57
Cooperative Power Association
  Coal Creek 1                                59
                                v

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        CONTENTS (continued)
 Duquesne Light
   Elrama 1-4                                   61
   Phillips 1-6                                63
 Indianapolis  Power &  Light
   Petersburg  3                                65
 Kansas  City Power & Light
   Hawthorn 3                                   66
   Hawthorn 4                                   68
   LaCygne 1                                   69
 Kansas  Power  & Light
   Jeffrey 1                                   70
   Lawrence 4                                   71
   Lawrence 5                                   72
 Kentucky Utilities
   Green River 1-3                             73
 Louisville Gas &  Electric
   Cane  Run 4                                   74
   Cane  Run 5                                   75
   Cane  Run 6                                   76
   Mill  Creek  3                                77
   Paddy's Run 6                                78
 Minnkota Power Cooperative
   Milton R. Young 2                            79
 Montana Power
   Colstrip 1                                   81
   Colstrip 2                                   82
 Nevada  Power
   Reid  Gardner 1                               83
   Reid  Gardner 2                               84
   Reid  Gardner 3                               86
 Northern Indiana  Public Service
   Dean  H.  Mitchell  11                          87
 Northern States Power
   Sherburne 1                                  88
   Sherburne 2                                  89
 Pacific  Power  & Light
   Jim Bridger  4                                90
 Pennsylvania Power
   Bruce  Mansfield 1                           91
   Bruce  Mansfield 2                           92
Philadelphia Electric
  Eddystone 1A                                93
Public Service Company of New Mexico
  San Juan 1                                  94
  San Juan 2                                  95
  San Juan 3                                  96
                 VI

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                      CONTENTS  (continued)
Section 4

Section 5

Section 6

Section 7


Section 8


Section 9

Section 10

Section 11

Section 12
                                             Page

Salt River Project
  Coronado 1                                  97
South Carolina Public Service Authority
  Winyah 2                                    98
South Mississippi Electric
  R.D. Morrow 1                               99
  R.D. Morrow 2                              100
Southern Illinois Power Coop
  Marion 4                                   101
Southern Indiana Gas & Electric
  A.B. Brown 1                               103
Springfield City Utilities
  Southwest 1                                105
St. Joe Zinc
  G.F. Weaton 1                              107
Tennessee Valley Authority
  Shawnee 10A                                108
  Shawnee 10B                                109
  Widows Creek 8                             111
Texas Utilities
  Martin Lake 1                              113
  Martin Lake 2                              114
  Martin Lake 3                              115
  Monticello 3                               116
Utah Power & Light
  Hunter 1                                   117
  Huntington 1                               118

Summary of FGD Systems by Company            119

Summary of FGD Systems by System Supplier    121

Summary of FGD Systems by Process            123

Summary of Operating FGD Systems by
Process and Unit                             124

Summary of End-Product Disposal
Practices for Operational FGD Systems        126

Summary of FGD Systems in Operation          128

Summary of FGD Systems Under Construction    131

Summary of Contract Awarded FGD Systems      133

Summary of Planned FGD Systems               134

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                       CONTENTS (continued)
 Section 13


 Section 14
Section 15
 Total FGD Units and Capacity (MW)
 Installed by Year

 Design and Performance Data for
 Operational Particle Scrubbers

 Commonwealth Edison
   Will County 1
 Detroit Edison
   St.  Clair 6
 Minnesota Power and Light
   Aurora 1
   Aurora 2
   Clay Boswell 3
 Montana-Dakota Utilities
   Lewis & Clark 1
 Pacific Power and  Light
   Dave Johnston 4
 Potomac Electric Power
   Dickerson 1
   Dickerson 2
   Dickerson 3
 Public Service of  Colorado
   Arapahoe 4
   Cherokee 1
   Cherokee 4
   Valmont  5
 Southwestern  Public Service
   Harrington  1

 Design  and  Performance Data for
 Operational Foreign FGD Systems

Chugoku Electric
  Shimonoseki 1
Electric Power Development Company
  Isogo 1
  Isogo 2
  Takasago 1
  Takasago 2
  Takehara 1
 138

 151

 157
 159
 161

 163

 165

 167
 168
 170

 175
 177
 179
 181

 186


 188


188

190
192
194
196
198
                               viii

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                      CONTENTS (continued)
Appendix A     FGD System Cost Data:  Operational
               and Nonoperational Systems                   A-l

               A-l Major FGD System Equipment Summary       A-8
               A-2 Cost Element Factors                     A-13
               A-3 Description of Cost                      A-16
               A-4 Categorical Results of Reported and
                   Adjusted Capital and Annual Costs for
                   Operational FGD Systems                  A-19
               A-5 Costs for Operational FGD Systems        A-20
               A-6 Costs for Nonoperational FGD Systems     A-25

Appendix B     Definitions                                  B-l

Appendix C     Glossary of Units                            C-l
                                IX

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                             TABLES


No.                                                         Page

I         Number and Total Capacity of FGD Systems           xi

II        Summary of Changes, January - March 1980          xiii

III       Performance of Operational Units,
          January - March 1980                              xiv



                             FIGURE


No.                                                         Page

 1        computerized data base structure diagram          xii

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

     Table 1 summarizes  the status of FGD  systems in the  United
States  at  the end of March  1980.  Table II lists the units that
have changed status during  the first quarter  1980, and Table III
shows the  performance of operating units during this period.
             TABLE 1.  NUMBER AND TOTAL CAPACITY OF FGD SYSTEMS


Status
Operational
Under construction
Planned:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only
FGD systems
TOTAL

No. of
units
65
42

23
2
15

34
181
Total
Controlled
Capacity, MW*
23,887
19,583

11,532
842
10,255

19,572
85,671
Equivalent
Scrubbed
Capacity, MW"1"
22,100
18,454

10,519
842
10,221

19,432
81,568
* 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).
t
                                  XI

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H-
H-
                             Figure  1.  Computerized  data  base structure diagram.

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                               TABLE  II.   SUMMARY  OF  CHANGES
                                    JANUARY - MARCH 1980
FGD status report
12/31/79
Arizona Electric Power Coop
Four Corners 1
Four Corners 2
Four Corners 3
Basin Electric Power Coop
Laramie River 3
Cincinnati Gas & Electric
East Bend 1
Deseret Generation & Trans. Coop
Moon Lake 1
Moon Lake 2
Grand Haven Brd. of Light & Pwr.
J.B. Sims 3
Michigan So. Central Pwr. Agency
Project 1
Muscatine Power & Water
Muscatine 9
Nevada Power
Reid Gardner 4
New York State Elec. & Gas
Somerset 1
Philadelphia Electric
Eddys tone IB
Eddystone 2
Seminole Electric
Seminole 1
Seminole 2
Tennessee Valley Authority
Johnsonville 1-10
Paradise 1
Paradise 2
Texas Municipal Power Agency
Gibbons Creek 1
United Power Association
Stanton 2
Wisconsin Power S Light
Columbia 2
TOTAL
Operational
No.
62
+ 1
+ 1
+ 1














65
MW*
21.5218
175
175
229














22.100
Under
construction
No.
39
-1
-1
-1
+1







+1
+ 1

+1
+1
+1


42
MW*
16,051
175
175
229
600







240
334

704
704
400


18,454
Contract
awarded
No.
23

-1


+ 1
+1
+1


-1
-1
+1
+1
+1
-1
-1
-1
+1
-1
23
MU*
11.631a

600


81
55
160


240
334
620
620
600
704
704
400
50
316
10.519
Letter
of Intent
No.
2















2
MU*
842















842
Requesting/
eval. bids
No.
15



+1
+1


-1
+1
+1

-1
-1
-1



15
MU*
10.281



410
410


160
250
870

620
620
600



10,221
Considering
FGD
No.
35


+1




-1
-1






34
MW*
19,902


650




250
870






19.432
Total
No.
176


+1
+1
+1
+1
+1







+1
-1
181
MW*
80,228a


650
410
410
81
55







50
316
81.568
• Equivalent scrubbed capacity.
1 This value was «od1fied slightly due to « MW correction.
                                               Xlll

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                                 TABLE  III.   PERFORMANCE  OF OPERATIONAL  UNITS
                                             JANUARY  - MARCH  1980
Plant
Toribigbee 2
Toabigbee 3
Pleasant* 1
Apache 2
Apache 3
Choi la 1
Cholla 2
Four Corners 1
Four Corners 2
Four Corners 3
Green 1
Duck Creek 1
Newton 1
Craig 2
Conesville 5
Conesville 6
Coal Creek 1
Elraaa 1-4
Phillips 1-6
Petersburg 3
Hawthorn 3
Hawthorn 4
La Cygne 1
Jeffrey 1
Lawrence 4
Lawrence 5
Green River 1-3
Cane Run 4
Cane Run 5
Cane Run 6
Hill Creek 3
Paddy's Run 6
FGO syste*
capacity,
179
179
519
195
195
119
350
175
175
229
242
378
617
447
411
411
327
510
410
532
90
90
874
540
125
420
64
188
200
299
44?
72
Flue gas
X scrubbed
70
70
83
100
100
100
100
100
100
100
100
90
100
100
100
100
60
100
100
100
100
100
100
75
100
100
100
100
100
100
100
100
FGD capacity
on line
during
PMW^'
179
179

195
195
119

175
175
229

378
617
447
411
411
327
510
410
532
90


540
125
420

188
200
299
442

Mo information
for this
period, MW3


519



350



242











874









Shut dour
through-
out
period,





















90




64




72
January 1980
Jependabi 1 ity X '
vt
90
00

90
92






32
52

27
89

100
73

1DO
100




100





OPR
62
98

58
92
97





35
46

44
76
100
100
89

100



100
100

100
92
49


REL



89
92






38
54

52
76

100
74













UTL
48
43

57
92
97





32
45

15
76
%
98
72

93
0


100
100
0
96
72
14
0
0
February 1980
Dependability X '
AVI
99
100

93
95






49
53

92
90

100
71

100
100




100





OPR
99
100

97
74
100





49
39

66
78
100
100
79

100



100
100

100
72
85
36

REL



93
96






52
40

81
82

100
71













UTL
99
3

93
71
100





49
39

33
72
100
92
70

100
0


100
52
0
67
50
47
27
0
March 1980
Dependability * '
AVI
100
100

99
91







36

66
94




100
100




100





OPR
98


99
91
96






34

82
73
100



100



100
100

81
45
70
37

REL



99
91







37

82
73
















UTL
90
0

99
91
96






34

82
16
96



100
0


100
55
0
74
27
65
31
0
(continued)

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TABLE III (continued)
Plant
Hilton R. Young 2
Colstrip 1
Colstrip 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Dean H. Mitchell 11
Sherburne 1
Sherburne 2
Jim Bridger 4
Bruce Mansfield 1
Bruce Mansfield 2
Eddystone 1A
San Juan 1
San Juan 2
San Juan 3
Coronado 1
Winyah 2
R.O. Morrow 1
R.D. Morrow 2
Marion 4
A.B. Brown 1
Southwest 1
G. F. Weaton 1
Snawnee IDA
Shawnee 10B
Widows Creek 8
Martin Lake 1
Martin Lake 2
FGO system
capacity,
405
360
360
125
125
125
115
740
740
550
917
917
120
361
350
534
280
140
124
124
184
265
194
60
10
10
550
595
595
Flue gas
X scrubbed
92
100
100
100
100
100
100
100
100
100
100
100
N/Ad
100
100
100
80
50
62
62
100
100
100
N/Ad
N/Ad
N/Ad
100
75
75
FGD capacity
on line
duri ng
•>$?!!•
405


125
125
125

740
740
550
917
917

361
350
534
280
140
124
124
184
265
194
60
10
10
550
595
595
No information
for this
period, tor

360
360



115






















Shut down
through-
out
period,
MW*












120
















Ja
)epe
TO.
7


100
97
100

97
97

98
97

87
31



0
0

99
61



70


luary
idabi 1
WIT
11


100
97
100




100
100

57
21





100
98
56



90


980
ty XC
-an-
ii


100
97
100












0
0

98
62






e
-oTT-
7


100
82
91




90
91

47
21



0
0
10
98
52



45


February 1980
Dependability Xc'e
~AVl
0


100
97
78

97
96

98
94

67
40






99
55



85


OPR
0


100
97
98




100
100

65
23





100
70
50



94


REL



100
97
78















70
50






UTL
0


100
97
78




94
100

59
26





31
69
50



77


March 1980
Dependability X •
AVL
29


66
98
60

98
98

98
98

93
57






45
43



87


OPR
29


84
98
100




100
100

73
31





100
65
35



79


REL
29


85
98
100















68
35






UTL
29


34
98
60




84
84

26
20





48
27
35



77


(continued)

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TABLE  III  (continued)
Plant
Hart in Lake 3
Honticello 3
Hunter 1
Huntington 1
TOTAL
FGO systen
capacity .
595
800
360
366

Flue gas
X scrubbed
75
100
90
85

FGO capacity
on line
during
P$°g>
S95
800


18.208
No information
for this
period, HWa


360
366
3,546
Shut down
through-
out
period.




346
January 1980
pependability X '
Wl





OPR





REL





UTL





February 1980
Dependability X '
Wl





OPR





REL





UTL





March 1980
Dependability X 'e
AVL





OPR





REL





UIL





 .  Equivalent  scrubbed capacity.
   This category  includes the flue gas  capacity being handled by the  FGD  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 and demonstration units is not applicable unless the system  is designed to bring a  unit  into compliance
   with SO2 Mission standard.
   Availability,  operability, reliability,  and utilization as defined in  Appendix C of this report.

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As indicated in Table 1, 65 power generating units (all coal-
fired) are now equipped with operating FGD systems.  These units
represent a total controlled capacity of 23,887 MW.  Current
projections indicate that the total power generating capacity of
the U.S. electric utility industry will be approximately 931 GW
by 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 382 GW or 41 percent of the 1990 total
will come from coal-fired units.  The distribution of power
generation sources, both present (April 1979) and future (January
1990)  is as follows:3

               Coal  Nuclear  Oil  Hydro  Gas  Other  GW (total)

April 1979     39%      9%    26%   12%   13%    1%      588
January 1990   41%     22%    18%   10%    8%    1%      931

Based on the known commitments to FGD by utilities as presented
in Table 1, the percentage of electrical generating capacity
controlled by FGD for both the present  (March 1980) and the
future  (January 1990) is as follows:

                         % of coal-fired       % of total
                       generating capacity  generating capacity

March 1980*                   10.4                 4.1
January 1990                  22.4                 9.2

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  55 to 60 systems repre-
senting approximately 36,000 to 41,000 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  (March  1980) and a projected
(January 1990) breakdown of throwaway product systems versus
saleable product systems as a percent of the total known committ-
ments to FGD as of the end of the first quarter 1980:
  The number of committed FGD systems is as of March  1980; however,
  the figure used for the total generating capacity and  coal  fired
  generating capacity is based on  the available April 1979 figures.
                                xvn

-------
          Throwaway product process       Saleable product process       Process undecided   Total
               % of total                 % of total               % of total
          Line  Limestone   Other     Sulfur  H-SO,   Gypsum  N/A*

March 1980   28.1    39.4    25.5       4.0    3.0                               Ioo
January 1990  16.4    36.4    20.5       1.1    2.4     0.2   3.0         20.0        loo
*
 N/A - not available (these systems will utilize a saleable product process but the byproduct is unknown at
 this time).
                   HIGHLIGHTS:  JANUARY  -  MARCH 1980

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

   Tombigbee 2 of Alabama Electric Cooperative achieved availabili-
   ties of 90%, 99%,  and 100% for the months of January, February,
   and March, respectively.  The FGD system was unavailable only  69
   hours in January due to a ruptured waste slurry line and an
   abraded expansion  joint.  No major FGD related problems were
   reported for February or March.  The Tombigbee 3 FGD system had
   availabilities of  100% for both January and February; however,
   the Unit 3 boiler  only operated for 24  hours in February.  Unit 3
   did not operate at  all during March.

   Arizona Electric Power Cooperative reported availabilities of
   90%, 92%, and  99%  for the Apache 2 FGD system during January,
   February, and  March, respectively.  The Apache 3 availabilities
   were 91%, 95%,  and  91% for the same period.  Most of the FGD
   system outage  time  reported was due to  the malfunction of pumps.

   The Cholla 1 FGD system of Arizona Public Service had operabili-
   ties of 97%, 100%,  and 96% for the months of January, February,
   and March, respectively.  No major FGD  related problems were re-
   ported for the three month period although some outage time was
   required for repair of reheater ductwork.

   Arizona Public Service announced during the period that modifica-
   tions to the particle scrubbers at the  Four Corners 1, 2, and  3
   units were completed and the systems have begun operation in an
   SC>2 removal mode.   Initially,  the two  Chemico venturi scrubbers
   designed for primary particle control  at each unit were also
   removing approximately 30% of the SC>2  due to the alkalinity of
   the fly ash.   These systems were modified to accommodate addi-
   tional SC-2 removal  (67.5%)  by converting the scrubbers to lime/
   alkaline fly ash systems.   Actual conversion of each system was
   completed in November 1979.
                                 XVI11

-------
Basin Electric Power Coop announced that construction of the
Laramie River 3 FGD system began during February 1980.  Particle
and S02 emissions at this 600 MW (gross) unit will be controlled
by four lime/spray drying towers followed by a common ESP.  The
system is designed to remove 85 percent of the S02 before the
flue gas exits through a 600 foot acid brick lined stack.
Initial start up of the system is expected in July 1981.

Cincinnati Gas and Electric announced plans during the period for
the installation of a second 650 MW (gross) generator at the East
Bend power plant.  The boiler will be identified as Unit 1 and
will be required to meet an SC>2 emission standard of 0.84 Ib/MMBtu,
Currently, the utility is considering only FGD as a means of
controlling the S02 emissions.  The process type has not been
selected and the projected start-up date of the unit has not been
finalized.

No major FGD related problems were encountered during the first
quarter, 1980 with the Conesville 6 FGD system of Columbus and
Southern Ohio Electric.  As a result, the unit had availabilities
of 89%, 90%, and 94% for January, February, and March, respec-
tively.  The system utilization was only 16% in March due to an
annual boiler/turbine inspection that began on March 9.

Cooperative Power Association reported FGD system utilization
parameters of 96%, 100%, and 96% for January, February,  and
March, respectively.  Some minor FGD outage time was reportedly
caused by nozzle plugging and cracking which resulted in the unit
operating at a reduced load for a short time in January.  No
major FGD related problems were reported for February or March.

Deseret Generation and Transmission Coop announced plans during
the period for two new 410 MW  (gross) units to be located in
Vernal, Utah.  The units will be designated as Moon Lake  1 and  2,
and will burn coal with an average sulfur content of  0.5%.
Currently, the utility is requesting/evaluating bids  for  lime-
stone FGD systems to control S02 emissions from these two units.
Baghouses will be used for primary particle removal. The FGD
systems will operate in a closed water  loop and the sludge
generated will be disposed of  in an on-site landfill.   The ex-
pected start up of Unit 1 is December 1984.  The  start  up date  of
Unit 2 is not finalized but is expected between 1987  and 1989.

Grand Haven Board of Light and Power announced that a contract
has been awarded to Babcock and Wilcox  for the installation of  a
lime FGD system at the new 81 MW  (gross) J.B. Sims 3  unit.  The
boiler, which will be  located  in Grand  Haven, Michigan,  will  fire
coal with an average sulfur content of  2.75%.  The FGD  system
will include two 100% capacity spray towers preceded  by a cold
side ESP for primary particle  removal.  Each spray tower will be
                                xix

-------
 equipped  with  a  chevron  mist  eliminator  and  an  in-line  hot water
 reheater  to  boost  the  temperature  of  the flue gas  before  it exits
 through a 360  foot stack.   Initial start up  of  this unit  is
 expected  in  June 1983.

 Michigan  South Central Power  Agency reported during the period
 that a contract  has been awarded to Babcock  and Wilcox  for a
 limestone wet  scrubbing  system to  control  SO? emissions from the
 new Project  1  unit.  The 55 MW  (gross) boiler,  which will be
 located in Litchfield, Michigan, will burn coal with an average
 sulfur content of  2.25%.  The SC>2  removal  equipment will  consist
 of a spray tower system  preceded by a hot  side  ESP for  primary
 particle  removal.  Initial  start up of the system  is expected in
 July 1982.

 A contract was awarded during the  first  quarter, 1980,  to Re-
 search Cottrell  by Muscatine  Power and Water for the installation
 of a limestone FGD system at  the new 166 MW  (gross) Muscatine 9
 unit.  The Combustion Engineering  boiler will burn coal with an
 average sulfur content of 3.17%.   The FGD  system will consist of
 three double loop combination towers, each with a  spray tower
 lower stage and  a  "wetted film contactor"  grid  type upper stage
 (Research  Cottrell design).   Upstream of the FGD system will be
 a cold side ESP  for primary particle removal.   The system will
 operate in a closed water loop and the sludge will be disposed of
 in a landfill.   The expected  start up date is September 1982.

 Nevada Power reported that the Reid Gardner  2 FGD  system  had an
 availability of  98% for  all three  months of  the first quarter,
 1980.   Minor outages were reportedly caused  by  problems with the
 emergency  spray  system and the malfunctioning of ID fan controls.

 Nevada Power began requesting/evaluating bids during the  period
 for a system to  control  SO2 emissions from the  new unit scheduled
 for installation at the  Reid  Gardner station.   The boiler will be
 identified as  Unit 4 and will burn coal with an average sulfur
 content of 0.75%.  Construction of the unit  is  expected to begin
 sometime  in 1980 and initial  start up is scheduled for  April
 1983.

New York  State Electric  and Gas began requesting/evaluating bids
 in February, 1980 for a  limestone  FGD system to be installed at
 the new 870 MW (gross)  Somerset 1  unit.  The boiler will  fire a
bituminous coal with an  average sulfur content  of  2.4%.   The
 limestone absorber will be designed for a  90% SC>2  removal effi-
 ciency and will be preceded by a cold side ESP  for particle
 removal.   The  sludge generated will be dewatered and stabilized
before being landfilled.   Expected  start up  of  the system is June
 1984.
                                xx

-------
At Sherburne 1 of Northern States Power the FGD system had
availabilities of 97%, 97%, and 98% for the months of January,
February, and March, respectively.  The Sherburne 2 FGD system
had availabilities of 97%, 96%, and 98% for the same period.  No
major FGD related problems were reported for either unit during
the first quarter and both boilers achieved the highest gross
generation to date in January.

Pennsylvania Power reported that the Bruce Mansfield 1 FGD system
had availabilities of 98% for all three months of the first
quarter, 1980.  The Bruce Mansfield 2 availabilities were 97%,
94%, and 98% for January, February, and March, respectively.  No
FGD related problems were reported for the three month period.

Philadelphia Electric announced during the period that construc-
tion has begun on the new magnesium oxide FGD system that is
being installed at the Eddystone 1 unit.  Operation of the
prototype magnesium oxide system which treated one-third of the
flue gas from the coal fired boiler has been terminated.  The SO-
removal equipment is being replaced with a similar magnesium
oxide system designed to treat 100% of the boiler flue gas.  The
expected start up of the new system is December 1982.  Current
regulations do not require the utility to control SC>2 emissions
from the Unit 1 boiler until the new FGD system is available for
operation.

Construction is also underway on the FGD system being installed
to control S02 emissions from the 334 MW  (gross) Eddystone  2
boiler.  This system will also be magnesium oxide and is being
supplied by United Engineers.  Expected start up is  scheduled for
December 1982.

Seminole Electric announced that contracts were awarded during
February, 1980 to Peabody Process Systems for the installation of
limestone FGD systems on the two new 620 MW  (gross)  Seminole  1
and Seminole 2 units  located in Palatka, Florida.  Each unit will
be a pulverized coal  boiler firing coal with  an average sulfur
content of 2.75%.  Each FGD system will consist of five spray
towers preceded by two ESP's for primary particle removal.  One
of the five modules for each system will be a spare.  The  ex-
pected start up dates for Units 1 and  2 are June 1983, and June
1985, respectively.

Tennessee Valley Authority announced that a contract has been
awarded to Riley Stoker/Environeering  for the installation of a
magnesium oxide FGD system at  the  1450 MW  (gross) Johnsonville
power station located in New Johnsonville, Tennessee.  The system
will consist of four  venturi  scrubber/absorber  trains (one spare)
and sulfuric acid will be  produced as  a byproduct.   The equiva-
lent of  600 MW of flue gas will be treated by the FGD system,
with the remaining  60% of  the  gas  being bypassed  for reheat.
Expected start up of  this  system  is  December  1981.


                               xx i

-------
Tennessee Valley Authority also announced during the period that
construction has begun on the FGD systems being installed on the
Paradise 1 and 2 boilers.  Each FGD system will consist of six
trains, each train consisting of two Venturis in series, the
first for primary particle control and the second for primary SO2
removal.  Inlet flue gas will be used to heat water, which in
turn will be used to reheat the outlet flue gas.  The systems are
being supplied by Chemico and are expected to start up in March
1982, and June 1982, for Units 1 and 2, respectively.

Texas Municipal Power Agency announced that construction began
during the first quarter, 1980 on the FGD system being stalled at
the Gibbons Creek station.  The system is being installed on
Unit 1, a new 400 MW (gross) boiler that will fire lignite with
an average sulfur content of 1.06%.  The emission control system
will consist of a cold side ESP followed by three 50% capacity
limestone spray towers.  Also included will be a chevron mist
eliminator and a steam coil reheat system downstream of each
spray tower.  The unit is expected to begin operation in January
1982.

United Power Association announced during the period that a con-
tract has been awarded to Komline and Sanderson for the installa-
tion of a lime/spray drying FGD system at the new Stanton 2 unit.
The boiler, which will be located in Stanton, North Dakota, will
fire lignite with an average sulfur content of 0.77%.  The FGD
system will consist of a spray dryer tower followed by a fabric
filter for the removal of the spent reagent and particulate
matter.  The cleaned flue gas will exit to the atmosphere through
a 254 foot concrete stack.  Expected start up of this unit is
January 1982.

Wisconsin Power and Light announced that plans for the installa-
tion of an FGD system at the Columbia 2 unit have been dropped.
The utility will be utilizing a low sulfur coal at this unit in
order to comply with the applicable SO- emission standard.
                            REFERENCE

a.   U.S. Department of Energy.  Energy Information Administra-
     tion.  Office of Energy Data Interpretation.  Division of
     Coal Power Statistics.  Inventory of Power Plants in the
     United States, April 1979.  Pub. No. DOE/EIA-0095.

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

-------
                                            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 fGD  SURVEY:  JANUARY - MARCH 198C
                                              SECTION  1
                                             LIST OF  F&D  SYSTEMS
COMPANY NAME/
UNIT NAME
COLUMBUS & SOUTHERN OHIO ELEC.
POSTON
POSTON
COMMONWEALTH EDISON
POWERTON
COOPERATIVE POWER ASSOCIATION
COAL CREEK
COAL CREEK
OELMARVA POWER K LIGHT
DELAWARE CITY
VIENNA
DESERET GENERATION g TRANS COO
MOON LAKE
MOON LAKE
DUOUESNE LIGHT
ELRAMA
PHILLIPS
EAST KENTUCKY POWER COOP
J. K. SMITH
J. K. SMITH
SPURLOCK
GENERAL PUBLIC UTILITIES
COHO
GILBERT
SCOTTSVILLE
SEWARD
WEHRUn
GRAND HAVEN BRD OF LIGHT K PUR
J. B. SIMS
HOOSIER ENERGY
MEROH
MEROM
HOUSTON LIGHTING g POWER co.
M.A. PARISH
INDIANAPOLIS POWER K LIGHT
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
KANSAS CITY POWER B LIGHT
HAWTHORN
HAWTHORN
LA CVGNE
KANSAS POWER K LIGHT
JEFFREY
JEFFREY
LAWRENCE
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED

A. FEDERAL NSPS(£/79)
B. FEDERAL NSPSM2/71)
C. STANDARDCS) MORE STRINGENT
D. STANDARD**) MORE STRINGENT
UNIT NO. UNIT LOCATION

5
6

51

1
2

1-3
9

1
2

1-4
1-6

1
2
2

1
1
1
7
1

3

1
2

8

1
2
3
3
4

3
4
1

1
2
4
4.
5.
6.
7.


THAN
THAN

NELSONVILLE
NELSONVILL?

PERKIN

UNDERWOOD
UNDERWOOD

DELAWARE CITY
VIENNA

VERNAL
VERNAL

ELSAMA
SOUTH HEIGHT



MAYSV1LLE

GIRARD TWP.
MILFORD
SCOTTSVILLE

OHIO
OHIO

ILLINOIS

NORTH DAKOTA
NORTH DAKOTA

DELAWARE
MARYLAND

UTAH
UTAH

PENNSYLVANIA
PENNSYLVANIA



KENTUCKY

PENNSYLVANIA
NEW JERSEY
PENNSYLVANIA
E. WHEATFIELD TPENNS YLVANI A
WEHHUM

GRAND HAVEN

SULLIVAN
SULLIVAN

BOOTH

PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG

KANSAS CITY
KANSAS CITY
LA CYGNE

WAMEGO
WAMEGO
LAURENCE
PLANNED - LETTER OF
PENNSYLVANIA

MICHIGAN

INDIANA
INDIANA

TEXAS

INDIANA
INDIANA
INDIANA
INDIANA
INDIANA

MISSOURI
MISSOURI
KANSAS

KANSAS
KANSAS
KANSAS
START-UP
DATE

8/86
0/bO

4/8?

8/79
7/8D

4/60
6/87

12/84
0/88

10/75
7/73

1/85
1/87
1/81

12/88
0/91
0/91
5/87
0/95

6/81

5/82
7/81

11/82

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

11/72
8/72
2/73

8/78
4/85
1/76
STATUS

6
6

2

1
2

2
6

5
5

1
1

6
6
2

6
6
6
6
6

3

3
2

3

6
6
6
1
2

1
1
1

1
2
1
HEG
CLASS

D
D

E

B
B

E
A

A
A

D
D

A
A
B

A
A
A
A
A

A

B
B

A

C
C
C
B
B

D
D
E

D
D
D
INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING FGD SYSTEMS;


NSPS<6/79)
NSPS(13/71) BUT NOT



MORE STRINGENT
ALSO ALTERNATIVE



THAN NSPS



•6/79)
METHODS




E. STANDARD(S) EguAL TO OR LESS STRINGENT THAN NSPSC12/71)

-------
                                            EPA UTILITY FGD SURVEY:  JANUARY  - MARCH
                                            SECTION 1
                                   SUMMARY LIST OF FGD SYSTEMS
COMPANY
   UNIT
        NAME/
        NA*t
                                UNIT  NO. UNIT LOCATION
                                START-UP          REG
                                  DAT^     STATUS CLASS
KANSAS POWER t. LIGHT
   LAWRENCE

KENTUCKY UTILITIES
   GREEN RIVER

LAKELAND UTILITIES
   MCINTOSH
                                         LAWfc EMCE
                                                        KANSAS
LOUISVILLE G«S
   CANE RUN
   CANE RUN
   CANE RUN
   MILL CREEK
   WILL CREEK
   HILL CREEK
   MILL CREEK
   PADDY'S RUN
               &  ELECTRIC
   TS1»BLE
   TR li»3LE
           C PUNT*
           COUNTY
"1CHIGAN  SO.
   PROJECT
              CENTRAL  PWR
"I1DDLE SOUTH  UTILITIES
   ARKANSAS COAL
   ARKANSAS COAL
   LOUISIANA  COAL
   LOUISIANA  COAL
   MISSISSIPPI  COAL
   MISSISSIPPI  COAL

MINNESOTA  POWER  *•  LIGHT
   CLAY B OS * ELL

KI1NNKOTA  POWER  COOPERATIVE
   MILTON  R.  YPUNG

MONTANA POWER
   COLSTR1P
   COLSTR1P
   COLSTRIP
   COLSTR1P

"IUSCATINE  POWER  *  WATER
   MUSCATINE

NEVADA POWER
   HARRY  ALLEN
   HARRY  ALLEN
   HARRY  ALLFN
   HARRY  ALLEN
   REID GARDNER
   REID GARDNER
   REID GARDNER
   REID GARDNER
   WARNER  VALLEY
           VALLEY
                                         CENTSAL CITY    KENTUCKY
                                         LAKELAND
LCUISVILLf
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
BEDfCKD
B t 0 F 0 h D
                                         LITCHFIELO
                                         COHA'SET
                                         CENTf
                                         COLSTRIP
                                         COLSTRIP
                                         COLSTRIP
                                         COLSTRIP
                                          MUSCMINE
                                                         FLORIDA
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUC KY
KENTUCKY
KENTUCKY
KENTUC KY
                                                         MICHIGAN
                                                         MISNE SOTA
                                                         NORTH DAKOTA
                MONTANA
                MONTANA
                MONTANA
                MONTANA
                                                         IOWA
N.F.  LAS  VEGAS NEVADA
N.F.  LAS  VEGAS NEVADA
N.f.  LAS  VEGAS NEVADA
N.c.  LAS  VEGAS NEVADA
MOAPA           NEVADA
MOAPA           NEVADA
MOAPA           NEVADA
MOAPA           NEVADA
ST.  GEORGE     UTAH
ST.  GEORGE     UTAH
                                 11/71


                                  9/75


                                 1C/c1
8/76
zn~>
4/79
4/ei
4/e?
8/7?
7/E1
4/73
7/64
7/tf
1
1
1
2
t.
1
2
1
6
6
D
D
D
E
E
D
B
E
A
A
                                                                           7/c'
ARKANSAS
ARK AN; «s
LOUIS I ANA
LOUIS I *NA
MISSISSIPPI
MISSISSIPPI
1/bf
1/£q
r/f-6
0/6B
C/£?
C'/c7
5
C
C
t
5
5
                                                                           4/fcC
                                                                           9/77
                   9/75
                   5/76
                   1/64
                   C/84
                                                                            6/c6
                                                                            6/8?
                                                                            6/8?
                                                                            t/89
                                                                            4/74
                                                                            4/74
                                                                            6/76
                                                                            4/e3
                                                                            6/a5
 1.   OPERATIONAL UNITS
 ?.   UNITS UNDER CONSTRUCTION
 3.   PLANNED - CONTRACT AWARDED
                                 4.   PLANNED - LETTER OF    INTFNT  SIGNED
                                 5.   PLANNED - REQUESTING/EVALUATING  BIDS
                                 6.   PLANNED - CONSIDERING ONLY  FGD  SYSTEMS
                                 7.   PLANNED - CONSIDERING FGD  SYSTEMS;  ALSO ALTERNATIVE METHODS
 A.   FEDERAL NSPS(6/7?)
 B.   FEDERAL NSPSCI2/71)
 C.   STINDARD(S) "ORE STRINGENT  THAN NSPS<6/79)
 D.   STANDARDS) MORE STRINGENT  THAN NSPS<1?/71) BUT NOT MORE  STRINGENT THAN NSPS<6/79)
 E.   STANDARD(S) ?OUAL TO OR  LESS  STRINGENT THAN NSPSM2/71)

-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH  1980
                                             SECTION  1
                                    SUMMARY LIST Of  Ft,D  SYSTEMS
  COMPANY  NAME/
     UNIT  NAME
                                 UNIT NO. UNIT LOCATION
                                         START-UP
                                           DATE
                                   SEfc
                           STATUS CLASS
  NEW  YORK  STATE  ELEC  8 GAS
     SOMERSET                     1

  NIAGARA  MOHAWK  POWER COOP
     CHARLES  R. HUNTLEY          66

  NORTHERN  INDIANA  PUB SERVICE
     DEAN  H.  MITCHELL             11
     SCHAHFER                     17
     SCHAHFE"                     18

  NORTHERN  STATES  POWER
    RIVERSIDE                    6,7
     SHERBURNE                    1
    SHERBURNE                    2
    SHERBURNE                    3

  OTTER TAIL  POWER
    COYOTE                       1

  PACIFIC GAS * ELECTRIC
    MONTEZUMA                    1
    MONTEZUMA                    2

  PACIFIC POWER R LIGHT
    JIM BRIDGES                  4

  PENNSYLVANIA POWER
    BRUCE MANSFIELD              1
    BRUCE MANSFIELD              2
    BRUCE MANSFIELD              3

  PHILADELPHIA ELECTRIC
    CROMBY
    EDDYSTONE                    1A
    EDDYSTONE                    IB
    EDDYSTONE                    2

  POTOMAC ELECTRIC POWER
    DICKERSON                    4

 PUBLIC SERVICE INDIANA
    GIBSON                       5

 PUBLIC SERVICE OF NEW MEXICO
    SAN JUAN                     1
    SAN JUAN                     2
    SAN JUAN                     3
    SAN JUAN                     4

 PWR AUTHORITY OF STATE OF NY
    FOSSIL

 SALT RIVER PROJECT
    CORONADO                     1
    CORONADO                     2
    CORONADO                     3

 SAN MIGUEL ELECTRIC  COOP
    SAN MIGUEL                    1
         SOMERSET
         BUFFALO
         GARY
         WHEATFIELD
         WHEATfIELD
         MINNEAPOLIS
         BECKER
         BECKER
         BECKER
         BEULAH
         COLLINSVILLE
         COLLINSVILLE
         ROCK  SPRINGS
         SHIPPINGPORT
         SHIPPINGPORT
         SHIPPINGPORT
         PHOENIXVILLE
         EDDYSTONE
         ECDYSTONE
         EDDYSTONE
         DICKERSON
        PRINCETON
        WATERFLOW
        WATERFLOW
        yATERFLOU
        WATERFLOW
        NEW YORK
        ST. JOHNS
        ST. JOHNS
        ST. JOHNS
                                         SAN  MIGUEL
                        NEW YORK
                        NEW YORK
 INDIANA
 INDIANA
 INDIANA
 MINNESOTA
 MINNESOTA
 MINNESOTA
 MINNESOTA
                        NORTH DAKOTA
 CALIFORNIA
 CALIFORNIA
                        WYOMING
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
                        MARYLAND
                        INDIANA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW M5XICO
                        NEW  YORK
ARIZONA
ARIZONA
ARIZONA
                                                         TEXAS
                                          6/84
7/76
6/83
6/65
7/80
3/76
4/77
5/84
3/61
6/67
6/68
1
4
4
2
1
1
5
2
6
e
E
A
A
E
D
D
C
E
C
C
                                          9/79
12/75
 7/77
10/8?
 9/75
12/82
12/fc2
                                          5/87
                                          0/82
 4/78
 8/7P
12/79
 6/62
                                         11/87
11/79
 7/80
 6/87
 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  FGD SYSTEMS;  ALSO ALTERNATIVE METHODS
 A.   FEDERAL NSPS(6/79)
 B.   FEDERAL NSPSM2/71)
 C.   STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
 D.   STANDARD(S) WORE STRINGENT THAN NSPSC12/71)  BUT  NOT  MORE  STRINGENT THAN NSPS(6/79)
 E.   STANDARD(S) EQUAL TO OR LESS STRINGENT THAN  NSPS(1?/71)

-------
                                           EPA UTILITY  FGO SURVEY: JANUARY  - MARCH  1980

                                           SECTION  1
                                  SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
SE11NOLE ELECTRIC
SEM1NOLE
SEMINOLE
UNIT
1
2
NO. UNIT LOCATION
PALATKA FLORIDA
PALATKA FLORIDA
START-UP
DATE
3/83
3/85
REG
STATUS CLASS
3 A
3 A
SIKESTON BOARD OF MUNIC. UTIL.
   SIKESTON                    1

SOUTH CAROLINA PUBLIC SERVICE
   WINYAH                      2
   WINYAH                      3
   WINYAH                      4
   SIKESTON       MISSOURI           1/81
   GEORGETOWN     SOUTH  CAROLINA     7/77
   GEORGETOWN     SOUTH  CAROLINA     5/80
   GEORGETOWN     SOUTH  CAROLINA     7/81
SOUTH MISSISSIPPI ELEC PWR
   R.D. MORROW                  1
   R.D. MORROW                  2
   HATTISBURG
   NATTISBURG
MISSISSIPPI
MISSISSIPPI
8/78
6/79
SOUTHERN ILLINOIS POWER COOP
   MARION
   MARION

SOUTHERN INDIANA GAS & ELEC
   A.B. BROUN
   MARION
   MARION
ILLINOIS
ILLINOIS
                                         WEST  FRANKLIN  INDIANA
 5/79
 0/66
                                     4/79
SOUTHWESTERN ELECTRIC POWER
   HENRY W. PIRKEV              1

SPRINGFIELD CITY UTILITIES
   SOUTHWEST                    1
    HALLSVILLE
                   TEXAS
    SPRINGFIELD    MISSOURI
                                    12/84
                                     4/77
SPRINGFIELD WATER,  LIGHT  &  PWR
   DALLMAN                      3

ST. JOE ZINC
   G.F. WEATON                  1
    SPRINGFIELD    ILLINOIS
                                         MONACA
                                    11/80
                   PENNSYLVANIA     11/79
TAMPA  ELECTRIC
   BIG BEND                     4

TENNESSEE  VALLEY  AUTHORITY
   JOHNSONVILLE                 1-10
   PARADISE                     1
   PARADISE                     2
   SHAWNEE                     10A
   SHAWNEE                     106
   WIDOWS  CREEK                 7
   WIDOWS  CREEK                 8

TEXAS  MUNICIPAL  POWER AGENCY
   GIBBONS CREEK                1

TEXAS  POWER  t LIGHT
   SANDOy                       4
   TWIN  OAKS                   1
   TWIN  OAKS                   2

TEXAS  UTILITIES
   FOREST  GROVE                 1
   MARTIN  LAKE                 1
   MARTIN  LAKE                 2
   MARTIN  LAKE                 3
   MARTIN  LAKE                 4

1.   OPERATIONAL  UNITS           4.
2.   UNITS  UNDER  CONSTRUCTION    5.
3.   PLANNED - CONTRACT AWARDED  6.
                                 7.
    TAMPA
                   FLORIDA
    NEW JOHNSONVILLTENNESSEE
    PARADISE
    PARADISE
    PADUCAH
    PADUCAH
    BRIDGEPORT
    BRIDGEPORT
    CARLOS
    ROCKDALE
    BREMOND
    BREMOND
    ATHENS
    TATUM
    TATUM
    TATUM
    TATUN
 KENTUCKY
 KENTUCKY
 KENTUCKY
 KENTUCKY
 ALABAMA
 ALABAMA
                   TEXAS
 TEXAS
 TEXAS
 TEXAS
 TEXAS
 TEXAS
 TEXAS
 TEXAS
 TEXAS
                                     3/85
12/81
 3/82
 6/82
 4/72
 4/72
 9/81
 5/77
                   1/82
 7/80
 8/84
 8/85
 0/81
 4/77
 5/78
 2/79
 0/85
PLANNED - LETTER OF    INTENT  SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING F6D SYSTEMS;  ALSO  ALTERNATIVE METHODS
 A.   FEDERAL NSPSC6/79)
 B.   FEDERAL NSPSH2/71)
 C.   STANDARDS) MORE STRINGENT THAN NSPSC6/79)
 D.   STANDARDS) MORE STRINGENT THAN NSPS<12/71>  BUT NOT MORE STRINGENT THAN NSPSJ6/79)
 E.   STANDARDS) EQUAL TO OR LESS STRINGENT  THAN  NSPS<12/71>

-------
EPA UTILITY F60 SURVEY: JANUARY - MARCH  198C
                                              SECTION  1
                                    SUMMARY  LIST  OF  FGD  SYSTEMS
  COMPANY NAME/
     UNIT NAME
                                 UNIT NO. UNIT  LOCATION
                                         START-UP
                                          DATE
                                   REG
                           STATUS  CLASS
  TEXAS UTILITIES
     MILL CREEK
     MILL CREEK
     MONTICELLO

  TUCSON ELECTRIC POWER
     SPRINGERVILLE
     SPRINGERVILLE

  UNITED POWER ASSOCIATION
     STANTON

  UTAH  POWER K LIGHT
     HUNTER
     HUNTER
     HUNTER
     HUNTER
     HUNT1NGTON
         HENDERSON
         HENDERSON
         MT. PLEASANT
         SPRINGERVILLE
         SPRINGERVILLE
         STANTON
         CASTLE DALE
         CASTLE DALE
         CASTLE DALE
         CASTLE DALE
         PRICE
TEXAS
TEXAS
TEXAS
ARIZONA
ARIZONA
NORTH DAKOTA
UTAH
UTAH
UTAH
UTAH
UTAH
C/85
0/86
5/78
6/65
1/87
                                          1/62
5/79
6/8P
0/83
0/85
5/78
 1.  OPERATIONAL UNITS
 2.  UNITS UNDER CONSTRUCTION
 3.  PLANNED - CONTRACT AWARDED
4.  PLANNED - LETTER  OF     INTENT  SI6NED
5.  PLANNED - REQUESTING/EVALUATING  BIDS
6.  PLANNED - CONSIDERING  ONLY  F6D SYSTEMS
7.  PLANNED - CONSIDERING  FGD SYSTEMS;  ALSO ALTERNATIVE METHODS
 A.  FEDERAL NSPS(6/79)
 B.  FEDERAL NSPSC12/71)
 C.  STANDARDS) MORE STRINGENT  THAN  NSPS<6/79>
 D.  STANDARDS) MORE STRINGENT  THAN  NSPS<12/71>  BUT NOT MORE STRINGENT THAN NSPS<6/79>
 E.  STANOARD(S) EQUAL TO OR LESS  STRINGENT  THAN  NSPS<12/71>

-------
                                              EPA UTILITY fGO SURVEY: JANUARY - MARCH 1980
                                              SECTION 2
                                        STATUS  Of  FGO SYSTEMS
JNIT IDENTIFICATION
                                                                  ABSTRACT
ALABAMA ELECTRIC COOP
TOMBIGBEE
2
HEW       255.0 MU (GROSS)
          179.0 MU (ESC)
COAL
 1.15 US  BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION:  3. IX
STATUS 1     STARTUP  9/78
TOMBIGBEE 2 OF ALABAMA  ELECTRIC  COOP  IS  A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA. THE  BOILER  GENERATES  A MAXIMUM FLUE GAS FLOW OF 953.OCO
ACFM AND BURNS BITUMINOUS  COAL  WITH AN  AVERAGE SULFUR CONTENT OF 1.ZX AND
AN AVERAGE HEAT CONTENT  OF  11,500  BTU/LB. THE  UNIT SO? EMMISSION LIMITA-
TION VALUE IS 1.2 LB/HMBTU.  PRIMARY PARTKULATE MATTER CONTROL JS PROVID-
ED BY A HOT SIDE ESP. THE  S02  REMOVAL EOUIPMENT CONSISTS OF TWO SPRAY
TOWERS SUPPLIED BY PEABODV  PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REA-
GENT. A CHEVRON MIST  ELIMINATOR  IS INCLUDED FOR EACH TOWER AND THE FLUE
GAS is REHEATED WITH  BYPASSED  GAS  BEFORE  BEING VENTED TO A too FOOT ACID-
BRICK LINED STACK. THE  SYSTEM  OPERATES  IN AN OPEN WATER LOOP MODE AND
SPENT ABSORBENT IS DISPOSED  OF  IN  AN  ON-SITE LINED POND.
ALABAMA ELECTRIC COOP
TOMBIGBEE
3
MEW       255.0 MU (GROSS)
          179.P MU (ESC)
COAL
 1.15 ZS  BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION:   3. IX
STATUS 1     STARTUP  6/79
TCMBI66EE 3 OF ALABAMA  ELECTRIC  COOP  IS  A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA. THE  BOILER  GENERATES  A MAXIMUM FLUE GAS FLOW OF 953,OCO
ACFM AND BURNS BITUMINOUS  COAL WITH AN AVERAGE SULFUR CONTENT OF 1.2X AND
AN AVERAGE HEAT  CONTENT  OF  11,500 BTU/LB . THE UNIT SO? EMISSION LIMITATION
VALUE IS 1.2 LB/MMBTU.  PRIMARY PARTICULATE CONTROL IS PROVIDED BY A HOT
SIDE ESP. THE S02 REMOVAL  EQUIPMENT CONSISTS OF TWO SPRAY TOWERS SUPPLIED
BY PEABODY PROCESS SYSTEMS  WHICH UTILIZE  A LIMESTONE REAGENT. A CHEVRON
MIST ELIMINATOR  IS INCLUDED IN EACH TOWER, AND THE FLUE GAS IS REHEATED
WITH BYPASSED GAS BEFORE BEING VENTED TO  A 400 FOOT ACID BRICK LINED
STACK. THE SYSTEM OPERATES  IN  AN OPEN WATER LOOP MODE, AND SPENT ABSORBENT
IS DISPOSED IN AN ON-SITE  LINED  POND.
ALLEGHENY POWER SYSTEM
1ITCHELL
33
RETROFIT  300.0 MU  (GROSS)
          300.0 MU  (ESC)
COAL
 2.80 XS  BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION:   1.U
STATUS 3      STARTUP  8/82
UNIT 33 AT ALLEGHENY  POWER  SYSTEM'S MITCHELL POWER STATION IN COURTNEY,
PENNSYLVANIA  IS  A  2.8X  SULFUR COAL FIRED BOILER.  A CONTRACT WAS
AWARDED TO CHE*!C0 FOR  A LIME SCRUBBING PROCESS.  S02 REMOVAL
EFFICIENCY WILL  BE 9SX.   START UP IS PLANNED FOR  AUGUST OF 1982.
ALLEGHENY POWER  SYSTEM
PLEASANTS
1
NEW       625.0  MU  (GROSS)
          519.P  MU  (ESC)
COAL
 3.70 XS  BITUMINOUS
LIME
BABCOCK S WILCOX
ENERGY CONSUMPTION: ****X
STATUS 1      STARTUP   3/79
ALLEGHENY POUER  SYSTEM'S  PLEASANTS 1 IS A BITUMINOUS COAL  (3.7CZ  S.  12.150
BTU/LB)  FIRED  BOILER  IN  BELMONT, WEST VIRGINIA. BABCOCK  ANO  UlLCOK  SUP-
PLIED A  LIME  FGD  SYSTEM  DESIGNED TO REMOVE 90* 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  DISCHARGES THROUGH A 1?00 FOOT  PLAC1TE LINED
STACK. THE  SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGD  SYSTEM  ON  THIS
UNIT HAS BEEN  OPERATIONAL SINCE MARCH OF 1979.
ALLEGHENY  POUER  SYSTEM
PLEASANTS
2
KEU        625.0  MU  (GROSS)
           519.0  MU  (ESC)
COAL
 4.50  XS   BITUMINOUS
LIME
aABcOcK (  WILCOX
ENERGY  CONSUMPTION: *•**»
STATUS  I      STARTUP   9/80
 ALLEGHENY  POUER  SYSTEM'S PLEASANTS 2 IS  A BITUMINOUS  COAL (3.7X  S,  12,150
 BTU/LB)  FIRED  BOILER UNDER CONSTRUCTION  IN BELMONT,  WEST  VIRGINIA.  BABCOCK
 AND  UILCOX IS  SUPPLYING A LIME FGD SYSTEM DESIGNED  TO REMOVE  9OX 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 GAS BEFORE  IT IS  DISCHARGED THROUGH A
 1200  FOOT  PLACITE LINED STACK. THE SYSTEM UILL  OPERATE  IN AN  OPEN WATER
 LOOP. FGD  SYSTEM START UP IS EXPECTED IN SEPTEMBER,  1980.
ARIZONA  ELECTRIC  POUER  COOP
APACHE
2
MEW        195.0  MU  (GROSS)
           195.0  MU  (ESC)
COAL
   .55  XS  BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY  CONSUMPTION:  4.11
STATUS  1     STARTUP  8/78
 APACHE  2  OF  ARIZONA ELECTRIC POUER COOP IS LOCATED  IN  COCH1SE.  ARIZONA AND
 IS  A  DRV  BOTTOM PULVERIZED COAL FIRED UNIT WITH  A FLUE  GAS  FLOW  OF  735,000
 ACFN. BITUMINOUS COAL UITH A HEATING VALUE OF  10.000  BTU/LB,  A  SULFUR CON-
 TENT  Of  0.7X AND AN ASH CONTENT OF 15* IS THE  FUEL  USED  (OR  THIS UNIT.
 PARTICULATE  CONTROL IS EFFECTED BY A HOT SIDE  ESP.  THE  UNIT  IS  CURRENTLY
 IN  OPERATION UITH STARTUP IN AUGUST  1978. TUO  PACKED  TOWERS  EMPLOYING
 LIMESTONE ABSORBENT AND HAVING A DESIGN S02  REMOVAL OF  85*  WERE  SUPPLIED
 Bt  RESEARCH  COTTRELL. MIST ELIMINATION IS PROVIDED  BY  CHEVRON TYPE  ELIMI-
 NATORS.  NO REHEAT is EMPLOYED. A too FT COLE  BRAND  CXL2000  LINED STACK is
 IN  USE.  THE  SYSTEM OPERATES IN AN OPEN UATER  LOOP MODE AND  WASTE MATERIAL
 IS  DISPOSED  OF IN OFF-SITE SLUDGE PONDS.

-------
 EPA UTILITY F6D SURVEY: JANUARY  - MARCH  1980
                                               SECTION 2
                                         STATUS  OF  FGO SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 ARIZONA ELECTRIC POWER COOP
 APACHE
 3
 HEW        195.0 MW (CROSS)
           195.0 MW (ESC)
 COAL
   .55 XS  BITUMINOUS
 LIMESTONE
 RESEARCH COTTRELL
 ENERGY CONSUMPTION:  4.11
 STATUS 1     STARTUP  6/79

 ARIZONA PUBLIC  SERVICE
 CHOLLA
 1
 RETROFIT  119.0 MW (GROSS)
           119.C MU (ESC)
 COAL
   .50 XS  BITUMINOUS
 LIMESTONE
 RESEARCH COTTRELL
 ENERGY CONSUMPTION:  3.4X
 STATUS 1     STARTUP 10/73
 APACHE  3  OF  ARIZONA ELECTRIC POWER COOP  IS A  DRY BOTTOM,  PULVERIZED  COAL
 FIRED  UNIT  IN COCHISE. ARIZONA. LOW (0.72) SULFUR BITUMINOUS  COAL  WITH AN
 AVERAGE  HEATING VALUE OF 10,000 BTU/L.B PRODUCES A MAXIMUM  FLUE  GAS FLOW OF
 735,000  ACFM. THE FLUE GAS PASSES THROUGH A HOT SIDE  ESP  TO TWO RESEARCH
 COTTRELL  PACKED TOWERS, WHERE LIMESTONE  IS USED TO REMOVE  B5X  (DESIGN) Or
 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  f&O
 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 ?0 YEARS* CAPACITY.

 ARIZONA  PUBLIC SERVICE'S CHOLLA 1 IS LOCATED  IN JOScPH CITY,  ARIZONA  AND
 IS A TAN6ENTIALLV FIRED, W£T BOTTOM PULVERIZED COAL UNIT.  IT  IS FUELED BY
 BITUMINOUS  COAL THAT HAS A SULFUR CONTENT OF  C.5X AND A HEATING VALUE OF
 10,150 BTU/LB. PARTICULATE MATTER IS CONTROLLED BY TWO FLOODED  DISC  SCRUB-
 BERS.  THE FGD SYSTEM BEGAN IN OCTOBER, 1973 AND IS NOW OPERATIONAL.  502 js
 CONTROLLED  BY ONE TOWER WITH MUNTERS PACKING  EMPLOYING A  LIMESTONE
 ABSORBENT.   THE UNIT WAS SUPPLIED BY RESEARCH COTTRELL AN 0 HAS  A DESIGN
 REMOVAL  OF  921.  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        350.0 «W (GROSS)
           350-0 Mw (ESC)
 COAL
   .50 XS  BITUMINOUS
 LIMESTONE
 RESEARCH COTTRELL
 ENERGY  CONSUMPTION: •**.»
 STATUS  1     STARTUP  4/78
CHOLLA  ?  OF  ARIZONA  PUBLIC SERVICE IS LOCATED IN JOSEPH CITY,  ARIZONA.  THE
BOILER  BURNS PULVERIZED BITUMINOUS COAL (0.5X S, 10,150 BTU/LB).  MECHANI-
CAL  COLLECTORS  PROVIDE PRIMARY PARTICULATE CONTROL.   FOUR  PARALLEL
FLOODED DISC AND  PACKED TOWER S02 ABSORBER TRAINS (THREE ARE REQUIRED FOR
FULL LOAD)  REMOVE THE FLUE GAS SO?.   THE DESIGN SO?  REMOVAL FOR  THE
SYSTEM, WHICH BEGAN  OPERATIONS IN APRIL, 1978, IS 75X.  THE CLEANED  GAS
PASSES  THROUGH  AN IN-LINE STEAM REHEATER INTO AN ACID BRICK LINED STACK.
THE  OPEN  WATER  LOOP  SYSTEM DEPOSITS ITS SLUDGE INTO A FLY  ASH  POMC.
ARIZONA  PUBLIC  SERVICE
CHOLLA
t
NEW        3SO.O MW  (GROSS)
           126.0 MW  (ESC)
COAL
   .50 XS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: »**«X
STATUS 2     STARTUP  6/80
CHOLLA 4 OF  ARIZONA  PUBLIC  SERVICE IS PRESENTLY UNDER CONSTRUCTION  IN
JOSEPH CITY,  ARIZONA.  START UP IS SCHEDULED FOR JUNE, 1960.  THE  PULVERIZFA
COAL  (0.5X  S,  10,150 BTU/LB) FIRED BOILER WILL EXHAUST FLUE  GAS  THROUGH AN
ESP TO A PACKED  TOWER  WHICH WILL TREAT 36X OF THE GAS WITH LIMESTONE.
ARIZONA  PUBLIC  SERVICE
FOUR CORNERS
1
RETROFIT   175.0  MW  (GROSS)
           175.0  MW  (ESC)
COAL
  .75 XS   SUBBITUMINOUS
LIME/ALKALINE FLYASH
CHEMICO
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  FARHIN6TON, NEW MEXICO TO HANDLE  ADDITIONAL
SO? 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  SO?
REMOVAL EFFICIENCY  SINCE THE  CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS  67.5X.  OPERATIONS  COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC  SERVICE
FOUR CORNERS
2
RETROFIT  175.0 MW  (GROSS)
          175.0 MU  (ESC)
COAL
  .75 XS  SUBBITUMINOUS
LIME/ALKALINE FLYASH
CHEMICO
ENERGY CONSUMPTION: *****
STATUS 1     STARTUP  11/79
ARIZONA PUBLIC SERVICE  HAS  UPGRADED  THE OPERATIONAL PARTICULATE  SCRUBBERS
AT FOUR CORNERS  1,2,  AND  3  IN  FARMIN6TON, NEW MEXICO TO HANDLE ADDITIONAL
SO? REMOVAL. INITIALLY, THE FRONT FIRED, DRV BOTTOM, PULVERIZED  COAL  (SUB-
BITUMINOUS, 0.75X S,  8650 BTU/LB) UNITS 1 AND 2 SUPPLY 814,000 ACFM EACH
INTO ? CHEMICO VENTURI  SCRUBBERS  PER UNIT FOR PRIMARY PARTICULATE CONTROL
AND APPROXIMATELY 301 S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN  SO?
REMOVAL EFFICIENCY SINCE  THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67.SX. OPERATIONS  COMMENCED IN NOVEMBER, 1979.

-------
                                              EPA  UTILITY  FGD  SURVEY: JANUARY - MARCH 1980
                                              SECTION  i
                                        STATUS  OF  FGD  SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
ARIZONA PUBLIC SERVICE
FOUR CORNERS
J
RETROFIT  229." MU (GROSS)
          229.0 MW (ESC)
COAL
  .75 ZS  SUBBITUMINOUS
LIME/ALKALINE FLYASM
CHEMICO
ENERGY CONSUMPTION: *****
STATUS 1     STARTUP  11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE  OPERATIONAL  PART1CULATE  SCRUBBERS
AT FOUR CORNERS 1,2. AND * IN FARMIN6TON,  NEW  MEXICO  TO  HANDLE  ADDITIONAL
S02 REMOVAL. INITIALLY, THE FRONT FIRED, DRY BOTTOM,  PULVERIZED  COAL  (SUE-
BITUMINOUS, 0.75X S, 8650 BTU/LB) UNIT 3 SUPPLIES  1,030,0*0.  ACfM  INTO  2
CHEMICO VfNTURl SCRUBBERS FOR PRIMARY PARTICIPATE  CONTROL  AND  APPROXIMATE-
LY 301 502 REMOVAL USING ALKALINE FLY ASH.  THE DESIGN SO^  REMOVAL EFFICI-
ENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH SCRUBBING  IS  6?.5Z.
OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
4
RETROFIT  7SS.O MW (GROSS)
          755.0 MW 
COAL
  .75 XS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: ****X
STATUS 3     STARTUP  0/82
ARIZONA PUBLIC SERVICE AWARDED A  CONTRACT  TO  UNITED  ENGINEERS  FOR A LIME
FGD SYSTEM TO BE RETROFITTED ONTO UNITS  4  AND  5  AT  ITS  FOUR  CORNERS STA-
TION IN FARMIN6TON, 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,  6650 BTU/LB)  FIRED UNITS.
THE PARTKULATE EMISSIONS ARE HANDLED  BY AN  ESP. START  UP  IS  EXPECTED IN
1982.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5
RETROFIT  755.0 MW (GROSS)
          755.0 MW (ESC>
COAL
  .75 XS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: ****X
STATUS 3     STARTUP   0/82
ARIZONA PUBLIC SERVICE AWARDED  A CONTRACT  TO  UNjTED  ENGINEERS FOR A LIME
FGD SYSTEM TO BE RETROFITTED  ONTO UNITS  4  AND  5  AT  ITS  FOUR  CORNERS STA-
TION IN FARM1NGTON, NEy MEXICO. BASED  ON THE  PROTOTYPE  HORIZONTAL SCRUB-
BING PROGRAM CONDUCTED BY  THE UTILITY, A HORIZONTAL  SYSTEM WAS CHOSEN TO
CONTROL THE EMISSIONS FROM THESE COAL  (0.75*  S,  8650 BTU/LB) FIRED UNITS.
THE PARTICULATE EMISSIONS  ARE HANDLED  BY AN  ESp. START  UP IS EXPECTED IN
1982.
ASSOCIATED ELECTRIC COOP
THOMAS HILL
3
NEW       730.C MW  (GROSS)
          670.0 MW  (ESC)
COAL
 4.80 ZS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: ****X
STATUS 2     STARTUP   1/82
THOMAS HILL 3 OF ASSOCIATED  ELECTRIC  COOP IS  A PULVERIZED COAL (A.8Z S,
9,700 BTU/LB) FIRED  UNIT  LOCATED  IN  MOBERLY,  MISSOURI. TWO COLD SIDE fSP'S
WILL PRECEDE THE FOUR 91.51  EFFICIENT PULLMAN KELLOGG HORIZONTAL WEIR FGD
MODULES USING MAGNESIUM-PROMOTED  LIMESTONE  AS THE ABSORBENT. THE CLEANED
GAS WILL PASS THROUGH A VERTICAL  CHEVRON MIST ELIMINATOR TO A 620 FOOT
BRICK LINED STACK. REHEAT  WILL  BE  ACCOMPLISHED BY BYPASS. DRY FIXATED
SLUDGE WILL BE TRUCKED TO  AN ACTIVE  STRIP MINE. THE SYSTEM WILL USE A
CLOSED WATER LOOP. THE FGO SYSTEM IS  UNDER  CONSTRUCTION AND START UP IS
EXPECTED IN JANUARY,  1982.
9ASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
1
NEW       440.C MW  (GROSS)
          440.0 MW  (ESC)
COAL
  .68 XS  LIGNITF
LIME/SPRAY  DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION:   .OX
STATUS 2     STARTUP   4/82
UNIT 1 Of BASIN ELECTRIC  POWER  COOP'S  ANTELOPE VALLEY PLANT IS PRESENTLY
UNDER CONSTRUCTION  IN  BEULAH,  NORTH  DAKOTA. THIS UNIT WILL BURN PULVERIZED
COAL (0.68X S, 6600  BTU/LB  LIGNITE)  AND SUPPLY 2,055,000 ACFH TO A DRY
LIME FGD SYSTEM SUPPLIED  BY  WESTERN  PRECIPITATION. THE 62X EFFICIENT
SYSTEM WILL CONSIST  OF 5  NIRO  ATOMIZER  SPRAY DRYERS AND TWO BAGHOUSES.
THE CLEANED GAS,  ALONG WITH  A  4X  BYPASS REHEAT, WILL EXIT A 600 FOOT
PVC LINED STACK.  THE SYSTEM  WILL  USE  A  CLOSED WATER LOOP AND THE DRY
POWDER WILL BE USED  FOR LANDFILL  IN  A  COAL MINE. START UP IS EXPECTED
IN APRIL, 1982.
BASIN ELECTRIC  POWER  COOP
ANTELOPE VALLEY
2
NEW       440.0 MW  (GROSS)
          440.0 MW  
COAL
   .68 XS  LIGNITE
LIME/SPRAY  DRYING
VENDOR  NOT  SELECTED
ENERGY  CONSUMPTION:   .OX
STATUS  5      STARTUP   4/84
ANTELOPE VALLEY  2  OF  BASIN  ELECTRIC  POWER COOP WILL BE LOCATED IN BEULAH,
NORTH DAKOTA.  THE  UTILITY  IS  PRESENTLY CONSIDERING VARIOUS FGD PROCESSES
FOR THIS LIGNITE  (0.68X  S,  6600 BTU/LB) FIRED UNIT. THE UNIT WILL BE
REQUIRED TO  COMPLY WITH  STATE EMISSIONS STANDARDS VIA BEST AVAILABLE
CONTROL TECHNOLOGY. START  UP  IS SCHEDULED FOR APRIL, 1964.

-------
 EPA  UTILITY FGD SURVEY: JANUARY - MARCH  1980
                                               SECTION Z
                                         STATUS  OF  fGD SYSTEMS
 UNIT  IDENTIFICATION
                                                                   ABSTRACT
 BASIN ELECTRIC POWER COOP
 LARANIE  RIVER
 1
 NEW        570.C MW (GROSS)
           600.0 MW (ESC)
 COAL
   .81 2S  SUBBITUMINOUS
 LIMESTONE
 RESEARCH COTTRELL
 ENERGY CONSUMPTION:   .OX
 STATUS 2     STARTUP  4/80
 BASIN  ELECTRIC  POWER  COOP'S LARAMIE RIVER 1 IS PRESENTLY  UNDER  CONSTRUC-
 TION  IN  WHEATLANO,  WYOMING. THE PULVERIZED CO»L (0.81t S,  8139  BTU/LB)
 FIRED  BOILER  HILL FEED 2,300.000 ACFM OF FLUE GAS THROUGH  A  COLD  5IDE
 ESP  TO FIVE  RESEARCH  COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH  WILL
 REMOVE 90X Of THE S02. THE CLEANED GAS WILL EXIT FROM A VERTICAL  CHEVRON
 DEMISTER  INTO A  600 FOOT ACID BRICK LINED STACK. NO REHEAT WILL BE USED.
 THE  FLYASH FIXATED  SLUDGE WILL BE DEwATERED TO "3X SOLIDS  BEFORE  PE1NG
 LANDFILLED,  AND  THE SYSTEM WILL EMPLOY A CLOSED WATER LOOP.  START UP  IS
 SCHEDULED FOR APRIL,  198C.
 BASIN ELECTRIC  POWER COOP
 LARAMIE  RIVER
 2
 NEW        570.0 MW  
           600.0 MW  USO
 COAL
   .81 IS  SUBBITUMINOUS
 LIMESTONE
 RESEARCH COTTRELL
 ENERGY CONSUMPTION:   .OX
 STATUS 2    STARTUP 11/80
BASIN ELECTRIC  POWER  COOP'S  LARAMIE RIVER 2 IS PRESENTLY UNDER  CONSTRUC-
TION IN WHEATLAND,  WYOMING.  THE  PULVERIZED COAL (D.81X S, 8139  BTU/LB)
FIRED BOILER  WILL  FEED  2,300,000 ACFN OF FLUE GAS THROUGH A OLD  SIDE
ESP TO FIVE RESEARCH  COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH  WILL
REMOVE 90X Of THE  S02.  THE  CLEANED GAS WILL EXIT FROM A VERTICAL  CHEVRON
DEMISTER INTO A  600 FOOT  ACID BRICK LINED STACK. NO REHEAT WILL  BE USED.
THE FLYASH FIXATED  SLUDGE WILL BE DEWATERED TO P3X SOLIDS BEFORE  BEING
LANDFILLED, AND  THE SYSTEM  WILL  EMPLOY A CLOSED WATER LOOP. START UP  IS
SCHEDULED FOR NOVEMBERt  1980.
 BASIN  ELECTRIC  POWER  COOP
 LARAMIE  RIVER
 3
 NEW        570.C MW  
-------
                                             EPA UTILITY  FGO  SURVEY:  JANUARY  -  MARCH  I960
                                             SECTION 2
                                       STATUS Of  FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
BIG DIVERS ELECTRIC
SREEN
2
NEW       242.0 MW (GROSS)
          242.C MU (ESC)
COAL
 3.75 XS  BITUMINOUS
LIKE
AMERICAN AIR FILTER
ENERGY CONSUMPTION: ****X
STATUS 2     STARTUP 11/80
UNIT 2 OF BIG RIVERS ELECTRlC'S GREEN STATION IS BEING CONSTRUCTED  IN
SEBREE, KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75X S,  9750  BTU/LB)
FIRED BOILER WILL SUPPLY 1,000.000 ACFM  TO A COLO  SIDE ESP  FOLLOWED  BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH WILL  REMOVE  90*  Of  THE
S02. THE CLEANED GAS WILL PASS THROUGH A CHEVRON MIST ELIMINATOR  AND
WILL EXIT A SAUERISEN 72 LINED STACK AfTER IT IS HEATED BY  STEAM  COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM U1LL  BE POZ-0-TEC
STABILIZED. START UP IS SCHEDULED FOR NOVEMBER, 19fa0.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
NEW       416.0 MH (GROSS)
          378.0 MU (ESC)
COAL
 3.30 IS  BITUMINOUS
LIMESTONE
RILEY STOKER/ENVIRONEERING
ENERGY CONSUMPTION:   2.9*
STATUS 1     STARTUP  7/76
DUCK CREEK 1 OF CENTRAL ILLINOIS LIGHT  IS LOCATED  IN  CANTON,  ILLINOIS.  THE
BALANCED DRAFT, FRONT FIRED, DRY BOTTOM  UNIT  BURNS  PULVERIZED  BITUMINOUS
COAL (3.3* S. 10,500 BTU/LB) AND SUPPLIES 2,415,000 ACFM  OF  FLUE  GAS  TO
TWO COLO SIDE ESP'S FOLLOWED BY  FOUR  RILEY  STOKER/ENVIRONEERING  ROD  DECK
SPRAY TOwER MODULES. THE  FGD SYSTEM HAS  BEEN  OPERATIONAL  (ONE  MODULE)
SINCE JULY, 1976, AND IS  DESIGNED TO  REMOVE 85X  OF  THE  SO?.  HORIZONTAL
CHEVRON MIST ELIMINATORS  FOLLOW  THE ABSORBERS, AND  THE  CLEANED GAS  EXITS
TO A 500 FOOT CEILCOTE LINED STACK WITHOUT  REHEAT.  THE  SYSTEM  OPERATES  IN
A CLOSED WATER LOOP. AND  THE SLUDGE IS  DISPOSED  OF  IN AN  ON  SITE  CLAY
LINED POND.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
2
NEW       450.0 MW  (GROSS)
          416.0 MU  (ESC)
COAL
  3.3?  ZS  BITUMINOUS
LIMESTONE
VENDOR NOT  SELECTED
ENERGY CONSUMPTIONr *••*»
STATUS 5      STARTUP   1/86
CENTRAL  ILLINOIS LIGHT  IS  CURRENTLY  EVALUATING  BIDS ON A LIMESTONE OR DUAL
ALKALI FGD SYSTEM  FOR UNIT  2  OF  ITS  DUCK  CREEK  STATION.  THE BITUMINOUS
COAL FIRED BOILER  WILL  FEED  ITS  FLUE  GAS  THROUGH A COLD  SIDE ESP. THE
SYSTEM WILL OPERATE  IN  A CLOSED  WATER LOOP AND  IS SCHEDULED TO BEGIN
OPERATIONS IN JANUARY,  1986.
CENTRAL  ILLINOIS  PUBLIC  SERV
NEWTON
1
NEW       617.0 MU  (GROSS)
          617.0 MU  (ESC)
COAL
 2.25  XS BITUMINOUS
DJAL ALKALI
3UELL/ENVIROTECH
ENERGY  CONSUMPTION: ****X
STATUS  1     STARTUP   9/79
NEWTON  1 OF  CENTRAL  ILLINOIS  PUBLIC  SfRVICE 1$ A TANGENTlALLY FIRED, DRV
BOTTOM, PULVERIZED BITUMINOUS  COAL U*  S, 10,900 RTU/Lb) FIRED UNIT
LOCATED IN NEWTON, ILLINOIS.  A COLD  SIDE ESP RECEIVES 2,163,480 ACFM
OF FLUE GAS  AND  FEEDS  IT  TO  FOUR  BUELL  ENV1ROTECH POLYSPHERE PACKED
TRAY TOWERS  FOLLOWED BY  TWO  VERTICAL MJST ELIMINATORS PER MODULE. THE
CLEANED 6AS  IS BOOSTED 25 OEG  F BY A COMBINATION OF TWO DIFFERENT TYPES
OF IN-LINE REHEATERS PLUS BYPASS  REHEAT, AND THFN EXITS A 53C FOOT
PRECRETE LINED STACK.  THE WATER LOOP IS CLOSED, AND THE SLUDGE IS
POZ-0-TEC TREATED.
 CENTRAL  MAINE  POUER
 SEARS  ISLAND
 1
 NEtf        600.0  MU  (GROSS)
           600.0  MU  (ESC)
 COAL
 • •*•*  X S
 PROCESS  NOT  SELECTED
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION:  • •**«
 STATUS 6     STARTUP   1/89
 SEARS  ISLAND  1  IS  A  PLANNED UNIT TO BE BUILT ON PENOBSCOT BAY BY  CENTRAL
 MAINE  POUER.  BECAUSE  OF THE DISCOVERY OF A GEOLOGICAL FAULT ON SEARS
 ISLAND,  PLANS FOR  A  1150 MU NUCLEAR POWER PLANT HAVE BEEN REPLACED WITH
 PLANS  FOR  A 600 MU COAL FIRED PLANT. LIME AND LIMESTONE SCRUBBING ARE
 THE  PRIMARY METHODS  BEING CONSIDERED FOR COMPLIANCE WITH THE NSPS. IT
 WILL BE  TUO YEARS  BEFORE ALL PERMITS REQUIRED HAVE BEEN RECEIVED. START
 UP  IS  SCHEDULED FOR  JANUARY, 1989.
 CINCINNATI  GAS  & ELECTRIC
 EAST  BENO
 1
 NEW        650*0 MU (CROSS)
           650.0 MW (ESC)
 COAL
 **•** XS
 PROCESS  NOT SELECTED
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION:  2.9X
 STATUS 6     STARTUP  O/ 0
 CINCINNATI  GAS  AND ELECTRIC HAS PLANS FOR A NEW UNIT, EAST BEND 1, TO
 BE  LOCATED  ADJACENT TO EAST BENT 2 AT THE RABB1THASH, KENTUCKY SITE.   THE
 COAL  FIRED  BOILER WILL HAVE A GENERATING CAPACITY OF 650MW.  THE UNIT'S
 EXPECTED  START  UP HAS NOT BEEN OETERHINE6.
                                                  11

-------
 EPA UTILITY FGC SURVEY: JANUARY - MARCH  1980
                                               SECTION i
                                         STATUS  OF  FGD SYSTEMS
 JNIT IDENTIFICATION
                                                                   ABSTRACT
 CINCINNATI GAS & ELECTRIC
 EAST BEND
 2
 MEW       650.0 wy (GROSS)
           650.0 MU (ESC)
 COAL
  5.CO XS
 LIME
 BABCOCK K UILCOX
 ENERGY CONSUMPTION:  2.9*
 STATUS 2     STARTUP  9/80
 E«ST  BEND  2  OF CINCINNATI GAS AND ELECTRIC IS  A PULVERIZED  COAL  <5][  S)
 FIRED BOILER UNDER CONSTRUCTION IN RABBITHASH, KENTUCKY.  THE  EMISSION
 CONTROL SYSTEM CONSISTS OF A HOT SIDE ESP FOLLOWED BY  THREE BABCOCK  AND
 WILCOX LIME  fGD MODULES. THE 87X CLEANED GAS WILL PASS  THROUGH A  CHEVON
 MIST  ELIMINATOR BEFORE BEING HARMED BY AN INDIRECT HOT  AIR  REHEMER  AND
 EXITING THROUGH A BRICK LINED 65C FOOT STACK.  THE SLUDGE  FROM THIS  CLOSED
 WATER LOOP SYSTEM WILL BE POZ-0-TEC STABILIZED BEFORE  DISPOSAL IN  AN ON
 SITE  LANDFILL. START UP IS EXPECTED IN SEPTEMBER, 198C.
 COLORADO UTE ELECTRIC ASSN.
 CRAIG
 1
 NEW       447." MU (GROSS)
           447.0 MU (ESC)
 COAL
   .45 XS  SUBBITUMINOUS
 LIMESTONE
 PEABOCY  PROCESS SYSTEMS
 ENERGY  CONSUMPTION:  5.4X
 STATUS  2     STARTUP  4/80
 THE  COLORADO  UTE ELECTRIC ASSN IS PRESENTLY CONSTRUCTING  TWO  IDENTICAL
 UNITS  IN  CRAIG, COLORADO, CRAIG 1 AND 2. BOTH UNITS  WILL  FIRE  PULVERIZED
 SUBBITUMINOUS COAL (0.45S S, 13,000 8TU/LB). EACH UNIT'S  HOT  SIDE  ESP  AND
 FOUR MAGNESIUM PROMOTED LIMESTONE SPRAY TOWERS WILL  REMOVE  85X  Of  THE  SOJ.
 THE  SCRUBBER  CXHAUST WILL BE WARMED BY AN IN-LINE STE»M COIL  REHEATER  AND
 WILL PASS  THROUGH A 600 FOOT TALL ACID BRICK LINED STACK. THE  SYSTEW WILL
 OPERATE  IN A  CLOSED WATER LOOP, AND THE STABILIZED SLUDGE WILL  BE  DISPOSED
 OF  IN  AN OFF  SITE M1NEFILI.  UNIT 1 START UP IS EXPECTED IN  APRIL,  1981?.
 COLORADO UTE ELECTRIC ASSN.
 CRAIG
 2
 NEW        447.0 MW (GROSS)
           447.0 MW (ESC)
 COAL
   .41  XS  SUBBITUMINOUS
 LIMESTONE
 PEABODY  PROCESS SYSTEMS
 ENERGY  CONSUMPTION:  5.4X
 STATUS  1     STARTUP  8/79
 THE  CRAIG  2  UNIT  OF  THE COLORADO UTE ELECTRIC ASSN IS LOCATED
 IN CRAIG,  COLORADO.  THE CRAIG 2 UNIT FIRES PULVERIZED
 SUB8ITUM1NOUS  COAL  (0.45X S, 13,000 BTU/LP). THE UNIT'S HOT SIDE  ESP  AND
 FOUR  MAGNESIUM PROMOTED LIMESTONE SPRAY TOWERS WILL REMOVE 85X OF  THE  S02.
 THE  SCRUBBER  EXHAUST  IS WARMED BY AN IN-LINE STEAM COIL REHEATER  AND
 PASSES  THROUGH A  600  FOOT TALL ACID BRICK LINED STACK. THE SYSTEM
 OPERATES  IN  A  CLOSED  WATER LOOP, AND THE STABILIZED SLUDGE IS DISPOSED
 OF IN AN OFF  SITE MINEFILl. START UP OF UNIT 2 WAS IN AUGUST, 1979.
 COLORADO  UTE  ELECTRIC  ASSN.
 CRAIG
 3
 NEW        447.0  MW  (GROSS)
           447.^  MM  (ESC)
 COAL
   .45  XS   SUBBITUMINOUS
 LIME/SPRAY  DRYING
 VENDOR  NOT  SELECTED
 ENERGY  CONSUMPTION:  ****X
 STATUS  6      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 (0.451 S, 10,000 BTU/LB).  THE SYSTEM WILL
UTILIZE  A DRY  SCRUBBER WITH  LIMESTONE INJECTION FOR EMISSION CONTROL.
THE UNIT IS SCHEDULED  TO  COMMENCE OPERATIONS IN 1982.
COLUMBUS  t  SOUTHERN OHIO ELEC.
CONESVILLE
5
NEW       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 89.5X (DESIGN). EACH MODULE HAS ONf
BULK ENTRAINMENT SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS  THROUGH AN  800  FOOT TALL ACID BRICK LINED STACK.
THE POZ-O-TEC STABILIZED  SLUDGE  is PUMPED INTO AN ON SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN  AN  OPEN WATER LOOP.
COLUMBUS ( SOUTHERN OHIO  ELEC.
CONESVILLE
6
NEW       411.0 MW (GROSS)
          411.0 MU (ESC)
COAL
 4.67 XS  BITUMINOUS
LIME
AIR CORRECTION DIVISION,  UOP
ENERGY CONSUMPTION:  3.91
STATUS 1     STARTUP   6/78
CONESVILLE 6 OF COLUMBUS  AND  SOUTHERN  OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS  COAL  (4.67X  5,  10,850 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLD SIDE ESP  RECEIVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TWO  THIOSORBIC LIME  TCA  MODULES SUPPLIED BY UOP.
THE S02 REMOVAL EFFICIENCY  OF  THE  TWO  MODULES, WHICH BEGAN INITIAL
OPERATION IN JUNE, 1978,  IS 89.5X  (DESIGN). EACH MODULE HAS ONE
BULK ENTRAINMENT SEPARATOR  AND TWO  CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN  800 FOOT  TALL ACID BRICK  LINED STACK.
THE POZ-0-TEC STABILIZED  SLUDGE  IS  PUMPED  INTO AN ON SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN  AN  OPEN  WATER LOOP.
                                                 12

-------
                                              EPA UTILITY FGD SURVEY: JANUARY  - MARCH  196C
                                              SECTION 2
                                        STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
COLUMBUS
POSTON
5
NEW
         t SOUTHERN OHIO ELEC.  COLUMBUS  AND  SOUTHERN OHIO ELECTRIC HAS  PLANS  FOR  TuO  NEW UNITS, POSTON 5
                                AND  6,  TO BE  LOCATED IN ATHENS, OHIO. THE  COAL  (2 . 5X  S,  11,000
          425.0 MW (GROSS)
          375.0 MU (ESc>
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:   4.7X
STATUS 6     STARTUP  8/86
                                FIRED UNITS  WILL UTILIZE EITHER A LIME,  LIMESTONE,  OR  DUAL ALKALI FGD
                                SYSTEM.  START UP OF UNIT 5 IS EXPECTED IN  1986.
COLUMBUS £ SOUTHERN  OHIO  ELEC.  COLUMBUS AND SOUTHERN OHIO ELECTRIC  HAS  PLANS  FOR  TWO NEW UNITS, POSTON 5
POSTON                          AND 6, TO BE LOCATED IN ATHENS,  OHIO.  THE  COAL <2.5X S, 11,000 BTU/LB)
6                               FIRED UNITS WILL UTILIZE  EITHER  A  LIME,  LIMESTONE, OR DUAL ALKALI FGD
NEW       425.0  MW (GROSS)      SYSTEM. START UP OF UNIT  6 IS  EXPECTED  IN  1989.
          425.0 MW  (GROSS)
          375.P MW  (ESC)
COAL
 2.50 US
PROCESS NOT SELECTFD
VENDOR NOT SELECTED
ENERGY CONSUMPTION:   4.7*
STATUS 6     STARTUP   0/89
COMMONWEALTH  EDISON
POWERTON
51
RETROFIT  450.0  MU  (GROSS)
          450.0  MU  (ESC)
COAL
 3.53 XS
LIMESTONE
AIR CORRECTION  DIVISION,  UOP
ENERGY  CONSUMPTION:   5.6X
STATUS  2      STARTUP  4/80
                                COMMONWEALTH EDISON  IS PRESENTLY  RETROFITTING BOILER NUMBER 51 AT ITS
                                POUERTON STATION WITH A UOP  LIMESTONE  F6D SYSTEM. UNIT 51 IS ONE OF TWO
                                IDENTICAL BOILERS SUPPLYING  STEAM TO  AN 850 M« TURBINE. THE PULVERIZED
                                COAL (3.6* s, ic,500 BTU/LB)  FIRED  BOILER FEEDS FLUE GAS THROUGH AN ESP
                                TO 3 TCA MODULES WHICH ARE DESIGNED TO REMOVE 74X OF THE soz. A STEAH
                                INDIRECT HOT AIR REHEATER  WILL  BOOST  THE TEMPERATURE BEFORE THE 6A$ EXITS
                                AN ACID BRICK LINED  STACK. THE  SYSTEM WILL UTILIZE A CLOSED WATER LOOP,
                                AND THE SLUDGE WILL  BE POZ-0-TEC  STABILIZED AND DISPOSED OF IN A LANDFILL.
                                THE FGD SYSTEM IS UNDER CONSTRUCTION,  AND THE START UP IS EXPECTED  IN
                                APRIL, 1980.
 COOPERATIVE  POWER  ASSOCIATION
 COAL  CREEK
 1
 NEW        545.0 MU (GROSS)
           327.0 MU (ESC)
 COAL
   .63 XS   LIGNITE
 LIME/ALKALINE  FLYASH
 COMBUSTION  ENGINEERING
 ENERGY  CONSUMPTION: ****X
 STATUS  1      STARTUP  8/79
                                COAL CREEK 1 AND  2 ARE  TWO  PULVERIZED LIGNITE (9.63X S, 6?58  BTU/IB)  FIRED
                                UNITS OWNED BY THE COOPERATIVE  POWER ASSN AND UNITED POWER. A  COLD  SIDE
                                ESP RECEIVES ?,POO,000  ACFM OF  FLUE GAS AND EXHAUSTS IT TO  FOUR  COUNTER-
                                CURRENT SPRAY TOWERS. MIST  ELIMINATION IS PROVIDED BY A BULK  ENTRAlNMfNT
                                SEPARATOR AND TWO CHEVRON MIST  ELIMINATORS. A MINIMUM OF  40*  BYPASS  REHEAT
                                WILL BE PROVIDED  BEFORE  THE CLEANED 6AS EXITS THE 650 FOOT  ACID  BRICK
                                LINED STACK. THE  TOWER  DESIGN S02 REMOVAL EFFICIENCY IS 9CX.  THE SYSTEM
                                WILL OPERATE IN AN OPEN  WATER LOOP, AND THE FLYASH STABILIZED  SLUDGE  WILL
                                BE DISPOSED IN A  CLAY LINED POND.  UNIT 1 OPERATIONS BEGAN  IN  AUGUST  1979.
 COOPERATIVE  POWER ASSOCIATION
 COAL  CREEK
 2
 MEW        545.0 MU (GROSS)
           327.0 MW (ESC)
 COAL
   .63 XS   LIGNITE
 LIME/ALKALINE FLYASH
 COMBUSTION  ENGINEERING
 ENERGY CONSUMPTION: ****X
 STATUS 2      STARTUP  7/80
                                COAL CREEK 1  AND  2  ARE  TWO PULVERIZED LIGNITE (Q.63X  S,  6258  BTU/LB)  FIRED
                                UNITS OWNED BY THE  COOPERATIVE POWER ASSN AND UNITED  POUER.  A COLD  SIDE
                                ESP RECEIVES  2,200,000  ACFM OF FLUE GAS AND EXHAUSTS  IT  TO  FOUR  COUNTER-
                                CURRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED BY  A  BULK  ENTRAINNENT
                                SEPARATOR AND TUO CHEVRON MIST ELIMINATORS. A MINIMUM  OF 4QX  BYPASS REHEAT
                                WILL BE PROVIDED  BEFORE THE CLEANED GAS EXITS THE 650  FOOT  AClB  B&U*
                                LINED STACK.  THE  TOWER  DESIGN S02 REMOVAL EFFICIENCY  IS  90X.  THE  SYSTEM
                                WILL OPERATE  IN  AN  OPEN WATER LOOP, AND THE FLYASH STABILIZED SLUDGE  WILL
                                BE DISPOSED OF IN A CLAY LINED POND. UNIT 2 IS PRESENTLY UNDER CONSTRUC-
                                TION AND SHOULD  INITIALLY START OPERATIONS IN JULY,  1980.
 DELMARVA  POWER & LIGHT
 DELAWARE  CITY
 1-3
 RETROFIT   180.0 MU (GROSS)
           180.0 MU (ESC)
 COKE
  7.00 XS   FLUID PETROLEUM COKE
 dELLMAN LORD
 DAVY NCKEE
 ENERGY CONSUMPTION: ****X
 STATUS 2      STARTUP  4/80
                                DELMARVA  POWER  8  LIGHT'S DELAWARE CITY PLANT HAS  FOUR  BOILERS, THREE OF
                                WHICH HAVE  STEAM  CAPACITIES OF 5OPK LB/HR EACH. THE  BOILERS  GENERATE STEAM
                                AS WELL AS  ELECTRICITY FOR GETTY "REFINING AND MARKETING.  LOU SULFUR CRUDE
                                OIL  UILL  BE  REPLACED UITH COKE (7-8X S) IN THE BOILER  WHEN  THE FGD SYSTEM
                                IS COMPLETE,  IN APRIL, 1980. A VENTURI PARTICULAR  SCRUE6ER  AND A UELLMAN-
                                LORD  FGD  SYSTEM (90X DESIGN EFFICIENCY) SUPPLIED  BY DAVY  POUERGAS ARE
                                PRESENTLY UNDER CONSTRUCTION. AN INDIRECT GAS REHEATER UILL  BE USED.
                                THE  SYSTEM  WILL OPERATE IN AN OPEN WATER LOOP.
                                                  13

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 EP» UTILITY  fGD  SU&VEY:  JANUARY  - MARCH 1980
                                               SECTION 2
                                         STATUS OF FGD SYSTEMS
 JNIT IDENTIFICATION
                                                                    ABSTRACT
 DELMARVA POWER K LIGHT
 VIENNA
 9
 NEW       55P.O MW (GROSS)
           550.C MW (ESC)
 COAL
  2.70 XS
 PROCESS NOT SELECTED
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION: ***«X
 STATUS 6     STARTUP  A/87
    DELMARVA POWER  AND  LIGHT  IS PLANNING A NEW UNIT. VIENNA  9,  TO
    BE CONSTRUCTED  IN VIENNA, MARYLAND.  THE UTILITY IS PRESENTLY  CONSIDERING
    A LIMESTONE  FGD  UNIT  FOR  EMISSION CONTROL.  THE PULVERIZED  COAL  FIRED  UNIT
    IS EXPECTED  TO  COMMENCE  OPERATIONS IN JUNE 19?7.
 DESERET GENERATION K TRANS
 100N LAKE
 1
 NEW       410.0 My (GROSS)
           410.0 MW (ESC)
 COAL
   .50 XS  BITUMINOUS
 LIMESTONE
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION: ****X
 STATUS 5     STARTUP 12/84
COO MOON LAKE 1 IS A PULVERIZED  COAL  (0.5X S, 10,500 BTU/LB) FIRED UNIT
    PLANNED BY DESERET  GENERATION AND TRANSMISSION COOP. TO BE LOCATED  IN
    VERNAL, UTAH.  THE  UTILITY  IS PRESENTLY REQUESTING BIDS FOR A yET LIME-
    STONE SCRUBBING  SYSTEM  HAVING A  so? REMOVAL EFFICIENCY OF 95*.   THE  SYSTEM
    WILL FEATURE * BAGHOUSE  DESIGNED  TO REMOVE 99.6* OF THE PARTICULATE.   THE
    UNIT WILL OPERATE IN  »  CLOSED WATER LOOP WITH SLUDGE DISPOSAL ON  SITE
    IN A LANDFILL.   OPERATIONS  ARE  SCHEDULED TO COMMENCE IN 1P84.
 DESEOET GENERATION 8 TRANS
 MOON LAKE
 2
 NEW       410.0 MW (GROSS)
           410.0 RW (ESC)
 COAL
   .50 XS  BITUMINOUS
 LIMESTONE
 VENDOR NOT SELECTED
 ENERGI CONSUMPTION: *»*«X
 STATUS 5     STARTUP  0/88
COO MOON LAKE 2 IS A PULVERIZED  COAL  (0.5X  S, 10,500 BTU/LB) FIRED UNIT
    PLANNED BY DESERtT  GENERATION  AND TRANSMISSION COOP. TO fc£ LOCATED  IN
    VERNAL, UTAH.  THE  UTILITY  IS  PRESENTLY REQUESTING BIDS FOR A WET LIME-
    STONE SCRUBBING SYSTEM  HAVING  A  S02  REMOVAL EFFICIENCY OF 95X.  THE  SYSTEM
    WILL FEATURE A BAGHOUSE  DESIGNED  TO  REMOVE 99.6* OF THE PARTICULATE.   THE
    UNIT WILL OPERATE IN  4  CLOSED  WATER  LOOP WITH SLUDGE DISPOSAL ON S]T£
    IN A LANDFILL.  OPERATIONS  ARE  SCHEDULED TO COMMENCE IN 1<»88.
 OUQUESNE  LIGHT
 ELRAMA
 1-4
 RETROFIT   510.0 MW (GROSS)
           510.0 MW (ESC)
 COAL
  2.20 XS
 LIME
 CHEMICO
 ENERGY  CONSUMPTION:  3.5X
 STATUS  1      STARTUP 10/75
    ELRAMA 1-4 OF DUQUESNE LIGHT  CONSISTS  OF  FOUR PULVERIZED COAL (2.2X  S,
    11,350 PTU/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  CHENICO, 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 POI-0-TEC STABILIZED  SLUDGE  IS  HAULED TO AN OFF SITE LAND-
    FILL. THE SYSTEM HAS BEEN OPERATIONAL  SINCE OCTOBER, 1975.
DUOUFSNE  LIGHT
PHILLIPS
1-6
RETROFIT   408.0  "W  (GROSS)
           410.0  MW  (ESC)
COAL
 1.92 XS   BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION:  J.4X
STATUS 1      STARTUP  7/73

EAST KENTUCKY POWER COOP
J.  K. SMITH
1
NEW        650.0  *W  (GROSS)
           650.0  MW  (ESC)
COAL
•*•** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *•*•*
STATUS 6      STARTUP  1/85
    THE  PHILLIPS POWER STATION Of DUOUESNE  LIGHT  CONSISTS OF SIX DRY POTTOM
    PULVERIZED CO*L (2.2X S, 11,350 BTU/LB)  FIRED  UNITS LOCATED IN SOUTH
    HEIGHT,  PENNSYLVANIA. PARTICULATE CONTROL  IS  ACCOMPLISHED BY SIX ESP/
    MECHANICAL COLLECTOR COMBINATIONS (ONE/BOILER).  ONE TWO STAGE AND THREE
    SINGLE  STAGE VARIABLE THROAT VENTURI  LIME  FGD  MODULES SUPPLIED BY CHEMICO
    ARE  DESIGNED TO REMOVE 83X OF THE S02 FROM THE  FLUE GAS. TWO CHEVPON 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 34(j FOOT TALL
    ACID  BRICK LINED STACK. THE SYSTEM  OPERATES IN  AN  OPEN WATER LOOP, AND
    THE  POZ-0-TEC STABILIZED SLUDGE IS  TRUCKED TO  AN OFF  SITE LANDFILL. THE
    SYSTEM  HAS BEEN OPERATIONAL SINCE JULY,  1973.

    THE  EAST  KENTUCKY  POWER COOP HAS PLANS  TO  FIRE  TWO NEU UNITS.  THE J.K.
    SWITH 1  AND  2 WILL UTILIZE EITHER A DRY  PROCESS  OR A  WET LINE PROCESS
    FOR  EMISSION CONTROL.  UNIT 1 IS EXPECTED  TO START UP IN JANUARY, 1985.
                                                 14

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                                              EPA UTILITY F6D  SURVEY:  JANUARY  - MARCH 1960
                                              SECTION 2
                                        STATUS OF FGO SYSTEMS
JNIT IDENTIFICATION
                                                                   ABSTRACT
EAST KENTUCKY POWE" COOP
J. K. SMITH
2
NEW       650.0 MW  (GROSS)
          650.0 My  (ESc)
COAL
.**•* »S
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«*•»
STATUS 6     STARTUP   1/87
                                THE  EAST  KENTUCKY POWER COOP  HAS PLANS  TO  FIRE  TyO NEW UNITS.  THE J.K.
                                SMITH 1  AND 2 WILL UTILIZE EITHER  A  DRY PROCESS OR A W£T LjMt PROCESS
                                FOR  EMISSION CONTROL.  UNIT  2  IS EXPECTED  TO START UP IN JANUARY,  19£7.
EAST KENTUCKY POWER COOP
SPURLOCK
2
SEW       500.C MW  (GROSS)
          500.0 MW  (ESC)
COAL
 3.5T XS
LIME
ADL/COMBUSTION EOUIP  ASSOCIATE
ENERGY CONSUMPTION: ****X
STATUS 2      STARTUP   1/81
                                SPURLOCK 2 Of EAST KENTUCKY  POWER  COOPERATIVE IS A BALANCED  DRAFT  PULVER-
                                I7ED COAL (3.5J S, 11,000  BTU/LB)  FIRED  UNIT UNDER CONSTRUCTION  IN  M*YS-
                                VILLE, KENTUCKY. THE  EMISSION  CONTROL SYSTEM WILL CONSIST OF AN  E?P  FOL-
                                LOWED BY AN ADL/COMBUSTION EQUIPMENT ASSOCIATES LIME FGD SYSTEM  (90X
                                DESIGN S02 REMOVAL EFFICIENCY).  FLUE GAS FROM UNIT ONE WILL  BE USED  TO
                                REHEAT THE CLEANED GAS.  THE  SYSTE", SLATED FOR START UP  IN  JANUARY,  1981,
                                WILL EMPLOY A CLOSED  WATER LOOP  AND POZ-0-TEC SLUDGE STABILIZATION.
GENERAL PUBLIC  UTILITIES
COHO
1
NEW        690.0 MW  (GROSS)
           800.0 MW  (ESC)
COAL
 3.50  XS
PROCESS NOT  SELECTED
VENDOR  NOT  SELECTED
ENERGY  CONSUMPTION:   9.<.X
STATUS  6      STARTUP  12/88
                                COHO 1 IS A 3.5X S COAL  FIRED  UNIT PLANNED BY GENERAL PUBLIC  UTILITIES  TO
                                BE LOCATED IN ERIE,  PENNSYLVANIA. PRIMARY CONSIDERATION  IS  BEING  GIVEN  TO
                                LIME AND LIMESTONE NON-SLURRY  TYPE FGD SYSTEMS. THE UNIT  »ND  FGD  SYSTEM
                                ABE SCHEDULED TO START UP  IN DECEMBER, 1988.
GENERAL  PUBLIC  UTILITIES
GILBERT
1
NEW        625.0 MW (GROSS)
           625.0 MW (ESO
COAL
  3.50  XS
PROCESS  NOT  SELECTED
VENDOR  NOT SELECTED
ENERGY  CONSUMPTION: *«**X
STATUS  6     STARTUP  0/90
                                GENERAL PUBLIC UTILITIES  HAS PLANS FOR A NEW UNIT,  GILBERT  9,  TO PE
                                LOCATED IN M1LFORD,  NEW  JERSEY.  THE UTILITY IS CONSIDERING  FGO  »S AN
                                EMISSION CONTROL  STRATEGY.   THE EXPECTED START UP  DATE  IS  IN 1990.
 GENERAL  PUBLIC UTILITIES
 SCOTTSVILLE
 1
 NEW        625.n MW (GROSS)
           625.C MW (ESC)
 COAL
  3.50  XS
 PROCESS  NOT  SELECTED
 VENDOR  NOT SELECTED
 ENERGY  CONSUMPTION: «**«X
 STATUS  6     STARTUP
                                GENERAL PUBLIC  UTILITIES IS PLANNING « NEW UNIT  TO  BE  LOCATED IN
                                StOTTSVILLE,  PENNSYLVANIA.  THE SCOTTSVILLE  1  UNIT  IS  EXPECTED TO START
                                UP IN 1991.   THE  UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS A EMISSION
                                CONTROL STRATEGY.
GENERAL  PUBLIC  UTILITIES
SEWARD
7
NEW        690.0 MW (GROSS)
           800.0 MW (ESC)
COAL
•****  zs
PROCESS  NOT SELECTED
VENDOR  NOT SELECTED
ENERGY  CONSUMPTION:  9.4*
STATUS  6     STARTUP  5/87
                                GENERAL PUBLIC  UTILITIES IS PLANNING A NEW UNIT,  StWARD 7, TO BE BUILT IN
                                SEWARD, PENNSYLVANIA. THE UTILITY IS PRESENTLY  CONSIDERING ONLY FGD AS THE
                                EMISSION  CONTROL  STRATEGY, WITH NON-SLURRY TYPE  LIKE  AND LIMESTONE SYSTEflS
                                LOOKING THE  MOST  PROMISING. START UP IS  EXPECTED  IN  HAY, 1987.
                                                  15

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 EPA  UTILITY FGO SURVEY: JANUARY - MARCH  1980
                                               SECTION I
                                         STATUS  OF  FGD SYSTEMS
 JMT  IDENTIFICATION
                                                                   ABSTRACT
 GENERAL  PUBLIC  UTILITIES
 WEHRUM
 1
 NEW        625.C MW (GROSS)
           625.P *U 
 COAL
  3.50 XS
 PROCESS  NOT SELECTED
 VENDOR  NOT SELECTED
 ENERGY  CONSUMPTION: ****X
 STATUS  6     STARTUP  0/95
    THE WEHRUM 1 UNIT  PLANNED  BY  GENERAL PUBLIC UTILITIES IS TO BE  LOCATED
    IN WEHRUH, PENNSYLVANIA.   THE UTILITY is PRESENTLY CONSIDERING  FGD  AS  AN
    EMISSION CONTROL  STRATEGY.  THE  UNIT IS EXPECTED TO COMMENCE  OPERATIONS
    IN 1995.
 GRAND  HAVEN BRD  OF  LIGHT &
 i.  B.  SIMS
 3
 MEW         81.0  MW  (GROSS)
            81.0  MU  (ESC)
 COAL
 2.75  XS  BITUMINOUS
 LIME
 BABCOCK g UILCOX
 ENERGY  CONSUMPTION: **•**
 STATUS  3      STARTUP  6/B3
PUR THE GRAND HAVEN  BOARD  OF  LIGHT AND POWER'S J.P. SIMS 3 IS A  PLANNFD
    BITUMINOUS COAL  (2.75X St H»COC BTU/Lb) FIRED UNIT TO BE LOCATED  IN
    GRAND HAVEN, MICHIGAN.  A CONTRACT HAS BEEN AWARDED TO BABCOCK  AND ULCOX
    TO 5UPPL> TWO  SPRAY  TOuERS TO CONTROL EMISSIONS.  EACH SCRUBBER  SYSTEM
    WILL UTILIZE A CHEVRON MIST ELIMINATOR AND AN IN-LINE CEHEATER.   THE
    SLUDGE IS TO Bt  DISPOSED  IN AN OFF SITE LANDFILL.  OPERATIONS  ARE  TC
    COMMENCE IN JUNE,  19E3.
HOOSIER  ENERGY
HEROM
1
NEW        490.0  MW  (GROSS)
           441.0  MU  (ESC)
COAL
 3.50  XS
LIMESTONE
MITSUBISHI  HEAVY INDUSTRIES
ENERGY  CONSUMPTION: ****X
STATUS  3      STARTUP  5/82
    MEROM 1 AND 2 ARE  TWO  NEW  UNITS  BUNG BUILT BY HOOSIER EfcFRGY  IN  SULLIVAN
    INDIANA. THESE PULVERIZED  COAL  (3.5X  S) FIRED UNITS WITH PRODUCE  1,732,000
    ACFM OF FLUE GAS WHICH UILL  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 SLUDG?  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
2
NEW        490.0  MU  (GROSS)
           441.0  MU  (ESC)
COAL
 3.50  XS
LIMESTONE
MITSUBISHI  HEAVY INDUSTRIES
ENERGY  CONSUMPTION: *****
STATUS  2      STARTUP  7/81
    MEROM 1 AND 2 ARE TWO  NEW  UNITS  BEING  BUILT BY HOOSIER ENERGY IN  SULLIVAN
    INDIANA. THESE PULVERIZED  COAL  (3.5X  S)  FIRED UNITS WITH PRODUCE  1,732,OCO
    ACFM OF FLUE GAS WHICH  WILL  BE  CLEANED BY A COLD SIDE ESP UPSTREAM  OF  A
    MITSUBISHI LIMESTONE GRID  TOWER  ABSORBER  (90X DESIGN SO? REMOVAL).  THE
    SYSTEM WILL UTILIZE BYPASS REHEAT AND  A  700 FOOT STACK. THE SLUOGf  WILL
    BE STABILIZED AND LANDFILLED, AND THE  SYSTEM WILL OPERATE IN A  CLOSED
    WATER LOOP MODE. START  UP  OF UNIT 2  IS SCHEDULED FOR JULY, 1981.
HOUSTON LIGHTING  t  POWER  CO.
ri.A. PARISH
8
NEW       600.0 MU  (GROSS)
          492.P MU  (ESC)
COAL
  .60 XS  SUBBITUMINOUS
LIMESTONE
CHEMICO
ENERGY CONSUMPTION:  ****X
STATUS 3      STARTUP 11/82
    U.A. PARISH £ IS A PULVERIZED  COAL  (0.6X  S,  8?00 BTU/LB) FIRED UNIT  PLAN-
    NED BY HOUSTON LIGHTING  AND  POWER CO  TO BE  LOCATED IN THOMPSONS, nXAS.
    THE UTILITY HAS AWARDED  A  CONTRACT  TO CHEMICO FOR A LIMESTONE
    FGO SYSTEM WHICH WILL REMOVE 82X OF  THE FLUE  GAS 502.  REHEAT
    WILL BE PROVIDED BY BYPASSING  18X OF  THE  PARTICULATE CLEANED FLUE GAS.
    SLUDGE WILL BE DEWATERED,  BLENDED UITH FLYASH, AND DISPOSED IN AN ON
    SITE LANDFILL. START UP  IS EXPECTED  IN NOVEMBER, 1982.
INDIANAPOLIS POWER  S  LIGHT
PATRIOT
1
NEU       650.0 MU  (GROSS)
          650.0 MU  (ESC)
COAL
 3.50 tS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6     STARTUP   0/87
    INDIANAPOLIS POWER AND LI6HT  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.
                                                 16

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                                              EPA  UTILITY  FGD SURVEY: JANUARY - MARCH 19gn
                                              SECTION 2
                                        STATUS  Of  FGD SYSTEMS
UNIT IDENTIfICATION
                                                                  ABSTRACT
INDIANAPOLIS POWER g LIGHT
PATRIOT
2
NEW       650.0 fW (GROSS)
          650.C MW (ESC)
COAL
 3.50 XS
LIMESTONE
t/ENDOR NOT SELECTED
ENERGY CONSUMPTION:  *****
STATUS 6     STARTUP   0/87
INDIANAPOLIS POWER AND LIGHT  HAS PLANS  FOR  THREE  NEW UMTS.  PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA.   THE  UTILITY PLANS ON U
A LIMESTONE fGD PROCESS fOR EMISSION  CONTROL.
INDIANAPOLIS POUER 8  LIGHT
PATRIOT
3
NEW       650.0 *W (GROSS)
          650.0 MU (ESC)
COAL
 3.50 XS
LIMESTONE
YENDOH NOT SELECTED
ENERGY CONSUMPTION: ****x
STATUS 6     STARTUP   0/87
INDIANAPOLIS POUER AND  LIGHT  HAS  PLANS  FOR TH*EE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED  IN  PATRIOT,  INDIANA.  THE UTILITY PLANS ON UTILIZING
A LIMESTONE fGD  PROCESS  FOR  EMISSION CONTROL.
INDIANAPOLIS POWER  8  LIGHT
PETERSBURG
3
MEW       532.0 "«  (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  4.5X  S  BITUMINOUS COAL (11,COO 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 REHEATEP THAT
BOOSTS THE GAS TEMPERATURE BY 30 DEC F BEFORE IT EXITS THE 616 FOOT  RIGI-
FLAKE 4S50 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  K  LIGHT
 PETERSBURG
 4
 NEW       530.0  MW  (GROSS)
          530.0  MW  (ESC)
 COAL
  3.50  XS  BITUMINOUS
 LIMESTONE
 RESEARCH  COTTRELL
 ENERGY  CONSUMPTION:  2.1X
 STATUS  2      STARTUP  10/84
PETERSBURG  4  OF  INDIANAPOLIS POWER AND LIGHT IS A BITUMINOUS  COAL  (5.5CX  S
11,000  BTU/LB)  FIRED  BOILER UNDER CONSTRUCTION IN PETERSBURG,  INDIANA.  THE
LIMESTONE  FGD  SYSTEM  FOR THIS UNIT WJLL BE SUPPLIED BY RESEARCH  COTTRELL.
THE  SYSTEM  WILL  OPERATE  IN A CLOSED WATER LOOP, AND SLUDGE  WILL  B*  P07-0-
TEC  STABILIZED  BEFORE PONDING. START UP IS SLATED FOR OCTOBER  Of  1984.
KANSAS  CITY  POUER  8  LIGHT
HAWTHORN
3
RETROFIT    90.0  MW (GROSS)
            90.0  MW (ESC)
COAL
   .60 XS   BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY  COMSUMPTIONt   2.2*
STATUS  1      STARTUP 11/72
 HAWTHORN  3  OF  KANSAS CITY POWER A«D LIGHT IS  A DRY  BOTTOM  PULVERISED
 BITUMINOUS  COAL  (0.6* S, 98CC BTU/LB) FIRED UNIT LOCATED  IN  KANSAS
 MISSOURI, WHICH  WAS CONVERTED FROM LIMESTONE  FURNACE  INJECTION  AND  TAIL
 END  SCRUBBING  TO A LIME SLURRY SYSTEM. TWO COMBUSTION  ENGINEERING MARBLE
 BED  ABSORBERS, WHICH WERE DESIGNED TO REMOVE  70* OF THE  FLUE GAS  S02,
 BEGAN  OPERATION  IN JANUARY, 1977. ONE HORIZONTAL CHEVRON  MIST ELIMINATOR
 PER  MODULE  IS  UPSTREAM OF AN IN-LINE FINNED TUBE REHEATER, WHICH  RAISES
 THE  TEMPERATURE  OF THE CLEANED GAS BEFORE IT  EXITS  THROUGH A GUNITE LINED
 200  FOOT  STACK.  THE FLVASH STABILIZED SLUDGE  IS  DEPOSITED  IN AN UNL1NEO
 SLUDGE POND.  THE SYSTEM OPERATES IN A CLOSED  WATER  LOOP  MODE.
 KANSAS  CITY  POUER 8 LIGHT
 HAWTHORN
 4
 RETROFIT   90.0 MW (GROSS)
            90. C1 MW (ESC)
 COAL
   .60 XS  BITUMINOUS
 COMBUSTION ENGINEERING
 ENERGY CONSUMPTION:  2.2Z
 STATUS 1     STARTUP  8/72
 HAWTHORN  4  OF KANSAS CITY POWER AND LIGHT IS  A  DRY  BOTTOM  PULVERIZED
 BITUMINOUS  COAL C0.6X S, 9800 BTU/LB) FIRED  UNIT  LOCATED  IN KANSAS CITY,
 MISSOURI, WHICH WAS CONVERTED FROM LIMESTONE  FURNACE  INJECTION AND TAIL
 END  SCRUBBING TO A LIME SLURRY SYSTEM. TWO COMBUSTION  ENGINEERING MARBLE
 BED  ABSORBERS, WHICH WERE DESIGNED TO REMOVE  701  OF THE  FLUE GAS $02,
 BEGAN OPERATION IN JANUARY, 1977. ONE HORIZONTAL  CHEVRON  MIST ELIMINATOR
 PER  MODULE  IS UPSTREAM OF AN IN-LINE FINNED  TUBE  REHEATER, WHICH RAISES
 THE  TEMPERATURE OF THE CLEANED GAS BEFORE IT  EXITS  THROUGH A GUNITE LINED
 200  FOOT  STACK. THE FLYASH STABILIZED SLUDGE  IS DEPOSITED  IN AN UNLINED
 SLUDGE POND. THE SYSTEM OPERATES  IN * CLOSED  WATER  LOOP  MODE.
                                                  17

-------
 EPA UTILITY FGD SURVEY:  JANUARY  - MARCH 198C
                                               SECTION 2
                                         STATUS Of FGD SYSTEMS
 JNIT  IDENTIFICATION
                                                                   APSTRACT
 KANSAS  CITY POWER K LIGHT
 LA  CYGNE
 1
 NEW       874.C MW (GROSS)
           874.P »W (ESC>
 COAL
  5.39  XS  SUBBITUMINOUS
 LIMESTONE
 BABCOCK  R WILCOX
 ENERGY  CONSUMPTION:  2.7*
 STATUS  1     STARTUP  2/73
 LA  CYGNE  1  IS  A WET BOTTOM, CYCLONE FIRED  PULVERIZED  SUBfa ITUMINOUS COAL
 (5.39X  S,  9421 BTU/LB) FIRED UNIT OF KANSAS  CITY  POWER  AND LIGHT, LOCATED
 IN  LA  CYGNE,  KANSAS. THE EMISSION CONTROL  SYSTE"!  CONSISTS OF EIGHT VARIA-
 BLE  THROAT  VENTURI/LIMESTONE SIEVE TRAY  TOWER  TPAINS  SUPPLIED EY FABCOCK
 AND  WILCOX.  EACH 8CX (S02 REMOVAL, DESIGN) EFFICIENT  TRAIN IS FOLLOWED BY
 A COMBINATION  SIEVE TRAY AND CHEVRON MIST  ELIMINATOR, FOLLOWED B1 AN  INDI
 RECT REHEATER. THE  CLEANED GAS E»JTS THROUGH A  ?C'0 FOOT  STEEL LINED STACK.
 THE  SYSTEM  OPERATES IN A CLOSED kATFR LOOP,  AND  THE  SCRUBBER SLUDGE IS
 DISPOSED  IN  AN UNLINED POND. INITIAL OPERATIONS  OF THE  FGD SYSTEM BEGAN  1N
 FEBRUARY,  1977.
 KANSAS  POWER  & LIGHT
 JEFFREY
 1
 NEW        720.0 MW (GROSS)
           540.0 MW (ESC)
 COAL
   .32 XS
 LIMESTONE
 COMBUSTION  ENGINEERING
 ENERGY  CONSUMPTION: *****
 STATUS  1      STARTUP  P/7B
KANSAS  CITY  POWER  AND LIGHT'S JEFFREY  1  IS  A  TANGENTIAL FIRED PULVERIZED
COAL  (G.32X  S,  8125  BTU/LP) UNIT IN WAMPGO, KANSAS.  THE EMISSION CONTROL
SYSTEM  FOR THIS  UNIT CONSISTS OF • COLD  SIDE  ?SP  FOLLOWED  BY SIX (ONE
SPARE)  LIMESTONE  SPRAY TOWER MODULES SUPPLIED  BY  COMBUSTION ENGINEERING.
THE DESIGN SO?  REMOVAL EFFICIENCY IS 5C*  (INCLUDING  A  30X  BYPASS R£HEAT>.
THE UNIT  HAS  BEEN  OPERATIONAL SINCE AUGUST, 1978.
KANSAS POWER  &  LIGHT
JEFFREY
2
NEW        700.0  MW  (GROSS)
           490.0  MW  (ESC)
COAL
  .30 XS
LIMESTONE
COMBUSTION  ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2      STARTUP  4/80
UNIT 2, PRESENTLY  UNDER CONSTRUCTION AT KANSAS  POWER  AND LIGHT'S JEFFREY
ENERGY CENTER  IN  JEFFREY, KANSAS, WILL BURN  0.3X  S  PULVERIZED COAl (81CO
BTU/LB).  THIS  UNIT'S  EMISSION CONTROL SYSTEM  WILL  CONSIST OF  A COLD SIDE
ESP AND COMBUSTION ENGINEERING LIMESTONE  SPRAY  TOWERS.  A 70X  FLUE GAS
BYPASS WILL  PROVIDE  REHEAT OF THE CLEANED GAS BEFOhE  IT EKITS THROUGH A
6TO FOOT  STACK.  THE  SYSTEM WILL OPERATE IN A  CLOSED  WATER LOOP MODE, AND
THE SLUDGE WILL  BE STABILIZED WITH BOTTOM ASH AND  PIPED TO AN ON-SITE
CLAY LINED POND.  SCHEDULED START UP OF THE SYSTEM  IS  APRIL,  196C.
KANSAS POWER  &  LIGHT
LAWRENCE
4
RETROFIT   125.0 MW  (GROSS)
           125.0 MW  (ESC)
COAL
  .55 XS
LIMESTONE
COMBUSTION  ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1      STARTUP   1/76
LAWRENCE 4 OF  KANSAS  POWER AND LIGHT IS A BALANCED  DRAFT,  TANGENTIAL FIRED
PULVERIZED COAL  (0.55X S, 1C,COT BTU/LB) UNIT  LOCATED  IN  LAWRENCE, KANSAS.
A NEW COMBUSTION  ENGINEERING LIMESTONE ROD DECK/SPRAY  TOWER  SYSTEM
REPLACED THE EXISTING MARBLE BED TAIL END SCRUBBER  IN  JANUARY, 1977. THE
SYSTEM TREATS  403,000 ACFM OF FLUE GAS. WITH A  DESIGN  S02  REMOVAL OF
73*. MJST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS  AND  ONE BULK
ENTRAINMENT  SEPARATOR FOLLOWING EACH OF THE TWO MODULES.  A FINNED TUBE
REHEATER BOOSTS THE  TEMPERATURE OF THE CLEANED  GAS  BY  20  DEG F BEFORE
IT IS EXHAUSTED THROUGH A 120 FOOT STACK. THE  SLUDGE  IS  DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A FINAL  DISPOSAL  POND. THE
SYSTEM OPERATES IN  A  CLOSED WATER LOOP.
KANSAS POWER  &  LIGHT
LAWRENCE
5
RETROFIT  420.0 MW  (GROSS)
          420.0 MW  (ESC)
COAL
  .55 XS
LIMESTONE
COMBUSTION  ENGINEERING
ENERGY CONSUMPTION: **«*X
STATUS 1      STARTUP  11/71
LAWRENCE  5  OF  KANSAS  POWER AND LIGHT IS A BALANCED  DRAFT,  TANGENTIAL FIRED
PULVERIZED  COAL  (0.55X  S, 10,000 RTU/LB) UNIT  LOCATED  IN  LAWRENCE, KANSAS
A NEW COMBUSTION  ENGINEERING LIMESTONE ROD DECK/SPRAY  TOWER  SYSTEM        *
REPLACED  THE EXISTING MARBLE BFD TAIL END SCRUBBER  IN  APfclL. 1978. THE
SYSTEM TREATS  403,000 ACFM OF FLUE GAS, WITH A DESIGN  S02  REMOVAL OF
73*. MIST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS  AND  ONE  BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES.  A FINNED TUBE
REHEATER  BOOSTS  THE  TEMPERATURE OF THE CLEANED GAS  BY  20  DEG F BEFORE
IT IS EXHAUSTED  THROUGH A 120 FOOT STACK. THE  SLUDGE  IS  DISPOSED IN AN
UNLINED INTERIM  POND, WHICH OVERFLOWS INTO A FINAL  DISPOSAL  POND. THE
SYSTEM OPERATES  IN  A  CLOSED WATER LOOP.
KENTUCKY UTILITIES
GREEN RIVER
1-3
RETROFIT   64.0  MM  (GROSS)
           64.C  MW  (ESC)
COAL
 4.00 XS  BITUMINOUS
LIME
AMERICAN AIR  FILTER
ENERGY CONSUMPTION:   3.IX
STATUS 1      STARTUP   9/75
GREEN RIVER  1-3  OF  KENTUCKY UTILITIES ARE THREE  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  FOLLOWED BY AN AMERICAN  AIR  FILTER LIME  MOBILE
BED CONTACTOR  (SOX  DESIGN  S02 REMOVAL EFFICIENCY). A  RADIAL VANE MIST
ELIMINATOR IS  FOLLOWED  BY  A STEAM TUBE REHEATFR  AND  A  165  FOOT STACK.
SLUDGE IS DISPOSED  IN AN  ON-SITE UNLINED POND, AND THE  SYSTEM OPERATES
IN A CLOSED  WATER LOOP.  THE SYSTEM HAS BEEN OPERATIONAL  SINCE SEPTEMBER,
1975.
                                                  18

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                                              EPA UTILITY  FGD  SURVEY: JANUARY - MARCH  198n
                                              SECTION  2
                                        STATUS OF  FGO  SYSTEMS
     IDENTIFICATION
                                                                   ABSTRACT
LAKELAND UTILITIES
>IC INTOSH
J
NEW       364.C  MW  (GROSS)
          364.C  I»W  (ESC)
COAL
 2.56 XS  BITUMINOUS
LIMESTONE
BABCOCK X WILCOX
ENERGY CONSUMPTION: ****X
STATUS I      STARTUP  10/81
                                MCINTOSH 7 Of LAKELAND UTILITIES  IS BEING CONSTRUCTED  IN  LAKELAND,
                                FLORIDA. PABCOCK AND  WILCOX  HAS 6F.EN AWARDED A CONTRACT TO  SUPPLY  AN
                                85X EFFICIENT  FIRED  UNIT.
                                COMBUSTION  ENGINEERING IS SUPPLYING  THE  LIME/LIME STONE FGD SYSTEM  WHICH
                                WILL  COMPLY WITH LOCAL EMISSION STANDARDS BY ApRIL OF 1982.
                                                  19

-------
 EPA  UTILITY FGD SU"VEY: JANUARY  -  MARCH  1980
                                               SECTION 2
                                         STATUS  Of  FGD SYSTEMS
 JNIT  IDENTIFICATION
                                                                   APSTRACT
 LOUISVILLE GAS « ELECTRIC
 tlLL  CREEK
 J
 NEW        44?.0 MW (GROSS)
           44?.C MW (ESC)
 COAL
  3.75 XS  BITUMINOUS
 LIME
 AMERICAN AIR FILTER
 ENERGY  CONSUMPTION:  1.62
 STATUS  1     STARTUP  8/78
                                LOUISVILLE  GAS  »N|>  ELECTRIC'S MILL CREEK 3 IS A 3.75X  S  COAL  (11,FOG BTU/
                                LB)  FIRED UNIT  LOCATED IN LOUISVILLE* KENTUCKY. AMERICAN  AIR  FILTER  SUP-
                                PLIED A CARBIDE  LIME  FGD SYSTEM FOR THIS UNIT WHICH WAS  DESIGNED  T0  REMOVE
                                85X  OF TH?  SO?  FROM THE FLUE GAS. AN ESP IS FOLLOWED BY  FOUR  MOBILE  B*D
                                SPRAY TOWERS  AND  A  STEAM TUBE REHFAUR. THE WATER LOOP IS  OPEN,  A*D  TH£
                                FLYASH AND  LI»E  STABILIZED SLUDGE is PONDED. THIS UNIT HAS  BEEN  OPERATION-
                                AL SINCE AUGUST,  1978.
 LOUISVILLE  GAS  & ELECTRIC
 flLL  CREEK
 4
 NEW       495.0 !"W (GROSS)
          495.P MW (ESC)
 COAL
 3.75  XS
 LIME
 AMERICAN  AIR  FILTER
 ENERGY  CONSUMPTION:  *****
 STATUS  2      STARTUP  7/81
                                MILL CREEK 4  OF  LOUISVILLE  GAS  AND ELECTRIC 1$ A PULVERIZED  BITUMINOUS
                                COAL (3.75X S,  11,500  bTU/LB)  FIRED UNIT UNDE" 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,  »ND
                                THE SLUDGE WILL  BE  STABILIZED WITH L»*E AND FLYASH. STEAM TUBES WILL
                                PROVIDE REHEAT  OF THE  CLEANED GASES. THE SYSTEM IS SCHEDULED  TO S'APT
                                UP JN JULY OF 1961.
LOUISVILLE  GAS  &  ELECTRIC
PADDY'S  RUN
5
RETROFIT    7?.c MU  (GROSS)
            7?.0 WW  (ESC)
COAL
 2.50 SS  BITUMINOUS
LIME
COMBUSTION  ENGINEERING
ENERGY CONSUMPTION:   2.8X
STATUS 1     STARTUP  4/73
                                UNIT 6 AT LOUISVILLE  GAS  AND  ELECTRIc'S PADDY'S RUM STATION  IS  A  DRY  BOT-
                                TOM PULVERIZED COAL  (?.5X  S,  11,500 BTU/LB) FIRED UNIT IN LOUISVILLE,  KEN-
                                TUCKY. A RETROFIT CARBIDE  LIME  FGD  SYSTEM BY COMBUSTION ENGINEERING  TREATS
                                400.000 ACFM OF  FLUE  GAS  FROM THE BOILER. AN ESP is FOLLOWED BY  TWO  MARBLE
                                BSD ABSORBERS, A DIRECT  COMBUSTION  RBHEATER, AND A 250 FOOT  STACK.  WIST
                                ELIMINATION IS PROVIDED  BY ONE  CHEVRON/MODULE- THE LIME FIXATED  SLUDGE IS
                                TRUCKED TO AN UNL1NED  POND, AND  THE WATER LOOP IS CLOSED. THE  FGD SYST[N
                                BEGAN INITIAL OPERATIONS  IN APRIL,  1973.
LOUISVILLE GAS  &  ELECTRIC
TRIMBLE COUNTY
1
NEW       575.0 MU  (GROSS)
          575.0 WW  (ESC)
COAL
 4.00 XS  BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6      STARTUP   7/84
                                LOUISVILLE GAS AND ELECTRIC  WILL  8E  INSTALLING FGO SYSTEMS ON  TWO  OF  THE
                                FOUR BOILERS AT THE  UTILITY'S  PLANNED TRIMBLE COUNTY STATION IN  BEDFORD,
                                KENTUCKY. THE PULVERIZED  *»  S  (IF NO COAL WASH IS INCLUDED) COAL  FIPED
                                UNITS' FLUE 6AS KILL  BE  CLEANED BY  ESP'S  AND WET SCRUBBING (9QX  REMOVAL
                                EFFICIENCY). SLUDGE  DISPOSAL  STRATEGY IS  UNDECIDED. UNIT 1 IS  SCHEDULED
                                FOR START UP IN JULY  OF  1984.
LOUISVILLE GAS  t  ELECTRIC
TRIMBLE COUNTY
2
HEW       575.0 MW  (GROSS)
          575.0 MW  (ESC)
COAL
 4.00 XS  BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTIONS  ****X
STATUS 6     STARTUP   7/86
                                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  42  S  (IF  NO COAL WASH IS INCLUDED) COAL  FIRED
                                UNITS' FLUE GAS WILL Bt  CLEANED BY ESP'S  AND WET SCRUBBING (90X REMOVAL
                                EFFICIENCY). SLUDGE DISPOSAL STRATEGY  IS  UNDECIDED. UNIT 2 IS SCHEDULED
                                FOR START UP IN 19S6.
MICHIGAN SO. CENTRAL  PWfi  AGENC THE PROJECT 1 UNIT OF MICHIGAN  SOUTH  CENTRAL  POWER AGENCY IS TO BE  CON-
PROJECT
1
NEW
           S5.0  MU  (GROSS)
           55.0  MU  (ESC)
COAL
 2.25 XS
LIMESTONE
BABCOCK K U1LCOX
ENERGY CONSUMPTION: ****X
STATUS 3      STARTUP  7/82
STRICTED IN LITCHFIELD,  MICHIGAN,  AND WILL UTILIZE A WET LIMESTONE  FGD
PROCESS.  THE PULVERIZED  COAL  FIRED  BOILER WILL FEED ITS FLUE GAS  THROUGH
A HOT SIDE ESP FOLLOWED  BY  A BABCOCK AND  WILCOX LIMESTONE SPRAY TOWER.
THE CLEANED GAS WILL  PASS  THROUGH  A  HIST  ELIMINATOR BEFORE PEING WARMED
BY AN IN-LINE REHEATER AND  EXITING  A 25P  FOOT STACK.  THE SLUDGE IS  TO
BE DISPOSED OFF SITE. START UP IS  SCHEDULED FOR JULY, 1982.
                                                 20

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                                              EPA UTILITY FGD SURVEY: JANUARY - MARCH 198n
                                              SECTION I
                                        STATUS OF  FGD SYSTEMS
JSIT IDENTIFICATION
                                                                  ABSTRACT
H1DDLE SOUTH UTILITIES
ARKANSAS COAL
5
NEU       890.0 MU (GROSS)
          89D.O MW (ESC)
COAL
  .50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: •*•*!{
STATUS 5     STARTUP  1/86
MIDDLE SOUTH UTILITIES HAS  AWARDED  CONTRACTS  ON SIX NEW LOU SULFUR 
COAL  FIRED  UNITS.  THE UTILITY IS CURRENTLY REQUESTING/EVALUATING  BIDS  FOR
THE  FGO  SYSTEMS,  ALTHOUGH THE TYPE OF SYSTEM HAS NOT  BEEN  DECIDED.  MISSIS-
SIPPI  COAL  1  WILL START UP IN 1985.
DIDDLE  SOUTH  UTILITIES
MISSISSIPPI COAL
2
NEU        890.0 MU  (GROSS)
           890.0 MW  (ESC)
COAL
   .50 XS
PROCESS NOT SELECTED
VENDOR  NOT SELECTED
ENERGY  CONSUMPTION:  ***«J
STATUS  5      STARTUP   0/87
MIDDLE  SOUTH  UTILITIES HAS AWARDED CONTRACTS ON SIX  NEW  LOW  SULFUR (Q.5X)
COAL  FIRED  UNITS. THE UTILITY is CURRENTLY REQUESTING/EVALUATING  BIDS fOR
THE  FGD  SYSTEMS,  ALTHOUGH THE TYP-F OF SYSTEM HAS NOT  BEEN  DECIDED. MISSIS-
SIPPI COAL  2  WILL START UP IN 1987.
                                                  21

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 EPA UTILITY FGD SU»VEY: JANUARY  -  MARCH  1980
                                               SECTION i
                                         STATUS  OF FGD SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 1INNESOTA POWER 8 LIGHT
 CLAY BOSUELL
 4
 NEW       554.C MW (GROSS)
           475.P «U 
 COAL
   .94 XS  SUBBITUMINOUS
 LIME/ALKALINE FLYASH
 PEABOOY  PROCESS SYSTEMS
 ENERGY CONSUMPTION:  1.3X
 STATUS 2     STARTUP  4/80
 CLAY  BOSNELL  4 OF MINNESOTA POyER AND LIGHT  IS  A  SUBBITUMINOUS  COAL O.54X
 S, 8896  bTU/LB) FIRED UNIT UNDER CONSTRUCTION IN  COHASSfT,  MINNESOTA.
 PEABODY  PROCESS SYSTEMS WILL SUPPLY A LI ME/ALKALINE  FLYASH  SYSTEM HHICH
 IS DESIGNED  TO REMOVE 69X OF THE S02 IN THE  FLUE  GAS.  TWO HOT  SIDf ESP'S
 WILL  BE  FOLLOWED BY VENTURI/SPRAY TOWER TRAINS.  MIST  ELIMINATION  WILL  BE
 PROVIDED  BY  A  SIEVE TRAY FOLLOWED BY A SPIN  VASE  CHEVRON, AND  REHfAT WILL
 BE PROVIDED  BY BYPASSING 5X OF THE FLUE GAS. THE  SYSTEM  WILL OPcRME IN A
 CLOSED WATER  LOOP MODE, AND THE SLUDGE WILL  BE  DISPOSED  IN  A LINED POND.
 OPERATIONS  ARE SCHEDULED TO COMMENCE IN APRIL,  1980.
 "UNNKOTA POWER COOPERATIVE
 PULTON R. YOUNG
 Z
 nw        440.0 MM (GROSS)
           405.0 MU (ESC)
 COAL
   .70 XS  LIGNITE
 LIME/ALKALINE FLYASH
 ADI/COMBUSTION EQUIP ASSOCIATE
 ENERGY CONSUMPTION:  1.6X
 STATUS 1     STARTUP  9/77
MINNKOTA  POWER  COOPERATIVE'S MILTON R. YOUNG  2  IS  A  CYCLONE  FIRE&  LIGNITE
(0.70XS,  6500 BTU/LB) BOILER LOCATED IN CENTER, NORTH  DAKOTA.  TH£  BOILER
PRODUCES  ?,021,4QO ACFM OF FLUE GAS, WHICH IS CLEANED  BY  TWO  ESP'?  AND  TWO
ADL/COMBUSTION  EQUIPMENT ASSOCIATES LIME/ALKALINE  FLYASH  SPPAV  TOWERS  (75X
DESIGN  SO?  REMOVAL EFFICIENCY). THE CLEANED GAS PASSES THROUGH  A  CHEVRON
MIST  ELIMINATOR BEFORE IT JOINS A 15X BYPASS  ȣHEAT  AND  EXITS  A 550 FOOT
STACK.  THE  WATER LOOP IS OPEN, AND THE SLUDGE IS TRUCKED  TO  AN  OFf-SlTE
MINEFILL. THIS  SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER,  1977.
 MONTANA  POUER
 COLSTRIP
 1
 1EW        360.0 MU (GROSS)
           360.0 MU (ESC)
 COAL
   .77 XS  SUBBITUHINOUS
 LIME/ALKALINE FLVASH
 ADL/COMBUSTION EOUIP ASSOCIATE
 ENERGY CONSUMPTION:  3.3X
 STATUS 1     STARTUP  9/75
COLSTRIP  1  OF  MONTANA POUER IS A SUBBITUMINOUS COAL  (0.77X  ;,  884?  PTU/LB)
FIRED UNIT  LOCATED  IN COLSTRIP, MONT/SNA. AOL/COMB USTION EQUIPMENT  ASSOCI-
ATES SUPPLIED  A  LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING  OF  THREE
VENTURI SCRUBBER/SPRAY TOUER ABSORBER TRAINS. THE ABSORBERS ARE  FOLLOUED
BY HORIZONTAL  CHEVRON MIST ELIMINATORS, A STEAM TUBE  REHEATER,  AND  A  SCO
FOOT STACK.  THE  UNSTABILI7ED SLUDGE IS DISPOSED IN AN ON-S1TE  LINED  POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN  IN SEPTEMBER  OF  1975.
 10NTANA  POUER
 COLSTRIP
 2
 MEW        360.0 MU (GROSS)
           360.0 MU (ESC)
 COAL
   .77  XS  SUBBITUMINOUS
 LINE/ALKALINE FLYASN
 ADL/COMBUSTION EOUIP ASSOCIATE
 ENERGY CONSUMPTION:  3.3X
 STATUS 1     STARTUP  5/76
COLSTRJP  1  OF  MONTANA POWER IS A SUBBITUMINOUS COAL  (0.77*  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 TOUER ABSORBER TRAINS. THE ABSORBERS ARE  FOLLOWED
BY HORIZONTAL  CHEVRON MIST ELIMINATORS, A STEAM TUBE REHEATER, AND  A  5'0
FOOT STACK. THE  UNSTABILIZED SLUDGE  IS DISPOSED IN AN ON-SlTE  LINED  POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN MAY OF 1976.
MONTANA  POUER
COLSTRIP
3
NEW        700.0 MU  (GROSS)
           700.0 MH  (ESC)
COAL
  .70 XS
LIME/ALKALINE  FLVASH
ADL/COMBUSTION EQUIP  ASSOCIATE
ENERGY CONSUMPTION: ****!
STATUS 2     STARTUP   1/84
MONTANA POUER'S  COLSTRIP  3  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/COMBUSTION EQUIPMENT ASSOCIATES FOR A LIME/ALKALINE  FLYASH
FGD SYSTEM ON THIS  UNIT.   START UP IS SCHEDULED FOR JANUARY, 1984.
HONTANA POWER
COLSTRIP
4
NEW       700.0 MU  (GROSS)
          700.0 MU  (ESC)
COAL
  .70 XS
LIME/ALKALINE FLVASH
AOL/COMBUSTION EQUIP  ASSOCIATE
ENER6V CONSUMPTION: ****X
STATUS 2     STARTUP   0/8*
MONTANA POUER'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/COMBUSTION EQUIPMENT  ASSOCIATES FOR A LIME/ALKALINE FLVASH
FGD SYSTEM ON THIS UNIT.  START  UP  IS SCHEDULED FOR 1984.
                                                 22

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                                              EPA UTILITY FGD SURVEY: JANUARY - MARCH  I960
                                              SECTION 2
                                        STATUS Of  FGD SYSTEMS
JSIT IDENTIFICATION
                                                                  ABSTRACT
•USCAT1NE POWER 8 WATER
1JSCATJNE
9
MEW       166.0 "W (GROSS)
          160.0 »W (ESC>
COAL
 J.17 XS  BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION:
STATUS 3
                  MUSCAT1NE 9 IS  A PULVERIZED  BITUMINOUS  COAL OX S. 11,230 6TU/L6) fIREO
                  UNIT PLANNED B» MUSCATINE  PONER  AND  WATER TO PE LOCATED IN MUSCATISE,
                  IOWA. A CONTRACT WAS  AtiAROEO TO  RESEARCH COTTRELL FOR « LIMESTONE UNIT FOR
                  EMISSION CONT1QL.  THE  FGO  SYSTEM WILL FEATURE AN ESP, TWO 1CCX CAPACITY
                  TOWERS, STEAf CC1L REHEAT,  A CLOSED  WATER LOOP. AND FOSCfcD OXIDATION OF
                  THE SLUDGE BEFORE  LANDFILL.  THE  DESIGN  502 REMOVAL WILL BE 94X. START UP
                  WILL TAKE PLACE IN 1982.
        4.82
STARTUP  9/82
NEVADA POWER
HARRY ALLEN
1
Ntw       500.C rw  (GROSS)
          500.C *w  (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 UMT TO BE  LOCATED  IN
                  LAS VEGAS, NEVADA.  THE  UTILITY IS CONSIDERING A HOT SIDE ESP IN  CONJUNC-
                  TION WITH AN  FGO  SYSTEM.  SPECIFICATIONS HAVE NOT YET BEEN PREPARED.  START
                  UP IS SCHEDULED  FOR  JUNE, 1986.
NEVADA POWER
HARRY ALIEN
2
NEW       500.0 MU  (GROSS)
          500.0 MW  (ESC)
COAL
***** XS
PROCESS NOT  SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  ****X
STATUS 6      STARTUP   6/87
                  NEVADA POWER'S  HARRY  ALLEN 2 IS A PLANNED COAL FIRED  UNIT  TO  BE  LOCATED  IN
                  LAS  VEGAS,  NEVADA.  THE  UTILITY IS CONSIDERING A HOT SIDE  ESP  IN  CONJUNC-
                  TION WITH AN  FtD  SYSTEM.  SPECIFICATIONS HAVE NOT YET  BEEN  PREPARED.  START
                  UP  IS SCHEDULED  fOR JUNE, 1967.
NEVADA POWER
HARRY ALLEN
3
NEW        500.0  MU  (GROSS)
           500.0  MU  (ESC)
COAL
***** XS
PROCESS NOT  SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  *****
STATUS 6      STARTUP   6/88
                  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 YET  BEEN  PREPARED.  START
                  UP  IS  SCHEDULED FOR JUNE, 1988.
NEVADA  POWER
HARRY ALLEN
4
NEW        500.0  »W  (GROSS)
           500.0  MM  (ESC)
COAL
***** XS
PROCESS NOT  SELECTED
VENDOR  NOT SELECTED
ENERGY  CONSUMPTION.-  ****X
STATUS  6      STARTUP   6/89
                   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 SYSTEM. SPECIFICATIONS  HAVE NOT VET  BEEN PREPARED. START
                   UP  IS SCHEDULED FOR JUNE, 1989.
NEVADA POWER
REID  GARDNER
1
RETROFIT   125.0  flU  (GROSS)
           125.0  MU  (ESC)
COAL
   .50 XS   BITUMINOUS
SODIUM CARBONATE
AOL/COMBUSTION  ECUIP  ASSOCIATE
ENER6Y CONSUMPTION: *••*)[
STATUS 1      STARTUP   4/74
                   REID  GARDNER  1 IS A MET BOTTOM LOW SULFUR  COAL  10.51  S,  12,450 BTU/LB)
                   FIRED UNIT OWNED BY NEVADA POWER, LOCATED  IN  MOAPA,  NEVADA. A SODIUM CAR-
                   BONATE-BASED  (TRONA) SCRUBBING SYSTEM BY  AOL/COMBUSTION  ECUIPHENT ASSOCI-
                   ATES  CONSISTS OF ONE MODULE CONTAINING  TWIN  VARIABLE  THROAT VENTURIS FOL-
                   LOWED BY A SEPARATOR IN SERIES WITH \ SINGLE  STAGE  PEFORATED PLATE WASH
                   TOWER. PRIMARY PARTICULATE CONTROL IS PROVIOEC  BY  UPSTREAM MULTICLONES.
                   A  RADIAL VANE MIST ELIMINATOR PRECEDES  AN  INDIRECT  STEAM HOT AIR REHEATED
                   AND  A 200 FOOT STACK. THE SYSTEM OPERATES  IN  AN OPEN  WATER LOOP, AND THE
                   SLUDGE IS DISPOSED IN AN ON-SITE CLAV LINED  SOLAR  EVAPORATION POND. THE
                   DESIGN SO? REMOVAL EFFICIENCY IS 9Qt. THE  SYSTEM HAS  BEEN OPERATIONAL
                   SINCE APRIL,  1974.
                                                  23

-------
 EPA UTILITY  FGB  SURVEY: JANUARY - MARCH 1980
                                               SECTION t
                                         STATUS OF F6D SYSTEMS
 JNIT IDENTIFICATION
                                                                    ABSTRACT
 NEVADA POWER
 REID GARDNER
 2
 RETROFIT  125.0 MW  (GROSS)
           135.0 MW  
-------
                                              EPA UTILITY  FGO  SURVEY:  JANUARY - MARCH 19E'
                                              SECTION 2
                                        STATUS Of FGD SYSTEMS
JMT IDENTIFICATION
                                                                   ABSTRACT
NIAGARA MOHAWK  POWFR  COOP
CHARLES R. HUNTLFY
66
HETfiOflT   100.0  "U  (GROSS)
           100.0  "W  (ESC)
COAL
 1.60 *S
ABUEOUS CARBONATF
ROCKWELL  INTERNATIONAL
ENERGY CONSUMPTION: *****
STATUS 2      STARTUP   4/?2
                                CHARLES  R.  HUNTL
                                12,530 PTU/LB) F
                                AWARDED  TO  ATOMI
                                F.FF HUNT ReTSOF
                                TAL  SULFU"  AS AN
                                THE  EMPIRE  STATE
                                FOLLOWED BY TWO
                                STACK. THE  WATEP
                                1082.
                                                EY 6t OF NIA&ARA  POWER  COOP  is  A PULVERIZED COAL (i.sx s,
                                                JRED UNIT LOCATED  IN  BUFFALO,  MEW >ORK.  A CONTRACT W IS
                                                CS INTERNATIONAL  FOR  THE  DESIGN AND INSTALLATION OF A 9^*
                                                IT AGUEOUS CARBONAT?  FG6  SYST?* WHICH WILL PRODUC? EL^.EN-
                                                 END PRODUCT.  FUNDS  ARE  BEING  PROVIDED BY THE U.S.EPA AND
                                                 ELECTRIC ENERGY  RESEARCH CORP. A SPR»Y DRYER WILL EE
                                                bANKS OF FIGHT CYCLONES  AN ESP, AND A ?"C FOOT STfEL  LINED
                                                 LOOP WILL BE  OPEN.  START UP OF THE FGD SYSTEM WILL BE IN
          INDIANA  PUB  SERVICE
DEAN H. MITCHELL

RETROFIT   115.C MW  (GROSS)
           115." "W  (ESC)
COAL
 3.5C  IS
JeLLMAN LORD
0»VY POWERGAS
E!»CRGY  CONSUMPTION: 27.8*
STATUS  1      STARTUP   7/76
                                NORTHERN INDIANA PUBLIC SERVICE'S  DEAN  H. MITCHELL 11 IS A COAL  (?.5X  S,
                                11,000 PTU/LB) FIRED UNIT  LOCATED  IN  GARY, INDIANA. A RETROFIT WELLMAN
                                LORD FGD SYSTrK BY DAVY POWERGAS  HAS  BEEN OPERATING ON THIS UNIT  SINCC
                                JULY,  197«. AN ESP IS FOLLOWED  PY  A  VARIABLE THROAT VENTURI SCSUBPER
                                AND A  TRAY TOWER ABSORBER  (90*  DESIGN S02 REMOVAL EFFICIENCY). A  DIRECT
                                COMEUSTION RAISES THE CLEANED GAS  TEMPERATURE 5-" DEC F BEFORE  THE GAS
                                IS DISCHARGED THROUGH A 168  FOOT  STAINLESS STEEL AND FRP LINED STACK.
                                ELEMENTAL SULFUR AND SULFATE  IS PRODUCED  PY THE PROCESS DEVELOPED faY
                                ALLIED CHEMICAL. THE SYSTEM  OPERATES  IN A CLOSED WATER LOOP MODE.
NORTHERN  INDIANA  PUB  SERVICE    SCHAHFtP 17 OF NORTHERN  INDIANA  PUBLIC SfRVICc IS A 3.2X  SULFUR  COAL  FIRED
SCHAHFER                        UNIT PLANNED FOR CONSTRUCTION  IN WHEATFIELD, INDIANA. THE UTILITY  H»S
?                               SIGNED A LETTER OF INTENT  WITH F MC  FOR THE INSTALLATION OF  A  DUAL  ALKALI
                                F6D SYSTEM AT THIS UNIT. PART1CULATE MATTER WILL BE COLLECTED  BY  AN  ESP
                                AND THE SYSTE" WILL  INCLUDE  A  REHFATEfi.  START UP OF THIS UNIT  IS
                                SCHEDULED FOR JUNE OF  1983.
          421.0  MU  (GROSS)
          421.0  MW  (ESC>
.,F-

C()AL
 3.Zr
OJAL ALKALI

[NERGY  CONSUMPTION: *****
STATUS  *      STARTUP  6/85
          INDIANA PUB SERVICE
SCHAHFER
1E
           421.0 MW (GROSS)
           421 .C MW (ESC)
COAL
 3.2"  US   BITUMINOUS
OJAL ALKALI

ENERGY  CONSUMPTION: *****
STATUS  *      STARTUP  6/85
                                SCHAHFER 18 OF NORTHERN  INDIANA  PUBLIC SERVICE  IS  A  3.2X  SULFUR  COAL FIRED
                                UNIT PLANNED FOR CONSTRUCTION  IN WHEATFIELD, INDIANA.  THE  UTILITY  HAS
                                SIGNED A LETTER  OF  INTENT  WITH FWC FOR THE INSTALLATION  OF A  DUAL  ALKALI
                                FGD SYSTEM AT THIS  UNIT. PARTICULATE MATTER WILL BE  COLLECTED BY AN ESP
                                AND THE SYSTE" WILL INCLUDE  A  REHfATER.  START  UP  OF  THIS  UNIT IS
                                SCHEDULED FOR JUNE  OF  1985.
          STATES POWER
RIVERSIDE
           110.0 MU (GROSS)
           110.0 MW (ESC)
COAL
 1.5
            DRYING
JOY  MFG/N1RO ATOMI7ER
ewERGY  CONSUMPTION: *****
TTATUS  2
                                RIVERSIDE 6 AND  7  ARE  TWO COAL FIRED BOILERS OWNF.D  BY  NORTHERN STATES
                                POWER AND LOCATED  IN MINNEAPOLIS, MINNESOTA.  EACH  BOILER  GENERATES A FLUE
                                GAS  FLOW OF 320,000  ACFM AT 350 F. CURRENTLY, A  DEMONSTRATION LIME/SPRAY
                                DRYING  FGD SYSTEM  IS  UNDER CONSTRUCTION THAT WILL BE  CAPABLE  OF TREATING
                                THE  FLUE GAS  FROM  BOTH BOILERS.  THE SYSTEM If BEING  SUPPLIED BY
                                NIRO ATOMIZER/JOY  MANUFACTURING AND WILL CONSIST OF A  SPRAY pR»ER FOLLOWED
                                BY A BAGHOUSE.   THE  CLEAN FLUE GAS WILL EE VENTED TO  TWO  3QC  FT CONCRETE
                                STACKS  WITH FIRE BRICK LINERS.  SPENT ABSORBENT  WILL  BE  DISPOSED OF IN ON
                                AND  OFF SITE  LANDFILLS.  OPERATIONS ARE EXPECTED TO BEGIN  IN  JULY, 1V8C.
                                NORTHERN  STATES  POWER'S SHERBURNE  1  IS  A  BALANCED DRAFT PULVERIZED SUB6I-
                                TUMINOUS  COAL  (C.80* S, 8*00 BTU/IB)  FIRED  BOILER IN BECKER, MINNESOTA. A
                                SOX  EFFICIENT  (DESIGN) LIWESTONE/ALKALINE  FLYASH FGD SYSTEM SUPPLIED BY
                                COMBUSTION ENGINEERING HAS BEEN  OPERATIONAL ON  THIS UNIT SINCE MA">CH Of
                                1976.  TWELVE  VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
                                ARE  FOLLOWED  BY  ONE CHEVRON MIST ELIHINATORS/TRAIN, AN IN-LINE HOT WATER
                                REMEATER, AND  A  650 FOOT CORTEN  LINED STACK. THE SLUDGE IS FORCIBLY OXI-
                                DIZED  AND DISPOSED IN A CLAY LINED  SETTLING POND. THE WATER LOOP IS OPEN.
NORTHERN  STATES  POWER
SHERBURNE

1,u        7AO.O  "W (GROSS)
'lfc"        740.0  MW (ESC)

C°*gO  XS   SUBBITUMINOUS
, ,-ESTONE/ALKALlNE fLlASH
COMBUSTION ENGINEERING
      * CONSUMPTION:  2.7*
STATUS 1     STARTUP  3/76
                                                  25

-------
 EPA  UTILITY F&O SU"VEY:  JANUARY  - MARCH 19SC
                                               SECTION  i
                                         STATUS OF  FGD  SYSTEMS
 JNIT IDENTIFICATION
                                                                    APSTR* CT
 NORTHERN STATES POWER
 SHERBURNE
 2
 NEW        740.T MW (GROSS)
           740.? »H (ESC)
 COAL
   .80 XS  SURBITUMINOUS
 LIMESTONE/ALKALINE FL»«SH
 COMBUSTION ENGINEERING
 ENERGY CONSUMPTION:  2.71
 STATUS 1     STARTUP  4/77
NORTHERN  STATES  POWER'S SHERBURNE  2  IS  A  BALANCED DRAFT PULVERIZED  SUPfal
TUM1NOUS  COAL Sl  S,  8500 BTU/LB) FIRED UNIT TO  B?  CON-
STRUCTED  IN  BECKER, MINNESOTA.  DUE  TO THE LATEST TECHNOLOGY  THAT HAS  BEEN
DEVELOPED BIDS  HAVE AGAIN BEEN  OPENED.   THE  UTILITY IS PRESENTLY EVALUAT-
ING  THREE DIFFERENT TYPES OF  FGD SYSTEMS.  MAY, 1984 IS EXPECTED START UP.
 OTTE"  TAIL POwER
 COYOTE
 1
 NEW        440.? MU (GROSS)
           440.0 MW (ESC)
 COAL
   .87  XS   LIGNITE
 AQUEOUS  CARBONATE/SPRAY DRYING
 JHEELABRATOR-FRYE/R.I .
 ENERGY  CONSUMPTION:  1.1X
 STATUS  2      STARTUP  3/81
COYOTE  1  IS  A  CYCLONE FIRED PULVERIZED  LlGNiTE (0.875X S, 7050 BTU/LB)
BOILER  UNDER  CONSTRUCTION IN BEULAH,  NORTH  DAKOTA. THIS UNIT IS JOINTLY
OWNED BY  FIVE  UTILITIES, WITH OTTER TAIL  POWER BEING THE MAJOR OWNER  «KD
CONSTRUCTOR.  AN AQUEOUS CARBONATE DRY  FGD  SYSTEM DESIGNED TO REMOVE  7^1
OF THE  S02  IS  BEING SUPPLIED BY WHEELABRATOR-FRYE  AND ATOMICS INTFRNATIOK.
At. THE SPRAY  OR YER/B AGHOUSE SYSTEM IS  SCHEDULED TO START UP IN
PACIFIC  GAS  8  ELECTRIC
10NTEZUMA
1
NEW        800.0 «W (GROSS)
           800.0 MW (ESC)
COAL
   .80  XS  SUBBITUMINOUS
LIMESTONE
VENDOR  NOT  SELECTED
ENERGY  CONSUMPTION:  3.51
STATUS  6     STARTUP  6/87
MONTEZUMA  1  OF  PACIFIC GAS AND ELECTRIC  IS  A  CO«L (O.PX S, 12fCQQ  BTU/LB)
FIRED BOILER  PLANNED FOR COLL IN 5VILLE, CALIFORNIA. THE EMISSION CONTROL
SYSTEM WILL  CONSIST OF A PAGHOUSE AND  A  LIMESTONE FGD SYSTEM. SLUDGE  WILL
BE DISPOSED  OF  IN A LANDFILL. START UP DATE  IS  JUNE, 1937.
PACIFIC  GAS  8  ELECTRIC

-------
                                              EPA UTILITY FGO SURVEY: JANUARY  - MARCH  196C
                                              SECTION i
                                        STATUS Of  FGO SYSTEMS
JN1T IDENTIFICATION
                                                                  ABSTRACT
PENNSYLVANIA POWER
3I1UC? MANSFIELD
1
NEW       917." *W (GROSS)
          917.^ »W (ESC)
COAL
 3.0*1 * S  BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION:   6.0*
STATUS 1     STARTUP  12/75
                               BRUCE MANSFIELD  1 OF  PENNSYLVANIA  POWER
                               BOILER FIRING PULVERIZED  COAL  (3.P* S, 1
                               PENNSYLVANIA. A  CHEMICO  TH10SORBIC LIME
                               FLYASH AND SO?  (92.1)(>  FROM 3,350,000 AC
                               CONSISTS OF  SIX  VARIABLE  THROAT VCNTURI
                               THROAT VENTURI  ABSORt?RS, HORIZONTAL MIS
                               TION REHEATERS,  AND  A 95C FOOT FLAKEGLAS
                               THE WATER LOOP  IS OPEN,  AND THE CALC1LOX
                               AN OFF SITE  LANDFILL. THIS SYSTEM  HAS BE
                               1975 .
                                                    IS « SUPERCRITICAL, BALANCED  DRAFT
                                                    1,50C BTU/LB)  IN  SHIPPIN&PORT,
                                                    FGD SYSTEM WAS  DESIGNED  TO  CEMOVE
                                                    FM OF FLUE GAS. THE FGD  SYSTEM
                                                    SCRUBRERS  FOLLOWED BY  SIX  FIXED
                                                    T ELI"INATORS,  TWO DIRECT  COMBuS-
                                                    S STACK SHARED  PY UNITS  1  AND I.
                                                     STABILIZED  SLUDGE IS  DISPOSED  IN
                                                    EN OPERATIONAL  SINCE  DECE^bER,
PENNSYLVANIA POWER
3RUC f. MANSFIELD
2
MEW       917.C  MW  (GROSS)
          917.0  MW  (ESC)
COAL
 3.CO X S  BITUMINOUS
LIME
CHEMICO
ENERGY  CONSUMPTION:  6.C*
STATUS  1     STARTUP   7/77
                               BRUCE MANSFIELD  i  OF  PENNSYLVANIA POWER IS A SUPERCRITICAL,  BALANCED  DRAFT
                               BOILER  FIRING  PULVERIZED  COAL H.CX S, 11.50C BTU/LB)  IN  WHIPPINGPOST,
                               PENNSYLVANIA.  A  CHEMICO  TH10SOREIC LIME FGD SYSTEM WAS  DESIGNED  TO  REMOVE
                               FLYASH  AND  SO? (V2.1X)  FROM 3,35C,000 ACFM OF FLUE GAS.  THE  FGD  SYSTEM
                               CONSISTS  OF  SIX  VARIABLE  THROAT VENTURI SCRUBBERS FOLLOWED BY  SIX  fIXEC
                               THROAT  VENTUfil ABSORBERS, HORIZONTAL MIST ELIMINATORS,  TWO DIRECT  COMPtS-
                               TION REHEATERS,  AND  A 950 fOOT FLAKEGLASS STACK  SHARED  BY UNITS  1  AND ;.
                               THE  «ATER LOOP IS  OPEN,  AND THE CALCILOX STABILIZED  SLUDGE IS  DISPOSED  IN
                               AN OFF  SITE  LANDFILL. THIS SYSTEM HAS BEEN OPERATIONAL  SINCE JULY,  1977.
PENNSYLVANIA  POWER
3RUCE MANSFIELD
j
•4EW        917.0  »W  (GROSS)
           917.C  MW  (ESC)
COAL
 3.or1 *s
LIME
PULLMAN KELLOGG
ENERGY  CONSUMPTION: •**•»
STATUS  2      STARTUP 10/80
                               BRUCE  MANSFIELD  3 OF PENNSYLVANIA POWER  IS  A  SUPERCRITICAL  PULVERIZED COAL
                                (7.03t  S,  11,5r>C  BTU/LB) FIRED BOILER UNDER  CONSTRUCTION  IN  S HIPP INGPOR T ,
                               PENNSYLVANIA.  FOUR ESP'S WJLL TREAT 3,308,000 ACFM  OF  FLUE  GAS, FOLLOWED
                               BY  FIVE  (ONE  SPARE) PULLMAN KELLOGG THIOSORBIC  LIME ABSORBERS WHICH
                               WILL REMOVE  92.2X OF TH£ S02. THE CLEANED GAS WILL  PASS  THROUGH
                               CHEVRON  MIST  ELIMINATORS AND DIRECT COMBUSTION  REHEATERS BEFORE
                               DISCHARGE THROUGH A 6 <"0 FOOT 1NCONEL 625 LINED  STACK.  THE  FLYASH STA-
                               BILIZED  SLUDGE WILL b€ PIPED TO THE EXISTING  OFF  SITE  LANDFILL PRESENTLY
                               USED BY  UNITS  ONE AND TWO. START UP IS EXPECTED IN  OCTOBER, 198C.
 PHILADELPHIA  ELECTRIC
 CROMBY
RETROFIT
           150. H  MW (GROSS)
           150. C  «W (ESC)
            PHILADELPHIA FLECTRIC HAS PLANS  FOR  THE  RETROFIT OF AN FGO SYSTEM ON ONE
            OF  THE TWO 3.nx SULFUR COAL  FIRED BOILERS  AT CROMBY STATION IN PHOEN1X-
            VILLE, PENNSYLVANIA.  A CONTRACT  HAS  BEEN  AWARDED TO UNITED ENGINEERS
            FOR  A MAGNESIUM OXIDE SYSTEM.   THE  START UP D«TE IS SET FOR 1962.
 COAL
  3.C?  XS
 MAGNESIUM  OXIDE
 JNITEO  ENGINEERS
 ENERGY  CONSUMPTION: •***«
 STATUS  3      STARTUP 12/82
 PHILADELPHIA
 EDDYSTONE
 1 A
 RETROFIT
              ELECTOR
          120."  MW  (GROSS)
          120.9  MW  (ESC)
COAL
 2.60 XS  BITUMINOUS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: •*•*»
STATUS 1      STARTUP   9/75
 PHILADELPHIA
 EDBYSTONE
 IB
 RETROFIT
              ELECTRIC
          240.0  MU
          240.0  MW
(GROSS)
(ESC)
 COAL
  2.60 XS
 1AGNESIUM
           OXIDE
 UNIT  1  OF PHILADELPHIA ELECTRIC'S  E&D*STONE.  PENNSYLVANIA STATION IS  A
 BITUMINOUS COAL (2.6X S, 13,600 BTU/LB)  FIRED UNIT WHICH USES ESP'S,
 MECHANICAL COLLECTORS, AND THREE PARTICULATE  SCRUBBERS (TWO VENTRI ROD
 AND ONE VENTURI) PROVIDE PRIMARY PARTICULATE  CONTROL. THE 1A FGD SYSTEM
 CONSISTS  OF A MAG OX OOD DECK  SPRAY  TOWER FOLLOWING THE VENTURI SCRUBBER.
 THE 90X EFFICIENT (DESIGN) ABSORBER,  A  RETROFIT BY UNITED ENGINEERS,  LEADS
 TO A  LOUVER TYPE MIST ELIMINATOR,  A  DIRECT COMBUSTION REMEATtR, AND  A
 249 FOOT  STACK. THE SPENT SLURRY IS  REGENERATED AT THE ESSEX SULFURIC
 ACID  PLANT IN NEWARK, NEW JERSEY,  AND  THE MAG-OX is RETURNED TO EPDY-
 STONE.  THE SYSTEM OPERATES IN  AN OPEN  WATER LOOP, AND HAS BEEN OPERA-
 TIONAL  SINCE SEPTEMBER, 1975.
•»—•»••— ——•—••!•—•••••••«•—••••»••••—• •»•• ••«•»««••»•«•••»•*•••••••»_,»• W»W »
 UNIT  1  OF PHILADELPHIA ELECTRIC'S  EDDYSTONE,  PENNSYLVANIA STATION IS  A
 BITUMINOUS COAL (2.6)1 S, 13.6CO 6TU/LB)  FIRED UNIT WHICH USES ESP'S,
 MECHANICAL COLLECTORS, AND THREE PARTICULATE  SCRUBBERS (TWO ROD DECK
 SPRAY TOWERS AND ONE VENTURI)  FOR  PRIMARY PARTICULATE CONTROL.  THE
 16 FGD  WILL FOLLOW  THE TWO ROD DECK  SPRAY TOWERS.  UNITED ENGINEERS
 WILL  SUPPLY A MAGNESIUM 0*I&E  fGD  SYSTEM FOR  EMISSION CONTROL.
 THE START UP DATE IS SET FOR  DECEMBER,  1982.
 JNITED ENGINEERS
 ENERGY CONSUMPTION: ****X
 STATUS 2     STASTUP  12/82
                                                  27

-------
 EPA  UTILITY FGD SURVEY:  JANUARY - MARCH 198C
                                               SECTION  2
                                         STATUS OF  fGD  SYSTEMS
 JNIT  IDENTIFICATION
                                                                    AESTR* CT
 PHILADELPHIA ELECTRIC
 EDDYSTONE
 RETROFIT

 COAL
  i.50 XS
 MAGNESIUM
334.?
334.T
           OXIDE
MW
MW
(GROSS)

EDDYSTONE I OF  PHILADELPHIA ELECTRIC IS A 2.5*  SULFUR  COAL F IBEb BOILER
LOCATED 1H EDDYSTONE,  PENNSYLVANIA.  THE PLANT'S  GENERATING
CAPACITY IS 3T4  MU.   UNITED ENGINEERS WILL SUPPLY  A  MAGNESIUM OXIDE
FCD SYSTEM FOR  EMISSION  CONTROL.  START UP IS SET  FOR  DECEMBER. 19S^.
 JNITED  ENGINEERS
 ENERGY  CONSUMPTION: *****
 STATUS  2     STARTUP 1?/f2
 POTOMAC  ELECTRIC POWER
 DICKERSON
 I.
 HEW        650.H py (GROSS)
           BOO.? My 
 COAL
 1.9H  XS   BITUMINOUS
 PROCESS  NOT SELECTED
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION: *****
 STATUS 6      STARTUP  5/87
                      DICKERSON 4 OF POTOMAC ELECTRIC  POWER  IS A PULVERIZED  COAL  (2.0* «, 11,000
                      BTU/LP)  FIRED UNIT PLANNED  FOR  LOCATION IN DICKERSON,  MARYLAND.  THE UTIL-
                      ITY  IS  CONSIDERING AN FGD  SYSTEM FOR  THIS UNIT, BUT  THERt ARE  NO F1&M
                      PLANS  FOR THE INSTALLATION  OF  AN FGD  SYSTEM. START UP  OF  THE  BOILER IS
                      EXPECTED  IN 1385. FGD SYSTEM  ST«RT  UP  IS EXPECTED IN MAY, 1967.
PUBLIC  SERVICE  INDIANA
SIB SON
5
MEW        65P.O MW (GROSS)
           650.0 My (ESC)
COAL
 3.30 ZS
LIMESTONE
PULLMAN KELLOGG
ENERGY  CONSUMPTION: ****X
STATUS  3      STARTUP  0/82
                     GIBSON  5  OF  PUBLIC SERVICE OF  INDIANA IS A 3.?* SULFUR  COAL  FIRED UNIT
                     PLANNED  FOR  LOCATION IN PRINCETON,  INDIANA. A CONTRACT  MAS  AWARDED TO
                     PULLMAN  KELLOGG F0« A LIMESTONE  FGD  SYSTEM CONSISTING OF  FOUR  KELLOGG-
                     WEIR  AbSORBER-fEACTOR MODULES.   SYSTEM START UP IS EXPECTED  IN 1VP2.  T
                     SYSTEM  WILL  USE KELLOGG'S PROPRIETARY MAGNESIUM-PROMOTED  LIMESTONE.
PUBLIC  SERVICE  OF  NEW MEXICO
SAN JUAN
1
RETROFIT   361.0 MW (GROSS)
           361 .0 *H (ESC)
COAL
  .fcO XS   SUHB1TUMINOUS
4ELLMAN LORD
DAVY POWE&GAS
ENERGY  CONSUMPTION:  4.4X
STATUS  1      STARTUP  4/78
                     S«N  JUAN  1  OF PUBLIC SERVICE  CF  NEW  MEXICO IN WATERfLQWi  NEW  MEXICO IS A
                     COAL  (0.6*  S, E1-0 PTU/LB)  FIPED  BOILER  WHICH SUPPLIES  1,T19,CCO ACFM Of
                     FLUE  GAS  TO A RETROFIT WELLMAN  LO"D  FGO  SYSTE* BY DAVY  POWERGAS. THE EMIS-
                     SION  CONTROL SYSTEM, OPERATIONAL  SINCE  APRIL OF 1978, CONSISTS  OF A HOT
                     SIDE  ESP  FOLLOWED BY FOUR  (ONE  SPARE)  VENTURI SCRUBBER/SPR AY  TOWEC ABSOR-
                     BER  TRAINS  WHICH WERE DESIGNED  TO REMOVE S5X OF THE FLUE  GAS  S02. AN !»,-
                     DIRECT  HOT  A11 PEHEATER PPECEDE?  * BRICK UNEC STACK. END  PRODUCT ELE«EN-
                     T»L  SULFUR  IS PRODUCED BY  THE ALLIED  CHEMICAL PROCESS.  THE  WATER LOOP IS
                     CLOSED.
PUBLIC  SERVICE  OF  NEW MEXICO
SAN JUAN
2
RETROflT   350.0 MW (GROSS)
           350.0 MW (ESC)
COAL
  .80 XS   SUBBITUMINOUS
BELLMAN LORD
DAVY POWERGAS
ENERGY  CONSUMPTION:  4.6X
STATUS  1      STABTUP  8/78
                     SAN  JUAN  2  OF F>UBLIC SERVICE  OF  NEW  MEXICO JN WATERFLOW,  NEW  MEXICO IS A
                     COAL  (0.6*  S, 81uO RTU/LB) FIRED  P01LER  WHICH SUPPLIES  1,319,000 ACFM Of
                     FLUE  GAS  TO A RETROFIT UELLMAN LORD  FGD  SYSTEM PY DAVY  POWERGAS. THE EMIS-
                     SION  CONTROL SYSTEM, OPERATIONAL  SINCE  AUGUST OF 1978,  CONSISTS  OF  A HOT
                     SIDE  ESP  FOLLOWED BY FOUR  (ONE SPARE)  VENTURI SCRU6BER/SPRAY  TOwEP  ABSOR-
                     BER  TRAINS  WHICH WERE DESIGNED TO REMOVE  P5X OF THE  FLUE  GAS  S02.  AN IK,-
                     DIRECT  HOT  AIR REHEATER PRECEDES  A BRICK  LINED STACK. END PRODUCT  ELEMEN-
                     TAL  SULFUR  IS PRODUCED BY  THE ALLIED  CHEMICAL P10CESS.  THE WATER LOOP IS
                     CLOSED.
PUBLIC  SERVICE  OF  NEW MEXICO
SAN JUAN
3
NEW        534.0 MW (GROSS)
           534.0 MW (ESC)
COAL
  .80 IS   SUBBITUHINOUS
WELLMAN LORD
DAVY POWERGAS
ENERGY  CONSUMPTIONi  3.6X
STATUS  1      STARTUP 12/79
                      SAN  JUAN  T  IS A COAL (0.81 S, 8100  BTU/LB) FJRED UNIT OF  THE  PUfLIC
                      SERVICE  OF  NEW MEXICO AND JS LOCATED  IN WATERFLOW, NEW MEXICO.  THT fGD
                      SYSTEM,  SUPPLIED BY DAW POUERGAS  IS  AN INTEGRATION OF THE WELLMAN
                      LORD  SO?  RECOVERY PROCESS AND ALLIED  CHEMICAL'S SOZ REDUCTION TO  fULfUfi
                      PROCESS.  FIVE (ONE SPARE) VENTURI  SCRUBSER/SPRAY TOWER ABSORBER  <9C* DE-
                      SIGN  S02  REMOVAL) TRAINS FOLLOW  A  HOT SIDE ESP. AN INDIRECT  HOT  AJt
                      REHEATER  BOOSTS THE GAS TEMPERATURE  50 DEC F. THE SYSTEM  OPERATES
                      IN A  CLOSED  WATER LOOP MODE. OPERATIONS COMMENCED IN DECEMBER,  19?9.
                                                  28

-------
                                              EPA  UTILITY  fGD  SURVEY: JANUARY - MARCH 1960
                                              SECTION 2
                                        STATUS Of  FGO SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
4
VEU       534.0 MW (GROSS)
          534.P MW (ESC)
COAL
  .80 XS  SUBBITUMINOUS
rfELLMAN LORD
DAVY POWERGAS
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 UATERFLOW, NEW MEXICO. THE FGD
                               SYSTEM BEING  SUPPLIED BY  DAVY  POWERGAS IS AN INTEGRATION OF THE yELLMAM
                               LORD S02 RECOVERY  PROCESS AND  ALLIED CHEMICAL'S S02 REDUCTION TO SULfUR
                               PROCESS. FIVE  (ONE  SPARE) VENTUR1 SCRUBBER/SPRAY TOWER ABSORBER <"C* DE-
                               SIGN SO? REMOVAL)  TRAINS  WILL  FOLLOW A HOT SIDE ESP. AN INDIRECT HOT AIR
                               RFHEATER WILL  BOOST THE  GAS TEMPERATURE 50 DEG F. THE SYSTEM WILL OPERATE
                               IN A CLOSED WATER  LOOP MODE. START UP IS EXPECTED IN JUNE,  1983.
P4R AUTHORITY OF STATE  OF  NY
FOSSIL
*EW
COAL
          700.0 MW  (GROSS)
          700.0 MW  (ESC)
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
NOVEMBER, 1987.
      XS
PROCESS NOT  SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  *****
STATUS 6      STARTUP  11X87
SALT RIVER  PROJECT
CORONAOO
1
NEW       350.r  MW  (GROSS)
          280.0  MW  (ESC)
COAL
 1.00  XS  SUBBITUMINOUS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION:  4.3X
STATUS 1      STARTUP 11/79
                                SALT  RIVER  PROJECT'S CORONADO 1 IS A DR* BOTTOM PULVERIZED  SUBBITUMINOUS
                                COAL  (1.0X  S, 83QO BTUJLB) FIRED BOILER LOCATED IN  ST.  JOHNS.
                                ARIZONA.  PULLMAN KELLOttG SUPPLIED THE TWO LIMESTONE  HORIZONTAL  WEIR  SPRAY
                                TOWERS  WHICH WILL REMOVE P2.5X OF THE S02 FROM THE  FLUE  GAS PASSED THROUGH
                                THEM. VERTICAL HEIL MIST ELIMINATORS PRECEDE  A 500  FOOT  STACK.  A  MINIMUM
                                OF  201  BYPASS PROVIDES REH£AT. THE WATER LOOP IS  AN  OPEN "ODE.  AND THE
                                UNSTABILI7ED SLUDGE IS DISPOSED IN AN UNLINED POND.  START UP WAS
                                IN  NOVEMBER, 1979.
 SALT  RIVER  PROJECT
 CORONADO
 2
          350.0  MW  (GROSS)
          280.0  MW  (ESC)
 COAL
  1.00 XS  SUBBITUMINOUS
 LIMESTONE
 PULLMAN KELLOGG
 ENERGY  CONSUMPTION:  4.3X
 STATUS  2      STARTUP  7/80
                                SALT RIVER PROJECT'S CORONADO 2  IS  A  DRY  BOTTOM  PULVERIZED SUBEI TUMI NOUS
                                COAL (1.0X S. 83CO BTU/LB) FIRED BOILER  UNDER  CONSTRUCTION IN ST. JOHNS,
                                ARIZONA.  PULLMAN KELLOGG IS SUPPLYING  TWO LIMESTONE  HORIZONTAL WEIR SPRAY
                                TOWERS  WHICH WILL REMOVE P2.5X OF THI  502 FROM THE FLUE  GAS PASSED THROUGH
                                THEM. VERTICAL HEIL MIST ELIMINATORS  PRECEDE  A  500 FOOT  STACK. A MINIMUM
                                OF 20X  BYPASS WILL PROVIDE REHEAT.  THE  WATER  LOOP WILL BE OPEN, AND THE
                                UNSTA8IL1ZED SLUDGE WILL EE DISPOSED  IN  AN UNLINED POND. START UP IS EX-
                                PECTED  IN JULY, 1980.
 SALT  RIVER  PROJECT
 CORONADO
 3
 NEW        400.0 MU (GROSS)
           280.C MW (ESC)
 COAL
   .60 XS  SUBBITUMINOUS
 LIMESTONE
 VENDOR NOT  SELECTED
 ENERGY CONSUMPTION:  3.8X
 STATUS 6     STARTUP  6/87
                                CORONADO 3 IS A DRV BOTTOM PULVERIZED  SUBBITUMINOUS COAL (1.CX 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
                                2?X BYPASS REHEAT, AND THE SLUDGE  WILL PROBABLY BE PONDED. SCHEDULED OPER-
                                ATION DATE IS 1987.
 SAN  MIGUEL ELECTRIC COOP
 SAN  MIGUEL
 1
 NEW        400.0 MW (GROSS)
           400.0 MW (ESC)
 COAL
  1.70 XS  LIGNITE
 LIMESTONE
 BABCOCK S WILCOX
 ENERGY CONSUMPTION:  5.OX
 STATUS 2     STARTUP  9/80
                                SAN MIGUEL 1 OF THE  SAN MIGUEL  ELECTRIC  COOP IS A LIGNITE (1.7X S. 5000
                                BTU/LB) FIRED RADIANT BOILER  UNDER  CONSTRUCTION IN SAN MIGUEL, TEXAS. THE
                                EMISSION CONTROL  SYSTEM ON  THIS UNIT  WILL CONSIST OF A COLD SIDE ESP FOL-
                                LOWED BY FOUR BABCOCK AND WILCOX  96X  EFFICIENT LIMESTONE TCA MODULES.
                                CHEVRON MIST ELIMINATORS  WILL PRECEDE AN IN-LINE REHEATER AND  AN ACID
                                BRICK LINED STACK.  THE WATER  LOOP WILL BE CLOSED, AND THE DEwATERED  SLURRY
                                WILL BE MIXED WITH  FLYASH BY  RESEARCH COTTRELL AND DISPOSED IN AN OFF SITE
                                LANDFILL.
                                                  29

-------
 EPA  UTILITY FGO SURVEY: JANUARY - MARCH  1980
                                               SECTION 2
                                         STATUS OF  F6D SYSTEMS
 UNIT  IDENTIFICATION
                                                                   ABSTRACT
 SEMINOLE  ELECTRIC
 SEMINOLE
 1
 MEW        620.0 MW (GROSS)
           620.P MU (ESC)
 COAL
  2.75  ZS   SUBBITUMINOUS
 LIMESTONE
 PEABOOY  PROCESS SYSTEMS
 ENERGY CONSUMPTION: *****
 STATUS 3      STARTUP  3/83
                                SEMINOLE 1 OF SEMINOLE  ELECTRIC  IS  A  CO*L (2.75* Si 11,700 BTU/LB)  FIRED
                                UNIT PLANNED FOR LOCATION  IN  PALATKA,  FLORIDA. THE EMISSION CONTROL  SYSTEh.
                                WILL CONSIST OF  ESP'S AND  A  LIMESTONE  FGD SYSTEM. THE FGD SYSTEM WILL 6E
                                SUPPLIED BY PEABOOY  PROCESS  SYSTEM.  4TART UP TS EXPECTED IN MARCH OF
                                1983.
 SEMINOLE  ELECTRIC
 SEMINOLE
 2
 NEW        620.0 nw (GROSS)
           620.0 MW (ESC)
 COAL
 2.75  *S   SUBBITUMINOUS
 LIMESTONE
 PEABODY PROCESS SYSTEMS
 ENERGY  CONSUMPTION: *****
 STATUS  3      STARTUP  ?/85
                                SEMINOLE 2 OF SEMINOLE ELECTRIC  IS  A  COAL  (2.75* S, 11.7CO BTU/LB) FIREO
                                UNIT PLANNED FOR LOCATION  IN  PALATKA,  FLORIDA.  THE EMISSION CONTROL SYSTEM
                                WILL CONSIST OF ESP'S AND  A LIMESTONE  fGD  SYSTEM. THE FGD SYSTEM WILL BE
                                SUPPLIED BY PEABODV  SYSTEMS.  START  UP  IS  EXPECTED IN MARCH OF
                                1985.
SIKESTON BOARD  OF  MUNIC.  UTIL. THE SIKESTON BOARD OF MUNICIPAL  UTILITIES' SiKESTON 1 IS A PULVERIZED  COAL
                                (2 8* S, 11,3*C BTU/L8)  FIRED  BOILER  UNDER CONSTRUCTION IN SIKESTON, MIS-
                                SOURI. BABCOCK AND W1LCOX  IS  SUPPLYING AN EMISSION CONTROL SYSTEM  CONSIST-
                    (GROSS)      ING OF TWO ESP'S AND THREE  50* CAPACITY  LIMESTONE VENTURI FGD MODULES.  THE
                    (ESC)        CLEANED GAS WILL PASS THROUGH  CHEVRON MIST ELIMINATORS BEFORE EXITING  A
                                450 FOOT FRP LINED FLUE  (A  SECOND CARBON STEEL LINED  FLUE, USED  FOR  EMER-
                                GENCY BYPASS, IS ALSO IN  THE  STACK).  THE WATER LOOP WILL BE OPEN,  AND  THE
                                SLUDGE WILL BE PONDED. START  UP  IS SLATED FOR JANUARY, 19P1.
SIKESTON
1
NEW       235.0 MW
          235.0 MW
COAL
 2.80 *S
LIMESTONE
BABCOCK K WILCOX
ENERGY CONSUMPTION:
STATUS 2     STARTUP
                      1.6*
                       1/81
SOUTH CAROLINA  PUBLIC  SERVICE
iJINYAH
2
NEW       280.0  MW  (GROSS)
          UO.O  MU  (ESC)
COAL
 1.70 XS  BITUMINOUS
LIMESTONE
BABCOCK t WILCOX
ENERGY CONSUMPTION:  1.1*
STATUS 1      STARTUP   7/77
                                WINYAH  2 OF SOUTH CAROLINA PUBLIC SERVICE  IS  A  PULVERIZED BITUMINOUS COAL
                                (1.70*  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 69*  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
                                UNLINEO POND. THIS SYSTEM HAS BEEN OPERATIONAL  SINCE  JULY OF 1977.
SOUTH CAROLINA  PUBLIC  SERVICE
tflNVAH
S
1EU       280.0 MW  (GROSS)
          280.0 MM  (ESC)
COAL
 1.70 XS
LIMESTONE
BABCOCK I WILCOX
ENERGY CONSUMPTION:  2.1*
STATUS 2      STARTUP  5/80
                                WINVAH  3 IS A DRY BOTTOM BOILER  UNDER  CONSTRUCTION  BY SOUTH CAROLINA PUB-
                                LIC  SERVICE WHICH WILL BURN 1.7*  SULFUR  COAL  (11,500 BTU/LB) IN GEORGE-
                                TOWN,  SOUTH CAROLINA. AN ESP WILL PRECEDE  A BABCOCK AND WILCOX LIMESTONE
                                FGD  SYSTEM AND AN INDIRECT STEAM  REHEATER.  THE  WATER LOOP WILL BE CLOSED,
                                EXPECTED START UP DATE IS MAY, 1980.
SOUTH CAROLINA  PUBLIC  SERVICE
WINYAH
4
NEW       280.0 MU  (GROSS)
          280.0 MU  (ESC)
COAL
 1.70 *S  BITUMINOUS
LIMESTONE
UNERICAN AIR  FILTER
ENERGY CONSUMPTION:  2.1«
                                SOUTH  CAROLINA PUBLIC SERVICE'S WINYAH  4  IS  A  PLANNED BITUMINOUS COAL
                                (1.7*  S,  11,500 6TU/L6) FIREO UNIT TO BE  LOCATED  IN  GEORGETOWN, SOUTH
                                CAROLINA. TWO AMERICAN AIR FILTER LIMESTONE  SLURRY SPRAY TOWERS WILL
                                FOLLOU AN ESP. THE TEMPERATURE OF THE CLEANED  GAS WILL BE RAISED BY AN
                                INDIRECT  STEAM REHEATER. THE SYSTEM WILL  OPERATE  IN  A CLOSED WATER LOOP
                                MODE.  THE CONTRACT FOR THE FGD SYSTEH HAS BEEN AWARDED, AND START UP IS
                                EXPECTED  IN JULY, 1981.
STATUS 3
              STARTUP  7/81
                                                 30

-------
                                              EPA UTILITY FGD SURVEY:  JANUARY - MARCH 1980
                                              SECTION 2
                                        STATUS Of FGD SYSTEMS
JNIT IDENTIFICATION
                                                                   ABSTRACT
SOUTH MISSISSIPPI FLEC  PWR
R.D. MORROW
1
NEW       200.P »U  (GROSS)
          124.0 MW  (ESC)
COAL
 1.30 XS  BITUMINOUS
LIMESTONE
RILE* STOKER/ENVIRONEERING
ENERGY CONSUMPTION:  5.5*
STATUS 1     STARTUP   8/78
                                R.D.  MORROW  1  OF
                                S,  12,000 BTU/L8
                                TROL  SYSTEM  FOR
                                STONE VENTRI-ROD
                                THE  CLEANED  GAS
                                JOINED  BY A  3SX
                                STACK SHARED BY
                                FLUE).  THE WATER
                                HAULED  61 TRUCK
                                SINCE AUGUST OF
 SOUTHERN MISSISSIPPI  ELECTRIC  IS  A  PULVERIZED COAL (1.31
) FIRED UNIT IN KATT1SSUKG,  MISSISSIPPI.  THE EMISSION CON-
THIS UNIT CONSISTS OF  A  HOT  SIDE  ESP FOLLOWED BY A LI*E-
 ABSORBER SUPPLIED BY  R1LEY  STOKER/ENVIRONEERING. AFTER
PASSES THROUGH A VERTICAL  CHEVRON  MIST ELIMINATOR, IT IS
BYPASS REHEAT BEFORE  IT  is DISCHARGED THROUGH A *r8 FOOT
UNITS 1 AND 2 (EACH  UNIT HAS  ITS  OwM AClD BRICK LINED
 LOOP IS CLOSED, AND  THE FLYASH  STABILIZED SLUDGE IS
TO AN OfF SITE LANDFILL. THE  SYSTEM  HAS  BEEN OPERATIONAL
1978.
SOUTH MISSISSIPPI  ELEC  PWR
R.D. MORROW
2
NEW       200.0  l»W  (GROSS)
          124.f  »W  (ESC)
COAL
 1.30 XS  BITUMINOUS
LIMESTONE
RILEV STOKER/ENVIRONEEB1NG
ENERGY  CONSUMPTION:  5.5*
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  HATT1S6URG,  MISSISSIPPI. THE EMISSION  CON-
                                TPOL  SYSTEM FOR THIS UNIT CONSISTS  OF  A  HOT  SIDE ESP FOLLOWED BY  • LIME-
                                STONE VlENTRl-BOD ABSORBER SUPPLIED  BY  R1LEY  STOK ER /E NVI R ONEER I NG . AFTER
                                THE CLEANED GAS PASSES THROUGH A  VERTICAL  CHEVRON MIST ELIMINATOR, IT  is
                                JOINED BY A 3?* BYPASS R{H£AT BEFORE  IT  IS DISCHARGED THROUGH A  4r8  FOOT
                                STACK SHARED BY UNITS 1 AND 2 (EACH  UNIT HAS ITS OhN 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 OF 1979.
SOUTHERN ILLINOIS POWER  COOP
1APJON
4
NEW       184.0 MW  (GROSS)
          184.f MW  (ESC>
COAL/REFUS
 3.50 XS
LIMESTONE
3ABCOCK 8 WILCOX
ENERGY CONSUMPTION:  *«««X
STATUS 1      STARTUP  5/79
                                UNIT 4 AT SOUTHERN  ILLINOIS  POWER COOP'S FARlON STATION  IN  MARION,  ILLI-
                                NOIS IS A CYCLONE  FIRED  COAL (3.OX S, 90CO BTU/LB) BOILER WHICH  IS  SERVED
                                BY A 89.4* EFFICIENT  (DESI6N)  LIMESTONE FGD SYSTEM SUPPLIED  BY 8APCOCK AND
                                ylLCOX. TWO SPRAY  TOWERS  AND A BRICK LINED STACK ARE  DOWNSTREAM  OF  AN ESP
                                IN THIS SYSTEM.  THE WATER LOOP IS OPEN, AND THE FLYASH STABILIZED SLUDGE
                                IS DEWATERED  AND  LANDFILLED. TH£  SYSTEM BECAME OPERATIONAL  DURING MAY OF
                                1979.
SOUTHERN  ILLINOIS  POWER COOP
HARION
5
NEW        300.0 MW (GROSS)
           300.C MW (ESC)
COAL
 3.00 *S
PROCESS  NOT  SELECTED
tfENOOR  NOT SELECTED
ENERGY  CONSUMPTION! ••***
STATUS  6      STARTUP  0/86
                                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
                                YF.T DECIDED ON AN FGD PROCESS  AS IT 1$ WAITING FOR THE  FINALIZATION OF
                                THE S02 REGULATIONS  THE  UNIT WILL HAVE TO MEET. START UP  IS  EXPECTED  IN
                                1986.
 SOUTHERN INDIANA GAS & ELEC
 A.8.  BROWN
 1
 NEW        265.0 «M (GROSS)
           265.0 MU (ESC)
 COAL
 3.35 XS  BITUMINOUS
 DUAL  ALKALI
 FMC
 ENERGY CONSUMPTION:   .8X
 STATUS 1     STARTUP  4/79
                                SOUTHERN INDIANA  GAS  AND  ELECTRIC'S A.B.BROWN  1  IS  A  DRY  BOTTOM PULVERIZED
                                COAL (4.SX S.  13,010  BTU/L6) FIRED UNIT IN WEST  FRANKLIN,  INDIANA. FMC
                                SUPPLIED A DUAL ALKALI  FGP  SYSTEM DESIGNED TO  REMOVE  85X  OF  THE FLUE GAS
                                S02. THE UNIT  CONSISTS  OF TWO THREE STAGE DISC CONTACTORS.  A COLD SIDE ESP
                                PROVIDES PRIMARY  PARTICULATE CONTROL, AND ONE  CHEVRON MIST  ELIMINATOR/MOD-
                                ULE PRECEDES  A 498  FOOT ACID BRICK LINED STACK.  THE  SYSTEM  PRODUCES A
                                FILTER CAKE WASTE PRODUCT WHICH IS DISPOSED IN AN ON  SITE  LANDFILL. THE
                                WATER LOOP CAN BE EITHER  OPEN OR CLOSED. THE SYSTEM  HAS BEEN OPERATIONAL
                                SINCE HARCH OF 1979.
 SOUTHWESTERN ELECTRIC POWER
 HENRY  W.  PIRKEY
 1
 NEW        720.0 MU (GROSS)
           720.0 MW (ESC)
 COAL
   .80  XS   LIGNITE
 LIMESTONE
 AIR  CORRECTION DIVISION, UOP
 ENERGY CONSUMPTION: ****X
 STATUS 3      STARTUP 12/84
                                HENRY W. PERKEY  1  IS  A WET BOTTOM LI6N1TE  (C.PX  S,  6300  eTU/LB) FIRED UNIT
                                PLANNED BY  SOUTHWESTERN ELECTRIC POWER FOR LOCATION  IN HALLSVILLE, TEXAS.
                                A CONTRACT  HAS BEEN AWARDED TO THE AIR CORRECTION  DIVISION OF UOP FOR FOUR
                                LIMESTONE SPRAY  TOWERS (99«X EFFICIENCY). HIST 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.
                                                  31

-------
EPA  UTILITY  FGD  SURVEY:  JANUARY - MARCH 1980
                                              SECTION 2
                                        STATUS OF FGD SYSTEMS
UNIT  IDENTIFICATION
                                                                   ABSTRACT
SPRINGFIELD  CITY  UTILITIES
SOUTHWEST
1
NEW       194.0 MU  (GROSS>
          194.0 MW  
COAL
 3.50 XS  BITUMINOUS
LIMESTONE
MR CORRECTION DIVISION,  UOP
ENERGY CONSUMPTION:   4.6X
STATUS 1      STARTUP   4/77
    SPRINGFIELD CITY UTILITIES*  SOUTHWEST  1  IS A PULVERIZED BITUMINOUS COAL
    (?.5X S, 12.50C BTU/LP)  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 8GX OF  THE
    FLUE GAS S02. ONE  CHEVRON/MODULE  LEADS TO A 384 FOOT CEILCOTE LINED  STACK.
    THE DRY FLYASH STABILIZED  SLUDGE  IS  OEWATERED BY A ROTARY DRUM VACUUM  AND
    TRUCKED TO A LANDFILL. THE SYSTEM HAS  BEEN OPERATIONAL SINCE APRIL,  1977.
SPRINGFIELD  WATER,  LIGHT &
DALLMAN
I
HEW       205.0  MU  (GROSS)
          205.0  MU  (ESC)
COAL
 3.30 XS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION:  5.91
STATUS 2      STARTUP  11/80
PWR DALLMAN 3 OF SPRINGFIELD  WATER,  LIGHT,  AND POWER IS A PULVERIZED  COAL
    (3.3X S, lOtSOO BTU/LB)  FIRED  BOILER  UNDER CONSTRUCTION IN SPRINGFIELD,
    ILLINOIS. RESEARCH  COTTRELL  IS SUPPLYING A LIMESTONE FGD SYSTEM DESIGNED
    TO REMOVE 95X OF  THE  S02  FROM  850,000 ACFM OF BOILER FLUE G«S. 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 BCEN FINALIZED, BUT THE UTILITY  IS  CON-
    SIDERING EITHER PONDING  OR LANDFILL.  FGD OPERATIONS SHOULD BEGIN  IN
    NOVEMBER, 198P.
ST. JOE ZINC
G.F. WEATON
1
RETROFIT   60.0  MW  (GROSS)
           60.0  MW  (ESC)
COAL
 2.00 XS  BITUMINOUS
CITRATE
BUREAU OF MINES
ENERGY CONSUMPTION:  ****X
STATUS 1      STARTUP  11/79
    G.F. WEATON 1, OWNED  61  ST.  JOE  ZINC,  IS  A COAL (3.CX 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 TPAIN
    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 SO 2 REMOVAL EFFICIEN-
    CY WILL BE OVER 90X.  THE  WATER  LOOP IS CLOSED LOOP MODE. THE FGD SYSTEM
    COMMENCED OPERATION  IN NOVEMBER  OF 1979.
TAMPA ELECTRIC
BIG BEND
t
*EU       475.C  MW  (GROSS)
          475.0  MU  (ESC)
COAL
 2.50 XS
PROCESS NOT  SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  ****X
STATUS 5      STARTUP   3/85
    UNIT 4 AT TAMPA ELECTRIC'S  BIG  BEND  STATION IS A PLANNED DRY BOTTOM  PUL-
    VERIZED COAL  (2.5X  S,  10,300  BTU/LB)  FIRED UNIT TO BE LOCATED IN TAMPA,
    FLORIDA.  THE FGD PROCESS HAS NOT YET BEEN CHOSEN.  AN ESP WILL PROVIDE
    PRIMARY PARTICULATE  CONTROL.  THE FGD SYSTEM, WHICH WILL REMOVE 9"X  OF  THE
    FLUE GAS S02, WILL  INCLUDE  AN INDIRECT HOT AIR REHEATER LEADING TO  A  490
    FOOT CONCRETE LINED  STACK.
TENNESSEE  VALLEY  AUTHORITY
JOHNSONVILLE
1-10
RETROFIT 1450.0 MU  (GROSS)
           600.0 MU  (ESC)
COAL
 3.10 XS
MAGNESIUM  OXIDE
RILEY ENVIRONEERING
ENERGY CONSUMPTION: ««**X
STATUS 3     STARTUP 12/81
    UNITS 1 THROUGH  10 AT JOHNSONVILLE  STATION OF TVA ARE COAL  (2.6X  5,  10,750
    BTU/LB) FIRED BOILERS LOCATED  IN  NEU  JOHNSONVILLE, TENNESSEE. UNITED  EN-
    GINEERS HAS BEEN AWARDED  A  CONTRACT TO PROVIDE ENGINEERING  ASSISTANCE  TO
    TVA FOR A 90Z EFFICIENT MAGNESIUM OXIDE FGD SYSTEM TO BE RETROFITTED  ON
    THESE UNITS. SULFURIC ACID  WILL BE  PRODUCED AS A BYPRODUCT  FROM THIS  SYS-
    TEM, UHICH UILL  FEATURE FOUR  VENTURI  SCRUBBER/ABSORBER TRAINS (ONE  SPARE),
    60X BYPASS REHEAT, AND A  600  FOOT STACK.  START UP IS EXPECTED IN  1981.
TENNESSEE VALLEY AUTHORITY
PARADISE
1
RETROFIT  704.0 MU  (GROSS)
          704.0 MU  (ESC)
COAL
 4.20 XS
LIMESTONE
CHEHICO
ENERGY CONSUMPTION: *«**x
STATUS 2     STARTUP   3/82
    PARADISE 1 OF TVA IS  A 4.2X  SULFUR  COAL FIRED UNIT LOCATED IN PARADISE,
    KENTUCKY. A CONTRACT  HAS BEEN  AWARDED  TO CHEMICO FOR AN 84.2X EFFICIENT
    LIMESTONE FGD SYSTEM  TO BE RETROFITT&D  ON THIS BOILER. SIX VENTURI  SCRUB-
    BERS AND VENTURI ABSORBER  TRAINS  WILL  FOLLOW AN ESP. INLET FLUE GAS WILL
    BE USED TO HEAT WATER, UHICH  IN  TURN UILL BE USED TO REHEAT THE OUTLET
    FLUE GAS. FORCED OXIDATION UILL  BE  USED IN ONE MODULE TO CONTROL  SCALING
    THROUGHOUT THE SYSTEM. THE UTILITY  EXPECTS TO GET AN 8CX SOLIDS LANDFILL-
    ABLE GRADE SLUDGE. OPERATIONS  SHOULD START IN MARCH, 1982.

-------
                                              EPA UTILITY  FGD  SURVEY:  JANUARY  - MARCH 1980
                                              SECTION i
                                        STATUS Of FGD SYSTEMS
JNIT IDENTIFICATION
                                                                   ABSTRACT
TENNESSEE VALLEY AUTHORITY
PARADISE
2
RETROFIT  70*.o MW  (GROSS)
          704.0 MW  (ESC)
COAL
 <..21 XS
LIMESTONE
CHEMICO
ENERGY CONSUMPTION: *»*«X
STATUS 2     STARTUP  6/82
PARADISE ? OF TVA  IS  A  4.2X  SULFUR COAL FIRED UNIT LOCATED  IN  PAR*D1SE,
KENTUCKY. A  CONTRACT  HAS  BEEN AWARDED TO CHEMICO FOR  AN  t4.2X  EFFICIENT
LIMESTONE FGD SYSTEM  TO BE  RETROFITT6D ON THIS BOILER. SIX  VENTURI  SCRUB-
BERS AND VENTURI ABSORBER TRAINS WILL FOLLOW AN ESP.  INLET  FLUE  GAS  WILL
BE USED TO HEAT  WATER,  WHICH IN TURN WILL BE USED  TO  REHEAT  THE  OUTLET
FLUE GAS. FORCED OXIDATION  HILL BE USED IN CNF MODULE TO  CONTROL SCALING
THROUGHOUT THE SYSTEM.  THE  UTILITY EXPECTS TO GET  AN  PCX  SOLIDS  LANDFILL-
ABLE GRADE SLUDGE.  OPERATIONS SHOULD START IN JUNE,  1982.
TENNESSEE VALLEY  AUTHORITY
SHAWNEE
13A
RETROFIT   10.0 My  (GROSS)
           10.0 MW  
COAL
 2.90  XS  BITUMINOUS
LIME/LIMESTONE
AIR  CORRECTION  DIVISION,  UOP
ENERGY  CONSUMPTION: ****X
STATUS  1      STARTUP   4/72
SHAWNEE  10 OF  TVA  IS  A 2.9J SULFUR BITUMINOUS  COAL  FIRED  BOILER  LOCATED IN
PADUCAH, KENTUCKY.  MODULE 10A IS A RETROFIT PROTOTYPE  LIME/LIMESTONE  TCA
SYSTEM SUPPLIED  BY  THE AIR CORRECTION DIVISION, UOP.  THE  SYSTEM  UTILIZES
A CHEVRON MIST ELIMINATOR AND A DIRECT COMBUSTION REHEATER,  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  FOANCISCO
IS THE MAJOR  CONTRACTOR, TEST DIRECTOR, AND REPORT  WRITER.  THE  SYSTEM HAS
BEEN OPERATIONAL SINCE APRIL, 1972.
TENNESSEE  VALLEY  AUTHORITY
SHAWNEE
1DB
RETROFIT    10.0  MW  IGROSS)
            10.0  MW  
-------
 EPA  UTILITY FGD SURVEY: JANUARY  - MARCH  198C
                                               SECTION 2
                                         STATUS OF FGO SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 TEXAS  POWER  *  LIGHT
 SANDOW
 I
 NEW        545.0 My (GROSS)
           382.0 MW (ESC)
 COAL
  1.60  XS   LIGNITE
 LIMESTONE
 COMBUSTION ENGINEERING
 ENERGY CONSUMPTION: *«**X
 STATUS 2      STARTUP  7/80
                   SANDOW  t  IS  A PULVERIZED 1.6X SULFUR  LIGNITE  FJPEO BOILER OF TEXA? POWER
                   AND  LIGHT UNDFR CONSTRUCTION IN ROCKOALE,  TEX«S.  COMBUSTION ENGINFEMNG  IS
                   SUPPLYING THREE LIMESTONE SPRAY TOWERS  FOF  THIS UNIT. A COLO SIDE ESP WILL
                   PROVIDE  PRIMARY PARTICULATE CONTROL.  A  3 OX  BYPASS  REHEAT WILL 6E USED, AND
                   THE  OVERALL  S02 REMOVAL EFFICIENCY  WILL  BE  75?. THE SYSTEM WILL OPIRATE  IN
                   A  CLOSED  WATER LOOP, AND THE SLUDGE WILL BE  PONDED. START UP IS EXPECTED
                   IN JULY,  198C.
TEXAS  POWER  8  LIGHT
TrflN  OAKS
1
MEW        750.0 MW (GROSS)
           750.C MW (ESC)
COAL
   .7H  XS   LIGNITE
LIMESTONE
CHEMICO
ENERGY CONSUMPTION:
                   TWIN OAKS  1  IS  A  0.75* SULFUR LIGNITE  FlRED  BOlLE'  PLANNED BY 1EX«S POWER
                   AND LIGHT  AND ALCOA FOR LOCATION IN BREMOND,  TEXAS. A CONTRACT HA? pEEN
                   AWARDED  TO CHEMICO FOP A LIMESTON? FGO  SYSTEM  ON  THIS UNIT. START UP IS
                   EXPECTED  IN  AUGUST OF 1984.
 STATUS  3
       *** *X
STARTUP  9/84
TEXAS  POWER  £  LIGHT
TuIN  OAKS
2
NEW        75C.n *W (GROSS)
           750.P MW (ESC)
COAL
   .7"  XS   LIGNITE
LIMESTONE
CHEMICO
ENERGY  CONSUMPTION: ***«X
STATUS  3      STARTUP  8>85
                   TWIN OAKS  2  IS  A  D.75X SULFUR LIGNITt flRfD  BOILER  PLANNED BY TEXAS POhER
                   AND LIGHT  AND ALCOA FOR LOCATION IN BREMONO,  TEXAS. A CONTRACT HAS REEN
                   AWARDED  TO CHEMICO FOR A LIMESTONE FGD SYSTEM  ON  THIS UNIT. START UP IS
                   EXPECTED  IN  AUGUST OF 1985.
TEXAS  UTILITIES
FOREST GROVE
1
NEW        750.0  "W (GROSS)
           750.C  MW (ESC)
COAL
   .80  XS   LIGNITE
PROCESS NOT  SELECTED
VENDOR  NOT  SELECTED
ENERGY  CONSUMPTlONr ***«X
STATUS  5      STARTUP   0/81
                  TEXAS UTILITIES  IS  PLANNING A LIGNITt (C.8X  S,  7000  BTU/LB) FIRED BOILER,
                  FOREST GROVE  1,  WHICH WILL BE LOCATED IN  ATHENS,  TEXAS.  THE UTILITY IS
                  PRESENTLY  REOUEST1NG BIDS ON AN FGD SYSTEM FOR  THIS  UNIT. TWO ESP'S WILL
                  PROVIDE  PRIMARY  PARTICULATE CONTROL, AND  NO  STACK  GAS  REHEAT IS PLANNED.
                  START UP  IS  EXPECTED IN LATE 1981.
TEXAS UTILITIES
1ARTIN  LAKE
1
NEW        793.0  MW  (GROSS)
           595.0  *W  (ESC)
COAL
  .90 XS   LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY  CONSUMPTION:  1.3X
STATUS  1     STARTUP   4/77
                  TEXAS UTILITIES'  MARTIN LAKE 1 IS A LIGNITE  (n.9X  S,  7380 BTU/LB) FIRED
                  BOILER  IN TATUM,  TEXAS. THIS UNIT IS EQUIPPED  WITH AN EMISSION CONTROL
                  SYSTEM  WHICH  INCLUDES A COLD SIDE ESP AND A  LIMESTONE FGD SYSTEM, BOTH
                  SUPPLIED BY RESEARCH  COTTRELL. THE FGD SYSTEM  CONSISTS OF SIX PACKED SPRAY
                  TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER  FLUE  GAS. THE REMAIN-
                  ING FLUE GAS  IS BYPASSED FOR REHEAT. THE TOTAL  DESIGN S02 REMOVAL EFFICI-
                  ENCY IS 7C.5X.  TbO  CHEVRONS/HODULE PROVIDE MIST  ELIMINATION. THE FLUE GAS
                  CLEANING WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN  ON-SITE LANDFILL.
                  THE SYSTEM OPERATES IN A CLOSED WATER LOOP.  INITIAL  SYSTEM OPERATIONS TOOK
                  PLACE IN APRIL, 1977.
TEXAS UTILITIES
HARTIN LAKE
2
NEW       793.0  MW  (GROSS)
          595.0  MW  (ESC)
COAL
  .90 XS  LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION:  1.3X
STATUS 1
             STARTUP   5/78
                  TEXAS UTILITIES*  MARTIN  LAKE 2 IS A LIGNITE  (0.9X  S,  738C BTU/LB) FIRED
                  BOILER IN TATUM,  TEXAS.  THIS UNIT IS EQUIPPED  WITH AN  EMISSION CONTROL
                  SYSTEM WHICH  INCLUDES A  COLD SIDE ESP AND A  LIMESTONE  FGD SYSTEM, BOTH
                  SUPPLIED BY RESEARCH  COTTRELL. THf FGD SYSTEM  CONSISTS  OF SIX PACKED SPRAY
                  TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL POILER  FLUE  GAS. THE REMAIN-
                  ING FLUE GAS  IS BYPASSED F0» REHEAT. THE TOTAL  DESIGN  502 REMOVAL EFFICI-
                  ENCY IS 70.5X. TWO  CHEVRONS/MODULE PROVIDE MIST ELIMINATION.  THE FLUE GAS
                  CLEANING WASTES ARE  FLYASH STABILIZED AND DISPOSED IN  AN  ON-SITE LANDFILL.
                  THE SYSTEM OPERATES  IN A CLOSED WATER LOOP.  INITIAL  SYSTEM OPERATIONS TOOK
                  PLACE IN MAY,  1978.
                                                  34

-------
                                              EPA UTILITY  FGD  SURVEY: JANUARY - MARCH 1980
                                              SECTION 2
                                        STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                   ABSTRA CT
TEXAS UTILITIES
1ARTIN L'K E
3
NEW       793.r *W  (GROSS)
          595.T MW  (ESC>
COAL
  .9" *S  LIGNITE
LIMESTONE
RESEARCH COTTRELI
ENERGY CONSUMPTION
STATUS 1
        1.3X
STARTUP  2/79
TEXAS UTILITIES' MARTIN  LAKE 3 IS A LIGNITE (^.91  S,  738C  BTU/LB)  FIRED
BOILER IN TATUM, TEXAS.  THIS UNIT IS EOUIPPED WITH AN  EMISSION  CONTROL
SYSTEM WHICH  INCLUDES  A  COLO SIDE ESP AND A LIMESTONE  FGD  SYSTEM,  BOTH
SUPPLIED BY RESEARCH  COTTRELL. THE FGO SYSTEM CONSISTS  OF  SIX  PACKED SPRAY
TOWER ABSORBERS WHICH  TREAT 75X OF THE TOTAL BOILER  FLUE  GAS.  THE  REMAIN-
ING FLUE GAS  IS BYPASSED FOR REHEAT. THE TQTAL DESIGN  SOi  REMOVAL  EFFICI-
ENCY IS 70.51. TWO  CHEVRONS/MODULE PROVIDE MIST ELIMINATION.  THE FLUE GAS
CLEANING WASTES ARE  FLYASH STABILIZED AND DISPOSED IN  AN  ON-SITE LANDFILL.
THE SYSTEM OPERATES  IN A CLOSED WATER LOOP. INITIAL  SYSTEM OPERATIONS TOOK
PLACE IN FEBRUARY,  19?9.
TEXAS UTILITIES
1ARTIN LAKE
4
NEW       750.C1  MW  (GROSS)
          750.0  MU  IESC)
COAL
  .9" IS  LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: ***«X
STATUS 3      STARTUP  0/85
                  MARTIN  LAKE  4 OF TEXAS UTILITIES  IS  A  LIGNITE < ? • 9* Si 7380 BTU'LP>  FIRED
                  BOILER  UNDER  CONSTRUCTION IN TATUM,  TEXAS.  A  CONTRACT FOR A LIMESTONE  FGD
                  SYSTEM  FOR  THIS UNIT HAS BEEN AWARDED  TO  RESEARCH  COTTRELL. CONSTRUCTION
                  HAS  NOT  YET  BEGUN ON THE FGD SYSTEM. FCD  START UP  IS EXPECTED IN  1985  OR
                  1986.
TEXAS  UTILITIES
«IILL  CREEK
1
NEW        750.C  MW  (GROSS)
           750.0  MW  (ESC)
COAL
.....  XS   LIGNITE
PROCESS NOT  SELECTED
VENDOR  NOT  SELECTED
ENERGY  CONSUMPTION: *«**X
STATUS  6      STARTUP   0/85
                   MILL  CREEK 1 OF TEXAS UTILITIES  IS  A  PLANNED LIGNITE  FIRED  UNIT  TC  PE
                   LOCATED  IN HENDERSON, TEXAS.  THE  UTILITY HILL INCLUDE AN  FGD  SYSTEM ON
                   THIS  UNIT. BUT NO DECISIONS HAVE  PEEN MADE AS TO THE  PROCESS  TYPE OR
                   VENDOR.  ESp's WILL PROVIDE PRIMARY  PARTICULATE CONTROL. START  UP  IS
                   EXPECTED IN 1965.
 TEXAS  UTILITIES
 
-------
 EPA UTILITY FGD SURVEY: JANUARY  -  MARCH  1980
                                               SECTION 2
                                         STATUS  OF FGO SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 TUCSON ELECTRIC POWER
 SPRINGERVILLE
 2
 NEW        370.0 MW <6ROSSJ
           370.0 MW (ESC)
 COAL
 •**«* XS  SUBBITUMINOUS
 LIME/SPRAY DRYING
 JOY  MFG/NIRO ATOMIZER
 ENERGY CONSUMPTION: ****X
 STATUS I     STARTUP  1/87
                                 TUCSON  GAS  AND ELECTRIC WILL BE BUILDING  TWO  NEW  UNITS  IN SPRINGE"vILLE,
                                 COLORADO.  SPRINGERVILLE 1 AND 2.  TH£ UNITS WILL  F1BE PULVERIZED SUB8ITU-
                                 MINOUS  COAL (CI.53-0.69X S AND 85CO-89CC ETU/LB).   A  CONTRACT  HAS BEEN
                                 AWARDED  TO  JOY MANUfACTUR1NG/MIR0 ATOMIZER FOR  A  LIME/SPRAY  DRYING FGD
                                 SYSTEM  TO  CONTROL PARTICIPATE MATTER AND  S02  EMISSIONS.   THE  SYSTEM WILL
                                 BE  DESIGNED TO ACCOMOOATE A REHEATER (SHOULD  ONE  BE  REQUIRED) AND WILL
                                 OPERATE  IN  A CLOSED WATER LOOP.  CLEANED  FLUE GAS  WILL  EXIT  THf  SYSTEM
                                 VIA  A 500  FOOT CONCRETE STACK.  OPERATIONS ARE  SCHEDULED  TO  BEGIN IN 1987
 JNITEO  POWER ASSOCIATION
 STANTON
 2
 MEW         SO.O MW (GROSS)
            50.C1 MW (ESC)
 COAL
   .77 XS  LIGNITE
 LIME/SPRAY DRYING
 KOMLINE 8  SANDERSON
 ENERGY  CONSUMPTION: ****X
 STATUS  3     STARTUP  1/82
                                 THE  UNITED  POWER  ASSOCIATION HAS PLANS FOR A PULVERIZED  COAL  (C.77» 5,
                                 7000  BTU/LB)  FIRED UNIT, STANTON 2, TO BE LOCATED  IN  STANTON,  NORTH
                                 DAKOTA.   A  CONTRACT HAS BEEN AWARDED TO KOMLINE AND  SANDERSON  FOR  A
                                 LIME  SPRAY  TOWER.   A FABRIC FILTER SUPPLIED BY RESEARCH  COTTRELL  WILL  bf.
                                 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 JANUARY,  1982.
 UTAH  POWER  & LIGHT
 HUNTER
 1
 NEW        400.0 MW (GROSS)
           360.f MW (ESC)
 COAL
   .55 XS   BITUMINOUS
 LIME
 CHEMICO
 ENERGY  CONSUMPTION: ***»X
 STATUS  1      STARTUP  S/79
                                HUNTER  1  OF  UTAH  POWER AND LIGHT IS A COAL (0.55X  S,  12.JCO  BTU/LP)  FIKEO
                                UNIT  IN  CASTLEDALE,  UTAH. CHEMICO SUPPLIED A PEBBLE LIME  WET  ScRUFBlNG
                                SYSTEM  WHICH  BECAME  OPERATIONAL IN "AY, 1979. THE  SCRUBBING  SYSTE"  IS  DE-
                                SIGNED  TO  OPERATE IN AN OPEN WATER LOOP WITH AN SO? REMOVAL  EFFICIENCY OF
                                8PX.  PRIMARY  PARTICULATE  CONTROL is PROVIDED BY AN UPSTREAM  ESP,  «ND  STACK
                                GAS REHEAT  IS  PROVIDED BY BYPASS. THE SLUDGE IS FL»ASH STABILIZED AND  DIS-
                                POSED ON-SITE.
UTAH  POWER  1  LIGHT
HUNTER
2
NEW       400.0 MW (GROSS)
          360.0 MW (ESC)
COAL
   .55 XS
LIME
CHEMICO
ENERGY CONSUMPTION:
STATUS  2
                     *** *X
              STARTUP  6/80
                                UTAH POWER  AND  LIGHT'S  HUNTER  2 IS A COAL <0.55* S, 12,50? BTU/LB)  FIRED
                                UNIT UNDER  CONSTRUCTION IN  CASTLEDALE, UTAH. CHEMICO IS SUPPLYING  A  PEBBLE
                                LIME WET SCRUBBING  SYSTEM  DESIGNED TO OPERATE IN AN OPEN  WATER  LOOP  WITH
                                AN S02 REMOVAL  EFFICIENCY  OF  BOX. AN UPSTREAM ESP PROVIDES PRIMARY  PARTIC-
                                ULATE CONTROL,  AND  A  BYPASS  SYSTEM PROVIDES STACK GAS REHEAT. THE  SLUDGE
                                WILL BE FLYASH  STABILIZED  AND  DISPOSED ON-SITF. START UP  OF BOTH THE  BOIL-
                                ER AND FGD  SYSTEM  IS  EXPECTED  IN  JUNE, 19EO.
UTAH POWER  t  LIGHT
HUNTER
3
NEW       400.0  1W  (GROSS)
          400.0  MW  (ESC)
COAL
  .55 XS  BITUMINOUS
LIMESTONE
CHEMICO
ENERGY CONSUMPTION: **««x
STATUS 3      STARTUP   0/83
                                UTAH POWER AND LIGHT  HAS  PLANS  FOR  TyO 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 FOR EMISSION CONTROL.  THE PULVERIZED
                                COAL FIRED UNITS  (0.55X  S,  12,500 BTu/LB) ARE TO BEGIN OPERATIONS  IN  1983
                                AND 1985, RESPECTIVELY.
JTAH POWER
HUNTER
4
NEW
           t LIGHT
          400.0  MU  (GROSS)
          400.0  MW  (ESC)
COAL
  .55 XS  BITUMINOUS
LIMESTONE
CHEMICO
ENERGY CONSUMPTION:
STATUS 3      STARTUP
                     >*•»%
                       0/85
UTAH POWER AND LIGHT HAS  PLANS  FOR  TyO NEW UNITS, HUNTER 3 AND 4, TO  BE
CONSTRUCTED IN CASTLEOALE,  UTAH.   A CONTRACT HAS BEEN AWARDED TO CHEMICO
FOR A LIMF, NONREGENERABLE  FGD  UNIT FOR EMISSION CONTROL.  THE PULVERIZED
COAL FIRED UNITS  (0.55X  S,  12,500 BTU/LB) ARE TO BEGIN OPERATIONS IN  1983
AND 1985, RESPECTIVELY.
                                                 36

-------
                                                 EPA UTILITY  FGO S U & V E Y :  JANUARY  -  P A (, C H

                                                 S ? C T I c r,  i
                                          STATUS  CF F G D  S Y S T £. |» $
      1 DENT I F 1C « T! ON                                                   A P S T K* C T
JTAH  POkFR  R LIGHT               hl'ST INbTC*.1  1  " F  UTAH  POED  ]S A  T J H.G E KT I * L L Y  F I P E D PULVFR12EO  COAL  ( 9 . 5 5 X
HJNTINGTCN                        b,  1i,5": RTU/Lr) P C I L t K  IN FSICt,  UTAH.  A COLD  SlEE F£P TfifATS 1 , 7 <. 2 , C C C
1                                  AfFI-OF  FLUEfA^AND  ISFOLLCbEt)OiACHE''ICOLIF'EFGDS»STEMCCNcISTI\G
NEW        41":.? WW  (GROSS)      Of  FOUfc  SPRAY TC»ERS  (cOX DESIGN  EFFICIENCY).  ONE  FOUC PASS  C H E V R "K /« PC U L E
           36*." VH  (ESC)        F»OVlCiS  "JST ELIVINA~]ON,  AND  A  CC*eiN«TICN  CF  A  STEAr TUBE  ANt  '•'.-Z~'l
COAL                              n^PASS ttHEATJPS HOOST  THr  GAS  TcwpcfijTucf 45-5"  DEG F. THE  SYSTE*  CP^f-
  .55  *S   BITUMINOUS             ATES  IN  A CLCCED wATES  LOOP, AND  THF  FLYASH  STABILIZED SLUDGE  IS  T';UCKcD
Li»t                              TC  A^ ON-?ITE L«NDF;LL.  THE SYSTE*  INCLUDES  A  t~c  FOOT ACIC  BOICK LI^EC
CHfMICO                           ST'CK, »SD  HAS  PtEN  CPcfiATiONAL  SINCE  «»«Y OF  1 9 ? 6 .
ENERGY  CONSUMPTION:  1.6*
STATUS  1      STARTUP   5/78

-------
 EP«  UTILITY F&D SURVEY:  JANUARY - MARCH  198C

                                              SECTION 7
                DF.STGN  AND  PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC  FGD  5TSTFMS
COMPANY  NAM?
PLANT  NAME
UNIT NUMBER
C ITY
STATE
GROSS  UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING C'PACITY W/FGD -  Mb
EQUIVALENT SCRUPBFD CAPACITY - »W

•• FUEL  DATA
    FUEL TYPE
    FUEL GR«DE
    AVERAGE HEAT  CONTENT - J/G
    AVERAGE ASH  CONTENT - X
    AVERAGE MOISTURE  CONTENT - x
    AVERAGE SULFUR  CONTENT - X
    AVERAGE CHLORIDE  CONTENT - 5!

•• FGD SYSTEM
    GENERAL PROCESS TYPE
    PROCESS TYPF
    SYSTEM SUPPLIER
    NEW/RETRQFIT
    ENERGY CONSUMPTION - X
    INITIAL START-UP  DATE
    COMMERCIAL START-UP DATE
    S02  DESIGN 8E»OVAL EFFICIENCY - X
    PARTICULATE  DESIGN REMOVAL EFFICIENCY  - X
    APSORBER  SPAR*  CAPACITY INDEX - X
    ABSORBER  SPARE  COMPONENTS INDEX

•* WATER LOOP
    TYPE
    FRESH MAKE-UP WATER - LITER/S
                                                   ALAMMA ELECTRIC COOP
                                                   TOMfclGBEE
                                                   2
                                                   LER&Y
                                                   ALA(- OMA
                                                     255.:
                                                     2?;.3
                                                     1 7C.O
                                                                  ( 115CC PTU/LP)
                                COAL
                                BITUMINOUS
                                 26749.
                                   14.DC
                                    7.?C
                                    1.15
                                                  WET  <:CRUPbING
                                                  LIMESTONE
                                                  PEAe-ODY  PROCESS  SYSTEMS
                                                  NEW
                                                       '.1
                                                   9/7°
                                                   9/7S
                                                        .0
                                                        .0
                                                  CLOSED
                                                      fl.
                                                  UC GPI«)
 •* DISPOSAL
     TYPE
                                LINED  POND
	PEPfORMANCE DATA	
PERIOD MODULE  AVAILABILITY OPERAPU1TY  RELIABILITY UTILIZATION   I  REMOVAL   PE»  BOILER   FGO    CAP.
                                                                   SO?   PART. HOURS HOURS   HOURS  FACTOR
 1/80
      A
      6
      SYSTEM
              35.8
              5*. 7
              61.5
                    90.7

       *• PHOBLEMS/SOLUTIONS/COMMENTS
21.1
33.5
4P.1
                                                                                744
                                                                           357
                          DURING JANUARY  UNIT  2  «AS UNAVAILABLE  6«  HOURS  DUE TO REPAIRS  NFEOED  ON
                          AN ABRADED EXPANSION JOINT AND A RUPTURF.D  WASTE SLURRY LINE.
 2/8"
       A
       B
       SYSTEM
              84.3
              74.7
              99.3
                  99.3

         PROBLEMS/SOLUTIONS/COMMENTS
                                                        84.3
                                                        74.7
                                                        99.3
                                                                               696
                                                                    69£
                                                                                              691
                          THE UNIT 2 FGD  SYSTEM  OPERATED ALL BUT  5  HOURS  CURING FEBRUARY,  IN  WHICH
                          TIME THE BOILER WAS  PF1NG MOU&HT ON-LINE.
 3/8C
       A
       b
       SYSTEM
100.0
                               81. t
                               79.4
                               97.8
                                       75.0
                                       73.0
                                       8P.9
                       744
                                                                    6?4
                                                                                             669

-------
                                                EPA  UTILITY F6D  SURVEY: JANUARY  -  PAHCH 1 
-------
 EP«  UTILITY FGD SU»VEY: JANUARY  - MARCH  198C
                                             SFCT1CN
                DrSIGN AND PERFORMANCE  DATA  FOR
                                                             DOMESTIC F&D SYSTff?
C OMPANY  NAME
PLANT  NAME
JNIT NUMBER
C ITY
STATE
GROSS UNIT GENEOAMN&  CAPACITY - Ww
NET UNIT GENERATING  CAPACITY W/FGD - *w
EOUIVALF.NT SCPUPFFD  CAPACITY - Mu

• * FUEL  DATA
    FUEL TYPE
    FUEL GRAD?
    AVcRAGE HEAT  CONTENT  -  J/G
    AVERAGE AJM CONTENT  - X
    AVc»AGE MOISTURE CONTENT - *
    AVERAGE SULFUR CONTENT  - *
    AVERAGE CHLORIDE CONTENT - *

•• FGD SYSTEM
    GENERAL PROCESS  TYPE
    PROCESS TYpr
    SYSTEM SUPPLIER
    NEW/RETROFIT
    ENERGY CONSUMPTION -  *
    INITIAL STAPT-UP DATE
    COMMfRfjAL START-UP DATE
    S02 BESI&N REMOVAL EFFICIENCY  - X
    PARTICULAR DFSIGM REMOVAL  EFFICIENCY
    ABSORBER SPASt CAPACITY  INDEX  - X
    A9SORBER SPARE COMPONENTS  INDE»

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

•*  DISPOSAL
    TYPE
                                                  «LAt-AMA  CLECTRIC COOP

                                                  TOMfl&BEE
                                                  7

                                                  LEKCY
                                                  ALAbAWA
                                                    179.:.



                                                  COAL

                                                   26749.         (  1150C


                                                      lll5
                                                 WET  SCRUPBING
                                                 LIMESTONE
                                                 PEAbODY  PROCESS  SYSTEMS
                                                 NEW
                                                      '.1
                                                  6/7"
                                                  6/79
                                                     fcS.^C
                                                     99.30
                                                  CLOSED
                                                      «.?         C   HC r-P»«)
                                                 LINED  PO^fD
..	.__	.	PE'f 0«MAMCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY RFLIAPILITY  UTILIZATION   1  REMOVAL   PER  SsOILfcG  FGD    C«F.
                                                                  502   PART.  HOURS HOURS  HOURS  FACTOR
1/80


A
B
SYSTEM 1CO.O
69.2
45.4
97.9
3". 5
20. C
47.1 744 3?t *<1
 2/6'
 3/BC
      •* PROBLtMS/SOLUTIONS/COMMENTS

                        DURING  JANUARY  UNIT 3 HAS AVAILABLE THE ENTIRE  MONTH.


                               33.3                      1.1
                              1CC.C                      7.4
                 '00.C        10C.C                      7.4                   e°6     ?4      24

      •• PHOBLEWS/SOLUT10NS/COMMENTS


                        DURING  FEBRUARY  THE UNIT 3 BOILER AND FGD SYSTEM OPFB4TED  ONLY  ?4 HOURS.
       A
       b
       SYSTEM
       A
       e
       SYSTEM
                                                         .0
                                                         .3
                                                         .C
                                                                               744
           100.0

*• PROBLEMS/SOLUTIONS/CONMENTS

                  DURING MARCH  THF  UNIT  3  GENERATOR WAS KEPT OUT OF  SFRVICt.

-------
                                              EPA UTILITY FGD SURVEY: JANUARY  - MARCH  I9t'

                                            SECTION 3
               DESIGN AND PERFORMANCE  DA^A  fOK  OPERATIONAL DOMESTIC FGD  SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
&SOSS UNIT GENERATING  CAPACITY  - MW
\ET UNIT GENERATING  CAPACITY  W/FGD  - l"w
EQUIVALENT SCRUPBC0  CAPACITY  -  «y

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

** FGD SYSTEM
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM SUPPLIER
    NEW/RETROFIT
    ENERGY CONSUMPTION -  I
    IMT1AL START-UP DATE
    COMMERCIAL START-UP  DATE
    S02 DESIGN REMOVAL EFFICIENCY - X
    PARTICULATt DESIGN REMOVAL  EFFICIENCY - 3t
    ABSORBER  SPARf COMPONENTS INDEX

•* WATER LOOP
    TYPE
    FRESH  MAKE-UP UATEH  - LITER/S
                                                 ALLEGHENY PObEB SYSTEM
                                                 PLE A*ANTS
                                                 1
                                                 BEL^ONT
                                                 WEST VIRGINIA
                                                   625.C
                                                   625.C
                                                   510.:
                                                 COAL
                                                 BITUMINOUS
                                                                 c  irccc
                                                    11. CC
                                                 WET SCRUFB INC-
                                                 LINE
                                                 BAECOCK ft yiLCCX
                                                 NEW
                                                  J/7'
                                                 **/•«
                                                    97. OC
                                                    59.55
                                                 CLOSED
                                                                 (*»**•  6PM)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPEHAPHITY  RELIABILITY UTILIZATION   *  REMOVAL   PER  BOILER   FGO    C»P.
                                                                  SO?  PART. HOURS HOURS   HOURS  FACTOR
 1/8^  SYSTEM

 2/80  SYSTEM

 3/8?  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMHENTS
                                                                               69C

                                                                               744
                          NO INFORMATION WAS AVAILABLE  ON  THE  OPERATIONS AT PLEASANTS  1  FOR  THE
                          FIRST QUARTER 1980.
                                                  41

-------
EPA UTILITY FGP SURVEY: JANUARY  -  PARCH  198C

                                            SECTION 3
               DESIGN AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
         NAMf
 PLANT NAME
 JV]f NUMBER
 C MY
 STATE
 GROSS UNIT GENERATING CAPACITY  -  MW
 NiET UNIT GENERATING CAPACITY  W/FGD  -  "W
 EQUIVALENT SCFUPBFO CAPACITY  -  fu
API20NA ELECTRIC POKER  COOP
APACHt
2
COCHISE
ARIZONA
  1 95.0
  1 75.0
  195.0
•* 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 - *
** FGC SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NFy/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COM"ERCJ*L START-UP DATE
SOi DESIGN REMOVAL EFFICIENCY - X

COAL
BITbllNOUS
2326U. < 1*000 ETU/LP)
15.00
9. 30
.55

WFT SCRUBBING
LI" £ STONE
RESEARCH COTTHELL
NE\-
4. 1
P/ ?«
I/ 7?
25 .CO
PAKT1CULATE DESIGN REMOVAL EFFICIENCY - X S9.5C
APSORBER SPARE CAPACITY INDEX - X
AHSORBE" SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP yATER - LITER/S
•* DISPOSAL
TYPE
PERIOD MODULE AVAILABILITY OPERAB1LITY
• w1
• -'

OPEN
115.9 ( 1»4C GP^)

PONt
RELIABILITY UTILIZATION * ȣMOVAL PER BOILER FGD C*P.
SO? PART. HOURS HOURS HOURS FACTOR
1/80   SYSTEM       90.9        5P.3        8
-------
                                             EPA UTILITY  FGD  SURVEY:  JANUARY - MARCH 15fc:
                                           SECTION  5
               DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FGD
COMPANY  NAME
PLANT  NAME
JNIT NUMBER
CITY
STATE
GROSS  UNIT  GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - MU
EQUIVALENT  SC&UBBFD CAPACITY - MW

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

•*  FGD SYSTEM
    GENERAL  PROCESS TYPE
    PROCESS  TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL STAPT-UP DATE
    COMMERCIAL START-UP DATE
    S02  DESIGN REMOVAL EFFICIENCY  -  X
    PART1CULATE DESIGN REMOVAL EFFICIENCY
    ABSORBER SPARE CAPACITY INDEX  -  X
    ABSORBER SPARE COMPONENTS  INDEX

 •*  WATER LOOP
     TYPE
     FRESH MAKE-UP  WATER - L1TER/S

 **  DISPOSAL
     TYPE
- X
     ARIZONA ELECTRIC POfcER COOP
     APACHE
     i
     COCMISE
     ARIZONA
       195.0
       1 75.C
       195.0
     COAL
     BITUMINOUS
      2326C.
        15.00
         9.00
          .55
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
    4.1
 6/79
 4/79
   65.00
   99.50
     .0
     .0
                ( 1TOCC 6TU/LB)
     OPEN
       340.2
                                                 POND
                <  5400 6PM)
	—	— PERFORMANCE DATA—	—	
PERIOD MODULE AVAILABILITY  OPERABIL1TY  RELIABILITY UT1LI7ATION  X REMOVAL   PER  BOILER  FGD    CAP.
                                                                 SO?   PART. HOURS HOURS  HOURS FACTOR


 1/80  SYSTEM      91.7         91.7        91.7        91.7     97.40         744   744    682

       •* PROBLEMS/SOLUTIONS/COMMENTS

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

                          OUTAGE TIME WAS ALSO CAUSED 8»  A BROKEN  FEED BELT TO THE LIMESTONE BALL
                          MILL.

 Z/60  SYSTEM      95.6         74.1        96.0        71.4     97.40         696   671    497

       •• PROBLEMS/SOLUTIONS/COMMENTS

                          DURING FEBRUARY OUTAGE  TIME MAS  DUE  TO A  PRECIPITATOR  FAILURE.

                          FORCED OUTAGE TIME WAS  ALSO CAUSED  BY  A  PUMP MALFUNCTION.

 3/80  SYSTEM      91.0         91.C        91.0        91.0                   744   744    677

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          SOME OF THE OUTAGE TIME DURING  MARCH OCCURRED BECAUSE  OF PU«IP  FAILURE.

                          OTHER OUTAGE TIME WAS  CAUSED  BY  STICKING VALVES  AND LIMESTONE  FEED-BELT
                          PROBLEMS.
                                                  43

-------
EPA  UTILITY  FGD  SU»VEY:  JANUARY - WAPCH 198C
                                            SECTION J
                       AND  PERFORMANCE DATA FOR OPERATIONAL DOMESTIC fGD SYSTEMS
 COMPANY  MANE
 PLANT  NAME
 UNIT NUMBER
 C ITY
 STATE
 GROSS  UNIT GENERATING  CAPACITY  - PI*
 NET UNIT  GENERATING  CAPACITY  W/FGO  - MW
 EQUIVALENT SCRUBBED  CAPACITY  -  MW

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

 *• FGD SYSTEM
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION -  *
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     302 DESIGN REMOVAL EFFICIENCY -  Z
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBED SPARF CAPACITY INDEX -  X
     ABSORBER SPARF COMPONENTS INDEX

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

 ** DISPOSAL
     TYPE
ARIZONA PUBLIC  SERVICE
CHOLLA
1
JOSEPH CITY
ARIZONA
  11<3.C
  115.0
  1 19.0
COAL
BITUMINOUS
 23699.
   13.50
   15.00
     .50
     .D2
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
RETROFIT
    3.4
10/7?
12/73
   92.00
   80.00
     .0
<  10150 BTU/LFJJ
OPEN
    7.6
               I  120 GPM)
POND
	......	____.....	—PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION
          PROBLEMS/SOLUTIONS/COMMENTS
                X REMOVAL   PER  BOILER  FGD    ClP.
                S02  PART. HOURS HOURS  HOURS  FACTOR
11/79


12/79


1/60


2/80


3/80


A
b
SYSTEM
A
B
SYSTEM
A
b
SYSTEM
A
e
SYSTEM
A
e
SYSTEM
77.0
9P.O
87.5
91. C
87.0
9C.5
95. C
99.0
97. C
100.0
99. Q
99.5
99.0
93. C
94.0
77.0
98.0
87.5
94.0
87.0
90. 5
9?.0
99.0
97.Q
ior.o
99.0
99.5
99.0
93.0
96.0


720 720 632


744 744 672


744 744 724


696 696 694


744 744 715
                         NO FORCFD OUTAGES UfRE  REPORTED BY  THE UTILITY  FOR  THE  FIVE  MONTH  PER10P.
                         SOME SCHEDULED OUTAGE  TIME HAS REQUIRED  FOR  REPAIR  OF  THE  REHEATED  DUCT-
                         WORK.

-------
                                             EPA UTILITY fee SURVEY: JANUARY - MARCH  1980

                                           SECTION 3
               DESIGN  AND  PERFORMANCE DATA fOR OPERATIONAL DOMESTIC f6D SYSTEMS
         NAME
 PLANT  NAME
 JNIT NUMBER
 CITY
 STATE
 GROSS  UNIT GENERATING CAPACITY - My
 NET  UNIT GENERATING  CAPACITY U/FGD - Mw
 EQUIVALENT SCRUPBED  CAPACITY - MW

 ««  FUEL OATA
     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
     NEK/RETROFIT
     ENERGY  CONSUMPTION - X
     INITIAL  START-UP DATE
     COMMERCIAL  START-UP D»TE
     S02 DESIGN  REMOVAL EFFICIENCY - X
     PAHT1CULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPAR? COMPONENTS INDEX

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

 •*  DISPOSAL
     TYPE
   ARIZONA PUBLIC SERVICE
   CHOLLA
   2
   JOSEPH CITY
   ARIZONA
     357.0
     25".0
     150.0
   COAL
   PITUMINOUS
      13.50
      15.00
        .50
        .02
   WET SCRUBBING
   LIMESTONE
   RESEARCH COTTRELL
   NEW
                  ( 1?150 BTU/LB)
    4/78
   *•/ «»
      75.00
X     99.70
      33.0
       1.0
   OPEN
       7.6
                   (  120 GPM>
   POND
	—	—-—PERFORMANCE DATA-------	
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY  UTILIZATION   X REMOVAL    PER  BOILER  FGD   (. tP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 a/80  SYSTEM

 3/80  SYSTEM

       *» PROBLEMS/SOLUTIONS/COMMENTS
                                 744

                                 696

                                 744
                         NO INFORMATION  IS  AVAILABLE  AS  OF  YET  WITH  RESPECT TO THE CHOLLA ? FGD
                         OPERATIONS.

-------
 EPA  UTILITY  FGO SURVEY: JANUARY - MARCH  198C

                                             SECTION 3
                DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC F6D SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 JNIT NUMBER
 C 1TY
 STATE
 GROSS  UNIT GENERATING CAPACITY - My
 NET UNIT  GENERATING CAPACITY H/FGD - Mw
 EOUIVALENT SCRUFBFD CAPACITY - I»W

 **  FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE  HEAT  CONTENT - J/G
     AVERAGE  ASH CONTENT - *
     AVERAGE  MOISTURE  CONTENT - *
     AVERAGE  SULFU"  CONTENT - Z
     AVERAGE  CHLORIDE  CONTENT - *

 **  FGD SYSTEM
     GENERAL  PPOCE«S TYPE
     PROCESS  TYPt
     SYSTEM SUPPLICR
     NEW/RETROFIT
     ENERGY CONSUMPTION  - X
     INITIAL  START-UP  DATE
     COMMERCIAL  START-UP DATE
     S02 DESIGN  REMOVAL  EFFICIENCY - *
     PARTICULAU DESIGN  REMOVAL EFFICIENCY - *
     ABSORBER 5P«RE  COMPONENTS INDEX
ARIZONA PUBLIC  SERVICE
FOUR CORNERS
1
FARKINGTON
NEW MEXICO
  1 75.0
  175.0
  1 75. C
COAL
SUBblTUMlNOUS
 20CC<..
   '2.nO
   1?.30
     .75
     .07
WET SCRUBBING
LIME/ALKALINE FLYASH
(   "600 BTU/LP)
RETROFIT

11/70
+ * / * *


   59.00
    1 .C-
------------------------------------------ PERFORMANCE  DATA
PE»10D MODULE  AVAILA9ILITY  OPERABILITY RELIABILITY  UTILIZATION
REMOVAL
?  PART.
             PER
            HOURS
                                  BOILER
                                  HOURS
                                                                                           FGD    CAP.
                                                                                          HOURS  FACTOR
12/79  SYSTEM                                                                  744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          INITIAL OPERATIONS STARTED  IN NOVEMBER  1979.

 1/8?  SYSTEM                                                                  744

 2/80  SYSTEM                                                                  696

 3/80  SYSTEM                                                                  744

       •* PROBLEMS/SOLUTIONS/COMMENTS

                          THE  UNIT IS  PRESENTLY IN THE S HAK E D OWN /DEBUGGI NG PHASE OF OPERATION.

-------
                                              EPA  UTILITY  FGD SURVEY: JANUARY - MARCH

                                            SECTION  3
               DESIGN AND PERFORMANCE DAT*  (OS  OPERATIONAL DOMESTIC FGD SYSTEMS
 C OWPAN*  NAME
 PLANT  N * M E
 JN1T NUMBER
 C ITY
 STftTE
 GROSS  UNIT  GENERATING CAPACITY  - MM
 YET  UNIT  GENERATING CAPACITY W/FGD - MW
 EQUIVALENT  SCRUBBED CAPACITY -  My

 *•  FUEL  DAT»
     FUEL TYPE
     FUEL GRADE
     AVERAGE  HEAT CONTENT - J/G
     AVERAGE  ASH CONTENT - X
     AVERAGE  MOISTURE CONTENT -  X
     AVERAGE  SULFU" CONTENT - *
     AVERAGE  CHLORIDE CONTENT -  *

 **  FGD SYSTFM
     GENERAL  PROCESS TYPE
     PROCESS  TYPE
     SYSTEM  SUPPLIER
     NEW/RETROFIT
     ENERGY  CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL ST»RT-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY  -  X
     PAHTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER  SPARE COMPONENTS  INDEX
ARIZONA PUBLIC  SERVICE
FOUR CORNERS
2
FARM1NGTON
NEW MEXICO
  1 75.5
  1 75.0
  1 75.0
COAL
SUBBITUMINOUS
 23C04.
   22.00
   12.30
     .75
     .07
tiET SCRUBBING
LIME/ALKALINE  FLVASH
CMEMICO
RETROFIT
(   ?6CC BTU/Lp)
11/79
** / * *

    99.00
    1.0
	PERFORMANCE DAT*	
PERIOD MODULE *V«ILABILITY  OPERAPILITY RELIABILITY UTILIZATION   *  REMOVAL   PER  BOILER  FED    CAP.
                                                                  <02  PART. HOURS HOURS   HOURS  FACTOR


11/70  SYSTEM                                                                  720

12/79  SYSTEM                                                                  744

       ** PROBLEWS/SOLUTIONS/COMMENTS

                          INITIAL OPERATIONS STARTED  IN  NOVEMBER 19?9.

 1/8P  SYSTEM                                                                  744

 2/80  SYSTEM                                                                  696

 3/80  SYSTEM                                                                  744

       •* PROBLEMS/SOLUTIONS/COMMENTS

                          THE UNIT IS PRESENTLY  IN  THE  SHAKEDOWN/DEBUGGING PHASE  OF  OPERATION.
                                                  47

-------
 EP»  UTILITY  FGD  SURVEY:  JANUARY  -  MARCH  198C


                                            SECTION 3
               DESIGN  AND  PERFORMANCE  DATA  fOR  OPERATIONAL DOMESTIC  fGD SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  UNIT NUMBER
  C JTY
  STATE
  GROSS  UNIT GENERATING  CAPACITY  -  M*
  NET UNIT GENERATING CAPACITY  W/fGD -  *W
  EQUIVALENT SCRUBBED CAPACITY  -  Mw

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

  *• FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPF
     SYSTEM SUPPLIER
     NEW/RETROF IT
     ENERGY CONSUMPTION - X
     INITIAL STAPT-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PART1CULATE DESIGN RtMOVAL  EFFICIENCY
     ABSORBER SPARE COMPONENTS INDEX
ABIZON* PUBLIC SfRVjCE
FOUR CORNERS
3
FARKINGTON
NEW MEXICO
  229.0
COAL
SUBBITUMINOUS
 2CCG4.
   23.10
   12.30
     .75
     .07
WET SCRUBBING
LIME/ALKALINE FLYASH
CHEMCO
RETROFIT
(   P60C BTU/Lp)
11/79
* * I * *


   99.00
    1.0
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  t  REMOVAL    PER   BOILER   FGD    CAP.
                                                                SO?   PART.  HOURS  HOURS   HOURS  FACTOR


11/79  SYSTEM                                                                 720

12/79  SYSTEM                                                                 7*4


       *• PBOBLEHS/SOLUTIONS/COMMENTS

                         INITIAL OPERATIONS STARTED  IN NOVEMBER 1979.

 1/80  SYSTEM                                                                 744

 2/80  SYSTEM                                                                 C>96

 3/80  SYSTEM                                                                 744

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         THE UNIT IS PRESENTLY IN THE SHAKEDOWN/DEBUGGING PHASE OF OPERATION.
                                                48

-------
                                              EPA UTILITY FGD  SURVEY:  JANUARY - MARCH 1°l'

                                            SECTION 3
               DESIGN AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC  F&D  SYSTEMS
 COMPANY  NAME
 PtANT  NAME
 JNIT NUMBER
 CITY
 STATE
 GROSS  UNIT GENERATING CAPACITY  -  Mw
 NET  UNIT GENERATING CAPACITY  W/FGO  - MU
 EQUIVALENT SCRUBBED CAPACITY  -  "V

 **  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

 *•  FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION  -  X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02  DESIGN REMOVAL  EFFICIENCY - X
     PART1CULATE OFSIGN  REMOVAL  EFFICIENCY -
     ABSORBER  SPARE COMPONENTS INDEX

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

 **  TREATMENT
     TYPE
BIG "IVE"S  ELECTRIC
GREEN
1
KENTUCKY
  24?.0
  2: -r. c
COAL
BITUMINOUS
 2267s.
   2T. 00
   11.00
    ?.75
WET SCRUBBING
LJNE
AMERICAN  AIR  FILTER
NEW
(   975C EiTU/LP)
12/79
12/79
    9?.00
    99.00
     1.0
CLOSED
                                                  POZ-0-TEC
                (*****
	_	._._. — PERFORMANCE  DATA	
PERIOD MODULE  AVAILABILITY  OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL    PER   BOILER  FGD   CAP.
                                                                  S02   PART.  HOURS HOURS  HOURS FACTOR


 1/80  SYSTEM                                                                   744

 2/8T  SYSTEM                                                                   696

 3/80  SYSTEM                                                                   744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          NO INFORMATION WAS  AVAILABLE  FOR THE FIRST QUARTER, 1980.
                                                  49

-------
 EPA UTILITY FGD SURVEY:  JANUARY  - MARCH 1980
                                             SECTION  2
                DESIGN  AND  PERFORMANCE DATA fOR OPERATIONAL  DOMESTIC  FGD  SYSTEMS
  COMPANY NAME
  PLANT NAME
  JNIT NUMBER
  CITY
  STATE
  GROSS UNIT GENERATING CAPACITY  -  Ntf
  NET  UNIT GENERATING CAPACITY W/FGD  -  "W
  EQUIVALENT SCRUBBED CAPACITY -  MW
                               CENTSAL ILLINOIS LIGHT
                               DUCK CREEK
                               1
                               CANTON
                               ILLINOIS
                                 4 14.0
                                 378.0
                                 378.C
     FUEL  DATA
      FUEL TYPE
      FUEL GRADE
      AVERAGE  HEAT CONTENT - J/G
      AVERAGE  ASH CONTENT - Z
      AVERAGE  MOISTURE CONTENT - X
      AVERAGE  SULFUR CONTENT - *
      AVERAGE  CHLORIDE CONTENT - I

     FGO SYSTEM
      GENERAL  PROCESS TYPE
      PROCESS  TYPE
      SYSTEM SU°PLIFR
      NEy/RETROFIT
      ENERGY CONSUMPTION - *
      INITIAL  STABT-UP DATE
      COMMERCIAL START-UP DftTE
      S02  DESIGN REMOVAL EFFICIENCY - X
      PAHTICULATE  DFSIGN REMOVAL EFFICIENCY
      ABSORBER SPAR?  COMPONENTS INDEX

     WATER  LOOP
      TYPE
      FRESH MAKF-UP  WATER - LITER/S
                               COAL
                               BITUMINOUS
                                24423.         < 1C5CC BTU/LP)
                                   9.12
                                  1«.OC
                                   3.30
                                    .03
                              WET  SCRUPBING
                              LIM ESTONE
                              RILEY  STOKER/ENVIRONEERING
                              NEW
                                   2.9
                               7/76
                               8/7°
                                  •5.00
                              CLOSED
                                  7,7. a
                                                 600 GP!»)
 •• DISPOSAL
     TYPE
                              LINED  POND
..—..	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY  OPtRAPILITY RELIABILITY  UTILIZATION
                                               *  REMOVAL   PER  BOILER   FGD    CAP.
                                               S02   PART. HOURS HOURS   HOURS  FACTOR
1/80 A
B
C
D
SYSTEM
21. P
58.5
17.1
29.2
32.4
27. C
67.6
1C. 6
31.9
35.2
29.8
65.9
2?. 3
35.4
38.3
24.8
5».5
17.1
29.3
32.4




744 684 241
       *• PROBLtMS/SOLUTIONS/COMMENTS
 2/80  A
       B
       C
       D
       SYSTEM
11.8
72.7
70.7
70.2
49.7
                          OUTAGE TIME WAS REGUIRED  DURING JANUARY FOR RECYCLE  TANK  COVERING  WORK.

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

                          OTHER PROBLEMS ENCOUNTERED DURING THE MONTH INCLUDED: A PLUGGED  LIMESTONE
                          FEEDER, INLET DAMPER PROBLEMS,  SLURRY SUPPLY HEADER  LEAKS AND  STORAGE
                          PUMP DISCHARGE VALVE REPAIRS.
11.8
72.7
70.7
41.2
49.1
12.5
73.5
71.5
47.8
51.9
11.8
72.7
70.7
41.2
49.1
                                                                               696   696
                                                                                             342
                                                 50

-------
                                             EPA UTILITY FGD SURVEY: JANUARY - MARCH 196"
CENTRAL ILLINOIS LIGHT: DUCK CREEK  1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERAPILITY RELIAPILITY UTILIZATION  * REMOVAL   PE"  BOILER  FGD   CAP.
                                                                SO?  PART. HOURS HOURS  HOURS fACTOR

       «* PROBLEMS/SOLUTIONS/COMMENTS
                         DURING FEBRUARY SOME OUTAGE TIME MAS DUE TO MODULE CLEANING AND THE
                         CLEANING OF THE MIST ELIMINATOR SECTION.
                         THE INLET DAMPER DRIVE WAS REPLACED DURING THF MONTH.
                         REPAIR OF THE FIBERGLASS ON THE SLURRY RECYCLE LINE HINDERED OPER-
                         ATIONS DURING THIS MONTH.
                         THE RECYCLE DISCHARGE VALVE WAS REPLACED CAUSING SOME  DOWN
 3/80  SYSTEM                                                                744
       ** PROBLEMS/SOLUTIONSKOMMENTS
                         NO INFORMATION WAS AVAILABLE FOR THE MONTw OF MARCH.
                                                 51

-------
 EPA  UTILITY fGD SURVEY: JANUARY - MARCH  198C

                                             SECTION  3
                DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC FGD SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  JNIT NUMBER
  C ITY
  STATE
  GROSS  UNIT GENERATING CAPACITY - My
  NET UNIT GENERATING CAPACITY W/FGO - I" W
  EQUIVALENT SCRUBBED CAPACITY - MM

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

  •*  FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEb/RETROFIT
     ENERGY CONSUMPTION  - X
     INITIAL STAPT-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  -  L1TER/S

 •* TREATMENT
     TYPE
                         - X
                               CENTRAL ILLINOIS PUBLIC SERV
                               NEW TON
                               1
                               NEW TON
                               ILLINOIS
                                 617.C
                                 575.0
                                 617.0
                               COAL
                               BITUMINOUS
                                25353.
                                  4.00

                                  2.25
                                    .20
                              WET  SCRUBBING
                              DUAL  ALKALI
                              BUELL/ENVIROTECH
                              NEW
                                  (  1T9CC  BTU/LP)
                   9/79
                  12/79
                     95.00
                     99.50
                      1.0
                              CLOSED
                                                 POZ-0-TEC
                                              (•****  GPM)
	.	._....	.	-PERFORMANCE DATA-----
PERIOD MODULE AVAILABILITY  OPERABIL1TY RELIABILITY UTILIZATION
 2/8?
                                                                 *  REMOVAL    PER   BOILER  FGD   c*p.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR
1/80 A
B
C
D
SYSTEM
68.7
66.4
52.2
21. C
52. r
57.1
60.6
48. S
19.1
4t.4
63.5
64.9
6H.5
26.3
57.8
55.5
5?. 9
47.4
1?.5
45.1




744 723 336
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         DURING  JANUARY  TESTS  WERE CONDUCTED TO CERTIFY  THE  GAS  EMISSIONS MONITOP
                         AT NEWTON.
       A
       ti
       C
       D
       SYSTEM
61.1
74.4
78.2
   f*
  • v
53.4
42.4
55.7
5«.5
  .0
30.2
45.0
57.7
59.1
42.4
55.7
5?.5
  .0
39.2
                                                                               696    696
                                                                                            :73
          PROBLEMS/SOLUTIONS/COMMENTS
 J/80
53.4
47.0
44.5
                         DURING  FEBRUARY  THE  D  MODULE WAS UNAVAILABLE DUE TO  THE  COLLAPSE  OF THE
                         PRECOOLfR MIST ELIMINATORS  CAUSED BY A TEMPERATURE EXCURSION.
52.6
42.3
41.1
                                            53.1
                                            4P.C
                                            46.5
            52.3
            42.1
            41.0

-------
                                              EPA UTILITY fGD SURVEY: JANUARY - MARCH 196?


CENTRAL ILLINOIS PUBLIC SERW: NEWTON  1  
-------
 EPA  UTILITY FGD SU"»ET: JANUARY - MARCH  198C

                                             SFCTJON 3
                DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC FGD SYSTEM?
 COMPANY  NAME
 PLANT  NAME
 JNIT NUMBER
 CITY
 STATE
 GROSS  UNIT GENERATING CAPACITY - My
 NET UNIT GENERATING CAPACITY U/fGD - My
 EQUIVALENT SCRUBBED CAPACITY - MW

 *•  FUEL  DAT*
     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

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

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

 ** DISPOSAL
     TYPE
COLORADO  UTE  ELECTPIC  «SSN.
CRAIG
2
C"AIG
COLORADO
  1,1.7.0
  4:,;. o
  447.0
                <  10000  E-TU/Lp)
COAL
SUBBITUMINOUS
 23260.
    S.OO
   16.00
     .45
     .00
WET SCRUBBING
LIMESTONE
PEABODY PROCESS  SYSTEMS
NEW
    5.4
 8/79
 6/80
   85.00
   99.80
    1.0
CLOSED
   19.9
MINEflLL
                (  316 6PM)
	.	.	._.—.............. PEP fORM AN CE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  t  REMOVAL    PER  BOILER  FGD    C»P.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS
                              744

                              6<>6

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

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

                          PROBLEMS WITH  OPENING/CLOSING THE BYPASS  DAMPER HAVE BEEN ENCOUNTERED.
                          LARGER  OPERATORS  ARE BEING LOOKED AT TO SOLVE  THE  PROBLEM.
                                                 54

-------
                                             EPA UTILITY fGD SURVEY; JANUARY - MARCH  198P

                                           SECTION ?
               DESIGN  AND  PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC FGC SYSTEMS
COMPANY NAME
PLANT  NAME
JNIT NUMBER
CITY
STATE
GROSS  UNIT  GENERATING  CAPACITY -MM
NET UNIT  GENERATING  CAPACITY U/FGD - My
EQUIVALENT  SCRUBBED  CAPACITY - MW

**  FUEL DAT*
    fUEL  TYPE
    FUEL  GRADE
    AVERAGE  HEAT  CONTENT - J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT - *
    AVERAGE  SULFUR  CONTENT - X
    AVERAGE  CHLORIDE CONTENT - *
                                               COLU1&US  &  SOUTHERN  OHIO  ELEC.
                                               CONESVILLE
                                               5
                                               CONESVILLE
                                               OHIO
                                                  411. C
                                                  375.0
                                                  411.0
                             COAL
                             BITUMINOUS
                              ?5i?7.
                                15.1C
                                 7.50
                                 4.67
                                                               (  10850 6TU/LP)
•* FGO SYSTEM
    GENERAL PROCESS TYPE
    PROCESS TYPE
    SYSTEM SUPPLIER
    NEW/RETROFIT
    ENERGY CONSUMPTION - X
    INITIAL START-UP DATE
    COMMERCIAL ST«RT-UP DATE
    S02 DESIGN REMOVAL EFFICIENCY  - X
    PARTICULATE DESIGN REMOVAL  EFFICIENCY  -  X
    ABSORBER SPARE CAPACITY INDEX  - X
    ABSORBER SPARE COMPONENTS  INDEX

** WATER LOOP
    TYPE                                        OPEN
    FRESH MAKE-UP WATER - LITER/S                  31.5

** TREATMENT
    TYPE                                        POZ-0-TEC

•* DISPOSAL
    TYPE                                        POND
                                                WET SCRUF8ING
                                                LIME
                                                AIR CORRECTION  DIVISION,  UOP
                                                NEW
                                                    *.9
                                                 1/77
                                                 2/77
                                                    89.50
                                                      .?C
                                                      .0
                                                      .0
                                                                <   500 GPM)
	..—...	_—..__.._pEBfORBAN£E
PERIOD MODULE AVAILABILITY OPERAPILITY  RELIABILITY  UTILIZATION
                                                                X REMOVAL   PER   BOILER   FGC    C«P-
                                                                S02  PART. HOURS  HOURS   HOURS  FACTOR
1/80 A 25.0 38.0 45.0 13.0
B 29.0 50.0 59.0 17.0
SYSTEM 27.0 44.0 52.0 15.0


744 255 112
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         DURING  JANUARY  A  BOILER OUTAGE OCCURRED FROM THE FIRST OF THE  MONTH  TO  THE
                         TWENTIETH,  DURING WHICH TIME MAINTENANCE WAS PERFORMED ON THE  FGD  SYSTEM.
 2/80
      A
      B
      SYSTEM
90.0
93.0
92.0
6J.O
69.0
66.0
77.C
84.C
81.0
31.0
34.0
33.0
                                                                              696    348
                                                                                           230
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          A  BOILER  OUTAGE  LASTING APPROXIMATELY 17 DAYS ALSO OCCURRED  DURING
                          FEBRUARY.
 5/80
       A
       B
       SYSTEM
                   88.0
                   88.0
                   88.0
            82.0
            81.0
            82.0
            82.C
            81.0
            82.C
            82.0
            81.0
            82.0
                                                                               744    744
                                                                                            610
                                                 55

-------
EP» UTILITY  FGD  SURVEY:  JANUARY - MARCH 198C

COLUMBUS 6  SOUTHFRM  OHIO ELEC.: CONESV1LLE  5  KONT.J
	pEBfCRMANCF DATA	
PERIOD MODULE AVAILABILITY  OPE R AE> I L IT Y RELIABILITY  UTILIZATION  X REMOVAL    PER   BOllE"   FGO   C»P.
                                                                  «02  PAST. HOURS  HOURS   HOURS fACIOR


       •* PROBLIWS/SOLUTIONS/COMWENTS

                          DURING  MARCH PROBLEMS  NERE  EXPERIENCED WITH THE IUC?  SLUDGE  STABILIZATION
                          PROCESS AND SOMF OUTAGE  TIKE RESULTED.  ALSO DURING MARCH  SOME  GRlt RODS
                                EC REPL'CING  «ND  SOME  RUBBER  LINER FAILURES OCCURRED.
                                                 56

-------
                                              EPA UTILITY  fGD  SURVEY: JANUARY - MARCH 19£r
                                           SECTION  2
               DE57GN AND PERFORMANCE CA^A FOR  OPERATIONAL  DOMESTIC  f&D
 COMPANY  NAME
 PLANT  NAME
 JNIT NUMBER
 C ITY
 STATE
 GROSS  UNIT  GENERATING CAPACITY - M*
 NET  UNIT GENERATING CAPACITY W/FGD - My
 EQUIVALENT  SCRUBBED CAPACITY - Mtt
                                         COLU»bUS &  SOUTHERN  OHIO  ELEC.
                                         CONESVILLE
                                         6
                                         CONcSVlLLE
                                         OHIO
                                           01. j
                                           375.:
                                           411. j
«• fUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HfAT CONTENT  -  J/G
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT  -  t
    AVERAGE SULFUR CONTENT  -  X
    AVERAGE CHLORIDE CONTENT  -  *

•« FGD SYSTEM
    GENERAL PROCESS TYPE
    PROCESS TYP?
    SYSTEM SUPPLIER
    NEn/RETROFIT
    ENERGY CONSUMPTION  -  X
    INITIAL START-UP DATE
    COMMERCIAL START-UP DATE
    SOe DESIGN REMOVAL  EFFICIENCY - X
    PARTICULAR DESIGN  REMOVAL  EFFICIENCY
    APSORBER SPAR? CAPACITY  INDEX - X
    ABSORBER SPARF COMPONENTS INDEX

»« yATEB LOOP
    TYPE
    FRESH MAKE-UP  WATER - LITER/S

•• TREATMENT
    TYPE

** DISPOSAL
    TYPE
                                                 COAL
                                                 PITU"INOUS
                                                  25Z37.         ( 1085C PTU/LP)
                                                    15.10
                                                     7. 50
                                                     4.67
                                                      .01
                                                 hET SCRUF>6INC
                                                 LIME
                                                 AIR CORRECTION DIVISION, OOP
                                                 NEW
                                                     3.9
                                                  6/7?
                                                 * * / * *

                                                    89.5C
                                              *        ."0
                                                 OPEN
                                                    21.5
                                                 POZ-0-TEC
                                                 POND
                                                                GPM)
	.	......	.	.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPEPAPILITY  RELIABILITY UTILIZATION  X  REMOVAL    PE"  BOILER  FGD   C*P«
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR
1/60  A
      e
      SYSTEM
            88.0

            89.C

*• PROBLEMS/SOLUT10NS/COMHENTS
                                74.0
                                78.0
                                76.0
                                     74.0
                                     7?.C
                                     76.?
                                                        74.0
                                                        7S.O
                                                        76.0
                                               744
                                                     743
                                                            565
                          NO  MAJOR  FGD RELATED PROBLEMS WERE  REPORTED  FOR  JANUARY.
 2/80
       A
       B
       SYSTEM
            87.C
            92.0
            90.0
                               75.0
                               81.0
                               78.0
            78.0
            85.0
            82.0
                                                       69.0
                                                       75.0
                                                       72.0
                                                                               6<>6   642
                                                                                     501
          PROBLEHS/SOUUTIONS/COHHENTS
 3/80
A
B
STSTE"
                   93.0
                   94.0
                   94.0
                          IN  FEBRUARY, MIST ELIMINATOR N072LE  PLUGGING OCCURRED CAUSING SOME OUTAGE
                          TIME.
69.0
76.0
73.0
                                           69.0
                                           76.0
                                           73.0
                                                 15.0
                                                 16.0
                                                 16.0
                                                                               744
                                                                                     163
                                                                                             119
                                                  57

-------
EP* UTILITY F6C SURVEY: JANUARY - MARCH 198C


COLUMBUS 8 SOUTHERN OHIO ELEC.: CONESVILLE 6 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERAPHITY RELIABILITY UTILI?ATION  * REMOVAL   PcR  &OJLEP  FGD   C«F.
                                                                SO?  F««T. HOURS HOUCS  HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMWENTS

                         THE BOILER WENT DOWN ON MAPCH 9TH FOR A BOILEP/TURBIN£ INSPECTION AND
                         REMAINED DOWN THROUGH THE END OF THE MONTH.
                                                58

-------
                                              EPA UTILITY  FGD  SURVEY:  JANUARY - MARCH 1 9 fc '

                                            SFCTION  ;
               DESIGN AND PERFORMANCE  DATA F1R OPERATIONAL  DOMESTIC  FGD  SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 JM T NUMBER
 i ITT
 STATE
 &COSS  UNIT GENERATING  CAPACITY  - Mi,
 SET  UNIT GENERATING CAPACITY  Y/FGD  - »b
 tOu!VAL?NT SCRUBBED CAPACITY  -  MM

 • <  fUE L  DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT  -  J/G
     AVERAGE ASH CONTENT  - X
     AVERAGE MOISTURE  CONTENT  -  *
     AVE'A&E SULFU" CONTENT  -  X
     AVERAGE CHLORIDE  CONTENT  -  *

 * *  FGO  SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NE./RETROFIT
     ENERGY CONSUMPTION -  J
     INITIAL START-UP  DATE
     COMMERCIAL START-UP  DATE
     S02  DESIGN REMOVAL EFFICIENCY - 1
     PAKTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER  SPARE COMPONENTS INDEX
          LOOP
     TYPE
     fRESH MAKE-UP  WATER  - LITER/S

  • TREATMENT
     TYPE

  • DISPOSAL
     TYPE
                  COOPERATIVE POUE" ASSOCIATION
                  COAL CREEK
                  1
                  UND £ SfcOOD
                  NORTH  DAKOTA
                    5*5.:
                    4^5.:
                    327.:
COAL
LIGNITE
 14^6.
    7.u
   30.8!
     . i-
                                          ETU/LP)
                  yET SCRUPB1NG
                  LIMP/ALKALINE
                  COMLUSTION ENGINEERING
                  NEW
                   8/7"
                  t, * / * *
                     ?'.3C
                     9-5.50
                  OPEN
                  FLYASH STASILIJATION
                                                  LINED POND
	PERFORMANCE DATA	
PERIOD MODULE  AVAILABILITY OPERABJL1T1 RELIAPILITY  UTILIZATION  *  REMOVAL    PE»  BOILER  FGD    C«P.
                                                                  SO?   PART.  HOURS HOURS  HOURS FACTOR
 1/S?  SYSTEM                  1CP.O

       ** PROBLE»S/SOLUTIONSyCOMMENTS
                         96.1
                                                       715
                                                              715
                          DURING JANUARY  TWO  MODULES AT A TIME WERE  TAKEN  OFF-LINE FOR INSPECTION
                          AND CLEANING.   SOME  CRACKED NOZZLES AND  PLUGGAGE  WERE FOUND DURING THE
                          INSPECTION.

                          SOME OUTAGE TIME  DURING THE MONTH WAS  CAUSED  BY  BOILER RELATED PROBLEMS.
                          A BOILER TRIP WAS  CAUSED BY THE TURBINE.

                          AN HOUR OUTAGE  TIME  WAS NECESSARY DUE  TO  A  LOSS  OF  POWER TO THE CONTROL
                          SYSTEM.  ABNORMAL  DRUM LEVEL WAS ALSO  ENCOUNTERED.

                          A THREE TO  FOUR HOUR OUTAGE WAS SCHEDULED  TO  MAKE REPAIRS ON THE  EOUIPMFNT.

 2/80   SYSTEM                  100.0                     99.9                   696   695     695

        **  PROBLEMS/SOLUTIONS/COMMENTS

                          WHILE  THE BOILER  WAS OFF-LINE DUE TO  ID  FAN TROUBLE CAUSED  BY  ELECTRICAL
                          GROUNDING,  TWO  MODULES WERE TAKEN OFF  LINE SO CALIBRATIONS  COULD  BE  DONE.
 3/60   SYSTEM
100.0
                                                         96.1
                                                                                74*
                                                                                       715
                                                                                              715
                                                  59

-------
EPA UTILITY  FGD SU»VEY: JANUARY  -  MARCH 1980

COOPFRATIVE  POWER »SSOC1ATION: COAL  CREEK 1 tCONT.)
	p£RfORWANC?
PERIOD MODULE  AVAILABILITY OPE&APIL1TY  RELIABILITY UTU17AUON   *  REMOVAL   PE»  BOILER   fGD   C«P.
                                                                   <02   PART. HOURS HOUBS   HOURS FACTOR


       ** PROBLEWS/SOLUTIONS/COM^ENTS

                          THE BOILER  TRIPPED  THREE TIMES DURING  THE MONTH.  ONE TRIP  WAS  DUE  TO THE
                          CUT DOWN OF  TRANSMISSION POWER.

                          THE UNIT WAS DOWN  WITH THE BOILER  FOR  FOUR  HOURS TO CLEAN  THE  FILTER ON
                          THE STATOR  COOLING  PUMPS.

                          DURING MARCH STACK  EMISSION TESTS  HERE  RUN.  THE SYSTEM OPERATtD  WITH ONE
                          MODULE DOWN  DURING  TESTING.
                                                  60

-------
                                                 UTILITY FGD SURVEY:  JANUARY  -  MlfcCH
                                           SfCTlON I
               DESIGN  AND  PERFORMANCE DATA f Of OPERATIONAL DOMESTIC  F&D  SYSTEM?
COMPANY NAME
PLANT N«ME
JM T NUMBER
C ITY
STATE
GROSS UNIT GENERATING  CAPACITY  -  W*
NET UNIT GENERATING CAPACITY  W/FGD  -
EQUIVALENT SC"UPB?C CAPACITY  -  MW
                                                DUCUESNE  LIGHT
                                                ELK fcMA
                                                1-4
                                                ELR «"A
                                                PENNSYLVANIA
                                                   ST'.C
                                                   475.0
 ••  FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE  HEAT CONTENT - J/G
     AVERAGE  ASH CONTENT - *
     AVERAGE  MOISTURE  CONTENT - *
     AVERAGE  SULFUR CONTENT - X
     AVERAGE  CHLORIDE  CONTENT - *

 •«  F&D  SYSTEM
     GENERAL  PROCESS TYPE
     PROCESS  TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL  START-UP DATE
     COMMERCIAL  START-UP DATE
     SO?  DESIGN  REMOVAL EFFICIENCY - X
     P«RT1CULATE DESIGN REMOVAL EFFICIENCY  -
     ABSORBER SPAR? CAPACITY INDEX - X
     APSORBER SPARE COMPONENTS INDEX

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

 *«  TREATMENT
     TYPE

 ••  DISPOSAL
     TYPE
                                                COAL

                                                 244".;.
                                                   tl.CC
                                                MET SCRUPbING
                                                LIME
                                                CHEM1CO
                                                RETROFIT
                                                    3.5
                                                10/75
                                                1C/75
                                                    £7.30
                                                    •59.:o
                                                    35.C
                                                    1.?
                                                OPEN
                                 (  11J5C  ErTU/LP)
                                                POZ-0-TEC



                                                LANDFILL
                                                                <««.««
	...	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERAPILITY  RELIABILITY UTILISATION  x REMOVAL    PER   BOILER   FGD    CAP.
                                                                 SO?  PART.  HOURS  HOURS   HOURS  FACTOR
12/79





101
ZD1
301
401
5CM
SYSTEM
1CO.O
100.0
100. ?
P8.1
100.0
100.0
51.6
9C.9
10P.O
tf.t
100.0
1CO.C
1CO.C
100.0
96.1
8A.4
100.0
100.0
*?.5
85.5
10C.O
61.5
100.0
98.7





744 700 587
          PROBLEMS/SOLUTIONS/COMMENTS
       101
       2C1
       301
                   95.8
                   87.1
                   84.6
                          THERE  HAVE  BEEN NO SCRUBBER-RELATED OUTAGES  OVER  THE  SEPTEMBER  THRU
                          DECEWBE*  PERIOD.

                          THE  SLUDGE  IS NOW BEING TRUCKED TO A  REMOTE  SITE  10 MILES *WAY  CAUSING
                          OPERATING COSTS TO INCREASE.

                          THE  NEW S02 WONITOfi HAS PLUGGED ONLY  ONCE  SINCE  OCTOBEd AHD HAS REOU1REC
                          ONLY 4 HOURS OF MAINTENANCE PER WEEK.
 91.2
100.0
100.0
             94.8
                                            84.6
75.2
87.1
84.6
                                                 61

-------
EPA UTILITY  FGD  SU'VEt: JANUARY - MARCH  198C

DJQUfSNE LIGHT:  FLRAMA 1-4 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE  AVAI LAB I LIT» OPERAEILITY  RELIABILITY UTILIZATION
                                                                  TI  PEMOVAL    PER  BOILER   FGD    c»p.
                                                                  SO?   PART.  HOURS HOURS  HOURS  FACTOR
401
501
SYSTEM
86. 4
100.0
100. C
55.6 7?.1 45.?
100.0 ic:>.o 1CO.C
100. C 1C".C 9?. 2


744 613 528
       101
       201
       301
       401
       501
       SYSTEM
100.0
100.0
100.0
100. n
 77.6
100.0
 85.4
100.0
10C.C
1CO.C
 56.8
10P.C
100.0
100.C
1Cn.C
1CC.C
 64.0
100.C
 96.6
100.0
 7^.7
 4C.Z
 9?.0
                                                                                      493
                                                                                             427
       ** PR06LEWS/SOLUTIONS/COMPENTS
 3/80  SYSTEM
                          THE  S02 MONITOR IS  STILL  OPERATING WELL AND  HAS  LOGGED SIX MONTHS OF
                          OPERATION.  THE TWO  RUBBER  LINED WORMEN RECYCLE  PUMPS HAVE NOW LOGGED
                          14,000 HOURS AS OF  FEBRUARY  198C AND ARE STILL  OPERATING WITHOUT ANY
                          PROBLEMS.  THE HIGH  AVAILAPILITIES ARE DUE TO  THE  5TH MODULE BEING A TRUE
                          SPARE.

                          THE  S02 MONITOR IS  STILL  OPERATING WELL AND  HAS  LOGGED SIX MONTHS OF

                                                                                744
       •* PROBLtlS/SOLUTIONS/COMMENTS

                          NO  INFORMATION WAS  AVAILABLE FOR THE MONTH OF  MARCH,

-------
                                              EPA  UTILITY  FGD  SURVEY: JANUARY - PARCH 19fa:

                                            SECTION  3
               DESIGN «ND PERFORMANCE DATA  FOR  OPERATIONAL  DOMESTIC FGD SYSTEMS
 COMPANY  NAME
 PLANT SAME
 JNl T NU*B E P.
 CITY
 STATE
 GROSS UNIT GENERATING CAPACITY  - I" W
 SET  UNIT GENERATING CAPACITY W/FGD
 EQUIVALENT SCRUBBED CAPACITY -  MW
                                                DUGUESNE  LIGHT
                                                PHILLIPS
                                                1-6
                                                SOUTH  HEIGHT
                                                PENNSYLVANIA
                                                  4 . o. . 0
                                                  37T.CI
                                                  4 1 :. 0
 •*  FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - I
     AVERAGE SULFUR CONTENT - »
     AVERAGE CHLORIDE CONTENT - *
                                                COAL
                                                BITUMINOUS
                                                 Ztfc'j.
                                                   16. 27
                                                    <.D2
                                                    1 .92
                                         BTU/Lp)
>*  FGD  SYSTEM
    GENERAL PBOCE5S TYPE '
    PROCESS TYPE
    SYSTEM SUPPLIER
    NEw/RETROFIT
    ENERGY CONSUMPTION - X
    INITIAL START-UP DATE
    COMMERCIAL START-UP DATE
    S02 DESIGN REMOVAL EFFICIENCY - X
    PARTUULATE DESIGN REMOVAL EFFICIENCY  -  X
    ABSORBER SPAR? CAPACITY INDEX - X
    ABSORBER SPARC COMPONENTS INDEX

•«  WATER LOOP
    TYPE
    FRESH MAKE-UP MATES - LITES/S
                                                 WET SCfiUP&INt
                                                 LIME
                                                 CHEMICO
                                                 RETROFIT
                                                     ?.*
                                                  7/7'
                                                 * * / * *
                                                    b7.CC
                                                    99.00
                                                    1?.0
                                                      .6
                                                 OPEN
                                                                 <*•*«•
 •* TREATMENT
     TY PE
                                                 POZ-0-TEC
    DISPOSAL
     TYPE
                                                 LANDFILL
...	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERAEILITY  RELIABILITY UTILHATION  t  REMOVAL    °E»   BOILER   FGD   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR
12/70




101
201
3C1
401
SYSTE"

99
90
77
67
.0
.9
.7
.7
.1

10?
ior
100
7;
.c
.c
.c
.0
.c

1CC.
9°.
61.
6B.
^
0
6
?
r
•
10C.
90.
77.
67.
0
0
o
0
0




744 567 494
          PROBLEMS/SOLUTIONS/COMMENTS
       101
       201
       331
       401
       SYSTEM
                  98.1
                 100.0
                  97.6
                  73.9
                          PRESENTLY THE UTILITY HAS BEEN  ADDING  SOBIUM  ThlCSULFATE TO THE LIME TO
                          PREVENT SCALE FORMATION.  THIS  PROCESS  HAS  IMPROVED  SO? COLLECTION AS
                          MELL.

                          THE  SCRUBEER FAN HOUSING LINERS  ARE BEING  REPLACED.

                          THE  MECHANICAL COLLECTORS A9E BEING UPGRADED  TO IMPROVE THE QUALITY OF
                          THE  MET SLUDGE.
   .0
IjC.O
100.C
10?.0
 89. C
 98.0
10C.D
 9'.5
 73.9
  .0
93.3
99.0
9*.0
73.0
                                                                               744
                                                                                     6"4
                                                                                            536
                                                 63

-------
EPA UTILITY  FGC  SURVEY:  JANUARY - MARCH  198C

OJQUESME  LIGHT:  PHILLIPS  1-6  (CONT.)
PERIOD MODULE AVAILABILITY

i/60 1P1
2C1
301
401
SYSTEM

13.7
91.6,
8ft.?
94.?
71.4
OPERABIL ITY

17.3
1GP.C
1CO.O
1 j ? . C
79.3
RFLI AP1L ITY

17.7
91.7
S6.C1
94 . "•
71.4
UTILIZATION * REMOVAL PE° BCILER FGD C»P.
?o?
1T.7
91.7
84.6
9". 5
7".1
PART. HOURS HOURS HOURS FACTOR




t°6 551 488
       **  PROBLE-S/SOLUTIONS/COMMENTS

                          SODIUM  THIOSULFATE  ADDITION CONTINUED  THROUGH THE  FIRST GiUARTER  AND  THE
                          MIST  ELIMINATOR SCALING HAS bEE >'  SIGNIFICANTLY REDUCED.  ?07C-500C HOURS
                          OF  OPERATION HAVE BEEN  LOGGED WITHOUT  MIST ELIMINATOR  SCALE UP.   THE
                          UTILITY REPORTS THAT  $02 REMOVAL  EFFICIENCY HAS  IMPROVED ?X DUE  TO THIS
                          AS  WELL.   THt UTILITY  IS LOOKINC  INTO  THE  ADDITION  OF  SODIUM THIOSULFATF
                          AT  ELRAMA.

                          THE  FAN RUBBfcR LINE'S  HAVE  BEEN A  CONT1NUAL PROELEM.   TWO WILL BE REPLACED
                          WITH  INCONEL THF NEXT  TIME  THE RUBBER  LINERS FAIL.

                          THE  PHILLIPS F&D SYSTFM HAD A SYSTEM  AVAILABILITY  OF  71.&Jr  FOR THE YEAR
                          1979.

 3/8n  SYSTEM                                                                     744

       *•  PROBLEMS/SOLUTIONS/COMMENTS

                          NO  INFORMATION WAS  AVAILABLE FOR  THE MONTH OF MARCH.

-------
                                             EPA UTILITY FGD SURVEY: JANUARY - MARCH 19tr


                                           SECTION ?
               DESIGN  AND  PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC FGD SYSTEM*
 COMPANY  NAME
 PLANT  NAME

 JNIT  NUMBER
 CITY
 STATE
 GROSS  UNIT GENERATING  CAPACITY - M«
 NET  UNIT GENERATING  CAPACITY W/FGO - »W
 EQUIVALENT SCRUBBED  CAPACITY - Mw
INDIANAPOLIS POWFR & LIGHT
PETERSBURG
r

PETERSBU»G
INDI ANA
  512.?
  515.C
  532. 3
    FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE  HEAT CONTENT - J/G
     AVERAGE  ASH CONTENT - X
     AVERAGE  MOISTURE  CONTENT - If
     AVERAGE  SULFU" CONTENT - X
     AVERAGE  CHLORIDE  CONTENT - I
COAL
BITUMINOUS
 25C3*.
(  1"75C  PTU/LP)
    F&6 SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYP*
     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
WET SCRUPBING
LIMESTONE
AIR CORRECTION DIVISION,  UOP
NEW
    2.4
12/77
12/77
   tc.OC
   95.3C
      .6
 •* WATER LOOP
     TYPE

     FRESH MAKE-UP WATER - LITER/S
CLOSED
 •• TREATMENT

     TYPE


 •« DISPOSAL
     TYPE
POZ-O-TEC
                                                 LANDFILL
	PERFORMANCF  BATA	
PcRlOO MODULE AVAILABILITY OPE«AP1L1TY RELIABILITY  UTILIZATION
                 t  RfcHOVAL    PER   BOILER

                 S02   PART.  HOURS HOURS
                          FGD   CAP.

                          HOURS  FACTOR
 1/bO  SYSTEM


 i/80  SYSTEM


 3/6"  SYSTEM
                              744


                              694


                              744
          PROBLEMS/SOLUTIONS/COMMENTS
                         DURING  THE  FIRST  QUARTER  1980,  THE  ENTIRE  SCRUBBER PACKING BED WAS LOST
                         DUE  TO  EXCESSIVE  WEAR  OF  THE  NEOPRENE FOAM PACKING PALLS.  THESE ARE TO
                         BE  REPLACED IN  APRIL,  AT  WHICH  TINE THE  UNIT WILL BE TAKEN OFF LINE TO
                         ACCOMODATE  THE  REPAIR.

                         BYPASS  DAMPER  FAILURES  ALSO  OCCURRED AND ARE REPORTED TO BE A CONTINUAL
                         PROBLEM.  MODIFICATIONS WERE  MADE  TO THE GULLOTINE TYPE DAMPERS DURING
                         THE  PERIOD.
                                                 65

-------
 EPA  UTILITY FGO SURVEY: JANUARY  - MARCH 1980

                                             SFCTION  ?
                DESIGN AND  PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC FGD SYSTFMS
 COMPANY  NAME
 PLANT  NAME
 UNIT  NUMBER
 C ITY
 STATE
 GROSS  UNIT GENERATING CAPACITY  - My
 NET UNIT GENERATING CAPACITY  W/FGD  - «y
 EQUIVALENT SCPUPBED 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  -  *

 •*  FGD  SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEy/RETBOfIT
     ENERGY CONSUMPTION - I
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02  DESIGN HE"OVAL EFFICIENCY - I
     PARTKULATE  DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE COMPONENTS INDEX

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

 ** TREATMENT
     TYPE

 ** DISPOSAL
     TYPE
                                KANSAS CITY
                                HAW THORN
                                1
                                KANS9S CITY
                                MISSOURI
                                   9?.0
                                   J5.T
                                   91.9
                                COOL
                                BITUMINOUS
                                 227Q5.
                                   11 .CO
                                            POWER K  LIGHT
                                   (   9600 BTU/IP)
                                     .60
                                yET  SCRUPbING
                                LIME
                                COMBUSTION ENGINEERING
                                RETROFIT
                                    2.2
                                11/7?
                                * * / * *
                                   70.00
                                   59.00
                                CLOSED
                                               <**.»« GFP)
                                FLYASH  STABILIZATION
                                                  POND
	PERFORMANCE DATA	
PERIOD MODULE  AVAILABILITY OPERAPIL1TY RELIABILITY  UTILIZATION  T  &Ef>OVAL    PE«  BOILER  FGD    C»P.
                                                                  SO?   PART.  HOURS HOURS  HOURS  FACTOR
13/79
11
12
IT)
/79
SYSTEM
SYSTEM
SYSTEM
100
100
100
.0
.0
.0
10C.
100.
100.
0
0
0
91
38
9?
.0
.0
.3
744
720
744
677
274
6?4
677
274
684
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          THE FGD SYSTEM WAS  AVAILABLE  VIRTUALLY 100Z  Of  THE  TIME THE BOILER
                          OPERATED.  THE LOW  NOVEMBER  FIGURES ARE BUE  TO  A  406  HOUR  BOILER OUTAGE
                          CAUSED PY SUPERHEAT  TUBE  LEAKS AND A 4? HOUR OUTAGE  CAUSED PY ECONOMIZE'
                          LEAKS.
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM
100.0

100.0

100.0
100.0

100.0

100.0
 97.0

100.0

100.0
744

696

744
696

744
S92

696

744
                                                  66

-------
                                               EPA  UTILITY FGO SUfcVEl:  JANUARY - PARCH  196"

KANSAS CITT  POWtR  X LIGHT: HAWTHORN  3 KONT.)
	-PERFORMANCE DATA	
PERIOD MODULE  »VA]LAaiLITl  OPERAFILITH RFLIAP1LITV  UT1L17AT10N   t  B£l«OV*L   P£"   bOILER   FGO   C*P.
                                                                    SO'   PART. HOUPS  HOURS   HOURS FACTOR


       **  PROBIEWS/SOLUTIONS/COMMENTS

                           THE  FGD SYSTEM WAS  AVAILABLE 1O^X OF  THE  TIME THE BOILER OPERATED.  NO
                           PROBLEMS WERE ENCOUNTERED.

-------
 EPA  UTILITY  FGt>  SURVEY: JANUARY - MARCH 19?C

                                            SFCTION  3
                DESIGN AND PERFORMANCE DAT* FOR OPERATIONAL  DOMESTIC  FtD  SYSTEMS
COMPANY NAME
PLANT  NAME
UNIT NUMBER
C ITY
STATE
GROSS  UNIT GENERATING  CAPACITY  - MW
NET UNIT GENERATING  CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED  CAPACITY -  MW

•* FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HFAT  CONTENT  -  J/G
    AVERAGE ASH CONTENT  - x
    AVERAGE MOISTURE CONTENT -  *
    AVERAGE SULFU" CONTENT  - X
    AVERAGE CHLORIDE CONTENT -  X

•• FGO SYSTEM
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM SUPPLIER
    NEW/RETROFIT
    ENERGY CONSUMPTION  -  X
    INITJAL START-UP DATE
    COMMERCIAL START-UP  DATE
    S02 DESIGN REMOVAL  EFFICIENCY - X
    PARTICULATE DESIGN  REMOVAL  EFFICIENCY
    ABSORBER SPARF COMPONENTS INDEX

«• WATER LOOP
    TYPF
    FRESH hAKF-UP WATER - LITER/S

•• TREATMENT
    TYPE

•• DISPOSAL
    TYPE
                                            - X
                                                 KANSAS  CITY  POWER  K  LIGHT
                                                 HAWTHORN
                                                 4
                                                 KANSAS  CITY
                                                 MISSOURI
                                                     90.?

                                                     9C.O
COAL
BITUMINOUS
 22795.
   11.Co

     .6C
                                                                 (   9800  6TU/LB)
WET SC
LIME
COMbUSTION ENGINEERING
RETROFIT
    2.2
 8/72
* * / * *
   7T.OC
   99.OC
     .6
                                                 CLOSED
                                                                 (*****  6PM)
                                                 FLYA'H STABILIZATION
                                                 POND
...	.—.-	...—- —	..	PERFORMANCE DATA--	
PERIOD MODULE AVAILABILITY OPERAPHIM  RELIABILITY UTILIZATION  t REMOVAL    PER   BOILER   FGO   CAP.
                                                                 S02   PART.  HOURS  HOUPS   HOURS FACTOR
ID/79
11 /79
1Z/79
SYSTEM
SYSTEM
SYSTEM
100
100
too
.0
.0
.0
100.
100.

0
0

89
4C

.0
.0
.0
744
72C
744
662
2P8
r*
662
268
:
       •• PROBLEMS/SOLUTIONS/COMMENTS

                         THE UNIT  WENT  DOWN  ON NOVEMBER 26TH FOR A TURBINE  GENERATOR  OVERHAUL.

 1/8?  SYSTEM     100.0                                   .0                   744      C       0

 H/60  SYSTEM     10C.O                                   ,C                   696      C       0

 3/60  SYSTEM     100.0                                   .0                   744      C       0

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THE UNIT  REMAINED  OFF LINE THROUGH THE FIRST OUARTED  198C  BECAUSE  OF THE
                         TURBINE GENERATOR  OVERHAUL.
                                                 68

-------
                                              EPA  UTILITY F6D SURVEY: JANUARY  - MARCH  198?

                                            SECTION  3
               DESTGN *ND PERFORMANCE DAT/)  FOR  OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 JNIT NUMBER
 C ITY
 STATE
 GROSS  UNIT  GENERATING CAPACITY - Mw
 NET  UMT GENERATING CAPACITY U/FGD -  MW
 EQUIVALENT  SCRUBBED CAPACITY - My

 •*  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 - *

 •*  F6D SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM  SUPPLIES
     NEW/RETROFIT
     ENERGY  CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP D»TE
     S02  DESIGN »E"OVAL EFFICIENCY  -  Z
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER  SPARE COMPONENTS  INDEX

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

 ••  DISPOSAL
     TYPE
- X
KANSAS CITY POWE"
LA CYGNE
1
LA OGNE
KANSAS
  S74.0
  823.0
  874.0
                         LIGHT
     COAL
     SUBBITUMINOUS
      21913.
        24.36
         S.60
         5.39
          .0?
yET SCRUBBING
LIMESTONE
BABCOCK  f  UILCOX
NEW
    2.7
 2/7?
 6/7?
   S-.30
   99.50
      .6
     CLOSED
         72.3
                                                 UNLINED  POND
                (   9421  BTU/Lp)
                  iue
	.—.	.	PERFORMANCE  DATA —	
PERIOD MODULE IVAILABIL1TY  OPERABILITY RCLIARIL1TY UTILIZATION   X  REMOVAL   PER  BOILER   FGD    CAP.
                                                                  SO?  PART. HOURS HOURS   HOURS  FACTOR


 1/8C  SYSTEM                                                                  744

 2/8?  SYSTEM                                                                  606

 3/80  SYSTEM                                                                  744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION WAS AVAILABLE  FOR  THE FIRST QUARTER 19SO>
                                                  69

-------
 EPA  UTILITY FGO SU»VEYt JANUARY - MARCH  198C

                                             SECTION I
                DESIGN AND PERFORMANCE  DATA  fOR  OPERATIONAL DOMESTIC FGD SYSTEMS
  COMPANY  NAME
  PLANT  N»«E
  JN1T  NUMBER
  C ITY
  STATE
  SROSS  UNIT  GENERATING CAPACITY - M W
  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 - 1
     AVERAGE SULFUR  CONTENT - X
     AVERAGE CHLORIDE  CONTENT - T
KANSAS  POyER  &  LIGHT
JEF FREY
1
WAMEGO
KANSAS
  720.0
  6a:.o
  54D.O
COAL

 18899.
    5.80
   2«.00
     .52
     .01
                             E-TU/LB)
     FGD  SYSTEM
     GENERAL  PROCESS  TYPE
     PROCESS  TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION  -  X
     INITIAL  START-UP  DATE
     COMMERCIAL  START-UP DATE
     S02 DESIGN  REMOVAL  EFFICIENCY - x
     PARTICULATE DESIGN  REMOVAL  EFFICIENCY
     ABSORBER SPARC CAPACITY  INDEX - X
     ABSORBER SPARF COMPONENTS  INDEX
- X
WET SCRUBBING
LIMESTONE
COKeUSTION ENGINEERING
NEW
 8/7?
* * / * *
   to.co
   59.OC
   2C.O
    1.0
 •* WATER LOOP
     TYPE
     FRESH MAKE-UP WATE8  -  L1TER/S

 •* DISPOSAL
     TY PF.
CLCSFD
   35.1
POND
                     (  557  GFI")
	.	.	 — PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY  OPERAPILITY RELIABILITY UTILIZATION   *  REMOVAL   PER  BOILER  FGD    C«P.
                                                                  502   PART. HOURS HOURS  HOURS  FACTOR
 1/80  SYSTEM

 2/8"  SYSTEM

 3/E
       SYSTEM

       • • PROBL£MS/SOLUTIONS/COM!»ENTS
                              744

                              606

                              744
                          NO  MAJO»  PROBLEMS WERE ENCOUNTERED DURING  THE  FIRST QUARTER
                          INTAKE  MIXER MODIFICATIONS WERE PERFORMED.
                                             SOME
                                                 70

-------
                                              EPA UTILITY fGO SURVEY:  JANUARY  - HARCH 1060

                                            SECTION !
               DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC  FGD  SYSTEMS
COMPANY  NAME
PLANT  NAME
JMT NUMBER
CITY
STATE
S50SS  UNIT  GENERATJMG CAPACITY  -  M«
SET  UNIT GENERATING CAPACITY W/FGD  - Mt,
EQUIVALENT  SC»UPBED CAPACITY -  My

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

**  FGD SYSTE1
     GENERAL  PROCESS TYPE
     PROCESS  TYPF
     S»STEM  SUPPLIER
     NEW/RETROFIT
     ENE"G1  CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02  DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     APSORBER  SPARF CAPACITY  1NDFX - X
     ABSORBER  SPARF CO"PONENTS  INDEX

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

«•  TREATMENT
     TYPE

•*  DISPOSAL
     TYPE
                                                KANSAS POWER &  LIGHT
                                                LAWRENCE
                                                4
                                                LAWRENCE
                                                KANSAS
                                                  1 35.0
                                                  1 15.0
                                                  1 i5.0
COAL

 23Z6J.
    0.80
   12.::.
     .?5
     .03
                                                WET SCKUPbING
                                                LIMESTONE
                                                COMtUSTION  ENGINEERING
                                                RETROFIT
                                                                  1rOCC PTU/LP)
                                                 1/76
                                                * * / * *
                                                   73.00
                                             X     95.90
                                                      .->
                                                      .0
                                                CLOSED
                                                                <<•«.. GPM)
                                                 FORCED  OXIDATION
                                                  POND
	—	PERFORMANCE DATA	— • —	
PERIOD MODULE AVAILABILITY  OPERABILIT1 RELIABILITY  UTILIZATION  * REMOVAL    PER   BOILER  FGO   CAP.
                                                                  SO?  PART.  HOURS HOURS  HOURS FACTOR
1/80  SYSTEM                  100.0

2/8"  SYSTEM                  100.0

3/8P  SYSTE*                  100.0

      ** PROBLEMS/SOLUTIONS/COn«ENTS

                         NO MAJOR PROBLEMS
       1CT.3

       10C.3

       1CT.O
                                                                                744
                                                                                744
                                                                                      744

                                                                                      696

                                                                                      744
744

696

744
                                                  REPORTED TO HAVE BEEN  EXPERIENCED WITH THE
                          LAWRENCE 4 SCRUBBER  DURING THE FIRST QUARTER  19?:.
                                                  71

-------
 EP*  UTILITY FGD SURVEY: JANUARY  -  MARCH  1980

                                             SECTION 3
                OESTGN AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  JN1T  NUMBER
  CITY
  STATE
  GROSS  UNIT  GENERATING CAPACITY - MM
  NET UNIT  GENERATING CAPACITY W/FGD - MW
  EQUIVALENT  SCRUBBED CAPACITY - My

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

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

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

  •* TREATMENT
     TYPE

  •* DISPOSAL
     TYPE
   KANSAS  POWER  i.  LIGHT
   LAURENCE
   5
   LAURENCE
   KANS*S
     420.0
     400.0
     420.0
   COAL

    23260.         <  1^000
       9.80
      12.DO
        .55
        .03
   WET SCRUBBING
   LIMESTONE
   COMBUSTION ENGINEERING
   RETROFIT
   11/71
   * * / * *
      52.00
X     98.90
        .0
        .0
   CLOSED
   *** »•••
                   (**»»*  GPM)
   FORCED OXIDATION
   POND
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY  UTILIZATION   X REMOVAL   PER  BOILER   FGO    CAP.
                                                                  S02  PART. HOURS HOURS   HOURS  FACTOR
1/80
2/80
3/en
SYSTEM
SYSTEM
SYSTE*
IOC
100
100
.0
.0
.0
100
51
54
.0
.7
.8
744
606
744
744
340
4?E
744
360
4C8
       •• PROBLEMS/SOLUTIONS/COMMENTS
                          THE  LAWRENCE 5 SCRUBBER OPERATED  WITHOUT ANY MAJOR PROBLEMS DURING  THE
                          FIRST  QUARTER 1980.  THE BOILER WAS  DOWN FROM THE MIDDLE OF FEBRUARY  TO
                          THE  MIDDLE  OF MARCH FOR TURBINE REPAIRS, DURING WHICH TIME SCRUBBER
                          MAINTENANCE WAS PERFORMED.
                                                 72

-------
                                               EPA UTILITY FGD  SURVEY:  JANUARY - MARCH  1980

                                             SECTION 5
               DESIGN  AND  PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC  FGD SYSTEMS
 COMPANY NAME
 PLANT NAME
 JN]T NU"3ER
 C ITY
 STATE
 GROSS UNIT GENERATING  CAPACITY - M«
 MET UNIT GENERATING  CAPACITY U/FGD - MW
 EQUIVALENT SCRUBBED  CAPACITY - I»W
KENTUCKY UTILITIES
GREEN RIVER
1-3
CENTRAL  CITY
KENTUCKY
   64.0
   63.0
   t4.0
 •«  FUEL DAT«
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT - J/G
     AVERAGE ASH CONTENT - *
     AVERAGE MOISTURE  CONTENT - I
     AVERAGE SULFUR  CONTENT - J
     AVERAGE CHLORIDE  CONTENT - T
COAL
BITUMINOUS
   13. AC
   17.10
    4. CO
                <  11000 BTU/LH)
 •* FGD SYSTEM
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEb/RETPOF IT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL  ST»RT-UP DATE
     502 DESIGN  REMOVAL EFFICIENCY  -  X
     PARTICULATt DESIGN REMOVAL EFFICIENCY - I
     ABSORBER SPARE  CAPACITY INDEX  -  J;
     ABSORBER SPAR?  COMPONENTS  INDEX

 •* WATER LOOP
     TYPE                                         CLOSED
     FRESH MAKE-UP  WATER - LITER/S                   4.7

 ** DISPOSAL
     TYPE                                         LINED POND
WET SCRUBBING
LIME
AMERICAN  AIR  FILTER
RETROFIT

 9/75*
 6/76

    99*. 50
      .0
      .0
                <   75 GPM)
	... — _	.	...—.—PERFORMANCE  DATA--"—	
PERIOD MODULE  AVAILABILITY OPERAPILITY  RELIABILITY UT1L1?AT10N  I REMOVAL    PER   BOILER  FGD    c«P.
                                                                   SO?  PART.  HOURS HOURS  HOURS  FACTOR
1/60 SYSTEM
8/81 SYSTEM
3/80 SYSTEM
100.0
100.0
100.0
.0
.0
.0
744
696
744
C
r\
w
C
           PROBLEMS/SOLUTIONS/COMMENTS
                          THE  BOILER  REMAINED OUT  OF  SERVICE DUE TO BOILER  REPAIRS.
                          EXPECTED  TO BE OPERATING  IN ANOTHER MONTH.
                                                                                        THE UNIT  IS
                                                   73

-------
 EPA  UTILITY FGD  SUPVEY:  JAVUAR1 - MARCH  1980
                                              SECTION  3
                DESIGN  AND  PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC  FGO  SYSTEMS
  COMPAN1 NAME
  PLANT NAME
  UNIT NUM3ER
  C ITY
  STATE
  SROSS UNIT GENERATING  CAPACITY - MM
  NET  UNIT GENERATING CAPACITY  y/FGD -
  EQUIVALENT SCRUBBED CAPACITY  - MW
                                                  LOUISVILLE GAS 8 ELECTPK
                                                  CANE  RUN
                                                  4
                                                  LOUISVILLE
                                                  KENTUCKY
                                                    1 6 « . • j
                                                    1 75.0
                                                    1&R.D
  **  FUEL DATA
      FUEL  TUPE
      FUEL  GRADE
      AVERAGE HEAT CONTENT  -  J/G
      AVtKAGE ASH CONTENT - X
      AVERAGE MOISTURE CONTENT  -  *
      AVERAGE SULFU" CONTENT  -  ?
      AVERAGE CHLORIDE CONTENT  -  *

  **  F&D  SYSTEM
      GENERAL PROCESS TYPE
      PROCESS TYPF
      SYSTEM  SUPPLIER
      NEn/flETROFIT
      ENERGY  CONSUMPTION -  *
      INJT]AL START-UP DATE
      COMMERCIAL START-UP DATE
      soi DESI&N REMOVAL EFFICIENCY  -  ~i
      PARTICULATE  OFSIGN REMOVAL  EFFICIENCY
      APSORBER  SPARE  CAPACITY INDEX  -  X
      ABSORBER  SPARE  COMPONENTS INDEX

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

 •• DISPOSAL
      TYPE
                                                  COAL
                                                  BITUMINOUS
                                                   26749.
                                                     1*.1"
                                                      9.00
         (  115PC 6TU/L")
                                                 WET  SCRUPbING
                                                 LJ^E
                                                 AME KUAN  AIR  F 1 LTE R
                                                 RETRPFIT
                                                      1.«
                                                  S/ 76
                                                  5/77
                                                    t 5.CO
                                                    99.-C
                                                 OPEN
                                                     6.3
                                                 LINED POND
                                                                 <   100 CPI")
	.	PERFORMANCE DATA	.
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION   X  REMOVAL   PER  BOILER   FGD   CAP.
                                                                   SO?  PART. HOU15 HOURS   HOURS FACTOR
1/60  SYSTEM

2/8^  SYSTE*

J/fcn  SYSTEM
                               10P.O

                                99.8

                                8T.5
95.6

66.7

74.3
                                                                                744
                                                                                744
                                                                                       711
                                                                                      6»7
711

464

553
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          NO MAJOR OPERATIONAL PROBLEMS WERE  REPORTED  fOD THE FIRST QUARTER  1987
                          xITH EITHER  THE  BOILER OR THE FGD  SYSTEM.
                                                  74

-------
                                              EPA UTILITY fGO SURVEY: JANUARY  -  MARCH  196"

                                            SECTION 3
               OFSIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC FGD  SYSTFMS
 COMPANY  NAME
 PLANT  NAME
 JNIT NUMBER
 CITY
 STATE
 iROSS  UNIT  GENERATING CAPACITY  - MW
 MET  UNIT GENERATING CAPACITY W/FGD  -  MW
 EQUIVALENT  SCRUBBED CAPACITY -  MW

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

 •*  FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TIP?
     SYSTEM  SUPPLIER
     NEW/RETROFIT
     ENERGY  CONSUMPTION  - X
     INITIAL START-UP DATE
     COM»ERCIAL START-UP DATE
     SOc  DESIGN RE»OVAL  EFFICIENCY  - i
     PARTICULATE DFSIGN  REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY  INDEX  - J
     ABSORBER SPARF COMPONENTS  INDEX

 ••  WATER LOOP
     TYPF
     FRESH MAKF-UP  WATER - LITER/5

 •«  TREATMENT
     TYPE

 •*  DISPOSAL
     TYPE
LOUISVILLE G*S  R  ELECTRIC
CANE RUN
5
LOUISVILLE
KENTUCKY
  2C".0
  192.0
  2CO.O
                t  1150C  6TU/LP)
COAL
BITUMINOUS
 26749.
   17.10
    9.00
    *.75
     .04
WET SCRUPbING
LlM£
COMBUSTION  ENGINEERING
BETROF IT
    1.5
12/77
 7/7S
    &5.JC
      .0
 OPEN
                (**•** GPM)
POZ-0-TEC
                                                 LINED  POND
	PERFORMANCE  DATA-—	 —	
PERIOD MODULE AVAUAB1L1T1  OPERABU1TK RF.LIAPUITY  UTU17AT10N  X REMOVAL   PER   BOILER   FGD   C«P.
                                                                  SO?  PART. HOURS  HOURS   HOURS  FACTOR
 1/6C  SYSTEM                   92.1                     72.2                   744    5S3     537

       •• PROBIEMS/SOLUTIONS/COMMENTS

                          DURIN6 JANUARY NO  OPERATIONAL PROBLEMS WERE ENCOUNTERED.

 Z/fcC  SYSTEM                   71.9                     49.7                   696    4?1     346

 3/60  SYSTEM                   44.5                     27.2                   744    454     202

       «* PROELEWS/SOLUTIOXS/COHMENTS

                          IM FEBRUARY THE UTILITY  RAN  OUT OF CARBIDE LIME CAUSING  INTERRUPTION OF
                          THE FGD SYSTEM OPERATION.   THE UNAVAILABILITY  OF LIME  WAS  CAUSED PV FREF2E
                          UPS ENCOUNTERED BY AIRCO,  THE LIME SUPPLIER.

                          REHEATER TUBE PROBLEMS  WERE  ALSO ENCOUNTERED IN FEBRUARY  AND CONTINUED
                          THROUGH MARCH.  THE  UTILITY  HOPES TO REPLACE THE TUPE  BUNDLES  IN THE
                          SUMMER.

-------
 EP»  UTILITY  fGD SURVEY: JANUARY - MARCH  198C

                                             SECTION  3
                DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC fGD SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 UNIT  NUMBER
 CITY
 STATE
 GROSS  UNIT GENERATING CAPACITY - MM
 NET UNIT  GENERATING CAPACITY hl/FGD - >"W
 EQUIVALENT SCRUBBED CAPACITY - MW

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

 ••  FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TVPF
     SYSTEM SUPPLHR
     NEW/RETROFIT
     ENERGY CONSUMPTION  - I
     INITIAL START-UP  DATE
     COMMERCIAL ST«RT-UP DATE
     so? DESIGN RE»OVAL  EFFICIENCY - x
     PARTICULATE OfSIGN  REMOVAL EFFICIENCY
     ABSORBER SPARF  CAPACITY INDEX - X
     ABSORBER SPARE  COMPONENTS  INDEX

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

 *• DISPOSAL
     TYPE
- X
     LOUISVILLE  GAS  8 ELECTRIC
     CANE  RUN
     6
     LOUISVILLE
     KENTUCKY
        299.0
        277.9
        299.C
      COAL
      BITUMINOUS
      25596.         <  11000

         9.0C
         4.8C
           .C4
UET SCRUPLING
DUAL ALKALI
AOL/CO«*BUST10N EQUIP  ASSOCIATE
RETROFIT
    1.0
 1.1 79
* • / * *
   55. :o
   99. "0
   2:.o
     CLOSED
     LANDFILL
	.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERA8ILITY  RELIABILITY UTILIZATION  I  REMOVAL    PE"   BOILER   FGD   C'P.
                                                                 SO?   PART.  HOURS HOURS   HOURS FACTO*.
 1/80  SYSTEM                   49.0

       •• PROBLE^S/SOLUTIONS/COM^ENTS
            17.8
                                   744
                                    21C
                          FGD  SYSTEM  OUTAGE  TIME IN JANUARY WAS  CAUSED BY  THE  LOSS  OF  THE
                          THE  RAKE  WOULDN'T  TURN AND THE THICKENER HAD TO  BE CLEANED  OUT.
 J/8?  SYSTEM                   64.7

 3/80  SYSTEM                   70.0

       •• PROBIEMS/SOLUTIONS/COMMENTS
            47.0

            64. 5
696

744
                                    3P6

                                    6?6
                                                103
127

480
                         IN  FEBRUARY  AND  MARCH OUTAGE TI»l WAS CAUSED PY PROBLEMS  WITH  THE  RECYCLE
                         PUMPS.

-------
                                              EPA UTILITY FGD  SURVEY:  JANUARY - MARCH 1980

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

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

 •* FGO 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 - t
     PARTICULATE DESIGN  REMOVAL  EFFICIENCY
     ABSORBER  SPARE COMPONENTS INDEX

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

 •* TREATMENT
     TYPE

 •« DISPOSAL
     TYPE
                                           - X
                                                LOUISVILLE  GAS  &  ELECTRIC
                                                MILL CREEK
                                                3
                                                LOUISVILLE
                                                KENTUCKY
                                                  44?. 0
                                                  420.0
                                                  442.0
                                                COAL
                                                BITUMINOUS
                                                 26749.
                                                   11.50

                                                    3.75
                                                      .04
WET SCRUBBING
LIME
AMERICAN AIR FILTER
NEW
    1.6
 8/78
 3/79
   £5.00
   99.00
     .3
                < 115CC  f-TU/LP)
                                                 OPEN
                                                     9.4
                                                                (   15C GPf)
                                                 FLYASM/LIME  STABILIZATION
                                                  POND
.......	..	...	...... — ....—.....P£pf ORMANCE  DATA	
PERIOD MODULE AVAILABILITY  OPERABILITV RELIABILITY  UTILIZATION  X REMOVAL   PER   BOILED   FGD   C'P.
                                                                  SO?  PART. HOURS  MOU"S   HOURS FACTCB
1/80  SYSTEM

2/80  SYSTEM                   36.1

3/80  SYSTEM                   36.9

      *• PROBLEMS/SOLUTIONS/CONMENTS
                                                           .0

                                                         26.6

                                                         3C.6
                                                                                744
                                                                                744
                          THE UNIT CAME BACK  ON  LINE  ON FEBRUARY 1QTH AFTER  THE  TURBINE  OVE"HAUL
                          UORK UAS COMPLETED.

                          PROBLEMS ENCOUNTERED DURING FEBRUARY AND MARCH k]TH  THE  FGO  S>STt*
                          OPERATION INCLUDED  FROZEN  WATER LINES AND yORN GASKETS  "LOWING  1% THE
                          REHEATER FLANGES.
                                                  77

-------
 EPA UTILITY FGD SURVEY:  JANUARY - MARCH 198C

                                             SECTION  5
                DESIGN  AND  PERFORMANCE DATA FOB  OPERATIONAL DOMESTIC FGD SYSTEMS
  COMPANY NAME
  PLANT N«ME
  JNIT NUMBER
  CITY
  STATE
  GROSS UNIT GENERATING  CAPACITY  - M*
  'JET  UNIT GENERATING CAPACITY  W/FGD
  EQUIVALENT SCRUBBED CAPACITY  -  *W

  **  FUEL DAT*
      FUtL TYPE
      FUEL GR»DE
      AVERAGE HEAT CONTENT  -  J/6
      AVE°AGE ASM CONTENT - X
      AVERAGE MOISTURE CONTENT  -  t
      AVERAGE SULFUR CONTENT  -  X
      AVERAGE CHLORIDE CONTENT  -  f.
      LOUISVILLE GAS S. ELECTRIC
      PADDY'S  "UN
      6
      LOUISVILLE
      KENTUCKY
         7?.0
         67.0
         7?.0
      COAL
      BlTUWjNOUS
       36749.
         11.50

         2.50
                <  11500 PTU/LP)
     FGD  SYSTEM
      GENERAL PROCESS TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      HEW/RETROF]T
      ENERGY CONSUMPTION - X
      INITIAL START-UP DATE
      COMMERCIAL ST«RT-UP DATE
      SO?  DESIGN REMOVAL EFFICIENCY  -  X
      PARTICULATE  DESIGN RtlOVAL  EFFICIENCY
      ABSORBER SPARF CAPACITY INDEX  -  X
      Af-SORBER SPAR* COMPONENTS INDEX
- X
y£T SCRUPBING
LIME
COMBUSTION  ENGINEERING
RETROFIT
    3.9
 4/75
* * / * *
   Sti.OO
   99.10
     .3
     .0
    WATER  LOOP
      TYPE
      FRESH  MAKE-UP WATER
     CLOSED
         3.1
                <    50  GPM)
 ••  TREATMENT
     TYPE
     LIME STABILIZATION
 •* DISPOSAL
     TYPE
     POND
...	.—---.	..........	-.PERFORMANCE DATA	.-.—..-...—...._..._.	....—_	__
PERIOD MODULE  AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL    PER   BOILER  FGO   CAP.
                                                                  SO?  PART.  HOURS  HOURS  HOURS FACTOR
1/6^ SYSTEM
3/60 SYSTEM
3/BC SYSTEM
.0
.0
.0
744
696
744
0
0

0
0
0
       «« PROBLEMS/SOLUTIONS/COnMENTS
                          THIS UNIT DID NOT OPERATE  DURING THE FIRST BUARTER  1980  DUE TO A LACK OF
                          DEMAND.  THIS UNIT  IS  USED  AS  A  PEAKING UNIT AND WILL  BE  RETIRED SOMETIME
                          IN  1987.
                                                 78

-------
                                              EPA UTILITY FGD SURVEY: JANUARY  -  MARCH  19t'
               DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC FGO SYSTEMS
 COMPANY  NAME
 PLANT NAME
 UNIT NUMBER
 C ITY
 STATE
 GROSS UNIT GENERATING CAPACITY  - My
 N?T  UNIT GENERATING CAPACITY W/FGD -  MW
 EQUIVALENT SCRUBBED CAPACITY -  MW

 *•  FUEL  DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASM CONTENT - X
     AVERAGE MOISTURE CONTENT -  X
     AVERAGE SULFU" CONTENT - X
     AVERAGE CHLORIDE CONTENT -  X

 *•  FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL ST«RT-UP DATE
     S02  DESIGN REMOVAL EFFICIENCY  -  X
     PARTICULAR DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY  INDEX  -  X
     ABSORBER SPARE COMPONENTS  INDEX

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

 •*  DISPOSAL
     TYPE
                        POWER COOPERATIVE
                         YOUNG
                                           I   65CC  PTU/Lp)
                           MINSKOTA
                           MILTON R
                           2
                           CENTER
                           NORTH DAKOTA
                             44?. 0
                             4C2.0
                             4C5.?
               COAL
               LIGNITE
                15119.
                   6.5Q
                  3?.00
                    .70
                    .01
                           WET SCRUBBING
                           LIME/ALKALINE  FLYASH
                           AOL/COMBUSTION  EQUIP  ASSOCIATE
                           NEW
                               1.6
                            9/77
                            6/7R
                              o5.:o
                              99.tC
                            CLOSED
                               44.1
                                                 MINEFILL
                                              700 GPK)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  DURABILITY RELIABILITY UTILIZATION   X  REMOVAL   PER  BOILER  FGD    CAP.
                                                                  502  PART. HOURS HOURS  HOURS  FACTOR
1 /80 A
B
SYSTEM
67.7
67.7
7.1
10.5
.0
10.5 10.5
7.1
.0
7.1


7*4 504 27
       *• PROBLEMS/SOLUTIONS/COMMENTS
                          DURING JANUARY THE COLD WEATHER  CAUSED SOME FROZEN LINES AND  THE  BOOSTE"
                          FAN TO FREEZE.

                          A HIGH PERCENTAGE OF COARSE  SOLIDS  IN THE THICKENER CAUSED  SOME OUTAGE
                          TIME.   THE WARM GEAR ON THE  THICKENER ALSO BROKE CAUSING PROBLEMS.
       A
       B
       SYSTEM
.0
.0
.0
.0
.0
.C
.0
                                                                               696
                                                                                      696
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          THE PROBLEMS RELATED TO  THE  COLD  WEATHER CONTINUED THROUGH  FEBRUARY.
                          ICE ON THE BOOSTER  FAN HAD  TO  BE  MELTED.
                                                                            THE
                          THE SHAFT SLEEVES ON  SEVERAL  SPRAY RECYCLE PUMPS WERE  REPLACED.
                          THE GEAR REDUCER  FAILED  ON  THE  B-SIDE ABSORBER AGITATOR  CAUSING  PROBLEMS.
                                                  79

-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH  1980

1INNKOTA POWER COOPERATIVE: HILTON R. TOUNG ?  (CONT.)
.	_	.	.	— PERFORMANCE  DAT*	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X  REMOVAL    PER   BOILE"   FGD    CAp.
                                                                S02   PART.  HOURS  HOURS   HOURS  FACTOR


                         THE ISOLATION DAMPEP CHAINS BROKE DURING  THE  MONTH.

 3/8?  A           28.9        22.t                    22.6
       B           28.9         6.2                     #.2
       SYSTEM      28.9        28.8        28.?        2?.8                   744    743     107

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING "ARCH COLD WEATHER CONTINUED TO PE A  PROBLEM.

                         THE TOROUE SWITCHES ON THE ISOLATION DAMPERS  WERE  REPLACED.  THE  OAMPEK
                         PROBLEMS CAUSED THE BOOSTER FAN TO TRIP.

                         AN EXCESSIVE AMOUNT OF COARSE PARTICLES IN THE THICKENER CONTINUED TO  BF
                         A PROBLEM.  PLUGGED BLEED LINES FROM THE  ABSORBER  TO THE THICKENER WERE
                         ALSO ENCOUNTERED.

                         THE A-SIDE ABSORBER AGITATOR  EXPERIENCED  A PROBLEM WITH  THE ANCHOR BOLTS
                         SHEARING.

                         THE SHAFT SLEEVES ON THE SPRAY RECYCLE PUMPS  WOULD NOT HOLD THE PACKING
                         SO THEY HAD TO BE REPLACED IN MARCH.
                                               80

-------
                                              EPA UTILITY  FSD  SURVEY: JANUARY - MARCH 1980

                                           SECTION  3
               DESIGN AND PERFORMANCE DATA FOB OPERATIONAL  DOMESTIC  FGC SYSTEMS
 COMPANY  NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING CAPACITY - Mw
 NET UNIT GENERATING CAPACITY U/FGD - My
 EQUIVALENT SCRUBBED CAPACITY - MU

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

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

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

 **  DISPOSAL
     TYPE
- X
                     (  1843  BTU/L6)
     MONTANA POWER
     COLSTRIP
     1
     COLSTRiP
     MONTANA
       360.0
       332.0
       360.0
COAL
SUB6ITUMJNOUS
 20569.
    S.60
   23.90
     .77
     .01
WET SCRUBBING
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP  ASSOCIATE
NEW
    3.3
 9/75
11/75
   60.00
   99.50
   2D.O
     .5
     CLOSED
        23.3
                                                 POND
                     <   370  GPi")
....	.....—.....................—PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL    P£R   BOILER   FGD   C»F«
                                                                 S02  PART.  HOU"S  HOURS   HOURS  FACTOt
12/79  SYSTEM

 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                   74A

                                   711,

                                   696

                                   744
                          NO  INFORMATION WAS AVAILABLE FOP THE PE»lOD  OF  DECE'BEC  197" THROUGH
                          MARCH  1980.
                                                 81

-------
 EPA  UTILITY  FGD SUDVET: JANUARY - MARCH i9»c
                DESIGN AND PERFORMANCE DATA
                                            SECTION  3
                                            FOP OPERATIONAL
                                                            DOMESTIC  FGD  SYSTEMS
  COMPANY  NAI»F
  PLANT  NAME
  JNIT NUMBER
  CITY
  STATE
  GROSS  UNIT GENERATING  CAPACITY - MX
  NET UNIT  GENERATING  CAPACITY  U/FGD -
  EQUIVALENT SCRURB^D  CAPACITY  - I»W
  ••  FUEL  DATA
      FUEL  TYPE
      FUEL  GRADE
      AVERAGE HEAT
      AVERAGE
      AVEMGE
      AVERAGE
      AVERAGE
     CONTENT - J/G
ASH CONTENT - X
MOISTURE CONTENT - *
SULFU" CONTENT - X
CHLORIDE CONTENT - 5!
•*  FGD SYSTEM
    GENERAL PROCESS TYPE
    PROCESS TYpr
    SYSTEM SUPPLICR
    NE w/RETROFIT
    ENERGY CONSUMPTION - X
    INITIAL START-UP DATE
    COMMERCIAL START-UP DATE
    S0£  DESIGN REMOVAL EFFICIENCY - X
    P«STlCULATt  DESIGN REMOVAL EFFICIENCY
    A5SCR9ED  SP«RC CAPACITY INDEX - X
    AHSCRPER  5P«Rr CO"PONENTS INDEX

1 *  WATER  LOOP
    TYPf
    FRESH  MAKF-UP WATER - L I T£K/S

'•  DISPOSAL
    TYPE
                                    MONTANA POWER
                                    COLSTHIP
                                    2
                                    COLSTRIP
                                    MON TANA
                                      36?. 0
                                      332.0
                                      3tO.O
                                                CO«L
                                                SUBfclTUMjNOUS
                                                 255«9.
                                                    ?.6C
                                                   i3.90
                                                     .77
                                                     ."1
                                                 WET SCRUPBING
                                                           BTU/L?)
                                   ADL/COMBUSTION
                                   NEW
                                        '.3
                                    5/76
                                   10/76
                                      d^.OC
                                      99.50
                                      2C.O
                                         .5
                                                                EOUIP ASSOCIATE
                                                 CLOSED
                                                    23.3
                                                 POND
                                                                (   370 GPU)
         .	.......	.....—-PERFORMANCE  DATA	—	----- — — -.-_.	.
       MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   x  REMOVAL   PER  BOILER  FGD   CAP.
                                                                 SC2  PART. HOUBS HOURS  HOURS FACTOR
12/79  SYSTEM

 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM

       ••  PROBLEMS/SOLUTIONS/COMrENTS
                                                                744

                                                                744

                                                                696

                                                                744
                         NO INFORMATION HAS AVAILABLE FOR THE PERIOD  FROM  DECEMBER  1979 THROUGH
                         MARCH 198C.
                                                82

-------
                                              EPA  UTILITY  F6D  SURVEY: JANUARY - MARCH  1980

                                            SECTION  3
               DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY  NAME
 PLANT  N«ME
 JN1T NUMBER
 CITY
 STATE
 GROSS  UNIT GENERATING CAPACITY - Mw
 NET  UNIT GENERATING CAPACITY W/FGD - "to
 EQUIVALENT SCRUBBED CAPACITY - MW

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

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

 **  WATER LOOP
     TYPE
     FRESH MAKf-UP yATER - LITER/S

 «•  DISPOSAL
     TYRE
   NEVADA POWER
   REID GARDNER
   1
   MOAPA
   NEVADA
     125.0
     11?.0
     125.0
   COAL
   BITUMINOUS
    28959.
       9.30
       5.50
        .50
        .05
   WET SCRUBBING
   SODIUM CARBONATE
   ADL/COMBUSTION EQUIP  ASSOCIATE
   RETROFIT
<  12450 BTU/LB)
    4/74
   * * / * *
      9".00
X     97.00
   CLOSED
       9.8
                                                 LINED POND
                   (   155  6PM)
...	.	......	.	.....—.-PEPF OHMANCE DATA —	 —	
PERIOD MODULE AVAILABILITY  OP£RABIL1T» RELIABILITY UT1LI7AT10N  X  REMOVAL    PER   BOILER  FGD   CAP.
                                                                 S02   PART.  HOURS HOURS  HOURS FACTOR


 i/eo  SYSTEM     100.0        100.0       100.0       100.0                   7**   744    7*4

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER AND FGD SYSTEM OPERATED THE ENTIRE  MONTH WITH NO OUTAGES.

 2/8"  SYSTEM     100.0        100.0       100.0       100.0                   696   696    696

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING FEBRUARY, NO OUTAGES OCCURRED*

 3/80  SYSTEM      66.2         83.7        84.7         33.8                   744   30C    251

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE FIRST OF MARCH THE  FGo  SYSTEM  WAS OFF  LINE FOR A SCHEDULED
                         OVERHAUL.

                         THE  FGD UNIT HAS FORCED  DOWN ONCE  TO  REPAIR THE VENTURI PUMP  AND SIX OTHER
                         TIMES DUE TO LOW VENTURI FLOW.
                                                  83

-------
 EP»  UTILITY  fGO SURVEY: JANUARY - MARCH 1980

                                             SECTION  3
                OFSIGN AND PERFORMANCE DATA  FOR  OPERATIONAL  DOMESTIC  FGD SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  JN1T NUMBER
  C ITY
  STATE
  GROSS  UNIT GENERATING CAPACITY - MW
  NET UNIT  GENERATIVE  CAPACITY W/FGD - MW
  EQUIVALENT SCRUPBEO  CAPACITY - My
      NEVADA POWER
      REID GARDNER
      2
      MOAPA
      NEVADA
        125.0
        110.0
        125.0
 •*  FUEL  DATA
      FUEL TYPE
      FUEL GRADE
      AVERAGE HEAT  CONTENT  - J/G
      AVERAGE ASH CONTENT - Z
      AVERAGE MOISTURE  CONTENT - t
      AVERAGE SULFUR  CONTENT - X
      AVERAGE CHLORIDE  CONTENT - t
      COAL
      BITUMINOUS
       28959.
          9.00
          5.50
           .50
           .05
         (  12450  6TU/LB)
 •*  FGD  SYSTEM
     GENERAL  PROCESS  TYPE
     PROCESS  TYPF
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION  -  X
     INITIAL  START-UP DATE
     COMMERCIAL  START-UP DATE
     S02 DESIGN  REMOVAL  EFFICIENCY  - Z
     PARTICULATE OFSIGN  REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY  INDEX  - X
     ABSORBER SPARE COMPONENTS  INDEX

 •* WATER LOOP
     TYPE
     FRESH MAKE-OP WATER - LITER/S
      WET  SCRUBBING
      SODIUM  CARBONATE
      AOL/COMBUSTION  EQUIP ASSOCIATE
      RETROFIT
      4/74
      **/ •»
         90.00
  X      97.00
           .0
            r\
     CLOSED
         9.8
         <  155 GPM)
 •* DISPOSAL
     TYPE
     LINED  POND
	..... — ...	PERFORMANCE DATA — ———— — —— ——....	...	_„_
PERIOD MODULE AVAILABILITY  OPERAPILITY  RELIABILITY UTILIZATION  t REMOVAL   PER  BOILER   FGD    CAP.
                                                                 SO?  PART. HOURS HOURS   HOURS  FACTOR
 1/80  SYSTEM      97.3         96.9

       ** PROBLEMS/SOLUTIONS/COMMENTS
96.9
81.6
744
                                         637
                                                607
                         DURING JANUARY  THE  SCRUBBER WENT OFF LINE WITH THE BOILER TO REPLACE  THE
                         REBUILT NO.  2 HIGH  PRESSURE HEATER.  THIS OUTAGE LASTED APPROXIMATELY
                         112 HOURS.

                         REPAIRS WERE NEEDED  ON  THE  LEFT HAND INTERCEPT VALVE ON THE TURBINE CAUSING
                         THE SCRUBBER TO  COME  OFF  LINE  WITH THE BOILER.

                         THE CLEANING OF  THE  VENTURI RACE TRACK NOZZLES CAUSED TWO SCRUBBER OUTAGES.

                         THE SCRUBBER WENT OFF  LINE  SO  MAINTENANCE COULD BE DONE ON THE ID FAN
                         DAMPER CONTROLS.
 2/80  SYSTEM      97.P        97.0

       **  PROBLEMS/SOLUTIONS/COMMENTS
                                            97.0
                                                        97.0
                                                                              696
                                         696
                                                675
                         THE SCRUBBER WAS TAKEN  OFF-LINE  TWICE  DURING FEBRUARY DUE TO A MALFUNCTION
                         OF THE ID FAN CONTROLS.   THE  PRESSURE  SENSING LINES WERE ALSO CLEANED
                         DURING THE OUTAGE.

                         THE SCRUBBER RACE TRACK  NOZZLES  HAD  TO BE  CLEANED TWICE, CAUSING APPROX-
                                                84

-------
                                             EPA UTILITY FGD SURVEY: JANUARY  - MARCH  198?
NEVADA POWER: REID GARDNER 2 (CONT.)
..	..—.	..—-PERFORMANCE DATA—	——
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER   BOILER   FGD    C«P
                                                                502   PART. HOURS  HOURS   HOURS
                         IRATELY 4 HOURS OUTAGE TIME.
                         THE DISCHARGE VALUE ON THE  VENTUR1  RECYCLE  PUMP WAS REPLACED  DURING
                         FEBRUARY.
                         REPAIRS WERE HADE ON THE SCHURBER  EMERGENCY  SPRAY LINE  CAUSING  ABOUT  4
                         HOURS OUTAGE TIME.
                         THE SCRUBBER HAD TO BE SHUT DOWN SO REPAIRS  ON THE  ID  FAN  DAMPER CONTROLS
                         COULD BE MADE.
 3/80  SYSTEM      97.5        97.5        97.5         97.5                  74*    744     725
       «* PROBLEMS/SOLUTIONS/COMMENTS
                         DURING MARCH THE SCRUBBER bAS  TAKEN OFF  LINE DUE  TO NO  EMERGENCY SPRAY.
                         DURING THIS TIME MAINTENANCE WAS DONE  ON THE A AND  P  ASH SLUICE PUMPS.
                         LATER IN THE MONTH  AN OUTAGE WAS CAUSED  BY  A LEAK  IN  THE EMERGENCY SPRAY
                         LINE.
                         LOU VENTURI FLOW ALSO WAS A PROBLEM DURING  MARCH.
                                                 85

-------
 EPA UTILITY FGD SU"VEY:  JANUARY  -MARCH 1980
                                             SECTION 3
                DESIGN  AND  PERFORMANCE  DATA  fOR OPERATIONAL DOMESTIC fGO
  COMPANY NAME
  PLANT NAME
  JNIT NUMBER
  CITY
  STATE
  GROSS UNIT GENERATING CAPACITY  - MU
  SET  UNIT GENERATING CAPACITY W/FGD - Mw
  EQUIVALENT SCRUBBED CAPACITY -  MW

  ••  FUEL DATA
      FUEL T»PE
      FUEL GR«OF
      AVERAGE  HEAT CONTENT - J/G
      AVERAGE  ASH CONTENT - X
      AVERAGE  MOISTURE CONTENT -  t
      AVERAGE  SULFUR CONTENT - X
      AVERAGE  CHLORIDE CONTENT -  *

  ••  FGD  SYSTEM
      GENERAL  PROCESS  TYPE
      PROCESS  TYPF
      SYSTEM  SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION  - X
      INITIAL  START-UP DATE
      COMMERCIAL  START-UP  DATE
      S02  DESIGN  REMOVAL  EFFICIENCY  - X
      PARTICIPATE  DESIGN  REMOVAL  EFFICIENCY
      ABSORBER  SPARE CAPACITY  INDEX  - X
      ABSORBER  SPARE COMPONENTS  INDEX

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

 •• DISPOSAL
      TYPE
                  NEVADA POyER
                  REID GARDNER
                  3
                  MOAPA
                  NEVADA
                    125. 0
                    II"1.G
                    1c5.9
                  COAL
                  BITUMINOUS
                   28959.
                      S.3C
                      9.0C
                       .50
                       .05
                  WET  SCRUBBING
                  SODIUM  CARBONATE
                  AOL/COMBUSTION EQUIP ASSOCIATE
                  NEW
                                                                < 1245C BTU/LR)
                   6/76
                   7/76
                     85.00
              Z      99.00
                       .0
                       .0
                  CLOSED
                      9.8
                  LINED  POND
                                                                (   155  GPM)
......—.................—-—.-. ————PERFORMANCE DATA	———	—	.......—
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL    PER  BOILER  FGD   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM      100.0         99.7

       *• PROBUKS/SOLUTIONS/COMMENTS
           100.0
                                                       91.3
                                               744
                                                     681
                                                            679
                          DURING JANUARY THE SCRUBBER AND BOILER WERE  OFF  LINE  FOR  APPROXIMATELY
                          64  HOURS  TO REPAIR AND BALANCE THE BOILER  ID  FAN.
                                                                               696
                                                     552
                                                                                            542
2/80  SYSTEM      78.8         9S.2         77.9        77.9

      ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING FEBRUARY TWO OUTAGES WERE NECESSARY SO  THE  ID  FAN  COULD  BE  BALANCED.

                         THE  SCRUBBER AND BOILER WENT OFF LINE SO THAT  THE  COAL  LEAKS  ON THE
                         BURNER LINES COULD BE REPAIRED.
                         HIGH  FURNACE  PRESSURE CAUSED THE SCRUBBER AND BOILER  TO  TRIP  OFF.
 3/80  SYSTEM
                   60.3
99.7
            «9.7
                                                        60.2
                                                                               744
                                                                                    450
                                                            448
       «• PROBLEMS/SOLUTIONS/COMMENTS
                          THE  UNIT  AND  SCRUBBER  WENT DOWN TWICE DURING MARCH.  THE  FIRST  OUTAGE  WAS
                          TO BALANCE  THE  ID  IAN.  LATER IN THE MONTH THE ID FANS  AND  THE
                          PRECIPITATORS HAD  TO BE REPAIRED.
                                                 86

-------
                                              EPA  UTILITY F6D SURVEY: JANUARY - MARCH  1980

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

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

 ** FGO SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     SO? DESIGN REMOVAL EFFICIENCY  -  X
     P«RTICULAT£ DfSIGN REMOVAL  EFFICIENCY
     ABSORBER SPAR* CAPACITY INDEX  -  X
     ABSORBER SPARE COMPONENTS  INDEX

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

 •* BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
NORTHERN INDIANA PUB  SERVICE
DEAN H. MITCHELL
11
GARY
INDIANA
  115.0
   78.0
  115.0
COAL
*** * * *
 25586.

   11.00
    3.50
WET SCRUBBING
WELLMAN LORD
DAVY POWERGAS
RETROFIT
   27.8
 7/76
 6/77
   93.00
   9S.5C
     .0
     .0
CLOSED
(  11000 BTU/LB)
                <*.*•*  GPM)
ELEMENTAL  SULFUR
.	_—.	—..—.—.	PERFORMANCE DATA	-—	
PERIOD MODULE AVAILABILITY OPERABIL1TY  RELIABILITY UTILIZATION  X  REMOVAL    PER   BOILER  FGD   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR

12/79  SYSTEM                                                                  744

 1/80  SYSTEM                                                                  744

 2/80  SYSTEM                                                                  696

 3/80  SYSTEM                                                                  744

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION WAS AVAILABLE IRON DECEMBER  1979 THROUGH MARCH 1980.
                                                 87

-------
 EPA UTILITY r&t> SURVEY: JANUARY - MARCH 1980

                                            SECTION  3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC  FGO  SYSTEMS
  COMPANY  NAME
  PLANT NAME
  UNIT NUMBER
  CITT
  STATE
  GROSS UNIT GENERATING CAPACITY - MM
  NET  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

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

  •• HATER  LOOP
      TYPE
      FRESH MAKE-UP WATER  - LITER/S
- X
     NORTHERN  STATES  POWER
     SHERBURNE
     1
     BECKER
     MINNESOTA
       743.0
       700.0
       740.0
                     <  8500  BTU/LB)
COAL
SU8BITUMINOUS
 19771.
    9.00
   25.00
     .80
     .03
WET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
    2.7
 3/76
 5/76
   SO.00
   99.00
    8.0
     .9
     CLOSED
     *******
                    (***** 6PM)
  '• TREATMENT
     TYPE

  '* DISPOSAL
     TYPE
     FORCED OXIDATION
                                                 LINED POND
	—————————————	—PERFORMANCE  DATA————	—	———.....
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
97.0
97.0
98.0
74* 793
696 687
744 688
       ** PROBLEMS/SOLUTIONS/COMHENTS
                         DURING THE FIRST QUARTER,  1960  NO  MAJOR  PROBLEMS  HERE  ENCOUNTERED WITH
                         THE F6D UNIT.

                         FROM MID-SEPTEMBER TO MID-OCTOBER  THE  UTILITY  HAS SCHEDULED A BOILER
                         OUTAGE IN WHICH TIME THE MARBLE BEDS WILL BE INSPECTED.
                                                88

-------
                                             EPA UTILITY F6D SURVEY: JANUARY  - MARCH  1980

                                           SECTION 3
               DESIEN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD  SYSTFHS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING CAPACITY - MM
 NET UNIT GENERATING CAPACITY U/FGD - MW
 EQUIVALENT SCRUBBED CAPACITY - MU

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

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

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

 •* TREATMENT
     TYPE

 •• DISPOSAL
     TYPE
- X
     NORTHERN STATES POWER
     SHERBURNE
     2
     BECKER
     MINNESOTA
       740.0
       700.0
       70.0
                    <  8500 BTU/LB)
COAL
SUBBITUMINOUS
 19771.
    9.00
   25.00
     .80
     .03
UET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
    2.7
 4/77
 4/77
   53.00
   99.00
    8.0
     .9
     OPEN
                     (***»* 6PM)
     FORCED OXIDATION
                                                LINED  POND
..	_	.	—PERFORMANCE  DATA—	
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY  UTILIZATION   X  REMOVAL   PER  BOILER  FGD   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
97.0
96.0
98.0
744 744
696 696
744 744
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         DURING THE  FIRST QUARTER,  1980 THE  FGD SYSTEM EXPERIENCED NO MAJOR
                         PROBLEMS.

                         A FOUR MEEK BOILER  OUTAGE  IS  SCHEDULED FOR MAY IN WHICH TIME THE MARBLE
                         BEDS HILL BE  REMOVED  FROM  THE FGD UNIT.
                                                 89

-------
 EPA  UTILITY FGD SURVEY: JANUARY - MARCH 1980
                                            SECTION  3
                DESIGN AND PERFORMANCE DATA FOR  OPERATIONAL  DOMESTIC  FGD
  COMPANY  NAME
  PLANT  NAME
  JN1T NUMBER
  CITY
  STATE
  GROSS  UNIT GENERATING CAPACITY - My
  NET  UNIT  GENERATING CAPACITY U/FGD - MU
  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

  **  F6D SYSTEM
      GENERAL PROCESS TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION  - X
      INITIAL START-UP DATE
      COMMERCIAL  START-UP DATE
      S02 DESIGN  REMOVAL  EFFICIENCY - X
      PARTICULATE DESIGN  REMOVAL EFFICIENCY
      ABSORBER SPARE  COMPONENTS  INDEX

 *• WATER LOOP
      TYPE
      FRESH MAKE-UP WATER -  L1TER/S

 •• DISPOSAL
      TYPE
- X
      PACIFIC  POKER  8  LIGHT
      JIM  BRIDGER
      4
      ROCK  SPRINGS
      WYOMING
        550.0
        507.8
        550.0
                     (   9300  BTU/LB)
COAL
SUBBITUMlNOUS
 21632.
    '.00
   18.00
     .56
     .01
MET SCRUBBING
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
NEU
     .2
 9/79
 2/80
   91.00
   99.00
     .9
     CLOSED
     *******
     POND
                    <***•* GPM)
........	...	...	.	-.PERFORMANCE DAT*	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION
                     X REMOVAL   PER  BOILER   FGD    CAP.
                     S02  PART. HOURS HOURS   HOURS  FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM

       •• PROBLEMS/SOLUTIONS/COHMENTS
                                  744

                                  696

                                  744
                         THE UNIT  IS STILL  IN  THE  SHAKEDOWN PHASE.  A NUMBER OF MECHANICAL PR08LFMS
                         AND SOME  CONTROL PROBLEMS HAVE  BEEN ENCOUNTERED.
                                                90

-------
                                             EPA  UTILITY  fGD SURVEY: JANUARY - MARCH 1980

                                           SECTION  2
              DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC fGo SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY  - HW
NET UNIT GENERATING CAPACITY W/FGD -  Mb
EQUIVALENT SCRUBBED CAPACITY -  MH
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
SHIPP1NGPORT
PENNSYLVANIA
  917.0
  825.0
  917.D
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
» u c o 4 r c ruinpTnc rnuTcuT — v
A V t N A u C LMLv/nlUt 1 DN 1 C N 1 ~ A
• * FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP BATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X

COAL
BITUMINOUS
26749. 1 11500 BTU/LB)
12.90
7.00
3.00

UET SCRUBBING
LIME
CHEMICO
NEW
6.0
12/75
6/76
92.10
PARTICULAR DESIGN REMOVAL EFFICIENCY - X 99.80
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
«» WATER LOOP
TYPE
FRESH MAKF-UP HATER - LITER/S
•• TREATMENT
TYPE
** DISPOSAL
TYPE
PERIOD MODULE AVAILABILITY OPERABILITv
1/8C SYSTEM 98.6 100.0
2/80 SYSTEM 98.1 100.0
.0
.0

OPEN
******* (***** GPM)

CALCILOX

LANDFILL
RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
90.* 74* 672 672
93.7 696 652 652
       **  PROBLEMS/SOLUTIONS/COMMENTS

                         NO MAJOR FGD RELATED PROBLEMS OCCURRED  DURING JANUARY AND FEBRUARY.

3/80   SYSTEM       98.8        100.0                    83.7                   7**   623    623

       •*  PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER HAS OUT ONE WEEK IN MARCH  DUE  TO A PLUGGED AIR PREHEATER. NO
                         MAJOR FGD RELATED PROBLEMS WERE  REPORTED  FOR MARCH.
                                                 91

-------
 EPA  UTILITY  FGD  SURVEY:  JANUARY - MARCH 198C


                                            SECTION 3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  JNIT NUMBER
  CITY
  STATE
  GROSS  UNIT 6ENERATING  CAPACITY  - My
  NET  UNIT  GENERATING  CAPACITY  W/FGD  -  MU
  EQUIVALENT SCRUBBED  CAPACITY  -  Mw

  **  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

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

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

  •• TREATMENT
      TYPE

 •• DISPOSAL
     TYPE
- X
     PENNSYLVANIA POhER
     BRUCE MANSFIELD
     2
     SHIPPINGPORT
     PENNSYLVANIA
       917.0
       835.0
       917.0
     COAL
     BITUMINOUS
      26719.
        1?.90
         7.00
         3.00
WET SCRUBBING
LIME
CHEMICO
NEU
    6.0
 7/77
• */ »•

   92.10
   99.80
     .0
     OPEN
     •***«**
     CALCILOX



     LANDFILL
               ( 11500 BTU/LB)
                    ****** GPM)
	.	.	.............	-PERFORMANCE DATA	—	—	_
PERIOD NODULE 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

 3/80  SYSTEM      94.7       100.0                    99.8                  696   694    694

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGD SYSTEM EXPERIENCED NO MAJOR PROBLEMS DURING JANUARY AND  FEBRUARY.

 3/80  SYSTEM      98.4       100.0                    83.7                  744   380    380


       ** PROBLEMS/SOLUTIONS/COMMENTS


                         THE BOILER HAS OUT 16 DAYS IN MARCH FOR A SCHEDULED BOILER INSPECTION.
                         NO MAJOR FGD RELATED PROBLEMS HERE REPORTED.
                                                92

-------
                                             EPA  UTILITY  FGO SURVEY: JANUARY - MARCH 1980


                                           SECTION  3
               DESIGN  AND  PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 JN1T NUMBER
 CITY
 STATE
 GROSS  UNIT  GENERATING  CAPACITY  - MW
 NET UNIT GENERATING  CAPACITY  W/FGD  - My
 EQUIVALENT  SCRUBBED  CAPACITY  -  WW

 •*  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  -  *

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

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

 *•  BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
PHILADELPHIA
EDDHSTONE
1A
EDDYSTONE
PENNSYLVANIA
  130.0
  1 20.0
  120.0
COAL
BITUMINOUS
 31634.
    9.40
    5.90
    Z.60
ELECTRIC
  ( 13600 BTU/LR)
WET SCRUBBING
MAGNESIUM OXIDE
UNITED ENGINEERS
RETROFIT
 9/75
 9/75
    93.00
    99.00
      .0
      .0
OPEN
     8.3
 SULFURIC  ACID
                       GPM)
...	.	...	..	....... — __.._.-. —.-PER f ORM AN CE DATA—	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                 *  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
                         THE BOILER AND  TURBINE  WERE  DOWN  DURING THE FIRST QUARTER 1980 FOR TURBINE
                         MAINTENANCE.


                         OPERATION OF THIS  PROTOTYPE  MAGNESIUM OXIDE SYSTEM, WHICH TREATED ONE
                         THIRD  OF THE FLUE  GAS  FROM  THE  EDDVSTONE 1 BOILER, HAS BEEN TERMINATED*
                         THE S02 REMOVAL EQUIPMENT  IS PRESENTLY BEING REPLACED WITH A SIMILAR
                         NAG-OX SYSTEM  DESIGNED  TO  TREAT 100X OF THE BOILER FLUE GAS.  THE EXPECTED
                         START  DATE OF  THIS SYSTEM  IS DECEMBER 1982.  CURRENT REGULATIONS DO NOT
                         REQUIRE CONTROL OF SO?  EMISSIONS  UNTIL THE NEW SCRUBBER IS AVAILABLE
                         FOR OPERATION.
                                                 93

-------
 EPA  UTILITY FGD  SU»VEY: JANUARY - MARCH 1980

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


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

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

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


  ** BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
                                     - X
                                           PUBLIC  SERVICE  OF  N£W  MEXICO
                                           SAN  JUAN
                                           1
                                           WAT£»FLOW
                                           NEW  MEXICO
                                             361.0
                                             314.0
                                             361.0
                                           COAL
                                           SUBBITUMINOUS
                                           22795.
                                              1S.30
                                              U.82
                                                .80
                                                .03
                               WET SCRUBBING
                               WELLMAN LORD
                               DAVY POWERGAS
                               RETROFIT
                                   4.4
                                4/73
                               ** / * *
                                  90.00
                                  99.80
                                  35.0
                                   1.0
                                          CLOSED
                                             30.2
                                              <  9800 BTU/LP)
                                              (  480 GPM)
                                          ELEMENTAL SULFUR
                                          MARKETED
...	.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION
                                                          x REMOVAL   PER  BOILER   FGD    CIP.
                                                          S02  PART. HOURS HOURS   HOURS  FACTOR
 1/80
 2/80
 3/80
A
B
C
D
SYSTEM

A
B
C
D
SYSTEM

A
B
C
D
SYSTEM
 81.0
 96.0
   .P
 83.0
 87.C

   .0
 99.0
  3.0
 99.0
 67.0

   .0
100.0
 83.0
 97.0
 93.0
51.0
42.0
  ,C
79.0
57.0

  .0
94.0
 3.0
98.C
65.0

  .0
50.0
83.0
85.0
73.0
       .«  PROBLEMS/SOLUT10NS/COHMENTS
42.0
35.0
  .0
65.0
47.0

  .0
86.0
 2.0
8".0
59.0

  .0
18.0
29.0
30.0
26.0
                                                                              744   610
                                                                              696   634
                                                                              74*
                                                                                    262
                                                                                           351
                                                                                           411
                                                                                           191
                         SCRUBBER OPERATIONS AT UNIT  ONE  ARE  STILL  LIMITED TO TWO MODULES BECAUSE
                         OF A LACK OF REHEAT.
                                                94

-------
                                              EPA UTILITY FGD SURVEY: JANUARY  -  MARCH  1980

                                            SECTION 3
               DFSIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC FGD  SYSTEMS
 COMPANY  NAME
 PLANT NAME
 JNlT NUMBER
 C ITY
 STATE
 5ROSS UNIT GENERATING CAPACITY  - Mw
 NET UNIT GENERATING CAPACITY W/FGD -  Mw
 EQUIVALENT SCRUBBED CAPACITY -  MW

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

 *«  FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPF
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     SO? DESIGN REMOVAL EFFICIENCY  -  X
     PARTICULATE DFSIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY  INDEX  -  X
     ABSORBER SPARE COMPONENTS  INDEX

 **  WATER LOOP
     TYPE
     FRESH MAKE-UP  WATER - L1TER/S

 •*  BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
                                          PUBLIC  SERVICE  OF NEW MEXICO
                                          SAN  JUAN
                                     -  X
                                          WAT CR
                                          NEW  MEXICO
                                            35'.0
                                            3:6.:
                                            351.0
                                          COAL
                                          SUBblTUMTNOUS
                                           2279i.
                                             ip.no
                                             14.82
                                               .80
                                               .03
                             WET  SCRUPBING
                             WELLMAN  LORI>
                             DAVY  POWF.RGAS
                             RETROFIT
                                  4.6
                               8/78
                             * * / * *
                                 91.00
                                 99.50
                                 33.0
                                  1.0
                                          CLOSED
                                             30.2
                                             <   9800 BTU/LO)
                                             <  48C GPIO
                                          ELEMENTAL SULFUR
                                          MARKETED
_.	_	-	...	....	_ — ..	— PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERAPILITY RELIABILITY UTILIZATION
 2/80
 3/80
E
F
G
H
SYSTEM

E
f
G
H
SYSTEM
97.0
22.0
  .0
  .0
40.0

87.0
85.0
  .0
  .0
57.0
66.0
 2.0
  .0
  .0
23.0

  .0
94.0
  .0
  .0
31.C
       **  PROBLEMS/SOLUTIONS/COMMENTS
                                                                  X  REMOVAL   PE»  BOILER   FGD    C«P.
                                                                  SO?  PART. HOURS HOURS   HOURS  FACTOR
„ E
F
G
H
SYSTEM
92.0
.C
.0
.0
31.0
63.0
.0
.0
.0
21. C
62.0
.0
.0
.0
21.0




744 737 155
65.3
12.0
  .0
  .0
26.0

  .0
59.0
  .0
  .0
20.0
                                                                               696    6»3     17?
                                                                               744    472     147
                          DURING THE FIRST QUARTER  ONLY  ONE ABSORBER COULD PE OPERATED  DUE  TO AN
                          ELECTRICAL PROBLEM.   CURRENTLY, OPERATIONS ARE LIMITED  TO  TWO  ABSORBERS
                          UNTIL REHEAT IS INSTALLED,  WHICH IS EXPECTED TO PE COMPLETED  IN  APRIL.
                                                  95

-------
 EPA UTILITY  FGD  SURVEY:  JANUARY - "ARCH 1980


                                            SECTION 3
               DESIGN  AND  PERFORMANCE  DATA  FO&  OPERATIONAL DOMESTIC  FGD SYSTFMS
  COMPANY  NAMf
  PLANT  NAME
  JNJT NUMBER
  CITY
  STATE
  GROSS  UNIT GENERATING  CAPACITY  -  Mu
  NET UNIT  GENERATING  CAPACITY  W/FGD -  My
  EQUIVALENT SCRUBBED  CAPACITY  -  Mw

  »*  FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE HEAT CONTENT  -  J/G
     AVERAGE ASM CONTENT - *
     AVERAGE MOISTURE CONTENT  -  *
     AVERAGE SULFUR CONTENT  -  X
     AVERAGE CHLORIDE CONTENT  -  *
PUBLIC SERVICE OF
SAN JuAN
3
WATERfLOW
NEW MEXICO
  534.C
  463.0
  534.0
                   NEW
 COAL
 SUBfalTUMjNOUS
 15S41.
    2?.45
    14.ea
      .8C
      .37
               <   MOC BTU/tp)
 **  FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPF
     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 INDFX  - X
     ABSORBER SPARF COMPONENTS INDEX

 •* BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
WET SCRUPbING
WELLIAN LORD
DAVY POWFHGAS
12/79
* * y
     .6
   99. 5C
    2.5
    1.3
SULFUR1C ACID
MARKETED
	.	-PERFORMANCE DATA--	— — _.»,
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION  x REMOVAL   PER  BOILER  FGD   CAP
                                                                S02  PART. HOURS HOURS  HOURS  FACTOR
1/80

2/80

3/80

M 86. P
SYSTEM
M 98.0
SYSTEM
M
SYSTEM
54.0

H.O

80. 0

43.0

1.0

63.0


744

696

744

366

44

547
       .«  PflOBLtMS/SOLUTIONS/COMMENTS
                         THE ONE MODULE CURRENTLY OPERATIONAL AT SAM JUAN 3 OPERATED WITHOUT AN*
                         MAJOR  PROBLEMS DURING THE FIRST QUARTER.  THE BOILER WAS OFF LINE FOR
                         3-4 WEEKS IN FEBRUARY DUE TO AN ELECTRICAL PROBLEM.
                                                96

-------
                                             EPA UTILITY F6D SURVEY:  JANUARY  -  MARCH  108'


                                           SECTION 3
               DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC  fGD  SYSTEMS
 COMPANY  NAME
 PLANT NAME
 JNIT NUMBER
 C ITV
 STATE
 GROSS UNIT GENERATING CAPACITY - My
 NET UNIT GENERATING CAPACITY W/FGD - MW
 EQUIVALENT SCRUBBED CAPACITY - MW

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

 •* FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - t
     INITIAL START-UP DATE
     COMMERCIAL ST«RT-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - I
     PARTICULATt DESIGN REMOVAL EFFICIENCY
     ABSORBED  SPARE CAPACITY INDEX - X
     ABSORBER  SPARF COMPONENTS INDEX

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

 ** DISPOSAL
     TYPE
                                         SALT RIVER PROJECT
                                         CORONADO
                                         1
                                         ST. JOHNS
                                         ARIZONA
                                           350.0
                                           350.0
                                           280.0
                                         COAL
                                         SUBBITUM1NOUS
                                          19306.
                                            25.00
                                            16.00
                                             1.00
<   P3CO 6TU/LEO
                                         WET SCRUBBING
                                         LIMESTONE
                                         PULLMAN KELLOGG
                                         NEW
                                             *.3
                                         11/70
                                         12/79
                                            82.50
                                      X     '9.87
                                              .0
                                              .0
                                         OPEN
                                                 LINED  POND
                                                         (   270 GPM)
.---«------------ —	— PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERAB1LITY RFLIAP1LITY  UTILIZATION   X  REMOVAL   P£R  BOILER  FGD   CAP-
                                                                 SO?  PART. HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM


 3/80
SYSTEM


** PROBLEMS/SOLUTIONS/COMMENTS
              744


              696


              744
                         DURING  THE PERIOD  THE  STACK EMISSION TESTS HERE COMPLETED.  NO OPERATIONAL
                         INFORMATION WAS  AVAILABLE.
                                                 97

-------
 EPA UTILITY FGO  SURVEY: JANUARY - MARCH 1980


                                            SECTION *
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  UNIT NUMBER
  CITY
  STATE
  GROSS  UNIT GENERATING  CAPACITY - MU
  NET UNIT  GENERATING  CAPACITY  W/FGD  - "W
  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  - Z

  •*  FGO 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
     PARTUULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPAR? CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS  INDEX

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

 *• DISPOSAL
     TYPE
- X
      SOUTH  CAROLINA  PUBLIC  SERVICE
      WINYAH
      2
      GEORGETOWN
      SOUTH  CAROLINA
       28C.O
       25«.C
       uo.o
     COAL
     BITUMINOUS
      26749.
         13.50

         1.70
               < 115CO ETU/LP)
WET SCRUPBING
LIMESTONE
BABCOCK * WILCOX
NEW
    1.1
 7/77
**/ **
   69.00
   59.40
     .3
     .c
     OPEN
         6.3
                    (  100 6PM)
     PONC
	.	.___._....-—	-PERFORMANCE DATA————————--—.........	.	
PERIOD MODULE AVAILABILITY OPERAE'lLITY RELIABILITY  UTILIZATION  X  REMOVAL   PER   BOILER  FGD   CAP?"
                                                                SO?  PART.  HOURS  HOURS   HOURS  FACTOR


 1/80  SYSTEM                                                                 744

 2/80  SYSTEM                                                                 696

 3/80  SYSTEM                                                                 744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE FIRST QUARTER 19SO THE UNIT OPERATED WITH NO  MAJOR PROBLEMS.
                                                98

-------
                                              EPA UTILITY FGD  SURVEY:  JANUARY - MARCH 108T

                                            SECTION 3
               DESIGN AND PERFORMANCE  DATA FOR OPERATIONAL  DOMESTIC  FGD  SYSTEMS
 COMPANY NAME
 PLANT NAME
 JN1T NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING CAPACITY  - Mw
 NET UNIT GENERATING CAPACITY  W/FGD  - My
 EOUIVALENT SCRUBBED CAPACITY  -  MW

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

 •* FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROF IT
     ENERGY CONSUMPTION  -  X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     SO? DESIGN REMOVAL  EFFICIENCY - X
     PARTICULATE DESIGN  REMOVAL  EFFICIENCY
     ABSORBER  SPARE CAPACITY INDEX - X
     ABSORBER  SPARE COMPONENTS INDEX

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

 •• TREATMENT
     TYPE

 •* DISPOSAL
     TYPE
- X
     SOUTH MISSISSIPPI EtEC  PWR
     R.D. MORROW
     1
     HATTISBURG
     MISSISSIPPI
       Z C -i. D
       180.0
       124.0
                     <  1200C  BTU/L8)
COAL
BITUMINOUS
 27?1i.
   15.00
    6.5C
    1.30
     .01
WET SCRUBBING
LIMESTONE
RILEY STOKER/ENVIRONEERING
NEW
    c c
 8/73*
 8/7?
   85.00
   99.60
      .T
      .0
     CLOSED
     FHASH  STABILIZATION
                                                  LANDFILL
......———- — ........... — .........——PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILI7ATION  X REMOVAL    PER   BOILER  FGD   CAP.
                                                                  SO?  PART.  HOURS  HOURS  HOURS FACTOR
 1/80  SYSTEM         .0

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                    740
                          THE UNIT REMAINED OFF  LINE  DURING JANUAH1 DUE  TO  THE  FAILURE OF THE
                          LININGS.
 2/6?  SYSTEM

 3/80  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          NO INFORMATION WAS  AVAILABLE FO" FEBRUARY AND  MARCH.
                                   696

                                   744
                                                  99

-------
 EP» UTILITY FGD  SURVEY:  JANUARY  - MARCH 198C

                                             SECTION 3
                DESIGN  AND  PERFORMANCE  DATA  FOP OPERATIONAL DOMESTIC FGD SYSTEMS
  COMPANY NAME
  PLANT NAME
  JNJT NUMBER
  CITY
  STATE
  GROSS UNIT GENERATING CAPACITY - MU
  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 - *
      AVERAGE  SULFUR  CONTENT - X
      AVERAGE  CHLORIDE CONTENT - X

  •* FGD  SYSTEM
      GENERAL  PROCESS TYPE
      PROCESS  TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION - x
      INITIAL  START-UP DATE
      COMMERCIAL  START-UP  DATE
      S02 DESIGN  REMOVAL EFFICIENCY - X
      PART1CULATE  DESIGN REMOVAL EFFICIENCY
      ABSORBER SPARE  COMPONENTS INDEX
                -  X
 ** WATER LOOP
     TYPE
     FRESH MAKE-UP  WATER

 *• TREATMENT
     TYPE

 •• DISPOSAL
     TYPE
LITER/S
                      SOUTH MISSISSIPPI fLEC  PWR
                      R.D. MORROW
                      3
                      HATTISBUPG
                      MISSISSIPPI
                        200.0
                        180.0
                        124.0
                                     < 12000 BTU/LB)
COAL
BITUMINOUS
 27912.
   15.00
    6.50
    1.30
     .01
WET SCRUBBING
LIMESTONE
RILEY STOKER/ENVIRONEEPING
NEW
    5.5
 6/79
 6/79
   85.00
   99.60
     .0
                      CLOSED
                                     <****«
                      FLYASH  STABILIZATION
                     LANDFILL
	....—.—..—-——	.. — -PERFORMANCE DATA	--. ————.-—..— ...	.___	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION  x REMOVAL    PER   BOILER   FGD   CAP
                                                                 S02   PART.  HOURS HOURS   HOURS FACTOR
 1/80  SYSTEM         .0

       ** PROBLEMS/SOLUTIONS/COMMENTS
                  .0
                               .0
                                                   744
                                                         698
                          THE  UNIT  REMAINED  OFF LINE DURING JANUARY DUE  TO  THE  FAILURE  OF  THE
                          LININGS.
 2/80  SYSTEM

 3/60  SYSTEM

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         NO  INFORMATION  WAS  AVAILABLE FOR FEBRUARY AND MARCH.
                                                   696

                                                   744
                                                100

-------
                                             EPA UTILITY fGD SURVEY: JANUARY  - MARCH  1960

                                           SECTION 3
               DESIGN AND  PERFORMANCE DATA fOR OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY  NAME
 PLANT NAME
 JNIT NUMBER
 CITY
 STATE
 GROSS UNIT  GENERATING CAPACITY - MU
 NET UNIT GENERATING CAPACITY W/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

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

 • • HATER LOO'
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 •* TREATMENT
     TYPE

 •• DISPOSAL
     TYPE
             - X
                  SOUTHERN  ILLINOIS  POWER  COOP
                  MARION
                  4
                  MARION
                  ILLINOIS
                    184.0
                    160.0
                    184.0
                  COAL/REFUSE
                  ***»*•
                   30934.
                     16.00
                     10.00
                      3.50
                       .10
                  WET  SCRUBBING
                  LIMESTONE
                  BAB COCK  ( UILCOX
                  NEW
              <  9000 BTU/LB)
5/79
5/79
  89.40
  99.60
                  OPEN
                  *** **» *
                                 (***•• GPM)
                  FLYASH STABILIZATION
                                                 LANDFILL
— —	—	—	-PERFORMANCE  DATA	—	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X  REMOVAL   PER  BOILER  FGD   C»P.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR
13/79
11/79
12/79
SYSTEM
SYSTEM
SYSTEM

100.0
100.0
.0
26.7
71.0
744
720
744
0
192
528
0
192
528
** PROBLEMS/SOLUT10NS/COMHENTS
                         THE  UNIT WAS  DOWN  FROM OCTOBER  1  THROUGH NOVEMBER 17 FOR A BOILER/TURBINE
                         INSPECTION.   NO  MAJOR  FGD  RELATED PROBLEMS WERE ENCOUNTERED DURING THE
                         FOURTH  QUARTER  1979  OTHER  THAN  SOME FREEZE-UPS CAUSED BY THE U1NTER
                         WEATHER.
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM
100.0

100.0

100.0
      10.0

      31.0

      48.4
744    72

696   216

744   360
 72

216

360
                                                101

-------
EPA UTILITY  fGD  SU»VEY: JANUARY - MARCH 1980

SOUTHERN ILLINOIS  POWER COOP: MARION 4 (CONT.)
......	...	.................... .....PERfORM»NCE  DATA —	— ———.	- ———.«__.
PERIOD MODULE AVAILABILITY  OPERABILIT» RELIABILITY UTILIZATION   X  REMOVAL    PE»  BOILER  FGD    CAP.
                                                                  SO?   PART. HOURS HOURS  HOURS  fACTOR


       •* PROBLEMS/SOLUTIONS/COHMENTS

                          DURING JANUARY THE LOW BOILER AND  SCRUBBER  HOURS  WERE A RESULT OF AN
                          EIGHTEEN DAY BOILER OUTAGE NEEDED  FOR  CORRECTION  OF  TUBE PROBLEMS.  BOILER
                          OUTAGES DUE TO TUBE PROBLEMS  WERE  ALSO  EXPERIENCED IN FEBRUARY AND MARCH.

                          THE  ONLY REPORTED FGD DELATED PROBLEM  DURING  THE  FIRST QUARTER 1980 WAS
                          KEEPING THE BELT IN THE SLUDGE DISPOSAL SYSTEM  PROPERLY ALIGNED.
                                               102

-------
                                             EPA UTILITY  FGD  SURVEY:  JANUARY  - MARCH 198?

                                           SECTION 3
               DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FED  SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 JNIT  NUMBER
 CITY
 STATE
 GROSS  UNIT  GENERATING CAPACITY - My
 NET UNIT GENERATING CAPACITY W/FGO - MM
 EQUIVALENT  SCRUBBED CAPACITY - MW

 **  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT CONTENT - J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT - X
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTENT - X
                                         SOUTHERN INDIANA GAS t  ELEC
                                         A.B. BROUN
                                         1
                                         WEST FRANKLIN
                                         INDIANA
                                           265.0
                                           250.0
                                           265.0
                                         COAL
                                         BITUMINOUS
                                          25819.
                                             9.40
                                            13.3C
                                             3.35
                                               .05
                                             < 11100  BTU/LB)
 ** F6D SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - i
     PARTKULATE 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
                                         UET  SCRUBBING
                                         DUAL ALKALI
                                         FMC
                                         NEU
                                              .8
                                          4/79
                                          4/79
                                             85.00
                                    - X      99.50
                                             20.0
                                              .3
                                          CLOSED
                                          *»*****
                                          NONE


                                          LANDFILL
                                                         (•**** GPM)
	—.	——	——PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION
                                                          X REMOVAL   PER  BOILER   FGD    CAP*
                                                          SO?  PART. HOURS HOURS   HOURS  FACTOR
 1/80
A
B
SYSTEM
99.0
99.0
99.0
96.5
99.0
98.0
                                            98.0
96.5
99.0
99.0
                                                                               744
                                                                                     744
                                                                                            727
       •* PROBLEMS/SOLUTIONS/COMMENTS
                          THE  7  HOURS  OF  FORCED OUTAGE TIME DURING JANUARY WERE  DUE  TO A THICKENER
                          RAKE STALL.
 2/80
A
B
SYSTEM
99.1
98.4
99.0
70.3
70.0
7C.O
                                            70.0
69.4
68.7
69.0
                                                                               696    6?7
                                                                                     481
          PROBLEMS/SOLUTIONS/COMMENTS
 3/80  A
       B
       SYSTEM
            43.8
            38.4
            45.0
                          SOME  OUTAGE TIME IS FEBRUARY WAS DUE TO A  WET  SLUDGE  PRODUCT CAUSED BY
                          A  CHEMICAL IMBALANCE.
             44.4
             35.4
             65.0
                                     68.0
                         26.5
                         21.1
                         27.0
                                                                               744   304
                                                                                     177
                                                 103

-------
EPA UTILITY  FG6  SURVEY: JANUARY - MARCH  1980

SOUTHERN INDIANA  GAS  « ELEC: A.B. BROWN  1  (CONT.)
	„.___.—.	_._...—.._._—__—_	.. PERFORMANCE DATA—	——	-——_.._
PERIOD MODULE AVAILABILITY  OPERABIL1T1 RELIABILITY  UTILIZATION  » REMOVAL   PER   BOILER  FGD    CAp""~
                                                                  SO?  PART.  HOURS  HOURS  HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMHENTS

                          DURING MARCH, DOWN  TJME  WAS DUE TO A SCHEDULED UNIT OUTAGE,  DURING UHICH
                          TIME MAINTENANCE UAS  PERFORMED ON THE SCRUaBER.
                                               104

-------
                                              EPA  UTILITY F6D  SURVEY: JANUARY - MARCH 196n

                                            SECTION  3
               DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC F60 SYSTEMS
 COMPANY  NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING CAPACITY - MW
 NET UNIT GENERATING CAPACITY W/FGD - MW
 EQUIVALENT SCRUBBED CAPACITY - NW

 • *  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

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

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

 • *  DISPOSAL
     TYPE
                                                     CITY UTILITIES
                                    - X
                                                         (  12500  BTU/LB)
                             SPR JNGF1ELD
                             SOUTHWEST
                             1
                             SPRINGFIELD
                             MISSOURI
                               194.D
                               173.0
                               194.0
                             COAL
                             BITUMINOUS
                              29075.
                                13.00

                                 3.50
                                  .30
                             WET SCRUBBING
                             LIMESTONE
                             AIR CORRECTION  DIVISION.  UOP
                             NEW
                                 4.6
                              4/77
                             • */ • *
                                83.00
                                99.70
                                  .0
                                  .0
                                          CLOSED
                                             19.8
                                                 LANDFILL
                                                         I   315 GPM)
	—	—	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION
                                                          t REMOVAL   PE»  BOILER   FGD    CAP-
                                                          SO?  PART. HOURS HOURS   HOURS  FACTOR
1/80


S-1
S-2
SYSTEM
24.4
68.7
61.5
38.6
72.5
55.6
*7.9
73.0
61.5
36.3
68.0
52.2


744 698 388
          PROBLEMS/SOLUTIONS/COMMENTS
 2/80
S-1
S-2
SYSTEM
36.6
73.9
55.3
                          AT  THE  BEGINNING OF JANUARY THE  ID  FAN  EXPANSION JOINT BROKE FOLLOWED BY
                          THE UNIT COMING OFF LINE.


                          DURING  THE  LATER PART OF THIS PERIOD  THE  DEMISTER AND TRAP OUT TRAY HEADER
                          FROZE.   AFTER REPAIRS WERE MADE  BOTH  MODULES  WERE PUT ON LINE.  BOTH WERE
                          KEPT RUNNING UNTIL THE 20TH WHEN A  FLANGE BROKE LOOSE ON THE DEMISTER
                          HEADER.


                          AFTER THE REPAIRS WERE COMPLETED TH£  MODULE OPERATED UNTIL THE 27TH WHEN
                          FREEZING AIR LINES TO THE BALL MILLS  PREVENTED THE USE OF BOTH MODULES
                          DUE TO  THE  LACK OF SLURRY.

                          THE UNIT WAS ON LINE AT THE BEGINNING OF  THE  MONTH PUT DEVELOPED  pRESAlURA-
                          TOR SPRAY NOZZLE PROBLEMS.  bHILE THIS  WAS BEING REPAIRED THE UNIT WAS
                          TAKEN OFF LINE.  APART FROM THIS TIME THE NODULE WAS ON LINE.
29.1
71.7
50.4
29.0
71.6
SO.4
29.0
71.6
50.3
                                                                               6'6    695
                                                                                             350
                                                 105

-------
EP» UTILITY  FGD  SURVEY: JANUARY - MARCH  1980

SPRINGFIELD  CITY  UTILITIES: SOUTHWEST  1  (CONT.)
	PERFORMANCE DATA--		
PERIOD MODULE »V»ILABIL1T»  OPERAB1LITY RELIABILITY  UTILIZATION  * REMOVAL    P£R   BOILER  FGD   C»p7~
                                                                  S02  PART.  HOURS  HOURS  HOURS FACTOR


       •* PROBLEMS/SOLUTIONS/CONMENTS

                          THE S-1 MODULE WAS  OUT  OF  SERVICE IN THE FIRST PART  OF  FEBRUARY DUE TO
                          FROZEN AND BROKEN LINES.   THE  SUPERNATE LINE BROKE  IN SEVERAL PLACES TAKING
                          BOTH MODULES OUT OF  SERVICE  FOR SEVERAL DAYS.  ONCE  THIS  UAS  REPAIRED BOTH
                          MODULES WERE IN SERVICE  AS  REQUIRED BY LOAD EXCEPT  FOR  A  FEW  MINOR TRIPS.

                          THE S-2 MODULE WAS  EITHER  IN SERVICE OR AVAILABLE  FOR HOST  OF THE  MONTH.

 3/80  S-1          64.5         64.1        64.1         64.1
       S-2          22.C          5.8          5.8          5.8
       SYSTEM       43.3         34.9        34.9         34.9                   744    744    240

       *• PROBLEMS/SOLUTIONS/COMMENTS

                          DURING MARCH THF S-1 MODULE  WAS OUT FOR 11 DAYS TO  CLEAN  THE  ABSORBER
                          SECTION.

                          THE S-2 MODULE UAS  OUT OF  SERVICE FOR CLEANING THE  ABSORBER SECTIONS AND
                          DEMISTERS FOR NEARLY ALL THE PERIOD BUT WAS AVAILABLE OH  THE  25TH.
                          IT  UAS NOT RUN, HOWEVER, DUE TO LOU UNIT LOADS.
                                                106

-------
                                              EPA UTILITY fGD SURVEY: JANUARY  -  MARCH 198C1

                                            SECTION 2
               DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC FGD  SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING  CAPACITY  - MW
 NET UNIT GENERATING CAPACITY  U/FGD  -  MW
 EOUIVALENT SCRUBBED CAPACITY  -  MW

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

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

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

 ** BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
   ST.  JOE 7INC
   G.F. toEATON
   1
   MONACA
   PENNSYLVANIA
      6r'.0
      60.0
      6C.O
   COAL
   BITUMINOUS
    29C75.
      11.50
<  1?500 BTU/LB)
       3.00
        .20
   WET SCRUBBING
   CITRATE
   BUREAU OF MINES
   RETROFIT
   *******
   11/79
    1/80
      90.00
X     99.60
        .0
        .0
   CLOSED
                   (*****  GPM)
   ELEMENTAL SULFUR
.............	.......—.—. — _	..—. — PERFORMANCE DATA	•
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION
                                                                  x  REMOVAL   PER  BOILER  FGD    CAP.
                                                                  SO?  PART. HOURS HOURS  HOURS  FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                 744

                                 696

                                 744
                          THE  SYSTEM IS STILL GOING  THROU6H  THE  DEBUGGING PHASE OF OPERATION.   SOME
                          EQUIPMENT PROBLEMS HAVE OCCURRED,  ESPECIALLY WITH THE HYDROGEN  SULFITE
                          GENERATOR EQUIPMENT.  ANOTHER  MAJOR  PROBLEM AREA HAS BEEN THE HEAT EX-
                          CHANGERS, ONE OF WHICH HAD  TO  BE  REMOVED AND SENT BACK.  120 HOURS OF
                          OPERATION WERE LOGGED DURING THE  FIRST QUARTER 198Q BRINGING THE  TOTAL
                          SYSTEM HOURS OF OPERATION  TO 164.
                                                 107

-------
 EPA UTILITY FGD SURVEY: JANUARY  -  MARCH 1980

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

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

  ••  FGD  SYSTEM
      GENERAL PROCESS TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      NEy/RETROFIT
      ENERGY CONSUMPTION - X
      INITIAL START-UP DATE
      COMMERCIAL START-UP DATE
      SO?  DESIGN REMOVAL EFFICIENCY - X
      PARTICULATE DESIGN REMOVAL EFFICIENCY
      ABSORBER  SPARE COMPONENTS INDEX

  •* WATER  LOOP
      TYPE
      FRESH  MAKE-UP  WATER  - LITER/S
- X
      TENNESSEE  VALLE* AUTHORITY
      SHAWNfcE
      10A
      PADUCAH
      KENTUCKY
         10.0
         10.0
         10.0
      COAL
      BITUMINOUS
         ?.90
                     <*•**•*  BTU/LBJ
     WET SCRUBBING
     LIME/LIMESTONE
     AIR CORRECTION  DIVISION,  UOP
     RETROFIT
      4/72
     ** / **
     ********
          .0
     CLOSED
     *******
                     (*****
	.	—...	..	——-PERFORMANCE DATA—--
PERIOD MODULE AVAILABILITY  OPERABUITV RELIABILITY UTILIZATION
                     X REMOVAL   PER  BOILER   FGO   CAP  ~
                     S02  PART. HOURS HOURS   HOURS FACTOR
 3/80  SYSTEM

       «* PROBLEMS/SOLUTIONS/COMMENTS

                          REFER  TO THE PERFORMANCE UPDATE INFORMATION  FOR  SHAWNEE  10B.
                                                108

-------
                                             EPA UTILITY F6D SURVEY:  JANUARY  -  MARCH 1980

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

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

 • *  FGD SYSTEM
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEU/RETROFIT
     ENERGY CONSUMPTION  - Z
     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
TENNESSEE VALLEY AUTHORITY
SHAUNEE
10B
PADUCAH
KENTUCKY
   10.0
   10.0
   10.0
COAL
BITUMINOUS
                        BTU/LB)
    2.90
WET  SCRUBBING
LIME/LIMESTONE
RETROFIT
*** •«**
 4/72
** / »*
 CLOSED
 • ** ****
                (**•**
.._————- —————-—..........PERFORMANCE DATA——
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION
                 X REMOVAL
                 SO?  PART.
 PER  BOILED  FGD   CAP.
HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS
                              74*

                              696

                              744
                          DURING  THE  FIRST BUAf)T£R OF 1980, ONLY THE VENTUR1 /SPRAY TOWER  SYSTEM WAS
                          OPERATED.   THE TCA SYSTEM CONTINUED TO OPERATE  DURING  THE QUARTER  ON DOW*
                          BASIC  ALUMINUM SULFATE PROCESS UNDER EPRI/UOP/TVA  SPONSORSHIP.
                          THE  LIHESTONE/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,
                          WAS  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
                          6 PERCENT  AND 26 PERCENT, RESPECTIVELY.  THEREFORE,  IT APPEARS  THAT THE
                          ADIPIC  ACID (OR CARBOXYLIC ACID) DEGRADATION  TAKES  PLACE AT SCRUBBER INLET
                          PH ABOVE ABOUT 5.1 UNDER CONDITIONS ASKED.
                          A SERIES OF IINESTONE/ADIP1C 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 PPP
                          ADIPIC  ACID, L/G OF 21 GAL/MCF, AND 8.3 INCHES  H20 PRESSURE DROP, S02
                          REMOVAL WAS 65 PERCENT WITH 2200 PPM INLET SO?  CONCENTRATION.
                          FORCED  OXIDATION USING A SINGLE TANK WITH  UIMESTONE/AOIP1C ACID SLURRY ON
                                                 109

-------
EPA  UTILITY  FGD  SURVEY: JANUARY - MARCH 198C
TENNESSEE  VALLEY  AUTHORITY:  SHAUNEE  IOB 
-------
                                              EPA UTILITY  FGD  SURVEY:  JANUARY - PUfiCH
                                           SECTION  J
               DESIGN AND PERFORMANCE DATA FOR  OPERATIONAL  OONESTjC  FGD
 COMPANY NAME
 PLANT NAHE
 JNIT NUMBER
 CITT

 GROSS UNIT GENERATING CAPACITY  - WH
 uFT UNIT GENERATING CAPACITY W/FGO - MW
 EQUIVALENT SCRUBBED CAPACITY -  MW


 • » FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT  - J/G
     AVERAGE ASH CONTENT - *
     AVERAGE MOISTURE CONTENT -  1
     AVERAGE SULFUR CONTENT - »
     AVERAGE CHLORIDE CONTENT -  *


 .* FGO StSTEN
     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
     PHRT1CULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER  SPARE CAPACITY  INDEX  -  I
     ABSORBER  SPARE COMPONENTS  INDEX


 ** DlSPOS»t
     T»PE
                                    - Z
                                         TENNESSEE VALLEY AUTHORITY
                                         WIDOWS CREEK
                                         8
                                         B»IDGEPORT
                                         ALA&AM*
                                           5 5 :. 0
                                           516.0
                                           559.3
                                         COAL

                                          23260.
                                            25.30
                                            10.00
                                             3.70
                                             < 1"OOC BTU/LP)
                              WET SCRUBBING
                              LIMESTONE
                              TENNESSEE VALLEY AUTHORITY
                              RETROFIT
                                  4.7
                               5/77
                               1/78
                                 6".00
                                 99.50
                                   .3
                                   .0
                                          POND
                                          •PERFORMANCE DATA-
" PIQD MODULE  AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER
PE                                                               S02   PART.  HOURS  HOURS
                                                                                   FGO   CAP.
                                                                                  HOURS  FACTOR
 1/BO
A
B
C
D
SYSTEM
 70.4
 83.5
100.0
 28.3
 70.6
 79.8
100.0
100.0
 54.6
 9C.4
39.2
S6.3
55.5
ze.9
44.5
                                                                 83.60
                                                744
                                                      366
                                                             331
           PROBLEMS/SOLUTIONS/COMMENTS
                          DURING JANUARY THE UNIT 8 BOILER  EXPERIENCED  LOW AVAILABILITY, CAUSING THF
                          FORCED OXIDATION TESTS TO BE DISCONTINUED  UNTIL  AFTER THE SCHEDULED
                          MAINTENANCE OUTAGE WHICH WILL BEGIN  IN  SEPTEMBER 19RO.  THE FORCED OXIDA-
                          TION TESTS ARE EXPECTED TO RESUME  IN JANUARY  1981.
 2/80
A
B
C

SYSTEM
 80.0
 86.1
 90.7
 87.2
 85.9
88.6
90.2
97.5
98.2
93.7
                         7?. f
                         74.0
                         80.0
                         80.6
                         76.5
                                                                 84.00
                       696    571
                                                            535
        *«
           PROBLEMS/SOLUT1 ON S/COMENTS
                          BY FEBRUARY 27. 1980. THE  DIFFERENTIAL  PRESSURE ACROSS TRAIN "C" ABSORBER
                          HAD REACHED 19 INCHES WATER GA6E.   THE  HIGH  ABSORBER DIFFERENTIAL PRESSURE
                          WAS CAUSED BY PLUG6A6E OF  TURBULENT CONTACT  ABSORBER (TtA) SPHERES WHICH
                          WERE INSTALLED DURING SCRUBBER  OPTIMIZATION  TESTS.  THE TCA SPHERES WILL
                          BE REMOVED IN MARCH.
 3/80
                    93.5
                                88.0
                                                         85.3
                                                 111

-------
EPA UTILITY FGO SURVEY: JANUARY  -  MARCH  1980

TENNESSEE VALLEY AUTHORITY:  WIDOWS  CREEK  8  (CONT.)
.	—.__.__._.._..—..—___—_	.—PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION
X REMOVAL   PER  BOILER  FGD    CAP.
SO?  PART. HOURS HOURS  HOURS  FACTOR
B
C
D
SYSTEM
93.0
71.9
93.3
87.9
90.6
73.3
63.9
78.9
87.9
71.1
61.9
76.6


8?. 60


744


722


570
       ** PROBIEMS/SOLUTIONS/COMNENTS
                         ON MARCH 3 THE TCA  SPHERES  INSTALLED IN TRAIN C AS PART OF THE OPTIMIZA-
                         TION TESTS HERE REMOVED.   THE  SPHERES HAD  BECOME PLUGGED, RESULTING IN AN
                         ABSORBER DIFFERENTIAL  PRESSURE  OF  20 INCHES WATER GAGE.  THE SPHERES HAD
                         BEEN IN USE SINCE NOVEMBER  17,  1979.
                                               11Z

-------
                                             EPA UTILITY  FGO  SURVEY:  JANUARY - MARCH 198?

                                           SECTION  3
               DESIGN ANP PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  F6D  SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING CAPACITY - HW
 NET UNIT GENERATING CAPACITY W/F6D - 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

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

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

 *• TREATMENT
     TYPE

 ** DISPOSAL
     TYPE
- X
     TEXAS UTILITIES
     MARTIN LAKE
     1
     TATUH
     TEXAS
       793.0
       7SO.O
       595.0
     COAL
     LIGNITE
      17166.
         8.QO
        33.00
          .90
     *»*****«
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
    1.3
 4/77
10/78
   71.00
   99.40
     .0
     .0
               <  7380 6TU/LB)
     CLOSED
        34.6
                <   550  6PH)
     FLYASH STABILIZATION
                                                 LANDFILL
	.........—.....	......—...	——PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERAB1LITV  RELIABILITY UTILIZATION
                      X  REMOVAL    PER  BOILER  FGO   CAP.
                      SO?   PART.  HOURS HOURS  HOURS FACTOR
 1/80  StSTEM

 Z/80  SYSTEM

 3/80  SYSTEM

       •* PROBLEMS/SOLUTIONS/COMMENTS
                                   744

                                   696

                                   744
                          PLUGGING  PROBLEMS CONTINUED IN THE FIRST QUARTER  1980,  PARTICULARLY IN
                          THE  WETTED  FILM CONTACT AREA AND THE MIST ELIMINATOR  SECTION.   THE
                          MIST ELIMINATOR PLUGGING HAS RECENTLY SOLVED BY SWITCHING  BACK  TO LAKE
                          WATER FOR HIST ELIMINATOR WASH FROM AN ASH POND WATER WASH THEY HAD BEEN
                          TESTING.
                          THE  FPP STRUCTURAL WORK IS BECOMING A PROBLEM.
                          WORK WAS REPLACED WITH STAINLESS STEEL.
                               MUCH OF THE FRP SUPPORT
                          THE  UTILITY HAS PLANS TO INSTALL A NEW MODULE  IN  EARLY 198Z,  THE NEW
                          MODULE  HAS BECOME NECESSARY DUE TO THE INCREASE  IN  THE SULFUR CONTENT OF
                          THE  LIGNITE.
                                                113

-------
 EPA UTILITY FGD SURVEY: JANUARY - MARCH  1980

                                             SECTION  3
                DESIGN AND PERFORMANCE DATA  FOR OPERATIONAL  DOMESTIC  FGD  SYSTEMS
  COMPANY NAME
  PLANT NAME
  UNIT NUMBER
  CITY
  STATE
  GROSS UNIT GENERATING CAPACITY - My
  NET  UNIT GENERATING CAPACITY 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 - Z
      AVERAGE  CHLORIDE  CONTENT - Z

  *• F6D  SYSTEM
      GENERAL  PROCESS TYPE
      PROCESS  TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION - X
      INITIAL  START-UP  DATE
      COMMERCIAL  START-UP  DATE
      S02  DESIGN  REMOVAL EFFICIENCY - I
      PARTICULATE OESI6N REMOVAL EFFICIENCY
      ABSORBER SPARE  CAPACITY INDEX - X
      ABSORBER SPARE  COMPONENTS  INDEX

 •* HATER LOOP
      TYPE
      FSESH MAKE-UP WATER  - 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
        31.00
          .90
     ********
UET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEU
    1.3
 5/78
**/ •*
   71.00
   99.40
     .0
     .0
               (  7380 6TU/LR)
     CLOSED
        34.6
               <  550 GPM)
     FLVASH STABILIZATION
     LANDFILL
.........................	PERFORMANCE  DATA-—-
PERIOD MODULE AVAILABILITY OPERA8UITV  RELIABILITY  UTILIZATION
                     X REMOVAL   PER  BOILER  FGD   CAP
                     S02  PART. HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 Z/80  SYSTEM

 3/80  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                  744

                                  696

                                  744
                         PLUGGING PROBLEMS  CONTINUED  IN  THE  FIRST  QUARTER 1980*  PARTICULARLY IN
                         THE WETTED FILM CONTACT  AREA  AND  THE  MIST ELIMINATOR SECTION.  THE
                         HIST ELIMINATOR PLUGGING WAS  DECENTLY SOLVED  BY SWITCHING BACK TO LAKE
                         WATER FOR HIST ELIMINATOR HASH  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 A  NEW  MODULE  IN  THE  FALL  1982.  THE NEU
                         MODULE HAS BECOME NECESSARY DUE TO  THE  INCREASE  IN  THE  SULFUR  CONTENT OF
                         THE LIGNITE.
                                               114

-------
                                             EPA UTILITY FGD SURVEY: JANUARY - MARCH

                                           SECTION 3
               DESIGN AND  PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGp SYSTrMS
 COMPANY  NAME
 PLANT  NAME
 JN1T NUMBER
 CITY
 STATE
 GROSS  UNIT  GENERATING CAPACITY - Mw
 NET UNIT GENERATING CAPACITY W/FGO - ttu
 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

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

 .*  TREATMENT
     TYPE

 • *  DISPOSAL
     TTPE
     TEXAS  UTILITIES
     MARTIN LAKE
     3
     TATUW
     TEXAS
       793.C
       750.0
       595.0
     COAL
     LIGNITE
      17166.
         8.00
        33.00
          .90
     WET SCRUBBING
     LIMESTONE
     RESEARCH COTTRELl
     NEW
         1.3
      2/79
     ** / * *
        71.00
- X     99.40
          .0
          .0
     FLYASH STABILIZATION
                                                 LANDFILL
(   7380 BTU/LB)
......——	PERFORMANCE  DATA	
PERIOD NODULE AVAILABILITY OPERABILIT1 RELIABILITY  UTILIZATION
                     X REMOVAL    PER   BOILER   FGD    C«P.
                     SO?   PART.  HOURS  HOURS   HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM

       •* PROBLEflS/SOLUTIONS/COMMENTS
                                   696

                                   744
                         PLUGGING PROBLEMS  CONTINUED  IN  THE FIRST QUARTER 1980t PARTICULARLY IN
                         THE WETTED  FILM  CONTACT  AREA AND THE MIST ELIMINATOR SECTION.  THE
                         HIST  ELIMINATOR  PLUGGING WAS RECENTLY SOLVCD 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*  MUCH OF THE FRP SUPPORT
                         WORK  WAS REPLACED  WITH  STAINLESS STEEL.

                         THE UTILITY  HAS  PLANS  TO INSTALL A NEW MODULE IN EARLY 1983.  THE NEW
                         MODULE HAS  BECOME  NECESSARY  DUE TO THE INCREASE IN THE SULFUR CONTENT  OF
                         THE LIGNITE.
                                                115

-------
 EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980

                                            SECTION  3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FCD SYSTEMS
  COMPANY NAME
  PLANT  NAME
  UNIT NUMBER
  CITY
  STATE
  GROSS  UNIT GENERATING CAPACITY - M«
  NET  UNIT GENERATIN6 CAPACITY W/FGD - MW
  EQUIVALENT SCRUBBED CAPACITY - MU

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

  **  FGD  SYSTEM
      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

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

  ** TREATMENT
      TYPE

  *• DISPOSAL
      TYPE
   TEXAS UTILITIES
   MONTICELLO
   3
   MT. PLEASANT
   TEXAS
     800.0
     750.0
     800.0
   COAL
   LIGNITE
   • * *****
      18.90
      31.90
       1.50
        .04
   WET SCRUBBING
   LIMESTONE
   CHEMICO
   NEW
(****»* BTU/lB>
    5/78
   10/78
      74.00
X     99.50
        .0
        .0
   CLOSED
                  (  546 CPM)
   FLYASH STABILIZATION
                                                 LANDFILL
..	............................,..—-__.PER FORM AN CE DATA——————————————._..	
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD    CAP.
                                                                 S02  PART. HOURS HOURS   HOURS  FACTOR


 1/80  SYSTEM                                                                 744

 2/80  SYSTEM                                                                 696

 3/80  SYSTEM                                                                 744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         MO PROBLEMS VEftE  ENCOUNTERED DURING THE FIRST QUARTER OF 1980.
                                                116

-------
                                             EPA UTILITY  F60  SURVEY:  JANUARY - MARCH 1980

                                           SECTION 3
               DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FGo  SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS  UNIT  GENERATING CAPACITY - MU
 NET UNIT GENERATING CAPACITY W/fGD - MU
 EQUIVALENT  SCRUBBED CAPACITY - HU

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

 •*  F6D 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  - Z
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARE COMPONENTS  INDEX

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

 **  TREATMENT
     TYPE

 «*  DISPOSAL
     TYPE
   UTAH POUER l LIGHT
   HUNTER
   1
   CASTLE  DALE
   UTAH
     400.0
     400.0
     360.0
   COAL
   BITUMINOUS
    29075.
      10.00
       6.50
        .55
   *«******
   WET SCRUBBING
   LIME
(  12500 BTU/Lf))
   NEU
    5/79
   **/ * *
      80.00
*     99.50
        .0
   OPEN
   *******
                   (*****  GPM)
   FLYASH STABILIZATION
                                                 POND
..	.....	.	...	—.	—PERFORMANCE DATA	—	
PERIOD MODULE AVAILABILITY  OPERABIL1TY RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER   FGD   CAP.
                                                                 SOZ   PART. HOURS HOURS  HOURS FACTOR


 1/80  SYSTEM                                                                  7*4

 2/80  SYSTEM                                                                  69«

 J/80  SYSTEM                                                                  744

       •* PROBLEMS/SOLUTIONS/COMMENTS

                          NO INFORMATION  WAS AVAILABLE FOR THE FIRST  QUARTER  1980.
                                                117

-------
 EP» UTILITY FGD SURVEY: JANUARY - MARCH  i960

                                             SECTION  3
                DESIGN AND PERFORMANCE 6ATA  FOP  OPERATIONAL  DOMESTIC  FGD  SYSTEMS
  COMPANY NAME
  PLANT NAME
  JNIT NUMBER
  CITY
  STATE
  GROSS UNIT GENERATING CAPACITY - My
  NET UNIT GENERATING CAPACITY W/FGD - My
  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

  •*  FGD  SYSTEM
      GENERAL PROCESS TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY  CONSUMPTION  - X
      INITIAL START-OP  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
- X
      UTAH  POWER  8  LIGHT
      HUN71NGTON
      1
      PR! CE
      UTAH
        43:.o
        iCD.O
        366.0
      COAL
      BITUMINOUS
      29075.
         10.00
         6.50
          .55
      ********
WET SCRUBBING
LlM£
CHEMICO
NEW
    1.6
 5/78
*•/ •*
   80.00
   99.50
    2.5
     .0
     CLOSED
        18.9
               ( 125CO BTU/LB)
                    <  300 GPM)
     FLYASM STABILIZATION
                                                 LANDFILL
— ———————————————PERFORMANCE  DATA — ——————....____..__
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   x  REMOVAL    PER   BOILER  FGD   c**~"
                                 	S02   PART.  HOURS  HOURS   HOURS FACTOR


 1/80  SYSTEM                                                                 744

 2/80  SYSTEM                                                                 696

 3/80  SYSTEM                                                                 744

       **  PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION WAS AVAILABLE  FOR THE FIRST  QUARTER  1980.
                                               118

-------
                                     EPA UTILITY  FGD  SURVEY: JANUARY - HARCH 1960
                                     SECTION  4
                         SUMMARY OF  FGD  SYSTEMS  BY  COMPANY
                                       	STATUS	
                            TOTAL      OPERATIONAL   CONSTRUCTION   CONTRACT
                                                                   AWARDED
                         PLANNED
COMPANY NAME
ALABAMA ELECTRIC COOP
ALLEGHENY POWER SYSTEM
AR^ONA ELECTRIC POWER COOP
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC COOP
BASIN ELECTRIC POWER COOP
BIG RIVERS ELECTRIC
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CINCINNATI GAS It ELECTRIC
COLORADO UTE ELECTRIC ASSN.
COLUMBUS K SOUTHERN OHIO ELEC.
COMMONWEALTH EDISON
COOPERATIVE POWER ASSOCIATION
DELMARVA POWER K LIGHT
DESERET GENERATION K TRANS COO
DUQUESNE LIGHT
EAST KENTUCKY POWER COOP
GENERAL PUBLIC UTILITIES
GRAND HAVEN BRD OF LIGHT K PWR
HOOSIER ENERGY
HOUSTON LIGHTING S POWER CO.
INDIANAPOLIS POWER t LIGHT
KANSAS CITY POWER g LIGHT
KANSAS POWER t LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LOUISVILLE GAS 1 ELECTRIC
MICHIGAN SO. CENTRAL PWR AGENC
MIDDLE SOUTH UTILITIES
MINNESOTA POWER t LIGHT
MINNKOTA POWER COOPERATIVE
MONTANA POWER
MUSCATINE POWER t WATER
NEVADA POWER
NEW YORK STATE ELEC & GAS
NIAGARA MOHAWK POWER COOP
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
OTTER TAIL POWER
PACIFIC GAS t ELECTRIC
PACIFIC POWER t LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
POTOMAC ELECTRIC POWER
PUBLIC SERVICE INDIANA
PUBLIC SERVICE OF NEW MEXICO
PWR AUTHORITY OF STATE Or NY
SALT RIVER PROJECT
SAN MIGUEL ELECTRIC COOP
SERINOLE ELECTRIC
SIKESTON BOARD OF HUNIC. UTIL.
SOUTH CAROLINA PUBLIC SERVICE
SOUTH MISSISSIPPI ELEC PWR
SOUTHERN ILLINOIS POWER COOP
SOUTHERN INDIANA GAS t ELEC
SOUTHWESTERN ELECTRIC POWER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER. LIGHT t PWR
ST. JOE ZINC
TAMPA ELECTRIC
TENNESSEE VALLEY AUTHORITT
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER K LIGHT
NO.
2
3
2
8
1
5
4
2
1
1
2
3
4
1
2
2
2
2
3
5
1
2
1
5
3
4
1
1
10
1
6
1
1
4
1
10
1
1
3
4
1
2
1
3
4
1
1
4
1
3
1
2
1
3
2
2
1
1
1
1
1
1
7
1
3
ix W
358.
1738.
790.
2684.
670.
2680.
1764.
794.
617.
600.
1700.
1341.
1572.
450.
654.
730.
820.
920.
1800.
3475.
81.
882.
492.
3012.
1054.
1575.
64.
364.
3554.
55.
534Q.
475.
405.
2120.
160.
3125.
870.
100.
957.
2450.
440.
1600.
550.
2751.
844.
800.
650.
1779.
700*
840.
400.
1240.
235.
700.
248.
484.
265.
720.
194.
205.
60.
*75.
3153.
(00.
1882.
NO.
2
1
2
5
0
0
1
1
1
0
0
1
2
0
1
0
0
2
0
0
0
c
0
1
3
3
1
0
5
0
0
0
1
2
0
3
0
0
1
2
0
0
1
2
1
0
0
3
0
1
0
0
0
1
2
1
1
0
1
0
1
0
3
0
0
MM
358.
519.
390.
1348.
0.
0.
242.
378.
617.
C.
0.
447.
822.
0.
327.
0.
0.
920.
0.
0.
0.
0.
0.
532.
1054.
1085.
64.
0.
1201.
0.
0.
0.
405.
720.
0.
375.
0.
0.
115.
1480.
0.
0.
550.
1834.
120.
0.
0.
1245.
0.
280.
0.
0.
0.
140.
248.
184.
265.
0.
194.
0.
60.
0.
570.
0.
0.
NO.
n
1
n
1
1
4
1
0
0
c
1
1
0
1
1
1
0
n
1
0
n
1
0
1
0
1
0
1
3
C
0
1
0
2
0
0
0
1
0
1
1
0
0
1
2
0
0
1
0
1
1
0
1
1
0
0
0
0
0
1
0
0
3
1
1
»n
C-
519.
C.
126.
670.
2J40.
242.
I. •
0.
C.
650.
447.
C.
450.
327.
180.
0.
0.
500.
C.
C.
441.
C.
530.
C.
490.
C.
364.
1203.
C.
0.
475.
0.
1400.
c.
0.
0.
100.
0.
110.
440.
0.
0.
917.
574.
C.
c.
534.
0.
280.
400.
0.
235.
280.
0.
0.
0.
0.
0.
205.
0.
0.
1983.
400.
382.
NO*
0
1
r.
2
0
0
0
c
c
0
0
0
0
c
c
0
0
c
0
c
1
1
1
0
c
0
0
0
0
1
0
c
0
0
1
0
c
0
0
0
0
0
0
0
1
0
1
0
0
0
0
2
0
1
0
0
0
1
0
0
0
0
1
0
2
MW
c.
300.
w •
1510.
0.
c.
0.
C..
c.
c.
c.
0.
0.
w •
1. •
w«
u •
c.
*s •
0.
81.
441 .
492.
w •
0.
0.
J.
r\
u •
C.
55.
0.
0.
c.
w .
160.
0.
0.
G.
u *
0.
0.
0.
0.
0.
150.
C.
650.
0.
0.
0.
0.
1240.
0.
280.
0.
0.
0.
72C.
0.
0.
0.
0.
600.
0.
1500.
NO.
0
n
f\
r\
n
1
2
1
n
1
1
1
2
^
'
i
2
f\
2
5
0
0
n
3
0
^
0
0
2
n
6
n
r\
n
n
7
1
r
2
1
n
2
0
0
0
1
0
a
i
i
D
0
n
0
0
1
c
c
0
0
0
1
0
0
0
MW
V. •
0.
c.
£.
0.
44?.
88 C.
416.
0.
603.
«s:.
447.
75C;.
U •
w •
55T.
ez:.
r.
. •
13CO.
3475.
C.
C.
c.
195C.
r, t
0 .
C.
" .
1150.
C .
534C.
C.
C.
:.
0.
2750.
87C.
0.
842.
86C.
0.
1600.
0.
c.
0.
800.
C.
P.
7CC.
280.
C *
o.
0.
0«
c.
3QQ.
0-
0.
0.
0.
0.
475.
0.
c.
0.
NOTE - PLANNED STATUS  INCLUDES  LETTER OF INTENT S1G
        AND CONSIDERING  ONLY  FGD  SYSTEMS
NED* REAUESTING/EVALUTING  BIDS,
                                         119

-------
EPA UTILITY F6D SURVEY: JANUARY  - MARCH  1980
                                              SECTION «
                                 SUMMARY  OF  FCO  SYSTEMS BY COMPANY

TOTAL
OPERATIONAL
CONSTRUCTION CONTRACT
PLANNED
AWARDED
COMPANY NAME
TEXAS UTILITIES
TUCSON ELECTRIC POWER
UNITED POWER ASSOCIATION
UTAH POWER C LIGHT
NO.
8
2
1
5
MW
5585.
740.
50.
1886.
NO.
4
0
0
2
MW
2585.
0.
0.
726.
NO.
0
0
0
1
MW
0*
0.
0.
360.
NO*
1
z
1
2
MW
750.
740.
50.
800.
NO.
3
0
0
C
My
2250.
0.
0.
C.
   TOTALS                          181 81568.     65  22100.     42 18*54.    23 10519.    51 3Q495.
      NOTE - PLANNED STATUS  INCLUDES  LETTER  OF INTENT SIC   NED, RE-OOESTINC/EVALUTIN6  BIDS,
              AND CONSIDERING  ONLY  FtO  SYSTEMS
                                               120

-------
                EPA UTILITY  (GO SURVEY: JANUARY - MARCH  1980
               SECTION  5
SUMMARY OF F60 SYSTEMS  BY  SYSTEM SUPPLIER
               TOTAL
	STATUS	
OPERATIONAL  CONSTRUCTION    CONTRACT
                             AWARDED
SYSTEM SUPPLIER
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH  1980
                                             SECTION  <
                             SUMMARY OF  FGO  SYSTEMS  PY  SYSTEM  SUPPLIER

TOTAL
SYSTEM SUPPLIER/PROCESS
KOMLINE K SANDERSON
LIME/SPRAY DRYING
TOTAL -
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
TOTAL -
PEABODY PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
PULLMAN KELLOGG
LIME
LIMESTONE
TOTAL -
RESEARCH COTTSELL
LIMESTONE
TOTAL -
RILEY ENVIRONEERING
MAGNESIUM OXIDE
TOTAL -
RILEY STOKER/ENVIRONEERIN6
LIMESTONE
TOTAL -
ROCKWELL INTERNATIONAL
AOUEOUS CARBONATE
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
LIME
MAGNESIUM OXIDE
TOTAL -
WHEELABRATOR-FRYE/R.I.
AOUEOUS CARBONATE/SPRAY DRYING
TOTAL -
NO.

1
1

2
2

6
1
7

1
4
5

14
U

1
1

3
3

1
1

1
1

2
4
6

1
1
My

50.
50.

682.
882.

2492.
475.
2967.

917.
1880.
2797.

5615.
5615.

600.
600.

626.
626.

100.
100.

550.
550.

1510.
844.
2354.

440.
440.
OPERATIONAL
NO.

0
C

r
C

3
r
3

C
1
1

7
7

0
n

3
3

0
0

1
1

0
1
1

0
0
MU

^
-' •
0.

C.
C.

805.
0.
805 .

0.
280.
280.

2644.
2644.

0.
0.

626.
626.

0.
0.

550.
550.

0.
120.
120.

0.
0.
CONSTRUCTION
NO.

0
0

1
1

1
1
2

1
2
3

5
5

0
0

0
0

1
1

0
0

0
2
2

1
1
MW

0.
0.

441.
441.

447.
475.
922.

917.
950.
1867.

2061.
2061.

0.
0.

0.
0.

100.
100.

0.
0.

0.
574.
574.

440.
440.
CONTRACT
AWARDED
NO.

1
1

1
1

2
0
2

0
1
1

2
2

1
1

C
0

0
0

0
0

2
1
3

0
0
iy

5n.
50.

441.
441.

1240.
0.
1240.

0.
650.
650.

91p.
910.

600.
600.

?.
0.

0.
C.

C.
0.

1510.
15D.
1660.

0.
0.
       TOTAL -
                                        130  51073.
65 22100.
                                                                    42 18454.
                                                                                 23 10519.
                                              122

-------
                                           EPA UTILITY fGO SURVEY: JANUARY  -  MARCH  19fcO
                                          SECTION 6
                               SUMMARY  OF  FGD SYSTEMS R» PROCESS
                                  TflTAt
	STATUS	
OPERATIONAL  CONSTRUCTION   CONTRACT
                            AWARDED
                                                      PLANNED
PROCESS
                                NO.
                                      MW
                                             NO.
                                                   MU
                                                          NO.
                                                                Mta
                                                                        NO.
                                                                              MW
                                                                                     NO.
                                                                                           MW
AQUEOUS CARBONATE
CITRATE
LIMESTONE
MAGNESIUM OXIDE
WELLMAN LORD
1
1
3
5
6
100.
60.
1760.
1444.
2C74.
0
1
0
1
4
0.
60.
0.
120.
1360.
1
0
0
2
2
100.
0.
fi.
574.
714.
0
0
1
2
C
j »
o •
160.
75:.
j.
*
n
2
rt
n
^.
? m
16CC.
w •
? •
  SUBTOTAL - SALEABLE  PRODUCT
                                     5(38.
                                                  154C.
                                                                1T88.
                                                                              910.
                                                          1600.
UEOUS CARPONATE/SPRAY DRYING
AL ALKALI
ME
MESTONE
MESTONE/ALKALINE



FLVASH
ME;ALKALINE FLVASH
ME/LIMESTONE
ME/SPRAY CRYING


OCESS NOT SELECTED
ID1UM CARBONATE

SUBTOTAL - THROWAUAt PRODUCT
1
5
34
66
2
11
2
8
31
5
165
440.
2^23.
13P71.
29721.
1480.
4233.
20.
2P27.
20340.
1175.
76130.
0
3
17
24
2
7
2
n
0
*
59
0.
11S1 .
6209.
£714 .
148C.
2^31.
20.
C.
ri
925.
20560.
1
g
9
2C
0
4
*
3
D
r
37
440.
0.
4791.
8»83.
C.
220?.
r .
115T.
C.
C.
17066.
r
0
4
13
0
o
r
w
3
\_
0
20
;,
0.
1891 .
6928.
J.
j.
0.
793.
j.
^ •
9609.
7
2
4
9
n
C
j
2
i1
1
49
C .
842.
1 3 8 1 • .
5196.
3.
0.
c.
887.
20340.
25:.
28895.
TOTALS

  SALEABLE  X  OF  TOTAL  MW
181 S1568.

        7
   65  22100.

          7
42 18454.

       8
23 11519.

       9
51  3C495.

       5
                                              123

-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
                                            SECTION 7
                      SUMMARY OF OPERATIONAL fGD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
CITRATE
6.F. yEATON

DUAL ALKALI
A.B. BROUN
CANE RUN
NEWTON
UNIT NO.
1

1
(
1
CAPACITY
MW
60.
60.
265.
299.
617.
INITIAL
STARTUP
11/79

4/79
4/79
9/79
COMMERCIAL
ST»RTUP
1/80

4/79
o/ c
12/79
                                                      1181.
              L1*E
                BRUCE  MANSFIELD
                BRUCE  MANSFIELD
                CANE  RUN
                CANE  RUN
                CONESVILLE
                CONESVILLE
                FL"AMA
                GREEN
                GREEN  RIVER
                HAWTHORN
                HAWTHORN
                HUNTER
                HUNTINGTON
                MILL  CREEK
                PADDY'S  RUN
                PHILLIPS
                PLEASANTS
              LIMESTONE
                AP«CHE
                APACHE
                CHOLLA
                CHOLLA
                CORONADO
                CRAIG
                DUCK CREEK
                JEFFREY
                LA  CY6NE
                LAWRENCE
                LAWRENCE
                MARION
                MARTIN LAKE
                MARTIN LAKE
                MARTIN LAKE
                MONTICELLO
                PETERSBURG
                R.D. MORROW
                R.D. MORROW
                SOUTHWEST
                TOMBIGBEE
                TO"B1GBEE
                WIDOWS CREEK
                WINYAH
 4
 5
 5
 6
 1-4
 1
 1-3
 3
 4
 1
 1
 3
 «
 1-6
 1
2
3
1
?
1
2
1
1
1
4
5
4
1
2
3
3
3
1
2
1
2
3
t
2
 917.
 917.
 186.
 200.
 411.
 411.
 510.
 242.
  64.
  90.
  90.
 360.
 366.
 442.
  72.
 410.
 519.

6209.
             LIMESTONE/ALKALINE  FLVASH
               SHERBURNE                1
               SHERBURNE                2
                                                      87U.
               740.
               740.

              1480.
12/75
 7/77
 8/76
12/77
 1/77
 6/78
10/75
12/79
 9/75
11/72
 8/72
 5/79
 5/78
 8/78
 4/73
 7/73
 3/79
 6/76
 !>/ 0
 »/77
 7/78
 2/77
 O/ 0
10/75
12/79
 6/76
 C/ 0
 C/ 0
 C/ 0
 P/ 0
 3/79
 C1/ 0
 o/ c
 O/ 0
195.
195.
119.
350.
280.
447.
378.
540.
874.
125.
420.
184.
595.
595.
595.
800.
532.
124.
124.
194.
179.
179.
550.
140.
8/78
6/79
10/73
4/78
11/79
8/79
7/76
8/78
2/73
1/76
11/71
5/79
4/77
5/78
2/79
5/78
12/77
8/78
6/79
4/77
9/78
6/79
5/77
7/77
1/79
4/79
12/73
r*/ o
12/79
6/80
»/78
O/ 0
6/73
O/ 0
O/ 0
5/79
10/78
O/ 0
O/ 0
10/78
12/77
8/78
6/79
P/ 0
9/78
6/79
1/78
O/ 0
           3/76
           4/77
            5/76
            4/77
                                               124

-------
                               EPA UTILITY FGO  SURVEY:  JANUARY  -  MARCH  1"8'
                              SECTION 7
        SUMMARY OF OPERATIONAL FGO SYSTEMS BY PROCESS  AND  UNIT
PROCESS/
  UNIT NAME
                          UNIT NO.
                                       CAPACITY
                                          MW
                                                  INITIAL
                                                  STARTUP
        COMMERCIAL
         STARTUP
LIME/ALKALINE FLYASH
  COAL CREEK
  COLSTRIP
  COLSTRIP
  FOUR CORNERS
  FOUR CORNERS
  FOUR CORNERS
  MILTON R. YOUNG
LIME/LINE STONE
  SHAWNEE
  SHAWNEE
MAGNESIUM OXIDE
  EDDYSTONE
SODIUM  CARBONATE
  JIM BRIDGES
  REID  GARDNER
  REID  GARDNER
  REID  GARDNER
 WELLMAN  LORD
   DEAN H.  MITCHELL
   SAN JUAN
   SAN JUAN
   SAN JUAN
 TOTAL
                           10B
                           1A
                                         327.
                           11
                           1
                                         175.
                                         175.
                                         229.
                                           10.
                                           10.
                                           20.

                                          120.

                                          120.

                                          550.
                                          125.

                                          12sl

                                          925.


                                          115.
                                          361.
                                          350.
                                          534.

                                         136Q.

                                        22100.
                                                    8 /79
                                                    9/75
                                                    5/76
                                                   11/79
                                                   11/79
                                                   11/79
                                                    9/77
4/72
4/72
                                                    9/75
                                                    9/79
                                                    4/74
                                                    4/7*
                                                    6/76
 7/76
 4/78
 8/7?
12/79
            -I 0
          11/75
          10/76
            r/ o
            ?/ o
            ?/ 0
            6/78
:>/  c
'/  c
                                                               9/75
            2/?0
            ->/ C
            "/ C
            7/76
6/77
n/ p
?/ 0
«/ 0
                                   125

-------
EPA UTILITY FGD SU»VEY: JANUARY - MARCH 1980

                                            SECTION 8
              SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR  OPERATIONAL  FGD  SYSTEMS
PROCESS/
UNIT NAME
CITRATE
G.F. WEATON
DJAL ALKALI
A. St BROWN
CANE RUN
MEWTON
L11E
3RUCE MANSFIELD
3RUCF MANSFIELD
CANE RUN
CANE RUN
CONESVILLE
CONESVILLE
ELAAMA
GREEN
GREEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HJWTINGTON
MILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS
LIMESTONE
APACHE
APACHE
CHOLLA
CHOLLA
CORONADO
CRAIG
DUCK CREEK
JEFFREY
LA CVGNE
LAWRENCE
LAWRENCE
MARION
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MONTICELLO
PETERSBURG
R.D. NORROU
R.D. MORROW
SOUTHUEST
TOMBIGBEE
TOWBIG8EE
WIDOWS CREEK
WINY AH
UNIT

1

1
6
1

1
2
4
5
5
6
1-4
1
1-3
3
4
1
1
3
6
1-6
1

2
3
1
2
1
2
1
1
1
4
5
4
1
2
3
3
3
1
2
1
2
3
8
2

NO STABILIZED UNSTABILI/ED TYPE DISPOSITION

ELEMENTAL SULFUR

LANDFILL
LANDFILL


LANDFILL
LANDFILL
LINED POND
LINED POND
POND
POND
LANDFILL

LINED POND
POND
POND
POND
LANDFILL
POND
POND
LANDFILL


POND
POND
POND
POND
LINED POND
HINEFILL TO WASTE
LINED POND
POND
UNLINED POND
POND
POND
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LINED POND CAS03-CAS04 POND
LINED POND CAS03-CAS04 POND
POND
POND
LIMESTONE/ALKALINE FLYASH
SHERBURNE
SHERBURNE
LIME/ALKALINE FLtASH
COAL CREEK
COLSTSIP
COLSTRJP
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
MILTON R. YOUNG
1
2

1
1
2
1
2
3
2
LINED POND
LINED POND

LINED POND
POND
POND



flNEFILL
                                              126

-------
                                               EPA  UTILITY FGD SURVEY: JANUARY  - MARCH

                                              SECTION  f
               SUMMARY  OF  END-PRODUCT DISPOSAL  PRACTICES FOR OPERATIONAL  FGO  SYSTEMS
PROCESS;
JNIT NAME
                                	THROWAWAY	
                        UNIT  NO   STABILIZED   UNSTABILIZED
                                                                             -BYPRODUCT-
                                                                     TYPE
                                                                                       01SPOSITION
LIME/LIMESTONE

SHAKNEE
SHAfcNEE

MAGNESIUM OXIDE

EODYSTONE

S3D1UM CARBONATE

JIM PRIUGES
REID GARDNER
REID GARDNER
REID GARDNER

         LORD
DEAN H. "ITCHEll
SAN JUAN
SAN JUAN
SAN JUAN
                        1CB
                        1A
                        <•
                        1
                        2
                        3
                        11
                        1
                        2
                        3
                                                             SULFURK  ACID
                                              POND
                                              LINED  POND
                                              LINED  POND
                                              LINED  POND
                                                              ELEMENTAL  SULFUR
                                                              ELEMENTAL  SULFUR
                                                              ELEMENTAL  SULFUR
                                                              SULFU"IC  ACID
MARKETED
MARKETED
MARKETED
                                                  127

-------
EP* UTILITY FGD  SU"VEY:  JANUARY - MARCH  198C
                                              SECTION 9
                                 SUMMARY  OF  FGD  SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
ALABAMA ELECTRIC COOP
TOMB16BF.E 2
•LABAMA ELECTRIC COOP
TOMBIGBEE 3
ALLEGHENY POWER SYSTEM
PLEASANTS i
ARIZONA ELECTRIC POWER COOP
APACHE 2
ARIZONA ELECTRIC POWER COOP
APACHE 3
ARIZONA PUBLIC SERVICE
CHOLL* t
ARIZONA PUBLIC SERVICE
CHOLLA 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZONA PUPLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
BIG RIVERS ELECTRIC
GREEN 1
CENTRAL ILLINOIS LI6HT
DUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
COLORADO UT£ ELECTRIC ASSN.
CRAJ6 Z
COLUMBUS t SOUTHERN OHIO ELEC.
CONESV1LLE 5
COLUMBUS t SOUTHERN OHIO ELEC.
CONESVILLE 6
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
OUOUESNE LIGHT
ELRAM* 1-4
DUQUESNE LIGHT
PHILLIPS 1-6
INDIANAPOLIS POWER t LIGHT
PETERSBURG 3
KANSAS CITY POWER « LIGHT
HAWTHORN 3
KANSAS CITY POWER * LIGHT
HAWTHORN *
KANSAS CITY POWER « L16HT
LA CY6NE 1
KANSAS POWFfi t LIGHT
• c r c n r « 1
NEta OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROf IT
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
CAPAC ITY
MW
179.:
179.0
519.1
195 .1
195.?
119. ?
350.?
175.0
175.0
229.0
242."
378. C
617.?
447.0
411.0
411.0
327.0
510.0
410.0
532.0
90.0
90.0
874.3
540.0
PROCESS/
SYSTEM SUPPLIER
IJMESTOM*
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
PA8COCK * WILCOX
LIMESTONE
RESEARCH COTTBELL
LIMESTONE
OESEARCH COTTBELL
LIMESTONE
RESEARCH COTT&F.LL
LIMESTONE
RESEARCH COTTRELL
LJME/AIKALINE FlYASH
CHEMICO
IJME/ALKALIWE FLYASH
CHEMJCO
LIME/ALKALINE FLYASH
CHEMICO
LIME
AMERICAN AIR FILTER
LIMESTONE
RILEY STOKER/ENVIRONEERING
DUAL ALKALI
BUELL/ENVISOTECH
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
AIR CORRECTION DIVISION, UOP
LJME
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME
CHEMICO
LIME
CHEMICO
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK 8 UILCOX
LIMESTONF
COMRUSTION ENGINEERING
STAPT-UP
DATE
9/78
6/79
3/79
3/78
6/79
10/7!
4/78
11/79
11/79
11/79
12/79
7/76
9/ 79
8/79
1/77
6/78
8/79
10/75
7/73
12/77
11/72
8/72
2/73
8/78
                                                128

-------
             EPA UTILITY  FGD  SURVEY: JANUARY - MARCH  1980
            SECTION  9
SUMMARY OF FGD SYSTEMS  IN  OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
KANSAS POWER t LIGHT
LAWRENCE 4
KANSAS POWER ( LIGHT
LAWRENCE 5
KENTUCKY UTILITIES
GREEN RIVER 1-3
LOUISVILLE GAS ( ELECTRIC
CANE RUN t
LOUISVILLE GAS t ELECTRIC
CANE RUN 5
LOUISVILLE 6AS t ELECTRIC
CANE RUN 6
LOUISVILLE GAS ( ELECTRIC
MILL CREEK 3
LOUISVILLE GAS t ELECTRIC
PADDY'S RUN 6
M1NNKOTA POWER COOPERATIVE
MILTON R. YOUNG 2
MONTANA POWER
COLSTRIP 1
MONTANA POWER
COLSTRIP Z
NEVADA POWFR
REID GARDNER 1
NEVADA POWER
OEID GARDNER 2
NEVADA POWER
REID GARDNER 3
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
NORTHERN STATES POWER
SHERBURNE 1
NORTHERN STATES POWER
SHERBURNE 2
PACIFIC POWER 8 LIGHT
JIB BRIDGER 4
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
PHILADELPHIA ELECTRIC
EDDVSTONE 1A
PUBLIC SERVICE Of NEW MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 2
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
NEW OR C
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
:APACIT»
nw
125.0
420.0
64. 0
188.0
200.0
299.0
442.0
72.0
405.0
360.0
360.0
125.0
125.0
125.0
115.0
740.0
740.0
550.0
917.0
917.0
120.0
361.0
350.0
534.0
PROCESS/ S
SYSTEM SUPPLIER
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
DUAL ALKALI
AOL/COMBUSTION EOUIP ASSOCIATE
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
LIME/ALKALINE FLYASH
ADL/COMBUST10N EOUIP ASSOCIATE
LIME/ALKALINE FLYASH
AOL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALINE FLYASH
AOL/COMBUSTION EOUIP ASSOCIATE
SODIUM CARBONATE
AOL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
AOL/COMBUSTION EOUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EOUIP ASSOCIATE
WELLMAN LORD
DAVY POWER6AS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
SODIUM CARBONATE
AIR CORRECTION DIVISION. UOP
LIME
CHEHICO
LIME
CHEMICO
MAGNESIUM OJUDE
UNITED ENGINEERS
WELLMAN LORD
DAVY POWERGAS
WELLMAN LORD
DAW POWERGAS
WELLMAN LORD
DAVY POWERGAS
START-UP
DATE
1/76
11/71
9/75
8/76
12/77
4/79
8/78
4/73
9/77
9/75
5/76
4/74
4/74
6/76
7/76
3/76
4/77
9/79
12/75
7/77
9/75
4/78
8/78
12/79
                 129

-------
EPA UTILITY FGD SUPVEY: JANUARY  -  MARCH  1980
                                             SECTION 9
                                 SUMMARY  OF  FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
SALT RIVER PROJECT
CORONADO 1
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 2
SOUTH MISSISSIPPI ELEC PWR
R.O. MORPOW 1
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW 2
SOUTHERN ILLINOIS POWER COOP
MARION 4
SOUTHERN INDIANA GAS & ELEC
A.B. BROUN 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
ST. JOE ZINC
G.F. UEATON 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
TEXAS UTILITIES
MONTICELLO 3
UTAH POWER t, LIGHT
HUNTER 1
UTAH POWER & LIGHT
HUNTIN6TON 1
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW
280.0
UO.O
124.0
124.3
184.0
265.0
194.0
60.0
10.0
10.0
550.0
595.0
595.0
595.0
800.0
360.0
366.0
PROCESSy
SYSTEM SUPPLIER
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BAB COCK I WILCOX
LIMESTONE
RILEY STOKER/ENVIRONEERING
LIMESTONE
RILEY STOKER/ENVIRONEERING
LIMESTONE
BAB COCK K WILCOX
DUAL ALKALI
FMC
LIMESTONE
AIR CORRECTION DIVISION. UOP
CITRATE
BUREAU OF MINES
LIME/LIMESTONE
*IR CORRECTION DIVISION, UOP
LIME/LIMESTONE
CHEMICO
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
CHEMICO
LIME
CHEMICO
LIME
CHEMICO
START-UP
DATE
11/79
7/77
a/78
6/79
S/79
4/79
4/77
11/79
4/72
4/72
5/77
4/77
5/78
2/79
5/78
5/79
5/78
                                               130

-------
                 EPA  UTILITY FGO SURVEY: JANUARY  - MARCH 198C
                SECTION  10
SUMMARY Of FGO  SYSTEMS  UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
ALLEGHENY POWEP SYSTEM
PLEASANTS 2
ARIZONA PUBLIC SERVICE
CHOLLA 4
ASSOCIATED ELECTRIC COOP
THOMAS HILL 3
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 1
BASIN ELECTRIC POUER COOP
LARAniE RIVER 1
BASIN ELECTRIC POWER COOP
LARAMIE RlvER 2
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 3
BIG RIVERS ELECTRIC
6REEN 2
CINCINNATI GAS t ELECTRIC
EAST BEND 2
COLORADO UTE ELECTRIC ASSN.
CRAIG 1
COMMONWEALTH EDISON
POWERTON 51
COOPERATIVE POWER ASSOCIATION
COAL CREEK 2
DELMARVA POWER t LIGHT
DELAWARE CITY 1-3
EAST KENTUCKY POUER COOP
SPURLOCK 2
HOOSIER ENERGY
HERON 2
INDIANAPOLIS POUER I LIGHT
PETERSBURG 4
KANSAS POWER K LIGHT
JEFFREY 2
LAKELAND UTILITIES
MCINTOSH 3
LOUISVILLE GAS t ELECTRIC
MILL CREEK 1
LOUISVILLE GAS S ELECTRIC
HILL CREEK 2
LOUISVILLE GAS 1 ELECTRIC
MILL CREEK 4
MINNESOTA POWER & LIGHT
CLAY BOSUELL 4
MONTANA POWEP
COLSTRIP 3
MONTANA POWER
COLSTRIP 4
NEU OR CAPACITY
RETROFIT nu
NEW
NEW
NEU
NtW
NEW
NEW
NEW
N£W
NEW
NEW
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEU
NEU
NEW
NEU
519.0
126.0
670.0
440.0
600.0
603.0
600.0
242.0
653.0
447.0
45D.O
327.0
180.0
500.0
441 .0
530.0
490.0
364.0
358.0
350.0
495.3
475.0
700.0
700.0
PROCESS/ START-UP
SYSTEM SUPPLIER BATE
LIME
BABCOCK K UILCOX
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
PULLMAN KELLOGG
LIME/SPRAY DRYING
JOY MF6/NIRO ATOHI7ER
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIME/SPRAY DRYING
BABCOCK 8 WILCOX
LIME
AMERICAN AIR FILTER
LIME
BABCOCK * WILCOx
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AID CORRECTION DIVISION. UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
UELLMAN LORD
DAVY MCKEE
LINE
AOL/COMBUSTION EQUIP ASSOCIATE
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK t WILCOX
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME/ALKALINE FLVASH
PEABODY PROCESS SYSTEMS
LIME/ALKALINE FLVASH
ADL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALIME FLYASH
ADL'COMBUSTION EQUIP ASSOCIATE
9/80
6/80
1/82
4/82
4/80
11/80
4/82
11/80
9/80
4/8C
4/80
7/80
4/80
1/81
7/81
10/84
4/80
10/81
4/81
4/82
7/81
4/80
1/84
0/84
                     131

-------
EPA UTILITY FGO SURVEY:  JANUARY  - MARCH 1980
                                             SECTION  10
                              SUMMARY OF FGD SYSTEMS  UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
NORTHERN STATES POWER
RIVERSIDE 6,7
OTTER TAIL POWER
COYOTE 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 3
PHILADELPHIA ELECTRIC
EDDYSTONE 1B
PHILADELPHIA ELECTRIC
EODVSTONE 2
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 4
SALT RIVER PROJECT
CORONADO 2
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SIKESTON BOARD OF MUNIC. UTIL.
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
WINVAH 3
SPRINGFIELD WATER, LIGHT « 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 i LIGHT
SANDOW 4
UTAH POWER & LIGHT
HUNTER 2
NEW OR
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
CAPACITY
MW
100.0
110.0
440.3
917.0
240.0
334.0
534.0
230.3
400.0
235.0
280.0
205.0
704.0
704.0
575.0
400.0
382.0
360.0
PROCESS/
SYSTEM SUPPLIER
AQUEOUS CARBONATE
ROCKWELL INTERNATIONAL
LIME/SPRAY DRYING
JOY MF6/NIRO ATOMIZER
AQUEOUS CARBONATE/SPRAY
WHEELABRATOR-FRYE/R.I .
LIME
PULLMAN KELLOGG
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
WELLMAN LORD
DAVY POWERGAS
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BAB COCK K WILCOX
LIMESTONE
BAB COCK K WILCOX
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
CHEKICO
LIMESTONE
CHEMICO
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
CHEMICO
START-UP
DATE
4/82
7/80
DRYING 3/81
10/80
12/82
12/82
6/82
7/80
9/flO
1/81
5/80
11/80
3/82
6/82
9/81
1/82
7/80
6/80
                                               132

-------
               EPA  UTILITY FGD SURVEY: JANUARY  - MARCH 1980
               SECTION  11
SUMMARY Of CONTRACT  AWARDED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
ALLEGHENY POWE« SYSTEM
MITCHELL 33
•R110NA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
GRAND HAVEN BOD OF LIGHT I PVR
J. B. SIMS 3
HOOSIER ENERGY
MEROM 1
HOUSTON LIGHTING & POWER CO.
V.A. PARISH 8
MICHIGAN so. CENTRAL PUR AGENC
PROJECT 1
MUSCATINE POWER t WATER
MUSCATINE 9
PHILADELPHIA ELECTRIC
CROMBV
PUBLIC SERVICE INDIANA
GIBSON 5
SEMINOLE ELECTRIC
SEMINOLE 1
SEMINOLE ELECTRIC
SEMINOLE 2
SOUTH CAROLINA PUBLIC SERVICE
UINYAH 4
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY 1
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE 1-10
TEXAS POWER t LIGHT
TWIN OAKS 1
TEXAS POWER t LIGHT
TWIN OAKS 2
TEXAS UTILITIES
MARTIN LAKE 4
TUCSON ELECTRIC POWER
SPRIN6ERVILLE 1
TUCSON ELECTRIC POWER
SPR1NGERVILLE 2
UNITED POWER ASSOCIATION
STANTON 2
UTAH POWER t LIGHT
HUNTER 3
UTAH POWER t LIGHT
HUNTER *
NEW OR I
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROf IT
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NiW
NEW
NEW
NEW
NEW
NEW
CAPAC ITY
MU
300.0
755.0
755.3
81.9
4*1.0
492.0
55.0
160.0
150.0
650.0
620.0
620.0
280.0
720.0
600.0
750.0
750.0
750.0
370.0
370.0
50.0
400.0
400.0
PROCESS/
SYSTEM SUPPLIER
LIME
CHEMICO
LIME
UNITED ENGINEERS
LIME
UNITED ENGINEERS
LIME
PABCOCK t WILCOX
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
CHEMICO
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
RESEARCH COTTRELL
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
AIR CORRECTION DIVISION. UOP
MAGNESIUM OBIDE
RILEY ENVIRONEERING
LIMESTONE
CHEMICO
LIMESTONE
CHEMICO
LIMESTONE
RESEARCH COTTRELL
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LINE/SPRAY DRYING
KOMLINE 8 SANDERSON
LIMESTONE
CHEMICO
LIMESTONE
CHEMICO
START-UP
DATE
8/82
0/82
0/82
6/83
5/82
11/82
7/82
9/82
12/82
C/82
3/83
3/85
7/81
12/84
12/81
e/84
8/85
0/85
6/85
1/87
1/82
0/83
0/85
                   133

-------
EPA UTILITY FGD SURVEYr JANUARY - MARCH 1980
                                            SECTION 12
                                  SUMMARY OF PLANNED FGO SYSTEMS
    COMPANY NAME/
    UNIT NAME
           NEU OR   CAPACITY  PROCESS;
UNIT NO.  RETROFIT     NW     SYSTEM SUPPLIER
                                        START-UP
                                          DATE
              LETTER OF INTENT SIGNED

                                    NEW
    NORTHERN INDIANA PUB SERVICE
    SCHAHFER               17

    NORTHERN INDIANA PUB SERVICE
    SCHAHFER               18
          NEU
421 .0   DUAL ALKALI
        FMC


421 .0   DUAL ALKALI
        FMC
              REQUESTING/EVALUATING BIDS
    BASIN ELECTRIC  POWER COOP
    ANTELOPE  VALLEY        2

    CENTRAL  ILLINOIS LIGHT
    DUCK  CREEK              2

    DESERET  GENERATION & TRANS COO
    MOON  LAKE              1

    DESERET  GENERATION fc TRANS COO
    MOON  LAKE              2

    MIDDLE  SOUTH  UTILITIES
    ARKANSAS  COAL          5

    MIDDLE  SOUTH  UTILITIES
    ARKANSAS  COAL          6

    MIDDLE  SOUTH  UTILITIES
    LOUISIANA COAL          1

    MIDDLE  SOUTH  UTILITIES
    LOUISIANA COAL          2

    MIDDLE  SOUTH  UTILITIES
    MISSISSIPPI COAL       1

    MIDDLE SOUTH  UTILITIES
    MISSISSIPPI COAL       2

    NEVADA POWER
    REID  GARDNER            4

    NEW YORK  STATE  ELEC  t  GAS
    SOMERSET                1

    NORTHERN  STATES  POWER
    SHERBURNE               3

    TAMPA ELECTRIC
    BIG BEND                4

    TEXAS UTILITIES
    FOREST GROVE            1

             CONSIDERING  FGD  SYSTEMS

   BIG RIVERS ELECTRIC
   0. B. WILSON            1

   BIG RIVERS ELECTRIC
   D. B.  WILSON            2

   CENTRAL MAINE  POWER
   SEARS  ISLAND            1

   CINCINNATI G*S t ELECTRIC
   EAST BEND                1

   COLORADO  UTE ELECTRIC ASSN.
   CRAIG                    3
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
IS
NEW
NEW
NEW
NEW
NEW
440.0
416.0
410.0
410.0
890.0
890.0
890.0
890.0
890.3
890.0
250. C
870.0
860.0
475.0
?50.0
440.0
440."
600.0
650.0
447.0
                              LIME/SPRAY DRYING
                              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

                              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
                              VENDOR NOT SELECTED

                              LIMESTONE
                              VENDOR NOT SELECTED

                              LIMESTONE
                              COMBUSTION ENGINEERING

                              PROCESS  NOT SELECTED
                              VENDOR NOT SELECTED

                              PROCESS  NOT SELECTED
                              VENDOR NOT SELECTED
                             LIME
                             VENDOR NOT SELECTED

                             LIME
                             VENDOR NOT SELECTED

                             PROCESS NOT SELECTED
                             VENDOR NOT SELECTED

                             PROCESS NOT SELECTED
                             VENDOR NOT SELECTED

                             LIME/SPRAY DRYING
                             VENDOR NOT SELECTED
 6/83


 6/85





 4/84


 1/86


12/84



 0/88


 1/86


 1/88



 0/86


 0/88


 C/85


 0/87


 4/83


 6/84


 5/84


 3/85


 0/81





 0/84


 0/8S


 1/89



 O/ 0


 0/82
                                              134

-------
           EPA UTILITY  F6D  SURVEY:  JANUARY - MARCH
          SECTION 12
SUMMARY OF PLANNED FGD  SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
COLUMBUS 8 SOUTHERN OHIO ELEC.
POSTON 5
COLUMBUS K SOUTHERN OHIO ELEC.
POSTON 6
DELMARVA POWER t LIGHT
VIENNA 9
EAST KENTUCKY POWER COOP
J. K. SMITH 1
EAST KENTUCKY POYE» COOP
J. K. SMITH 2
GENERAL PUBLIC UTILITIES
COHO 1
GENERAL PUBLIC UTILITIES
GILBERT 1
GENERAL PUBLIC UTILITIES
SCOTTSVILLE 1
GENERAL PUBLIC UTILITIES
SEWARO 7
GENERAL PUBLIC UTILITIES
WEHBUM 1
INDIANAPOLIS POWER g LIGHT
PATRIOT 1
INDIANAPOLIS POWER & LIGHT
PATRIOT 2
INDIANAPOLIS POWER & LIGHT
PATRIOT 3
LOUISVILLE GAS 8 ELECTRIC
TRIMBLE COUNTY 1
LOUISVILLE GAS t ELECTRIC
TRIMBLE COUNTY 2
NEVADA POWER
HARRY ALLEN 1
NEVADA POWER
HARRY ALLEN 2
NEVADA POWER
HARRY ALLEN 3
NEVADA POWER
HARRY ALLEN 4
NEVADA POWER
UARNER VALLEY 1
NEVADA POWER
UARNER VALLEY 2
PACIFIC GAS C ELECTRIC
MONTEZUMA 1
PACIFIC GAS t ELECTRIC
MONTEZUMA 2
POTOMAC ELECTRIC POWER
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPAC IT1
MM
375 .0
375.0
550. a
650.0
650.0
800.0
625.0
625.0
800. D
625.0
650.0
65D.O
65C.C
575.0
575. T
500. 0
500.0
500.0
500.0
25C. 0
250.0
800.0
800.0
800.0
PROCESS/
SYSTEM SUPPLIER
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
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
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
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
START-UP
DATE
8/86
C/89
6/87
1/85
1/87
12/St
"/9G
0/91
5/87
0/95
0/87
C/87
0/87
7/84
7/86
6/86
6/87
6/88
6/89
6/85
6/86
6/87
6/88
5/87
                        VENDOR  NOT SELECTED
              135

-------
EPA OTILITT F60 SURVEY: JANUARY  - MARCH 1980
                                             SECTION 12
                                   SUMMARY OF PLANNED fGD SYSTEMS
    COMPANY NAME/
    UNIT NAME
           NEW OR    CAPACITY   PROCESS/
UNJT NO.  RETROFIT      MW      SISTEW SUPPLIER
                                         START-UP
                                           DATE
    PUR AUTHORITY OF STATE OF NY
    FOSSIL
    SALT RIVER PROJECT
    CORONADO               3
    SOUTHERN ILLINOIS POWER COOP
    MARION                 5
    TEXAS UTILITIES
    MILL CREEK

    TEXAS UTILITIES
    MILL CREEK
          NEW


          NEW


          NEW


          NEW


          NEW
700.0   PROCESS NOT SELECTED
        VENDOR NOT SELECTED

ZS0.9   LIMESTONE
        VENDOR NOT SELECTED

300.0   PROCESS NOT SELECTED
        VENDOR NOT SELECTED

751.0   PROCESS NOT SELECTED
        VENDOR NOT SELECTED

750.0   PROCESS NOT SELECTED
        VENDOR NOT SELECTED
11/87


 6/87


 C/86


 0/8S


 0/86
                                               136

-------
                     EPA  UTILITY FGO SURVEY: JANUARY  -  MARCH  1960
                    SECTION  1J
TOTAL F6D UNITS AND  CAPACITY  INSTALLED
YEAR
1968
1969
1971
1972
1973
197*
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1995
UNDEFINED
NEW 01
NO.
1
0
4
8
8
3
6
8
11
13
20
20
11
22
5
11
12
9
13
6
3
1
1
1
12
* LINE
«W
140.
0.
702.
518.
1938.
606.
2018.
2786.
4684.
4736.
6356.
8040.
5038.
9331.
1772.
6995.
6766.
4946.
8290.
4390.
1*75.
t25.
625.
625.
2612.
TERMINATED
NO. NW
C 0.
1 140.
C 0.
C 0.
1 175.
3 340.
3 1637.
3 850.
1 47.
C 0.
1 23.
C 0.
C 0.
0 0.
0 0.
0 C.
0 0.
C 0.
C 0.
0 0.
0 0.
C 0.
C 0.
0 0.

TOTAL
NO.
1
0
4
12
19
19
22
27
37
50
69
89
100
122
127
138
150
15"
172
1T8
iei
182
183
184

ON LINE
«W
140.
0.
7C2.
122C.
29?3.
3250.
3631.
5567.
10204.
1494Q.
21273.
29313.
34351.
43682.
45454.
52449.
59215.
64161 .
72451.
76741.
78216.
78841.
79466.
80091.

                         137

-------
  EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
                                             SECTION 14
                    DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
   COMPANY  NAME
   PLANT  NAME
  C ITY
  STATE
  REGULATORY CLASSIFICATION
  PARTICULATE EMISSION  LIMITATION  -  N6/J
  S02 EMISSION LIMITATION  -  N6/J
  NET PLANT GENERATING  CAPACITY  -  MW
  GROSS UNIT GENERATING  CAPACITY - MH
  NET UNIT GENERATING CAPACITY W/F60 -  "W
  NET UNIT GENERATING CAPACITY UO/FGD - MU
  EQUIVALENT SCRUBBED CAPACITY - MW

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

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

  •* ESP
      NUMBER
      TYPE
      SUPPLIER
      PARTICULATE DESIGN REMOVAL EFFICIENCY
      FLUE GAS TEMPERATURE  - C

  •*  PARTICULATE  SCRUBBER
      NUMBER
      TYPE
      SUPPLIER
      SHELL MATERIAL
      LINING MATERIAL
      TYPE  OF  NOZZLES
      FLUE  GAS CAPACITY  - CU.M/S
      FLUE  GAS TEMPERATURE  -  C
      LIQUID RECl«CUL»TION  RATE  - LlTER/s
      L/6  RATIO - LITER/CU.M
      PRESSURE DROP  - KPA
      SUPERFICIAL GAS VELOCITY  -  M/S
      PAOTICULATE  INLET  LOAD  - G/CU.M
      PARTICULATE  DESIGN  REMOVAL  EFFICIENCY
- t
      COMMONWEALTH EDISON
      UILL COUNTY
      1
      ROMEOVlLLE
      ILLINOIS
      ******
         86.
        774.
       1U7.0
        167.0
        137.0
                <   .200
                <  1.800 LB/MMPTU)
     BABCOCK  g  UILCOX
     CYCLONE
     CYCLIC
      0/55
       3£3.36
       179.4
       107.
         3.S
                <  7700CO  ACFM)
                <  355  F)
                <  350  FT1
                <  12.4  FT)
                     <  9570 BTU/Lfi)
                     9.100 -  10.500
COAL

 22260.

    7.40
3-16

******
    1.50
0.3 - 4.5
COLD SIDE
WESTERN PRECIPITATION
   79.0
  179.4        <  355 F)
     VENTURI
     BABCOCK R UILCOX
     CARBON STEEL
     PLASITE AND KAOCRETE
     STAINLESS STEEL
       181.7        < 3S5000 ACFM)
       179.4        (  355 F)
       3(5.4        ( 5800 GPM)
         ?.*        <1S.O GAL/1000ACF>
     *******        (»***• jN-H20)
        36.6        (  120.0 FT/S)
          .4        (   .16 GR/SCF)
  X      98.0
-——————---———-—	--——-PERFORMANCE  DATA——
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION
                                                                 X REMOVAL   PER  BOILER  FGD    CAP
                                                                 S02  PART. HOURS HOURS  HOURS  FACTOU
3/75


A
B
SYSTEM
94.0
.0

99.2
.0

81.2
.0



744 609
                                                138

-------
                                             EPA UTILITY  fGO SURVEY:  JANUARY  -  MARCH  I960
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
	PERFORMANCE  OAT A.	
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY  UTILIZATION   T  OfMOVAL    P£"   BOILER  fGO   OP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR
       *• PROBLEMS/SOLUTIONS/COMMENTS
                         A VENTURI HOSE LEAK  FORCED  MODULE  A  OUT ONCE.
                         MODULE B WAS OUT OF  SERVICE TWICE  FOR  NO DEMAND AND ONCE AS A RESULT OF
                         ACCIDENTAL  50 MINUTE  TRIP.
                         COAL BURNED THIS MONTH  AVERAGED  LESS THAN ONE  PERCENT SULFUR.
 4/75
A
B
SYSTE"
                   37.0
            39.5
              .0
                        35.0
                          .0
                                                                              72C
                                                                                    6*5
        *«  PROBIEMS/SOLUTIONS/COMMENTS
                          CHICAGO  FLU  ASM  IS  TREATING MATERIAL FROM THE SCRUBPf WITH LIME  AND
                          ASH  AND  DUMPING  IT  INTO THE HOLDING BASIN.
                          A  BOILER OUTAGE  FORCED  MODULE A OUT OF SERVICE ONCE THIS MONTH  (MODULE
                          WAS  ALREADY  OUT  OF  SERVICE).
                                                                                        FLY
                          COAL  BURNED  THIS  MONTH WAS RECLAIM COAL AND VARIED IN SULFUR  CONTENT.
  5/75
A
e
SYSTEM
64.5
37.1
84.5
37.1
84.5
37.1
                                                                               744
                                                                                     744
        **  PROBLEMS/SOLUTIONS/COMMENTS
                          NODULE  P WAS  IN SERVICE ON "AY 20 FOR THE FIRST  TIME  SINCE  APRIL  13t  197J.
                          REC1RCULAT10N TANK MIXERS.
                          NODULE  A (WHICH WAS THE ONLY ONE OPERATING) WAS  FORCED  OUT  TWICE  IN APRIL
                          TO AVOID POND OVERBOARDING INTO THE DES PLAINES  RIVER.  THE  SECONO OUTAG?
                          LASTED  UNTIL  MAY 5. DURING THE PAST SEVERAL MONTHS  Of GENERALLY  CONTINUOUS
                          OPERATION OF  MODULE ». IT HAS BECOME APPARENT  THAT  THE  PRESENT LIQUID
                          CIRCULATING SYSTEM CANNOT BE OPERATED IN  A CONTINUOUSLY CLOSED CYCLE. THE
                          WATER IMBALANCE POSES A HIGH RISK Of OVERBOARDING  FROM  THE  SLUDGE POND
                          DURING  LONG PERIODS OF SUSTAINED OPERATON. THE  FOLLOWING REVISIONS HAVE
                          BEEN MADE TO  REDUCE THE WATER IMBALANCE:
                               1. THE PUMP GLAND WATER FLOWS HAVE BEEN CUT FROM 10 GPM TO  5 GPM.
                               2. THE SCRUBBER HOUSE SERVICE WATER  FILTER BACKWASH HAS BEEN ROUTED
                                  OUT OF THE SYSTEM.
                               3. THE CONTINUOUS UNDERSPRAY HAS BEEN CHANGED  TO AN INTERMITTENT
                                  SPRAY  5 MINUTES ON,  5 MINUTES OFF.
                          THE THICKENER  HAS BEEN DOWN  SINCE APRIL  21 DUE  TO A BROKEN  GEAR  AND A STUCK
                          SWEEP ARM. THE THICKENER  HAS BEEN BYPASSED AND  THE  SLUDGE IS GOING TO THE
                          POND.
                          DURING MAY, MODULE A WAS  OUT  FOR 45  MINUTES  DUE TO  A DAMPER TRIP.
                          NODULE  A WAS OUT ONCE  FOR  SPRAY NOZZLE  CLEANING.
                          NODULE B WAS OUT TWICE AFTER  START UP,  ONCE  FOR A VENTURI PUMP TRIP AND
                          ONCE FOR A RECIRCULATION  TANK LEVEL  TRIP.
                          CHICAGO FLY ASH IS TREATING  THE MATERIAL  FROM  THE SCRUBBER  WITH LIME  AND
                          FLY ASH AND  DUMPING  IT INTO  THE HOLDING BASIN. A MIXER HAS  BEEN INSTALLED
                          AT THE THICKENER,  WHICH ENABLES THEM TO SUBSTITUTE  SEALED DUMP TRUCKS  FOR
                          THE CEMENT TRUCKS  WHICH WERE  USED  IN THE  PAST  FOR MIXING AND TRANSPORTING
                          THE WASTE  MATERIAL TO  THE HOLDING  BASIN.
                          COAL BURNED  THIS  MONTH VARIED GREATLY  IN  SULFUR CONTENT, RANGING  FROM  LOW
                          SULFUR  WESTERN COAL  TO HIGH  SULFUR  ILLINOIS  COAL.
  6/75
 A
 B
 SYSTEM
 64.1
 85.5
 60.6
 84.6
 54.1
 75.4
                                                                               720    642
        ** PROBLEMS/SOLUTIONS/COMMENTS
                           A  REHEATER  PLUGGAGE  INSPECTION FORCED ONE NODULE A OUTAGE.
                           A  LOW  LEVEL TRIP CAUSED A 35 MINUTE OUTAGE, AND NO DEMAND  ACCOUNTED  FOR  TWO
                           MORE MODULE A  OUTAGES.
                           NODULE B  WAS  OUT FOR 95 HOURS TO CLEAN THE BOOSTER FAN  AND  DEMISTER.
                           HIGH BOOSTER  FAN VIBRATIONS CAUSED MODULE B> TO  SHUT  DOWN ON JUNE  30.
                           DURING THIS MONTH HIGH SULFUR COAL WAS BURNED IN A TwO  WEEK TEST, AND  LOW
                           SULFUR COAL WAS BURNED THE REST OF THE MONTH.
   7/75   A
         B
         SYSTEM
                .0
             79.2
               .0
             79.4
                            .0
                         73.5
                                                                                744
                                                                                      689
                                                 139

-------
 EPA UTILITY  FGD  SURVEY:  JANUARY - MARCH 1980

 COMMONWEALTH EDISON:  WILL  COUNTY 1 6
                                                140

-------
                                              EPA UTILITY FGD SURVEY:  JANUARY  - MARCH 1980

COMMONWEALTH EDISON: WILL  COUNTY  1  (CONT.)
......—....—	——	—-——PERFORMANCE DATA--	.......	--
PERIOD MODULE AVAILABILITY  OPERABIL1TY RELIABILITY UTILIZATION   T  REMOVAL   PER  BOILER  f6D   C«P.
                                                                  S02   PART. HOURS HOURS  HOURS FACTOR

       B             8.8         20.4                      8.5
       SYSTEM                                                                  744   309

       •*  PROBLEMS/SOLUTIONS/COMMENTS
                          UNIT 1 WAS DOWN FROM OCTOBER 11  THROUGH MARCH 19 FOR ITS BOILER TURBINE
                          AND SCRUBBER OVERHAUL.  THE  MAJOR ITEMS TO BE ACCOMPLISHED DURING  THE
                          OUTAGE WERE:
                               1. SIMPLIFICATION  OF THE  MILLING  SYSTEM CONTROL.
                               2. PULLING AND CLEANING OF THE  MODULE  B REHEATER  AND RETURNING  IT
                                  REPLACED WITH MARGINAL BUNDLES LEFT OVER FROM  MODULE  A.
                               3. CLEANING OF THE POND PUMP BAY.
                               4. REMOVAL OF THE  VENTUHI AND ABSORBER PUMP CHECK  VALVES  tONE  OF  THEM
                                  FAILED LAST SPRING  AND DESTROYED  A  PUMP  LINSR  AND IMPELLER).
                               5. CLEANING AND REPAIR OF THE VENTURI  NOZZLES AND  SUPPORTS.
                               6. REPAIR OF  CORRODED  REHEATER  SUPPORTS.
                               7. RESETTING  AND  ADJUSTMENT OF  ALL DAMPERS.
                               8. REVISION OF SCRUBBER CONTROLS  BY  REMOVING THE  CONTROLS  NO LONGE"
                                  USED OR NEEDED.
                               9. INSPECTION AND  CLEANING OF THE ENTIRE  SCRUBBER AND  RELATED
                                  EQUIPMENT.
                          NODULE A  WAS PUT INTO  THE  GAS  PATH ON MARCH 22  AND REMAINED AVAILABLE  FOR
                          SERVICE THE  REST OF THE MONTH.
                          NODULE B  HAD TO  REMAIN  OUT  OF  SERVICE UNTIL MARCH  29  WHILE  ITS REPAIRED
                          REHEATER  WAS INSTALLED.

  A/76  A            23.0         20.0                     19.2
        B                        49.3                     47.3
        SYSTEM                                                                  720   691

        ** PROBLEMS/SOLUTIONS/COMMENTS
                          UNIT  1 RETURNED  TO SERVICE APRIL 2 AFTER A  SHORT TURBINE CONTROL OUTAGE.
                          BOTH  MODULES CAME  ON  LINE JUST  BEFORE  THE  BOILER.
                          A  FIVE DAY  OUTAGE  OF  MODULE B WAS DUE  TO REHEATER  TUBE BUNDLE LEAKS.
                          SEVERAL MODULE B OUTAGES WERE  DUE TO  PLUGGED  ABSORBER TANK  SCREENS CAUSED
                          BY  MILL AND CLASSIFIER FAILURES  WHICH  ALLOWED  ROCK  TO GET  INTO THE SYSTEM.
                          NODULE B  WAS THOROUGHLY CLEANED.
                          ONLY  ONE  ABSORBER  PUMP IS  BEING USED  IN  MODULE B,  SINCE THE  1B2  PUMP LINER
                          FAILED AS A RESULT OF   A BROKEN  DISCHARGE VALVE. A  REPLACEMENT LINER IS
                          BEING INSTALLED.
                          A  SCRUBBER  TESTING AND EVALUATING PROGRAM  WAS  STARTED THIS MONTH.  MUCH  OF
                          THE LATTER  TWO WEEKS  OF THE MONTH WERE SPENT TRAINING THE  TESTING  PERSON-  .
                          NEL.  THE  PROGRAM WILL  PROVIDE  CHEMISTRY  DATA AND OPERATING CHARACTERISTICS

  5/76  A              .0           .0                        .0
        SYSTEM                                                                  744    665

        ** PROBLEMS/SOLUTIONS/COMMENTS
                          A  VENTRUI HOSE LEAK FORCED MODULE B OFF  ONCE THIS MONTH.
                          MODULE 6  WAS TAKEN OUT OF  SERVICE ONCE BECAUSE OF A PLUGGED  ABSORBER  TANK
                           SCREEN.
                          NODULE 6  WAS OFF ONCE  DUE  TO  A FOULED I.D. FAN.
                           NODULE B  WAS OUT OF THE GAS PATH ONCE DUE  TO NO DEMAND.

  6/76  A            52.0        44.2                     37.6
        B            86.2        84.5                     71.9
        SYSTEM                                                                   720    612

        ** PROBLEMS/SOLUTIONS/COMMENTS
                           NODULE A SUFFERED VENTURI  PUMP LINER  FAILURES  ON APRIL  78  WHEN  AN  INLET 16
                           INCH BUTTERFLY  ISOLATION  VALVE BROKE APART AND  FELL  INTO THE VENTURI  PUPP.
                           BOTH THE A  AND BACKUP  AB  VENTURI PUMP LINERS  WERE DESTROYED. MODULE A
                           REMAINED OUT  SERVICE  UNITL JUNE 9,  WHEN THE LINERS WERE  REPLACED.
                           NODULE A WAS  OFF  ONCE  FOR  SHEARED BYPASS DAMPER PINS.
                           I.D. BOOSTER  FAN  FOULING  FORCED MODULE A OFF  ONCE THIS MONTH FOR ABOUT
                           164 HOURS.
                           BOTH MODULES  WERE OFF  TWICE DUE TO NO DEMAND.  DURING THESE OUTAGES, THE
                           DEHISTERS  WERE  WASHED  AND ABSORBER TRAY SCALE* IF  ANY, WAS KNOCKED OFF.
                           NODULE B WAS  OUT  OF  THE GAS PATH FOR SEVERAL  SHORT  VENTURI LOW  FLOW TRIP
                           OUTAGES  DUE TO  A  PLUGGED, SCALED VENTURI  TANK SCREEN. AT THE END OF THE
                           MONTH, THE  MODULE WAS  TAKEN OUT TO CLEAN  THE  SCREEN.
                                                  141

-------
 EPA UTILITY FGD SU»VEY:  JANUARY  - MARCH 1980

 COMMONWEALTH EDISON: yiLL  COUNTY  1  (CONT.)
 	--	.....	.	PERFORMANCE DATA	
 PERIOD MODULE AVAILABILITY OPERABILlTY  RELIABILITY UTILIZATION
                                               x REMOVAL   PER  BOILER   FGD    c*p
                                               S02  PART. HOURS HOURS   HOURS  FACTOR
                           THE  MODULE  B  I.D.  BOOSTER FAN REOUIRED CLEANING  DURING  THE  MONTH.
                           THE  REHEATER  TUBES ARE SCALING, WHICH  RESULTS  IN  A  LOWER  HEAT  TRANSFER RATE
                           RATE,  AND  THEREFORE INCREASES I.D. BOOSTER FAN FOULING.  THE ONLY WAY Tn
                                                                THE ONLY WAY  TO
       CLEAN THE REHEATERS  EFFECTIVELY  IS  TO REMOVE THEM, WHICH DEMANDS A
       TIAL OUTAGE.
  7/76
        A
        B
        SYSTEM
 19.9
 86.?
   .0
 90.0
   .0
 72.3
                                                                                7*4
                                                                                      598
           PROBLEMS/SOLUTIONS/COMMENTS
                          MODULE A WAS  OFF  THE FIRST PART OF THE MONTH DURING REPAIRS  TO  THE  ABSORBrn
                          THE LATTER  PART OF  THE  MONTH THE MODULE WAS READY FOR SERVICE BUT  WAS
                          OPERATED BECAUSE  OF THICKENER-POND SLUDGE OVERLOADING.
                          MODULE B HAS  FORCED OFF ONCE TO BALANCE THB I.D. BOOSTER  FAN. AND  ONtF
                          WASH THE FAN.
                          MODULE B WAS  OUT  OF THE GAS PATH TWICE DUE TO NO DEMAND.
  8/76
        A
        B
        SYSTEM
 98.2
 65.4
 57.6
 61.4
 3?.3
 4P.9
                                                                               744
                                                                                      495
           PROBLEMS/SOLUTIONS/COMMENTS
                          HOOULE A WAS OUT  OF  THE  GAS PATH THE FIRST HALF OF THE MONTH T  AVOID
                          THICKENER-POND OVERLOADING.
                          DURING THE LATTER  HALF OF  THE  MONTH, MODULE A WAS USED WITH THREE  MIMflB
                          FORCED OUTAGES AND ONE FOUR DAY  NO DEMAND OUTAGE.
                          NODULE B WAS OUT  OF  THE  GAS PATH THREE TIMES DUE TO NO DEMAND.
                          LOSS OF CHEMICAL  CONTROL CAUSED  TWO MODULE A OUTAGES.
                          MODULE B WAS OFF  FOR  NINE  DAYS  DUE TO FOULING.
                          SPENT SLURRY VALVE REPAIRS  FORCED  A MODULE B OUTAGE.
                          ON AUGUST 12 THE  OPERATING  PH  CONTROL SET POINT WAS REDUCED FROM  5  4  TO
                          5.1. IT is BELIEVED  THAT THIS  LOWER PH is THE CAUSE OF THE FOULING"OUTAI-«:
                          OF MODULE B ON AUGUST 21.  MODULE A WAS ALSO OPERATED FOR THREE  DAYS   AMn
                          IT, TOO, EXPERIENCED  INCREASED  SACLE FOULING. THE PH SET POINT  WAS  THE*
                          INCREASED BACK TO  5.4.
 9/76
       A
       B
       SYSTEM
42.3
79.4
28.7
                         22.6
                         59.9
                                                                               720   566
          PROBLEMS/SOLUTIONS/COMMENTS
                          NODULE A WENT OFF ONCE DUE  TO A  LOW  FLOW  TRIP.
                          NODULE A WAS TAKEN OFF ONCE FOR  CLEANING  OF  THE  RECIRCULAT ION TANK AND
                          PUMPS, AND.INSPECTION OF PUMP ISOLATION VALVES.
                          A LINER LEAK IN 1A2 ABOSOHBER PUMP ALSO FORCED MODULE A OFF.
                          NODULE A WAS OUT OF TH GAS  PATH  TWICE  DUE  TO NO  DEMAND.
                          NODULE A WAS TAKEN OFF ONCE TO AVOID THICKENER-POND OVERLOADING.
                          SPENT  SLURRY VALVE TROUBLE  CAUSED TWO  MODULE  B OUTAGES.
10/76
       A
       B
       SYSTEM
27.9
76.4
28.9
56.2
37.9
54.8
                                                                               744
                                                                                     726
       *• PROBLEMS/SOLUTIONS/COMMENTS
                          HIGH  SULFUR  ILLINOIS COAL WAS BURNED  IN THE BOILER  FROM  MARCH THROUGH
                          OCTOBER.
                          THE SCRUBBER HASTE MATERIAL HAS TREATED HITH LIME  AND  FLY  ASH AND HAULER  tn
                          AN OFF  SITE  DISPOSAL AREA.                                             tv  T°
                          NODULE  A  OPERATED ON ONE ABSORBER PUNP, ALLOWING  TESTING ON A LOWER
                          ABSORBER  FAN.
                          HOOULE  A  HAS OUT OF THE GAS PATH ONCE FOR AN I.D.  BOeOOSTEH FAN TRIP.
                          WORK  ON RECIRCULATION TANK LEVEL CONTROLS CAUSED  A  MODULE  A OUTAGE.
                          NODULE  B  HAS FORCED OFF ONCE TO REPAIR A REHEATER  HEADER LEAK.
                          ONE MODULE B OUTAGE HAS FOR VENTURI N027LE CLEANING.
                          NODULE  B  WENT  OFF FOR A VENTURI LOU FLOW TRIP.
                          NODULE  B  REMAINED OUT OF SERVICE WHILE NODULE A HAS BEING  TESTED TO AVOID
                          THICKENER-POND OVERLOADING.
                          A VACUUM  FILTER WAS TIED IN AT THE THICKENER.
                                                142

-------
                                              EPA UTILITY  fGO  SURVEY: JANUARY - MURcH

COMMONWEALTH EDISON:  WILL  COUNTY  1  UONT.)
		PERFORMANCE  DATA	
PERIOD MODULE  AVAILABILITY  OPERARILITY RELIABILITY  UTILIZATION  X REMOVAL   PER   BOILER   FGD   C«P.
                                                                  $02  PART.  HOURS  HOURS   HOURS FACTOR
11/76


A
B
SYSTEM
20.1 25.6
72.2 69.6

20.1
4.7



7?0 566
        **  PROBLEMS/SOLUTIONS/COMMENTS
                          MODULE A OPERATED  ON  ONE  ABSORBER PUMP DURING  MODULE  B  OUTAGE.
                          MODULE B WAS  FORCED  OUT OF THE GAS PATH ONCE  FOR  A  MILLING SYSTEM FAILURE.
                          MODULE f ENCOUNTERED  A  VENTURI HEADER LEAK.
                          THE VENTURI NOZZLES  REQUIRED CLEANING DURING  THE  MONTH.
                          REPLACEMENT Of  THE SPENT  SLURRY VALVE NECESSITATED  A  »OOULE OUTAGE.
                          MODULE f WAS  OFF  ONCE DUE TO A CHEMICAL SYSTEM UPSET.
                          MODULE B WAS  OUT  Of  THE GAS PATH TWICE DUE TO NO  DEMAND (MODULE A taAS  NOT
                          IN SERVICE  AT  THE  TIME  OF THE OUTAGE).

 12/76  A           44.0         4B.3                     44.9
        B           53.4         51.7                     48.0
        SYSTEM                                                                  744    692

        ** PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  THE  LAST WEEK OF NOVEMBER, THE  1«2  ABSORBER  PUMP HAS TAKEN OUT  OF
                          SERVICE  FOR OVERHAUL. THE REPAIRS WERE  COMPLETED  ON DECEMBER  6, yHEN  THF
                          MODULE  ASSUMED A ONE ABSORBER PU«P STANDBY CAPABILITY  UNTIL THE  1A1  ABSOR-
                          BER PUMP CAN  BE REPAIRED.
                          DURING  THE  LAST HALF OF THE MONTH, MOOUELE A OPERATED  WHILE MODULE  B  WA<
                          BEING  REPAIRED.
                          MODULE  P PERFORMED SAT1SFACT10RILY DURING  THE FIRST HALF  OF THE MONTH,
                          EXPERIENCING ONLY ONE NO  DEMAND  OUTAGE. ON THE 17TH, HOWEVER, THE  SPENT
                          SLURRY  VALVE  FAILED  AND THE MODULE HAS  REMAINED OUT or  SERVICE.

  1/77  A           98.?         98.7                      95.8
        8           13.5          1.1                       1.1
        SYSTEM                                                                   744    722

        *• PROBLEMS/SOLUTIONS/COMMENTS
                          THE  1A1 ABSORBER  PUMP  KENT  OUT  IN LATE  SEPTEMBER WITH  BURNED  OUT  BEARINC-S
                          AND  REMAINED OUT  THROUGH  JANUARY WAITING FOR  PARTS.
                          LOU  SULFUR  COAL WAS  BURNED  IN THE BOILER FROM NOVEMBER THROUGH JANUARY.
                          DUE  TO THE  LOU VOLUME  OF  SLUDGE  PRODUCED WHILE BURNING LOU SULFUR  COAL,
                          MUCH  OF THE SLUDGE HANDLING TIME WAS SPENT DIGGING OUT THE ACCUMULATED
                          SLUDGE IN  THE  REC IRCULAT ION PONDS.  THIS MATERIAL,  ALONG WITH  SCRUBBER
                          WASTE MATERIAL, WAS  TREATED WITH LIME AND FL1ASH AND  HAULED TO AN OFF
                           SITE  DISPOSAL  AREA.
                          MODULE A WAS  FORCED  OUT  ONCE  BY A FAILED  SPENT SLURRY  VALVE.
                           PLUGGED DEMISTED  UNDERSPRAYS  CAUSED  ANOTHER  MODULE  A  OUTAGE.
                          MODULE A WENT  OUT ONCE BECAUSE OF NO DEMAND  AND  ONCE  DUE  TO A BOILER  OUTAGE
                           (MODULE B  WAS  ALREADY  OUT OF  SERVICE FOR  REPAIRS).
                          MODULE B BECAME  AVAILABLE FOR SERVICE ON  JANUARY 27. AFTER REPAIRS TO  THE
                           SPENT SLURRY  VALVE  WERE  COMPLETED. DUE TO SEVERE HEATHER  CONDITIONS!  THf
                           MODULE WAS PLACED IN THE  GAS  PATH JANUARY 31.

  2/77   A            38.8         42.6                     38.8
         B            72.0         45.7                     41.7
         SYSTEM                                                                   672   613

         «* PROBLEMS/SOLUTIONS/COMMENTS
                           THERE WAS  VERY LITTLE  DIGGING IN THE RECIRCULATION PONDS. CHICAGO FLYASH
                           SPENT MOST OF  THEIR  TIME ON CLEANING AND  MAINTENANCE.

  ,/77   A           96.9         6«.7                    6«.2
         B           80.9         75.5                     73.9
         SYSTEM                                                                   744    728

         ** PROBLEMS/SOLUTIONS/COMMENTS
                           AN ERT  S02 ANALYZER WAS  INSTALLED ON  THE  DISCHARGE SIDE  OF MODULE  B  I.D.
                           BOOSTER FAN.  THIS IS AN  "IN  SITU" ON-DISPERSIVE  ANALYZER  THAT  CONTINUALLY
                           MEASURES AND READS  OUT CONCENTRATIONS  OF  S02, CO,  C02, AND NO.
                           AN ABSORBER  SUCTION HEADER LEAK  FORCED  MODULE 6 FROM  THE  6AS PATH.
                           MODULE  FJ UAS FORCED OUT  DUE  TO  A SLURRY  VALVE GASKET  LEAK.
                                                   143

-------
EPA UTILITY FGD SURVEY:  JANUARY  - MARCH 1980

COMMONWEALTH EDISON: WILL  COUNTY  1  (CONT.I
..	.	.	...	...—-PERFORMANCE DATA-- —
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION
                                               *  REMOVAL    PER   BOILER  FGD   CAP
                                               SO?   PART.  HOURS HOURS  HOURS FACTOR
                          A  PLUGGED  FEED SLURRY RECIRCULAT1ON LINE WAS ENCOUNTERED  IN  MODULE  B
                          HIGH  SULFUR  COAL WAS BURNED FOR SEVEN DAYS THIS MONTH  TO  PROVIDE  HIGH
                          SULFUR  SLUDGE  FOR THE UOP SLUDGE TEST.
                          CHICAGO FLYASH SPENT 75* OF THEIS TINE DIGGING IN THE  POND.  THE  REST U*S
                          SPENT ON THE  THICKENER AND VACUUM FILTER IPERATION. THE SCRUBBER  WASTE
                          MATERIAL WAS  TREATED WITH LIME FLYASH AND HAULED OFF SITE.
                          DISPOSAL AREA.
 4/77  A
       B
       SYSTEM
 86. 1
 45.5
 67.7
 3P.2
 61.?
 27.3
                                                            720    65C
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         THE PERFORMANCE  OF  THF  ERT SG2 ANALYZER TO DATE HAS BEEN, AT BEST   UNREII.
                         BLE AND  INCONSISTENT.  THE EOT TECHNICIANS ARE OUT TO SERVICE THE  ANALYZES
                         ALMOST EVERY  OTHER  DAY. THE  PROPLEM, ACCORDING TO ERT TECHNICIANS,  is  or •
                         "THERMAL NATURE".  WHEN  THE ANALYZES REACHES A CERTAIN TEMPERATURE   A CMTD
                         SHORTS OUT. THEY HAVE  NOT BEEN ABLE TO LOCATE THE FAULTY  INTEGRATED
                         YET.
                         A BOILER TUBE  LEAK  REPAIR FORCED MODULE A OUT OF THE GAS  PATH  ONCE  THIS
                         MONTH  (MODULE  6  WAS  ALREADY  DOWN FOR REPAIRS).
                         MODULE B WAS  FORCED  OUT OF THE GAS PATH TWICE FOR AN ABSORBER  SUCTION
                         HEADER LEAK REPAIR.
                         MODULE P WAS  OUT OF  SERVICE  ONCE TO WASH THE I. D. BOOSTER  FAN.
                         CHICAGO  ADMIXTURES  SPENT MOST OF THEIR TIME DIGGING IN THE  SMALL  POND
                         GETTING  PEADY  FOR  THE  MGO ADDITION AND FORCED OXIDATION TEST.  THE  SC
                         WASTE MATERIAL WAS  TREATED WITH LIME AND FLYASH AND HAULED  TO  AN  OFF
                         DISPOSAL AREA.
 5/77  A
       B
       SYSTEM
89.*
98.0
 2.2
5C.9
 2.0
47.3
                                                                              744   691
       *•  PROBLEMS/SOLUTIONS/COMMENTS
                         THE ERT S02 ANALYZER  HAS  BEEN  REMOVED  FROM SERVICE DUE TO A POOR  PERFORM
                         ANCE RECORD OVER  THE  LAST THREE  MONTHS. EOT IS IN THE PROCESS OF  RE-
                         ENGINEERING THEIR  ANALYZER.
                         THE MGO ADDITION  TEST  WENT  WELL. ALTHOUGH THE MGO INCREASED S02 RENOVA1
                         EFFICIENCY ABOUT  10X,  IT  DID PRACTICALLY NOTHING FOR THE TWO MORE  SERIOnc
                         PROBLEMS, SINCE THICKENER AND  SLUDGE  PRODUCTION AND LIMESTONE CONSUMDTT«^
                         HATE WERE ABOUT THE SAME.                                      «™»«ncTION
                         NODULE A WAS FORCED OUT OF  THE GAS  PATH ONCE  THIS MONTH WHEN THE  INLET
                         VALVE ON 1A? ABSORBER  PUMP  FAILED.
                         MODULE B WAS TAKEN OFF TO CLEAN  AND INSPECT THE REHEATER TUBES.
                         BOTH MODULES HERE  FORCED  OFF FOR THE  FIRST FIFTEEN DAYS OF THE MONTH Due T
                         A FAILED 120V CONTROL  TRANSFORMER FOR  THE POND RETURN PUMPS. THE  TRANSFORM
                         ER HAD TO BE ORDERED  FROM  WESTINGHOUSE.
                         HIGH SULFUR COAL HAS  BURNED  FOR  ELEVEN  DAYS DURING THE MONTH.
6/77
       A
       B
       SYSTEM
31. f
93.2
13.3
93.*
10.5
73.5
                                                                              720   566
      •* PROBLEMS/SOLUTIONS/COMMENTS
                         THE 1»1 ABSORBER PUMP IS STILL OUT  OF  SERVICE  WAITING FOR PARTS 1AJ
                         ABSORBER PUMP'S ISOLATION VALVES  FORCED  MODULE  A  OFF FOR MOST OF T(E MONTH
                         NODULE A HAD ONE NO DEMAND  AND ONE  BOILER  OUTAGE  THIS MONTH.               '
                         NODULE B UAS ALSO FORCED OFF TO CLEAN  THE  I.D.  BOOSTER FAN.
                         NO HIGH SULFUR COAL WAS BURNED THIS  MONTH.
7/77
      B
      SYSTEM
                   70.3
                               41.4
                                                       21.0
                                                           744
                                                                 377
      •* PROBLEMS/SOLUTIONS/COMMENTS
                         HIGH SULFUR COAL HAS BURNED FOR EIGHT  CAYS  THIS  MONTH. LIMESTONE OPERATION
                         WAS NORMAL FOR HIGH SULFUR OPERATION.
                         NODULE  B HAS FORCED OUT OF THE GAS PATH ONCE  TO  REMOVE A PLUGGED DIFFUSED
                         THE FINAL TEST, FORCED OXIDATION SEEMDD TO  BE  THE  MOST SUCCESSFUL OF ALL
                         USING LIQUID OXYGEN, UP TO 12,000 CFM  OF GASEOUS 02  UAS FED INTO EACH   *
                         VENTUftI DOUNCOMEff, OXIDATION OF SULFITE TO  SULFATE WAS INCREASED FROM

-------
                                              EPA UTILITY  FGO SURVEY: JANUARY - MARCH  19»C
COMMONWEALTH EDISON: WILL COUNTY  1  (CONT.)
	PERFORMANCE DATA--	
PERIOD NODULE  AVAILABILITY  OPERAE1LIT1  RELIABILITY UTIL17AT10N
                                                          Tt  REMOVAL    PEP  BOILER  FGD   CAP.
                                                          S02   PART. HOURS HOURS  HOURS FACTOR
                          35  TO  90 X
                          NODULE  B WAS  ALSO FORCEO OFF DUE TO A LOW LEVEL  IN  THE  SLURRY  STORAGE
                          NODULE  B WAS  ALSO FORCEO OfF DUE TO REHEAT6R TUBE  BUNDLE LEAKS.
                                                                                         TANK.
 9/77
A
B
SYSTEM
99.8
 9.7
99.6
12.0
            8C.8
             9.7
           PROBLEMS/SOLUTIONS/COMMENTS
                          NODULE » WAS AVAILABLE THE ENTIRE MONTH WITH  JUST  THE VENTURI PUMP OPERAT-
                          ING.
 9/77
A
B
SYSTEM
61.0
52.3
77.8
75.4
            54.0
            5?.3
                                                                               720   499
        «• PROBLEMS/SOLUTIONS/CONNENTS
                          MODULE B ENCOUNTERED HIGH VIBERATIONS  IN  ITS BOOSTER FAN DURING THE FIRST
                          WEEK Of THE MONTH. AFTER THE  FAN  WAS BALANCED, THE MODULE OPERATED  INT1L
                          THE UNIT OUTAGE ON SEPTEMBER  21.
 13/77  A             .0
        B             .0
        SYSTEM

 11/77  A             .0
        B            8.8
        STSTEM
                         50.1
                                                   .
                                                   .0
                                                   .0
                                                                        744
                                                                        720   126
           PROBLEMS /SOLUTIONS/COMMENTS
                          UNIT ONE CAME UP  ON  NOVEMBER  25 AFTER A SIXTY-THREE  DAY  OUTAGE.
                          MODULE B IS  IN  THE GAS  PATH FATED EXPERIENCING SOME  OIFICULTT  IN  BALANCING
                          ITS BOOSTER  FAN.
 12/77
 A
 B
 STSTEM
 42.5
 84.1
 42.5
 84.1
47.8
94.6
42.5
84.1
                                                                                744
                                                                                      661
           PROBLEMS/SOLUTIONS/COMMENTS
                          PLUGGAGE  WAS  ENCOUNTERED IN TH EMOOULE e REHEATEK.  PECAUSE  NO  SPARE REHRAT
                          COILS  WERE  AVAILABLE,  THE UTILITY TRIED TAKING  SOME  COILS  fROM MODULE A
                          MODULE  B  APPEARED  TO BE MORE ORE SEVERELY PLUGGED THAN  ORIGINALLY THOUGHT.
                          MODULE  »  UAS  DOWN  HALF THE MONTH BECAUSE 01  A  MAIN  STEAM LEAK  WHICH COULD
                          NOT  BE  ISOLATED.
                          MODULE  A  OPERATED  UNTIL SEPTEMBER 19, WH E A COMBINATION OF MUD AND SCALE
                          BUILD-UP  ON THE SUMP FLOOR STRUCTURALLY DAMAGED THE MODULE. REPAIRS PUT
                          THE  MODULE  OUT OF  SERVICE UNTIL HID DECEMBER.
  1/78
 A
 B
 STSTEM
 69.0
 22.0
 89.9
 29.6
             66.3
             22.0
                                                                                744
                                                                                      549
        **  PROBLEMS/SOLUTIONS/COMMENTS
                           ON  JANU1RT 7, THE MODULE B I.D. BOOSTER  FAN  DISCHARGE DUCT STARTED VIBRAT-
                           ING WILDLY. THIS FORCED THE BOILER  OFF WHILE  THE  SHOP MADE REPAIRS TO THE
                           DUCTWORK AND BALANCED THE FAN WITH  AN  I.fl.D.  MACHINE.
                           WHEN THE UTILITY ATTEMPTED TO POT MODULE  B BACK IN THE GAS PATH. A LEAK  IN
                           THE SLURRY LINE FORCED IT BACK  OFF.
                           A PLUGGED VENTURI POMP FORCED MODULE B OFF  THE REST OF THE MONTH.
                           DURING THE OUTAGE, THE REHEATER COILS  HERE  CLEANED WITH A HIGH PRESSURE
                           (5000 LB) SPRAYER.
                           NODULE A UAS FORCED OFF WHEN  A  STEAM REGULATING VALVE BLEU ITS PACKING.
                           ON  THE 23RD, BOTH MODULES WERE  TAKEN OFF AND DRAINED TO ALLOW THE  SHOP  TO
                           INSTALL NEW ISOLATION VALVES  IN THE ABSORBER AND VENTURI PUMPS.
                           TOWARD THE END OF THE MONTH,  SOME PROBLEMS  WERE ENCOUNTERED WITH THE  POND
                           RETORN PUMPS FREEZING.
   2/78   A
         B
         STSTEM
             40.9
             69.5
              56.5
              92.9
                          34.4
                          56.5
                                                                                 672    409
                                                  145

-------
EP« UTILITY  FGD  SU»VEY:  JANUARY - MARCH 198C

COMMONWEALTH EDISON:  WILL  COUNT*  1 .
                          MODULE  B  OPERATED VERY WELL AND AN INSPECTION  SHOWED THE MODULE TO BE VERY
                          CLEAN.

 3/78  A           93.5        100.0         90.6
       B           88.5         84.7         76.0        26.2
       SYSTEM                                                                  744    230

       ** PROBLEMS/SOLUTIONS/COMMENTS
                          THIS MONTH,  DUE TO COAL CONSERVATION, UNIT  1  WAS ON  THE  SYSTEM VERY LITTIt
                          MODULE  B  HAD  DIFFICULTY FOR SEVERAL DAYS BECAUSE OF  A  CRACKED SHEAVE ON TM
                          VENTURI PUMP.                                                                E
                          HIGH PRESSURE  CLEANING ON BOTH MODULES DURING  THE  COAL  CONSERVATION ALONG
                          WITH  REMOVING  THE VENTURI THROAT RESTRICTOH BLOCKS  PROVED  BENEFICIAL IN
                          MAINTAINING BETTER CONTROL OF THE DRAFT CONDITIONS  IN  THE  SCRUBBER.

 4/78  A           99.9         99.7                     92.0
       B          100.0         99.9                     92.2
       SYSTEM                                                                  720    665

       ** PROBLEMS/SOLUTIONS/COMMENTS
                          THE PRESSURE  DIFFERENTIAL ACROSS THE VENTURIS HAS  BEEN  REDUCED BY  APPRO*!
                          MATELY  40X AT  140 MW BY REMOVING THE VENTURI RESTRICTOR  BLOCKS. PARTICULAR
                          REMOVAL AND SOLIDS CARRYOVER  COULD BE ADVERSELY AFFECTED BY  THIS  ACTION
                          SINCE PARTICULATE REMOVAL AT  THE VENTURI  IS A  FUNCTION  OF  WATER DROPLET*
                          SIZE, WHICH IN  TURN  IS A  FUNCTION OF PRESSURE DROP.  INCREASED SOLIDS CAPRv
                          OVER COULD POSSIBLY  COMPUNO REHEATER PLUGGING PROBLEMS.  THE  UTILITY IS
                          KEEPING A CLOSE MATCH FOR PLUGGING, BUT HAS NOT YET  FOUND  ANYTHING UNUSim
                          MODULE  A WAS FORCED  OUT OF  THE  GAS  PATH ONCE THIS MONTH  FOR  A VENTURI PTcc
                          LEAK.                                                                    4PE

 5/78  A             9.5        99.4                     55.2
       B            89.?       100.0                     56.1
       SYSTEM                                                                  744    413

       **  PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  THE LAST PART OF THE MONTH BOTH MODULES WERE  FORCED OUT OF  THE GAS
                         PATH DUE TO REHEATER  LEAKS. IT  REQUIRED A TWO DAY OUTAGE TO  REMOVE  THE
                         LEAKING REHEATER  BUNDLES. ADDITIONAL REHATERS ARE ON ORDER AND ARE  EXPECT
                         ED TO ARRIVE IN  JUNE.

 6/78   A            87.1         94.5                     25.7
       B            85.6        100.0                     25.1
       SYSTEM                                                                  720    181

       **  PROBLEMS/SOLUTIONS/COMMENTS
                         DURING A SCRUBBER  INSPECTION. 25X DIEMISTER  AND 75X  ABSORBER  SPRAY  PLUGGAGF
                         WAS DISCOVERED  IN  MODULE  A. MODULE  B  WAS  NOT AS BAD.
                         HIGH VIBRATION  WAS ENCOUNTERED  IN THE  TURBINE BEARINGS DURING  BOILER  STABT
                         UP, CAUSING THE BOILER  TO SHUT  BACK  DOWN.
                         THE PUG MILL FOR  CHICAGO  ADMIXTURES  HAS BEEN APPROVED, AND THE  NEW  SLUDGE
                         TREATMENT  SYSTEM  SHOULD BE  OPERATING  BY  FALL.
                         THE SCRUBBER WAS  FORCED OUT OF  THE  GAS  PATH  ONCE THIS MONTH  WHEN THE  161
                         ABSORBER DISCHARGE VALVE  FAILED  TO  OPEN.
                         THE BOILER WAS  FORCED  OFF  THE LAST  FOUR DAYS OF THE MONTH FOR  CYCLONE
                         LEAKS. DURING THIS OUTAGE.  THE  A  AND  B  MODULE SPENT  SLURRY VALVES
                         WERE REPLACED.

7/78  A            97.0        100.0                    11.6
      B            99.?        100.0                    11.6
      SYSTEM                                                                   744    77
                                               146

-------
                                              EPA UTILITY FGO SURVEY:  JANUARY  -  MARCH
COMMONWEALTH EDISON; WILL  COUNTY  1  
-------
EP» UT1LJTH FGO  SURVEY:  JANUARY -MARCH 1980

COMMONWEALTH EDISON:  WILL  COUNTY 1 (CONT.)
.	-—-----PERFORMANCE  DATA	—	...	_
PERIOD MODULE AVAILABILITY  OPERABILITY RELIAB1L1TT  UTILISATION   *  REMOVAL   PER  BOILER  F6D   "cAp~~
                                  			502   PART. HOURS HOURS  HOURS  FACTOR
       e
       SYSTEM
                    85.2
                               100.0
                                      48.3
                                                                               720   348
       *• PROBLEMS/SOLUTIONS/COMM6NT5
                          THE  UNIT HAS DOWN THREE TIMES  THIS  MONTH  DUE  TO A  VENTURI  PUMP AND
                          BOOSTER FAN OUTAGES.
12/78  A
       e
                    65.3
                    64.5
             100.0
             100.0
                          64.5
                          64.5
                                                                               744    4*0
          PROBLEMS/SOLUTIONS/COMMENTS
                          REHEATER TUBE LEAKS CAUSED TwO OUTAGES.
                          THE  MODULE  B SPENT SLURRY DRAIN WAS REPAIRED,
 1/79
       A
       B
       SYSTEM
 83.5
 62.2
100.0
 87.1
                                                        61.3
                                                        5!.4
                                                                               744
                                                                                     456
          PROBLEMS/SOLUTIONS/COMMENTS
                          THE  S02  PLANT WAS FORCED OFF TWICE THIS MONTH  DUE  TO  REHEATER  TUBE
                          TWO  TUBES  ON  MODULE A AND FOUR TUBES ON MODULE B WERE  REPLACED.
                          THE  I.D. BOOSTER FAN ON MODULE B WAS FOULED AND HAD  TO BE  REPLACED
                          TWO  SPECIAL SECTIONS Of VENTURI PIPING, A SIXTEEN  TO  EIGHT  INCH ECCEKTBir
                          REDUCER  AND AN  OFFSET TEE WERE PREPARED BY LOCKPORT  FABRICATING AND INST.
                          LEO  THIS MONTH. THE ORIGINAL REDUCER AND TBE HAD BEEN  PATCHED  AND WELDED  5
                          MANY  TIMES  THAT THEY WERE BEYOND REPAIR.
 2/79
       A
       B
       SYSTEM
 93.0
 93.0
 91.3
 91.3
                                                        54.2
                                                        54.2
                                                                               672    399
       •* PROBLEMS/SOLUTIONS/COMMENTS
                         THE UNIT  WAS  FORCED OFF ONCE FOR A MAIN STEAM HEADER LEAK.
 J/79
       A
       B
       SYSTEM
100.0
 68.6
100.0
100.0
                                                        46.0
                                                        46.0
                                                                               744    343
          PROBLEMS/SOLUTIONS/COMMENTS
                         THE SYSTEM  WAS  FORCED  OUT TWICE IN FEBRUARY AND FOUR TIMES  IN  MARCH DUE
                         TO A VENTURI  HEADER  LEAK. A TEN FOOT SECTION OF PIPE WILL  HAVE  TO BE
                         REPLACED DUE  TO EXTENSIVE CORROSION.
                         THE SYSTEM  WAS  DOWN  ONCE  FOR A SPRAY HEADER LEAK.
                         NODULE B EXPERIENCED A LEAK IN THE VENTURI DOWNCOMER. A  FIVE  FOOT SECTin
                         OF THE PIPE HILL  HAVE  TO  BE REPLACED.                                  1ON
 4/79   A
       SYSTEM
5/79
       A
       e
       SYSTEM
                                                                              720
                                                                              744
       *•  PROBLEMS/SOLUTIONS/COMMENTS
                         UNIT 1 WAS OUT OF SERVICE  THE  ENTIRE  MONTH DUE TO A BOILER OVERHAUL
                         CHICAGO ADMIXTURES WILL  STOCKPILE  THE FIXED SLUDGE ON STATION PROPERTY
6/79   SYSTEM

7/79   SYSTEM

8/79   SYSTEM
                                                            720

                                                            744

                                                            744
                                                        0
                                                        c
         PROBLEMS/SOLUTIONS/COMMENTS
                         UNIT 1 WAS OUT OF SERVICE  TO  REPLACE  THE  AIR HEATER TUBES, TUBE SHEET  ANh
                         HOPPERS.  DURING THIS OUTAGE.  THE  WORN VENTURI  SPRAY NOZZLES AND DEMISTEBC
                         WERE REPLACED.  WELDING LEAKS  AND  GENERAL CLEANING OF THE S02 INTERNALS
                         WAS ALSO DONE AT THIS TIME.
                                               148

-------
                                              EPA  UTILITY  F60 SURVEY: JANUARY - MARCH 196C
COMMONWEALTH EDISON: WILL COUNTY 1  (CONT.)
„„__„......—.	.	-PERFORMANCE DATA	—	
PERIOD MODULE AVAILABILITY  OPtRABILITV  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD    CAP.
                                                                 SO?  PART. HOURS HOURS   HOURS  FACTOR
                          THE  BOILER  AND THE SCRUBBER ARE SCHEDULED TO RETURN  TO  SERVICE  OCTOBER  1.
                          1979.
 9/79   SYSTEM

10/79   SYSTEM

11/79   A
        B
        SYSTEM
           53.3
           53.3
           53.3
           100.0
           100.0
           100.0
                        85. *
                        85.4
                      720

                      744



                      720
  0

  c


336
           PROBLEMS/SOLUTIONS/COMMENTS
                          ON NOVEMBER 5, UNIT 1 RETURNED TO  SERVICE  AFTER  A SIX MONTH OUTAGE TO
                          REPLACE THE AIR HEATER TUBES, TUBE  SHEET  AND  HOPPERS.
                          DURING THE OUTAGE, SEVERAL LENGTHS  OF  VENTURI PIPING HAD TO BE REPLACED
                          UITH NEW RUBBER LINED PIPE.
                          THE UNIT DID NOT FORCE THE BOILER  OFF  AT  AMY  TIME DURING NOVEMBER.
 12/79  A           77.0        99.5
        B           84.9       100.0
        SYSTEM      77.0        99.5
                                                57.5
                                                57.8
                                                57.5
                                                           744    431
                                                            428
           PROBLEMS/SOLUTIONS/COMMENTS
                          ON DECEMBER 4, UNIT  1  CAME  OFF  LINE  SO THAT THE AIR HEATER HOPPERS  AND
                          PRECIPITATOR HOPPERS  COULD  BE  EMPTIED  Of CARBON CARRY-OVER AND DEBRIS.
                          DURING THIS OUTAGE THE  SHOP REPAIRED A LEAK IN THE POND RETURN LINE.
                          ON DECEMBER 10, THE  A  MODULE DEVELOPED A SE.R10US STEAM LEAK  <25,000 MAKE-
                          UP) IN A LOWER REHEAT  BUNDLE.   THE LEAKING BUNDLE HAD TO BE  REMOVED AND
                          REPLACED.  THIS RESULTED  IN A  TWO DAY  FORCED OUTAGE.  LATTER  IN  THE MONTH
                          THE A MODULE BLEU  ANOTHER  REHEATER TUBE FORCING THE BOILER OFF FOR  AN
                          ADDITIONAL 25  HOURS  AND 12  MINUTES.
                          THE A NODULE 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 HW  BECAUSE THE RE-
                           HEATER  SECTIONS ON A AND B MODULES WERE PLUGGING.  ON JANUARY 17, THE
                           MODULES WERE  TAKEN OUT OF THE GAS PATH TO  BEGIN REMOVING  AND CLEANING THE
                           REHEATER SECTIONS WITH A HIGH PRESSURE (4CQO PSI> WATER SPRAY.  UNIT 1
                           BOILER  WAS LEFT ON TO PROVIDE STABILITY FOR THE 138 KV SYSTEM.
                           IN  THE  PAST,  ALL FORTY-TWO 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 WAS  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 BOTTO"
                           BUNDLES.  THERE ARE DOORS THAT ALLOW  EASY  ACCESS TO THE TOP AND BOTTOM
                           OF  THE  REHEATER.  USING THIS METHOD,  ONLY  TWELVE OF THE FORTY-TWO 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
                           TWENTY  HOURS.
                           THE B NODULE WAS  FORCED OFF LINE  ON  TWO  OTHER  OCCASIONS  IN  JANUARY.   BOTH
                           THESE OUTAGES  WERE  CAUSED BY  THE  REHEATER  
-------
EPA UTILITY  FGD  SURVEY: JANUARY  - MARCH 1980

COMMONWEALTH  EDISON: WILL COUNTY  1 (CONT.)
	PERFORMANCE  DATA	.._...	
PERIOD MODULE  AVAILABILITY OPERABlLlTY RELIABILITY  UTILIZATION  t REMOVAL    PER  BOILER   FGD    CAR
                                                                   SO?   PART.  HOURS HOURS  HOURS  FACTOR

       ** PROBLENS/SOLUT10NS/COMMENTS
                          NO INFORMATION FOR THE WILL COUNTY UNIT WAS  AVAILABLE  FOR FEBRUARY AND
                          MARCH.
                                                150

-------
                                             EPA UTILITY  fGO  SURVEY:  JANUARY - MARCH 1980

                                           SECTION U
                  DESIGN AND PERFORMANCE DMA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY  NAME
PLANT  NAME
UNIT NUMBER
CITY
STATE
REGULATORY  CLASSIFICATION
PARTICULATE  EMISSION LIMITATION - NG/J
S02  EMISSION  LIMITATION - NG>J
NET  PLANT  GENERATING CAPACITY - Mg
GROSS  UNIT  GENERATING CAPACITY - M«
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.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 - 1
     RANGE MOISTURE CONTENT  - X
     AVERAGE SULFUR CONTENT  - X
     RANGE SULFUR CONTENT -  X
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT  - X

 • • ESP

 ** MECHANICAL COLLECTOR

 ** PARTICULATE  SCRUBBER
     NUMBER
     TYPE
                                         DETROIT FDISON
                                         ST.  CLA1P
                                         6
                                         BELLE  RIVER
                                         MICHIGAN
                                         C
                                         ******
                                          1376.
                                          1775.0
                                           ZcD.O
(****** LP/KMPTU)
<  3.ZOO LP/WMBTU)
                                         COMBUSTION ENGINEERING
                                         BASE
                                          0/61
                                           465.77
                                           132.3
                                         ******
                                         *******
                                         COAL
                                         SUBblTUMINOUS
                                             4.00
« 98700C
( 270 F)
<•*** FT)
(***** FT)
                                                         (****«* BTU/LB)
                                                          0,500 - 9,600
                                         Zl  - H.
                                               .35
                                         0.3 -  C.4
                                          VENTURI
______....	-----PERFORMANCE  DATA	--
PERIOD MODULE  AVAILABILITY  OPERABlLITt RELIABILITY  UTILIZATION  X REMOVAL
                                                                  SO?
                                                                       PER   BOILER  FGD   CAP.
                                                                PART.  HOURS HOURS  HOURS FACTOR
        SYSTEM

tz/74   SYSTEM

 1/75   SYSTEM
                                                                        730

                                                                        744

                                                                        744
  2/75

  3/75

  4/75
*« PROBLEMS/SOLUTIONS/COMMENTS
                  INSTALLATION  OF  THE FGD SYSTEM WAS  ESSENTIALLY  COMPLETED BY THE NOVEMBER,
                  1974  THROUGH  JANUARY 1975 PERIOD.
                  A  FAULTY  INSTRUMENT PANEL WHICH HAS  INCORRECTLY WIRED HAS BEEN RETURNED  TO
                  THE MANUFACTURER FOR REPAIR.
                  TO DATE,  THE  UTILITY HAS WATER TESTED  ALL  THE AUXILIARY EQUIPMENT.   THE  10
                  FAN HAS BEEN  TESTED AND AIR BALANCE  HAS  BEEN CHECKED.

SYSTEM                                                                  6?2

SYSTEM                                                                  744

SYSTEM                                                                  7?0
                                                 151

-------
 EP» UTILITY FGO SURVEY: JANUARY - MARCH 1980

 DETROIT EDISON: ST. CLAIR 6 (CONT.)
 ....	......	...	..	PERFORMANCE  DATA	.....		
 PERIOD  MODULE AVAILABILITY OPERABIL1TY RELIABILITY  UTILIZATION   *  REMOVAL   PER  BOILER  F6D   CAP
                                                                  S02   PART. HOURS HOURS  HOURS FACTOR


        **  PROBLEMS/SOLUTIONS/COMMENTS
                          A COLD FLUE GAS RUN WAS  SUCCESSFULLY CONDUCTED  MARCH 22 AND 23.  DURING
                          THIS PERIOD THE RUBBER-LINED  PUMPS  WERE  REPAIRED AND THE LIMESTONE PREAR*-
                          TION SYSTEM yAS CALIBRATED.

  5/75   SYSTEM                                                                 744

  5/75   SYSTEM                                                                 720

  7/75   SYSTEM                                                                 744

        *•  PROBLEMS/SOLUTIONS/COMMENTS
                          THE  FIRST HOT FLUE GAS RUN WAS  CONDUCTED  ON  JUNE 22, 1975.   THE RUN LASTED
                          FOR  A PERIOD OF 22 HOURS.  DURING THIS  RUN,  THE  SCRUBBER WAS PURPOSELY
                          TRIPPED OFF AT LOADS OF  40 AND  80 PERCENT.   THIS WAS PERFORMED TO OBSERVE
                          IF  ANY DETRIMENTAL EFFECTS TO THE STEAM GENERATION  OPERATIONS RESULTED.
                          NONE WERE DETECTED.  THE SYSTEM WAS TAKEN OUT OF SERVICE FOLLOWING THIS
                          GAS  RUN TO CORRECT THE FOLLOWING MAJOR  OPERATION AREAS:
                                GAS CIRCUIT: LUGI  THROAT  POSITIONAL FAILURE;  DETERIORATION OF THE
                                DAMPER SEALS; SEVERE VIBRATIONS;  S02 ANALYZERS INOPERATIVE.
                                LIQUID CIRCUIT: FAILURE OF PH CONTROL  SYSTEM;  TARGET  FLOW METER
                                TARGETS H»VE BEEN  BROKEN  OFF; PUMP  SEAL WATER  LOW FLOW ALARM TRIPS.

  8/75   SYSTEM                                                                 744

  9/75   SYSTEM                                                                 720

        **  PROBLEMS/SOLUTIONS/COMMENTS
                          A SECOND  HOT FLUE  GAS RUN WAS INITIATED ON AUGUST  6  AND LASTED 27 HOURS
                          THE  RUN WAS TERMINATED BECAUSE OF A REHEATER THERMOCOUPLE  FAILURE.  A  *
                          SUBSEQUENT INSPECTION OF THE SCRUBBING  SYSTEM REVEALED  NO  APPARENT
                          ABNORMALITIES OR MALFUNCTIONS.
                          A THIRD HOT FLUE GAS RUN OF 41 HOURS DURATION WAS  COMPLETED  OCTOBER 9   Tut
                          MAIN OBJECTIVE Of  THIS RUN WAS TO EVALUATE VARIOUS  COMPONENTS OF THE FBFtu
                          WATER SPRAY SYSTEM AND EFFECTS ON SYSTEM OPERATION.   THE TEST RUN WAS
                          PREMATURELY TERMINATED BECAUSE OF A BOILER FEED  PUHP MALFUNCTION, RESULTl*r
                          IN A REDUCED BOILER LOAD CAUSING SUBSEQUENT  WEEPING  OF  THE  WASH TRAY.

ID/75  SYSTEM                                                                  744

11/75  SYSTEM                                                                  720

12/75  SYSTEM                                                                  744

       ** PROBLEMS/SOLUTIONS/COMMENTS
                          A FOURTH  FLUE  GAS  RUN OF  23 DAYS DURATION WAS TERMINATED DUE  TO EXCESSIVE
                          VIBRATION  IN THE I.D.  t  BOOSTER  FAN.  ONE OTHER  SCRUBBER-RELATED  OUTAGE
                          OCCURRED  WHEN  THE  PACKING OF  ONE OF  THE SCRUBBER RECIRCULATION  PUMPS  NEFDFh
                          MAINTENANCE.   S02  REMOVAL DURING THIS  PERIOD WAS 90  PERCENT  AND PARTICULAR
                          OUTLET  LOADING WAS  0.1  LB/1900 LBS OF  FLUE GAS FOR 1-3  PERCENT  SULFUR  COAL.

 1/76  SYSTEM                                                                  744

 2/76  SYSTEM                                                                  696

 3/76  SYSTEM                                                                  744

 */76  SYSTEM     100.0        100.0                                            720

       ** PROBLEMS/SOLUTIONS/COMMENTS
                          THE  30-DAY  VENDOR QUALIFICATION  RUN  AND FINAL ACCEPTANCE TEST  WERE
                          COMPLETED  BY MAY 29.   THE QUALIFICATION RUN  WAS   CONDUCTED ON  A  "HANDS  OFF-
                          BASIS USING  PLANT PERSONNEL EXCLUSIVELY.  THE SYSTEM WAS IN  SERVICE  100
                          PERCENT OF  THE TIME THE BOILER WAS  OPERATIONAL.   THE FINAL ACCEPTANCE  TEST
                          CONSISTED  OF SIX 4-HR. TEST RUNS CONDUCTED IN THE SPACE OF ONE  WEEK.   THE
                          S02  REMOVAL  EFFICIENCY FOR  HIGH  SULFUR  COAL  WAS  90.9 PERCENT.   PARTICULAR
                          REMOVAL ALSO EXCEEDED  DESIGN  LEVELS.  NO MAJOR CHEMICAL OR MECHANICAL-
                          RELATED PROBLEMS WERE  ENCOUNTERED.

 5/76  SYSTEM                                                                  744



                                                152

-------
                                              EPA  UTILITY FGO SURVEY: JANUARY - MARCH  198?

DETROIT EDISON:  ST. CLA1H 6  (CONT.)
	____		PERFORMANCE DATA	
PERIOD MODULE  AVAILABILITY  OPERAB1LITY  RELIABILITY UTILllATION  * REMOVAL    PEP   BOILER   FGD   CAP.
                                                                 SO?   PART.  HOURS  HOURS   HOURS FACTOR


 6/76  SYSTEM                                                                  720

 7/76  SYSTEM                                                                  744

 B/76  SYSTEM                                                                  7*4

       *• PROBLEMS/SOLUTIONS/COMMENTS
                          THE UTILITY IS NOW PREPARING TO  CONDUCT  A  2  MONTH  MINIMUM INTERNAL SCRUBBER
                          DEMONSTRATION PROGRAM TO ACQUIRE OPERATING  DATA AND INFORMATION.  FOLLOWING
                          THE COMPLETION OF THIS PROGRAM  THE  BOILERS  WILL FIRE LOW SULFUR DECKER
                          COAL (0.1 TO 4.0 PERCENT)  TO MEET  S02  EMISSION REGULATIONS.  THE SCRUBBERS
                          WILL CONTINUE TO OPERATE IN THE  PARTICULATE  REMOVAL NODE.

 9/76   SYSTEM                                                                  720

•10/76   SYSTEM                                                                  7*4

        • • PROBLEMS/SOLUTIONS/COMMENTS
                          THE INTERNAL 502 SCRUBBING  DEMONSTRATION PROGRAM COMMENCED ON OCTOBER  14.
                          THE SCRUBBERS OPERATES CONTINUOUSLY FOR 10 DAYS.
                          OPERATION ON THE DEMONSTRATION  PROGRAM WAS INTERRUPTED  BY  A FORCED  SCRUBBER
                          OUTAGE RESULTING FROM  SCALE AND SOLIDS CARRYOVER FROM THE  WASH  TRAY  AND
                          MIST ELIMINATOR  TO  THE SCRUBBER 1.0. BOOSTER FAN ASSEMBLY. CAUSING  VIBRA-
                          TION AND BALANCE PROBLEMS.   IT  WAS DECIDED TO  SANDBLAST THE fAN TO  REMOVE
                          SOLIDS BUILDUP ON THE  FAN  ASSEMBLY.
                          THE UTILITY PLANS TO MODIFY THE COMPONENT'S HASH SYSTEM FOR GREATER  FLOW
                          CAPABILITY  AFTER COMPLETION OF  THE SO? SCRUBBING PROGRAM.  DECO ALSO PLANS
                          TO  CONTINUE PARTICULATE  SCRUBBING FOLLOWING THE TERMINATION OF  THE  S02
                          PROGRAM 6V  UNCOUPLING  THE  SPRAY TOWERS AND MAINTAINING  THE PEABODY-LUR6I
                          VENTURI SCRUBBERS IN THE FLUE  GAS STREAM.  SOME LIMESTONE  NAY  HAVE  TO BE
                          ADDED  TO THE  PARTICULATE SCRUBBING SOLUTION IN ORDER TO PREVENT LOW PH
                          SWINGS AND  MINIMIZE THE  POSSIBILITY OF ACID CORROSION DAMAGE  TO THE
                          INTERNAL COMPONENTS.

 11/7«   STSTEM      80.0                                                        720

         *• PROBLEMS/SOLUTIONS/COMMENTS
                          FOLLOWING  THE  COMPLETION OF SAND BLASTING OPERATIONS TO SCRUBBER'S I.D.
                          BOOSTER  FAN FOR  REMOVAL  OF SOLIDS BUILD UP, OPERATIONS  RESUMED ON NOVEMBER
                          7 AND  CONTINUED  THROUGHOUT THE MONTH.   THE  SYSTEM'S AVAILABILITY  INDEX FOR
                          THE MONTH  WAS 80 PERCENT.  THE MAJORITY OF  THE OUTAGE  TIME WAS CONSUMED
                          PROCURING  SAND  BLASTING SERVICES.   THE  OPERATION  ITSELF REQUIRED  ONLY 8
                          HOURS.
12/76   SYSTEM       51.0
                                                                                744
         **  PROBLEMS/SOLUTIONS/COMMENTS
                           THE S02 DEMONSTRATION PROGRAM CONTINUED  THROUGHOUT DECEMBER.  THE  SYSTEM'SS
                           AVAILABILITY INDEX FOR THE PERIOD  WAS  51 PERCENT.
                           SCRUBBER OUTAGES RESULTED  FROM  LIMESTONE FEEDER PROBLEMS.
                           SCRUBBER OUTAGES RESULTED  FROM  DENSE  SLURRY TRAVERSE PUMP PROBLEMS.
                           SCRUBBER OUTAGES RESULTED  FROM  DENSE  SLURRY TANK AGITATOR MALFUNCTIONS.
                           PH SAMPLING LINE PLUGGING  RESULTED IN  SOME OUTAGE TIME.

  1/77  STSTEM        .0                                                       744

         SYSTEM        .0                                                       672

         ** PROBLEMS/SOLUTIONS/COMMENTS
                           THE S02 DEMONSTRATION PROGRAM  WAS  OFFICIALLY TERMINATED ON  DEC.  31,  1976.
                           THE SCRUBBER PLANT WAS SHUT  DOWN AT THIS POINT AND  FLUE GAS  WAS  BY-PASSED
                           AROUND THE  SYSTEM.

         SYSTEM        .0                                                       744
                                                  153

-------
 EPA UTILITY FGD SU»VEY: JANUARY - MARCH 1980

 DETROIT EDISON: ST. CLAIR 6 (CONT.)
 	PERFORMANCE DATA—--•
 PERIOD  MODULE  AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL   PER  BOILER  FGD   CAP.
SO?  PART. HOURS HOURS  HOURS FACTOR
        **  PROBLEMS/SOLUTIONS/COMMENTS
                          THE  BOILER REMAINS IN SERVICE, FIRING LOW SULFUR (0.3*) WESTERN COAL.
                          CURRENT PLANS CALL FOR THE SCRUBBER PLANT TO REMAIN OUT OF SERVICE UNTIL
                          MID-JUNE FOR DESIGN AND OPERATING MODIFICATIONS.  RESUMPTION OF SCRUBBER
                          OPERATIONS WILL OCCUR IN THE PRIMARY PARTICULATE-REMQVAL MODE.  THE
                          PEABODY-LURGI VENTUR1 SCRUBBERS AND SPRAY TOWER ABSORBERS WILL REMAIN  IN
                          THE  GAS STREAM.  SOLUTION WILL BE CIRCULATED THROUGH THE VENTURI'S WASH
                          TRAYS,  AND MIST ELIMINATORS.  NO SOLUTION KILL BE CIRCULATED THROUGH TH?
                          SPRAY  ZONE OF THE ABSORBER TOWERS.  LIMESTONE REAGENT WILL BE ADDED TO THE
                          SCRUBBING SOLUTION IN ORDER TO PREVENT LOW PH SWINGS AND SUBSEQUENT
                          MATERIALS DAMAGE TO THE SCRUBBER'S INTERNALS.  SO? REMOVAL SHOULD RESIDE
                          IN  THE  35 TO 5CX RANGE IN THIS MODE OF OPERATION BECAUSE OF THE SOLUTION'S
                          ALKALINITY DUE TO THE FLY ASH AND LIMESTONE.  ALSO DECO PLANS TO MAINTAIN
                          A  HIGHER L/G RATIO IN THE SCRUBBER MODULES.  THIS MODE OF OPERATION IS
                          PROJECTED TO CONTINUE FOR A ONE TO THREE YEAR PERIOD FOLLOWING THE
                          MID-JUNE RESTART.
 4/77  SYSTEM

 5/77  SYSTEM

 6/77  SYSTEM


 7/77  SYSTEM

 8/77  SYSTEM

 9/77  SYSTEM

ID/77  SYSTEM
                      .0

                      .0

                      .0

                      .0

                      .0

                      .0
             7?0

             744


             720

             744

             744


             720

             744
       ** PROBLEMS/SOLUTIONS/COHMENTS
                          THE  UNIT  WAS  PULLED  OFF  LINE  IN DECEMBER  1976  AND DID NOT RESTART UNTIL
                          OCTOBER 1977.   WHILE THE  UNIT HAS  DOWN THE  UTILITY INSTALLED BUILDINGS
                          AROUND PUMPS  THAT  WERE  EXPOSED TO  SEVERE  WEATHER CONDITIONS.
11/77  SYSTEM


12/77  SYSTEM

 1/78  SYSTEM

 2/78  SYSTEM      96.0

 J/78  SYSTEM      85.6

 4/78  SYSTEM      90.0

 5/78  SYSTEM      74.6
             720

             744

             744

             672

             744

             720

             744
          PROBLEMS/SOLUTIONS/COMMENTS
                         THE UNIT EXPERIENCED SPRAY  HEADER  PROBLEMS  IN  THE  ABSORBER  TOWER.   SOME
                         BROKEN N022LES WERE DISCOVERED.
                         THERE WERE SOME I.D. BOOSTER  FAN PROBLEMS.   THE  UTILITY  MUST  SAND  BLAST THS
                         FAN EVERY 4 TO 5 WEEKS WHEN THE MAGNITUDE  OF VIBRATION  OF  THE  FAN  BECOMES
                         EXCESSIVE FROM SCALE FORMATION; HOWEVER,  IN  THIS INSTANCE  THE  PROBLEM WAS
                         A RESULT OF A LOW FAN OIL LEVEL.
                         THE UTILITY NOW OPERATES 3  RECYCLE  TANK AGITATORS.   PREVIOUSLY ONLY 2 WFRP
                         OPERATED.  IT WAS FELT THAT PART OF THE TANK PLUGGING WAS  A RESULT OF
                         INSUFFICIENT AGITATION.
                         THE SLURRY SPRAY SURGE TANK ENCOUNTERED CONTINUAL  OVERFLOW  PROBLEMS WHEN
                         THE ABSORBER SUMP PUMP WAS  OPERATING.  THIS  HAS  BELIEVED TO BE A RESULT or
                         A BROKEN SECTION IN THE SPRAY NOZZLE LINES.  SPRAT  WAS  BEING  DIRECTED
                         UPWARD TO THE BOTTOM OF A TRAY INSTEAD OF  DOWN,  COUNTERCURRENT TO  THE
                         6AS FLOW AS INTENDED.
                         REHEATER PROBLEMS OCCURRED WITH THE FORMATION  OF OIL CLINKERS  IN THE
                         BURNER AREA.  IT WAS DISCOVERED THAT THE AIR SUPPLY  TO  THE  BURNER  WAS
                         INSUFFICIENT.
                                               154

-------
                                              EPA UTILITY FGO  SURVEY:  JANUARY - MARCH
DETROIT EDISON:  ST. CLAIR  6  (CONT.)
	PERFORMANCE CATA	
PERIOD MODULE  »V»UAB111TY  OPERAB1L1TY RELIABILITY UT1LI7ATION
                                                         T REMOVAL    PER   BOILER  FGD   CAP.
                                                         502   PART.  HOURS HOURS  HOURS FACTOR
                          SOME SPRAY HEADER PROBLEMS WERE  ENCOUNTERED.  THE FRP PIPING WAS  RUPTURING.
                          IT WAS SUSPECTED THAT THE RUPTURES  HERE  A RESULT OF "HATER HAMMER"  I.E.
                          THE SURGE THAT OCCURRS  IN THE  PIPE  WITH  A SUDDEN FLOW R»TE CHANGE.
                          THE SPRAY HEADERS WERE  PLUGGING.  WHEN THE HEADERS ARE DRAINED  (E.G.
                          SYSTEMS SHUTDOWN) SOME  SLURRY  SETTLES  IN THE HEADER LINES  ETC.   RINSE  LINES
                          ARE NOW BEING INSTALLED  TO FLUSH OUT HEADERS DURING FUTURE SHUTDOWNS.
 S/7«   SYSTEM
                    87.
                                                                       7?0
        «•  PROBLEMS/SOLUTIONS/COMMENTS
                          ONE OF THE BLADES  CAME  LOOSE  FROM AN I.0. BOOSTER FAN  AND  PASSED THROUGH
                          THE HOUSING.  REPAIRS  WERE  MADE WITHOUT SERIOUS COMPLICATIONS.
 7/78   SYSTEM
                    96.C
                                                                                744
        ** PROBIEMS/SOLUMOHS/COMMENTS
                          THE INSTALLATION Of  RINSE  LINES MAS NOT YET BEEN COMPLETED.
                          PROBLEMS WITH  RUPTURED  SPRAY HEADER PIPING CONTINUED.   IT  HAS BEEN POSSIBLE
                          TO OPERATE THE  SCRUBBER WITH THE RUPTURED LINES WITHOUT  SERIOUS
                          CONSEQUENCES.   IT  IS NOT CRUCIAL THAT REPAIRS BE MADE  IMMEDIATELY.

                                                                                744

                                                                                72C

                                                                                744

                                                                                720

                                                                                744

                                                                                744

        ** PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  THIS  PERIOD RECYCLE  TANK AGITATORS  HERE  BREAKING LOOSE  AND  SIMILAR
                          PROBLEMS  WERE  ENCOUNTERED WITH  THE  SLURRY  STORAGE  TANK AGITATORS.   THE
                          SCRUBBING  SYSTEM WAS REMOVED FROM  SERVICE  FROM  SEPTEMBER THROUGH  JANUARY.
                          STEADY  BEARINGS HERE INSTALLED  AT  THE  BOTTOM  OF THE RECYCLE  TANK  SOLVING
                          THE  RECYCLE  TANK AGITATOR PROBLEM.   THE  SLURRY  STORAGE TANK  SYSTEM ALREADY
                          HAD  STEADY BEARINGS.   THESE WERE  REWORKED  TO  IMPROVE OPERATIONS.
B/78
9/78
10/78
11/78
12/78
1/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
90.4
69.0
.0
.0
.0

  2/79

  3/79
SYSTEM

SYSTEM
           PROBLEMS/SOLUTIONS/COMMENTS
                           SOME REHEATER PROBLEMS OCCURRED.
  4/79  SYSTEM

  5/79  SYSTEM

  6/79  SYSTEM

  7/79  SYSTEM

  8/79  SYSTEM

  9/79  SYSTEM

 tO/79  SYSTEM
672

744



720

744

720

744

744

720

744
            PROBLEMS/SOLUTIONS/COMMENTS
                           THE SYSTEM  IS  CURRENTLY  DOWN BUT IS EXPECTED  TO  BE  BACK ON LINE SOON.  THE
                           SCRUBBING SYSTEM  HAS  OPERATED ONLY 1 WEEK SINCE  MAY 18, 1979 BECAUSE OF
                           SUMP PROBLEMS.
                           THE AGITATOR BEARING  SYSTEM WAS POORLY DESIGNED.  THE  BEARING SYSTE!J MAS
                           NOW BEEN COMPLETELY REDESIGNED.  THE AGITATORS HAVE  NOW OPERATED 2000 HOURS
                           ON THE NEW  BEARINGS.   THE UTILITY WILL PROBABLY  DRAIN  THE  TANK AFTER ABOUT
                           500 MORE HOURS  TO INSPECT AND READJUST THE BEARINGS.   THE  NEW BEARING
                                                  155

-------
EPA  UTILITY  FGD  SURVEY; JANUARY - MARCH  T980

DETROIT  EDISONr  ST.  CLAIR 6 
-------
                                            EPA UTILITY  F6D  SURVEY:  JANUARY - MARCH 1980
                                          SECTION  14
                 DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  PARTICLE  SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NU«BER
CITY
STATE
RE6ULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MU
*ET UNIT GENERATING CAPACITY W/FGC - MH
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
MINNESOTA POWER
CLAY BOSUELL
3
COHASSET
MINNESOTA
E
25?.
1720.
J5C.O
364.0
347.1
350.0
359.0
K LIGHT





( .600 LB/MMBTU)
( 4.000 LB/MMBTU)





«» 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 - 1
    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

** FABRIC  FILTER
    NUMBER
    TYPE

** ESP
    NUMBER

»* MECHANICAL  COLLECTOR
    NUMBER

*• PARTICULATE SCRUBBER
    NUMBER
    TYPE
    SUPPLIER
    NUMBER  OF  STAGES
    SHELL  MATERIAL
    LINING  MATERIAL
    INTERNAL  MATERIAL
    TYPE  OF NOZ7LES
    BOILER  LOAD/SCRUBBER - X
    fLUE  GAS  CAPACITY  -  CU.M/S
    FLUE  GAS  TEMPERATURE - c
    LIQUID  RECIRCULATION RATE  - LITER/S
    L/G RATIO - LITER/CU.M
    PRESSURE  DROP  - KPA
     SUPERFICIAL GAS VELOCITY  - M/S
     PARTICULATE INLET  LOAD  -  G/CU.M
     PARTICULATE OUTLET  LOAD - NG/J
     PARTICULATE DESIGN  REMOVAL EFFICIENCY
     S02 INLET  CONCENTRATION - PPM
     S02 DESIGN REMOVAL  EFFICIENCY  -  X
    COMBUSTION ENGINEERING
    PULVERI7ED COAL
    BASE
     5/73
      613.47
      123.3
      213.
        7.9
    COAL
    SUBBITUMINOUS
     19538.

        9.00
    4.81-16.0
        26.00
    24.C-28.C1
          .92
    0.5-1.5
          .01
    0.0-0.07
      0
     NONE
               (1300000  ACFM>
               ( 254  F)
               ( 700  FT)
               ( 26.0 FT)
               (   8400  BTU/LEO
               7JOO-9900
- X
     SPRAY IMPINGEMENT TOUER
     KREBS ENGINEERS
         1
     316LC SS
     NONE
     316L SS
     SPRAY NOZZLES WITH CERAMIC  INSERTS
       110.0
                     (130QOOO  ACfM)
                     (  ?S4  F)
                     (11340  6PM)
                      8.3 6AL/1000ACM
                     (*«•**  IN-H20)
                         8.0  FT/S)
                       3.00 GR/SCF)
                       .078 LB/MMBTU)
  613.5
  123.3
  714.4
    1.1
•****«*
    2.4
    6.9
   34.
   98.7
  800.000
     .0
                                                157

-------
EPA  UTILITY  FGD  SURVEY: JANUARY - MARCH 1980

MINNESOTA  POWER  R  LIGHT: CLAY BOSWELL 3 (CONT.)
	PERFORMANCE DATA		
PERIOD MODULE  AVAILABILITY  OPERAPILITY RELIABILITY UTILIZATION  X REMOVAL    P£R   BOILE"   FGD   CAP
                                                                 SO?  PART.  HOURS  HOURS   HOURS FACTOR


13/79  SYSTEM                                                                  744

11/79  SYSTEM                                                                  72G

12/79  SYSTEM                                                                  74*

       ** PROBLEMS/SOLUTIONS/COMMENTS
                          NO  INFORMATION  WAS  AVAILABLE FOP THE FOURTH QUARTER  1979.

 1/80  SYSTEM                                                                  744

 2/80  SYSTEM                                                                  696

 3/80  SYSTEM                                                                  744

       •• PBOBLEMS/SOLUTIONS/COMMENTS
                          THE UTILITY REPORTED  THAT THE SCRUBBER EXPERIENCED NO PROBLEMS  DURING  THE
                          1ST QUARTER 1980.
                                               158

-------
                                             EPA UTILITY FGO SURVEY:  JANUARY  - MARCH 1980

                                           SECTION H
                 DESIGN  AND  PERFORMANCE  DATA FOR OPERATIONAL PARTICLE  SCRUBBERS
COMPANY NAME
PLANT NAHE
JN1T NUMBER
CITV
STATE
REGULATORY CLASSIFICATION
PARTICIPATE  EMISSION  LIMITATION - N6/J
$02 EMISSION  LIMITATION  -  NGVJ
NET PLANT GENERATING  CAPACITY  - MW
GROSS UNIT GENERATING CAPACITY  - MW
NET UNIT GENERATING CAPACITY W/FGO - Mw
^ET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY -  MW

.* BOILER DATA
    SUPPLIER
    TYPE
    SERVICE  LOAD
    COMMERCIAL  SERVICE tlATE
    MAXIMUM  BOILER  FLUE  GAS (LOU - 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
    AVEDAGE  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 - T
    RANGE  CHLORIDE  CONTENT - X

.*  FABRIC  FILTER
    NUMBER
     TYPE
    MINNESOTA POWER * LIGHT
    SYL LASKIN
            (  .600 LB/MMPTU)
            ( 4.000 LB/MWPTU)
    AURORA
    MINNESOTA
    E
      25B.
     1721.
      116.0
       62.0
       57.3
       58.0
       5«.0
    COMBUSTION ENGINEERING
    PULVERIZED COAL
    INTERMEDIATE
     0/53
      141.57        (  3CQOOO  ACFM)
      171.1         <  340  F)
       91.          <  300  FT)
        3.2         <  10.5  FT)
    COAL
    SUBB1TUMINOUS
     23469.

        9.00
    4.81-16.r
        26.70
    24.C-28.0
        1.00
    .5-1.5
          .01
    0.00-0.07
      0
     NONE
             (   8800  BTU/LP)
             7509-9923
 «* ESP
     NUMBER
     TYPE

 .* MECHANICAL COLLECTOR
     NUMBER
     TYPE

 .. PART1CULATE SCRUBBER
     NUMBER
     TYPE
     SUPPLIER
     NUMBER OF STAGES
     SHELL MATERIAL
     LINING MATERIAL
     INTERNAL MATERIAL
     TYPE OF N027LES
     BOILER LOAD/SCRUBBER  -  X
     FLUE GAS CAPACITY  -  CU.M/S
     fLUE GAS TEMPERATURE  -  C
     LIQUID RECIPCULAT10N  RATE  - LITER/S
     L/G RATIO -  LITER/CU.M
     PRESSURE DROP  -  KPA
     SUPERFICIAL  GAS  VELOCITY  - M/S
     PARTICULATE  INLET  LOAD  -  G/CU.M
     PARTICULATE  OUTLET LOAD - NG/J
     PARTICULATE  DESIGN REMOVAL EFFICIENCY
     S02 INLET CONCENTRATION - PPM
     S02 OUTLET CONCENTRATION  - PPM
     S02 DESIGN REMOVAL EFFICIENCY - X
- X
      0
     NONE
      0
     NONE
     SPRAY IMPINGEMENT TOWER
     KREBS ENGINEERS
         1
     316 ELC SS
     NONE
     316 ELC SS
     SPRAY NOI2LES WITH  CERAMIC  INSERTS
       100.0
       1 37.4         <  291160  ACFM)
       171.1         <  34C  F)
       151.2         <  2400  GPIO
         1.1         C  8.3 6AL/1COHACF)
                     (•**»*  IN-H30)
  2.1
  4.7
 34.
 97.8
SCO.000
SCO.000
   .3
                     (     7.0 FT/S)
                     <   2.06 GR/SCF)
                     (   .078 LB/MMPTU)
                                                 159

-------
EPA UTILITY  F6D  SURVEY: JANUARY - MARCH  198D

MINNESOTA POWER  g  LIGHT: SYL LASKIN  1  ICONT.)
..	.—.__	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY  UTILIZATION  * REMOVAL    P£R   BOILER   FGD "~CAP
                                                                  SO?  PART. HOURS  HOURS   HOURS FACTOR


13/79  SYSTEM                                                                   744

11/79  SYSTEM                                                                   7?0

12/79  STSTEM                                                                   744

       *• PROBLEMS/SOLUTIONS/COMMENTS
                          NO INFORMATION WAS  AVAILABLE FOR THE FOURTH QUARTER  1979.

 1/80  SYSTEM                                                                   744

 2/80  SYSTEM                                                                   696

 J/80  SYSTEM                                                                   744

       • * PROBLEMS/SOLUTIONS/COMMENTS
                          THE  UTILITY REPORTED THAT  THE  SCRUBBER  EXPERIENCED NO PROBLEMS  DURINr  TL,
                          1ST  OUARTER 1980.                                                       ™E
                                               160

-------
                                             EPA UTILITY  FGD  SURVEY: JANUARY - MA&CH  19b?

                                           SECTION  U
                  PES1GN AND PERFORMANCE DAT* fOR OPERATIONAL PARTICLE SCRUBBERS
         NAM?
PLANT  NAME
     NUMBER
CITY
STATE
REGULATORY  CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
$02  EMISSION LIMITATION - NG/J
NET  PLANT  GENERATING CAPACIT1 - Hv
&POSS  UNIT  GENERATING CAPACITY - MW
NET  UNIT  GENERATING CAPACITY W/F&D - My
~FT  UNIT  GENERATING CAPACITY yO/FGD - MW
EQUIVALENT  SCRUPBFD CAPACITY - MU

*• BOILER  DATA
     SUPPLIER
     TYPE
     SERVICE LOAD
     COMMERCIAL SE"V1CE DATE
     MAXIMUM SORE" 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 - »
     RANGE M01STUR' CONTENT  - *
     AVERAGE SULFUR CONTENT  - X
     RANGE  SULFUR CONTENT -  *
     AVERAGE CHLORIDE  CONTENT - *
     RANGE  CHLORIDE CONTENT  - X

 ,. FABRIC  FILTER
     NUMBER
     TYPE
    MINNESOTA POWER * LIGHT
    SYL LASKIN
    2
    AURORA
    MINNESOTA
    E
      25?.          <  .600  LB/MMBTU)
     172?.          ( 4.00C  L8/MMPTU)
      1U.O
       t?.0
       57.3
       5 ° • ^
       5»!5
    COMBUSTION ENGINEERING
    PULVERIZED COAL
    INTERMEDIATE
     0/55
      141.57        <  3COOCP ACFM)
      171.1         <  34C  F)
       91.          (  300  FT)
        ?.2         <  10.5  FT)
    COAL
    SUBblTUMINOUS
     JD469.

        9.00
    4.81-16.0
        2i.70
    24.0-i8.C
        1.00
    .5-1.5
          .01
    C.GC-0.07
      0
     NONE
                     FTU/L">
              7509-9923
    ESP
     NUMBER
     TYPE

    MECHANICAL  COLLECTOR
     NUM9ER
     TYPE

    PARTICULATE  SC9UBBER
     NUMBER
     TYPf
     SUPPLIER
     NUMBER  OF  STAGES
     SHELL MATERIAL
     LINING  MATERIAL
     INTERNAL  MATERIAL
     TYPE  OF N027LFS
     BOILER  LOAD/SCRUBBER - X
     FLUE  GAS  CAPACITY -  CU.M/S
     FLUf  GAS  T^P'RATURE - C
     LlUUID  RECIRCULATION HATE -LITER/S
     L/G  RATIO - LITER/CU.^
     PRESSURE  CROP -  KPA
     SUPERFICIAL G'S  VELOCITY - «/S
     p»RTICULAT£ INLET LOAD - G/CU.M
     PART1CULATE OUTLET LOAD - NG/J
     PHRTICUIATE DESIGN REMOVAL EFFICIENCY
     502  INLET CONCENTRATION - PPM
     S02  OUTLET CONCENTRATION - PPM
     502  DESIGN REMOVAL EFFICIENCY  -  X
- X
      0
     NONE
      0
     NONE
     SPRAY IMPINGEMENT TOWER
     KREES ENGINEERS
         1
     316 ELC SS
     NOSE
     316 ELC SS
     SPRAY NOZZLES WITH CERAMIC  INSERTS
       1CO.O
       1 37.4         (  291160  ACfM)
       171.1         <  340  F)
       151.2         <  2400  GPM)
         1.1         (  8.3 GAL/10COACF)
     •**•*•*         ««*«•*  IN-H20)
                          7.C  FT/S)
                       ?.06 GR/SCF)
                       .078 LB/MME>TU)
  4.7
 34.
 97.8
SCO.000
5 CO.000
   .0
                                                 161

-------
EPA  UTILITY  FGP  SURVEY: JANUARY - MARCH  1980


-------
                                             EPA UTILITY  FGO  SURVEY: JANUARY  - MARCH  196?
                                           SECTION  H
                  DESIGN AND PERFORMANCE DAT* fOR OPERATIONAL PARTICLE
                                                                        SCRUBBERS
COMPANY NAME
PLAMT NAME
JN1T NUMBER
CITY
STATE
REGULATOR!  CLASSIFICATION
pARTICULATE  E«ISSION  LIMITATION - NG/J
SOi EMISSION  LIMITATION - NG/J
WET PLANT  GENERATING  CAPACITY - Mb
GROSS UNIT  GENERATING CAPACITY - My
SET UNIT GENERATING CAPACITY y/FGO - * *
MET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT  SCBUPBEO CAPACITY - My

**  BOILER  DATA
    SUPPLIER
    TYPE
    SERVICE LOAD
    COMMERCIAL  SERVICE DATE
    MAXIMUM 30UE = FLUE GAS FLOW - CU.M/S
    FLUE GAS  TEMPERATURE - C
    STACK  HEIGHT - M
    STACK  TOP 0!A«ETEP - N

..  FUEL DATA
    FUEL  TYPE
    FUEL GRADE
    AVERAGE MFAT CONTENT - J/G
    RANGE  HEAT  CONTENT - BTU/Lfc
    AVERAGE ASH CONTENT  - X
    RANGE  ASH CONTENT  -  X
    AVERAGE MOISTURE CONTENT  - 1
    RANGE  MOISTURE CONTENT -  X
    AVE"AGE SULFU" CONTENT -  X
     RANGE  SULFUR CONTENT - X
    AVERAGE CHLORIDE CONTENT  - T
    RANGE  CHLORIDE CONTENT -  x

.*  MECHANICAL COLLECTOR
     NUMBER
     TYPE
     SUPPLlER
     PARTICIPATE CFSIGN  RE10VAL  EFFICIENCY - t
     FLUE  GAS CAPACITY  -  CU.M/S
     FLUE  GAS TEMPERATURE -  C
     PRESSURE DROP  -  KPA
     PARTICULATE OUTLET  LOAD  - C/CU.I"

,.  pARTICULATE  SCRUBBER
     TYPE
     SUPPLIER
     NUMBER OF STAfiES
     SHELL  MATERIAL
     LINING MATERIAL
     INTERNAL MATERIAL
     NUMBER OF NOZZLES
     BOILER LOAD/SCRUBBER - X
     fLUE GAS CAPACITY  - CU.M/S
     FLUE GAS TEMPERATURE - C
     LIGUID  RECI"CULATION RATE - LITEH/S
     L/G RATIO - LlTER/CU.1*
     PRESSURE DftOP -  Kt>A
     PARTICULATE I«JLET LOAD - G/CU.M
     pARTICULATt OUTLET LOAD - G/CU.M
     SOi INLFT  CONCENTRATION - NG/J
MONTANA-DAKOTA  UTILITIES  CO.
LEWIS & CLARK
1
SIDNEY
MON TANA
<   .ZCC LE./MMBTU)
<  1.000 Lt/MMPTU)
   £6.
  43".
   5?. 3
    51.5
CO*!faUSTICN  ENGINEERING
PULVERIZED  COAL
EAS E
10/5?
  153.37        (  325CCC
  215.6         (  4?C F)
    76.          •  25u FT)
     4.4         (  14.5 FT)
 COAL
 LIGNITE
  15 '.03.

     7. SO
 34. 25-38.16
      .61
 . 32-1.43
<  645C  FTU/LP)
 t200-6
  1
 MULTICLONE
 WESTERN PRECIPITATION
    £5.7
   1C6.2         (  ?25CC^ ACFf)
   176.7         (   ?5C  F)
 **«*•**         (**•»»  ]K-H?0)
     ?.93        <   1.26  GC/SCF)
 VESTURI
 RESEARCH  COTTRFLL
     1
 CAftbON  STEEL
 CEILCOTE  FLAKELINE 1C3
 CARBON  STEEL  WITH  1" NORTON  CA-3'fc
   14".0
   215.6
   212.6
      1.7

   327.2
       .1
  ? S 1 3 4 .
 ( 31373T  ACFM)
 (  42C F)
 < 3374 GPf)
 03.0 GAL/1CCCACF)
 (..«.. IK-H2C)
 (143 .CC  GF/SCF)
 (  .0?C  tfi/SCF)
 <......
                                                 163

-------
EPA UTILITY  FGD SU"VEY:  JANUARY - MARCH  198C

10NTANA-OAKOTA UTILITIES  CO.: LEWIS 8 CLARK  1 (CONT.)
	....	..	..	 — PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY  OPE»ABIL1T» RELIAP1LITY UTILIZATION  * REMOVAL    PE»  B01LE'   FGD    C*P.
                                                                    SO?  PART.  HOURS HOURS   HOURS  FACTCS


li/79  StSTEM                                                                    7?C

       ••  PROBLEMS/SOLUTIONS/COMMENTS
                           DURING A SCHEDULED  BOILER OUTAGE  GENEBAL SC"UBPER  MAINTENANCE  „«S
                           PERfORMED.

11/79  SYSTEM                                                                    7 ? C

       ••  PROBltMS/SOLUTIONS/COMPENTS
                           DURING NOVEMBER THE  SCRUBBER HAS T EI»POI< AR I L Y BYPASSED  TO ALLOW  FOB R E P A I (, S
                           NECESSITATED PY A LEAK  IN THE  FLOODED DISC  SCRUBBER.

U/7P  SYSTEM                                                                    74*

       ••  PROBLEMS/SOLUTIONS/COMMENTS
                           THE  UTILITY REPORTED THAT NO SC"UBBER PROPLEHS OCCURRED DURING  DECEMBER.

 1/6?  SYSTEM                                                                    7tl>

 ?/bO  SYSTEM                                                                    6"6

 J/80  SYSTEM                                                                    744

       ••  PROBLEMS/SOLUTIONS/CONMENTS
                           DURING THE JANUARY  THROUGH MARCH PERIOD  THE SCRUBBER WAS  AVAILABLE MORE
                           THAN 95T OF THE TIM?.
                           THE  EROSION PROPLEM  MENTIONED DURING  NOVEMBER  CONTINUED.   SECTIONS OF THE
                           LINED  CAREON ST'EL  COLUMN WILL SUPPORTING THE  FLOODED  DISC  uE»E HUPTURIIVG
                           FILLING THE INNER CHAMBER blTH SLURRY AND ULTIMATELY RENDERING THE DISC   '
                           MOVEMENT MECHANIST  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 INNEC
                           CHAMBER.  THE  UTILITY HAS H»D SOME SUCCESS  IN  OTHER EROSION  AREAS BY
                           MAKING REPAIRS  WITH  A HASTELLOY MATERIAL.  PLANS ARE BEING  !"ADE TO JACKET
                           THE  ENTIRE DISC  SUPPORT  COLUMN WITH HASTELLOY  G.
                                                 164

-------
                                             EPA UTILITY  fGC  SURVEY: JANUARY - MARCH

                                           SECTION  14
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
         NAME
PLANT  NAME
      NUMBER
STATE
•CtULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
CQ2  EMISSION LIMITATION - NG/J
     PLANT GENERATING CAPACITY - MW
       UNIT GENERATING CAPACITY - MM
     UNIT GENERATING CAPACITY W/FGD  -  MW
     UNIT GENERATING CAPACITY WO/FGD - MW
"oUlVALENT SCRUBBED CAPACITY - MW

    BOILER DATA
     SUPPLIER
     TYPE
     SERVICE LOAD
     COMMERCIAL  SERVICE  DATE
     MAXIMUM BOILER  FLUE GAS  FLOW  -  CU.M/S
     fLUE GAS TE"PE«ATURE  -  C
     STACK HEIGHT  -  M
     STACK TOP DIAMETER  -  M

    FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE HEAT  CONTENT  -  J/G
     RANGE MEAT  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 CHLORID?  CONTENT  - X

    PARTICULATE  SCRUBBER
      NUMBER
     TYPE
      SUPPLIER
      SHELL  MATERIAL
      LINING  MATERIAL
     BOILER  LOAD/SCRUBBER  -  X
      FLUE GAS  CAPACITY  - CU.M/S
      FLUE  GAS  TEMPERATURE  -  C
      LIQUID  RECIRCULATION RATE - LITER/S
      L/G RATIO - L1TER/CU.M
      PRESSURE  DROP - KPA
      PARTICULATE INLET LOAD  - G/tU.M
      PARTICULATE OUTLET LOAD - G/CU.M
      PARTICULATE DESIGN REMOVAL EFFICIENCY
      S02 INLET CONCENTRATION - PPM
      S02 BESIGN  REMOVAL EFFICIENCY  -  X
    PACIFIC POWER s LIGHT
    DAVE JOHNSTON
    4
    GLENROCK
    WYOMING
- X
       90.
                       .210  LE/MMPTU)
                       .5CC  LB/MMBTU)
      330.0
      326. 5
      33r.O
       37.0
    COMBUSTION  ENGINEERING
    PULVERIZED  COAL
    »* / »«
       707.85
       1 J2.2
       76.
     COAL
     SUBblTUMINOUS
      17252.

        13.00
     ******
        16.00
     ******
          .50
             nsooooc  ACFM)
             i  270  »>
             (  250  FT)
             (***** FT)
             <   74,30 BTU/LB)
              5,000-9,COO
          .04
     VENTURI
     CHEMCO
     CARBON STEEL, 3/?" AT  VENTURI  THROAT
     POLYESTER-LINED STEEL
        33.3
       327.5         < 694COP  ACFM)
       135.0         «  275  F)
       409.5         ( 6500  GPM)
         1.7         (13.0 6AL/1000ACF)
     *******         (*****  IN-H20)
                     <  *.TC GR/SCF)
                     (  .040 Gfi/SCF)
  9.Z
   .1
 99.7
SCO.000
 40.0
   ___ - ----------------------------------- PERFORMANCE DATA
        MODULE AVAILABILITY OPERAB1L1TY  RELIABILITY  UTILIZATION
                                                                  X  REMOVAL   PER  BOILER  FGD    CAP.
                                                                  so?   PART.  HOURS HOURS  HOURS  FACTOR
        SYSTEM

,,/79  SYSTEM

12/7C  SYSTEM
                                   744
                                   744
                                                 165

-------
EP» UTILITY  FGD SURVEY:  JANUARY - MARCH  19SO

PACIFIC  POME"  R LIGHT:  DAVE  JOHNSTON 4  (CONT.)
	p£B fORWANCF  DATA	
PERIOD MOOULf  AVAILABILITY  OPERAPUITY RFLlAPUlTir UTILIZATION  1 REMOVAL    Pt»   BOH.ER   Ftt>    C»P?~
                                                                    SO?  PART.  HOURS HOURS  HOURS  FACTOR


       ••  PROBLfel"S/SOLUTION S/COMMENTS
                          NO  INFORMATION  WAS  AVAILABLE  FOB  THE  FOUBTH (JUABTfR  1079.

 1/63  SYSTE"                                                                     744

 Z/8n  SYSTE"                                                                     696

 5/8?  SYSTEM                                                                     744

       ••  PROBlf'SfSOLUTIONS/COMWENTS
                          NO  INFORMATION  WAS  AVAILABLE  FOR  TH£  FIRST OOARTER  T980.
                                                 166

-------
                                              EPA  UTILITY FGO SURVEY:  JANUARY - MARCH  19fc
                                            SECTION  14
                  DESIGN AND  PERFORMANCE DAT*  FOR OPERATIONAL PARTICLE  SCRUBPE»S


COMPANY  NAME                                     POTOMAC ELEC™U  POWER
PLANT  NAME                                        DICKERSON
jialT «,U"BER                                      1
rjTY                                              DICKERSON
cTATE                                             MARYLAND
RetUL»TORY  C L» SS I F I C AT I ON                        *««**.
PARTICULATE EMISSION LIMITATION - NG/J          ......          (......  LP/KM?TU)
     EMISSION LIMITATION -  NG/J                   *«..*•          («*••*•  LP/MMPTU)
     PLANT GENERATING CAPACITY  - Mw               1345.0
    SS  UNIT  GENERATING CAPACITY  - MW               191. 0
VCT  UNIT GENERATING CAPACITY w/fGo - *W           1?3.C
NCT  UNIT GENERATING CAPACITY yO/FGO -  MW        .......
£OUIV*LENT  SC&UP.BFD CAPACITY -  MU               .......

..  POILFR DATA
     SUPPLIER                                     ......
     Typc                                         PULVERIZED  COAL
     SERVICE LOAD                                 ......
     CO^'ERCIAL  ?E»VICF  DATE                     «./«.
     «»»1MU"I B01LE"  FLUE GAS FLOW  - CU.M/S       ........        (**..*..  ACFM)
     FLUE GAS  TE»P'RATUNE  - C                    .......         <*«*• F)
     STACK  HEIGHT  -  M                             ......          (..*. FT)
     STACK  TOP  DIA"ETEB  -  N                      .......         (*..«. ft)

..  FUEL  DATA
     FUEL TYPE                                    COAL
     FUEL GRADE                                   ......
     AVERAGE HEAT  CONTENT  - J/G                   272K..         < 117CC  E-TU
-------
 EPA UTILITY FGD SURVEY: JANUARY - MARCH  198C
                                             SECTION  U
                   DESIGN AND PERFORMANCE  OAT*  FOR  OPERATIONAL PAPTICLE SCRUBPEBS


  COMPANY NAME                                    POTOMAC  ELECTRIC PO^E"
  PLANT NAME                                      DICKERSON
  JNIT NUMBER                                     2
  CITY                                            DUKERSON
  STATE                                           MARYLAND
  REGULATORY CLASSIFICATION                       .*«.••
  PART1CULATE EMISSION LIMITATION - NG/J          •*«..*          (•*.**. LB/MMPTU)
  SOi  EMISSION LIMITATION - NG/J                  »..*«»          <«..... LB/MMPTU)
  NET  PLANT GENERATING CAPACITY - MW              134?.Q
  GROSS UNIT GENERATING CAPACITY - My               19?.0
  NET  UNIT GENERATING CAPACITY y/FGD ~ My           133.0
  NET  UNIT GENERATING CAPACITY WO/FGD - «W        ••*•••*
  EQUIVALENT SCRUPBFD CAPACITY - My               .......

  •*  ROILFR DATA
      SUPPLIER                                    *»».»*
      TYPE                                        PULVERIZED  COAL
      SERVICE LOAD                                ......
      COMMERCIAL SERVICE  BATE                     **/**
      MAXIMUM BORE"  FLUE  GAS FLOW - CU.M/S       ..***..*        («*.....  «CFM>
      FLUE GAS TEMPERATURE - c                    .......         <****  n
      STACK HEIGHT -  M                            ......          (....  fT)
      STACK TOP 01A«ETER  - M                      .......         (*..*.  FT)

  ••  FUEL DATA
      FUEL TYPE                                    COAL
      FUEL GRAOF                                  ......
      AVERAGE HEAT CONTENT - J/G                  ?72U.         (  11 7&0 PTU/LP)
      RANGE HEAT CONTENT  - 9TU/LB                                 ......
      AVERAGE ASH CONTENT  - 2                        14.00
      MANGE ASH  CONTENT -  I                       ......
      AVERAGE MOISTURE CONTENT - *                ........
      RANGE MOISTURE  CONTENT - »                  ......
      AVERAGE SULFUR  CONTENT - X                     ?.00
      RANGE SULFUR CONTENT - X                    ......
      AVERAGE CHLORIDE CONTENT - *                ........
      RANGE CHLORIDE  CONTENT - *                  ......

  •• PARTICULATE  SCRUBBER
      TYPE                                        VENTURI
      NUMBER  OF  STAGES                               2



..	.—	.	.	PERFORMANCE DATA	__
PERIOD MODULE AVAILABILITY  OPERAPILITY  RELIABILITY  UTILIZATION  x REMOVAL    PER   BOILER   FGD   c«p
                                                                  SO?  PART.  HOURS HOURS   HOURS FACTC
ID/79  SYSTEM

11/79  SYSTEM

12/70  SYSTEM
 3/69
                        100.0

                         96.A

                        icr.o
                         97.0

                         88.9

                        10T.O
                        744

                        730

                        744
      722

      664

      744
       722

       64?

       744
       •• PROBLEMS/SOLUTIONS/COMMENTS
                          A  OWE  0«Y  OUTAGE OCCURREDt DUE TO A FAN LIMNG PROBLEM.  NO  OTH?R
                          UNIT PROBLEMS  hE»E ENCOUNTERED DURING THE PERIOD.
 1/80  SYSTEM
                   95.4
                                96.4
                                                 95.4
                                                                              744
                                                                              736
                                                                                            71C
       *» PROBLEMS/SOLUTIONS/COMMENTS
                         IN  JANUARY  THF  SCRUP6ER yAS DOWN FOR J HOURS TO RfP«I» A SLURRY  RECYCLE
                         LINE  LEAK.
                         31  HOURS  OF  THE OUTAGE  TIME IN JANUARY UAS NECESSARY TO REPAIR  A  RECYCLE
SYSTEM

SYSTEM
                         PUMP.
                  100.0

                   96.9
100.0

 96.9
100.0

 96.9
696

744
696

744
6V6
                                                168

-------
                                              EPA UTILITY fGO SURVEY: JANUARY  -  MARCH 19B?

        ELECTRIC  POWER:  D1CKERSON  2
                                          •PERFORMANCE DATA-
t>foiot>  MODULE  AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION   *  REMOVAL    PER  BOILER  reo    C«P.
                                                                  S02   PART. HOURS HOURS  HOURS  FACTOR


        .*  PROBLEHS/SOLUTIONS/COMWENTS
                          IN MARCH THE SCRUBBER WAS DOWN  FOR  A  SCRUBBED LINING WARRANTY INSPECTION.
                          NO REPAIR WORK WAS NECESSARY.
                                                  169

-------
  EPA  UTILITY  FGD  SUPVEY: JANUARY - MARCH 198C
                                             SECTION  14
                    DESIGN AND PERFORMANCE DATA  FOR OPERATIONAL  PARTICLE  SCRUBPERS
   COMPANY  NAME
   PLANT  NAKE
   UNIT NUMBER
   CITY
   S TATE
   REGULATORY CLASSIFICATION
   PARTICULATE EMISSION  LIMITATION - NG/J
   SO? EMISSION  LIMITATION  -  NG/J
   SET PLANT GENERATING  CAPACITY - My
   GROSS  UNIT GENERATING CAPACITY  - Mw
   MET UNIT GENERATING CAPACITY  y/FGD - *H
   NET UNIT GENERATING CAPACITY  WO/FGD - MW
   EQUIVALENT SCRUBBED CAPACITY  -  MM
 POTO«AC ELECTRIC POyEC
 DICKERSON
 3
 MARYLAND
 ******
   668.
   548.0
   19?.0
   1S3.Q
 <****««
 <  1.6CC  LB/MMBTU)
  ** BOILER DATA
      SUPPLJ ES
      TYPE
      SERVICE LOAD
      COMMERCIAL SERVICE  DATE
      MAXIMUM BOILED FLUE GAS  FLOW  -  CU.M/S
      FLUE GAS TEMPFRATURE  - C
      STACK HEIGHT - M
      STACK TOP OIA^E TER  -  M
            ENGINEE»ING
 PULVERIZED  COAL
 BASE
  0/62
   27P.42        (  5POOCC ACFM)
   126.1         (  259  F)
   12?.          <  400  FT)
 .......         <***..  fT)
  •* FUEL DATA
      FUEL TYPE
      FUEL GRADE
      AVERAGE HFAT CONTENT - J/G
      RANGE HEAT CONTENT - BTU/LB
      AVERAGE ASH CONTENT - X
      RANGE ASH CONTENT - X
      AVERAGE MOISTURE CONTENT  - 5!
      RANGE MOISTURE CONTENT -  *
      AVERAGE SULFU" CONTENT -  X
      RANGE SULFUR CONTENT - I
      AVERAGE CHLORIDE CONTENT  - 2
      RANGE CHLORIDE CONTENT -  *
 COAL
 ******
 27214.

    14.00
 ******

 ******
    2.0C
 * * * * * *
< 117CC BTU/LB)
 ******
     ESP
      NUMBER
      SUPPLIER
      PARTICULATE  DESIGN REMOVAL EfflCJFNCr

     PARTICULAR  SCRUBBER
      NUMBER
      TYPE
      SUPPLIER
      BOILER  LOAD/SCRUBBER - t
      FLUE  GAS CAPACITY - CU.1/S
      FLUE  GAS TE^PFBATURE - c
      l/G RATIO -  LITER/CU.M
      PRESSURE DROP  - KPA
RESEARCH COTTRELL
VENTURI
CHEMICO
   50.C
  139.2
  126.1
    2.7
(  2957CO ACFM)
<   259 F)

-------
                                              EPA UTILITY fGO SURVEY:  JANUARY  - MARCH 1<58C
POTOMAC ELECTRIC  POWER:  D1CKERSON  3  
-------
EPA UTILITY  F&D  SURVEY: JANUARY  -  MARCH  19gC

POTOMAC ELECTRIC  POWER: D1CKERSON  3  (CONT.)
	PEOFORMAM C? DATA	
PERIOD MODULE  AVAILABILITY OPERAPILITY  RELIABILITY  UTILI7ATION
                                                           r REMOVAL
                                                           so?   PART.
                                                                               PER
                                                                              HOURS
bOlLER
HOURS
 FGD
HOURS
 csp.
FACTOR
 9/75  SYSTEM
13/75
11/75
12/75
1/76
2/76
3/76
4/76
5/76
6/76
7/76
3/76
9/76
11/76
12/7t
1 m
im
3/77
4/77
5/77
6/77
7/7'
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTE"
SYSTE"
•* PROBLEMS /SOLUTIONS/COMMENTS
                   THE  f&O SYSTEM CONSISTS  OF  A  SINGLE, TwO-STAGF  S CRUPbFR / AbS o* R E t , WHICH
                   INCORPORATES AN AD JUST ABLE -THROAT VENTu"! SCRUBBER  FOP  PARTICULATE REfOVjL
                   AND  A  SECOND STAGE  ABSORBER WITH A FIXED VENTURI  TO  REMOVE $02.  THE LICijOR
                   STREAMS FOR BOTH STAGES  ARE SEPARATE AND OPERATE  IN  A  CLOSED-LOOP MO&c.
                   UNTIL  NID-1975 THE  MAGNESIUM  SULflTE GENERATED  UAS  TRANSFERRED TO AN £P«
                   FINANCED FACILITY AT ThE  ESSEX  CHEMICAL COMPANY  SULFU"IC ACID I"! AN I! F A C T U c I N G
                   PLANT  IN RUMFORD, RHODE  ISLAND  WHERE MAGNESIUM  OXIDE WAS REGENERATED A M>
                   soz  FROM THE REGENERATION PROCESS WAS CONVERTED  TO  SULFURIC ACID.  THE
                   RUMFORD FACILITY HAS SINCE  BEEN CLOSED DOWN.
                   CONSTRUCTION UAS COMPLETED  IN  AUGUST AND THE SYSTEM  STARTED U" IN SEPT;»EEP
                   1973.   DURING INTERMITTENT  OPERATIONS FOR SHAKEDOWN  THROUGH JANUARY 1 ? 7 <,
                   THE  SYSTEM'S LONGEST CONTINUOUS RUN WAS 2? 1 HOURS.   THE  SYSTEM HAS Rt-   '
                   STARTED FRQM JULY THROUGH DECEMPER 1974, AND AGAIN  ON  AUGUST 11, 1975
                   APPROXIMATELY 87 HOURS.                                               ''
                   fGO  UNIT OUTAGES HERE  CAUSED PRIMARILt PY PIPE  AND  PU"P  CORRCSlON AND
                   MAJOR  TURBINE OVERHAUL OF THE  BOILER.  PARTICULATE  AND  SO? REMOVAL
                   EFFICIENCY  GUARANTEES  WERE  CORROBORATED DURING OPERATIONAL PHASES.
                   THE  FGD SYSTEM WAS  RESTARTED IN AUGUST.  STEAM  WAS  LOST  TO THE "GO Mix
                   TANK,  RFSULTING IN  A VERY MOIST PRODUCT FROM THE  CENTPIFuGE.  CAKING
                   D»tER  OCCURRED.  AT THIS  POINT, THE UTILITY DECIDED  TO  TEST ONLY THE
                   STAGE  OF THE SCRUBBING SYSTrM,  TAKING GAS AHEAC  OF  »hF  PRECIPMATOR.
                   OPERATION AT D1CKERSON TERMINATED AT THIS POINT.
                   THE  REMAINING SUPPLY OF MAGNESIUM OXIDE, ABOUT  IOC  TONS  (12 DAYS), HAS
                   BEEN DEPLETEOt AND  THE DICKERSON UNIT MAS BEEN TERMINATED  AS A FGD S>STc,v
                                                                                                    rot
                                                                                                  I .N T * e
                                                                                                  Fl'ST-
                                                                                                   FTD
                                                                         7?C

                                                                         744

                                                                         7?C

                                                                         744

                                                                         744

                                                                         6°6

                                                                         744

                                                                         7?C

                                                                         744

                                                                         7?C

                                                                         744

                                                                         744

                                                                         7?C

                                                                         7?C

                                                                         744

                                                                         744

                                                                         672

                                                                         744

                                                                         7?C

                                                                         744

                                                                         7?C

                                                                         744
                                                172

-------
                                              EPA UTILITY FGD SURVEY:  JANUARY  - PARCH 19E?
P3TO"AC  ELECTRIC  POWER:  DICKERSON  3 ALANCE«
                           OUTAGE TIME WAS  CAUSED BY LEAK REPAIRS IN SLURRY  PIPING.
  3/7?  SYSTE"
                     21.0
                                 22.C
                                                         21.Q
                                                                                744
                                                                                      717
                                                                                              156
            PROBLEMS/SOLUTIONS/COMMENTS
                           OUTAGE TIME WAS DUE TO RUBBER  LINING  FAILURE  IN THE RECYCLE PUMP  DISCHARGE
                           LINE.
         SYSTEM
                     80.7
                                 79.8
                                                          76.4
                                                                                72C
                                                                  689
         **  PROBLEMS/SOLUTIONS/COMMENTS
                           26 HOURS OF OUTAGE TIME WERE  DUE  TO SMALL LEAKS IN PIPING.
  5/78   SYSTEM
                     84. 5
                                 82.7
                                                          74.0
                                                                                 744
                                                                                       666
                                                                                              550
                                                                                              551
         **  PROBLEMS/SOLUTIONS/COMMENTS
                           A LEAK OCCURRED  IN  A  MIST  ELIMINATOR DRAIN.
                           THERE WAS A LEAK  IN  A BLEED LINE FOR THE SCRUBBER  RECYCLE  CIRCUIT.
                           OUTAGE TIME WAS  REQUIRED  FOR BLEED LINE REPLACEMENT.
  6/7»

  7/78
         SYSTEM

         SYSTEM
100.0

100.C
9T.1

  .0
6».7

  .0
72C

744
549

 16
495

  0
         • * PROBLEMS/SOLUTIONS/COMMENTS
                           THE VENTURI  SCRUBBEP HAD AN AVAILABILITY  OF  1CCX F0» JUNE AND JULY.   TH«
                           ONLY  VENTURI  OUTAGE TIME WAS IN JUNE.   THE  OUTAGE TIME WAS REQUIRED  TO
                           TIE IN  EQUIPMENT COMMON TO THE NEW UNIT AND  UNIT 3.
                           THE BOILER  WAS  DOWN IN JULY FOR AN OVERHAUL.
                           THE REASON  VENTURI HOURS CAN BE LOWER  THAN  BOILER HOURS WHEN THE  VENTURI
                           HAS A iro*  AVAILABILITY is PECAUSE THE  VENTURI  is NOT OPERATED UNDER LOW
                           LOAD  CONDITIONS.
   9/78  SYSTEM

   ,/78  SYSTEM

  13/78  SYSTEM

  11/75  SYSTEM

  U/7K  SYSTEM

   1/79  SYSTEM

   2/79  SYSTEM

   5/79  SYSTEM
                                                                                 744

                                                                                 72C

                                                                                 744

                                                                                 720

                                                                                 744

                                                                                 744

                                                                                 672

                                                                                 744
                                                   173

-------
 EPA  UTILITY  FGD  SURVEY:  JANUARY  -  MARCH  198C

 POTOMAC  ELECTRIC  POWERr  D1CKERSON  3  (CONT.)
	PEBfORMANCF DATA	
PERIOD MODULE AVAILABILITY  OPERAPILlTY  RELIABILITY  UTILIZATION  X  REMOVAL   PER  B01LEP  FGD   CAP.
                                                                 SO?  PACT. HQUuS HOURS  HOURS FACTOR


 4/79  SYSTEM                                                                 770

 5/79  SYSTEM                                                                 744

       •• PROBLEMS/SOLUTIONS/COMMENTS
                          SCRUEBER OUTAGE  HOURS  SINCE  SEPTEMBER 1978 U.E. SEPTEMBER  1976 THROUGH
                          MAY 2C,  1979)  TOTAL  140.   THE  UTILITY INDICATED  THAT IT IS  NO LONGfR ALLOW-
                          ABLE  TO  BYPASS THE  SCRUBBER  yHEN  PROBLEMS  OCCUP, CLEANING  THE PARTICULATf
                          MATTER SOLELY  yITH  THE  ESP.   THE  UTILITY  "UST  DROP  THE BOILER LOAD SO THE.
                          UNIT  REMAINS  IN  COMPLIANCE.
                          THERE HAVE BEEN  NO  PROBLEMS  REPORTED  FOR  THE LAST FEw MONTHS.  THE UTILITY
                          IS KEEPING AHEAD OF  PROBLEMS WITH A  CONSCIENTIOUS INSPECTION  AND l"AIf,l£>v-
                          ANCE  PROGRAM.

 6/79  SYSTEM                                                                 720

 7/79  SYSTEM                                                                 744

 8/79  SYSTEM                                                                 744

 9/79  SYSTEM                                                                 730

1D/79  SYSTEM                  98.6                     95.4                   744   72C    710

       •« PROBLE*S/SOLUTIONS/COMMENTS
                          A  TEN HOUR OUTAGE OCCURRED FOR  REPAIRS  OF  A  LEAD LINE LEAK.

11/79  SYSTEM                  95.2                     88.8                   7?0   67?    640

       •* PROBLEMS/SOLUTIONS/COMMENTS
                          IN NOVEMBERt 8 HOURS OUTAGE  TIME  WAS  "EOUIRED  TO REPAIR A  LEAK IN  A
                          RECYCLE LINE.

12/79  SYSTE"                  96.1                     9*.5                   744   724    696

       «• PROBLEMS/SOLUTIONS/COMMENTS
                          AN OUTAGE FOR GENERAL INSPECTION  TOOK  PLACE  DURING  DECEMBER.

 1/80  SYSTEM      78.7        88.2                     78.7                   744   664    586

       •* PROBLEMS/SOLUTIONS/COMMENTS
                         DURING JANUARY THE SCRUBBER  WAS DObN  TO REPAIR THE  FLAKEGLASS LINING.

 2/80  SYSTEM     100.0        10P.O                    100.0                   696   696    696

 3/80  SYSTEM     100.C        100.0                    1CC.O                   744   744    744

       ** PR08LEMS/SOLUTIONS/COMMENTS
                         DURING FEBRUARY AND MARCH THE SCRUBBER OPERATED  WITH  NO MAJOR PROBLEMS.
                                               174

-------
                                              EPA  UTILITY fGD SURVEY:  JANUARY - MARCH
                                            SECTION  14
                  DESIGN AND PERFORMANCE DAT*  FOR  OPERATIONAL PARTICLE  SCRUBBERS


COMPANY NAME                                     PUBLIC SERVICE  OF  COLORADO
PLANT NAME                                       ARAPAMOE
UNIT NUMBER                                      <•
CITV                                             DENVER
STATE                                            COLORADO
REGULATORY CLASSIFICATION                       **.»*»
PARTICULATE  EMISSION LIMITATION - NG/J             * 3 .          <   .1CC  Le/MweTU)
S02 E"ISS10N  LIMITATION - NG/J                  .*...,          (......  LF/MHPTU)
NET PLANT  GENERATING CAPACITY - My              *»»*..*
&ROSS UNIT GENERATING CAPACITY - My               112.C
HET~UNJT GENERATING CAPACITY W/FGD -  »H           1G'.8
ycl UNIT GENERATING CAPACITY yO/FGD -  MW        .*..«*«
EOUIVALFNT SCRUBBED CAPACITY - My                  11.3

•*  P01LER  DATA
    SUPPLIER                                     ««•«««
    TYPE                                         PULVERIZED  COAL
    SERVICE  LOAD                                •*•***
    COM'ERCIAL SERVICE DATE                      5/55
    MAXIMUM  BOUES fLUE GAS  FLOW  - CU.M/S         2*5.39        <  5200CC «CFK>
    FLUE  GAS  TEMPERATURE -  C                      1*8.9         (  3"0 F)
    STACK  HEIGHT - H                            *....*          («*•* fT)
    STACK  TOP DIAWETE" - «                      .*•«.*.         (..... FT)

..  FUEL CAT*
     FUEL  TYPE                                   COAL
     FUEL  GRADE                                  SUBEI TUMI NOUS
    AVERAGE  HEAT CONTENT -  J/G                   237J5.         <  IC^OC BTU/LP)
    RANGE  HEAT CONTENT - 8TU/L6                                  .«««**
     AVERAGE  ASH CONTENT  -  *                         9.3C
     RANGE  ASH CONTENT  -  2                       ***•««
     AVERAGE  MOISTURE CONTENT -  X                    T*.70
     RANGE  MOISTURE  CONTENT  - »                  .*...*
     AVERAGE  SULFU"  CONTENT  - X                        .95
     RANGE  SULFUR CONTEST -  X                   0.6-0.95
     AVERAGE  CHLORIDE CONTENT -  X                      .01
     RANGE  CHLORIDE  CONTENT  - X                  ••«..«
    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 - »
     RANGE CHLORIDF  CONTENT - X

    FABRIC FILLER
     NUMBER
     TYPE
COAL
BITUMINOUS
 23493.

   12.50
»•»•**
   11.2C
t  1C1DC ETU/LP)
      .65
     t *
      .01
 0
NONE
     NUMBER

 ,. ȣCHANICAL  COLLECTOR
     NUMBER

 .. PARTICULATE SCRUBBER
     NUMBER
     TYPE
     SUPPLIER
     NUMBER  OF  STAGES
     SHELL  MATERIAL
     LINING  MATERIAL
     INTERNAL  MATERIAL
     BOILER  LOAO/SCRUBPER -  X
     FLUE  GAS  CAPACITY  - CU.M/S
 MOBILE PACKED  TOWE9
 AIO  CORRECTION  DIVISION, UOP
     3
 CARBON STEEL
 RUB6?H
 STAINLESS STEEL GRIDS,  PLASTIC SPHERES
   100.0
   2*5.4         <  5?OCOO ACF«)
                                                  175

-------
EPA UTILITY  FGO  SURVEY: JANUARY - MARCH  1980

PJPLIC  SERVICE  Of  COLORADO: ARAPAHOfc 4  (CONT.)

      HUE  GAS  TEMPERATURE - C                      151.7         <  305  F)
      L/G RATIO  - LITER/cU.W                          7.5         <56.0 GAL/KOOACf)
      PRESSURE  DROP - KPA                         .*.....         (•••••  JM-H?O>
      SUPERFICIAL G»S VELOCITY - M/S                  3.4         <    11.0  FT/S)
      PARTICULATE INLET LOAD - G/CU.M                 1.8         <    .8r, GB/SCF)
      PARTICULATE OUTLET LOAD - G/CU.M                 .0         (  .32C GP/SCF)
      PARTICULATE DESIGN REMOVAL EFFICIENCY  -  »      93.0
      S02 INLET  CONCENTRATION - PPM                 5C7.00T
      so< OUTLET  CONCENTRATION - PPM                3i?.ooo
      SOZ DESIGN  REMOVAL EFFICIENCY - X              20.0



.	.—	PERFORMANCE  DATA	•--	
PERIOD  MODULE AVAILABILITY OPERAPILITY RELIABILITY  UTILIZATION  X REMOVAL   PEP  BOILER   FGO   C«P.
                                                                  SO?  PART. HOURS HQUoS   HOURS FACTOR


13/7<>   SYSTEM                                                                   744

11/79   SYSTEM                                                                   720

12/79   SYSTEM                                                                   744

        *•  PROBLEMS/SOLUTIONS/COMMENTS
                          DURING THE FOURTH  QUARTER  REHEAT£R  FAILURES OCCURRED.
                          LEAKAGE IN THE  INLINE  STEAM  TUBES HAS BEEN ENCOUNTERED.  CORROSION
                          IS KNOWN TO OCCUR  AFTER  LEAKS  ARE EXPERIENCED.
                          THE PRIMARY PROBLEM  KITH  THE  SYSTEM IS THE  INABILITY TO ISOLATE  MODULES.
                          IF  A PROBLEM OCCURS  NO MODULE  MAINTENANCE CAN EE PERFORMED  UNLtSS  THE
                          UNIT LOAD IS CUT BACK  OR  THE  UNIT IS SHUT OOyN.

 1/80   SYSTEM                                                                   744

 2/60   SYSTEM                                                                  6'e

 i/8?   SYSTEM                                                                   744

        ••  PROBLfcMS/SOLUTIONS/COMMENTS
                          THE MODULE ISOLATION PROBLEMS  CONTINUED THROUGH THE FIRST dUAPTFR  19t'.
                          USE OF  THE CARBON  STEEL  DAMPERS  HAS BEEN ABANDONED.  THE PKOGRA"  FOR RE-
                          PLACING THE DAMPERS  HAS  BEEN  SUSPENDED INDEFINITELY.
                          REHEATEH  STEAM TUBE  LEAKS  ARE  STILL CAUSING PROBLEM.  ThE  C STFA^ C C i Lr 0\
                          THIS  IN-LINE REHEAT  SYSTEM, i  or  WHICH ARE  3Uss AND 4 OF wnich  API C4s^o\
                          STEEL,  ARE EXPERIENCING  CORROSION PROBLEMS.  A SOLUTION TO  TbF  PRPfcLfl"  HA «:
                          NOT YET BEEN DETERMINED.
                          IN  FEBRUARY THE UTILITY  REPLACED  THE SCRUBBER B»LLS AND OH 01.   TutY ufc=-
                          REPLACEO  WITH THE  NE* HOLLOW HARC PLASTIC-WALLED BALLS WITH NOTCHED SEA"S
                          THE GRIDS  WERE ORIGINALLY  316L  SS,  CEPAMIC, POLYPROPYLENE,  «NO  "UB6ER L!\f
                          CARBON  STEEL,  faUT  HAVE BEEN REPLACED WITH 31?L SS GRIDS.
                          THE SCRUBBERS  OPERATED CONTINUOUSLY THROUGHOUT THE QUARTER  EXCEPT  fOU
                          BALL  AND  GRID  REPLACEMENT  DOWNTIME.
                                                176

-------
                                             EPA UT1L1TT FGD SURVEY:  JANUARY - MARCH 19fa?

                                           SECTION U
                  DESIGN  AND  PERFORMANCE DAT* FOR OPERATIONAL  PARTICLE  SCRUBPERS
PLANT  NAME
     NUMBER
STATE
REGULATORY  CLASSIFICATION
pARTJCULATE  EMISSION  LIMITATION - NG/J
S02  £«1SSION LIMITATION - NG/J
SET  PLANT  GENERATING  CAPACITY - MH
6BOSS  UNIT  GENERATING CAPACITY - Mu
NET  UNIT  GENERATING CAPACITY U/FGD - MW
NET  UNIT  GENERATING CAPACITY WO/FGD - MV
tOUJVALENT  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  -  *
     RANGE M01STUR? CONTENT  -  X
     AVERAGE SULFUR CONTENT  -  X
     RANGE Sl/LfUR CONTENT -  I
     AVERAGE CHLORIDE  CONTENT  -  »
     RANGE CHLORIDE CONTENT  -  X

 ..  FABRIC  FILTER
     NUMBER
     TYPE

 «•  ESP
     NUMBER

 t,  MECHANICAL COLLECTOR
     NUMBER

 .«  PARTICULATE  SCRUBBER
     NUMBER
     TYPE
     SUPPLIER
     NUMBER  OF  STAGES
     SHELL  MATERIAL
     LINING  MATERIAL
     INTERNAL  MATERIAL
     BOILER  LOAD/SCRUBBER - 1
     FLUE  GAS  CAPACITY - CU.M/S
     FLUE  GAS  TEMPERATURE - C
     L/G  RATIO - L1TER/CU.H
     PRESSURE  DROP - KPA
     SUPERFICIAL GAS VELOCITY - M/S
     PARTICULATE INLET LOAD - G/CU.M
     PARTICULATE OUTLET LOAD - G/CU.M
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     S02  JHLET CONCENTRATION - PPM
     S02  OUTLET CONCENTRATION - PPM
     S02  DESIGN REMOVAL EFFICIENCY -  X
   PUBLIC  SERVICE  OF  COLORADO
   CHEROKEE
   1
   DENVER
   COLORADO
    ** * * **
      MO.O
      115.0
      1CO.O
      115.0
      102.2
    6ABCOCK R WILCOX
    PULVERIZED COAL
                   <  .TOO
                   <«..».* LB/MMPTU)
     0/57
      245.39
      146.1
    COAL
    BITUMINOUS
     23493.

       12.50
    9.4-12.5
       11.30
              < 5?OCOC ACFM)
              < 295 f)
              <**»* fT)
              <**.«» FT)
               < 101CC  BTU/LB)
               ******
         .65
         k*
         .01
     0
    NONE
- X
     MOBILE PACKED TOWER
     AIR  CORRECTION DIVISION,  UOP
         3
     CARBOH STEEL
     RUBBER
     STAINLESS STEELi  1.5  INCH PLASTIC SPHERES
        67.0
       164.4         (  348400  Atrm
                        295  F)
                     
-------
EP* UTILITY FGD  SURVEY:  JANUARY - MARCH 1980

PUBLIC SERVICE or COLORADO:  CHEROKEE 1  
-------
                                             EPA  UTILITY  FGO SURVEY: JANUARY - MARCH  19fc(

                                           SECTION  14
                 DESIGN AND PERFORMANCE  DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION  -  NG/J
SOi EMISSION  LIMITATION  -  NG/J
NET PLANT GENERATING CAPACITY  -  MU
GROSS UNIT GENERATING  CAPACITY  - My
*ET UNIT GENERATING CAPACITY  U/FGD - MU
NET UNIT GENERATING CAPACITY  WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY  -  I»W

** BOILER DATA
    SUPPLIE"
    TYPE
    SERVICE  LOAD
    COMMERCIAL  SERVICE DATE
    MAXIMUM  BOILE"  FLUE  GAS FLOW - CU.M/S
    FLUE  GAS  TEMPERATURE - C
    STACK HEIGHT  -  M
    STACK TOP DI»M£TER - M

**  FUEL DATA
     FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT  CONTENT - J/G
    RANGE HEAT  CONTENT - BTU/LB
    AVERAGE  ASH CONTENT - *
     RANGE  ASH CONTENT - X
     AVERAGE  MOISTURE  CONTENT -  *
     RANGE  M01STURF  CONTENT - X
     AVERAGE  SULFUR  CONTENT - X
     RANGE  SULFUR  CONTENT - *
     AVERAGE  CHLORIDE  CONTENT -  1
     RANGE  CHLORIOF  CONTENT - X

 **  FABRIC  FILTER
     NUMBER
     TYPE

 • •  ESP
     NUMBER

 **  MECHANICAL COLLECTOR
     NUMBER

 «*  PARTICULATE SCRUBBER
     NUMBER
     TYPE
     SUPPLIER
     NUMBER OF  STAGES
     SHELL MATERIAL
     LINING MATERIAL
     INTERNAL MATERIAL
     L/G RATIO  -  LITER/CU.M
     PRESSURE DROP  -  KPA
     SUPERFICIAL  GAS  VELOCITY - M/S
     PARTICULATE  INLET LOAD  - G/CU.N
     PARTICULATE  OUTLET  LOAD  - G/CU.W
     PARTICULATE  DESIGN  REMOVAL EFFICIENCY
     S02 INLET  CONCENTRATION  - PPM
     S02 OUTLET CONCENTRATION - PPM
     S02 DESIGN REMOVAL  EFFICIENCY - X
PUBLIC SERVICE OF COLORADO
CHEROKEE
4
DENVER
COLORADO
   43.
               .1CC LB/MMBTU)
              .«.*« LB/MMPTU)
  71C.O
  375.0
  330.0
  375.0
  356.4
 COMBUSTION  ENGINEERING
 PULVERIZED  COAL

 3/6"
  717.29        (1520000 ACFM)
  135.0         <  275 F)
 ......          (.... ff>
 .......         (..... FT)
 COAL
 BITUMINOUS
  23493.

    12.50
 9.4-12.5
    11.30
 ******
      .65
             ( 101CC  BTU/LP)
      .01
  0
 NONE
 MOBILE PACKED  TOWER
 AIR CORRECTION  DIVISION,  UOP
     t
 CARBON STEEL
 RUBBER
 STAINLESS  STEEL,  1.5 INCH PLASTIC SPHERES
      7.5
  ?.4
  1.6
   .0
 97. Q
520. OOP
42C.OOO
 U.O
                 (56. C
                 (*•**• IM-H20)
                     11.* FT/S)
                     .7C GMSCF)
                    .C20 GP/SCF)
                                                 179

-------
EP» UTILITt  FGO  SURVEY: JANUARY - MARCH  1980

PUBLIC SERVICE  OF  COLORADO: CHEROKEE  4  PECTS  THIS  TO PROVE TO BE A PERMANENT SOLUTION.
                          ALSO  DURING THE OUT«6E  A  SECOND LAYER OF VERTICAL GRIDS  IS  PE1NG INSTALLS
                          ON  THE  THREE LAYER MOBLE  BED  TOWER.  THE VERTICAL GRIDS  SHOULD  CHECK THE
                          POTENTIAL FOR SIDE TO SIDE tALL MIGSATJOK.
                          THE OLD FANS ARE BEING  REPLACED HlTH HIGH STRENGTH  CARBON  STEEL FANS HAVINr
                          HEPLACAPLE CHROMIUM ALLOY  hEAR  PLATE BLADF TIPS.
                                                180

-------
                                             EPA UTILITY FGD SURVEY: JANUARY - MARCH  1980

                                           SECTION U
                 DESIGN  AND  PERFORMANCE  DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE  EMISSION  LIMITATION  - NG/4
S02 EMISSION  LIMITATION  -  N6/J
MET PLANT GENERATING  CAPACITY  -  MW
CROSS UNIT GENERATING CAPACITY  - My
MET UNIT GENERATING CAPACITY  W/FGO - Mu
MET 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.M/S
    FLUE GAS  TEMPERATURE - C
    STACK HEIGHT  -  M
    STACK TOP DIAMETER - M

**  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT  CONTENT - lit,
    RANGE HEAT  CONTENT - BTU/LB
    AVERAGE  *SH CONTENT - X
    RANGE ASH CONTENT - t
    AVERAGE  MOISTURE  CONTENT - %
    RANGE MOISTURE  CONTENT - X
    AVERAGE  SULFUR  CONTENT - X
    RANGE  SULFUR  CONTENT - X
    AVERAGE  CHLORIDE  CONTENT - X
    RANGE CHLORIDE  CONTENT - X

**  FABRIC  FILTER
    NUMBER
    TYPE
PUBLIC SERVICE OF COLORADO
VALMONT
5
VALHONT
COLORADO
   43.
**<***
  273.8
  166.0
  157.0
  163.0
  166.0
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
 0/64
  436.98
  126.7
              (  .100 LB/MNBTU)
              (****** LB/MMBTU)
               ( 926000  ACFM)
               C 260  F)
               <••*»  FT)
               <•****  FT)
COAL
SUBBITUMINOUS
  25121.

    6.00
5.4-7.0
    15.00
12.7-18.3
      .70
0.68-.73
               (  1T800 BTU/LP)
  0
 NONE
    ESP
     NUMBER
     TYPE
     FLUE 6AS CAPACITY - CU.M/S
 COLD SIDE
   218. 5
               ( 463000 ACFM)
    MECHANICAL COLLECTOR
     NUMBER
     FLUE GAS CAPACITY -
    PARTICULATE SCRUBBER
     NUMBER
     TYPE
     SUPPLIER
     NUMBER OF STAGES
     SHELL MATERIAL
     LINING MATERIAL
     INTERNAL MATERIAL
     TYPE OF NOZ7LES
     BOILER LOAD/SCRUBBER  -  X
     FLUE GAS CAPACITY - CU.M/S
     FLUE GAS TEMPERATURE  -  C
     L/6 RATIO - LITER/CU.*
     PRESSURE DROP - KPA
     SUPERFICIAL GAS VELOCITY  -  M/S
     PARTICULATE INLET LOAD  -  G/CU.M
     PARTICULATE OUTLET LOAD - G/CU.M
     S02 INLET CONCENTRATION - PPM
     S02 DESIGN REMOVAL EFFICIENCY - X
  1
   218.5
               c 463000 ACFM)
 MOBILE PACKED TOWER
 AIR CORRECTION DIVISION, UOP
     3
 CARBON STEEL
 RUBBER
 STAINLESS STEEL, 1.5 INCH PLASTIC  SPHERES
 25.
    36.0
   109.2        ( 231500  ACFM)
                    271  F)
                158.3 GAL/1000ACF)
                (•**«*  IN-H20)
                     11.0  FT/S)
                     .80 6R/SCF)
                    .020 GR/SCF)
  132.8
    7.8
••*•••*
    3.4
    1.8
     .0
  500.000
   40.0
                                                181

-------
EPA  UTILITY  FGO  SURVEY: JANUARY - MARCH  1980

PUBLIC  SERVK£  Of  COLORADO: VALMONT  5  <£ONT.)
	PERFORMANCE DATA	
PERIOD MODULE  AVAILABILITY OPERABILIT1  RELIABILITY UT1LI7ATION
                                                           *  REMOVAL    PER   BOUE*  F6o    c«p.
                                                           S02   PART.  HOURS HOURS  HOURS FACTOR
ID/7*  SYSTEM
                                                                                744
       •• PROBLEMS/SOLUTIONS/COMMENTS
                          THE SCRUBBER WAS  ORIGINALLY  INSTALLED FOR PARTJCULATE  REMOVAL  SINCE THE
                          PLANT BURNS LOy SULFUR  COAL;  HOWEVER, 45X OF THE SO? IS  REMOVED  AS  WELL
                          BECAUSE OF THE ALKALINITY  OF  THE FLYASH.
11/74  SYSTEM

1Z/74  SYSTEM

 1/75  SYSTEM
3/75
3/75
4/75
5/75
6/75
7/75
3/75
9/75
ID/75
11/75
12/75
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
                                                                         720

                                                                         744

                                                                         744

                                                                         672

                                                                         744

                                                                         7?C

                                                                         744

                                                                         720

                                                                         744

                                                                         744

                                                                         720

                                                                         744

                                                                         72C

                                                                         744

•• PROBLEMS/SOLUTIONS/COMMENTS
                   DURING  THE  FIRST TEAR OF OPERATION  PROBLEMS  INCLUDED DIFFICULTIES WITH  THF
                   MODULE  PACKING GRID SUPPORT, GENERAL  VESSEL  SCALE FORMATION, FLOW DISTRI-
                   BUTION  PROBLEMS, BALL BREAKAGE,  SCALING  IN  THE  MIST ELIMINATOR SECTION
                   AND  PLUGGING  Of THE REHEATER.   SCALE  FORMATION  WAS THE MOST PREDOMINANT
                   CONTINUING  MAJOR CAUSE OF DOWNTIME  IN  THE  SCRUBBER.  SCALE ACCUMULATION    ft
                   WAS  NOTED  ON  THE WET-DRY INTERFACE  IMMEDIATELY  DOWNSTREAM OF THE PRESATU
                   RATION  N072LES.  SCALE ALSO ACCUMULATED  HEAVILY ON THE UNDERSIDE OF  THE
                   FIRST  LATER OF GRID BARS.
                   SCALE  ON THE  UPPER GRID BARS WAS LESS  PREVALENT AS THE ACTION OF THE  "PiMr
                   PONG"  BALLS TENDED TO KEEP THE  SCALE  OFF  OF  THESE SECTIONS.  SCALE ALSO
                   COLLECTED  ON  THE WALLS OF THE VESSEL  AND  INTERMITTENTLY SLOUGHED OFF  AND
                   FELL INTO  THE  SUMP IN LARGE PIECES  CAUSING BLOCKAGE OF THE REC1RCULATI ON
                   PUMP SUCTION  SCREENS.  SCALING  OF THE  MIST ELIMINATOR ABATED SOMEWHAT WITH
                   THE  INTRODUCTION OF A CLEAR RINSE WATER  WASH.   SCALE FORMATION IN THE RE-
                   HEAT SECTION  SOMETIMES REOUJREO SUPPLEMENTAL  CLEANING OF  THE REHEATER IN
                   ADDITION TO THE CLEANING OBTAINED BY  THE USE  OF  THE SOOTBLOWERS WHICH uccr
                   INSTALLED  AS  A PART OF THE REHEATER EQUIPMENT.   UNDER NORMAL OPERATION
                   THE  SOOTBLOWERS LOCATED IN THIS REHEAT SECTION  WERE FAIRLY SUCCESSFUL IN
                   REMOVING THE  ACCUMULATION OF THE SCALE IN THE REHEATER.
                   ALTHOUGH MAN1  OF  THE INITIAL START-UP  PROBLEMS  WERE SOLVED OVER A PERIOD
                  OF TIME, THE  CALCIUM SULFATE-FLVASH SCALING CONTINUED TO  BE  A SIGNIFICANT
                  OPERATING  PROBLEM AT THE VALHONT INSTALLATION.   IN ADDITION  TO THESE
                   SCALING RELIABILITY PROBLEMS, A WATER  OUALIT* CONCERN ALSO SURFACED THAT
                  WAS A DIRECT RESULT OF THE PARTICULATE SCRUBBER  OPERATION.  THE RELATlVFiv
                  HIGH CAO CONCENTRATION IN THE VALMONT  FLTASH  RESULTED IN  FAIRLY HIGH SO?
                  REMOVAL RATES  C45-50 PERCENT) WITHIN THE UNITS.   SINCE  NO PH CONTROL CAPA
                  BILITT FOR  EITHER  THE RECIRCULATIN6 SLURRY OR THE  SYSTEM  BLOWOOWN SLURRY
                  WAS DESIGNED INTO  THE SYSTEM, AN ACID  CONDITION  WAS CREATED  IN THE SLURRY
                  AND THE SLOWDOWN  STREAM.   PH LEVELS OF THE SLOWDOWN NORMALLY RANGED BETuEFkj
                  1.7 AND 2.0.   ALTHOUGH THE  STREAM WAS NEUTRALIZED  TO  A  DEGREE  BY  ALKALINE
                  FLTASH, PSCC FELT  THAT IT WAS IMPORTANT TO INVESTIGATE  VARIOUS  CONTROL
                  MEASURES WHICH  COULD  BE  APPLIED  TO THIS STREAM.   THE  CALCIUM SULFATE
                  SCALING PROBLEM WAS  THOUGHT  TO  BE THE RESULT OF  A  SUPER-SATURATED CALCIUM
                                               182

-------
                                               EPA  UTILITY  FGD SURVEY: JANUARY  - MARCH  1980
PJBLIC  SERVICE  OF  COLORADO: VALMONT 5 (CONT.)
____	.	PERFORMANCE DATA	
PERIOD  MODULE  AVAILABILITY OPERABIL1TY RELIABILITY  UTILIZATION  T REMOVAL    PER   BOILER   FGD   CAP.
                                                                  SO?  PART. HOURS  HOURS   HOURS FACTOR

                          SULFATE CONDITION  IN  THE  REC 1RCULATING SLURRY.  BECAUSE  OF  THIS  IT WAS FELT
                          THAT CONTINUOUS PH  CONTROL  OF  THE REC 1RCULATING SLURRY,  CONVERSION OF THE
                          SYSTEM TO CLOSED LOOP OPERATION AND ESTABLISHING A  HIGHER  CONCENTRATION OF
                          SEEDING SOLIDS  IN  THE RECIRCULAT10N SLURRY  (THEREBY  CONTROLLING  THE SCALING
                          PROBLEMS WITHOUT CHEMICAL  ADDITIVES) WOULD BE NECESSARY  MEASURES.
                          FOR PH CONTROL, LIMESTONE  WAS  TESTED INITIALLY, THEN  LIME  WAS  UTILIZED FOR
                          THE ALKALI REAGENT.   IN THE FIRST TEST, SINCE LIMESTONE  UTILIZATION WAS A
                          MAJOR  CONCERN,  A SPECIAL  EFFORT WAS MADE TO REDUCE  THE  POTENTIAL FOR THE
                          SHORT  CIRCUITING OF  THE ADDED  LIMESTONE AND TO  PROVIDE  SUFFICIENT  RESIDENCE
                          TIME IN THE  REACTOR  SECTION OF  THE SYSTEM.  BY  UTILIZING FOUR  REATION MIX
                          TANKS  IN SERIES, PLUG FLOW  WAS  EXPECTED TC BE MORE  CLOSELY  SIMULATED.  TO
                          MAINTAIN A CLOSED  LOOP SYSTEM  WHERE THE QUANTITY OF  taATER  REMOVED  FROM THE
                          SYSTEM WAS HELD TO *  MINIMUM,  FOUR SYSTEM DESIGN FEATURES  WERE UTILIZED.
                               1. UTILIZATION  OF A  COMBINATION OF POND  SUPERNATANT AND MAKE-UP WATER
                                  FOR  RECYCLE  WATER.
                               2. PRESATURATION OF  THE INCOMING FLUE  GAS  WITH hECIRCULATING SLURRY.
                               3. INTERMITTENT  MIST ELIMINATOR WASH.
                               4. PROPER  SELECTION  OF MATERIALS OF CONSTRUCTION TO PROTECT AGAINST
                                  ATTACK  CAUSED faY  HIGH CHLORIDE CONCENTRATIONS.
                          THE SCRUBBERS  R R  D  FACILITY WAS NOT EQUIPPED WITH  A MECHANICAL THICKENER
                          FOR CONTROL  OF  THE SUSPENDED SOLIDS CONCENTRATION  OF THE REC IRCULATING
                          SLURRY  
-------
EPA  UTILITY  FGO  SURVEY: JANUARY  - MARCH  1980

PUBLIC  SERVICE  OF  COLORADO: VALMONT  5  (CONT.)
......	_ — .	.	PERFORMANCE DATA-
PERIOD MODULE  AVAILABILITY OPERAPIL1TY RELIABILITY  UTILIZATION  X REMOVAL
                                                                                E*   BOILER   FGO   CAP
                                                                  S02  PART.  HOURS  HOURS   HOURS FACTOR
 8/77  SYSTEM

 9/77  SYSTEM

10/77  SYSTEM

11/77  SYSTEM

1Z/77  SYSTE"

       SYSTEM

       SYSTEM

       SYSTEM
1/78

2/78

3/7?
744

720

744

7?0

744

744

672

744
       •• PROBLEMS/SOLUTIONS/COMMENTS
                          THERE  HAVE BEEN RECURRING  PROBLEMS  ASSOCIATED WITH BALL MIGRATION  IN  Tut
                          BALL  COMPARTMENT AS fc E LL AS  RECIRCULATION PUMP MOTOR PEARING FAILURE   Aiun
                          WEAR  AND FAILURE IN THE BALL COMPARTMENT LINING.  THERE HAVE BEEN  CONTTiuii.
                          PROBLEMS WITH REHEATER PLUGGING.   THERE  ALSO HAVE BEEN EXPANSION JOINT
                          FAILURES *T BOTH THF INLET AND  OUTLET  OF THE SCRUBBER.
                          MORE  RECENTLY THERE WAS A  PINCH  BELT  FAILURE.
                          THE  SCRUBBING SYSTEM HAS HAD AN  AVAILABILITY RANGE OF 50 TO 7SX yiTu  .1,
                          AVERAGE  OF 661.                                                      H  AN
 4/7?  SYSTEM

 5/78  SYSTEM

       • • PROBLEMS/SOLUTIONS/COMMENTS
                         NO  SIGNIFICANT  PROBLEMS WERE ENCOUNTERED.

 6/7«  SYSTEM

 7/78  SYSTEM

 8/78  SYSTEM

       • •  PROBLEMS/SOLUTIONS/COMMENTS
                         THE UTILITY HAD  NO COMMENTS FOR THIS PERIOD.
9/78
ID/78
11/78
12/78
1/79
2/79
3/79
4/79
5/79
6/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
                                                                              720

                                                                              744



                                                                              72C

                                                                              744

                                                                              744



                                                                              720

                                                                              744

                                                                              72C

                                                                              744

                                                                              744

                                                                              672

                                                                              744

                                                                              7?0

                                                                              744

                                                                              720
      •• PROBLEMS/SOLUTIONS/COMMENTS
                         AVERAGE SCRUBBER AVAILABILITY  FROM START UP THROUGH APRIL  1979  WAS  64 A5»
                         AVERAGE SCRUBBER AVAILABILITY  FOR  1978 WAS 66.85*.                    •*«
                         AVERAGE SCRUBBER AVAILABILITY  FBQM JANUARY 1, 1979 THROUGH  MAY.  197O
                         APPROXIMATELY 8PJt.                                                      "5
                         BALL  MIGRATION, ALTHOUGH NOT  SERIOUS, is A CHRONIC PROBLEM  FOR  VALMONT 5
                                               184

-------
                                              EPA UTILITY  FGD  SURVEY: JANUARY - MARCH 19gO
PUBLIC  SERVICE  OF  COLORADO: VALMONT 5 (CONT.)
__„___- — —	—-PERFORMANCE  DATA — ——-—-—	—	——	
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY  UTILIZATION  * REMOVAL   PE*  BOILER   FGD    CAP.
                                                                  S02  PART. HOURS HOURS  HOURS  FACTOR

                          EROSION AND CORROSION  HAVE  OCCURRED ON THE SCRUBBER GRID BAR  AREA  (PACKING
                          SUPPORT).
                          EROSION/CORROSION  IS  EVIDENT  IN THE MIST ELIMINATOR SECTION.
                          EROSION/CORROSION  OCCURRS  IN  THE REHEATER AREA AND SOOT BLOWER.
                          THE UTILITY HAD TO  REPLACE  INLET AKD OUTLET EXPANSION JOINTS.
                          REHEATER PLUGGING  HAS  BEEN  A  PROBLEM.
                          RECYCLE PUMP BEARING  FAILURES OCCURRED.
                          THE JACK SCREW  DRIVE  HAS BEEN MALFUNCTIONING ON INLET AND  OUTLET ISOLATION
                          DAMPERS.
 7/70

 8/79

 9/79
SYSTEM

SYSTEM

STSTE"
                                                           744

                                                           744

                                                           720
           PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  THE  ANNUAL  SHUTDOWN IN SEPTEMBER THE OLD  SCRUBBER  BALLS  WERE
                          REPLACED  WITH  A  NEW  BRAND.  DUE TO BALL MOTION THE  RUBBER  LINER  ERODED*
                          IN  THE  MIST ELIMINATOR SECTION EROSION AND CORROSION  OCCURRED.
 13/79

 11/79

 12/79
SYSTEM     100.0

SYSTEM      92.3

SYSTEM      98.1
                                                           744

                                                           72C

                                                           744
           PROBLEMS/SOLUTIONS/COMMENTS
                           ONE  OF  THE  MAJOR SYSTEM PROBLEMS IS THE  SCRUBBER  WALL WEAR WHICH HAS
                           TO  BE  PATCHED DURING THE SPRING AND FALL.
                           REHEATER  PLUGGING HAS BEEN A CHRONIC PROBLEM.
                           THE  UTILITY HAS REPORTED THE FOLLOWING ANNUAL  AVAILABILITIES FOR THE UNIT,
                               1972  -  1978: 64.JX
                               1972  -  1979: 65.9*
                                      1978: 66.81
                                      1979: 80.5T
  1/80
  2/8?
  3/8?
A
B
SYSTEM

A
B
SYSTEM

A
b
SYSTEM
98.5
98.5
98.5

84.4
94.9
89.7

85.0
85.0
85.0
                                                                                744
                                                                                696
                                                                                744
         *•  PROBLEMS/SOLUTIONS/COMMENTS
                           DURING THE FIRST QUARTER  1980.  NO MAJOR PROBLEMS WE"E ENCOUNTERED  WITH
                           THE SCRUBBER.
                                                  185

-------
EPA UTILITY  FGD  SU»VE«:  JANUARY - MARCH  1980
                                            SECTION  U
                   DESIGN  AND PERFORMANCE DATA  FOR OPERATIONAL PARTICLE SCRUBBERS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 REGULATORY CLASSIFICATION
 PARTICULATE EMISSION LIMITATION - N6/J
 S02  EMISSION LIMITATION  -  N6/J
 NET  PLANT GENERATING CAPACITY  - MW
 GROSS UNIT GENERATING CAPACITY  * «W
 NET  UNIT GENERATING CAPACITY W/FGD - MM
 NET  UNIT GENERATING CAPACITY yO/FGO - MW
 EQUIVALENT SCRUBBED CAPACITY -  Mw
 SOUTHWESTERN PUBLIC SERVICE
 HARRINGTON
 1
 AMARILLO
 TEXAS
 * *** * *
   516.
   360.0
   360.0
                                                                 <  .10C LB/MMPTU)
                                                                 ( 1.20C LE/MMPTU)
    BOILER  DATA
     SUPPLIER
     TYPE
     SERVICE  LOAD
     COMMERCIAL SERVICE DATE
     MAIIMUM  BOILER FLUE GAS FLOW -  CU.M/S
     FLUE GAS TEMPERATURE - c
     STACK  HEIGHT - M
     STACK  TOP DIAMETER - M

    FUEL DATA
     FUEL TYPE
     FUEL GRADF
    AVERAGE  HEAT CONTENT - J/G
    RANGE  HEAT  CONTENT - BTU/LB
    AVERAGE  ASH CONTENT - X
    RANGE  ASH  CONTENT  - X
    AVERAGE  MOISTURE CONTENT  - *
    RANGE  MOISTURE  CONTENT -  X
    AVERAGE  SULFU»  CONTENT -  X
    RANGE  SULFUR CONTENT - t
    AVERAGE CHLORIDE CONTENT  - t
    RANGE  CHLORIDE  CONTENT -  X
COMBUSTION  ENGINEERING
PULVERIZED  COAL
BASE
 S/76
  778.63        (1650000 ACFM)
  176.7         I  350 F)
   7ft.          (  250 FT)
     .8         (   2.7 FT)
COAL
SUBBITUMINOUS
 1953d.

    5.30
4.5-6
   27.10
25-3?
     .42
.39-.45
                                                                 <   8400 PTU/LB)
                                                                 8000-8900
• * 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

•• PARTICULATE  SCRUBBER
    NUMBER
    TYPE
    SUPPLIER
    NUMBER OF  STAGES
    SHELL MATERIAL
    LINING MATERIAL
    INTERNAL MATERIAL
    NUMBER OF  NOZZLES
    TYPE Of NOZZLES
    BOILER LOAD/SCRUBPER - X
    fLUE GAS CAPACITY - CU.M/S
    fLUE GAS TEMPERATURE - C
    LIQUID RECIRCULATION RATE  - LITER/S
    L/G RATIO  -  LITER/CU.M
    SUPERFICIAL  GAS VELOCITY - M>s
    PARTICULATE  INLET LOAD - NG/J
    PARTICULATE  OUTLET LOAD -  NG/J
    PAHTJCULATE  DESIGN REMOVAL EFFICIENCY - X
    502 INLET CONCENTRATION -  NG/J
    S02 OUTLET CONCENTRATION  - NG/J
                                                  1
                                                 COLD  SIDE
                                                 RESEARCH COTTRELL
                                                    95.C
                                                  77S.6         (1650PCC ACFM)
                                                  16S.3         (  335 F)
                                                 .......         (..... IN-H20)
                                                      .18       (   .C8 GR/SCF)
                                                MOBILE  PACKED  TOWER
                                                COMBUSTION  ENGINEERING
                                                     1
                                                CARBON  STEEL
                                                RIGID LINE  POLYESTER
                                                316L SS  FIBERGLASS  ALLOY 2C
                                                   59
                                                OPEN PIPE
                                                  141.6

                                                  444.1
                                                    3.1
                                                  43'.
                                                  21*.
                 30CCCC ACFM)
                  140 F)
                 7C5C GPM)
                ?3.0 GAL/1POCACF)
                    8.0 FT/S)
                  .185 LP/MMPTU)
                  .07C LE-/MMPTU)

               (  1.00C LP/MMPTU)
               (   .SCO LB/MMBTU)
                                               186

-------
                                              EPA UTILITY FGP SURVEY: JANUARY - MARCH  1980

SOUTHWESTERN  PUBLIC  SERVICE:  HARRINGTON  1  CCONT.)
__„	PERFORMANCE DATA —	
PERIOD  MODULE  AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION  t ȣKOVAL   PER  BOILER   FGD    CAP.
                                                                 S02  PART. HOURS HOURS  HOURS  FACTOR


10/70   SYSTEM                                                                  744

11/79   SYSTEM                                                                  ?20

12/79   SYSTEM                                                                  744

        *•  PROBLEMS/SOLUTIONS/COMMENTS
                          DURING OCTOBER THROUGH DECEMBER, TWO SPRAY PUMP KOTORS  FAILED.
                          THE FRP MATERIAL IN THE FLUSH PIPING HAS FAILED CAUSING SOME  LEAKAGE.
                          PLUGGING IN ONE MARBLE BED UAS ENCOUNTERED WHEN THE  CHEMISTRY  CONTROL  W*S
                          TEMPORARILY LOST.
                          THE CONE SHAPED EXPANDED METAL SCREEN COVERING THE BED  DRAIN  PIPES  HAS    E
                          ERODED AWA1 F»OP BALL MOVEMENT.  THE MARBLE BALLS HAVE  BEEN  DROPPING  INTO  1
                          THE CONE SHAPED EXPANDED METAL SCREEN COVERING THE PED  DRAIN  PIPES  HAS    E
                          ERODED AWAY FROM BALL MOVEMENT.  THE MARBLE BALLS HAVE  SEEN  DROPPING  INTO  1
                          THE RECYCLE TANK.  WHERE THE UTILITY HAS REPLACED THE  METAL  SCREEN  WITH ANE
                          THE CONE SHAPED EXPANDED METAL SCREEN COVERING THE BED  DRAIN  PIPES  HAS    E
                          ERODED AWAY FRO" GALL MOVEMENT.  THE MARBLE BALLS H»vF  REEN  DROPPING  INTO  Y
                          THE RECYCLE TANK.  WHERE THE UTILITY HAS REPLACED THE  METAL  SCREEN  WITH ANE
                          EXPANDED PLASTIC SCREEN, EROSION HAS MOT OCCURRED.

  1/60   SYSTEM                                                                  744

  2/80   SYSTEM                                                                  «96

  3/60   SYSTEM                                                                  744

        *•  PROBLEMS/SOLUTIONS/COMMENTS
                          DURING THE  FIRST QUARTER 19SO  THE  MIST  ELIMINATOR WASH PIPING RUPTURED
                          CAUSING PLUGGING IN SCRUBBERS  4  AND  S.   THt  UTILITY  PLANS TO REPLACE
                          ALL FRP PIPING  WITH STEEL.   THE  RUPTURE  ON  NO.  5  ALSO  DAMAGED THE HATER
                          SUPPLY HEADER.
                          THE MARBLE  BED  PLUGGING  REPORTED DURING  THE  LAST  QUARTER  jS  NOT YET
                          COMPLETELY  CLEARED.   THE SOFT  SCALE  IS  GRADUALLY  GOING BACK INTO THE
                          SOLUTION.   THE  PLATE  AREA  IS  CLEAN.
                          THE DUCT BENEATH THE  REHEATER  TUBING ON ONE  OF  THE  MODULES HAS  CORRODED TC
                          THE POINT  THAT  HOLES  HAVE  FORMED.   SCAL?  AND  M01STU«e  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 AREA  HAS EXPERIENCED ANY  ?CA
                          OR MOISTURE.
                                                  187

-------
 EPA  UTILITY  FGD  SURVEY:  JANUARY  -  MARCH 1980
                                             SECTION 15
                 DESIGN  AND  PERFORMANCE  DATA FOR OPERATIONAL FOREIGN FGC SYSTEMS


  COMPANY NAME                                    CHUGOKU ELECTRIC
  PLANT NAME                                      SHIMOMOSEKI
  JNIT NUMBER                                     1
  CITY                                            SHIMONOSEKI
  STATE
  GROSS UNIT GENERATING  CAPACITY  - MW               175.C
  SET UNIT GENERATING CAPACITY W/FGD - *W           175.C
  EQUIVALENT SCRUBBED CAPACITY -  MW                 175.0

  •• FUEL DATA
      FUEL TYPE                                   COAL
      FUEL GRADE                                  *••«*•
      AVERAGE HEAT CONTENT - J/G                  25046.        I 1C768  BTU/LP)
      AVERAGE ASH CONTENT - X                        24.6C
      AVERAGE MOISTURE CONTENT -  X                   2.30
      AVERAGE SULFUR CONTENT - X                       .59
      AVERAGE CHLORIDE CONTENT -  X                     .04

  •• F60  SYSTEM
      GENERAL PROCESS TYPE                        WET SCRUBBING
      PROCESS TYPE                                LIMESTONE
      SYSTEM SUPPLIER                             MITSUBISHI  HEAVY INDUSTRIES
      NEW/RETROFIT                                RETROFIT
      ENERGY CONSUMPTION - X                      ....«•.
      INITIAL START-UP DATE                       5/?o
      COMMERCIAL START-UP DATE                    7/79
      502  DESIGN RErOVAL EFFICIENCY - X              85.CO
      PARTICULATE DESIGN REMOVAL   EFFICIENCY - X   ........
      ABSORBER SPAR? COMPONENTS INDEX                  .0

  •* PYPRODUCT
      BYPRODUCT NATURE                             GYPSUM
      DISPOSITION



....—.......—....—-—-—.--—	PERFORMANCE DATA	
PERIOD MODULE  AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  » REMOVAL   PE»  BOILER  FGO    CAP""
                                                                  S02  PART. HOURS HOURS  HOURS  FACTOR
 7/79

 8/79

 9/79
13/79

11/79

12/79
 1/80

 3/80
 SYSTEM

 SYSTEM

 SYSTEM
100.0

100.0

100.0
ioe.0

10C.O

10C.O
100.0

10".0

100.0
 5*.8

100.0

100.0
  744

  744

  72C
408

744

720
408

744

720
       •• PROBLEMS/SOLUTIONS/COMMENTS
                          COMMERCIAL  OPERATIONS  BEGAN IN THE MIDDLE OF JULY 1979.  THE FGD UNIT HAt
                          OPERATED  CONTINUOUSLY  THROUGH THE THIRD QUARTER WITH NO PROBLEMS.
SYSTEM

SYSTEM

SYSTEM
100.r
100.0
 93.5
10C.C

10C.O

 93.5
100.0

1CO.O

 93.5
10P.O

100.0

 93.5
 744

 720

 744
744

72C

744
744

720

696
       .. PROBLEMS/SOLUTIONS/COMMENTS
                         THE FGD UNIT OPERATED  CONTINUOUSLY  THROUGH  THE  FOURTH QUARTER EXCEPT Foe
                         2 DAY SHUTDOWN TO  INSPECT  THi  GAS-GAS  HEATER  DURING DECEMBER.  THE BOILFB
                         WAS OPERATED FIRING  A  LOW  SULFUR  OIL  DURING  THE TWO DAYS.
STSTEH

SYSTEM
100.0

 55.2
100.0

1CO.C
100.0

 55.2
100.0

 55.2
 744

6960
744

384
744

384
                                                188

-------
                                               EPA UTILITY FGO SURVEY: JANUARY  -  MARCH 1980

CHUGOKU ELECTRIC: SHIMONOSEKI  i  (CONT.)
__.....——	—	PERF ORMANCE DATA	—	
PERIOD MODULE AVAILABILITY OPERABH1TY  RELIABILITY UTILIZATION  X  REMOVAL    PER   BOILER  FGO   CAP.
                                                                  S02   PART.  HOURS  HOURS  HOURS FACTOR


        ** PROBLEMS/SOLUTIONS/COMMENTS

                          DURING  JANUARY AND THE FIRST HALF Of  FEBRUARY  THE  FGD UNIT OPERATED UITH
                          NO  PROBLEMS.   THE UNIT WAS TAKEN OFF-LINE  IN THE MIDDLE  OF FEBRUARY FOR
                          SCHEDULED MAINTENANCE.
                                                   189

-------
 EPA  UTILITY  FGO  SURVEY:  JANUARY  -  MARCH  1980
                                            SECTION 15
                 DESIGN  AND  PERFORMANCE  DATA FOR  OPERATIONAL FOREIGN FGC SYSTEMS
 COMPANY NAME
 PLANT  NAME
 UNIT NUMBER
 CITY
 STATE
 G»OSS  UNIT GENERATING  CAPACITY  -  MW
 NET UNIT GENERATING CAPACITY  W/FGD -  MW
 EQUIVALENT SCRUBBED CAPACITY  -  I»W

 •*  FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE AJH CONTENT - *
     AVERAGE MOISTURE CONTENT  -  *
     AVERAGE SULFUR CONTENT -  %
     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
     502 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE COMPONENTS INDEX

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

 *• BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
ELECTRIC POWER DEVELOPMENT CO.
ISOGO
1
YOKOHAMA
JAPAN
  265.0
  23?.0
  265.0
COAL
******
 25958.
   16.CO
    7.00
      .60
WET SCRUBBING
LIMESTONE
IHI - CHEMICO
RETROFIT
»  11160 BTU/LP)
12/75
 3/76
   90.00
   96.70
     .0
OPEN
   22.3
GYPSUM
MARKETED
               <  354 GPI»>
	.	.	__	PERFORMANCE  DATA —	 —	
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY  UTILIZATION  *  REMOVAL    PER   BOILER   FGO    CAP"*
                                                                S02   PART.  HOURS  HOURS   HOURS  FACTOR
 4/73  SYSTEM


 5/7*  SYSTEM


 6/78  SYSTEM


 7/78  SYSTEM


 8/78  SYSTEM


 9/7P  SYSTEM


13/78  SYSTEM

11/7S  SYSTEM


12/78  SYSTEM


 1/79  SYSTEM


 2/79  SYSTEM


 3/79  SYSTEM
                             7?0

                             Tit,

                             720

                             744

                             744

                             7?0

                             744

                             720

                             744

                             744

                             672

                             744
                                               190

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                                                EPA  UTILITY FGD SURVEY:  JANUARY - MARCH  198T

ELECTRIC  POWER DEVELOPMENT  CO.:  ISOGO 1 
	—	PERFORMANCE DATA	—
PERIOD  MODULE AVAILABILITY  OPERABIL1TY RELIABILITY  UTILIZATION  T  REMOVAL   P£«  BOILER   FGD   C»P.
                                                                   SO?   PART. HOURS HOURS   HOURS FACTOR


        **  PR08LEMS/SOLUT10NS/COM*ENTS

                           100X  AVAILABILITY WAS  REPORTED FOR THE PE"IOD FROM 'P"IL  1978  THROUGH
                           MARCH 1979.
                                                   191

-------
 EPA UTILITY FGB SURVEY! JANUARY - MARCH 1980
                                            SECTION  15
                 DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  FOREIGN  FGD  SYSTFMS
  COMPANY NAME
  PLANT NAME
  UNIT NUMBER
  CITY
  STATE
  GROSS UNIT GENERATING CAPACITY - MM
  NET  UNIT GENERATING CAPACITY W/FGD - My
  EQUIVALENT SCRUBBED CAPACITY - MW

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

  ••  FGD  SYSTEM
      GENERAL PROCESS TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION  - X
      INITIAL STAPT-UP  DATE
      COMMERCIAL START-UP DATE
      SO?  DESIGN »E"OVAL  EFFICIENCY - *
      PARTICULATE DFSIGN  REMOVAL  EFFICIENCY
      ABSORBER SPARF  COMPONENTS  INDEX

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

  •* BYPRODUCT
      BYPRODUCT NATURE
      DISPOSITION
 ELECTRIC  POWER  DEVELOPMENT  CO.
 ISOGO
 2
 YOKOHAMA
 JAPAN
   265.0
   238.0
   265.0
 COAL

  25956.
    16.00
    7.00
      .60
MET SCRUBBING
LIMESTONE
IHI - CHEMICO
RETROFIT
    3.0
 3/76
 5/76
   9C.OO
   96.70
     .0
OPEN
GYPSUM
MARKETED
1116C BTU/LB)
                  354 GPM>
                                                       DATA—	.	.___
PE»IOD MODULE AVAILABILITY OPERABUITY  RELIABILITY  UTILIZATION   *  REMOVAL    PEP  BOILER  F6D   C»P

                                                                 SO?   PART.  HOURS  HOURS   HOURS FACTOR
4/78
5/78
6/7«
7/78
8/78
9/78
10/78
11/78
12/78
1/79
2/79
3/79
STSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
72C
7*4
720
744
744
720
744
720
744
744
6?2
744
                                               192

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                                               EPA  UTILITY FGO SURVEY:  JANUARY  - MARCH 19gr

ELECTRIC POWER  DEVELOPMENT CO.: ISOGO 2  
-------
 EPA UTILITY FGD SURVEY: JANUARY  -  MARCH  198C
                                             SECTION 15
                 DESIGN AND PERFORMANCE  DATA  FOP OPERATIONAL FOREIGN FGD SYSTEMS
 COMPANY  NAME
 PLANT  N»ME
 JNIT NUMB ER
 C ITY
 STATE
 GROSS  UNIT GENERATING  CAPACITY - Mb
 NET UNIT  GENERATING  CAPACITY W/FGD - My
 EQUIVALENT SCRUPBED  CAPACITY - MW

 **  FUEL  DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE HEAT  CONTENT  - J/G
    AVERAGE ASM CONTENT  - *
    AVERAGE MOISTURE CONTENT - »
    AVERAGE SULFUR CONTENT - X
    AVERAGE CHLORIDE CONTENT - 5!

 •*  FGO SYSTEM
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM SUPPUFR
    NEW/RETROFIT
    ENERGY CONSUMPTION -  I
    INITIAL START-UP DATE
    COMMERCIAL START-UP DATE
    S02 DESIGN REMOVAL EFFICIENCY  - t
    PARTICULATE DESIGN REMOVAL  EFFICIENCY  - X
    ABSORBER SPARE COMPONENTS  INDEX

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

•• BYPRODUCT
    BYPRODUCT NATURE
    DISPOSITION
                                                  ELECTRIC POWER DEVELOPMENT CO,
                                                  TAICASAGO
                                                  1
                                                  TAKASA60
                                                  JAPAN


                                                    23".C
                                                    25C.O
COAL

 25958.
   il.OO
    7.00
    1.80
                                                 WET  SCRUBBING
                                                 LIM ESTONE
                                                 HITSUI  - CHEMICO
                                                 RETBOFIT
                                                      3.2
                                                  2/75
                                                 * * / * *
                                                     97.OC
                                                                 (  1116C PTU/LR)
                                                      .0
                                                 OPEN
                                                    1J.1
                                                 GYPSUM
                                                                    ?OP
	.	.	PERFORMANCE DATA	_
PERIOD MODULE AVAILABILITY  OPERAB1LITY  RELIABILITY UTILI7ATION  * REMOVAL   PEP  BOILER   FGD    CAp"~
                                                                 $02  PART. HOURS HOURS   HOURS  FACTOR
W7R
5/7P
6/7R
7/7S
8/78
9/78
n/7«
11/7^
MI7P
1 /7Q
2/7
-------
                                              EPA UT1LJTK FGD SORVEK: JANUARY - MARCH  198?

ELECTRIC POWER DEVELOPMENT  CO.:  TAKASAGO  1  (CONT.)
.	—	—PE» FORWANCE DATA	—	
PERIOD MODULE AVAILABILITY  OPERABIL1TY  RELIABILITY  UTILIZATION  * REMOVAL   PE'  BOILER   FGO    C»P.
                                                                 SO?  PACT. HOURS HOURS   HOURS  FACTOR


       *• PROBIE»S/SOLUTIONS/COM*IENTS

                          DURING  APRIL  1978 THROUGH MARCH 1Q7Q NO FORCED OUTAGES OCCURRED.  THE FCD
                          SYSTEM  »V*ILABU1T> WAS 99.9j.
                                                 195

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 EPA UTUITY F&D SURVEY: JANUARY - MARCH 198C
                                            SECTION 15

                 DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
  COMPANY NAME
  PLANT NAME
  UNIT NUMBER
  CUT
  STATE
  GROSS UNIT GENERATING  CAPACITY  - My
  NET  UNIT  GENERATING  CAPACITY M/FGO  - KM
  EQUIVALENT SCRUBBED  CAPACITY -  «W

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

  •*  F6D  SYSTEM
      GENERAL PROCESS  TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      NEK/RETROFIT
      ENERGY CONSUMPTION -  t
      INITIAL START-UP DATE
      COMMERCIAL START-UP DATE
      S02 DESIGN REMOVAL EFFICIENCY -  X
      PARTKULATE DESIGN REMOVAL  FFF1CIENCY
      ABSORBER SPARE COMPONENTS INDEX

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

  •* BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
 ELECTRIC  POWER  DEVELOPMENT  CO.
 TAKASAGO
 2
 TAKASAGO
 JA«>AN

   2SC.O
   230.0
   250.0
 COAL


  25956.
    22.00
    7.00
    1.80
 ********
WET SCRUBBING
LIMESTONE
MITSUI - CHEM1CO
RETROFIT
    3.2
 3/76
**/ **
   93.00
<  11160  BTU/LB)
     .0
OPEN
   13.1
GYPSUM
  ?08 GPM>
....—.......	...	—	.....-_.._pERfORMANCE DATA — -	......	
PERIOD MODULE AVAILABILITY OPERARILITY RELIABILITY UTILIZATION  x REMOVAL   PEP  BOILER  FGO   CAP""

                                                                     P»RT. HOURS HOURS  HOURS FACTOR
*/7?
5/78
6/7S
7/78
8/78
9/78
13/78
11/78
12/78
1/79
2/79
3/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
720
744
744
720
744
720
744
744
6^2
744
                                               196

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                                              EPA UTILITY FGO SURVEY: JANUARY  -  MARCH 1980

ELECTRIC POWER DEVELOPMENT  CO.:  TAKASA60 2 
-------
 EPA UTILITY  FGD  SUSVEY:  JANUARY - MARCH  1980
                                              SECTION  15
                 DESIGN  AMD  PERFORMANCE DATA  FOR  OPERATIONAL fOREIGN FGD SYSTEMS
  COMPANY NAME
  PLANT NAME
  UNIT NUMBER
  CITY
  STATE
  GROSS UNIT GENERATING  CAPACITY  - Mw
  NET UNIT GENERATING CAPACITY  W/FGD - *y
  EQUIVALENT SCRUBBED CAPACITY  -  MW

  •* FUEL DATA
      FUEL TYPE
      FUEL GRAOF
      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
      S02  DESIGN REMOVAL EFFICIENCY  - X
      PARTICULATE DESIGN REMOVAL  EFFICIENCY
      ABSORBER  SPARE COMPONENTS INDEX

  •*  WATER  LOOP
      TYPE
      FRESH  MAKE-UP WATER - LITER/S
- X
      ELECTRIC  POWER DEVELOPMENT CO.
      TAKEHARA
      1
      M1HARA
      JAPAN
        25T.O
        231.0
        25D.O
COAL
MITSUI MINING
 2513Q.
   23.00
    9.05
    ?.DO
     .05
WET SCRUBBING
LIMESTONE
BABCOCK - HITACHI
RETROFIT
    3.2
 2/77
 2/79
   94.20
   91.70
     .0
     OPEN
        14.1
                             BTU/LB)
                                                                        GPW)
 •• BYPRODUCT
     BYPRODUCT  NATURE
     DISPOSITION
     GYPSUM
     MARKETED
	.	.—	..	.	- — PERFORMANCE DATA —	——	..«	
PERIOD MODULE  AVAllABUITY OPERABILITY RELIABILITY  UTILIZATION  t REMOVAL   PER   BOILER   F6D   CAP
                                                                  SO?  PART. HOURS  HOURS   HOURS FACTOR
4/78
5/78
6/78
7/78
8/78
9/78
10/78
11/78
12/78
1/70
2/79
5/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
7?0
744
744
720
744
720
744
744
672
744
                                                198

-------
                                               EPA  UTILITY FGD SURVEY: JANUARY  -  MARCH 198?

ELECTRIC POWER DEVELOPMENT  CO.: TAKEHARA 1  (CONT.)
	-PERFORMANCE  DATA	
PERIOD MODULE  AVAILABILITY  OPERABILITY RELIABILITY  UTILIZATION  X RE«OV»|_    PE"   BOILER  FGD    C»P«
                                                                  SO?   PART.  HOURS HOURS  HOURS  FACTOR



       *« PROBLfclS/SOLUTlONS/COMWENTS

                          99.95X AVAILABILITY  WAS REPORTED FOR THE PERIOD  FROI" APRIL 1978 THROUGH
                          MARCH 1979.
                                                  199

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                         APPENDIX A




FGD SYSTEM COST DATA:  OPERATIONAL AND NONOPERATIONAL SYSTEMS
                             A-l

-------
                           INTRODUCTION

      The cost of flue gas desulfurization (FGD)  systems for the
 control of sulfur dioxide emissions is an area of intense inter-
 est and substantial controversy.   As a result,  many computer
 models  have recently been developed to estimate capital and
 annual  costs.   As part of an  effort by the U.S.  Environmental
 Protection Agency to provide  meaningful economic data  concerning
 FGD systems,  reported economic  data have been  incorporated into
 the EPA Utility FGD Survey report.   This information has  appeared
 as  a separate  appendix of the report since October  1976.   Until
 January 1978,  this  cost appendix consisted entirely of  data
 reported by  the utilities with  little or no interpretation pro-
 vided by PEDCo Environmental, Inc.   Beginning with  the  May 197g
 report,  the  format  and content  of  the cost appendix were  revised
 to  include reported and adjusted costs  for the  operational FGD
 systems.
     The rationale  for  including adjusted  as well as reported
 costs stems primarily  from the  lack  of  comparability of the
 reported costs.  Many  of  the  reported cost figures,  both  capital
 and  operating,  are  largely site-sensitive  values that cannot be
 accurately compared  because they refer  to  different FGD battery
 limits  and different years in which  the  expenditures were made.
As a result, an  analysis  of the cost  data was made  for the opera-
 tional  units since  these  systems offer  the potential of having
 complete and accurate  economic data.  The  adjustments were made
 to provide comparable,  accurate cost  data  for the sulfur dioxide
portion of the  emission control system.  This,  in effect, will
eliminate much of the confusion that exists concerning the re-
ported data, and it will provide a common basis for the reported
costs.

                               A-2

-------
     In an attempt to promote further comparability of the
figures, the adjustment procedure was carried one step further
and standardized adjusted figures were developed.  This was done
by modifying the fixed annual cost rates such that they would be
identical for each unit (i.e. cost of depreciation, interim re-
placement, taxes, insurance and capital costs).  The newly ad-
justed total fixed annual cost rate was applied to the total ad-
justed capital cost in each case and a standardized adjusted
annual cost was obtained.
                                A-3

-------
                            APPROACH


     In March 1978, each utility having at  least one operational
FGD system was given a cost form containing all available cost

information then in the PEDCo files.  The utility was asked to

verify the data and fill in any missing information called for

on the form.  A follow-up visit by the PEDCo Environmental staff

was arranged to assist in data acquisition and to insure com-

pleteness and reliability of information.  Results of the cost

analysis were forwarded to each participating utility for final

review and comment.

     The cost data were treated solely to establish the accurate

costs for FGD systems, on a common basis, not to critique the

design or reasonableness of the costs reported by any utility.

Adjustments focused primarily on the following items:

     0    All capital costs were adjusted to July 1, 1977, dol-
          lars using the Chemical Engineering Index.  All capital
          costs,  represented in dollars/kilowatt ($/kW), were
          expressed in terms of gross megawatts (MW).  Actual
          costs were reported by utilities in dollar values for
          years 1970 to 1980.   These values are represented in
          terms of the year of greatest capital expenditures.

     0     Gross unit capacity was used to express all FGD capital
          expenditures because the capital requirement of an FGD
          system is dependent on actual boiler size before de-
          rating for auxiliary and air quality control power
          requirements.

     0     Particulate control costs were deducted.   Since the
          purpose of the study was to estimate the incremental
          cost for sulfur dioxide control, particulate control
          costs were deducted using either data contained in the
          cost breakdowns or as a percentage of the total direct
          cost (capital  and annual).   The percentage reduction
          varied  depending upon system design and operation.
                               A-4

-------
The capital costs associated with the modification or
installation of equipment not part of the FGD system
but needed for its proper functioning, were included
(e.g. - stack lining, modification to existing ductwork
or fans, etc.).

Indirect charges were adjusted to provide adequate
funds for engineering, field expenses, legal expenses,
insurance, interest during construction, allowance for
startup, taxes, and contingency.

All annual costs, represented in mills/kilowatt-hour
(mills/kWh), were expressed in terms of net megawatts
(MW) .

Net unit capacity was used to express all FGD annual
expenditures because the annual cost requirement  of an
FGD  system is dependent on the actual amount of kilo-
watt-hours  (kWh) produced by the unit after derating
for  auxiliary and air quality control power require-
ments.

All  annual costs were adjusted to a common capacity
factor  (65%).

Replacement  power costs were not included  since only  a
few  utilities reported such costs and these were  pre-
sented  using a variety of methods.

Sludge  disposal  costs were adjusted to  reflect  the
costs of  sulfur  dioxide waste disposal  only  (i.e.,
excluding  fly ash disposal) and  to provide  for  disposal
over the  anticipated lifetime of the  FGD  system.   This
latter  correction was necessary  since several utilities
reported  costs  for  sludge disposal capacity  that  would
last only  a  fraction of  the FGD  system  life.  The
adjustments  were based on a  land cost of  $2000/acre
with a  sludge depth of 50 ft  in  a clay-lined  pond (clay
is assumed to be available  at the site).

A 30-year life was  assumed  for  all process and  economic
considerations  for  all new  systems  that were installed
for the life of the unit.   A 20-year  life was assumed
for all process and economic  considerations for retro-
                      A-5

-------
          fit systems that were installed for the remaining por-
          tion of the life of the unit.*

     0    Regeneration and by-product recovery facility costs
          were added for those regenerable systems not reporting
          such costs.

     To the extent possible, all cost adjustments were made using

the previous assumptions developed by PEDCo Environmental.  When

cost data were inadequate, adjustments were made using process

design data in conjunction with the previous cost assumptions.

In some cases, no adjustments were possible because of in-

sufficient data.
   The  use  of a 30-year  service  life  for new units  coincides  with
   the  conclusion  of  the National  Power  Survey of the  Federal
   Power  Commission which recognized  this value as  reasonable for
   steam-electric  plants.   A 20-year  service life was  assumed for
   all  retrofit units even if the  remaining  life of the  units is
   less than this  value.   Thus,  two different rates are  used  and
   should be noted when  making comparisons between  new and retro-
   fit  systems.

                              A-6

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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:
     0    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

-------
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

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          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.

°    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 fe city,  county,  state,  or  Federal  government.

           Interest on borrowed funds.

 °     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

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                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:
  Contingency3

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

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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

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                   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

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                       TABLE A-3.   DESCRIPTION OF  COST
 Code
                 Title
           Description
 B

 c
L


M



N


0
      Farticulate 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,  ia
 included in total capital cost.

 One or a number of indirect  cost items
 or the cost associated with  one or a  '
 number of indirect cost  items,  are ex-
 cluded from the total capital cost.

 The cost of a chemical fixation process
 which stabilizes the flue gas cleaning
 wastes prior to disposal is  included in
 the total capital cost.

 The cost of a secondary  dewatering or
 treatment method,  such as filtration can
 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 ia
 included  in the total  capital cost.

 The cost  of  an  on-site disposal area for
 ponding of  treated or  untreated fiue 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 th«
 total capital cost.

Modifications to existing equipment  (stack
 fans, ducts, etc.) which are required be-
cause of  inclusion of an FGD system.

Complete cost of entire regeneration
 facility included in total capital cost.

Part of the cost associated with the re,
generation facility included in the tot.i
capital cost.                       «»*»!

Bench scale or pilot plant studies to de
termine process and design characteristics
 (continued)
                                    A-16

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                           TABLE A-3.   (continued)
Code
 M


 X
                      Title
      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.
                                                     Description
Capital expenditures underwritten by the
system supplier for system repairs or
modifications for optimization of perfor-
mance or R t D programs.
Capital expenditures for reagent supply
exceeds the amount required for the period
of initial operation.
Complete cost of all raw materials,
utilities, operating labor and maintenance
and repairs is included in the total
annual cost.
One or a number of direct annual cost items,
or the cost associated with one or a number
of direct annual cost items, are excluded
from the total annual cost.

Complete cost of all fixed cost elements,
including depreciation, interim replace-
ment,  insurance, taxes, and interest, is
included in the total annual cost.
One or a number of  fixed annual cost items,
or the cost associated  with one or  a
number of  fixed annual  cost items,  are  ex-
cluded from the total annual cost.
Plant  and  payroll  overhead costs  are in-
cluded in  the  total annual cost.
The  cost  of operating particulate collection
equipment  included in the FGD  system is in-
cluded in  the  total annual cost.

The  treatment  and disposal of  flue gas
 cleaning wastes that are  handled by an
outside  firm.

The  cost of additional  power-generating
 capacity required to compensate for power
 used by the FGD system.
                                          A-17

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                    RESULTS OF COST ANALYSIS

     The results of the operational FGD system survey are summarized
in Table A-4 and Section A-l.  Table A-4 produces a summary of a
categorical analysis of the reported and adjusted capital and
annual costs for the operational FGD systems addressed in the
survey.  Included in this categorical analysis are the ranges,
means, and standard deviation for all the various types and
categories of FGD systems examined.  Section A-l summarizes the
reported and adjusted capital and annual costs for all the oper-
ational FGD systems that were addressed in the cost study
(Section A-2 summarizes available cost data for nonoperational
FGD systems).
                              A-l 8

-------
              TABLE A-4.    CATEGORICAL RESULTS  OF  THE  REPORTED  AND  ADJUSTED
                    CAPITAL  AND  ANNUAL  COSTS  FOR OPERATIONAL  FGD  SYSTEMS
 CATEGORY
   	—	REPORTED		
   ---CAPITAL, I/KU--	ANNUAL, NILLS/KUH---
   RANGE     AV6   DEV      RANGE     AVG   DEV
 		ADJUSTED		
 	CAPITAL, »/KU	  —-ANNUAL, HILLS/KUH—
    RANGE     AVG   DEV      RANGE     AVG   DEV
 ALL

 MEU

 RETROFIT

 THROMAUAY PRODUCT

 SALEAILE PRODUCT

 LIMESTONE

 LINE

 •UAL  ALKALI

 LINE/ALKALINE rITASH

 SOIIUN CARIONATE

 UELLNAN LORI

 LIMESTONE/ALKALINE FLYASH

HA6NE5IUN OXIDE
  2V.2-189.0  80.9  40.2     .1-  14.9   4.4   4.4

  31.B-IB9.0  80.4  39.6     .1-  14.3   3.3   3.9

  29.2-154.9  82.0  4t.3    2.0-  14.9   4.1   4.5

  29.2-189.0  75.6  37.2     .1-  14.3   4.2   4.1

 127.9-156.9 142.3  14.5    2.0-  14.9   8.4   6.5

  31.8-168.0  74.0  37.9    1.3-  3.3   2.1    .6

  29.2-128.3  74.9  32.2     .1-  14.3   4.9   4.8

  43.2-189.0  96.7  65.5    3.2-  3.2   3.2    .0

 77.1- 85.9  80.0   4.1      .3-   .3   .3    .0

 42.9-120.0  79.8  37.0     2.1-  2.1    2.1    .0

127.9-154.9 137.6  13.7   14.9- 14.9  14.9    .0

 47.9- 47.9  47.9    .0    2.0-  2.0    2.0    .0

156.7-154.7 156.7    .0    2.0-  2.0    2.0    .0
  56.0-233.2  93.2  35.4    2.6-  13.0   5.7   2.7

  66.4-117.6  86.1  17.8    2.8-  8.7   5.2   2.0

  56.0-233.2 100.2  45.8    2.6-  13.0   6.1   3.2

  56.0-140.6  86.2  21.9    2.6-  8.7   5.1   2.0

 134.8-233.2 184.0  49.2   12.4- tl.O  12.7    .3

  56.0-117.6  88.6  25.5    2.6-  6.6   4.6   1.6

  47.5-140.6  90.8  22.2    2.7-  8.7   6.4   2.0

 **«**-   .0   .0    .0 »•**•-   .0   .0    .0

  77.2- 93.0  82.5  7.4    4.1-  5.2   4.5    .5

 60.9-107.9  76.6  22.2    3.2-  4.4   3.6    .6

 134.8-134.8 134.8    .0  12.4- 12.4  12.4    .0

 71.2-  71.2  71.2    .0    2.8-  2.8   2.8    .0

233.2-233.2 233.2    .0  13.0- 13.0  13.0    .0

-------
 EPA  UTILITY FGD SURVEY: JANUARY - PARCH  198C
                                             SECTION A-1
                                 COSTS  FO"  OPERATIONAL FGD SYSTEMS

JNIT DESCRIPTION
ALABAMA ELECTRIC COOP

179.0 MW (NET)

COST DtSCPIPTION
CAPACITY FACTOR, X

COST ELFMFNTS

PEPO&TFD
* * *

C,F,J

ADJUSTED
65



STANDARDIZED
ADJUSTED
65


 ALLEGHENY  POWER SYSTEM
 PLEASANTS
 1
  519.0  MW  (NET)
CAPACITY FACTOR, X                65
TOTAL CAPITAL, J/KU(YEAR>        1?8.Z
TOTAL ANNUAL, KILLS / KWH(YEAR )      2.8(197?)
COST ELEMFNTS                   B,C,J,S
                                                                               65
                                                        C)
                                                        C)
                                                             65
                                                           ******(
              r)
 ARIZONA  ELECTRIC POWER COOP
 APACHE
 2
  195.3  MW (NET)
 CAPACITY  FACTOR,  X
 TOTAL  CAPITAL,  t/KW(YEAR)
 TOTAL  ANNUAL,  MI LLS / KWH ( Y E AR )
 COST ELEMENTS
                                  44            65
                                  35.9(1977)  **««**(
                                   2.1(1978)  ******(
                                C ,F ,H,J,L,S,
                                U.W.Y.Z
      65
C)  ***«»»(
0)  *.....(
•:•)
")
 ARIZONA  ELECTRIC POWER COOP
 APACHE
 3
  195.0  MW  (NET)
 CAPACITY  FACTOR,  X
 TOTAL  CAPITAL,  J/KUCYEAR)
 TOTAL  ANNUAL,  MI LLS / KWH < Y EA R )
 COST ELEMENTS
                                  44
                                  71 .8( 1977)
                                   2.1(1978)
                                C,E,H,J,L,S,
                                U.W.Y.Z
                                                                               65
     65
0)  *»»**•(
G)  *«*..*<
 ARIZONA  PUBLIC  SFRVICt
 CHOLLA
 1
  119.0  MW  (NET)
CAPACITY  FACTOR,  X
TOTAL CAPITAL,  I/KW(YEAR)
TOTAL ANNUAL,  « I LLS / K WH ( Y E A R )
COST ELEMENTS
                                 »5            65            65
                                 52.0(1973)    56.0(1977)   56.0(1977)
                                   2.2(1976)     2.6(1977)    2.3(1977)
                               P,C,E,S,U,X   C,£,K,S,U,b  C,E,K,S,U,W
ARIZONA PUBLIC SERVICE
CHOLLA
2
350.0 MW (NET)
BIG RIVERS ELECTRIC
GREEN
1
242.0 MW (NET)
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
378.0 MW (NET)
CENTRAL ILLINOIS PUBLIC SERV
•ifcWTON
1
617. J MW (NET)
CAPACITY FACTOR, X 65 65

COST ELEMENTS B,D,T,X
CAPACITY FACTOR, X *** 65

COST ELEMENTS B,C
CAPACITY FACTOR, X *** 65

COST ELEMENTS C,F,J,K
CAPACITY FACTOR, X ••* 65

COST ELEMENTS C,F,G
65
C) »**•««( r )
C) *«•«•*< :,
65
C) ******( pj
65
C) *••«*•< r)

65

COLORADO UTE ELtCTRIC  ASSN.
CRAIG
2
 447.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
                                ***           65
                                 73.7(1979) «***.*(
                                •*.*•(   0) *****•(
     65
0) **»***(   QJ
0) ******(   Q)
                                   INDICATES COST FIGURES NOT YET AVAILABLE
                                             *-  2

-------
                                             EPA UTILITY fGD  SURVEY:  JANUARY  - MARCH 1980
                                           SECTION A-1
                                COSTS F0» OPERATIONAL  FGD  SYSTFMS
     DESCRIPTION
                               COST DESCRIPTION
                                	COST	
                                 REPORTED     ADJUSTED   STANDARDIZED
                                                           ADJUSTED
COLUMBUS & SOUTHERN OHIO ELEC.
CONESVILLE
5
411.0 MW (NET)

COLUI«BUS 8 SOUTHERN OHIO ELEC.
CONESVI LLE
6
411.0 MW (NET)

OUOUESNE LIGHT
ELlAltA
1-*
510.0 MW (NET)

DJQUESNE LIGHT
PHILLIPS
1-6
410.0 MW (NET)

CAPACITY FACTOR, x
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, I* I LLS / KWH ( Y E A R )
COST ELEMENTS

CAPACITY FACTOR, X
TO T A 1 f A D T T A 1 t^VUfVCAOt
1 U 1 ff (B IMrJIHLf '/RWlltAnJ
T fl T A 1 AUhllAI MTII C4tfLJIjfVCAD>
1 U 1 P L AnnUALt rilLLj/KWnlTtAHJ
COST ELEMENTS

CAPACITY FACTOR, X
TOTAL CAPITAL, J/KW(YEAR)
TOTAL ANNUAL, MI LLS / KWH ( Y E AR )
COST ELEMENTS

CAPACITY FACTOR, X
TOTAL CAPITAL, I/KW(YFAR)
TOTAL ANNUAL, MI LLS / KWH( Y E AR )
COST ELEMENTS

48
55.5(1975)
5.8(1978)
B,C,J,M,S,U,
W.X.Y
48
cc C / 1 Q 7 Q \
3 3 • j t iv/ej
Sfl / 1 O ? fl \
.Ol 1 " f C /
B,C,JI,M,S,U,
W.X.Y
64
113.4(1976)
8.6(1977)
B.D.F.l.J.M,
T.V.X.Y
7C
1"6. 9(1972)
7.8(1977)
B.D.F.J.J.f".
T.V.X.V
65
7f5. 7(1977)
7.4(1977)
C.E.J.M.S.U,
W,Y
65
7^ 7f4f>77\
''• f \ I V t I t
******( C)
C,E,J ,M,S ,U,
W,Y
65
127.1(1977)
7.8(1977)
C.E.I.J ,M,S ,
U,Y
65
141.6(1977)
8.6(1977)
C,E,1,J,M,S ,
U,Y
65
70.7(1977)
7.4(1977)
C.E.J.M.S.U,
W,Y
65




65
127.1(1977)
7.5(1977)
C.E.I ,J ,I",S,
U,Y
65
140.6(1977)
8.2(1977)
C, E,I ,J ,*,S,
U,Y
INDIANAPOLIS  POtfER  8  LIGHT
PETERSPURG
3
 532.0  MW  (NET)
CAPACITY FACTOR, X              ***
TOTAL CAPITAL, J/KW(YEAR)        99.5(1976)
TOTAL ANNUAL, MILLS/KWH(YEAR)  ***.**{    C)
COST ELEMENTS                  C,F,G,J,M
                                               65            65
                                              110.6(1977)   110.6(1977)
                                                6.6(1977)     7.4(1977)
                                             C,E,G,J,M,S,  C,E,G,J ,l", S,
                                             U,W,Y         U,W,Y
KANSAS  CITY  POWER  R  LIGHT
HAWTHORN

  90.0  MW  (NET)
CAPACITY FACTOR, X                14
TOTAL CAPITAL, J/KW(YEAR)         29.12(1972)
TOTAL ANNUAL, MILLS/KWH(YEAR)     8.4(1977)
COST ELEMENTS                  B,D,F,T,X
                                               65           65
                                               87.2(1977)   87.2(1977)
                                                4.3(1977)    4.4(1977)
                                             B, C.E.J, K,S, B,C,E ,J ,K ,S,
                                             U.W.X
                                                                                          U,W,X
KANSAS  CITY  POWER  8 LIGHT
HAWTHORN
4
  90.0  MW  (NET)
CAPACITY FACTOR, X               **»
TOTAL CAPITAL. f/KW(YEAR)         29.i2(1972)
TOTAL ANNUAL, MILLS/KWH(YEAR)      8.4(1977)
COST ELEMENTS                   B.D.F^T.X
                                               65           65
                                               87.2(1977)   87.2(1977)
                                                4.3(1977)    4.4(1977)
                                             B.C.E.J.K.S. B.C.E.J.K.S,
                                             U.W.X        U.W.X
KANSAS  CITY  POWER « LIGHT
tA  CYGNE

 874. 0  MW (NET)
CAPACITY FACTOR, X               42
TOTAL CAPITAL, S/KW(YEAR)        53.6(1972)
TOTAL ANNUAL. MILLS/KWH(YEAR)      1.3(1978)
COST ELEMENTS                   T
                                               65
                                               68.0(1977)
                                                3.8(1977)
                                                            65
                                                            68.0(1977)
                                                             3.9(1977)
                                                          C,E.J,K,S,U
 KANSAS POWER 8 LIGHT
 JEFFREY
 1
  540.0 MW (NET)
 CAPACITY  FACTOR,  X
 TOTAL  CAPITAL,  S/KW(YEAR)
 TOTAL  ANNUAL,  MI LLS/ KWH ( YE AR )
 COST  ELEMENTS
                                 ***            65
                                  56.8(1978) ***«**(
                                *-*****.{ 1978) •*****(
                                B.C
                                                             65
                                                           ***•*.<
                                                           ******(
0)
0)
 KENTUCKY UTILITIES
 6REEN RIVER
 1-3
   64.0 MW (NET)
 CAPACITY  FACTOR, X
 TOTAL  CAPITAL, S/KW(YEAR)
 TOTAL  ANNUAL. MI 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.W  C.E.J.S.U.W
                                w
                           ******    INDICATES COST FIGURES NOT VET AVAILABLE

                                              »-  21

-------
 EPA  UTILITY FGO SURVEY: JANUARY - MARCH  198C
                                             SFCT10N A-1
                                  COSTS  FOP  OPERATIONAL FGD SYSTEMS

UNIT DESCRIPTION COST DESCRIPTION

REPORTED ADJUSTED STANDARDIZED
ADJUSTED
 LOUISVILLE  GAS ft ELECTRIC
 CANE  RUN
 1>
  1P6.Q MW (NET)
 CAPACITY  FACTOR,  X
 TOTAL  CAPITAL,  1/KW(Y?AR)
 TOTAL  ANNUAL,  * ILLSIKWH(Y£AR)
 COST  ELEMENTS
   55            65           65
   66.5(1575)    6?.6(1977)   SG.6(1C77)
    2.7<1977>     5.8(1977)    6.2(1577)
 C,F,H,J,Q,T  C,E,H,JtK,0, C,E,HtJ,K,0,
              S,U,W         S.U.U
LOUI
CANE

203

SVILLE GAS & ELECTRIC
RUN

.n


MW (NET)

LOUISVILLE G«S & ELECTRIC

299

LOUI
3
442

.0

MW (NET)

SVILLE GAS & ELECTRIC

.0
MW (NET)
LOUISVILLE GAS t, ELECTRIC
PADDY'S RUN
6
72

.0

MW (N?T)
>UNNKOTA POWER COOPERATIVE
11LTON R. YOUNG
2
405


.0


MW (NET)

CAPAC
TOTAL
TOTAL
COST

ITY FACTOR, X
CAPITAL, $/KW( YEAR)
ANNUAL .
ELEMENTS




CAPACITY FACTOR, 3!

COST


ELEMENTS




CAPACITY FACTOR, I
TOTAL
COST
CAPAC
TOTAL
TOTAL
COST
CAPAC
TOTAL
TOTAL
COST

ANNUAL ,
ELEMENTS
MLLS/KWH(YEAP)

ITY FACTOR, X
CAPITAL, 5/KW ( YEAR )
ANNUAL ,
ELEMENTS


ITY FACTOR, X
CAPITAL, $/KW(YEAR)
ANNUAL ,
ELEMENTS




***

TfF


,HrJ

* * *
c 7 Q / 1 Q 77 %

C,E
W
.M^M.S.V,

1C
/ 2 A f 1 Q 7F )
1.3(1°78)
c,s

* * *
52.8(1973)

C,E


** *
95.9(1976)

C.f


,H,P

65
67. 5(1977)


u,w
65



65



65
76.4 (1977)

C,£,S,U,W
65
93.0(1977)

C .E.H.M.p.S ,
U.W
65
67.
5.

U.W
65



65
* * * * *

65
76.
6.
C.E.S
65
93.
5.
C.E.H
U.W
5(
6(







*(

4(
1977)
1°77)
K ^


r )
}


C )

1977)
4(T977)
.U
C(
2 (
.n

.W
1977)
1"77)
• P.S.

MONTANA POWER
COLSTRIP
1
 360.0 MW  (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
  76            65            65
  77.1(1975)    77.2(1977)    77.2(1977)
    .3(1977)     4.1(1977)     4.1(1977)
B,C,E,J,P,T   C,E,J,K,P,S,  C,E,J,K,P,s,
              U.W           U,W
MONTANA POWER
COLSTRIP
2
 360.0 MW (NET)
CAPACITY FACTOR, X                76
TOTAL CAPITAL, S/KH(YEAR)         77.1(1975)
TOTAL ANNUAL, MILLS/KWH(YEAR )       .3(1977)
COST ELEMENTS                   B,C,Ei,J,P,T
                65            65
                77.2(1977)    77.2(1977)
                 4.1(1977)     4.1(1977)
              C,E,J,K,P,S,  C,E,J,K,p,s,
              U.W           U.W
NEVADA POWER
REID GARDNER
1
 125.0 MH (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KU(VEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR )
COST ELEMENTS
  67           65            65
  42.9(1973)   60.9(1977)    60.9(1977)
   2.X1P77)    3.2(1977)     3.4(1977)
B,0,E#P,S,U, B.D.E.P.S.U,  B.D.E.P.S.U,
W,X          W,X           w,X
NEVADA POWER
REID GARDNER
2
 125.0 My (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, I/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
  67           65            65
  42.9(1973)   60.9(1977)    60.9(1977)
   2.t(1977)    3.2(1977)     3.4(1977)
B,0,E,P,S,U, B,0,E,P,S,U,  B.D.E.P.S.U,
w.x          u.x           w,x
                          ******    INDICATES COST FIGURES NOT YET AVAILABLE

                                             A-  22

-------
                                             EPA UTILITY  FGO  SURVEY:  JANUARY - MARCH
                                           SECTION  A-1
                                COSTS FOR OPERATIONAL  FGO  SYSTEMS

jNJT DESCRIPTION
NEVADA POWER
REID GARDNER
125.0 MW  FACTOR, X
TOTAL CAPITAL, S/KW(»EAR)
TOTAL ANNUAL, M I LLS / KWH ( Y E AR )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, f/KW(YEAR)
TOTAL ANNUAL, P. I LLS / KWH < Y EA R )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS /KWH (Y EA R )
COST ELEMENTS
CAPACITY FACTOR, X

COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MI LLS / KWH (Y EAR )
COST ELEMENTS

REPORTED
67
113.6(1975)
2.1(1977)
B,C,?.,L,S,U,
u,x
77
156. 9( 1«76)
U. 9(1976)
P.C.E ,'L,N,S,
u,w,xrz
'3
47.9(1972)
2.0(1977)
B.C, JyS.U.X,
Z
'3
47.9(1972)
2.0(1977)
B,C,J,S,U,X,
Z
** *

C,E,J
40
120.6(1975)
14.3(1977)
B.C.E ,G,I ,L,
s.u.w.x

ADJUSTED
65
107.9(1977)
4.4(1977)
B,C,E,L,S,U,
w,x
65
134.8(1977)
12.4(1977)
C.E.L.N.S ,U,
HtZ
65
71 .2(1977)
2.8(1977)
C,E,J,K,S,U,
W
65
71 .2(1977)
2.8(1977)
C.E.J.K ,S ,U,
W
65


65
102.1(1977)
?. 7(1977)
C,E,G,I,M,S,
U.W

STANDARDIZED
ADJUSTED
65
107.9(1977)
5.0(1977)
B.C.E, L.S.U,
W,X
65
134.8(1977)
11.0(1^77)
C,E,L,N,5,U,
W,Z
65
71. 2( 1977)
3.3(1977)
C,E,J,K,S,U,
U
65
71.211977)
3.3(1977)
C,E,J,K,S,U,
W
65


65
102.1(1977)
10.8(1977)
C.E,G,I.P,S,
U.W
PENNSYLVANIA  POwER
3RUCE MANSFIELD
2
 917.0  MW  (NET)
                                CAPACITY  FACTOR, X
                                TOTAL  CAPITAL, J/KW(YEAR)
                                TOTAL  ANNUAL, MI LLS/KWH(YEAR)
                                COST ELEMENTS
                                 40            65            65
                                 1?C.6(1975)   102.1(1977>  102.1(1977)
                                 14.3(1977)     ?.7(1977)   10.8(1977)
                               B,C,E,G,I,L,  C,E,G,I,M,S, C,E,6,1,W,S,
                               s,u,wrx       u,w          u.w
PHILADELPHIA  ELECTRIC
EDDYSTONE
1A
 120.0  MW  (NET)
CAPACITY FACTOR, X               ***            65
TOTAL CAPITAL, $/KW(YEAR)        156.7(1972)   233.2(1977)
TOTAL ANNUAL, MILLS/KWh(YEAR)      2.0(1972)    13.0(1977)
COST ELEMENTS                   0,F,N',P      C.E.N.P
                                                                                            65
                                                                                           233.2(1977)
                                                                                            12.4(1977)
                                                                                           C.E.N.P
PUBLIC SERVICE  OF  NEW  MEXICO
SAN JUAN
1
 361 .0 MU  (NET)
                                CAPACITY FACTOR,  X
                                TOTAL CAPITAL, $/KW(YEAR)
                                TOTAL ANNUAL, MI LLS /KWH (Y EAR )
                                COST ELEMENTS
                                                                 **«            65
                                                                 1?7. 9(1977) «*«***(
                                                                *.*...<   C) ••**..<
                                                                ».C,E ,N
                                                        C)
   *«,„»«(
   *•***.<
                                                                     0)
 PUBLIC  SERVICE OF NEW MEXICO
 SAN  JUAN
 2
  350.0  MW (NET>
                                CAPACITY FACTOR,  X
                                TOTAL CAPITAL, J/KW(YEAR)
                                TOTAL ANNUAL, MI LLS /KWH 
-------
 EP» UTILITY F&D SURVEY: JANUARY  -  MARCH 1980
                                             SECTION A-1
                                  COSTS  FOR  OPERATIONAL FGO SYSTEMS
 U*IT DESCRIPTION
                                 COST  DESCRIPTION
                                                                  REPORTED
                                               ---COST--
                                                ADJUSTED
                                                                                           STANDARDIZED
                                                                                             ADJUSTED
 SALT RIVER PROJECT
 CORONADO
 1
  280.0 MW (NET)
 CAPACITY  FACTOR. X              ***            65            65
 TOTAL  CAPITAL, */KW(YEAl>        '4.Q(197fi)  ***•*«(    0)  *.....(
 TOTAL  ANNUAL, MILLS/KWH(YFAR)  »*****(    C)  *»****(    C)  *****»(
 COST  ELEMENTS                  C,F
                                     C)
                                     f )
 SOUTH CAROLINA PUBLIC SERVICE   CAPACITY  FACTOR,  X               80            65            65
 JINYAH                          TOTAL  CAPITAL, $>KW(YEAR)        47.4(1976)    66.4(1977)    66.4(1977)
 2                               TOTAL  ANNUAL,  MlLLS/KUH(YEAR)     1.6(1975)     ?.9(1977)     3.2(1977)
  14Q.O MH (NET)                 COST ELEMENTS                   C,F,J,M,S,V   C,E,J,K,N,S,  C,E,J,K,K,S,
                                                                              U,W           U,W
 SOUTH MISSISSIPPI ELEC PWR
 R.D. MORROW
 1
  124.0 MW (NET)
 CAPACITY  FACTOR,  X              ***
 TOTAL  CAPITAL,  $/KW(YEAR>        37.4(1975)
 TOTAL  ANNUAL, MILLS/KWH(YEAR)  *•*•**(   C)
 COST ELEMENTS                   C,E
                                                                                65
                             65
 SOUTH MISSISSIPPI ELEC PHR
 R.D.  MORROW
 2
  124.0 MU (NET)
CAPACITY  FACTOR,  X               «**           65            65
TOTAL  CAPITAL,  J/KW(YEAR)        37.4(1975) ••****(    C)  ***«»•(
TOTAL  ANNUAL, MILLS/KWH(YEAR)  **«***(   0> **•***(    Q>  ***•••{
COST ELEMENTS                   C,E
                                     C)
 SOUTHERN ILLINOIS POWER COOP   CAPACITY  FACTOR,  X                65           65            65
 MARION                         TOTAL CAPITAL,  */KW(YEAR)        152.7(1978) *»***•(   0)  **•*•*(    P)
 4                               TOTAL ANNUAL, MILLS/KUH
COST ELEHENTS
  "0           65            65
  85.9(1978) *«•*.*(   cj **«...(    r)
   1.4(1978) **•*..(   C) ****..(    Q)
                          *««...   INDICATES COST  FIGURES  NOT  YET  AVAILABLE
                                             A-   24

-------
                                              tPA UTILITY  FGD  SURVEY: JANUARY - MARCH 1980
                                            SECTION  A-2
                               COSTS FOR NON-OPERATIONAL  FGD  SYSTEMS
tfMJT DESCRIPTION
                                COST DESCRIPTION
                                                                  REPORTED
                                                                              -—COST—-
                                                                               ADJUSTED
                                                                                          STANDARDIZED
                                                                                            ADJUSTED
BASIN ELECTRIC POWER COOP
         RIVER
        MW KW(YEAR)        82.5(1972)  ••*•**<    0) **«•*•(   C)
                                 TOTAL ANNUAL, MILLS/KWH(YEAR)  ******<    C)  ******(    C) *«**•*<   0)
                                 COST ELEMENTS                  A.C.E.M.N
 POTOMAC ELECTRIC POWER
 0JCKERSON

      .0 MW (NET)
                                                                                45
CAPACITY FACTOR, X               ***
TOTAL CAPITAL, $/KW(YEAR)        68.QO978)  **.*„.(
TOTAL ANNUAL, MI LLS /KWH< Y EAR )   •*****<    0)
COST ELEMENTS                   A,C,E,M
                                                        0)
                                                        Q)
                                                                                              .,
                                                                                                       )
 PUBLIC  SERVICE  OF  COLORADO
 tfALMONT

 *166.0  MW (NET)
                                                                                 .,
                                  CAPACITY FACTOR, X              .
                                  TOTAL CAPITAL, S/KH(YEAR)        87.0(1974) ******<   0) **•**•(   D
                                  TOTAL ANNUAL, MI LLS/KWH( YEAR )   *»****(    Q) **••••<   0) *****•(   0)
                                  COST ELEMENTS                   B ,C
                            ******   INDICATES COST FIGURES  NOT  YET AVAILABLE

                                               *-  25

-------
EPA UTILITY FGD  SURVEY:  JANUARY - MARCH 1980
                                            SECTION  A-2
                               COSTS FOR NON-OPERATIONAL FGD SYSTFHS
                                                                	COST	
UNIT DESCRIPTION                COST DESCRIPTION                  REPORTED     ADJUSTED    STANDARDI2ED
                                                                                             ADJUSTED

SALT RIVER PROJECT              CAPACITY FACTOSt  X               ***           65            65
CORONADO                        TOTAL CAPITALt J/KW(YEAR>         74.0(1978) ******(    g)  ******(    rj)
Z                               TOTAL ANNUALt MILLS/KWH(YEAR)   *****»(   0) **•***(    C>  ******(    C)
 280.0 HW (NET)                 COST ELEMENTS                   C,E
                                  INDICATES  COST  FIGURES NOT VET 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 SO2
removed from the flue gas by
the FGD system.
                             B-2

-------
FGD Viability Indexes
     Availability Index
      Reliability Index
Several parameters have been
developed to quantify the vi-
ability of FGD system technol-
ogy.  Various terms such as
"availability," "reliability,"
"operability," and "utiliza-
tion" are used to accurately
represent the operation of any
FGD system during a given per-
iod.  The above-mentioned pa-
rameters are defined below and
discussed briefly.  The objec-
tives of this discussion are
to make the reader aware that
several different definitions
are being used and to select
appropriate parameters that
can be used for reporting pur-
poses so that reasonably con-
sistent comparisons can be
made.

Hours the FGD system is avail-
able for operation  (whether
operated or not) divided by
hours in period, expressed  as
a percentage.  This parameter
tends to overestimate  the vi-
ability of  the FGD  system be-
cause it does not penalize  for
election not  to  operate  the
system when it could have been
operated.   Boiler downtime  may
tend to  increase the magnitude
of  the parameter because  FGD
failures  generally  cannot oc-
cur during  such  periods.

Hours  the  FGD system was oper-
ated divided by  the hours the
FGD system was called  upon to
operate,  expressed as  a per-
centage.   This parameter has
been developed in order not to
penalize the FGD system for
 elected outages, e.g., periods
when the FGD system could have
 been run but was not run be-
 cause of chemical shortages,
 lack of manpower, short dura-
 tion boiler operations, etc.
 The main problem in using this
                               B-3

-------
     FGD Operability Index
     FGD Utilization Index
End Product
     Saleable
formula is the concise determi-
nation whether or not the sys-
tem was "called upon to oper-
ate" during a given time per-
iod.  In addition, an undefined
value can result when the FGD
system is not called upon to
operate for a given period
(e.g., turbine or boiler out-
age when FGD system is avail-
able) .

Hours the FGD system was oper-
ated divided by boiler operat-
ing hours in period, expressed
as a percentage.  This param-
eter indicates the degree to
which the FGD system is actu-
ally used, relative to boiler
operating time.  The parameter
is penalized when options are
exercised not to use the FGD
system in periods when the
system is operable.  In addi-
tion, an undefined value can
result when the FGD system is
not called upon to operate for
a given period (e.g., turbine
or boiler outage when FGD sys-
tem is available).

Hours that the FGD system op-
erated divided by total hours
in period.  This parameter is
a relative stress factor for
the FGD system.  It is not a
complete measure of FGD system
viability because the parameter
can be strongly influenced by
conditions that are external
to the FGD system (e.g., in-
frequent boiler operation will
lower the value of the parame-
ter although the FGD system
may be highly dependable in
its particular application).
The S02 removed from the flue
gas is recovered in a usable
or marketable form (e.g., sul-
fur, sulfuric acid, gypsum,
                              B-4

-------
                                   ammonium sulfate,  sodium sul-
                                   fate).
     Throwaway
Energy Consumption, %
Equivalent Scrubbed Capacity
   (ESC)
FGD Status:
     Category 1
     Category 2
     Category 3
     Cateogry 4
     Category 5
The SC-2 removed from the flue
gas is not recovered in a us-
able or marketable form and
resulting sulfur-bearing waste
products must be disposed in
an environmentally acceptable
fashion.

The percentage of gross unit
electrical generating capacity
consumed by the FGD system, as
defined by the following equa-
tion:

[Net MW w/o FGD - Net MW w/FGD]/
Gross unit rating]
The effective scrubbed flue
gas in equivalent MW based on
the percent of flue gas  scrubbed
by the FGD system.
Operational - FGD  system  is  in
service removing SC>2.

Under construction - ground
has been broken for installa-
tion of FGD system,  but FGD
system has not become  opera-
tional.

Planned, Contract  Awarded -
contract has been  signed  for
purchase of FGD system but
ground has not been broken for
installation.

Planned, Letter of Intent
Signed - letter of intent has
been signed, but  legal con-
tract  for purchase has not
been awarded.

Planned, Requesting/Evaluating
Bids - bid  requests have  been
released but  no letter of in-
tent or  contract  has been is-
sued.
                              B-5

-------
     Category 6



     Category 7


     Category 8
Fuel Firing Rate - TPH
General Process Type
Initial Start-Up (FGD System)
New
Plant Name
Process Additives
Considering only FGD Systems -
an FGD system is proposed as a
means to meet an S02 regulation,

Considering an FGD system as
well as alternative methods.

Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended in-
definite period of time.

Boiler fuel firing rate in
terms of tons per hour at max-
imum continuous load.

The manner in which the SC>2
from the flue gas is collected,
e.g., wet scrubbing, spray
drying, dry adsorption.

Date when flue gas first
passes through any component
of the FGD system (or is
scheduled to do so).

FGD unit and boiler were de-
signed at the same time or
space for addition of an FGD
unit was reserved when boiler
was constructed.

Unit identification as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities/ McGraw-Hill - Current
Edition - or as indicated by
utility representative for in-
stallations in planning stages.

A chemical compound or element
which is added to the process
or normally found with the
main process reagent in small
quantities (e.g., Mg, adipic
acid) to promote improved
process operation (e.g., scale
reduction, increased SC>2
removal efficiency).
                              B-6

-------
Process Type
Regulatory Class
Retrofit
Spare Capacity Index - %
Spare Component Index
System Supplier
Total Controlled Capacity
  (TCC)
Company name if process is
patented.  Generic name if
several companies have similar
processes (e.g., Lime, Lime-
stone, Wellman Lord, Thorough-
bred 121) .

A.   New boiler constructed
     subject to Federal New
     Source Performance Stan-
     dards (NSPS), 8/17/71.

B.   Existing boiler subject
     to State Standard that is
     more stringent than the
     NSPS,  8/17/71.

C.   Existing boiler subject
     to State Standard that is
     equal to or less stringent
     than NSPS, 8/17/71.

D.   Other (unknown, undeter-
     mined) .

FGD unit will be/was added to
an existing boiler not specif-
ically designed to accommodate
FGD unit.

The summation of the individ-
ual component capacities  (%)
minus 100%.

The equipment spare capacity
index  (%) divided by the indi-
vidual component capacity  (%).

A firm that fabricates and
supplies flue gas desulfuriza-
tion systems.
The gross rating  (MW) of a
unit brought into compliance
with FGD, regardless of the
percent of flue gas treated at
the facility.  In the case of
prototype and demonstration
FGD systems, this figure will
be identical to the Equivalent
Scrubbed Capacity rather than
                              B-7

-------
Unit Rating
     Gross
     New w/FGD
     Net w/o FGD
                                   the gross unit rating if the
                                   system is not meant to bring
                                   the facility into compliance
                                   with S02 emission standards.
Operational - Maximum contin-
uous gross generation capacity
in MW; Preoperational - maxi-
mum continuous design genera-
tion capacity in MW.

Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
inclusive of emission control
systems.

Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
exclusive of emission control
systems.
                              B-8

-------
      APPENDIX C




TABLE OF UNIT NOTATION
          C-l

-------
                                TABLE OF UNIT NOTATION
Classification
Area

Concentration




Flow





Heat Content

Length


L/G Ratio


Mass/Weight

Pressure
Temperature
Volume

English Unit
Acre
Square foot
Grains per standard
cubic foot
Parts per million
Pounds per million
Btu
Actual cubic feet
per minute
Gallons per minute
Pounds per minute
Ton per day
Ton per hour
Btu per pound

Foot
Inch
Mile
Gallons per
thousand actual
cubic feet
Pound
Ton
Inches of water
Degree Fahrenheit
Cubic feet
Acre-feet
Symbol
acre
ft2
gr/scf

ppm ,
lb/10 Btu

ft /mm
(actual )
gal/min
Ib/min
t/day
t/h
Btu/lb

ft
in
mi
gal/1000
ft3
(actual )
Ib
t
in. H20
"F
ft3
Acre-f t
Survey Report
Nota t ion
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
Meqagram
Kilopascal
Degree Celsius
Cubic meter
Cubic meter
Symbol
M2
M2
g/m3

ppm
ng/J

m3/s

liter/s
kg/s
M t/d
M t/h
J/q

m
cm
km
liter/m


kg
Mg
kPa
°C
m
rn
Survey Report
Notation
SQ.M
SQ.M
G/CU.M

PPM
NG/J

CU.M/S

LITER/S
KG/S
M T/D
M T/H
J/G

M
CM
KM
LITER/CU.M


KG
MG
KPA
C
CU.M
CU.M
n
i
to

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                               TECHNICAL REPORT DATA
                         (Please read Inunctions on the reverse before completing)
 REPORT NO.
 PA-600/7-80-029b
                          2.
                                                     3. RECIPIENT'S ACCESSION NO.
 TITLE AND SUBTITLE
  PA Utility FGD Survey: January-March 1980
                                 . REPORT DATE
                                 May 1980
                                                     6. PERFORMING ORGANIZATION CODE
 AUTHOR(S)
M. Smith, M. Melia, and N.Gregory
                                                     8. PERFORMING ORGANIZATION REPORT NO.
                                 PN 3570-1-Z
 PERFORMING ORGANIZATION NAME AND ADDRESS
 PEDCo Environmental, Inc.
 .1499 Chester Road
Cincinnati, Ohio 45246
                                                     10. PROGRAM ELEMENT NO.
                                 INE828
                                 11. CONTRACT/GRANT NO.
                                 68-01-4147, Task 143
 2. SPONSORING AGENCY NAME AND ADDRESS
 EPA, Office of Research and Development
 Industrial Environmental Research Laboratory
 Research Triangle Park, NC  27711
                                 13. TYPE OF REPORT AND PERIOD COVERED
                                 Quarterly; 1-3/80
                                 14. SPONSORING AGENCY CODE
                                  EPA/600/13
 5.SUPPLEMENTARY NOTES jERL-RTP project officer is Norman Kaplan, Mail Drop 61, 919/
541-2556. The report supplements report EPA-600/7-80-029a.
 16. ABSTRACT
          The report is the first of three supplements updating the October-December
1979 report (EPA-600/7-80-029a) and should be used in conjunction with it. The
report, generated by a computerized data base system, presents a survey of oper-
ational and planned domestic utility flue gas desulfurization (FGD) systems, oper-
ational domestic particle scrubbers, and Japanese coal-fired utility boiler FGD
installations. It summarizes information contributed by the utility industry, process
suppliers, regulatory agencies,  and consulting engineering firms.  Domestic FGD
systems are tabulated alphabetically by development status (operational, under con-
struction, or in planning stages), utility company, process supplier, process, and
waste disposal practice.  It presents data on boiler design, FGD system design,
fuel characteristics , and actual performance. It includes unit by unit dependability
parameters and discusses problems and solutions associated with the boilers and
FGD systems. Process flow diagrams and FGD system economic data are appended.
 7.
                             KEY WORDS AND DOCUMENT ANALYSIS
                DESCRIPTORS
                     b.IDENTIFIERS/OPEN ENDED TERMS
                                                                  c. COSATi Field/Group
 Pollution
 Flue Gases
 Desulfurization
 Electric Utilities
 Waste Disposal
 Boilers
Maintenance
Pollution Control
Stationary Sources
Utility Boilers
13 B
2 IB
07A,07D

15E
13A
"\k. DISTRIBUTION STATEMENT

  Release to Public
                      19. SECURITY CLASS (ThisReport}
                      Unclassified
                        21. NO. OF PAGES

                           258
                      20. SECURITY CLASS (Thispage)
                      Unclassified
                                              22. PRICE
EPA Form 2220-t (9-73)
                                        C-3

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