PB83-168054
EPA (Environmental Protection Agency)
Utility FGD  (Flue Gas  Desulfurization) Survey
Volume I. Categorical  Summaries of FGD Systems
PEDCo-Enviromnental,  Inc.
Cincinnati, OH
Prepared for

Industrial Environmental Research Lab,
Research Triangle  Park,  NC
Sep 82
                   U.S. DEPARTMENT OF COMMERCE
                 National Technical Information Service
                                              -

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                                   EPA-600/7-82-05 8a
                                   September 1982
               EPA UTILITY FGD SURVEY
              OCTOBER - DECEMBER 1981

           VOLUME I.  CATEGORICAL SUMMARIES
                  OF FGD SYSTEMS
                         By

              Melia,  M.T. and N.G.  Bruck
             PEDCo  Environmental, Inc.
                 11499  Chester Road
           Cincinnati,  Ohio  45246-0100

              Contract No.  68-02-3173
                       Task  71
          EPA Project Officer:  N. Kaplan
   Industrial Environmental Research Laboratory
Office of Environmental Engineering and Technology
   Research Triangle  Park,  North Carolina   27711
                    Prepared for

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

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                                  TECHNICAL REPORT DATA
                           (Please rtad Inunctions on the reverse before completing)
i  REPORT NO.
EPA-600/7-82-058a
                            3.
  TITLE AND SUBTITLE
 EPA Utility FGD Survey: October-December 1981
 Volume I.   Categorical Summaries of FGD Systems
                                                         3 RECIPIENT'S ar.rpecin«»w«i
                      3   i 680?
             _
             5 REPORT OATE
             September 1982
             6. PERFORMING ORGANIZATION CODE
7 AUTHORIS)
 M.Melia and N.Brack
                                                         8 PERFORMING ORGANIZATION REPORT NO
9 PERFORMING ORGANIZATION NAME AND ADDRESS
 PEDCo Environmental, Inc.
 11499 Chester Road
 Cincinnati, Ohio  45246
                                                         10. PROGRAM ELEMENT NO
             11 CONTRACT/GRANT NO
             68-02-3173, Task 71
12 SPONSORING AGENCY NAME AND ADDRESS
 EPA, Office of Research and Development
 Industrial Environmental Research Laboratory
 Research Triangle Park, NC  27711
             13. TYPE OF REPORT AND PERIOD COVERED
             Quarterly; 10-12/81	
             14 SPONSORING AGENCY CODE
               EPA/600/13
is. SUPPLEMENTARY NOTES IERL-RTP project  officer is  Norman Kaplan, iMail Drop 61, 919/541-
 2556. Related reports are in the~EPA-600wC?-S&-029 -and -&lr-612. series.
16 ABSTRACT Th{i report is the first  full  compilation (not a supplement) since the
 October-December 1980 report  (EPA-600/7-81-012a and -12b).  Because the next three
 reports are to be supplements,  this  issue should be retained for reference throughout
 the year. The report, generated by a computerized data base system, presents a survey
 of operational and planned domestic  utility flue gas desulfurization (FGD) systems.
 It summarizes information contributed  by the utility industry, process suppliers,
 regulatory agencies, and consulting  engineering firms. Domestic FGD systems are tabu-
 lated alphabetically by development  status (operational, under construction, or in
 planning stages), utility company, process supplier, process, and waste disposal
 practice. It presents data on boiler design, FGD system design, fuel characteristics,
 and actual performance. Process flow diagrams and FGD system economic data are ap-
 pended. Section 3 of the report,  because of its length, appears in Volume II.
17.
                               KEY WORDS AND DOCUMENT ANALYSIS
                 DESCRIPTORS
                                            b.lDENTIFIERS/OPEN ENDED TERMS
                          c COSATi Held,Group
 Pollution
 Flue Gases
 Desulfurization
 Electric Utilities
 Waste  Disposal
 Boilers
 Maintenance
Pollution Control
Stationary Sources
Utility Boilers
I3B
21B
07A.07D

15E
13A
13 DISTRIBUTION STATEMENT
 Release to Public
                                             19 SECURITY CLASS (THu Report)
                                             Unclassified
                                                                       21 NO OF PAGES
                                       392
2O SECURITY CLASS fThtt pagt)
Unclassified
                          22 PRICE
EPA Form 2220-1 (9-731

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                             NOTICE


     This report  (prepared by PEDCo Environmental,  Inc.,  Cincin-
nati, Ohio under EPA Contract No.  68-02-3173,  Task  No.  71)  is
provided as an information transfer document.   Data in  this
report are supplied voluntarily by utility  representatives; flue
gas desulfurization (FGD) system  suppliers  and designers; regula-
tory agencies; and others.  Neither EPA  nor the designated con-
tractor warrants the accuracy or  completeness  of information
contained in this report.

     Distribution of a project summary will be made to  organiza-
tions and individuals indicating  a specific interest in the field
of FGD technology.  Those interested  can get on the mail list for
the project summary by contacting Norm Kaplan, Industrial Envi-
ronmental Research Laboratory, at 919/541-2556,  or  the  Emission
and Effluent Technology Branch secretary at 919/541-2578.  Copies
of the full report and preceding  issues  can be purchased from
National Technical Information Service,1  Springfield, Virginia,
22161.

     This report presents a summary of the  FGD system design and
performance data from a computerized  data based called, "Flue Gas.
Desulfurization Information System"  (FGDIS).  Access to the FGDIS
is available to the public  (subject to the  limitations  expressed
in the paragraph above) through the National Technical  Informa-
tion Service  (NTIS) for a non-profit  usage  charge.   Users have
the capability of accessing the additional  design and performance
data stored within the data base  that cannot be conveniently
printed in this report.  Direct access to the  data  base allows
statistical analyses of the data  (e.g.,  averages, maxima, minima,
and standard deviation of various parameters)  and tabulation of
the data to fit the individual informational needs  of the' user. .
Those interested should contact Walter Finch (NTIS) at 703/487-
4808.


          This document has been reviewed  in accordance with
          U.S. Environmental Protection Agency policy and
          approved for publication.  Mention of trade names
          or commercial products does not  constitute  endorse-
          ment or recommendation for use.
                                ii

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                       USE OF THIS REPORT


     This report is the first in a series of four issues.  The
succeeding three issues will be supplemental in nature.  This
report is the first full compilation since the October-December
1980 report (EPA-600/7-8L-012a&b).   Because the next three reports
are to be supplements, this issue should be retained for reference
throughout the year.  Much of the design and performance data
contained in this issue will not be published again until February
1983.-  Supplemental issues are cumulative in nature, so that it
is necessary only to retain the latest issue and this report to
have all the available information.

     This report contains a number of tables presenting tabula-
tions of some of the key data for S02 control systems on utility
boilers (e.g., categorical summaries by FGD system supplier, FGD
system status,, disposal practices, etc.).  Detailed design and
performance data for operational FGD systems (Section 3) appears
in Volume II of this report.  Design and performance data for
operational Japanese FGD systems and domestic particle scrubbers
are included in this report (Volume I); however, the information
was not updated during 1981.  A section is also included for
terminated FGD systems.  These are experimental or demonstration
FGD systems that were eventually shut down or FGD systems applied
to boilers that were later retired.  The Executive Summary con-
tains the number and capacity of FGD systems as of the end of
December 1981, future projections (December 1999) of controlled
and uncontrolled generating capacity, and unit by unit summaries
of status changes (e.g.,  contract awarded, under construction,
operational, etc.)  and performance (e.g., FGD system availability)
during the period.

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

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                            ABSTRACT


     This report, which is generated by a computerized data base
system, presents a survey of operational and planned domestic
utility flue gas desulfurization (FGD)  systems,  operational
domestic particle scrubbers, and Japanese coal-fired utility
boiler FGD installations.  It summarizes information contributed
by the utility industry, system and equipment suppliers, system
designers, research organizations,  and regulatory agencies.  It
presents data on system design, fuel characteristics, operating
history and actual performance.  Unit by unit dependability
parameters are included and problems and solutions associated
with the boilers, scrubbers, and FGD systems are discussed.

     The domestic FGD systems are tabulated alphabetically by
development status (operational, under construction, or in the
planning stages), utility company,  system supplier, process,
waste disposal practice, and regulatory class.  FGD system eco-
nomic data, definitions, and a glossary of terms are appended to
the report.  Current data for domestic FGD systems show 94 sys-
tems in operation, 40 systems under construction, and 88 planned
systems.  Projected 1999 FGD controlled capacity in the U.S. is
107,351 MW.
                              iv

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

Section 1      Summary List of FGD  Systems

Section 2      Status of FGD Systems

Section 3      Design and Performance  Data  for  Operational
                FGD Systems

               Alabama Electric
                 Tombigbee 2
                 Tombigbee 3
               Arizona Electric Power
                 Apache 2
                 Apache 3
               Arizona Public Service
                 Cholla 1
                 Cholla 2
                 Cholla 4
                 Four Corners 1
                 Four Corners 2
                 Four Corners 3
               Basin Electric Power
                 Laramie River 1
                 Laramie River 2
               Big Rivers Electric
                 Green 1
                 Green 2
               Central Illinois Light
                 Duck Creek 1
               Central Illinois Public Service
                 Newton 1
               Cincinnati Gas & Electric
                 East Bend 2
               Colorado Ute Electric
                 Craig 1
                 Craig 2

*Section 3, pages 47-851, appear In Volume II.
Pace

  ii
 iii
  iv
  xi
 xii

   1

   9


  47*
  47*-
  56*

  63*
  73*

  81*
  99*
 105*
 108*
 112*
 116*

 120*
 127*

 131*
 138*

 143*

 159*

 167*

 171*
 178*

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Merom 2                                      284*

Petersburg 3                                 287*
                    CONTENTS  (continued)

                                                          Page

             Columbus  &  Southern Ohio Electric
               Conesville 5                                187*
               Conesville 6                                200*
             Commonwealth Edison
               Powerton  51                                 210*
             Cooperative Power
               Coal  Creek 1                                215*
               Coal  Creek 2                                222*
             Delmarva  Power & Light
               Delaware  City  1                             227*
               Delaware  City  2                             233*
               Delaware  City  3                             239*
             Duquesne  Light
               Elrama  1-4                                  245*
               Phillips  1-6                                261*
             Hoosier Energy
               Merom 2
             Indianapolis Power & Light
               Petersburg 3
             Kansas  City Power & Light
               Hawthorn  3                                  296*
               Hawthorn  4                                  307*
               LaCygne 1                                   319*
             Kansas  Power & Light
               Jeffrey 1                                   342*
               Jeffrey 2                                   349*
               Lawrence  4                                  354*
               Lawrence  5                                  366*
             Kentucky  utilities
               Green River 1-3                             377*
             Louisville  Gas & Electric
               Cane  Run  4                                  387*
               Cane  Run  5                                  397*
               Cane  Run  6                                  406*
               Mill  Creek 1                                413*
               Mill  Creek 2                                418*
               Mill  Creek 3                                422*
               Paddy's Run 6                                430*
             Minnesota Power  & Light
               Clay  Boswell 4                              442*
             Minnkota  Power
               Milton  R. Young 2                           449*
             Monongahela Power
               Pleasants 1                                 463*
               Pleasants 2                                 469*
             Montana Power
               Colstrip 1                                  474*
               Colstrip 2                                  482*

*Section 3, pages 47-851,  appear In Volume II.
                             vi

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                   CONTENTS  (continued)

                                                          Pace

            Montana-Dakota Utilities
              Coyote 1                                     490*
            Nevada Power
              Reid Gardner 1                               493*
              Reid Gardner 2                               509*
              Reid Gardner 3                               528*
            Northern Indiana  Public Service
              Dean H. Mitchell  11                          543*
            Northern States Power
              Riverside 6-7                                555*
              Sherburne 1                                  560*
              Sherburne 2                                  578*
            Pacific Power & Light
              Jim Bridger 4                                592*
            Pennsylvania Power
              Bruce Mansfield 1                           598*
              Bruce Mansfield 2                           612*
              Bruce Mansfield 3                           621*
            Public Service Company of  New Mexico
              San Juan 1                                   626*
              San Juan 2                                   637*
              San Juan 3                                   649*
            Salt River Project
              Coronado 1                                   656*
              Coronado 2                                   662*
            San Miguel Electric
              San Miguel 1                                 667*
            Sikeston Board of Municipal  Utilities
              Sikeston 1                                   671*
            South Carolina Public Service Authority
              Winyah 2                                     675*
              Winyah 3                                     684*
              Winyah 4                                     690*
            South Mississippi Electric
              R.D. Morrow, Sr.  1                           693*
              R.D. Morrow, Sr.  2                           702*
            Southern Illinois Power Coop
              Marion 4                                     71°*
            Southern Indiana  Gas & Electric
              A.B. Brown 1                                 719*
            Springfield City  Utilities
              Southwest 1                                  729
            Springfield Water,  Light  & Power
              Dallman 3                                    74S
            St. Joe Zinc
              G.F. Weaton 1                                753*
*Sectlon 3, pages 47-851, appear in Volume II.

                             vii

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Section 4

Section 5

Section 6

Section 7


Section 8


Section 9

Section 10

Section 11

Section 12

Section 13


Section 14
        CONTENTS (continued)

                                             Page

Tennessee Valley Authority
  Shawnee 10A                                  760*
  Shawnee 10B                                  763*
  Widows Creek 7                               732*
  Widows Creek 8                               786*
Texas Power & Light
  Sandow 4                                     801*
Texas Utilities
  Martin Lake 1                                805*
  Martin Lake 2                                813*
  Martin Lake 3                                820*
  Monticello 3                                 826*
Utah Power & Light
  Hunter 1                                     833*
  Hunter 2                                     838*
  Huntington 1                                 842*
  Naughton 3                                   849*

Summary of FGD Systems by Company              852

Summary of FGD Systems by System Supplier      854

Summary of FGD Systems by Process              856

Summary of Operating FGD Systems by
 Process and Unit                              857

Summary of End-Product Disposal
 Practices for Operational  FGD Systems         860

Summary of FGD Systems in Operation            862

Summary of FGD Systems Under Construction      867

Summary of Contract Awarded FGD Systems       869

Summary of Planned FGD Systems                 870

Total FGD Units and Capacity  (MW)
 Installed by Year                             874

Design and Performance Data for
 Operational Particle Scrubbers                875

Commonwealth Edison
  Will County 1                                875
•Section 3, pages 47-851, appear in Volume II.
                                Vila.

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                       CONTENTS (continued)
Section 15
Section 16
Detroit Edison
  St. Clair 6
Minnesota Power and Light
  Clay Boswell 3
  Syl Laskin 1
  Syl Laskin 2
Montana-Dakota Utilities
  Lewis & Clark 1
Pacific Power and Light
  Dave Johnston 4
Potomac Electric Power
  Dickerson 1
  Dickerson 2
  Dickerson 3
Public Service of Colorado
  Arapahoe 4
  Cherokee- 1
  Cherokee 4
  Valmont 5
Southwestern Public Service
  Harrington 1

Design and Performance Data for
 Operational Foreign FGD Systems

Chugoku Electric
  Shimonoseki 1
Electric Power Development Company
  Isogo 1
  Isogo 2
  Takasago 1
  Takasago 2
  Takehara 1
Hokkaido Electric Power
  Tomakomai Thermal

Design and Performance Data for
 Discontinued Domestic FGD Systems

Arizona Public Service
  Four Corners 5A
Boston Edison
  Mystic 6
Commonwealth Edison
  Will County 1A
Dairyland Power Coop
  Alma 5
Pace


 901

 910
 913
 917

 921

 925

 928
 931
 934

 941
 945
 948
 951

 958


 962


 962

 967
 973
 979
 987
 994

 999
                                                            1002

                                                            1006

                                                            1010

                                                            1014
                               ix

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                       CONTENTS (continued)
Appendix A
Appendix B

Appendix C

Appendix D
Detroit Edison
  St. Clair 6A
Gulf Power
  Scholz 1
  Scholz 1A
  Scholz IB, 2B
  Scholz 1, 2
  Scholz 2A
Illinois Power Company
  Wood River 4
Key West Utility Board
  Stock Island 1
Philadelphia Electric
  Eddystone 1A
Potomac Electric Power
  Dickerson 3A
Public Service of Colorado
  Valmont 5A
Southern California Edison
  Mohave 1A
  Mohave 2A
Tennessee Valley Authority
  Shawnee IOC
Union Electric
  Meremac 2

FGD System Cost Data:  Operational
 and Nonoperational Systems

Introduction
Results of the Cost Analysis
Adjustment Procedure and Background
Costs for Operational FGD Systems
Costs for Nonoperational FGD Systems

Definitions

Table of Unit Notation

FGD Process Flow Diagrams
Page


1017

1021
1025
1030
1035
1039

1043

1047

1051

1060

1063

1066
1069

1072

1075


 A-l

 A-2
 A-6
 A-9
 A-21
 A-33

 B-l

 C-l

 D-l

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                             TABLES


No.                                                         Pace

I         Number and Total Capacity of FGD Systems           xii

II        Summary, of Changes, October-December 1981          xiv

III       Performance of Operational Units,
           October-December 1981                              xv



                             FIGURE


No.                                                         Page

 1        Computerized Data Base Structure Diagram          xiii
                               xi

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

     Table  1 summarizes the status  of  FGD systems  in  the United
States at the  end of December 1981.  Table 2 lists the units
that have changed status during the fourth quarter 1981, and Table
3 shows the performance of operating units during  this period.
            TABLE  1.  NUMBER AND TOTAL CAPACITY OF FGD SYSTEMS
Status
Operational
Under construction
Planned:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only FGD
systems
TOTAL
No. of
units
94
40
17
10
10
51
222
Total
controlled
capacity, MW*
35,931
17,386
10,035
7,643
5,630
30,726
107,351
Equivalent
scrubbed A
capacity, MW'
32,683
16,666
9,819
7,585
5,630
30,398
102,781
  The summation of the gross unit capacities  (MW) brought into compliance
  with FGD systems regardless of the percent  of the flue gas scrubbed  by the
  FGD system(s).
  The summation of the effective scrubbed flue gas in equivalent MW based
  on the percent of flue gas scrubbed by the  FGD system(s).
                                xii

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X
H-
1 1
TUJlxnl
Iftao)


Diinui
IJJOOI
                                 Figure 1.  Computerized data base structure diagram.

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                            TABLE 2.   SUMMARY OF CHANGES  OCTOBER -  DECEMBER  1981
FGO status report
September 3171481
East Kentucky Power
J.K. Smith 1
Louisville Gas I Electric
HI 11 Creek 2
Hoosler Energy
Hero* 2
Total
Opej
3?-

»i
»i
94
it tonal
3,792"

350
441
32.683
Ui
cons
8-

-1
-1
40
ider
ruction
MM*
17.457

350
441
16.666
Contract
awarded
No.
16
*l


17
W
9.169
650


9.819
it
of
ft"
-1


10
tter
ntent
MM*
8.235
650


7.585
Requesting/
eval. bids
No.
10



10
MM*
5.630



5.630
Const
f
no.
51



51
tiering
60 .
nr
30.398



30.398
Ti
no.
222



222
tal ,
"•" k
102.781°



102.781
        Equivalent scrubbed capacity.
        This value was •odlfled slightly due'to • KM correction.
'-ontinued

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                                   TABLE 3.  PERFORMANCE OF OPERATIONAL UNITS
                                                 OCTOBER-DECEMBER 1981
Plant
Alabana Electric
Toablgbee 2
ToBhlgbee 3
Arizona electric
Power
Apache Z
Apache 3
Arizona Public
Service
Choi la 1
Choi la 2
Choi la 4
Four Corners 1
Four Corners 2
Four Comers 3
Basin Electric Power
La rani e Rl*er 1
la ramie River t
Big Rivers Electric
Green 1
Green 2
Central Illinois Light
Duck Creek 1
Central Illinois Public
Service
Newton 1
Cincinnati Gas I
Electric
East Bend 2
Colorado Ute Electric
Craig 1
Craig 2
Colunbus 1 Southern
Ohio Electric
Conesvllle 5
Coneirllle 6
FGD systea
capacity.
ma

179
i;g


98
98


119
?64
126
I7S
I7S
229

570
570

242
242

416


617


650
410
410


411
411
Flue gas
I scrubbed

70
70


50
SO


100
100
3)
100
100
100

100
100

100
100

100


100


100
90
90


100
100
FGD
capacity
on line
during
period
hV.°

179
179


98
98









570
570

242
242

416


617


650
410
410


411
411
No Information
for this
period. MM*









119
264
126
175
175
229




















Shut down
throughout
P^od.



































October 1981
Dependability Ic>e
AVI

17
97


100
96









100
100

75
76

0


100



14
100


100
ion
OCR

52
SB


100
98










96

98
96




0



14
99


0
0
RCL

52
SB


100
96










100

98
96




0



14
99


0
0
UTL

9
57


42
96









0
95

75
73

0


0



14
99


0
0
Hovenber 1981
Dependability Ic>(
AVI

41
99


65
100









100
100
-
96
63

31


98



80
21


27
27
OPR

79
76


64
100









61
98

95
87

79


69



BO
47


0
0
RCL

79
76


65
89









100
100

95
87

91


85



80
52


0
0
UTl

36
59


64
89









59
98

9S
45

26


69



80
21


0
0
Decc-twr 1981 , .
Dependability tc>e
A»L

100
96













100
100

99
100

80


100



84
69


84
Bf»
OPR

54
57













78
93

98
98

82


es



84
69


8?
R3
Rtl

54
52













100
too

97
98

83


100



84
70


86
93
UTL

54
52













78
75

98
87

69


82



84
68


n
66
X
      (continued)

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TABLE 3 (continued)
Plant
Comnwealth Edison
Powerlon SI
Cooperative Power
Association
Coal Creek 1
Coal Creek 2
Delaarva Power 1 light
Delaware City 1
Delaware City 2
Delaware City 3
Duquesne Light
El rani 1-4
Phillips 1-6
Hoosler Energy
Heron 2
Indianapolis Power
1 Light
Petersburg 3
Kansas City Power
1 Light
Hawthorn 3
Hawthorn 4
La Cygne 1
Kansas Power 1 Light
Jeffrey 1
Jeffrey 2
Lawrence 4
Lawrence 5
Kentucky Utilities
Green River 1-3
Louisville Gas 1
Electric
Cane Run 4
Cane Run S
Cane Run 6
Hill Creek 1
HIM Creek 2
Hill Creek 3
Paddy's Run 6
Minnesota Power 1 Light
Clay Botwell 4
F6D sy steal
capacity.
HU»

4SO


321
327
60
60
60

510
408

441


532


to
90
874

540
490
125
420

64


188
200
299
3S8
350
427
72

47S
Flue gas
S scrubbed

100


60
60
100
100
100

100
100

90


too


100
100
100

75
70
100
100

100


100
100
100
100
100
too
100

85
FCO
capacity
on line
during
period
Hua.b

450


327
327
60
60
60

510
408

441







874

540
490
125
420




188
200

358
350
427


475
Ito Information
for this .
period. MT
















532


90
90



















Shut down
throughout
period,
MM'




























64




299



72


October 1981 , .
Dependability Ic'e
AVL






30
100
78

95
85









51






100


65
91
100
40

41
100

100
OPR




54
76
57
100
86

77
59









98









93
ion

41

90


95
REL






71
100
86

94
83









98









93
100

41

90


100
UTL

0


15
76
23
100
78

77
59









35






0


65
58
0
40

41
0

95
Noveaber 1981 .
Dependability Ic'e
AVL






70
89
42

100
74









94






100


99
89
100
37

32
100

94
OPR




57
67
70
69
69

77
41









100









100
100

40

37


96
REL






70
89
89

100
72









92









100
100

40

37


100
UTL




47
67
70
89
42

77
41









72






0


99
57
0
37

31
0

73
December 1981 „
Dependability I
AVL






73
99
95

100
73
















100


65
99
100
76
100
41
ion

100
OPR




60
67
08
99
95

60
49



















100
99

29
75
41


90
RU






68
99
95

100
73



















100
99

29
75
43


100
UTL

J2


45
67
59
99
95

60
49
















0


65
99
0
76
100
41
0

90
(continued)

-------
      TABLE 3 (continued)
Plant
Nlnnkota Power
Milton R. Young 2
Honongahela Power
Pleasants 1
Pleasants 2
Montana Power
Colstrlp 1
Col strip 2
Montana -Dakota
Utilities
Coyote 1
Nevada Power
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Northern Indiana Public
Service
DeanH. Mitchell 11
Northern States Power
Riverside 6-7
Sherburne 1
Sherbume 2
Pacific Power 1 Light
JlB Brldger 4
Pennsylvania Power
Bruce Mansfield 1
Bruce Mansfield 2
Bruce Mansfield 3
Publ Ic Service of New
Mexico
San Juan 1
San Juan 2
San Juan 3
Salt River Project
Coronado 1
Coronado 2
San Miguel Electric
San Hlguel 1
FGD lysten
capacity.
MM* '

185

668
668

360
360


440

125
125
125


115

110
740
740

S50
917
917
917


361
350
534

280
280

400
Flue gas
I scrubbed

42

100
100

100
100


100

100
100
100


99

100
100
100

100
100
100
100


100
100
100

80
80

inn
rcn
capacity
on line
during
period

185




360
360




125
125
125





740
740


917
917
917


361
350
534

280
280

400
Ho information
for this
period. MM* .



668
668





440








110


550












Shut down
throughout
period,
Hua

















115

















October 1981
Dependability Ic>*
AVL

100




98
98




0
100
100


100


100
100


100
98
99


100
65
98





OPR

100











99
99


0


100
100







96
62
84





REL

100











99
99





100
100







100
61
91





UTL

66










0
86
94


0


92
100







96
45
62





Hoveoter 1981
Dependability Xc>e
AVL

100




93
93




95
100
98


100


100
100


9B
94
100


100
93
94





OPR

98










78
100
98


0


100
100







95
71
90





DEL

99










61
100
98





100
100







100
90
93





UTL

89










9
47
98


0


95
100







Bl
59
69





December 1981
Dependability tc-e
AVI

100




97
96




100
95
99


100


100
100


99
95
100


99
95
ion





OPR

100










96
74
98


0


100
100







78
89
9?





REl

100










96
69
97





100
100







100
95
98





UTl

100










100
56
49


0


100
100







25
89
89





K"-
H-
        (continued)

-------
TABLE 3 (continued)
Plint
Sikeston Board or
Municipal Utilities
SUeston 1
South Carolina Public
Service
Ulnyah 2
Ulnyih 3
Ulnyah 4
South Mississippi
Electric Power
R.D. Morrow. Sr. 1
R.O. Morrow. Sr. 2
Southern Illinois Power
Marlon 4
Southern Indiana Gas
1 Electric
A.B. Brown 1
Springfield City
Utilities
Southwest I
Springfield Miter.
Light I Power
Dal loan 3
St. Joe Zinc
C.f We* ton 1
Tennessee Valley Author
Shaxnee IDA
Shaxnee 108
Widows Creek 7
UidOHS Creek 8
Texas Power I light
SandOM 4
Texas Utiltllei
Martin lake 1
Martin Lake 2
Martin lake 3
Honllcello 3
TGO system
capacity,
HW»


23S


140
280
280


124
124

173

265

194

IBS
60
ty
10
10
S7s
650

382

595
595
595
800
Flue gas
t scrubbed


100


SO
100
100


62
62

100

100

100

90
100
d
»/*d
N/A"
100
100

70

75
75
75
100
fGO
capacity
on line
during
period
HW'.b


23S


140
?BO
280


124
124



26S

194

IBS
60



S75
550







Ho Information
for this ,
period. HH°













173








10
10



382

S9S
S9S
595
800
Shut down
throughout
period,
HMa

































October 1981 , .
Dependability T '
AVL





32
96



75
100



98

47

94
12












OPR





71
96



99
100



94

87

68
12












DEL





72
97



99
100



94

98

84
12












UTL





30
96



72
100



84

45

S3
12












November 1981
Dependability t '
AVL





82
96
52


100
32



93

0


55












OPR





88
94
S3


99
99



91




SS












HI





88
95
54


99
99



91




SS












UTl





82
84
52


98
32



91

0


SS












December 1981
Dependability I '
AVL





81
97



100
100



98

78


1












OPR





82
97



100
99



63

82
1

1












RCL





81
97



100
99



63

96


1












UTl





55
97



100
94



38

66


•












(continued)

-------
          TABLE  3  (continued)
Plant
Utah POMCT i Light
Hunter 1
Hunter 2
Huntlngton 1
Mtughton 3
TOTAL
FGO systcn
capacity.
HU*
160
360
366
330
32.683
Flue gas
I scrubbed
90
90
as
100

FCD
capacity
on line
during
period
Hwa.b

23.371
Mo Information
for this .
period. HH
360
360
366
330
8,81?
Shut down
throughout
period.
HW>

550
October 1981 , .
Dependability tc>e
AVL


OPR

•
DEL


OIL


November 1981
Dependability Xc>e
AVL


OPR


DEL


UTL


Decenber 1981
Dependability Xc>*
AVL


OPR


REL


UTL


X
H-
X
e Equivalent scrubbed capacity.
b This category  Includes the flue gas capacity being handled by the FCO  systw it leatt part of the  tie* during the report period.
c The percent figures 11tied are average  values fcr all systes) scrubbing trains during the period.
d Flue gat X scrubbed for prototype and demonstration units Is not applicable unless the systesi Is designed to bring a unit Into compliance irith
  standard.
a Availability,  operablllty, reliability, and utllliatlen as defined In  Appendla C of this report.
                                                                                                                                                        esjlstlon

-------
Current projections  indicate  that the total power generating
capacity of the U.S. electric utility industry will be approxi-
mately 831 GW by the end  of 1999.  (This value reflects the
annual loss resulting  from the retirement of older units, which
is considered to be  0.4%  of the average generating capacity at
the end of each year.lrZ)  Approximately 373 GW or 45% of the
1999 total will come from coal-fired units.  The distribution pf
power generation sources,  both present (December 1980) and future
(December 1999) is shown  in Table 4.1
          TABLE 4.  POWER GENERATION SOURCES:  PRESENT AND FUTURE

December 1980
December 1999
Coal
41%
45%
Nuclear
10%
15%
Oil
24%
19%
Hydro
12%
11%
Gas
12%
9%
Other
n
1%
GW (total)
616
831
Based on the known  commitments to FGD by utilities as presented
in Table 1, the percentage of electrical generating capacity
controlled by FGD for  both the present (December 1981)  and the
future  (December 1999)  is shown in Table 5.
      TABLE 5.  FGD CONTROLLED GENERATING CAPACITY:  PRESENT AND FUTURE

December 1981*
December 1999
Coal -fired generating
capacity controlled
by FGD, %
14.2
28.7
Total generating
capacity controlled
by FGD, %
5.8
12.9
 The number of committed FGD systems is as of December 1981; however, the
 figure used for the total generating capacity and coal-fired generating
 capacity is based on the available December 1980 figures.


In light  of the revised  New Source Performance Standards,  actual
FGD control is expected  to be greater than what is reflected by
the figures above.   For  example, about 50 to 60 systems repre-
senting approximately 29,000 to 31,000 MW of generating capacity
presently fall into  the  uncommitted category.  These  are systems
that cannot be included  in the committed group at this  time
because information  regarding their status is not ready for
public release.

In an effort  to show general FGD usage and projected  usage
trends, Table 6 gives a  current (December 1981) and a projected
(December 1999) breakdown of throwaway product systems  versus
salable product systems  as a percent of the total known commit-
ments to  FGD  as of the end of the fourth quarter 1981:
                                x x

-------
                  TABLE 6.  SUMMARY OF FGD SYSTEMS BY PROCESS




Throwaway product process
°Wet systems
L1me
Limestone
Dual alkali
Sodium carbonate
NA*
°Dry systems
Lime
Lime/Sodium carbonate
Sodium carbonate
Salable product process
"Process "Byproduct
Aqueous carbonate/ Elemental sulfur
spray drying
Citrate Elemental sulfur
Lime Gypsum
Limestone Gypsum
Lime/limestone Gypsum
Magnesium oxide Sulfuric acid
Wellman Lord Sulfuric acid
We 11 man Lord Elemental sulfur
Process undecided
Total
Percent of total MW

December
1981


38.1
47.8
3.6
3.8
-

0.3
-
1.3


_

0.2
.
-
-
-
2.3
2.6
-
100.0
December
1999
December
1999
( Projected )|° ( Norma 1 1 zed )c


13.0
31.5
1.2
2.7
7.6

4.8
0.1
-


0.1

0.1
0.1
0.2
0.7
1.0
0.5
0.2
36.2
100.0


23.1
56.0
2.1
4.8
-

8.5
0.2
-


0.2

0.2
0.2
0.4
1.2
1.8
0.9
0.4
-
100.0
     -  Not available (these  systems are committed to a throwaway  product
  process; however, the actual process is unknown at this time).

  These values are based solely on information actually reported  by  utilities.
  This  breakdown could change  significantly as specific processes are chosen
  for plants now in the very early planning stages of development.

 cThe effect of those systems  listed as "NA" and "Process undecided" is
  removed.

              HIGHLIGHTS:  OCTOBER -  DECEMBER  1981

The  following paragraphs  highlight FGD  system developments  during
the  fourth quarter  1981.
                                    xxi

-------
Alabama Electric announced that the Tombigbee 3 FGD system
achieved availabilities of 97%, 99%, and 96% for the months of
October, November, and December,  respectively.   No major FGD
related problems were noted during the three-month period.

Arizona Electric Power reported that the Apache 3 FGD system
achieved 96% and 100% availabilities for the months of October
and November, respectively.  Information for December was not
available for this report.

Basin Electric Power reported availabilities of 100%, for the
Laramie River 1 and 2 FGD systems during the months of October,
November and December.  No major FGD-related problems were en-
countered during the fourth quarter.

Big Rivers Electric reported that the Green 1 FGD system achieved
96% and 99% availabilities for the months of November and Decem-
ber, respectively.  Operations at the beginning of the fourth
quarter were restricted due to piping and damper problems.

The Newton 1 FGD system of Central Illinois Public Service
achieved availabilities of 100%, 98%, and 100% for the months of
October, November and December.  No major FGD-related problems
were encountered during the fourth quarter.

Delmarva Power & Light announced that the FGD system installed on
Delaware 2 achieved availabilities of 100%, 89%, and 99% during
the fourth quarter.  Some ESP and presaturator problems were
noted during the three-month period.

Duquesne Light reported that the FGD system installed at Elrama
achieved 95%, 100%, and 100% availabilities for the months of
October, November, and December, respectively.  During the
period the recycle pumps of one of the five modules were replaced.
Due to the spare capacity, the system operation was not hindered.

East Kentucky Power announced that a contract has been awarded to
Babcock & Wilcox for the installation of a lime FGD system to
control S02 emissions from J.K. Smith 1.  This new unit will be
rated at 650 MW  (gross) and will fire coal with an average
sulfur content of 1.5%.  FGD systems startup is scheduled for
August 1987.

The Merom 2 FGD system of Hoosier Energy began initial operations
on December 30.  Merom 2 is rated at 490 MW (gross) and fires
coal with an average sulfur content of 3.50%.  The limestone FGD
system, which was supplied by Mitsubishi Heavy Industries, con-
sists of a cold-side ESP upstream of a grid tower absorber.  The
scrubbed gas is heated by a flue gas bypass before exiting a 700-
foot stack.
                               xxii

-------
Louisville Gas & Electric reported availabilities of 93%, 89%,
and 99% for the Cane Run 5 FGD system during the months of Octo-
ber, November, and December, respectively.  No major FGD-related
problems were encountered during the three-month period.

Initial operations of the Mill Creek 2 FGD system of Louisville
Gas & Electric began during December.  Mill Creek 2 is rated at
350 MW  (gross) and fires coal with an average sulfur content of
3.75%.  The lime FGD system, which was supplied by Combustion
Engineering, consists of two absorber modules.  Two hot side
ESP's are included for primary particle removal.  Availability of
the FGD system during the month of December was 100%.

Minnesota Power & Light reported availabilities of 100%, 94%, and
100% for the Clay Boswell 4 FGD system during the months of
October, November, and December, respectively.  No major FGD-
related problems were encountered during this period.

Minnkota Power announced that the FGD system installed on Milton
R. Young 2 achieved 100% availability for the months of October,
November and December.  No FGD-related problems were reported for
the three-month period.

Nevada Power reported that the Reid Gardner 1 FGD system achieved
95% and 100% availabilities for the months of November and Decem-
ber, respectively.  The system was not available during October
due to scheduled scrubber/boiler overhaul.  The Reid Gardner 2
FGD system achieved 100%, 100% and 95% availabilities for the
same three-month period.  The Reid Gardner 3 FGD system achieved
availabilities of 100%, 98%, and 99% during the three-months with
only minor problems being encountered.

The Sherburne 1 -and 2 FGD systems of Northern States Power
achieved 100% availability during the months of October, Novem-
ber, and December*  No FGD-related problems were encountered
during the three-month period.

Pennsylvania Power reported availabilities of 100%, 98%, and 99%
for the Bruce Mansfield 1 FGD system during the months of October,
November, and December, respectively.  Bruce Mansfield 2 achieved
availabilities of 98%, 94%, and 95% during the same three-month
period.  Bruce Mansfield 3 achieved availabilities of 99%, 100%,
and 100% during the same period.  Some minor ID fan problems and
general maintenance were encountered.

Public Service Company of New Mexico reported that the San Juan 1
FGD system achieved availabilities of 100%, 100%, and 97% during
the months of October, November, and December, respectively.  San
Juan 2 achieved 93% and 95% availabilities for the months of No-
vember and December, respectively.  Low availability in October
resulted from necessary mist eliminator maintenance.  San Juan 3
achieved availabilities of 98%, 94%, and 100% during the same
three-month period.  Operation of an additional module on San
Juan 3 commenced during the period.

                               xxiii

-------
South Carolina Public Service reported that the Winyah 3 FGD
system achieved availabilities of 96%, 96%, and 97% for the
months of October, November, and December, respectively.  Some
absorber pump problems were reported during the period.

Southern Indiana Gas & Electric reported availabilities of 98%,
93%, and 98% for the A.B. Brown 1 FGD system during the months
of October, November, and December,  respectively.   Some damper
problems were noted throughout the three-month period.

South Mississippi Electric Power reported availabilities of 100%
for the R.D. Morrow 1 FGD system during the months of November
and December.  Low availability for October was due to a scrubber
duct inspection.


References

 1.  U.S. Department of Energy.  Energy Information Administra-
     tion.  Office of Coal and Electric Power Statistics.  Elec-
     tric Power Statistics Division.  Inventory of Power Plants
     in the United States, 1980 Annual.  Publ. No. DOE/EIA-0095
     (80) .

 2.  Herman, Ira M.  New Generating Capacity;  When, Where, and
     by Whom.  Power Engineering 85(4)72.  April 1981.
                              xxiv

-------
                                            EPA UTILITY  FGD  SURVEY:  OCTOBER  -  DECEMBER 1931
                                           SECTION 1
                                  SUMMARY LIST OF  FGO SYSTEMS
COMPANY NAME/
UNIT NAME
ALABAMA ELECTRIC
TOMSIGBEE
TOM3IGBEE
ARIZONA ELECTRIC POWER
APACHE
APACHE
ARIZONA PUBLIC SERVICE
CHOLLA
CHOLLA
CHOLLA
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
ASSOCIATED ELECTRIC
THOMAS HILL
ATLANTIC CITY ELECTRIC
CUMBERLAND
BASIN ELECTRIC POWER
ANTELOPE VALLEY
ANTELOPE VALLEY
LARAI1IE RIVER
LARAMIE RIVER
LARAMIE RIVER
BIG RIVERS ELECTRIC
O.B. WILSON
D.B. WILSON
GREEN
GREEN
CAJUN ELECTRIC POWER
CHICOT
CHICOT
CHICOT
CHICOT
OXBOW
OXBOW
CENTRAL ILLINOIS LIGHT
OUCK CREEK
DUCK CREEK
UNIT NO.

2
3

2
3

1
2
4
1
2
3
4
5

3

1

1
2
1
2
3

1
2
1
2

1
2
3
4
1
2

1
2
UNIT LOCATION

LEROY
LEROY

COCHISE
COCHISE

JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARMIHGTON
FARMINGTON
FARMINGTON
FARMINGTON
FARMINGTON

MOBERLY

MILLVILLE

BEULAH
BEULAH
WHEATLAND
HHEATLAND
WHEATLAND

CENTERTOUN
CENTERTOMN
SEBREE
SEBREE

COUSHATTA
COUSHATTA
COUSHATTA
COUSHATTA
DE SOTQ PARISH
COSHATTA

CANTON
CANTON


ALABAMA
ALABAMA

ARIZONA
ARIZONA

ARIZONA
ARIZONA
ARIZONA
NEW MEXICO
NEW MEXICO
HEW MEXICO
NEW MEXICO
NEW MEXICO

MISSOURI

NEW JERSEY

NORTH DAKOTA
NORTH DAKOTA
WYOMING
WYOMING
WYOMING

KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY

LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA

ILLINOIS
ILLINOIS
START-UP
DATE

9/79
6/79

8/73
6/79

10/73
4/78
3/81
11/79
11/79
11/7°
12/84
12/84

1/82

1/88

10/83
10/85
7/80
7/81
11/82

7/84
O/ 0
12/79
11/80

0/86
0/88
0/92
0/94
0/85
0/85

7/76
1/87
STATUS

1
1

1
1

1
1
1
1
1
1
2
2

2

6

2
2
1
1
2

2
3
1
1

6
6
6
6
5
6

1
6
REG
CLASS

B
3

D
D

C
C
C
C
C
C
C
C

A

C

D
C
C
C
C

A
A
B
B

A
A
A
A
A
A

B
A
CENTRAL ILLINOIS PUBLIC SERV
   NEWTON                      1

CENTRAL MAINE POWER
   SEARS ISLAND                1
        NEWTON
                       ILLINOIS
                                        PENOBSCOT BAY  MAINE
                                         9/79


                                        11/89
1.  OPERATIONAL UNITS
2.  UNITS UNDER CONSTRUCTION
3.  PLANNED - CONTRACT AWARDED
4.  PLANNED - LETTER OF    INTENT SIGNED
5.  PLANNED - REQUESTING/EVALUATING BIDS
6.  PLANNED - CONSIDERING ONLY FGD SI STEMS
7.  PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A.  FEDERAL NSPSC6/79)
B.  FEDERAL NSPSt12/71)
C.  STANDARD(S) MOPE STRINGENT THAN NSPS(6/79)
D.  STANDARD(S) MORE STRINGENT THAN NSPSI12/71) BUT NOT MORE STRINGENT THAN NSFS(6/79)
E.  STANDARO(S) EQUAL TO OR LESS STRINGENT THAN HSPSdZ/71)

-------
EPA UTILITY FGD  SURVEY: CCTCSER  - DECEMBER  1981
                                           SECTION 1
                                  SUMMARY  LIST OF F60 SYSTEMS
 COMPANY NAME/
    UNIT NAME
                               UNIT NO. UNIT  LOCATION
                                        START-UP
                                          DATE
                                                 PES
                                         STATUS CLASS
 CENTRAL POWER  &  LIGHT
    COLETO CREEK
 CINCINNATI GAS
    EAST BEND
    EAST BEND
                * ELECTRIC
 COLORADO UTE  ELECTRIC
    CRAIG
    CRAIG
    CRAIG
 COMMONWEALTH  EDISON
    POWERTON
 OELMARVA POWER  ft  LIGHT
    DELAWARE  CITY
    DELAWARE  CITY
    DELAWARE  CITY
    VIENNA

 DESERET GEN  t TRANS
    BONANZA
    BONANZA

 DUQUESNE LIGHT
    ELRAMA
    PHILLIPS

 EAST KENTUCKY POWER
    J.K.  SMITH
    SPURLOCK

 FLORIDA POWER £ LIGHT
    MARTIN
    MARTIN

 GENERAL PUBLIC  UTILITIES
    COAL
    COAL
    COAL
    COAL
    SEUARD
 COLUMBUS I SOUTHERN OHIO  ELEC
    COHESVILLE                   5
    COHESVILLE                   6
    POSTON                      5
    POSTOM                      6
                                51
 COOPERATIVE POWER  ASSOCIATION
    COAL CREEK                   1
    COAL CREEK                   2
1-4
1-6
                                         FANNIN
         RABBITHASH
         RABBITHASH
         CRAIG
         CRAIG
         CRAIG
         CONESVILLE
         COMESVILLE
         NELSOMVILLE
         NELSONVILLE
                                         PEKIN
         UNDERWOOD
         UNDERWOOD
                                                       TEXAS
               KENTUCKY
               KENTUCKY
               COLORADO
               COLORADO
               COLORADO
               OHIO
               OHIO
               OHIO
               OHIO
                                                        ILLINOIS
               NORTH DAKOTA
               NORTH DAKOTA
         DELAWARE CITY  DELAWARE
         DELAWARE CITY  DELAWARE
         DELAWARE CITY  DELAWARE
         VIENNA         MARYLAND
         VERNAL
         VERNAL
ELRAMA
SOUTH HEIGHT
         WINCHESTER
         MAYSVILLE
         MARTIN COUNTY
         MARTIN COUNTY
               UTAH
               UTAH
PENNSYLVANIA
PENNSYLVANIA
               KENTUCKY
               KENTUCKY
               FLORIDA
               FLORIDA
1
2
3
4
7
UNDECIDED
UNDECIDED
UNDECIDED
UNDECIDED
EAST WHEATFI
UNDECIDED
UNDECIDED
UNDECIDED
UNDECIDED
ELOPENNSYLVAI
                                                                         9/92
                  0/83
                  3/81
                 10/80
                 12/79
                  4/83
                  1/77
                  6/7S
                  8/85
                  0/89
                                                                         4/80
                  7/79
                  7/80
                                 5/80
                                 5/80
                                 5/80
                                 5/90
                  9/84
                  0/88
10/75
 7/73
                  8/87
                  1/83
0
0
                  A
                  B
0/87
0/89
5/
-------
                                            EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
                                           SECTION 1
                                  SUMMARY LIST OF FC-D SYSTEMS
COMPANY NAME/
   UNIT NAME
                               UNIT NO.  UNIT LOCATION
                                        START-UP          3ES
                                          DATE    STATUS CLASS
GRAND HAVEH BRD OF LIGHT t PUR
   J.B. SIMS                   3
                                        GRAND HAVEN
                                                       MICHIGAN
HOOSIER ENERGY
   MEKOM
   MERCM

HOUSTON LIGHTING & POWER
   LIMESTONE
   LIMESTONE
   M.A. PARISH

INDIANAPOLIS POWER t LIGHT
   PATRIOT
   PATRIOT
   PATPIOT
   PETERSBURG
   PETERSBURG
ICWA ELECTRIC LIGHT &
   GUTHRIE CO.
                      PUR
JACKSONVILLE ELEC AUTHORITY
   ST.JOHNS RIVER PUR PARK
   ST.JOHNS RIVER PUR PARK

KANSAS CITY POWER t LIGHT
   HAUTHCRN
   HAUTKCRN
   LA CYGNE
1
2
6
KANSAS POWER & LIGHT
   JEFFREY                     1
   JEFFREY                     Z
   LAURENCE                    4
   LAURENCE                    5

KENTUCKY UTILITIES
   GREEN RIVER                 1-3
   HANCOCK                     1
   HANCOCK                     2

LAKELAND UTILITIES
   MCINTOSH                    3

LANSING BOARD OF MATER £ LIGHT
   ERICKSON                    2

LOS ANGELES DEPT OF HTR & PUR
   INTERMOUNTAIN               1
   INTERMOUNTAIN               2
   INTERMOUNTAIN               3
   INTERMOUMTAIN               4
MEPOM
MEROM
JEWETT
JEUETT
BOOTH
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
INDIANA
INDIANA
TEXAS
TEXAS
TEXAS
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
                                        PANORA
                                                       IOWA
         EAST PORT SITE FLORIDA
         EAST PORT SITE FLORIDA
KANSAS CITY
KANSAS CITY
LA CYGIIE
WAMEGO
WAMEGO
LAURENCE
LAURENCE
MISSOURI
MISSOURI
KANSAS
KANSAS
KANSAS
KANSAS
KANSAS
         CENTRAL CITY   KENTUCKY
         HAUESVILLE     KENTUCKY
         HAUESVILLE     KENTUCKY
         LAKELAND
                        FLORIDA
         DELTA TOWNSHIP MICHIGAN
         DELTA
         DELTA
         DELTA
         DELTA
UTAH
UTAH
UTAH
UTAH
                                                                         1/83
                                          5/82
                                         12/81
                 12/86
                 12/87
                 11/82
                                          0/87
                                          O/ 0
                                          O/ 0
                                         12/77
                                         10/84
                                                                        11/87
                 12/85
                  6/87
                                         11/72
                                          8/72
                                          2/73
                                          8/78
                                          1/60
                                          1/77
                                          4/78
                  9/75
                  4/89
                  4/94
                                          1/82
                                          1/87
0/66
0/87
0/88
0/89
                 A
                 A
                 A
                                   C
                                   C
                                   C
                                   3
                                   3
                 A
                 A
                 E
                 A
                 A
1.  OPERATIONAL UNITS
2.  UNITS UNDER CONSTRUCTION
3.  PLANNED - CONTRACT AWARDED
 4.  PUNNED - LETTER OF    INTENT SIGNED
 5.  PLANNED - REQUESTING/EVALUATING BIOS
 6.  PLANNED - CONSIDERING ONLY FGO SYSTEMS
 7.  PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A.  FEDERAL NSPS(6/79)
B.  FEDERAL NSPSC12/71)
C.  STANDARD!S) MORE STRINGENT THAN NSPSC6/79)
0.  STANDARD(S) MORE STRINGENT THAN NSPSt12/71) BUT NOT MORE STRINGENT THAN NSPSC6/79)
E.  STANDARD!S) EQUAL TO OR LESS STRINGENT THAN NSPSt12/71)

-------
EPA UTILITY F60 SURVEY:  OCTC3ER  -  DECEMBER  1981
                                            SECTION  1
                                   SUMMARY LIST OF F60 SYSTEMS
COMPANY NAME/
UNIT NAME
LOUISVILLE GAS & ELECTRIC
CANE RUM
CANE RUN
CANE RUN
MILL CREEK
MILL CREEK
MILL CREEK
MILL CREEK
PACOY'S RUN
THIMBLE COUNTY
TRIMDLE COUNTY
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT
MARCUETTE BOARD OF LIGHT t PMR
SHIR AS
MICHIGAN SO CENTRAL PUR AGENCY
PROJECT
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
ARKANSAS LIGNITE
UN ASSIGNED
UNASSIGNED
UILTCN
WILTON
MINNESOTA POWER S LIGHT
CLAY BOSHELL
UNIT NO.

4
5
6
1
2
3
4
6
1
2

3

3

1

5
6
1
2
1
2

4
UNIT LOCATION

LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
BEDFORD
BEDFORD

LA GRANGE

HAHQUETTE

LITCHFIELD





CONVENT
CONVENT

COHASSET


KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY

TEXAS

MICHIGAN

MICHIGAN

ARKANSAS
ARKANSAS
LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA

MINNESOTA
START-UP
DATE

8/76
12/77
4/79
12/30
12/81
6/78
6/82
4/73
7/85
7/89

0/83

9/82

6/82

0/90
0/92
0/89
0/93
0/83
0/91

4/80
STATUS

1
1
1
1
1
1
2
1
5
5

6

2

2

4
4
4
4
4
4

1
=513
CLASS

0
D
D
E
E
D
3
E
C
C

A

A

A

A
A
A
A
A
A

A
 MINNKOTA POWER
    MILTON R.  YOUN5             2

 MCN'CMGAHELA POWER
    PLEASANTS                   1
    PLEASANTS                   2

 MONTANA POWER
    COLSTRIP                    1
    COLSTRIP                    2
    COLSTRIP                    3
    COLSTRIP                    4

 MONTANA-DAKOTA UTILITIES
    COYOTE                      1

 MUSCATINE POWER i WATER
    MUSCATINE                    9

 NEBRASKA PUBLIC POWER  DISTRICT
    FOSSIL III                  1
        CENTER
                       NORTH DAKOTA
        WILLOW ISLAND  WEST VIRGINIA
        WILLOW ISLAND  WEST VIRGINIA
        COLSTRIP
        COLSTRIP
        COLSTRIP
        COLSTRIP
        BEULAH
        MUSCATINE
                                        SARGENT
MONTANA
MONTANA
MONTANA
MONTANA
                       NORTH DAKOTA
                       IOWA
                                                       NEBRASKA
                                         9/77
                  3/79
                 10/80
 9/75
 5/76
10/83
 0/84
                  4/81


                  9/82


                  3/92
                                                          B


                                                          A
 1.   OPERATIONAL UNITS
 2.   UNITS  UNDER CONSTRUCTION
 3.   PLANNED  -  CONTRACT  AWARDED
4.  PLANNED - LETTER OF    INTENT SIGNED
5.  PLANNED - REQUESTING/EVALUATING BIDS
6.  PLANNED - CONSIDERING ONLY FGD SYSTEMS
7.  PLANNED - CONSIDERING FGO SYSTEMS; ALSO ALTERNATIVE METHODS
 A.   FEDERAL NSPS(6/79)
 B.   FEDERAL NSPSt12/71)
 C.   STANOARD(S)  MORE STRINGENT THAN NSPSI6/79)
 0.   STANDARD(S)  MORE STRINGENT THAN NSPS(12/711 BUT NOT MORE STRINGENT THAN NSPSt6/79)
 E.   STANDARD(S)  EQUAL TO OR  LESS STRINGENT THAN NSPSI12/71)

-------
                                            EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
                                           SECTION 1
                                  SUMMARY LIST OF FGD SYSTEMS
COMPANY HAME/
UNIT NAME
NEVADA POWER
HACRY ALLEN
HARRY ALLEN
HARRY ALLEN
HARRY ALLEN
REID GARDNER
REID GARDNER
REID GARDNER
REID GARDNER
UNIT NO.

1
2
3
4
1
2
3
4
UNIT LOCATION

US VEGAS
LAS VEGAS
LAS VEGAS
LAS VEGAS
MOAPA
MOAPA
MOAPA
MOAPA


NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
START-UP
DATE

6/86
6/67
6/38
6/69
3/74
4/74
6/76
4/83
STATUS

6
6
6
6
1
1
1
4
PEG
CLASS

A
A
A
A
B
3
3
A
NEW YORK STATE ELEC & GAS
   SOMERSET

NIAGARA MOHAWK POWER
   CHARLES R. HUNTLEY

NORTHERN INDIANA PL'S SERVICE
   DEAN H. MITCHELL
   SCHAHFER
   SCHAHFER '

NORTHERN STATES POWER
   METRO COAL
   RIVERSIDE
   SHEREURNE
   SHERBURNE
   SHERBURNE
PACIFIC GAS &
   MOHTEZUMA
   MONTEZUMA
              ELECTRIC
PACIFIC POWER & LIGHT
   JIM BRIDGER
   JIM BRIDGER
   JIM ERIDGER
   JIM BRIDGER
   JIM BRIDGER

PENNSYLVANIA POWER
   BRUCE MANSFIELD
   BRUCE MANSFIELD
   ERUCE MANSFIELD

PHILADELPHIA ELECTRIC
   CBOM3Y
   EDDYSTONE
   EDDYSTONE

PLAINS ELECTRIC GST
   PLAINS ESCALANTE

PLATTE RIVER POWER AUTHORITY
   RAWHIDE
66
11
17
18
1
6-7
1
1
2
2A
3
4
         SOMERSET
         BUFFALO
                        NEW YORK
                        NEW YORK
                                          6/84
                                          4/82
GARY
WHEATFIELD
WHEATFIELO
UNDECIDED
MINNEAPOLIS
BECKER
BECKER
BECKER
COLLINSVILLE
COLLINSVILLE
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
SHIPPINGPORT
SHIPPINGPORT
SHIPPINGPORT
PHOENIXVILLE
EDDYSTONE
EDDYSTONE
INDIANA
INDIANA
INDIANA
UNDECIDED
MINNESOTA
MINNESOTA
MINNESOTA
MINNESOTA
CALIFORNIA
CALIFORNIA
WYOMING
WYOMING
WYOMING
WYOMING
WYOMING
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
7/76
6/83
6/85
0/90
11/80
3/76
3/77
0/85
6/93
6/94
0/83
0/90
1/32
0/86
9/79
12/75
7/77
6/80
5/83
12/82
12/82
         PREWITT


         FT. COLLINS
                        NEW MEXICO
                                                       COLORADO
12/83


12/83
                  A
                  E
                  0
                  D
                  C
                                                           c
                                                           C
                  A
                  A
                  A
                  A
                  D
B


C
1.  OPERATIONAL UNITS
2.  UNITS UNDER CONSTRUCTION
3.  PLANNED - CONTRACT AWARDED
 4.  PLANNED - LETTER OF    INTENT SIGNED
 5.  PLANNED - REQUESTING/EVALUATING BIDS
 6.  PLANNED - CONSIDERING ONLY FGD SYSTEMS
 7.  PLANNED - CONSIDERING FGO SYSTEMS! ALSO ALTERNATIVE METHODS
A.  FEDERAL NSPS(6/79)
B.  FEDERAL NSPSt12/71)
C.  STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
0.  STANOARD(S) MORE STRINGENT THAN NSPSI12/71) BUT NOT MORE STRINGENT THAN NSPSt6/79)
E.  STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSt 12/71)

-------
ErA UTILITY FGO SURVEY:  OCTOBER  - DECEMBER  1981
                                            SECTION 1
                                   SUMMARY LIST OF  FGD  SYSTEMS
 COMPANY NAME/
    UNIT NAME
                                UNIT NO.  UNIT LOCATION
                                       START-UP
                                         DATE
                                  RES
                          STATUS CLASS
 PUBLIC SERVICE INDIANA
    GIBSON                      5

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

 PMR AUTHORITY OF STATE OF  NY
    FOSSIL
 SALT RIVER PROJECT
    CORCNADO
    COHONADO
    CCRCNAOO

 SAN MIGUEL ELECTRIC
    SAN MIGUEL

 SEMINOLE ELECTRIC
    SEMINOLE
    SEMINOLE

 SIERRA PACIFIC POWER
    VALMY

 SIKESTCN BRD  OF MUNICIPAL UTIL
    SIKESTCH

 SOUTH CAROLINA PUBLIC SERVICE
    CROSS
    CROSS
    UINYAH
    UINYAH
    WINYAH

 SOUTH MISSISSIPPI ELEC PUR
    R.D. MORROW, SR.
    R.D. MORPOW, SR.

 SOUTHERN ILLINOIS POWER
    MARION
 SOUTHERN INDIANA GAS £
    A.3.  BPOWN
    A.B.  BROWN
                        ELEC
 SOUTHWESTERN ELECTRIC  POWER
    DOLET HILLS
    DOLET HILLS
    HENRY W.  PIRKEY

 SOYLAND  POWER
    SOYLAND
        PRINCETON
        MATERFLOW
        MATERFLOW
        WATERFLOW
        MATERFLOW
                                        NEW YORK
        ST. JOHNS
        ST. JOHNS
        ST. JOHNS
        SAN MIGUEL
        PALATKA
        PALATKA
                       INDIANA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
                                                        NEW YORK
ARIZONA
ARIZONA
ARIZONA
                       TEXAS
FLORIDA
FLORIDA
                                         8/82
 4/78
 3/73
12/79
 6/82
                                                                         4/87
11/79
 7/80
 0/89
                                         8/81
 3/83
 1/85
        MANSFIELD
        MANSFIELD
        HALLSVILLE
                                        UNDECIDED
LOUISIANA
LOUISIANA
TEXAS
                                                        ILLINOIS
 3/86
 0/83
12/84
                                                                         6/87
A
A
2
1
1
2
2
3
4
1
2
4
1
2
VALMY
SIKESTON
CROSS
CROSS
GEORGETOWN
GEORGETOWN
GEORGETOWN
HAITI ESBUHG
HATTIESBURG
MARION
WEST FRANKLIN
WEST FRANKLIN
NEVADA
MISSOURI
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
MISSISSIPPI
MISSISSIPPI
ILLINOIS
INDIANA
INDIANA
8/84
6/81
5/38
11/83
7/77
5/80
7/81
8/73
6/79
5/79
3/79
i/as
7
1
3
2
1
1
1
1
1
1
1
5
A
B
A
A
B
B
A
B
B
B
B
A
 1.   OPERATIONAL UNITS
 2.   UNITS UNDER CONSTRUCTION
 3.   PLANNED  -  CONTPACT  AWARDED
4.  PUNNED - LETTER OF    INTENT SIGNED
5.  PUNNED - REQUESTING/EVALUATING BIDS
6.  PLANNED - CONSIDERING ONLY FGO SYSTEMS
7.  PLANNED - CONSIDERING FGD SYSTEMS;  ALSO ALTERNATIVE METHG3S
 A.   FEDERAL NSPS(6/79)
 B.   FEDERAL NSPS(12/71)
 C.   STANDARD1S)  MOPE  STRINGENT  THAN NSPSC6/79)
 D.   STANDARD(S)  MORE  STRINGENT  THAN NSPSC12/71) BUT NOT MORE STRINGENT THAN NSPSJ6/79)
 E.   STANDARD(S)  EQUAL TO  OR  LESS  STRINGENT THAN NSPSt12/71)

-------
          EPA UTILITY FGO SURVEY: OCTOBER - DECEH3ER  1<=31
         SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
SPRINGFIELD CITY UTILITIES
SOUTHWEST
SPPIN5FIELD MATER. LIGHT & PUR
OALLMAN
ST. JOE ZINC
G.F. WEATON
SUNFLOWER ELECTRIC
HOLCOMB
TAMPA ELECTRIC
BIG BEND
TENNESSEE VALLEY AUTHORITY
PARADISE
PARADISE
SHAKNEE
SHAKNEE
WIDOWS CREEK
WIDOWS CREEK
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK
TEXAS POWER & LIGHT
SANOOH
TWIN OAKS
TWIN OAKS
TEXAS UTILITIES
FOREST GROVE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MAPTIN LAKE
MILL CREEK
MILL CREEK
MONTICELLO
TUCSON ELECTRIC POWER
SPRIMGERVILLE
SPRINGERVILLE
UNITED POWER ASSOCIATION
STANTON
UTAH POWER t LIGHT
HUNTER
HUNTER
HUNTER
HUNTER
HUNTINGTON
NAUGHTON
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED

A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSt 12/71)
C. STAMDARO(S) MORE STRINGENT
0. STANOARO(S) MORE STRINGENT
UNIT

1

3

1

1

4

1
2
10A
10B
7
8

1

4
1
2

1
1
2
3
4
1
2
3

1
2

1A

1
2
3
4
1
3
4.
5.
6.
7.


THAN
THAN
NO. UNIT LOCATION

SPRINGFIELD

SPRINGFIELD

MONACA

HOLCOMB

TAMPA

PARADISE
PARADISE
PAOUCAH
PAOUCAH
BRIDGEPORT
BRIDGEPORT

CARLOS

ROCKDALE
BREMOND
BREHONO

ATHENS
TATUM
TATUM
TATUM
TATUM
HENDERSON
HENDERSON
MT. PLEASANT

SPRINGERVILLE
SPRINGERVILLE

STANTON

CASTLE DALE
CASTLE DALE
CASTLE DALE
CASTLE DALE
PRICE
KEMMERER


MISSOURI

ILLINOIS

PENNSYLVANIA

KANSAS

FLORIDA

KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
ALABAMA
ALABAMA

TEXAS

TEXAS
TEXAS
TEXAS

TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS

ARIZONA
ARIZONA

NORTH DAKOTA

UTAH
UTAH
UTAH
UTAH
UTAH
WYOMING
START-UP
DATE

ft/77

is/eo

11/79

9/83

3/85

0/83
0/83
4/72
4/72
3/61
5/77

10/82

12/80
8/85
8/87

0/87
4/77
5/78
2/79
0/89
0/87
0/88
5/78

2/85
3/87

6/82

5/79
6/80
6/83
6/85
5/78
9/81
STATUS

1

1

1

2

3

2
*»
1
1
1
1

2

1
3
3

5
1
1
1
3
6
6
1

3
3

2

1
1
2
2
1
1
= ES
CLASS

3

B

B

A

A

E
E
E
£
E
E

A

3
A
A

A
B
B
3
A
A
A
B

B
3

A

B
3
A
A
B
C
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING FGD SYSTEMS!


NSPSC6/79)



NSPSJ 12/71) BUT NOT MORE STRINGENT
ALSO ALTERNATIVE






METHODS



THAN NSPSI 6/79)
E. STANOARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSt 12/71)

-------
EPA UTILITY FC-D SUSVEY:  CCTC3ER  - CECEKBER  1981
                                           SECTION  1
                                   SUMMARY  LIST OF FGD SYSTEMS
 COMPANY Hi '£/
    UNIT N- =
                               UNIT NO. UNIT  LOCATION
                                        START-UP
                                          DATE
                                  REG
                          STATUS CLASS
 WASHINGTON HVTER  POWER
    C3ESTCN COAL
    C=ESTCN COAL
    CRESTCN COAL
    CRESTCN COAL

 WEST PENN POWER
    MITCHELL

 WEST TEXAS UTILITIES
    OKLAUNION
    OKLAUNION
33
         CRESTON
         CRESTON
         CRESTON
         CRESTON
         COURTNEY
         OKLAUNION
         OKLAUNION
WASHINGTON
WASHINGTON
WASHINGTON
WASHINGTON
                        PENNSYLVANIA
TEXAS
TEXAS
 0/87
 0/87
 0/87
 0/87
                                          8/82
12/86
 0/90
 1.  OPERATIONAL UNITS
 2.  UNITS UNDER CONSTRUCTION
 3.  PLANNED  - CONTRACT AWARDED
 4.   PLANNED - LETTER OF     INTENT  SIGNED
 5.   PLANNED - REQUESTING/EVALUATING  BIDS
 6.   PLANNED - CONSIDERING ONLY FGO SYSTEMS
 7.   PLANNED - CONSIDERING FGO  SYSTEMS!  ALSO  ALTERNATIVE  METHODS
A.  FEDERAL NSPS(6/79)
B.  FEDERAL NSPSI12/71)
C.  STANDARD(S) MORE STRINGENT THAN NSPSC6/79)
0.  STANDARD(S) MORE STRINGENT THAN NSPSC12/71) BUT HOT MORE STRINGENT THAN NSPS(6/79)
E.  STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSI12/71)

-------
                                              EPA UTILITY  FGO  SURVEY:  OCTOBER  -  DECEMBER  1«81
                                             SECTION  2
                                       STATUS OF  FGD  SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
ALABAMA ELECTRIC
TCMBIGBEE
2
NEW       255 MM (CROSS)
          179 MM (ESC)
COAL
 1.15 XS  BITUMINOUS
LIMESTONE
FEA30DY PROCESS SYSTEMS
EHE=GY CONSUMPTION:   s.ix
STATUS 1     STARTUP  9/78
TOMBIGBEE Z OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA.  THE BOILER GENERATES A MAXIMUM FLUE GAS FLCW Or =53,000
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFU? CONTENT OF 1.15X AND
AN AVERAGE HEAT CCNTENT OF 11,500 BTU/LB. THE UNIT S02 EMMISSIGM LIMITA-
TION VALUE IS 1.2 LB/MM3TU. PRIMARY PARTICULATE MATTER CCNTROL IS P.'CVID-
ED BY A HOT SIDE ESP.  THE S02 REMOVAL EQUIPMENT CONSISTS OF TW3 SFPAf
TOWERS SUPPLIED BY  PEABOOY PROCESS SI STEMS WHICH UTILIZE A LIMESTONE REA-
GENT. A CHEVRON MIST ELIMINATOR IS INCLUDED FOR EACH TCXcS AND THE FLU:
GAS IS REHEATED WITH BYPASSED GAS BEFORE BEING VENTED TO A «0 FC2T ACID-
BRICK LINED STACK.  THE SYSTEM OPERATES IN AN OPEN UATER LOOP MODE AND
SPENT ABSORBENT IS  DISPOSED OF IN AN ON-SITE LINED POND.
ALABAMA ELECTRIC
TOMBIGBEE
3
NEW       255 MM (GROSS)
          179 MM (ESC)
COAL
 1.15 XS  BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION:   3.IX
STATUS 1     STARTUP  6/79
TOMBIGBEE 3 OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LCCATED
IN LEROY, ALABAMA.  THE BOILER GENERATES A MAXIMUM FLUE GAS FLCH Or 953.000
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CCNTENT OF 1.15X AMD
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB. THE UNIT S02 EMISSION LIMITATION
VALUE IS 1.2 LB/MMBTU. PRIMARY PARTICULATE CCNTROL IS PROVIDED BY A HOT
SIDE ESP. THE SOS REMOVAL EQUIPMENT CONSISTS OF TWO SPRAY TONERS SUPPLIED
BY PEABCOY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REAGENT. A CHEVRON
MIST ELIMINATOR IS INCLUDED IN EACH TOWER, AND THE FLUE GAS IS REHEATED
WITH BYPASSED GAS BEFORE BEING VENTED TO A 400 FOOT ACID ERICK LINED
STACK. THE SYSTEM OPERATES IN AN OPEN MATER LOOP MODE. AND SPENT ABSORBENT
IS DISPOSED IN AN ON-SITE LINED POND.
ARIZONA ELECTRIC POWER
APACHE
2
NEW       195 MM (GROSS)
           98 MM (ESC)
COAL
  .50 XS  BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  4.ix
STATUS 1     STARTUP  8/78
APACHE 2 OF ARIZONA ELECTRIC POMER COOP IS LOCATED IN COCHISE, ARIZONA AND
IS A DRY BOTTOM PULVERIZED COAL FIRED UNIT WITH A FLUE GAS FLOM OF 735,000
ACFM. BITUMINOUS COAL WITH A HEATING VALUE OF 10,000 BTU/LB, A SULFUR CCN-
TENT OP 0.55X AND AN ASH CONTENT OF 15X IS THE FUEL USED FOR THIS UNIT.
PARTICULATE CONTROL IS EFFECTED BY A HOT SIDE ESP.  HALF THE FLUE GAS
PASSES THROUGH TWO RESEARCH-COTTRELL PACKED TOWERS EMPLOYING LIMESTONE
ABSORBENT AND HAVING A DESIGN S02 REMOVAL OF 65X. MIST ELINIMATICN
IS PROVIDED BY CHEVRON TYPE ELIMINATORS. NO REHEAT IS EMPLOYED. A 400
FT COLE BRAND CXL2000 LINED STACK IS IN USE. THE SYSTEM OPERATES IN AN
OPEN MATER LOOP MODE AND WASTE MATERIAL IS DISPOSED OF IN OFF-SITE
SLUDGE PONDS. OPERATIONS COMMENCED IN AUGUST 1978.
ARIZONA ELECTRIC POMER
APACHE
3
NEM       195 MM (GROSS)
           98 MM (ESC)
COAL
  .50 XS  BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  4.1X
STATUS 1     STARTUP  6/79
APACHE 3 OF ARIZONA ELECTRIC POMER COOP IS A DRY BOTTOM, PULVERIZED COAL
FIRED UNIT IN COCHISE, ARIZONA. LOM (0.55X1 SULFUR BITUMINOUS COAL WITH AH
AVERAGE HEATING VALUE OF 10,000 BTU/LB PRODUCES A MAXIMUM FLUE GAS FLOW OF
735.000 ACFM. HALF OF THE FLUE GAS PASSES THROUGH A HOT SIDE ESP TO TWD
RESEARCH COTTRELL PACKED TOWERS. WHERE LIMESTONE IS USED TO REMOVE 85X OF
THE S02. THE GAS EXITS A HORIZONTAL CHEVRON MIST ELIMINATOR INTO ITS OHM
CEILCOTE LINED FLUE IN THE 400 FOOT STACK IT SHARES WITH UNIT 2. THE FGO
SYSTEM WHICH HAS BEEN OPERATIONAL SINCE JUNE OF 1979. USES NO REHEAT. THE
SYSTEM OPERATES IN AN OPEN WATER LOOP AND SLUDGE IS DISPOSED OF IN TWO OFF
SITE LINED PONDS MITH 20 YEARS EXPECTED LIFESPAN. TUO ADDITIONAL PONDS ARE
PLANNED, MHICH MOULD ADO ANOTHER 20 YEARS OF DISPOSAL CAPACITY.
ARIZONA PUBLIC SERVICE
CHOLLA
1
RETROFIT  119 MM (GROSS)
          119 MM (ESC)
COAL
  .50 XS  BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENEPGY CONSUMPTION:  3.4X
STATUS 1     STARTUP 10/73
ARIZONA PUBLIC SERVICE'S CHOLLA 1 IS LOCATED IN JOSEPH CITY, ARIZONA AMD
IS A TANGENTIALLY FIRED, MET BOTTOM PULVERIZED COAL UNIT. IT IS FUELED BY
BITUMINOUS COAL THAT HAS A SULFUR CONTENT OF 0.5X AND A KEATINS VALUE OF
10,150 BTU/LB. PARTICULATE MATTER IS CONTROLLED BY TWO FLOODED DISC SCRUB-
BERS. THE FGO SYSTEM STARTED UP IN OCT03ER, 1973 AND IS MCW OPERATIONAL.
502 IS CONTROLLED BY ONE TOWER MITH MUNTERS PACKING EMPLOYING A LIMESTONE
ABSORBENT.  THE UNIT, SUPPLIED BY RESEARCH COTTRELL. HAS A DESIGN S02 RE-
REMOVAL EFFICIENCY OF 92X.  CHEVRON MIST ELIMINATORS ARE LCCATED F3IO
-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981
                                             SECTION  2
                                       STATUS OF  FSO  SYSTEMS
UNIT IDENTIFICATION
                                                                ABSTRACT
ARIZCMA PUBLIC SEPVICE
CHOLLA
•»
MEM       375 MM (GROSS)
          126 MM (ESC)
COAL
  .50 XS
LIMESTONE
FESEARCH-COTTSELL
EHEPGY CONSUMPTION: ****/:
STATUS 1     STARTUP  3/81
CHOLLA 4 CF ARIZONA PUBLIC SERVICE IS LOCATED IN JOSEPH CITY, ARIZCMA.
THE PULVERIZED COAL (0.5X S. 10150 BTU/LB) PIPED BOILER EXHAUSTS FLUE
GAS THROUGH AN ESP TO A DOUBLE LOOP COMBINATION TOWER (RHSEARCH-COTTSELL
DESIGN) WHICH TREATS 36X OF THE GAS WITH LIMESTONE.   OPERATIONS COMMENCED
IN MARCH, 1981.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT  175 MM (GROSS)
          175 MM (ESC)
COAL
  .75 XS  SUBBITUMINOUS
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  ***«X
STATUS 1     STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1. 2, AND 3 IN FARMINGTON,  NEW MEXICO TO HANDLE ADDITIONAL
SOS REMOVAL. THE FRONT FIRED, DRY BOTTOM,  PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 6650 BTU/LB) UNITS 1  AND 2 SUPPLY 814,000 ACFM EACH
INTO 2 GEESI VENTURI SCRU23ERS PER UNIT FOP PRIMARY PARTICLE CCNTPOL
AND APPROXIMATELY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AN3 ALKALINE FLY ASH
SCRUBBING IS 67.5X. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
RETROFIT  175 MM (GROSS)
          175 MM (ESC)
COAL
  .75 XS  SU5BITUMINOUS
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
ENEPGY CONSUMPTION:  ***«x
STATUS 1     STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUS3ERS
AT FOUR CORNERS 1,2, AND 3 IN FARMINGTON,  NEW MEXICO TO HANDLE ADDITIONAL
S02 REMOVAL. THE FRONT FIRED, DRY BOTTOM,  PULVERIZED COAL (SL3-
BITUMINOUS. 0.75X S, 8650 BTU/LB) UNITS 1  AND 2 SUPPLY 814,000 ACFM EACH
INTO 2 GEESI VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICLE CONTROL
AND APPROXIMATELY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN SOZ
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67.5X. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
3
RETROFIT  229 MM (GROSS)
          229 MM (ESC)
COAL
  .75 XS  SUB3ITUMINOUS
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  ***»X
STATUS 1     STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1,2, AND 3 IN FAPMIN5TON,  NEW MEXICO TO HANDLE ADDITIONAL
S02 REMOVAL. THE FRONT FIRED, DRY BOTTOM,  PULVERIZED COAL (SU3-
BITUMINOUS, 0.75X S, 6650 BTU/LB) UNIT 3 SUPPLIES 1,033,000 ACFM INTO 2
INTO 2 GEESI VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICLE CONTROL
LY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02 REMOVAL EFFICI-
ENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH SCRUBBING IS 67.5X.
OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
4
RETROFIT  755 MM (GROSS)
          755 MM (ESC)
COAL
  .75 XS
LIME
BABCOCK £ HILCOX
ENERGY CONSUMPTION:  »***X
STATUS 2     STARTUP 12/84
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO BABCOCK £ MILCOX F03 A LIME
FGO SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND 5 AT ITS FC'J=! CORNERS STA-
TION IN FARMINGTON, NEW MEXICO. ALTHOUGH INITIAL PLANS CALLED FOR THE IN-
STALLATION OF HORIZONTAL ABSORBERS, THE B £ M SYSTEM WILL INCLUDE VERTICAL
SPRAY TOWERS TO CONTROL EMISSIONS FROM THESE COAL (0.75X S, SS50 BTU/LB)
FIRED UNITS.  THE PARTICULATE EMISSIONS ARE HANDLED BY AN ESP. START-UP IS
EXPECTED IN DECEMBER 1984.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5
RETROFIT  755 MM (GROSS)
          755 MM (ESC)
COAL
  .75 XS
LIME
BABCOCK £ WILCOX
ENERGY CONSUMPTION:  «cn»X
STATUS 2     STARTUP 12/84
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO BABCOCK £ MILCOX FC° A LIME
FGD SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND 5 AT ITS FOUR CORNERS STA-
TION IN FARMINGTON, NEW MEXICO. ALTHOUGH INITIAL PLANS CALLED FOR THE IN-
STALLATION OF HORIZONTAL ABSORBERS, THE B £ M SYSTEM WILL INCLUDE VERTICAL
SPRAY TOWERS TO CONTROL EMISSIONS FROM THESE COAL (0.75X S, 8650 BTU/LB)
FIRED UNITS.  THE PARTICULATE EMISSIONS ARE HANDLED BY AN ESP. START-UP IS
EXPECTED IN DECEMBER 1984.
                                                10

-------
                                              EPA UTILITY F6D  SURVEY:  OCTOBER  - OECEMSER  1981
                                             SECTION 2
                                       STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
ASSOCIATED ELECTRIC
ThCMAS HILL
3
MEM       730 KM (GROSS)
          670 MW (ESC)
COAL
 4.60 XS
LIMESTONE
H.U. KELL05S
ENERGY CONSUMPTION: *««*X
STATUS 2     STARTUP  1/82
THOMAS HILL 3 OF ASSOCIATED ELECTRIC COOP IS A FULVEFIZE3 COAL (4.6X S,
9,700 BTU/LB) FIRED UMIT UNDER CONSTRUCTION IN KC3ERLY, MISSC'JPI. TV.O COLO
SIDE ESP'S HILL PRECEDE THE FOUR 91.5X EFFICIENT M. U. KELLC33 HCRIZCN-
TAL WEIR FGO MODULES USIN3 MAG-PROMOTED LIMESTONE AS THE AgSC'BHNT. THE
CLEANED GAS WILL PASS THROUGH A VERTICAL CHEVRCN MIST ELIMINATCR TO A eJO
FOOT BRICK LINED STACK. REHEAT MILL BE ACCOMPLISHED 3Y FLUE GAS 3YPASS.
FIXATED SLUDGE WILL BE TRUCKED TO AN ACTIVE STFIP MINE. THE SfSTEM WILL
OPERATE IN A CLOSED MATER LOOP. THE FGD SYSTEM IS UNDE1? CONSTRUCTION AND
START-UP IS EXPECTED IN JANUARY 1982.
ATLANTIC CITY ELECTRIC
CUMBERLAND
1
HEM       330 MM (GROSS)
          330 MM (ESC)
COAL
 3.25 XS  BITUMINOUS
PPCCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *««»X
STATUS 6     STARTUP  1/88
CUMBERLAND 1 IS A PULVERIZED COAL (3.25X S) FIRED BOILER TO B£ LCCATED IN
MILVILLE, HEM JERSEY.  THE UTILITY IS CONSIDERING A TKRCHAWAY PRODUCT
FGO SYSTEM FOR 502 CONTROL. OPERATIONS ARE SCHEDULED TO BEGIN IN
JANUARY 1988.
BASIN ELECTRIC POWER
ANTELOPE VALLEY
1
NEM       440 MM (GROSS)
          440 MM (ESC)
COAL
  .68 XS  LIGNITE
LIME/SFRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ««*«X
STATUS 2     STARTUP 10/83
UNIT 1 OF BASIN ELECTRIC POMER COOP'S ANTELOPE VALLEY PLANT IS PRESENTLY
UNDER CONSTRUCTION IN BEULAH. NORTH DAKOTA. THIS UNIT MILL BURN PULVERIZED
COAL (0.68X S, 6600 BTU/LB LIGNITE) AND SUPPLY 2.055,000 ACFM TO A D"5Y
LIME FGD SYSTEM SUPPLIED BY WESTERN PRECIPITATION. THE 62X EFFICIENT
SYSTEM MILL CONSIST OF 5 NIRO ATOMIZER SPRAY DRYERS AND TWO BAG-HOUSES.
THE CLEANED GAS. ALONG WITH A 4X BYPASS REHEAT, WILL EXIT A 600 FOOT
PVC LINED STACK. THE DRY POWDER GENERATED BY THIS CLOSED MATER LCCP
SYSTEM WILL BE USED FOR LANDFILL IN A COAL MINE. START-UP IS EXPECTED
IN OCTOBER 1963.
BASIN ELECTRIC POWER
ANTELOPE VALLEY
2
NEM       440 MM (GROSS)
          440 MM (ESC)
COAL
  .68 XS  LIGNITE
LIME/SFRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 2     STARTUP 10/85
ANTELOPE VALLEY 2 OF BASIN ELECTRIC POMER COOP HILL BE LOCATES IN BEULAH,
NORTH DAKOTA. JOY/NIRO HAS BEEN AWARDED A CONTRACT FOR THIS LIGNITE
(0.68X S, 6600 BTU/LB) FIRED UNIT.  THE UNIT HILL BE REQUIRED TO CCM°LY
WITH STATE EMISSIONS STANDARDS VIA BEST AVAILABLE CONTROL TECHNCLC5Y.
START-UP IS SCHEDULED FOR OCTOBER 1985.
BASIN ELECTRIC POWER
LARAMIE RIVER
1
NEM       570 MW (GROSS)
          570 MM (ESC)
COAL
  .81 XS  SU3BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ***»•/.
STATUS 1     STARTUP  7/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 1 IS A PULVERIZED COAL
(0.9X S, 8139 BTU/LB) FIRED UNIT LCCATED IN U'HEATLAND, WYOMING.
THE BOILER FEEDS 2,300,000 ACFM OF FLUE GAS THROUGH A COLD SIDE
ESP TO FIVE RESEARCH COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH
REMOVE 90X OF THE S02. THE CLEANED GAS EXITS FROM A VERTICAL CHEVSCN
MIST ELIMINATOR INTO A 600 FOOT ACID BRICK LINED STACK.  NO REHEAT IS
USED.  THE FLYASH FIXATED SLUDGE IS OEWATEREO TO 83X SOLIDS BEFCRE BEING
LAMDFILLED. AND THE SYSTEM EMPLOYS A CLOSED HATER LOOP. OPERATIONS
BEGAN ON JULY 1, 1980.
BASIN ELECTRIC POWER
LARAMIE RIVER
2
HEW       570 MM (GROSS)
          570 MM (ESC)
COAL
   .81 XS  SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: »»«*X
STATUS 1     STARTUP  7/81
BASIN ELECTRIC POMER COOP'S LARAMIE RIVER 2 IS A NEM UNIT LOCATED
IN WHEATLAND, WYOMING. THE PULVERIZED COAL (0.81X S, 8139 BTU/LB)
FIRED BOILER FEEDS 2,300,000 ACFM OF FLUE GAS THROUGH A COLO SIDE
ESP TO FIVE RESEARCH-COTTRELL LIMESTONE PACKED TOWER MODULES, UHICH
REMOVE 90X OF THE S02. THE CLEANED GAS EXITS FRCM A VERTICAL CHEVCN
MIST ELIMINATOR INTO A 600 FOOT ACID BRICK LINED STACK.  NO REHEAT IS
USED.  THE FLYASH FIXATED SLUDGE IS DEMATEREO TO 83X SOLIDS 5EFOSE
BEING LANOFILLED IN THIS CLOSED MATER LOOP SYSTEM. START-UP TCOK PLACE
IN JULY 1981.
                                                11

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
B4SIH ELECTRIC FCWER
LAPAMIE RIVER
3
NEW       570 MM (GROSS)
          570 MM (ESC)
COAL
  .54 XS  SU33ITUMINOUS
LI-IE/SFRAY D5YIN3
BASCOCK & UILCCX
ENERGY CONSUMPTION: ****•/.
STATUS 2     STARTUP 11/82
LAHAMIE RIVER 3 OF BASIN ELECTRIC POUER CCOP IS UNDER CONSTRUCTION IN
UHEATLAN3, WYOMING, AND WILL UTILIZE FOUR DRY LIM£ INJECTION ."Cr'JLES,
AND A COLD SIDE ESP. THE BOILER WILL FIRE PULVERIZED COAL (3.5« S.
81CO BTU/LB) AMD WILL SUPPLY 2,SCO,000 ACFM OF FLUE GAS TO THE FC-D
SYSTEM, WHICH HILL REMOVE 85X OF THE S02 BEFCBE THE GAS EXITS TH?CL'3H
A 600 FOOT ACID BRICK LIKED STACK. A 3X BYPASS MILL BE USE9 FCR REHEAT.
THE SYSTEM WILL OPERATE IN A CLOSED KATES LOOP. AN3 THE DRY PC'-DE1? WASTE
WILL BE LANOFILLEO. OPERATIONS ARE SCHEDULED TO COMMENCE IN NOV. ISSC.
BIG RIVERS ELECTRIC
O.B. WILSON
1
NEW       440 KM (GROSS)
          440 MM (ESC)
COAL
•»»-*•* XS  BITUMINOUS
LIMESTONE
M.M. KELLOS3
ENERGY CONSUMPTION: **»*x
STATUS 2     STARTUP  7/84
BIG RIVERS ELECTRIC HAS PLANS FOR TWO NEW UNITS, D.B. WILSON 1 AND 2.
THE PULVERIZED COAL FIRED BOILERS MILL HAVE A MM RATING C.: 440 EACH.
THE WET LIMESTONE FGO SYSTEM FOB UNIT 1 IS CURRENTLY UNDER CONSTRUCTION.
START-UP IS SCHEDULED FCR JULY 1984.
BIG PIVERS ELECTRIC
D.B. WILSON
2
NEW       440 MM (GROSS)
          440 MM (ESC)
COAL
**«»» XS  BITUMINOUS
LIMESTONE
M.H. KELLOGG
ENERGY CONSUMPTION: »**»X
STATUS 3     STARTUP  O/ 0
BIG RIVERS ELECTRIC HAS PUNS FOR TWO NEW UNITS, O.B. WILSON 1 AND 2.
THE PULVERIZED COAL FIRED BOILERS MILL HAVE A MM RATING CF 440 EACH.
tl. M. KELLOG HAS BEEN AWARDED A CONTRACT FOR A WET LIMESTONE FGD
SYSTEM.  START-UP HAS BEEN DEFERRED INDEFINITELY.
BIG RIVERS ELECTRIC
GREEN
1
NEH       242 MM (GROSS)
          242 MM (ESC)
COAL
 3.75 XS  BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: «***x
STATUS 1     STARTUP 12/79
UNIT 1 OF BIG RIVERS ELECTRIC'S GREEN STATION IS LOCATED IN
SEBREE,KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75X S, 9750 BTU/LB)
FIRED BOILER SUPPLIES 1,000,000 ACFM TO A COLD SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH REMOVE 90X CF THE
S02. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND
EXITS A SAUERISEN 72 LINED STACK AFTER IT IS HEATED BY A STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED HATER LOOP SYSTEM IS POZ-0-TEC
STABILIZED. OPERATIONS COMMENCED IN DECEMBER 1979.
BIG RIVERS ELECTRIC
G'EEN

NEW       242 MM (GROSS)
          242 MM (ESC)
COAL
 3.75 XS  BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: «»**X
STATUS 1     STARTUP 11/80
UNIT 2 OF BIG RIVERS ELECTRIC'S GREEN STATION IS LOCATED IN SESREE,
KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75X S, 9750 BTU/LB)
FIRED BOILER SUPPLIES 1,000,000 ACFM TO A COLD SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWEPS WHICH REMOVE 90X CF THE
S02. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AMD
EXITS A SAUERISEN 72 LINED STACK AFTER IT IS HEATED BY A STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM IS POZ-0-TEC
STABILIZED. OPERATIONS COMMENCED IN NOVEMBER 1980.
CAJUN ELECTRIC POWER
CHICOT
1
NEM       562 MM (GROSS)
          562 MM (ESC)
LIGNITE
 1.70 XS
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***X
STATUS 6     STARTUP  0/86
CAJUN ELECTRIC POWER CCOP HAS PLANS FOR A NEM UNIT, CHICOT 1, TO BE
LOCATED IN SHREVEPORT, LOUISIANA.  THE UTILITY IS CONSIDERING A DRY
SCRUBBING FGD SYSTEM FOR EMISSION CONTROL FROM THE LIGNITE FIRED BOILER.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1986.
                                                12

-------
                                              EPA  UTILITY  F60  SURVEY:  OCTOBER - CECEK2ER  1981
                                             SECTION 2
                                       STATUS OF  F6D SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
CAJUN ELECTRIC POKER
CHICOT
Z
NEM       562 MM (G=OSS)
          562 MM (ESC)
LIGNITE
 1.70 XS
PROCESS NOT SELECTED
VEUDO1? NOT SELECTED
ENERGY CONSUMPTION: *«*»X
STATUS 6     STARTUP  0/88
CAJUN ELECTRIC POWER COOP HAS PLANS FOR A NEH UNIT, CHICOT 2, TC 5=
LOCATED IN SHREVEPCRT, LOUISIANA.  THE UTILITY IS CCNS:2E.-ZN5 A C-f
SCPUE3IN3 F6D SYSTEM FOR EMISSION CONTROL FROM THE LIGNITE FISEO EXILES.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 19S8.
CAJUN ELECTRIC POWER
CHICOT
3
HEM       562 MM (GROSS)
          562 MM (ESC)
LIGNITE
 1.70 XS
PROCESS MOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***X
STATUS 6     STARTUP  0/93
CAJUN ELECTRIC POWER COOP HAS PLANS FOR A HEW UNIT, CHICOT 3, TO BE
LOCATED IN SHREVEPORT, LOUISIANA.  THE UTILITY IS CONSIDERING A DRY
SCRUBBING FGD SYSTEM FOR EMISSION CONTROL FROM THE LIGNITE FIRED BOILER.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1992.
CAJUN ELECTRIC POWER
CHICOT
4
HEW       562 MM (GROSS)
          562 MM (ESC)
LIGNITE
 1.70 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »«»»X
STATUS 6     STARTUP  0/94
CAJUN ELECTRIC POMER COOP HAS PLANS FOR A NEM UNIT, CHICOT 4, TO GE
LOCATED IN SHREVEPORT, LOUISIANA.  THE UTILITY IS CONSIDERING A CRY
SCRUBBING FGD SYSTEM FOR EMISSION CONTROL FROM THE LIGNITE FIRED BOILER.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1994.
CAJUN ELECTRIC POWER
OXBOM
1
NEM       540 MM (GROSS)
          540 MM (ESC)
COAL
  .60 XS  LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «***X
STATUS 5     STARTUP  0/85
CAJUN ELECTRIC HAS PLANS TO CONSTRUCT A 540 MM UNIT, OXBOW 1, TO EE LCCAT-
ED IN OE SOLO PARISH, LOUISIANA.  THE UTILITY IS REQUESTING BIDS FCR A DRY
SCRUBBING PROCESS TO CONTROL EMISSIONS FROM THE PULVERIZED COAL FIPED
BOILER.  THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN 1965.
CAJUN ELECTRIC POMER
OXBOM
2
NEM       540 MM (GROSS)
          540 MM (ESC)
COAL
  .60 XS  LIGNITE
FPCCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »**»X
STATUS 6     STARTUP  0/85
CAJUN ELECTRIC HAS PLANS TO CONSTRUCT A 540 MM UNIT, OXECV4 2, TO BE
LOCATED IN OE SOLO PARISH, LOUISIANA.  THE UTILITY IS PRESENTLY CONSIDER-
ING A DRY SCRUBBING PROCESS TO CONTROL EMISSIONS FROM THE PULVERIZED
COAL FIRED BOILER.  OPERATIONS ARE SCHEDULED TO COMMENCE IN 1985.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
NEM       416 KM (GROSS)
          416 MM (ESC)
COAL
 3.66 XS  BITUMINOUS
LIMESTONE
ENVIPONEERING. RILEY STOKER
ENERGY CONSUMPTION:  2.9X
STATUS 1     STARTUP  7/76
DUCK CREEK 1 OF CENTRAL ILLINOIS LIGHT IS LOCATED IN CANTCN. ILLINOIS. THE
BALANCED DRAFT, FRONT FIRED, DRY BOTTOM UNIT BURNS PULVERIZED BITUMINOUS
COAL (3.66X S, 10,500 BTU/LB) AND SUPPLIES 2,415,000 ACFM OF FLUE GAS TO
TWO COLD SIDE ESP'S FOLLOWED BY FOUR RILEY STCKER/ENVIRCNEEPIN3 EC3 CECK
SPRAY TCMER MODULES. THE FGO SYSTEM HAS BEEN OPERATIONAL (AT LEAST CNE
MODULE) SINCE JULY, 1976. IT IS DESIGNED TO REMOVE 85X OF THE S02. HC=I-
ZONTAL CHEVRON MIST ELIMINATORS FOLLOW THE ABSORBERS, AND THE CLEANED GAS
EXITS TO A 500 FOOT CEILCOTE LINED STACK HITHOUT REHEAT. THE SYSTEM OPER-
ATES A CLOSED MATER LOOP, AND THE SLUDGE IS DISPOSED OF IN AN ON-SITE CLAY
LINED POND.
                                                13

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 EPA UTILITY FGO SURVEY: OCT03ER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
CENTRAL ILLINOIS LIGHT
DUCK CREEK
2
HEW       450 MM (G°OSS)
          450 MM (ESC)
COAL
 5.30 XS  BITUMINOUS
LI11ESTCNE
VEIJ30R NOT SELECTED
ENERGY CONSUMPTION: «»»«X
STATUS 6     STARTUP  1/87
CENTRAL ILLINOIS LIGHT IS CURRENTLY INVESTIGATING A LIMESTONE CR DUAL
ALKALI FGD SYSTEM FOR UNIT 2 AT ITS DUCK CREEK STATION.  THE 3ITUMIN3US
COAL FIRED BOILER MILL FEED ITS FLUE GAS THROUGH A COLD  SIDE ESP. THE
SYSTEM MILL OPERATE IN A CLOSED WATER LOOP AND IS SCHEDULED TO BEGIN
OPERATIONS IN JANUARY 1987.
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
MEM       617 MM (GROSS)
          617 MM (ESC)
COAL
 2.25 XS  BITUMINOUS
DUAL ALKALI
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  2.4X
STATUS 1     STARTUP  9/79
NEWTON 1 OF CENTRAL ILLINOIS PUBLIC SERVICE IS A TANGENTIALLY FIRED, DRY
BOTTOM, PULVERIZED BITUMINOUS COAL (2.25X S, 10,900 BTU/L3) FIRED UNIT
LOCATED IN NEHTON, ILLINOIS. A COLO SIDE ESP RECEIVES 2,165,460 ACrM
OF FLUE GAS AND FEEDS IT TO FOUR GEESI POLYSPHERE PACKED TRAY TCHES
ABSORBERS FOLLOMED BY TWO VERTICAL MIST ELIMINATORS PER MODULE. THE
CLEANED GAS IS BOOSTED 25 DEC F BY A COMBINATION OF TWO DIFFERENT TYPES
OF IN-LINE REHEATERS PLUS BYPASS REHEAT, AND THEN EXITS A 530 FCOT
PRECRETE-LINEO STACK. THE WATER LOOP IS CLOSED, AND THE SLL3GE IS
POZ-0-TEC TREATED.
CENTRAL MAINE POWER
SEARS ISLAND
1
NEM       600 MM (GROSS)
          600 MM (ESC)
COAL
 2.23 XS  BITUMINOUS
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»*«X
STATUS 6     STARTUP 11/89
SEARS ISLAND 1 IS A PLANNED UNIT TO BE BUILT ON PENOBSCOT BAY BY CENTRAL
MAINE POWER. BECAUSE OF THE DISCOVERY OF A GEOLOGICAL FAULT CN SEARS
ISLAND, PLANS FOR A 1150 MM NUCLEAR POWER PLANT HAVE BEEN REPLACED WITH
PLANS FOR A 600 MM COAL FIRED PLANT. LIME AND LIMESTONE SCRU3BIN3 ARE
THE PRIMARY METHODS BEING CONSIDERED FOR COMPLIANCE WITH THE NSPS. IT
MILL BE TWO YEARS BEFORE ALL PERMITS REQUIRED HAVE BEEN RECEIVED. START-
UP IS SCHEDULED FOR NOVEMBER 1939.
CENTRAL POWER t LIGHT
COLETO CREEK
2
NEM       720 MM (GROSS)
          720 MM (ESC)
COAL
  .39 XS  SUBSITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»»*X
STATUS 6     STARTUP  9/92
COLETO CREEK 2 OF CENTRAL POWER AND LIGHT IS A COAL (.39X5) FIRED UNIT
PLANNED FOR CONSTRUCTION IN FANNIN, TEXAS.  THE UNIT MILL BE BUILT 3Y
CENTRAL AND SOUTHWEST SERVICES, BUT MILL BE OPERATED BY CENTRAL POWER AND
LIGHT.  ONLY DRY SCRUBBING IS BEING CONSIDERED FOR S02 CCMTROL.  START-UP
IS TENTATIVELY SCHEDULED FOR SEPTEMBER 1992.
CINCINNATI GAS & ELECTRIC
EAST BEND
1
NEM       650 MM (GROSS)
          650 MM (ESC)
COAL
 4.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  2.9X
STATUS 6     STARTUP  0/88
CINCINNATI GAS AND ELECTRIC HAS PLANS FOR A NEM UNIT, EAST BEND 1, TO
BE LOCATED ADJACENT TO EAST BENT 2 AT THE RABBITHASH, KENTUCKY SITE.  THE
COAL FIRED BOILER WILL HAVE A GENERATING CAPACITY OF 650 MM.  THE UNIT IS
SCHEDULED TO START-UP IN 1988.
CINCINNATI GAS t
EAST BEND
2
NEW
                 ELECTRIC
          650 MM (GROSS)
          650 MM (ESC)
COAL
 3.00 XS
LIME
BABCOCK i MILCOX
ENERGY CONSUMPTION:  2.9X
STATUS 1     STARTUP  3/81
EAST BEND 2 OF CINCINNATI GAS AND ELECTRIC IS A PULVERIZED COAL (5X S,
DESIGN) FIRED BOILER LOCATED IN RABBITHASH, KENTUCKY.  THE EMISSION CON-
TROL SYSTEM CONSISTS OF A HOT SIDE ESP FOLLOWED BY THREE BA5CCCK AND~«ILCO
LIME FGD MODULES.  THE CLEANED GAS. «7X S02 REMOVAL. PASSES THROUGH A     J
CHEVRON MIST ELIMINATOR BEFORE BEING HEATED BY AN INDIRECT HOT AIR        -
REHEATER AND EXITS THROUGH A BRICK LINED 650 FOOT STACK.  THE SLUDGE FROM
THIS CLOSED HATER LOOP IS POZ-0-TEC STABILIZED BEFORE DISPOSAL IN AN ON-
SITE LANDFILL. OPERATIONS COMMENCED IN MARCH 1981.
                                                14

-------
                                             EPA UTILITY FGD SUPVEY: OCTC3EH  -  DECEMBER  1931
                                            SECTION 2
                                      STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
                                                                ABSTRACT
COLORADO UTE ELECTRIC
CRAIG
1
NEW       455 MM (GROSS)
          410 MH (ESC)
COAL
  .45 XS  SU3SITUMINOUS
LIMESTONE
PEA30DY PROCESS SYSTEMS
ENE=GY CONSUMPTION:   i.ix
STATUS 1     STARTUP 10/80
THE COLORADO UTE ELECTRIC ASSN HAS CONSTRUCTED A NEW UNIT, CPAIG 1, LCCAT-
ED IN CRAIG. COLORADO.   BOTH UNITS FIRE PULVERIZED SVSSITUMIf^'JS CCAL
(0.45X S, 10,000 BTU/LB).  THE EMISSION CCMTPOL SYSTEM FC3 THIS UNIT CON-
SISTS OF A HOT SICE ESP AND FOUR LIMESTONE SF3AY TCWE=S rCR PEKOVAL OF
PARTICULATE MATTER AND  85X OF THE SOI.   THE SCPUEEER EXHAUST IS HEATE3 3Y
A BYPASS REHEATER AND PASSES THROUGH A 600 FCOT ACID LIMES STACK.  THE
SYSTEM OPERATES IN A CLOSED MATER LOOP AND THE STABILIZED SLUCGE IS CIS-
FOSED OF IN AN OFF-SITE MIHEFILL.  UNIT 1 START-UP IS EXPECTED IN CCTC3ER
1930.
COLORADO UTE ELECTRIC
CRAIG
2
HEW       455 MM (GROSS)
          410 MV1 (ESC)
COAL
  .45 XS  SUBBITUMINOUS
LIMESTONE
FEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION:  -2.OX
STATUS 1     STARTUP 12/79
THE CRAIG 2 UNIT OF THE COLORADO UTE ELECTRIC ASSN IS LOCATED IN CRAIG,
COLORADO AND FIRES PULVERIZED SUBBITUMINOUS COAL (0.4SXS, 10,COO BTU/LB).
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP AND
FOUR LIMESTONE SPRAY TOUERS FOR REMOVAL OF PARTICULATE  MATTER A.'iO 85X
OF THE 502.  THE SCRUBBER EXHAUST IS HEATED BY A BYPASS REHEATED AND
PASSES THROUGH A 600 FOOT ACID BRICK LINED STACK.  THE Si STEM OFHPATES IN
A CLOSED LOOP, AND THE STABILIZED SLUDGE IS DISPOSED OF IN AN OFF-SITE
MINEFILL.  START-UP OF UNIT 2 MAS IN DECEMBER 1979.
COLORADO UTE ELECTRIC
CRAIG

HEM       447 MM (GROSS)
          447 MM (ESC)
COAL
  .45 XS  SUBBITUMINOUS
LIME/SPRAY CRYING
BABCOCK & MILCOX
ENEPGY CONSUMPTION:  «i«*X
STATUS 2     STARTUP  4/B3
CRAIG 3 OF COLORADO UTE ELECTRIC ASSN. IS UNDER CONSTRUCTION IN CRAIG,
COLORADO. THE UNIT HILL FIRE PULVERIZED SU3BITUMIHOUS COAL (0.45X S.
10,000 BTU/LB). THE DRY SCRUBBING SYSTEM UTILIZIMS LIME INJECTION WILL
BE SUPPLIED BY BABCOCK AND MILCOX. THE UNIT MILL HAVE A FABRIC FILTER FOR
PARTICULATE MATTER CONTROL. OPERATION OF THE FGO SYSTEM IS SCHEDULED TO
COMMENCE IN 1983.
COLUMBUS & SOUTHERN OHIO ELEC
CONESVILLE
5
HEM       411 MM (GROSS)
          411 MM (ESC)
COAL
 4.67 XS  BITUMINOUS
LIME
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION:  3.9X
STATUS 1     STARTUP  1/77
CONESVILLE 5 OF COLUM&US AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.67X S, 10,650 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLO SIDE ESP RECEIVES 1.393,893 ACFM OF FLUE
GAS AN3 PASSES IT TO TWO THIOSORBIC LIME TCA MODULES SUPPLIED BY UCP.
THE S02 REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH BEGAN INITIAL
OPERATION IN JANUARY 1977, IS 89.5X (DESIGN). EACH MODULE HAS ONE
BULK ENTRAPMENT SEPARATOR AND TMO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 800 FOOT ACID BRICK LINED STACK. THE
POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AH CN-SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN MATER LOOP.
COLUMBUS & SOUTHERN OHIO ELEC
CONESVILLE
6
HEM       411 MM (GROSS)
          411 MM (ESC)
COAL
 4.67 XS  BITUMINOUS
LIME
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION:  3.9X
STATUS 1     STARTUP  6/78
CONESVILLE 6 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.67X S, 10,850 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TMO THIOSCRBIC LIME TCA MODULES SUPPLIED BY UOP.
THE S02 REMOVAL EFFICIENCY OF THE TMO MODULES, WHICH BEGAN INITIAL
OPERATION IN JUNE 1978, IS 89.5X (DESIGN). EACH MODULE HAS ONE
BULK ENTRAINMENT SEPARATOR AND TMO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 800 FOOT ACID BRICK LINED STACK. THE
POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON-SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN MATER LOOP.
COLUMBUS I SOUTHERN OHIO ELEC  COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TMO NEM UNITS, POSTON S
POSTON
5
NEW       425 MM (GROSS)
          375 MM (ESC)
COAL
***** XS
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  4.7X
STATUS 6     STARTUP  8/86
AW 6, TO BE LOCATED IN ATHENS, OHIO. THE COAL (2.5X S. 11,000 BTU/LB)
FIRED UNITS HILL UTILIZE EITHER A LIME, LIMESTONE, OR DUAL ALKALI FGD
SYSTEM. START-UP OF UNIT 5 IS EXPECTED IN 1986.
                                                15

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF  FGD SYSTEMS
UHIT IDENTIFICATION
                                                                ABSTRACT
COLUMBUS « SOUTHERN OHIO ELEC
PQSTCN
6
tiZU       425 HW (GPOSS)
          375 MM (ESC)
COAL
 2.50 y.S
FPCCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  4.7X
STATUS 6     STARTUP  0/89
COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS  PLANS  FC3  TUO NEW UNITS,  FCSTCN 5
AND 6, TO BE LOCATED IN ATHENS.  OHIO. THE  COAL (2.5X S.  11,000  BTU/LB)
FIRED UNITS MILL UTILIZE EITHER  A LIME,  LIMESTONE,  CR DUAL ALKALI FGD
SYSTEM. START-UP OF UNIT 6 IS EXPECTED IN  1939.
COMMONWEALTH EDISON
PCWERTON
51
RETROFIT  450 MM (GROSS)
          450 KM (ESC)
COAL
 3.53 XS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION:  s.ex
STATUS 1     STARTUP  4/80
COMMONWEALTH EDISON HAS RETROFITTED BOILER  NUMBER  SI AT ITS PCWERTOH
STATION WITH A UOP LIMESTONE FGD SYSTEM.  UNIT 51 IS ONE OF TWO IDENTICAL
BOILERS SUPPLYING STEAM TO AN 850 MW TURBINE.  THE  PULVERIZED COAL
(3.53X S, 10,500 BTU/LB) FIRED BOILER FEEDS FLUE GAS THROUGH AM ESP
TO 3 TCA MODULES WHICH ARE DESIGNED TO REMOVE 7«»X  OF THE SQZ. A STEAM
INDIRECT HOT AIR REHEATER BOOSTS THE TEMPERATURE BEFORE THE GAS EXITS
AN ACID BRICK LINED STACK. THE SYSTEM OPERATES IN  A CLOSED WATER LOOP,
AND THE SLUDGE IS FOZ-0-TEC STABILIZED AND  DISPOSED OF  IN A LANDFILL.
THE FGD SYSTEM COMMENCED OPERATION IN APRIL, 1980.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
1
NEM       545 MM (GROSS)
          327 MM (ESC)
COAL
  .63 XS  LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****•/.
STATUS 1     STARTUP  7/79
COAL CREEK 1 AND 2 ARE TWO PULVERIZED LIGNITE (0.63/C S,  6253 BTU/LS) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AND UNITED POWER. A COLD SIDE
ESP RECEIVES 2,200,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FOUR COUNTER-
CURRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED BY A BULK EHTRAIISIEHT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40X BYPASS REHEAT
IS PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT ACID ERICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
OPERATES IN AN OPEN HATER LOOP, AND THE FLYASH STABILIZED SLUDGE IS
DISPOSED IN A CLAY LINED POND.  UNIT 1 OPERATIONS BEGAN IN JULY 1979.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
2
NEH       545 MM (GROSS)
          327 MM (ESC)
COAL
   .63 XS  LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****x
STATUS 1     STARTUP  7/80
COAL CREEK 1 AND 2 ARE TUO PULVERIZED LIGNITE (0.63X S, 6258 BTU/LB) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AMD UNITED POWER. A COLD SIC'
ESP RECEIVES 2,200,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FCUR COUNTER-
CURRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED BY A BULK ENTRAINMENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40X BYPASS REHEAT
IS PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT ACID BRICK
LINED STACK. THE TOWER DESIGN 502 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
OPERATES IN AN OPEN HATER LOOP, AND THE FLYASH STABILIZED SLUDGE IS
DISPOSED OF IN A CLAY LINED POND. UNIT 2 COMMENCED OPERATIONS IN JULY
1980.
DELMARVA POWER & LIGHT
DELAWARE CITY
1
RETROFIT   60 MM (GROSS)
           60 MM (ESC)
COKE
 7.00 XS  BITUMINOUS
MELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: ***»/£
STATUS 1     STARTUP  5/80
DELAWARE CITY 1, 2, AMD 3 OF DELMARVA POWER AND LIGHT ARE THREE RETRO-
FITTED COKE (7-8X S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF SOCK
LB/HR EACH.  THE BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING.  EACH BOILER SUPPLIES 295,000 ACrM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUS3ER FCR P4RTICULATE
CONTROL.  THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMIKATCR
TO A WET ESP FOR BOTH PARTICULATE AND ACID MIST REMOVAL.  A FOUR STAGE
WELLMAN-LORD SYSTEM, WHICH IS DESIGN FOR 90X REMOVAL. IS USED FGR SC2 CON-
TROL.  HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS EXITS OUT A 500 FT.
STACK.  THE EMISSION CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE.  IT IS A
CLOSED LOOP HATER SYSTEM.  THE SYSTEM BECAME OPERATIONAL IN MAY 1960.
OELMARVA POWER t LIGHT
DELAWARE CITY
2
RETROFIT   60 MM (GROSS)
           60 MM (ESC)
CCKE
 7.00 XS  BITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: ****%
STATUS 1     STARTUP  5/80
DELAWARE CITY 1, 2, AND 3 OF DELMARVA POWER AND LIGHT ARE THREE RETRO-
FITTED CCKE (7-8X S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF 5COK
LB/HR EACH.  THE BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING.  EACH BOILER SUPPLIES 295,000 ACFM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUSSER FOR PARTICULATE
CCNTPOL.  THE FLUE GAS THEN PASSES THRCU3H A CHEVRON TYPE MIST ELIKINATCR
TO A WET ESP F03 BOTH PARTICULATE AND ACID MIST REMOVAL.  A FOUR STAGE
WELLMAN-LORD SYSTEM, WHICH IS DESIGN FOR 90X REMOVAL. IS USED FCR SC2 CON-
TROL.  HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS EXITS OUT A 500 FT.
STACK.  THE EMISSION CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE.  IT IS A
CLOSED LOOP MATER SYSTEM.  THE SYSTEM BECAME OPERATIONAL IN MAY 1980.
                                                16

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                                              EPA UTILITY  F6D SURVEY:  OCTOBER  -  DECEMBER  1931
                                             SECTION  2
                                       STATUS OF  FGD  SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
OELMARVA POWER I LIGHT
DELAWARE CITY
3
RETPOFIT   60 MW (GPOSS)
           60 MW (ESC)
COKE
 7.30 XS  BITUMINOUS
HELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION:  ****•/.
STATUS 1     STARTUP 5/80
DELAWARE CITY 1, 2, AND 3 OF DELMARVA POWER AND LIGHT ARE THPEE =ET=0-
FITTED COKE (7-8X S) FIRED BOILERS WHICH HAVE A STEAM CAPiCITf Or ECCK
LB/HR EACH.  THE BOILERS GENERATE STEAM AS WELL A3 ELECTRICITY FC? GETTY
REFINING AND MARKETING.  EACH BOILER SUPPLIES £95,000 ACFM Or FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCFU=BEH F03 PARTICULATE
CONTROL.  THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMIS'ATCR
TO A WET ESP FOR BOTH PAPTICULATE AND ACID MIST REMOVAL.  A FO'JP. STASE
WELLMAN-LOHD SYSTEM, WHICH IS DESIGN F0° 90X REMOVAL, IS USED FCR SC2 CON-
TROL.  HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS EXITS OUT A 500 FT.
STACK.  THE EMISSION CONTROL SYSTEM IS SUPPLIED BY DAVY rCKEE.  IT IS A
CLOSED LOOP MATER SYSTEM.  THE SYSTEM BECAME OPERATIONAL IN MAY 19SO.
DELMARVA POWER & LIGHT
VIENNA
9
NEU       550 MM (GROSS)
          550 MW (ESC)
COAL
 2.50 XS  BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  2.7X
STATUS 6     STARTUP 5/90
DELMARVA POWER AND LIGHT IS PLANNING A NEW 550 MW (GROSS) UNIT, VIENNA 9,
BE CONSTRUCTED IN VIENNA, MARYLAND.  THE UTILITY IS PRESENTLY CONSIDERING
A LIMESTONE FGD UNIT FOR EMISSION CONTROL.  THE PULVERIZED COAL FIRED UNIT
WILL BURN COAL WITH AN AVERAGE SULFUR CONTENT OF 2.7X AND IS EXPECTED TO
COMMENCE OPERATIONS IN MAY 1990.
DESERET GEN & TRANS
BONANZA
1
NEW       410 MW (GROSS)
          410 MW (ESC)
COAL
  .50 XS  BITUMINOUS
LIMESTONE
COMSUSTICN ENGINEERING
ENERGY CONSUMPTION: »*»»X
STATUS 2     STARTUP 9/84
BONANZA (FORMERLY MOON LAKE) 1 IS A PULVERIZED COAL (.57. S, 10,500 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN VERNAL. UTAH.  THE FGD SYSTEM IS BEINS
SUPPLIED BY COMBUSTION ENGINEERING.  THE WET LIMESTONE SCRUS3ING SYSTEM
WILL HAVE AN S02 REMOVAL EFFICIENCY OF 95X.  THE SYSTEM WILL FEATURE A
BAGHOUSE SUPPLIED BY ECOLAIRE TO REMOVE 99.6X OF THE PARTICULATE MATTES.
THE UNIT WILL OPERATE IN A CLOSED WATER LOOP WITH SLUDGE DISPOSAL GN-SITE
IN A LANDFILL.  OPERATIONS ARE SCHEDULED TO COMMENCE IN SEPTEMBER 1984.
OESERET GEN
BONANZA
2
NEW
            & TRANS
          410 MW (GROSS)
          410 MW (ESC)
COAL
  .50 XS  BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»«*x
STATUS 5     STARTUP  0/88
BONANZA (FORMERLY MOON LAKE) 2 IS A PULVERIZED COAL ( .5X S, 10.500 BTU/LB)
FIRED UNIT PLANNED BY DESERET GENERATION t TRANS. COOP TO BE LCCATED IN
VERNAL, UTAH.  THE UTILITY IS ERESENTLY REQUESTING BIDS FOR A WET LIME-
STONE SCRUBBING SYSTEM HAVING AN S02 REMOVAL EFFICIENCY OF 95X. THE SYSTEM
WILL FEATURE A BAGHOUSE DESIGNED TO REMOVE 99.6X OF THE PARTICULATE.  THE
UNIT WILL OPERATE IN A CLOSED WATER LOOP WITH SLUDGE DISPOSAL ON-SITE
IN A LANDFILL.  OPERATIONS ARE SCHEDULED TO COMMENCE IN 1988.
OUQUESNE LIGHT
ELRAMA
1-4
RETROFIT
          510 MM (GROSS)
          510 MW (ESC)
COAL
      XS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  3.5X
STATUS 1     STARTUP 10/75
ELRAMA 1-4 OF DUQUESNE LIGHT CONSISTS OF FOUR PULVERIZED COAL (2.2X S,
11.350 BTU/LB) FIRED UNITS LOCATED IN ELRAMA. PENNSYLVANIA. THE EMISSION
CONTROL SYSTEM ON THIS SITE CONSISTS OF AN ESP FOLLOWED BY A MECHANICAL
COLLECTOR AND FIVE VARIABLE THROAT VENTURI LIME ABSORBER MODULES SUPPLIED
BY GEESI. WHICH ARE DESIGNED TO REMOVE 83X OF THE SC2 FROM THE FLUE GAS.
THE CLEANED GAS PASSES THROUGH A DIRECT OIL FIRED REHEATER BEFORE EXITING
A 400 FOOT ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER
LOOP, AND THE POZ-0-TEC STABILIZED SLUDGE IS HAULED TO AN OFF-SITE LAND-
FILL. THE SYSTEM HAS BEEN OPERATIONAL SINCE OCTOBER 1975.
CUQUESNE LIGHT
PHILLIPS
1-6
RETROFIT  408 MW (GROSS)
          408 MM (ESC)
COAL
 2.05 XS  BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  3.4X
STATUS 1     STARTUP  7/73
THE PHILLIPS POWER STATION OF DUQUESNE LIGHT CONSISTS OF SIX DRY BOTTOM
PULVERIZED COAL (1.92X S. 11,350 BTU/LB) FIRED UNITS LOCATED IN SOUTH
HEIGHT, PENNSYLVANIA. PARTICULATE CONTROL IS ACCOMPLISHED BY SIX ESP/
MECHANICAL COLLECTOR COMBINATIONS (ONE/BOILER). ONE TWO STAGE AND THREE
SINGLE STAGE VARIABLE THROAT VENTURI LIME FGO MODULES SUPPLIED BY GEESI
ARE DESIGNED TO REMOVE 83X OF THE S02 FROM THE FLUE GAS. TWO CHEVPCN MIST
ELIMINATORS/MODULE ARE FOLLOWED BY A DIRECT OIL FIRED REHEATER kHICH RAIS-
ES THE GAS TEMPERATURE BY 20 CE6 F BEFORE IT LEAVES VIA A 340 FCOT TALL
ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LCOP, AND
THE POZ-0-TEC STABILIZED SLUDGE IS TRUCKED TO AN OFF-SITE LANDFILL. THE
SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1973.
                                                17

-------
 EPA UTILITY FGO SURVEY: OCT03ER - DECEMBER 1931
                                             SECTION 2
                                       STATUS OF F6D SYSTEMS
UNIT I3ENTIFICATION
                                                                 ABSTRACT
EAST KENTUCKY POWER
J.K. SMITH
1
MEW       650 MW (GROSS)
          650 MM (ESC)
COAL
 1.50 XS  BITUMINOUS
LIME
BABCOCK & MILCOX
ENERGY CONSUMPTION: »«»*x
STATUS 3     STARTUP  8/87
THE EAST KENTUCKY POWER COOP HAS PLANS TO FIRE TU'O HEM UNITS, J.K. SKITH
1 AND Z. A CONTRACT MAS AWARDED TO BABCCCK AND UILCOX FC= A MET
LIME PROCESS TO CONTROL EMISSIONS. THE SYSTEM HILL OPERATE IN A CLOSED
MATER LOOP MODE.  START-UP FCR UNIT 1 IS EXPECTED IN 1937.
EAST KENTUCKY POWER
SPURLOCK
2
HEM       500 MM (GROSS)
          500 KU (ESC)
COAL
 3.50 XS
LIME
THYSSEN/CEA
ENERGY CONSUMPTION: *»*»X
STATUS Z     STARTUP  1/83
SPURLOCK 2 OF EAST KENTUCKY POWER COOPERATIVE IS A BALANCED CRAFT PULVER-
IZED COAL (3.5X S, 11 • 000 BTU/LB) FIRED  UNIT UKDER CONSTRUCTION IN MAYS-
VILLE, KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP FOL-
LOWED BY A THYSSEN/CEA LIME FGD SYSTEM (90X DESIGN S02 REMOVAL Err).
FLUE GAS FROM UNIT ONE WILL BE USED TO REHEAT THE CLEANED GAS. THE CLOSED
WATER LOOP SYSTEM, SLATED FOR START-UP IN 1983,  WILL EMPLOY A POZ-0-TEC
SLUDGE STABILIZATION FACILITY.
FLORIDA POWER 4 LIGHT
MARTIN
3
NEW       800 MW (GROSS)
          800 MW (ESC)
COAL
«**** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENEPGY CONSUMPTION: ****•/.
STATUS 6     STARTUP  0/87
FLORIDA POWER AND LIGHT HAS PLANS FOR TWO NEW UNITS, MARTIN 3 AND 4 TO BE
LOCATED IN MARTIN COUNTY, FLORIDA.  THE PULVERIZED COAL FIRED BOILERS
MILL HAVE A MM RATING OF 800 EACH.  THE UTILITY IS PRESENTLY CONSIDERING
ONLY FGO AS THE EMISSION CONTROL STRATEGY.  THE START-UP FCR UNIT 3 IS
PROJECTED FOR 1937.
FLOPIDA POWER I LIGHT
MARTIN
4
NEW       800 MM (GROSS)
          800 MM (ESC)
COAL
*««*» XS
PROCESS NOT SELECTED
VENCCR NOT SELECTED
ENERGY CONSUMPTION: ««»»X
STATUS 6     STARTUP  0/89
FLORIDA POWER AND LIGHT HAS PLANS FOR TOO NEW UNITS, MARTIN 3 AND 4 TO BE
LOCATED IN MARTIN COUNTY, FLORIDA.  THE PULVERIZED COAL FIRED BOILERS
MILL HAVE A MW RATING OF 800 EACH.  THE UTILITY IS PRESENTLY CONSIDERING
ONLY FGD AS THE EMISSION CONTROL STRATEGY.  THE START-UP FCR UNIT * IS
PROJECTED FOR 1989.
GENERAL PUBLIC UTILITIES
COAL
1
NEW       625 MW (GROSS)
          625 MW (ESC)
COAL
 3.50 XS
PROCESS NOT SELECTED
VENDOR NOT "ELECTED
ENERGY CONSUMPTION: »*»*X
STATUS 5     STARTUP  5/91
GENERAL PUBLIC UTILITIES HAS PLANS TO CONSTRUCT A 625 MM UNIT, COAL 1.
THE UTILITY IS PRESENTLY REQUESTING/EVALUATING BIDS FOR AN FGO SYSTEM TO
CONTROL EMISSIONS.  THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE
OPERATIONS IN MAY 1991.
GENERAL PUBLIC UTILITIES
COAL
2
NEW       625 MM (GROSS)
          625 MM (ESC)
COAL
 3.SO XS
PROCESS NOT SELECTED
VECTOR NOT SELECTED
ENERGY CONSUMPTION: nviHtx
STATUS 6     STARTUP  5/93
GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 625 MM UNIT, COAL 2.
THE UTILITY IS PRESENTLY CONSIDERING DHL  FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1993.
                                                18

-------
                                              EPA UTILITY FGO SURVEY:  CCTC3ER - DECEMBER 1931
                                             SECTION 2
                                       STATUS OF F63 SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
GENERAL PU3LIC UTILITIES
COAL
3
NEW       6£5 KM (GROSS)
          625 ru (ESC)
COAL
 3.50 XS
PSCCESS NOT SELECTED
VEK3C3 NOT SELECTED
ENERGY CONSUMPTION: wnn»X
STATUS 6     STARTUP  5/95
    GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 615 rw UNIT.  CC1L 3.
    THE UTILITY IS PRESENTLY CONSIDERING ONLY FGO AS THE EKISSIC'J CCNT=CL
    STPATEGY.  THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COGENCE OPZrATICNS
    IN 1995.
GENERAL PUBLIC UTILITIES
COAL
4
HEM       625 MM (GROSS)
          6Z5 KM (ESC)
COAL
 3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *»*»X
STATUS 6     STARTUP  5/96
    GENERAL PUBLIC UTILITIES HAS PLANS TO CONSTRUCT A 6£5 KM UNIT,  COAL 4.
    THE UTILITY IS PRESENTLY CONSIDERING ONLY FGO AS THE EKIS5ICN CCHTPOL
    STRATEGY.  THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
    IN 1996.
GENEPAL PUBLIC UTILITIES
SEMARD
7
NEW       690 KM (GROSS)
          690 KM (ESC)
COAL
***»* XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  9.4X
STATUS 5     STARTUP  5/39
    GENERAL PUBLIC UTILITIES IS PLANNING A NEM UNIT,  SEWAHO 7.  TO BE SUILT IN
    SEMARD, PENNSYLVANIA. THE UTILITY IS PRESENTLY REQUESTING BIDS FC3 AN FGO
    SYSTEM, WITH NON-SLURRY TYPE LIKE AND LIKESTONE SYSTEMS BEING THE
    PRIMARY CONSIDERATION. START-UP IS EXPECTED IN MAY 1939.
GRAND HAVEN BRO OF LIGHT t
J.B. SIMS
3
NEM        65 KM (GROSS)
           65 KM (ESC)
COAL
 2.75 XS  BITUMINOUS
LIME
BABCOCK & UILCOX
ENERGY CONSUMPTION: »«*»x
STATUS 2     STARTUP  1/83
PMR THE GRAND HAVEN BOARD OF LIGHT AND POWER'S J.B. SIMS 3 IS A BITU.1INIOUS
    COAL (2.75X S, 11,000 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN GPAKD
    HAVEN, MICHIGAN.  A CONTRACT HAS BEEN AMAROEO TO BAECCCK AMD UILCOX TO
    SUPPLY TWO SPRAY TOWERS TO CONTROL 502 EMISSIONS.  EACH SCRUBBER SYSTEM
    MILL UTILIZE A CHEVRON MIST ELIMINATOR AND AN IN-LINE REHEATER.   THE SYS-
    TEM MILL OPERATE IN A CLOSED WATER LOOP MODE AND THE SLUDGE HILL BE DIS-
    POSED OF IN AN OFF-SITE LANDFILL.  START-UP IS SCHEDULED FOR JAN. 1983.
HOOSIER ENERGY
RERCM
1
HEM       490 KM (GROSS)
          441 KM (ESC)
COAL
 3.50 XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: *«»*X
STATUS 2     STARTUP  5/82
    MEROM 1 AND 2 ARE TWO NEM UNITS BEING BUILT BY HC3SIER ENERGY IN SULLIVAN.
    INDIANA. THESE PULVERIZED COAL (3.5X S) FIRED UNITS WILL FHCDL'CE 1,732,000
    ACFM OF FLUE GAS WHICH MILL BE CLEANED BY A COLO SIDE ESP UPSTREAM OF A
    MITSUBISHI LIKESTONE GRID TOMER ABSORBER (90X DESIGN S02 REMOVAL). THE
    SYSTEM MILL UTILIZE BYPASS REHEAT AND A 700 FOOT STACK. THE SLUC3E WILL
    BE STABILIZED AND LAMDFILLED, AND THE SYSTEM MILL OPERATE IN A CLOSED
    MATER LOOP KOOE. START-UP OF UNIT 1 IS SCHEDULED FCR KAY 1982.
HOOSIER ENERGY
MEROM
2
NEM       490 KM (GROSS)
          441 KM (ESC)
COAL
 3.50 XS
LIKESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ««»»x
STATUS 1     STARTUP 12/81
    MEROM 2 IS A NEM UNIT BUILT BY HOOSIER ENERGY IN SULLIVAN. INDIANA. THIS
    PULVERIZED COAL (3.5X S) FIRED UNIT PRODUCES 866,000 ACFM OF FLUE GAS
    WHICH IS BEING CLEANED BY A COLD SIDE ESP UPSTREAM OF A MITSUBISHI
    LIMESTONE GRID TOWER ABSORBER (90X DESIGN S02 REMOVAL). THE SYSTEM
    UTILIZES BYPASS REHEAT AND A 700 FOOT STACK. THE SLUDGE IS BEING
    STABILIZED AND LANOFILLED, AND THE SYSTEM OPERATES IN A CLOSED MATER
    LOOP KOOE. UNIT 2 COMMENCED OPERATIONS IN DECEK5ER 1981.
                                                19

-------
 EPA UTILITY FGD SURVEY: OC7C3ER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF F5D SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
HOUSTON LIGHTING & POWER
LIMESTONE
1
MEW       750 MH (GPOSS)
          750 MM (ESC)
COAL
 1.03 XS  LIGNITE
LIMESTONE
CCMSUSTION ENGINEERING
ENE=GY CONSUMPTION *-m»Z
STATUS 3     STARTUP 12X86
HOUSTON LIGHTING AMD POWER CO HAS PLANS FOR TWO NEH UNITS, LIfSSTCME 1
AHO 2, TO BE LOCATED IN JEHITT, TEXAS.   THE PULVERIZED COAL (l.CSX S,
6177 BTU/LB) FIRED BOILER MILL UTILIZE  A WET LIMESTONE SCPU33IN3 PROCESS
FOR PRIMARY S02 COLLECTION.  A COLO SIDE ESP WILL ALSO Be USED FC3 PRIMARY
PARTICLE CONTROL.  THE UTILITY HAS AWARDED A CONTRACT TO CCrSUSTION ENGI-
NEERING FOR THE INSTALLATION OF THIS SYSTEM.  UNIT 1 IS SCHEDULED TO COM-
MENCE OPERATIONS IN 1936.
HOUSTON LIGHTING t POWER
LIMESTONE
2
NEW       750 MM (GROSS)
          750 MM (ESC)
COAL
 1.08 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »««»X
STATUS 3     STARTUP 12/87
HOUSTON LIGHTING AMD POWER CO HAS PUNS FOR TWO NEW UNITS, LIMESTONE 1
AND 2, TO BE LOCATED IN JEWITT, TEXAS.   THE PULVERIZED COAL (1.08X S,
6177 BTU/LB) FIRED BOILER HILL UTILIZE  A MET LIMESTONE SCRU33ING PROCESS
FOR PRIMARY S02 COLLECTION.  A COLD SIDE ESP MILL BE USED FOR PRIMARY
PARTICLE CONTROL.  THE UTILITY HAS AWARDED A CONTRACT TO COMBUSTION ENGI-
NEERING FOR THE INSTALLATION OF THIS SYSTEM.  UNIT 2 IS SCHEDULED TO COM-
MENCE OPERATIONS IN 1987.
HOUSTON LIGHTING & POWER
M.A. PARISH
8
NEW       600 MM (GROSS)
          492 MM (ESC)
COAL
  .60 XS  SUSBITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ****x
STATUS 2     STARTUP 11/82
M.A. PARISH 8 OF HOUSTON LIGHTING t POMER IS A PULVERIZED COAL (0.6X S.
8700 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN THOMPSONS. TEXAS.  GEESI
MILL SUPPLY A LIMESTONE FGD SYSTEM WHICH MILL REMOVE 82X OF THE FLUE
GAS S02. REHEAT MILL BE PROVIDED BY BYPASSING 18X OF THE PARTICULATE
CLEANED FLUE GAS. SLUDGE MILL BE DEWATERED, BLENDED MITH FLYASH, AND
DISPOSED OF IN AN ON-SITE LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE
IN NOVEMBER 1982.
INDIANAPOLIS POWER & LIGHT
PATRIOT
1
NEM       650 MM (GROSS)
          650 MM (ESC)
COAL
 3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***X
STATUS 6     STARTUP  0/87
INDIANAPOLIS POMER AND LIGHT HAS PLANS FOR THREE NEM UNITS. PATRIOT 1. 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA.  THE UTILITY PLANS CN UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POMER & LIGHT
PATRIOT
2
NEM       650 MM (GROSS)
          650 MM (ESC)
COAL
 3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »»*»x
STATUS 6     STARTUP  O/ 0
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA.   THE UTILITY PLANS TO UTILIZE
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POMER ft LIGHT
PATRIOT
3
NEM       650 MM (GROSS)
          650 MM (ESC)
COAL
 3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »K*«X
STATUS 6     STARTUP  O/ 0
INDIANAPOLIS POMER AND LIGHT HAS PLANS FOR THREE HEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA.   THE UTILITY PLANS ON UTILIZING.
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER -  DECEASES 1931
                                             SECTION 2
                                       STATUS OF  FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
INDIANAPOLIS POU'ER 4 LIGHT
PETERSBURG
3
(JEW       532 MM (GROSS)
          532 MM (ESC)
COAL
 3.25 7.3  BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION,  UOP
ENERGY CONSUMPTION:   2.4X
STATUS 1     STARTUP 12/77
PETERSBURG 3 OF INDIANAPOLIS POWER ANO LIGHT IS LOCATED IN PETc"S5l'=S,
INDIANA, AND BURNS 3.25X S BITUMINOUS COAL (11,000 BTL'/LB). TWO COLD SIOS
ESP'S ARE LOCATED UPSTREAM OF FOUR 85X EFFICIENT UOP LIMESTONE TCA
MODULES. A HORIZONTAL MIST ELIMINATOR PRECEDES AN INDIRECT HOT Al
-------
 EPA UTILITY FGO SU=VEY: OCTOBER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
KANSAS CITY POWER & LIGHT
HAWTHC3N
4
RETROFIT   90 MW (GROSS)
           90 KH (ESC)
COAL
  .60 XS  BITUMINOUS
LIKE
CCM2USTICN ENGINEERING
EHE°GY CONSUMPTION:  2.2X
STATUS 1     STARTUP  8/72
HAWTHORN 4 OF KANSAS CITY POWER AND LIGHT IS A DRY BOTTCM PULVERISED
BITUMINOUS COAL (0.6X S, 9800 BTU/LB) FIRED UNIT LOCATED IN KANSAS CITY.
MISSOURI, WHICH HAS CONVERTED FROM LIMESTONE FURNACE INJHCTICN At.3 TAIL
END SCRUBBING TO A LIME SLUPRY SYSTEM. TWO COM3USTICN EKSII.'c£3INS MAS3LE
BED ABSORBERS. WHICH WERE DESIGNED TO REMOVE 70X OF THE FLUE GAS SC2.
BEGAN OPERATION IN JANUARY 1977. ONE HORIZONTAL CHEVHCN MIST ELIMINATOR
PER MODULE IS LOCATED UPSTREAM OF AN IN-LINE FINNED TUEE REKEAT5R, WHICH
RAISES THE TEMPERATURE OF THE CLEANED GAS BEFORE IT EXITS THECUSH A GUNITE
LINED 200 FOOT STACK. THE FLYASH STABILIZED SLUDGE IS DEPOSITED IN AM
UNLINEO SLUDGE POND. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MC3E.
KANSAS CITY POWER & LIGHT
LA CYGNE
1
NEW       874 MM (GROSS)
          874 MW (ESC)
COAL
 5.39 XS  SUSBITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION:  3.2X
STATUS 1     STARTUP  2/73
LA CYGNE 1 IS A WET BOTTOM, CYCLONE FIRED PULVERIZED SUBSITUMINOUS COAL
(5.39X S, 9421 BTU/LB) FIRED UNIT OF KANSAS CITY POWER AMD LIGHT, LOCATED
IN LA CYGNE, KANSAS. THE EMISSION CONTROL SYSTEM CONSISTS OF EI3HT VARIA-
BLE THROAT VENTURI/LIMESTCNE SIEVE TPAY TOWER TRAINS SUPPLIED BY SAECOCK
AND WILCOX. EACH 80X (S02 REMOVAL, DESIGN) EFFICIENT TRAIN is FOLLOWED BY
A COMBINATION SIEVE TRAY AND CHEVRON MIST ELIMINATOR. AKO AH INDI-
RECT REHEATER. THE CLEANED GAS EXITS THROUGH A 700 FOOT STEEL LINED STACK.
THE SYSTEM OPERATES IN A CLOSED MATER LOOP, AND THE SCRUESER SLUCGE IS
DISPOSED IN AN UNLINED POND. INITIAL OPERATIONS OF THE FGO SYSTEM BEGAN IN
FEBRUARY 1973.
KANSAS POWER
JEFFREY
1
NEW
             & LIGHT
          720 MW (GROSS)
          540 MM (ESC)
COAL
  .32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: «***X
STATUS 1     STARTUP  6/78
KANSAS CITY POWER AND LIGHT'S JEFFREY 1 IS A TANGENTIAL FIRED PULVERIZED
COAL (0.32X S, 8125 BTU/LB) UNIT IN WAMEGO. KANSAS.  THE EMISSION CONTROL
SYSTEM FOR THIS UNIT CONSISTS OF A COLO SIDE ESP FOLLOWED BY SIX (ONE
SPARE) LIMESTONE SPRAY TOWER MODULES SUPPLIED BY COMBUSTION ENGINEERING.
THE DESIGN S02 REMOVAL EFFICIENCY IS SOX (INCLUDING  A 30X BYPASS REHEAT).
THE UNIT HAS BEEN OPERATIONAL SINCE AUGUST 1»78.
KANSAS POWER t LIGHT
JEFFREY
2
NEW       700 MW (GROSS)
          490 MW (ESC)
COAL
  .30 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *»**X
STATUS 1     STARTUP  1/80
UNIT 2, PRESENTLY OPERATING AT KANSAS POWER AND LIGHT'S JEFFREY ENERGY
CENTER IN JEFFREY, KANSAS, BURNS 0.3X S PULVERIZED COAu (81CO BTU/LB).
THIS UNIT'S EMISSION CONTROL SYSTEM CONSISTS OF A COLO SIDE ESP
AND COMBUSTION ENGINEERING LIMESTONE SPRAY TOWERS. A 30X FLUE GAS
BYPASS PROVIDES REHEAT OF THE CLEANED GAS BEFORE IT EXITS TK=.CUGH A
600 FOOT STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MCOE, AND
THE SLUDGE IS STABILIZED WITH BOTTOM ASH AND PIPED TO AN ON-SITE CLAY
LINED POND. INITIAL OPERATIONS COMMENCED IN APRIL 1980.
KANSAS POWER 4 LIGHT
LAURENCE
4
RETROFIT  125 MM (G°OSS)
          1Z5 MM (ESC)
COAL
  .55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *«*«X
STATUS 1     STARTUP  1/77
LAURENCE 4 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT,  TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 10,000 BTU/LB) UNIT LOCATED IN LAURENCE, KANSAS.
A NEW COMBUSTION ENGINEERING LIMESTONE  ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MA?BLE BED TAIL END SCRUBBER IN JANUARY 1977. THE
SYSTEM TREATS 403,000 ACFM OF FLUE GAS, WITH  A DESIGN S02  REMOVAL OF
73X. MIST ELIMINATION IS ACCOMPLISHED BY TWO  CHEVP.CNS AND  CN£ BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE  CLEANED GAS BY 20 OES F BEFOPE
IT IS EXHAUSTED THROUGH A 120 FOOT STACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A  FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED MATER LOOP.
KANSAS POWER & LIGHT
LAURENCE
5
RETROFIT  420 MM (GROSS)
          420 MM (ESC)
COAL
  .55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »»*»X
STATUS 1     STARTUP  4/78
LAURENCE 5 OF KANSAS POWER AND LIGHT IS A BALANCED  DRAFT,  TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 10,000 BTU/LB) UNIT LOCATED IN LAWRENCE,  KANSAS.
A NEW COMBUSTION ENGINEERING LIMESTONE  ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MARBLE BED TAIL END SCRUBBER  IN APPIL 1*73.  THE
SYSTEM TREATS 403.000 ACFM OF FLUE GAS,  WITH  A DESIGN S02  REMOVAL  OF
73X. MIST ELIMINATION IS ACCOMPLISHED BY TWO  CHEVRONS AND  CNE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED  TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE  CLEANED GAS  BY 23 DEG F BEFCRE
IT IS EXHAUSTED THROUGH A 120 FOOT STACK.  THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A  FINAL  DISPOSAL POND.  THE
SYSTEM OPERATES IN A CLOSED HATER LOOP.
                                                22

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                                              EPA UTILITY  F6D  SURVEY:  OCTOBER  -  DECEMBER  1°81
                                             SECTION  2
                                       STATUS OF  FGO  SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
KENTUCKY UTILITIES
GSEEH RIVER
1-3
RETROFIT   64 MM (GROSS)
           64 MM (ESC)
COAL
 4.00 XS  BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION:  3.1X
STATUS 1     STARTUP  9/75
GREEN RIVER 1-3 OF KENTUCKY UTILITIES ARE THREE DRY BOTTOM FULVE=IZ£D
BITUMINOUS COAL (4X S. 11.000 BTU/LB) PIPED UNITS LOCATED IN CEMTPAL
CITY, KENTUCKY. EACH BOILER SUPPLIES 360.OCO ACFM OF FLUE GAS TO A
VARIABLE THROAT VEHTU3I FOLLOWED BY AN AMERICAN AIR FILTER LL"= MC3ILE
BED CONTACTOR (BOX DESIGN S02 REMOVAL EFFICIENCY). A PAOIAL VANE MIST
ELIMINATOR IS FOLLOWED BY A STEAM TU3E REHEATER AN3 A 165 FOOT STACK.
SLUCGE IS DISPOSED IN AH CM-SITE UNLItJED POND, AND THE SI STEM OFEFiTES
IN A CLOSED WATER LOOP. THE SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER
1975.
KENTUCKY UTILITIES
HANCOCK
1
NEU       706 MM (GROSS)
          650 MM (ESC)
COAL
 3.50 XS  BITUMINOUS
LIMESTONE
BABCOCK t MILCOX
ENERGY CONSUMPTION:  »*»*X
STATUS 4     STARTUP 4/89
KENTUCKY UTILITIES HAS PLANS TO CONSTRUCT TWO HEW 650 MM (NET) PULVERIZED
COAL (3.5X S, 10,500 BTU/LB) FIRED BOILERS.  THE UNITS, HANCCCK 1 AK3 2,
ARE TO BE LOCATED IN HAUESVILLE, KENTUCKY.  THE UTILITY HAS SIGNED A LET-
TER OF INTENT WITH B & M FOR A MET LIMESTONE SCRU23INS SYSTEM WHICH MILL
OPERATE IN A CLOSED MATER LOOP MODE TO CONTROL EMISSIONS.  HANCCCK 1 AND 2
ARE SCHEDULED TO COMMENCE OPERATION IN 1939 AND 1994. RESPECTIVELY.
KENTUCKY UTILITIES
HANCOCK
2
MEW       708 MM (GROSS)
          650 MM (ESC)
COAL
 3.50 XS  BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »»*«X
STATUS 6     STARTUP  4/94
KENTUCKY UTILITIES HAS PLANS TO CONSTRUCT TWO NEW 650 MM (NET) PULVERIZED
COAL (3.5X S. 10,500 BTU/LB) FIRED BOILERS.  THE UNITS, HANCCCK 1 AND 2,
ARE TO BE LOCATED IN HAUESVILLE, KENTUCKY.  THE UTILITY IS PRESENTLY
INVESTIGATING A MET LIMESTONE SCRUBBING SYSTEM WHICH MILL OPERATE IN A
CLOSED MATER LOOP MODE TO CONTROL EMISSIONS.  HANCOCK 1 AND 2 ARE SCHED-
ULED TO COMMENCE OPERATION IN 1988 AND 1994, RESPECTIVELY.
LAKELAND UTILITIES
MCINTOSH
3
NEW       364 MM (GROSS)
          364 MM (ESC)
COAL
 2.56 XS  BITUMINOUS
LIMESTONE
BAGCOCK & UILCOX
ENERGY CONSUMPTION: *»»»X
STATUS 2     STARTUP  1/82
MCINTOSH 3 OF LAKELAND UTILITIES IS BEING CONSTRUCTED IN LAKELAND,
FLORIDA. BABCOCK AND MILCOX HAS BEEN AMARDED A CONTRACT TO SUPPLY AN
85X EFFICIENT (S02) LIMESTONE FGD SYSTEM FOS THIS UNIT. THE EMISSION CON-
TROL SYSTEM MILL CONSIST OF A COLO SIDE ESP FOLLOWED BY TWO PARALLEL FGD
MODULES AND A 250 FOOT ACID BRICK LINED STACK. THE SYSTEM MILL OPERATE IN
A CLOSED MATER LOOP, AND THE POZ-0-TEC STABILIZED SLUDGE MILL BE USED AS
A CONSTRUCTION BASE. CONSTRUCTION BEGAN IN NOVEMBER 1979 AND START-
UP IS SCHEDULED TO BE IN JANUARY 1982.
LANSING BOARD OF MATER I LIGHT THE ERICKSON 2 STATION OF THE LANSING BOARD OF MATER AND LIGHT IS A
ERICKSON
2
NEW
          160 MM (GROSS)
          160 MM (ESC)
CCM.
PLANNED UNIT TO BE LOCATED IN DELTA TOWNSHIP, MICHIGAN.  THE UNIT WILL
HAVE A MU RATING OF BETWEEN 160 AND 250. DEPENDING ON WHETHER OTHER MUNI-
CIPALITIES WILL JOIN IN THIS PROJECT.  THE UTILITY IS PRESENTLY CONSIDER-
ING THE USE OF FGD FOR EMISSION CONTROL.  OPERATIONS ARE SCHEDULED TO
COMMENCE IN 1987.
      XS
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *««H(X
STATUS 6     STARTUP  1/87
LOS ANGELES OEPT OF WTR » PWR
INTERMOUNTAIN
1
NEM       820 MM (GROSS)
          620 MM (ESC)
COAL
  .79 XS  SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»««x
STATUS 6     STARTUP  0/86
THE LOS ANGELES DEPARTMENT OF MATER AND POWER HAS PLANS FCR FOUR NEM
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MM BOILER MILL FIRE PULVERIZED COAL (0.79X S, 10,200 BTU/LBI
AND MILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUB3IN3 SYSTEM.
A HORIZONTAL WEIR TYPE SCRUBBER ALONG WITH A HOT SIDE ESP IS UiDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL.  THE CLEANED FLUE GAS
WILL EXIT A 750 FOOT STACK.  UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1986.
                                                23

-------
 EPA UTILITY FGO SURVEY:  OCTC3E3  -  DECEMBER  1981
                                             SECTION  2
                                       STATUS OF  FGO  SYSTEMS
UNIT IDEMTIFICATIOH
                                                                ABSTRACT
LCS AUGELES DEPT OF HTR £ PWR
INTERKC'JNTAIM
NEW       320 M.J IG-CSSI
          820 m (ESC)
COAL
  .79 7.5  SU33ITUMINCUS
LIME
VENDOR NOT SELECTED
EUIRGY CONSUMPTION; «***x
STATUS 6     STARTUP  0/37
THE LOS ANGELES DEPARTMENT OF MATER AND  POWER  HAS  PLANS FCP FOUR MEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4.  TO BE  LOCATED  IN DELTA.  UTAH.
EACH 820 hVI BOILER MILL FIRE PULVERIZED  COAL (0.7«X  S,  10,CCQ  ETU/L3)
AND MILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO  A MET  LIME SCSUBBIt.S SYSTEM.
A HORIZONTAL WEIR TYPE SCRUBBER ALONG  MITH A HOT SIDE  ESP IS UN3E3
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL.   THE CLEANED FLUE GAS
MILL EXIT A 750 FOOT STACK.  UNIT 2 IS SCHEDULED TO  COMMENCE OPERATIONS
IN 1967.
LOS ANGELES DEPT OF WTR t PUR
INTERMOUNTAIN
3
NEM       820 KM (GROSS)
          820 MM (ESC)
COAL
  .79 7.S  SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***X
STATUS 6     STARTUP  0/88
THE LOS ANGELES DEPARTMENT OF MATER AND  POMER  HAS PLANS FOR FOUR NEW
EOILERS, INTERMOUNTAIN 1, 2, 3 AND 4,  TO BE  LOCATED  IN DELTA.  UTAH.
EACH 820 MM BOILER MILL FIRE PULVERIZED  COAL (0.797.  S, 10,203  BTU/LB)
AND MILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO  A MET  LIME SCRU5EIN3 SYSTEM.
A HORIZONTAL MEIR TYPE SCRUBBER ALONG  MITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL.   THE CLEANED FLUE GAS
MILL EXIT A 750 FOOT STACK.  UNIT 3 IS SCHEDULED TO  COMMENCE OPERATIONS
IN 1988.
LOS ANGELES OEPT OF HTR & PMR
INTERMOUNTAIN
4
NEM       820 KM (GROSS)
          820 MM (ESC)
COAL
  .79 XS  SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «*«*X
STATUS 6     STARTUP  0/89
THE LOS ANGELES DEPARTMENT OF HATER AND  POMER  HAS PLANS FOR FOUR NEM
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4,  TO BE LOCATED  IN DELTA.  UTAH.
EACH 820 MM BOILER MILL FIRE PULVERIZED  COAL (0.79X  S, 10,200  BTU/LB)
AND HILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO  A UET  LIME SCRUBBING SYSTEM.
A HORIZONTAL MEIR TYPE SCRUBBER ALONG  HITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL.   THE CLEANED FLUE GAS
MILL EXIT A 750 FOOT STACK.  UNIT 4 IS SCHEDULED TO  COMMENCE OPERATIONS
IN 1989.
LOUISVILLE GAS t, ELECTRIC
CANE RUN
4
RETROFIT  188 MM (GROSS)
          188 MM (ESC)
COAL
 3.75 XS  BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION:  1.6X
STATUS 1     STARTUP  8/76
UNIT 4 AT LOUISVILLE GAS AND ELECTRIC'S CANE RUN STATION IS A PULVERIZED
BITUMINOUS COAL (3.75X S, 11,500 BTU/LB) FIPED UNIT IN LOUISVILLE, KEN-
TUCKY. AN ESP AND TWO AMERICAN AIR FILTER CARBIDE LIME MOBILE BED ABSORBER
MODULES (85X DESIGN S02 REMOVAL) TREAT 734,000 ACFM OF FLUE GAS FROM THE
BOILER. TWO CHEVRON MIST ELIMINATORS/MODULE ARE FCLLCMEO BY A DIRECT
COMBUSTION REHEATER AND A 250 FOOT STACK. THE HATER LOOP IS OPEN, AND
THE SLUDGE IS DISPOSED IN AN ON-SITE LANDFILL. THIS RETROFIT SYSTEM
HAS BEEN OPERATIONAL SINCE AUGUST 1976.
LOUISVILLE GAS t ELECTRIC
CANE RUN
5
RETROFIT  200 MM (GROSS)
          200 MM (ESC)
COAL
 3.75 XS  BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:  1.5X
STATUS 1     STARTUP 12/77
CANE RUN 5 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS COAL
(3.75X S, 11,500 BTU/LB) FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY. THE
BOILER SUPPLIES 700,000 ACFM OF FLUE GAS TO AN EMISSION CONTROL SYSTEM
CONSISTING OF AN ESP FOLLOWED AND TMO COMBUSTION ENGINEERING 85X EFFICIENT
(DESIGN) CARBIDE LIME SPRAY TOWERS. A STEAM TUBE REHEATER RAISES THE GAS
TEMPERATURE 40 DEG F. THE SYSTEM OPERATES IN AN OPEN HATER LOOP MODE, AND
THE SLUDGE IS POZ-0-TEC STABILIZED. OPERATION OF THIS RETROFIT SYSTEM
BEGAN IN DECEMBER 1977.
LOUISVILLE GAS t ELECTRIC
CANE RUN
6
RETROFIT  299 MM (GROSS)
          299 MM (ESC)
COAL
 4.80 XS  BITUMINOUS
DUAL ALKALI
THYSSEN/CEA
ENERGY CONSUMPTION:  l.OX
STATUS 1     STARTUP  4/79
LOUISVILLE GAS AND ELECTRIC'S CANE RUN 6  IS A 299-MM (GnOSS) BITUMINOUS
COAL (4.SOX S, 11,500 BTU/LB) FIRED UNIT  LOCATED IN LOUISVILLE.
KENTUCKY.  THYSSEN/CEA SUPPLIED A RETROFIT DUAL ALKALI DEMONSTRATION
FGD SYSTEM FOR THIS UNIT. THE EMISSION CONTROL SYSTEM, DESIGNED TO REMOVE
95X OF THE FLUE GAS S02, CONSISTS OF A COLD SIDE ESP AND TWO TRAY TOMER
MODULES. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND TMO
DIRECT COMBUSTION REHEATERS BEFORE EXITING A 518 FOOT STACK. THE HATER
LOOP IS OPEN, AND THE SLUDGE IS DISPOSED  IN AN ON-SITE LANDFILL.
FOR A ONE YEAR PERIOD FOLLOWING THE FIRST QUARTER OF OPERATION (WHICH BE-
GAN IN APRIL 1979), THE U.S.EPA SUBSIDIZED THE OPERATIONS (FOR $4.5 MAX)
FOR RiO AND REPORT WRITING.
                                                24

-------
                                              EPA UTILITY  FGD  SURVEY: OCTOBER  -  DECEASES 1931
                                             SECTION  2
                                       STATUS OF  FGD  SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
LOUISVILLE GAS & ELECTRIC
MILL CREEK
1
RETROFIT  353 MM (GROSS)
          358 MM (ESC)
COAL
 3.75 XS  BITUMINOUS
Lir.E
CC :SUSTIOH ENGINEERING
ENERGY CONSUMPTION:   1.4X
STATUS 1     STARTUP 12/80
MILL CREEK 1 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT LIME/LIMESTONE FGD SYSTEM IS PRESENTLY OFEPATrNG
ON THIS PULVERIZED COAL (3.75X S, 11,500 BTU/LB) PIPED UNIT. CC"2U3TION
ENGINEERING SUPPLIED THE LIME/LIMESTONE FGO SYSTEM WHICH IS SCHEDULED
TO COMPLY WITH LOCAL EMISSION STANDARDS BY APRIL 1931.
LOUISVILLE GAS & ELECTRIC
MILL CREEK
2
RETROFIT  350 KM (GROSS)
          350 MM (ESC)
COAL
 3.75 XS .BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:   1.4SC
STATUS 1     STARTUP 12/81
MILL CREEK 2 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LCL-ISVILLE, KEN-
TUCKY. A RETROFIT LIME/LIMESTONE FGD SYSTEM IS PRESENTLY OPERATING CM
THIS PULVERIZED COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT. CCM3USTICN
ENGINEERING SUPPLIED THE LIME/LIMESTONE FGD SYSTEM WHICH IS SCHEDULED TO
COMPLY WITH LOCAL EMISSION STANDARDS BY APRIL 1932.
LOUISVILLE GAS & ELECTRIC
MILL CREEK
3
NEM       427 MM (GPOSS)
          427 MM (ESC)
COAL
 3.75 XS  BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *»»*X
STATUS I     STARTUP  8/78
LOUISVILLE GAS AND ELECTRIC'S MILL CREEK 3 IS A 3.75X S COAL (11,500 BTU/
LB) FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY. AMERICAN AIR FILTER SUP-
PLIED A CARBIDE LIME FGD SYSTEM FOR THIS UNIT WHICH MAS DESIGNED TO REMOVE
85X OF THE S02 FROM THE FLUE GAS. AN ESP IS FOLLOWED BY FCL'S MD3ILE BED
CONTACTORS AND A STEAM TUBE REHEATER. THE MATER LOOP IS OPEN, AND THE
FLYASH AND LIME STABILIZED SLUDGE IS PONDED. THIS UNIT HAS BEEN OPERATION-
AL SINCE AUGUST 1978.
LOUISVILLE GAS t ELECTRIC
MILL CREEK
4
NEM       495 MM (GROSS)
          495 MM (ESC)
COAL
 3.75 XS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: »»««X
STATUS 2     STARTUP  6/82
MILL CREEK 4 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS
COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN LOUISVILLE,
KENTUCKY. THE EMISSION CONTROL SYSTEM MILL CONSIST OF AN ESP AND FOUR
MOBILE BED CONTACTORS.  THE SYSTEM'S HATER LOOP MILL BE CLOSED, AND
THE SLUCGE HILL BE STABILIZED HITH LIME AND FLYASH. STEAM TUBES WILL
PROVIDE REHEAT OF THE CLEANED GASES. THE SYSTEM 13 SCHEDULED TO START-
UP IN JUNE 1982.
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN
6
RETROFIT   72 MM (GROSS)
           72 MM (ESC)
SEAL
 2.50 XS  BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:  2.8X
STATUS 1     STARTUP  4/73
UNIT 6 AT LOUISVILLE GAS AND ELECTRIC'S PADDY'S RUN STATION IS A DRY BOT-
TOM PULVERIZED COAL (2.5X S, 11,500 BTU/LB) FIRED UNIT IN  LOUISVILLE, KEN-
TUCKY. A RETROFIT CARBIDE LIME FGD SYSTEM BY COMBUSTION ENGINEERING TREATS
400,000 ACFM OF FLUE GAS FROM THE BOILER. AN ESP IS FOLLOWED BY TWO MA=3LE
BED ABSORBERS, A DIRECT COMBUSTION REHEATER, AND A 250 FOOT STACK. MIST
ELIMINATION IS PROVIDED BY ONE CHEVPON/MODULE. THE LIME FIXATED SLLCSE IS
TRUCKED TO AN UNLIHEO POND, AND THE MATER LOOP IS CLOSED.  THE FGO SYSTEM
BEGAN INITIAL OPERATIONS IN APRIL 1973.
LOUISVILLE GAS & ELECTRIC
TRIMBLE COUNTY
1
NEH       575 MM (GROSS)
          575 MM (ESC)
COAL
 4.00 XS  BITUMINOUS
PROCESS NOT SELECTED
VEKDOH NOT SELECTED
ENERGY CONSUMPTION: *»*»'/.
STATUS 5     STARTUP  7/85
LOUISVILLE GAS AND ELECTRIC HILL BE INSTALLING FGD SYSTEMS CN TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 4X S (IF NO COAL HASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS HILL BE CLEANED BY ESP'S AND MET SCRUBBING !90X PEMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT  1 IS SCHEDULED
FOR START-UP IN JULY 1985.
                                                25

-------
 EPA UTILITY FGO SUPVEY: OCTOBER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ASSTPACT
LCJISVILLE GAS & ELECTRIC
TRIC3LE COUNTY
Z
NEW       575 Mrf (G30SS)
          575 MM (ESC)
COAL
 4.00 XS  BITUMINOUS
FPCCESS HOT SELECTED
VEfOCT NOT SELECTED
ENERGY CONSUMPTION: ***«X
STATUS 5     STARTUP  7/89
    LOUISVILLE GAS AND ELECTRIC WILL BE INSTALLING FGO SYSTEMS CM T'nO Or THE
    FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATICN II) EsCFC=Di
    KENTUCKY. THE PULVERIZED V/. S (IF NO COAL WASH IS INCLUDED) COiL FIRED
    UNITS' FLUE GAS MILL BE CLEANED BY ESP'S AND WET SCFUS3IN3 (9CX REMOVAL
    EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT Z IS SCHESULED
    FOR START-UP IN 1939.
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT
3
MEM       435 MM (GROSS)
          435 MM (ESC)
LIGNITE
 1.70 XS
LIMESTONE
VEU2CR NOT SELECTED
ENERGY CONSUMPTION:  a.ax
STATUS 6     STARTUP  0/88
    LOWER COLORADO RIVER AUTHORITY HAS PUNS TO CONSTRUCT A 435 MM UNIT,
    FAYETTE POWER PROJECT 3, TO BE LOCATED IN LA GRANGE, TEXAS.  THE LIGNITE
    (1.7X S, 4300 BTU/LB) FIRED BOILER WILL UTILIZE A WET LIMESTONE SCRUBBING
    SYSTEM DESIGNED TO REMOVE 90X S02.  OPERATIONS ARE SCHEDULED TO COMMENCE
    IN 1988.
MAEQUETTE BOARD OF LIGHT t
SHIRAS
3
MEM        44 MM (GROSS)
           44 MM (ESC)
COAL
•***«* XS
LIME/SFRAY DRYING
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  «***X
STATUS Z     STARTUP  9/62
PUR SHIRAS 3 OF THE MARQUETTE BOARD OF LIGHT AND POWER IS A PULVERIZED COAL
    FIRED BOILER UNDER CONSTRUCTION IN MARGUETTE, MICHIGAN.  THE UTILITY
    HAS AWARDED A CONTRACT TO GE ENVIRONMENTAL SERVICES FOR A LIME/SPPAY
    DRYING PROCESS TO CONTROL EMISSIONS.  THE SYSTEM WILL UTILIZE A FAERIC
    FILTER TO OBTAIN A PARTICLE REMOVAL EFFICIENCY OF 99.67..  THE UNIT IS
    SCHEDULED TO COMMENCE OPERATIONS IN SEPTEMBER 1982.
MICHIGAN SO CENTRAL PMR AGENCY
PROJECT
1
NEW        55 MM (GROSS)
           55 MM (ESC)
COAL
 2.25 XS  BITUMINOUS
LIMESTONE
BABCCCK £ MILCOX
ENERGY CONSUMPTION:  1.8X
STATUS 2     STARTUP  6/82
    THE PROJECT 1 UNIT OF MICHIGAN SOUTH CENTRAL POMER AGENCY IS UNDER CON-
    STRUCTION IN LITCHFIELD, MICHIGAN, AND WILL UTILIZE A MET LIMESTONE FGO
    PROCESS.  THE PULVERIZED COAL FIRED BOILER MILL FEED ITS FLUE GAS THROUGH
    A HOT SIDE ESP FOLLOWED BY A BABCOCK AND WILCOX LIMESTCNE EPP4Y TCMER.
    THE CLEANED GAS MILL PASS THROUGH A MIST ELIMINATOR BEFCPE BEING HEATED
    BY AN IN-LINE REHEATER AND EXITING A 250 FOOT STACK.  THE SLUDGE IS TO
    BE DISPOSED OFF SITE. START-UP IS SCHEDULED FOR JUNE 1982.
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
5
NEM       890 MM (GROSS)
          890 MM (ESC)
COAL
  .50 XS  LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:  »«*»x
STATUS 4     STARTUP  0/90
    UNIT 1 OF THE ARKANSAS ENERGY LIGNITE CENTER IS A LIGNITE (.5X S) FIRED
    BOILER. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH
    COMBUSTION ENGINEERING FOR A WET LIMESTCNE SCRUBBING SYSTEM TO CONTROL
    EMISSIONS. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1990.
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
6
NEW       690 MM (GROSS)
          890 KM (ESC)
COAL
  .50 XS  LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:  *»*»X
STATUS 4     STARTUP  0/92
    UNIT 2 OF THE ARKANSAS ENERGY LIGNITE CENTER IS A LIGNITE (.5X S) FIREO
    BOILER. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT HITH
    COMBUSTION ENGINEERING FOR A WET LIMESTCNE SCRUBBING SYSTEM TO CONTROL
    EMISSIONS. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1992.
                                                26

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEASES 1931
                                             SECTION 2
                                       STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
MICOLE SOUTH UTILITIES
UHASSIGNEO
1
NEW       890 KM (GROSS)
          890 KM (ESC)
COAL
   .50 XS
LIHESTCNE
CCMSUSTION ENGINEERING
ENERGY CONSUMPTION: •****•/.
STATUS 4     STARTUP  0/89
KIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH CC^3L'STIC'l
EN5INEERING FOR A MET LIMESTONE SCRUBBING SYSTEM TO CCNTrOL EMISSIONS.
THE PLANT NAME HAS NOT BEEN ASSIGNED.  THE PLANT HILL BE LOCATED
SOMEWHERE IN LOUISIANA.  START-UP IS SCHEDULED FOR 19S9.
MIDDLE SOUTH UTILITIES
UNASSIGNED
Z
NEM       890 KM (GROSS)
          890 KM (ESC)
COAL
   .50 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »«««X
STATUS-*     STARTUP  0/93.
MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH CCM3USTION
ENGINEERING FOR A MET LIMESTONE SCRUBBING SYSTEM TO CONTROL EMISSIONS.
THE PLANT NAME HAS NOT BEEN ASSIGNED.  THE PLANT MILL BE LOCATED
SCMEMHERE IN LOUISIANA.  START-UP IS SCHEDULED FOR 1993.
MIDDLE SOUTH UTILITIES
HILTON
1
NEM       690 KM (GROSS)
          890 KM (ESC)
COAL
   .50 XS
LIMESTONE
COMBUSTION  ENGINEERING
ENERGY CONSUMPTION: »«*»X
STATUS 4     STARTUP  0/88
HILTON 1 IS A COAL ( .SOX. S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA.  MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT MITH CCMEL'S-
TION ENGINEERING FOR A MET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CCNTROL.  START-UP IS SCHEDULED FOR 1968.
MIDDLE  SOUTH UTILITIES
MILTON
2
NEM       690 MM  (GROSS)
          890 KM  (ESC)
COAL
   .50 XS
LIMESTONE
COM2USTION  ENGINEERING
ENERGY  CONSUMPTION: **»»X
STATUS  ft     STARTUP  0/91
HILTON 2 IS A COAL (.SOX S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA.  KIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT MITH COMBUS-
TION ENGINEERING FOR A MET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CONTROL.  START-UP IS SCHEDULED FOR 1991.
 MINNESOTA  POMER S  LIGHT
 CLAY  BOSMELL
 4
 ISM        554 KM (GPOSS)
           475 KM (ESC)
CCDAL
i>-  .94 XS   SUEBITUMINOUS
 LIKE/ALKALINE FLYASH
 PEABOOY PROCESS SYSTEMS
 ENERGY CONSUMPTION:   1.3X
 STATUS 1     STARTUP  4/80
CLAY BOSMELL 4 OF MINNESOTA POWER AND LIGHT IS A EUBBITUMINCUS COAL (0.94X
S, 6896 BTU/LB) FIPEO UNIT LOCATED IN CCHASSET, MINNESOTA. PEABCQY
PROCESS SYSTEMS HAS SUPPLIED A LIME/ALKALINE FLYASH SYSTEM MHICH
IS DESIGNED TO REMOVE 84.6X OF THE S02 IN THE FLUE GAS. TWO HOT SIDE ESP'S
ARE FOLLOWED BY VENTURI/SPRAY TOMER TRAINS. MIST ELIMINATION IS PSOVIOEO
BY A SIEVE TRAY FOLLOWED BY A SPIN VANE CHEVRON, AND REHEAT IS SUPPLIED
BY BYPASSING 5X OF THE FLUE GAS. THE SYSTEM OPERATES IN A CLOSED WATER
LOOP MODE. AND THE SLUDGE IS DISPOSED IN A LINED POND. OPERATIONS
COMMENCED IN APRIL 1980.
 MIH.VKOTA POWER
 MILTON R.  YOUNG
 2"
 NEM       440 MM  (GROSS)
           185 MM  (ESC)
 COAL
   .70 XS  LIGNITE
 LIME/ALKALINE FLYASH
 THYSSEN/CEA
 ENERGY CONSUMPTION:   1.6X
 STATUS 1    STARTUP  9/77
MINNKOTA POWER COOPERATIVE'S MILTON R. YOUNG 2 IS A CYCLONE FIRED LIGNITE
(0.70XS, 6500 BTU/LB) BOILEP LOCATED IN CENTER, NORTH DAKOTA. THE BOILER
PRODUCES 2,021,400 ACFM OF FLUE GAS. HALF OF WHICH IS CLEANED BY TWO ESP'S
AND TWO THYSSEN/CEA LIME/ALKALINE FYLASH SPRAY TOWERS (75X DESIGN
S02 REMOVAL EFFICIENCY).  THE CLEANED GAS PASSES THROUGH A CHEVRON
MIST ELIMINATOR BEFORE IT JOINS A 15X BYPASS REHEAT (HOT UNSCRL'EBED
GAS), AND EXITS A 550 FOOT STACK. THE HATER LOOP IS OPEN, AND THE
SLUDGE IS TRUCKED TO AN OFF-SITE MINEFILL.  OPERATIONS BEGAN IN 1977.
                                                 27

-------
 EPA UTILITY FGC SVVEY: OCTC3E? - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
                                                                 ABS-'ACT
MCN3NGAHELA POWER
PLEASANTS
1
MEM
          668 MM (C-POSS)
          668 MM (ESC)

          BITUMINOUS
COAL
 3.00 XS
LIME
3ABCOCK & HILCOX
ENERGY CONSUMPTION:  *»»»X
STATUS 1     STARTUP  3/79
MCNONGAHELA POWER PLEASANTS 1 IS A BITUMINOUS COAL (5.70X S.  12.150
BTU/LB) FIRED BOILER IN BELMONT, WEST VIRGINIA.   BA3CCCK AND  WILCCX SUP-
PLIED A LIME FGO SYSTEM DESIGNED TO REMOVE 90X OF THE FLUE GAS SCC FPCM
THIS UNIT. THE EMISSION CONTPOL SYSTEM INCLUDES AH ESP UFSTPEAM CF FOUR
SF3AY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM PROVIDES REHEAT OF THE
CLEANED GAS BEFORE IT IS DISCHARGED THROUGH A 1200 FC3T PLACITE LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGD SYSTEM CM THIS
UNIT HAS BEEN OPERATIONAL SINCE MARCH 1979.
MONONGAHELA POWER
PLEASAHTS
2
NEM       666 MM (GPOSS)
          663 MM (ESC)
COAL
 3.00 XS  BITUMINOUS
LIME
BA5COCK & MILCOX
ENERGY CONSUMPTION: «*«»X
STATUS 1     STARTUP 10/80
                               MONONGAHELA POMER  PLEASANTS  Z  IS A  BITUMINOUS COAL  (4.5X S, 12150
                               BTU/LB)  FIRED BOILER  LOCATED IN BELMONT, WEST VIRGINIA.  BA3COCK AND
                               MILCOX SUPPLIED  A  LIME  FGD SYSTEM DESIGNED TO REMOVE 90X OF THE BOILER
                               FLUE  GAS SOZ. THE EMISSION  CONTROL SYSTEM CM THIS  UNIT INCLUDES AN ESP
                               UPSTREAM OF FOUR SPRAY  TOUER ABSORBERS.  A FLUE GAS BYPASS SYSTEM  PPOVIDES
                               REHEAT OF THE CLEANED GAS BEFCPE IT IS DISCHARGED THROUGH A 1200 FCOT
                               ACID  BRICK STACK.   THE  SYSTEM  OPERATES IN AN OPEN WATER LOOP.  THE FGO
                               SYSTEM OPERATION COMMENCED IN  OCTOBER 1980.
MONTANA POMER
COLSTRIP
1
NEM       360 MM (GROSS)
          360 MM (ESC)
COAL
  .77 XS  SUB3ITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION:  3.3X
STATUS 1     STARTUP  9/75
                               COLSTRIP 1  OF MONTANA POMER  IS A  360-MM  (GROSS) SU3BITUMINCUS COAL
                               (0.77X S, 8843 BTU/LB) FIRED UNIT LOCATED  IN COLSTRIP, MONTANA.   THYSSEN-
                               CEA SUPPLIED A LIME/ALKALINE FLYASH  FGD  SYSTEM CONSISTING OF THREE
                               VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS. THE ASSCPSERS ARE  FOLLOWED
                               BY HORIZONTAL CHEVRON MIST ELIMINATORS,  A  STEAM TUBE REHEATER, AND  A  500
                               FOOT STACK. THE UMSTABILIZED SLUDGE  IS DISPOSED IN AN CN-SITE LINED POND.
                               THE HATER LOOP IS CLOSED.  OPERATIONS INITIALLY BEGAN IN SEPTEMBER 1975.
MONTANA POWER
COLSTRIP
2
NEW       360 MM (GROSS)
          360 MM (ESC)
COAL
  .77 XS  SL'BBITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION:  3.3X
STATUS 1     STARTUP  5/76
                               COLSTRIP 2 OF MONTANA POMER  IS A  360-MM  (GROSS) SU5BITUMINOUS COAL
                               (0.77X S,  88*3 BTU/LB) PIPED UNIT LOCATED  IN COLSTRIP, MONTANA.   THYSSEN
                               CEA SUPPLIED A LIME/ALKALINE FLYASH  FGD  SYSTEM CONSISTING OF THREE
                               VENTURI SCRUBBER/SPRAY TOWER ABSORBER  TRAINS. THE ABSORBERS ARE  FOLLOWED
                               BY HORIZONTAL CHEVRON HIST ELIMINATORS,  A  STEAM TUBE REHEATER, AND A  500
                               FCOT STACK. THE UNSTASILIZED SLUDGE  IS DISPOSED IN AN ON-SITE LINED POND.
                               THE MATER  LOOP IS CLOSED.  OPERATIONS INITIALLY BEGAN IN MAY 1976.
MONTANA POMER
COLSTRIP
3
NEM       700 MM (G°OSS)
          700 MM (ESC)
COAL
  .70 XS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: *»*»X
STATUS 2     STARTUP 10/83
                               MONTANA POWER'S COLSTRIP 3 IS A LOM SULFUR COAL  (0.7X  S, 8300 BTU/LB)
                               FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A  CONTRACT  HAS  EEEN
                               AWARDED TO THYSSEH/CEA FOR A LIME/ALKALINE FLYASH  FGO  SYSTEM ON THIS UNIT..
                               START UP IS SCHEDULED FOR OCTOBER 1983.
MONTANA POWER
COLSTRIP
4
MEM       700 MM (GROSS)
          700 MM (ESC)
COAL
  .70 XS
LIME/ALKALINE FLYASH
THYSSEH/CEA
EHEPGY CONSUMPTION: »«*«x
STATUS 2     STARTUP  0/84
                               MONTANA POWER'S COLSTRIP 4 IS A  LOM SULFUR COAL  (0.7X S, 8800 BTU/LB)
                               FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A CONTRACT  HAS  EEEN
                               AWARDED TO THYSSEN/CEA FOR A LIME/ALKALINE FLYASH  FGD SYSTEM ON THIS UNIT.
                               START UP IS SCHEDULED FOR 1984.
                                                28

-------
                                              EPA UTILITY  FGD  SURVEY:  CCTCSER  -  DECEMBER  1981

                                             SECTION 2
                                       STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
MONTANA-DAKOTA UTILITIES
COYOTE
1
NEW       440 KM (GROSS)
          440 MM (ESC)
COAL
  .87 XS  LIGNITE
SCDIL'M CAPSCMATE/SFRAY  DRYING
U'HEELABRATOR-FRYE/R. I.
ENEPGY CONSUMPTION:   i.ix
STATUS 1     STARTUP 4/81
COYOTE 1 IS A CYCLONE FIRED PULVERIZED LIGNITE (0.87X S. 7C50 BTU/L3)
BOILER OPERATING IN BEULAH, NORTH DAKOTA.  THIS UNIT IS JOINTlf C'.Sil3
BY FIVE UTILITIES, WITH MONTANA-DAKOTA UTILITIES BEING THE HAJ2?
OWNER AND CONSTRUCTOR. AN AQUEOUS CAP50NATE DRY FGD SYSTEM Cf'IGNSD TO
REMOVE 70X OF THE S02 WAS SUPPLIED BY WHEELABRATCR-FRYE AN3 "-:<;;eLL
INTERNATIONAL. THE SPRAY ORYER/BAGHOUSE SYSTEM COMMENCED CFERATICN IN
APRIL 1981.
MUSCATINE POWER S WATER
MUSCATINE
9
NEW       166 MW (GROSS)
          166 MW (ESC)
COAL
 3.21 XS  BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:   4.ax
STATUS 2     STARTUP  9/82
MUSCATIHE 9 IS A PULVERIZED BITUMINOUS COAL (3.21X S, 11,200 BTU/L3) FIREO
UNIT UNDER CONSTRUCTION IN MUSCATINE, ICMA.  RESEARCH-COTTRELL IS
SUPPLYING A LIMESTONE SCRUBBING SYSTEM FOR EMISSION CONTROL. THE FGO
SYSTEM WILL FEATURE AN ESP, TWO 100X CAPACITY ABSORBER TCWEPS, STEAM COIL
REHEAT A CLOSED MATER LOOP, AND FORCED OXIDATION CF THE SLUDGE EEFCPE
LANDFILL. THE DESIGN S02 REMOVAL WILL BE 94X. START-UP IS SCHEDULED TO
TAKE PLACE IN 1982.
NEBRASKA PUBLIC POWER DISTRICT FOSSIL III 1 IS A PULVERIZED SUBBITUMINOUS COAL 10.35X S,  8000 BTU/LB)
FOSSIL III
1
NEW       650 KM (GROSS)
          650 KM (ESC)
COAL
  .36 XS  SUSBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «««*X
STATUS 6     STARTUP  3/92
FIRED UNIT PLANNED BY THE NEBRASKA PUBLIC POWER DISTRICT TO BE LOCATED
NEAR SARGENT, NEBRASKA.  THE UTILITY IS CONSIDERING A DRY SCRUS3IN5
FGO PROCESS TO CONTROL EMISSIONS FROM THE 650 MM BOILER.  START-UP FOR
THE UNIT IS TENTATIVELY SCHEDULED FOR MARCH 1992.
NEVADA FCHER
HARRY ALLEN
1
NEW       500 MM (GROSS)
          500 MM (ESC)
COAL
»**«* XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **»«X
STATUS 6     STARTUP  6/86
NEVADA POWER'S HARRY ALLEN 1 IS A PLANNED COAL FIPEO UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
UP IS SCHEDULED FOR JUNE 1986.
NEVADA POWER
HARRY ALLEN
Z
NEW       500 MW (GROSS)
          500 MW (ESC)
COAL
****» XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***»X
STATUS 6     STARTUP  6/87
NEVADA POWER'S HARRY ALLEN 2 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
UP IS SCHEDULED FOR JUNE 1987.
NEVADA POWER
HARRY ALLEN
3
NEW       500 KM (GROSS)
          500 KM (ESC)
COAL
*«»»» xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *««*X
STATUS 6     STARTUP  6/88
NEVADA POWER'S HARRY ALLEN 3 IS A PLANNED COAL FIPEO UNIT TO 3E LOCATED IN
LAS VEGAS. NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION HITH AN FGO SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
UP IS SCHEDULED FOR JUNE 1988.
                                                29

-------
 EPA UTILITY FGD SURVEY: CCTC3ES - DECSfSER 1981
                                             SECTION 2
                                       STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
NEVADA FCWs=
HARRY ALLEN
4
NEW

COAL
          SCO MW (GSOSS)
          SCO MM (ESC)
                               NEVADA POWER'S  HARRY  ALLEN 4  IS A PLANNED COAL FIRED UNIT TO EE  LOCATED  IN
                               LAS VEGAS. NEVADA.  THE UTILITY IS CONSIDERING A HOT SICE ES? IN  CONJUNC-
                               TION WITH AN  FGD  SYSTEM.  SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
                               UP IS SCHEDULED FOR JUNE  1989.
FPCCESS NOT SELECTED
VEN3CR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6     STARTUP  6/89
NEVADA POWER
REID GARDNER
1
RETROFIT  125 MM (GROSS)
          IZS MM (ESC)
COAL
   .50 XS  BITUMINOUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: *»»*Z
STATUS 1     STARTUP  3/74
                               REID  GARDNER  1  IS  A  125-MH  (GROSS) MET BOTTOM LOU SULFUR COAL  (0.5X Si
                               12,450  BTU/LB)  FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA.
                               THE THYSSEN/CEA SODIUM CARBONATE-BASED (TPQNA) SCRUBBING SYSTEM
                               CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THPOAT VENTURIS FOL-
                               LOWED 3Y A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFCRATiD PLATE WASH
                               TCWER.  PRIMARY  PARTICULATE  CONTROL IS PROVIDED BY UPSTPEAM KULTICLCS'ES.
                               A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM COIL  RtHEATcR
                               AND A 200 FOOT  STACK. THE SYSTEM OPERATES IN AN OPEN MATER LOOP, AN3 THE
                               SLUDGE  IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION  PCMD. THE
                               DESIGN  S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
                               SINCE MARCH 1974.
NEVADA POMER
REID GARDNER
2
RETROFIT  125 MM (GROSS)
          125 MU (ESC)
COAL
  .SO 7.5  BITUMINOUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: *»»*x
STATUS 1     STARTUP  4/74
                               REID  GARDNER  2  IS A  125-MH  (GROSS) MET BOTTCM LOU SULFUR COAL  (0.5X S,
                               12,450 BTU/LB)  FIRED UNIT OWNED BY NEVADA PCWEP, LOCATED IN M3APA, NEVADA.
                               THE THYSSEN/CEA SODIUM CARBONATE-BASED (TRCNA) SCRUBBING SYSTEM
                               CONSISTS OF ONE MODULE CONTAINING TMIH VARIABLE THROAT VENTURIS FOL-
                               LOWED BY A SEPARATOR IN SERIES MITH A SINGLE STAG; PEFCRATED PLATE WASH
                               TOMER. PRIMARY  PARTICULATE  CONTROL IS PROVIDED BY UFSTRE4M MULTICLCNES.
                               A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM COIL  REHEATEP
                               AND A 200 FOOT  STACK. THE SYSTEM OPERATES IN AN OPEN MATER LOOP, AND THE
                               SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION  POND. THE
                               DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
                               SINCE APRIL 1974.
NEVADA POMER
REID GARDNER
3
NEM       125 MU (GPOSS)
          125 MU (ESC)
COAL
   .50 XS  BITUMINOUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: *«»«X
STATUS 1     STARTUP  6/76
                               REID  GARDNER  3  IS  A  125-MU  (GROSS) MET BOTTOM LOW SULFUR COAL  (0.5X S.
                               12,450  BTU/LB)  FIRED UNIT OWNED BY NEVADA POMER, LOCATED IN MOAPA, NEVADA.
                               THE THYSSEN/CEA SODIUM CARBONATE-BASED (TRONA) SCRUBBING SYSTEM
                               CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
                               LOWED BY A SEPARATOR IN  SERIES MITH A SINGLE STAGE PEFORATED PLATE WASH
                               TCWER.  PRIMARY  PARTICULATE  CONTROL IS PROVIDED BY UPSTREAM MULTICLONES.
                               A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM COIL  REHEATER
                               AND A 200 FOOT  STACK. THE SYSTEM OPERATES IN AN OPEN MATER LOOP, AND THE
                               SLUDGE  IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION  POND. THE
                               DESIGN  S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
                               SINCE JUNE 1976.
NEVADA POMER
REID GARDNER
4
NEM       250 MU (GROSS)
          250 MU (ESC)
COAL
  .75 XS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: *»*»X
STATUS 4     STARTUP  4/83
                               REID  GARDNER 4 OF NEVADA POMER IS A COAL (0.75X S, 12.450 BTU/LB) FIRED
                               UNIT  PLANNED FOR LOCATION  IN MOAPA, NEVADA.  A LETTER OF INTENT HAS BEEN
                               SIGNED MITH THYSSEN/CEA TO PROVIDE A SODIUM CARBONATE FGD SYSTEM.  A
                               BAGHOUSE HILL PHECEED THE  FGD SYSTEM FC1? PARTICULATE MATTER CCNTPOL
                               SCHEDULED START-UP OF THIS 250-MM (GROSS) UNIT IS EXPECTED IN AFPIL
                               1983.
NEW YORK STATE ELEC 4 GAS
SOMERSET
1
NEM       625 MU (GROSS)
          625 MU (ESC)
COAL
 2.20 XS  BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENEPGY CONSUMPTION: **»*•/.
STATUS 4     STARTUP  6/84
                               THE NEM YORK STATE ELECTRIC S GAS CORP. HAS PLANS TO BUILD A PULVE°IZE3
                               COAL  FIRED BOILER IN SOMERSET, NEM YORK.  THE BOILER IS TO GENERATE A
                               FLUE  GAS FLOM OF 2,227,000 ACFM AND BURN A BITUMINOUS COAL WITH AN AVERAGE
                               SULFUR CONTENT OF 2.2X AND AH AVERAGE HEAT CONTENT OF 12,000 BTU/LB.
                               A  COLD SIDE ESP MITH A DESIGN EFFICIENCY OF 99.77X MILL PROVIDE THE Prl-
                               MARY  PARTICULATE REMOVAL.  A LIMESTONE ABSORBER MITH A DESIGN PEI1CVAL
                               EFFICIENCY OF 90X MILL BE USED FOR S02 REMOVAL.  THE SYSTEM HILL OPERATE
                               IN A  CLOSED LOOP MODE.  THE SLUDGE IS TO BE DEMATERED AND STABILIZED
                               BEFORE BEING LANDFILLED.  OPERATIONS ARE SCHEDULED FCR 1984.
                                                30

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF FGO SYSTEMS
 UNIT  IDENTIFICATION
                                                                 ABSTRACT
 NIAGARA MOHAWK POWER
 CHARLES R. HUNTLEY
 66
 RETROFIT  100 MM (GPOSS)
          100 MM (ESC)
 COAL
  1.80 ZS
 AQUEOUS CARBONATE/SPRAY DRYING
 ROCKWELL INTERNATIONAL
 ENERGY CONSUMPTION: *«**7.
 STATUS 2     STARTUP  4/82
CHARLES R. HUNTLEY 66 OF NIAGARA POWER COOP IS A PULVERIZES COAL fl.SX S,
12,500 BTU/LB) FIRED UNIT LOCATED IN BUFFALO,  NEW YCPK.  A CC'ITPACT MAS
AWARDED TO ROCKWELL INTERNATIONAL FOR THE DESIGN AN3 INSTALLATION OF A °OX
EFFICIENT RETROFIT ACUEOUS CARBONATE FG3 SYSTEM UHICH HILL FPC3UCE ELEMEN-
TAL SULFUR AS AN END PRODUCT. FUNDS ARE BEINS  PPOVIDEO BY THE U.S.EPA AND
THE EMPIRE STATE ELECTRIC ENERGY RESEARCH CORP. A SF=AY G°YE? WILL BE
FOLLOWED BY TWO BANKS OF 6 CYCLONES. AN ESP. AND A LINED 200 FCOT CASECN
STEEL STACK. THE MATER LOOP MILL BE OPEN. START-UP OF THE FGD SfSTEM MILL
BE IN
 NORTHERN INDIANA PUB SERVICE
 DEAN H. MITCHELL
 11
 RETROFIT  116 MM (GROSS)
          115 MM (ESC)
 COAL
  3.50 XS
 MELLMAN LORD
 DAVY MCKEE
 ENERGY CONSUMPTION: 12.IX
 STATUS 1     STARTUP  7/76
NORTHERN INDIANA PUBLIC SERVICE'S DEAN H. MITCHELL 11 IS A COAL (3.5X S,
11,000 BTU/LB) FIRED UNIT LOCATED IN GARY, INDIANA. A RETROFIT MELLMAN
LORD FGO SYSTEM BY DAVY POMERGAS HAS BEEN OPERATING ON THIS UNIT SINCE
JULY 1976. AN ESP IS FOLLOMED BY A VARIABLE THROAT VENTU3I SC8U33ES
AND A TRAY TOWER ABSORBER (90X DESIGN S02 REMOVAL EFFICIENCY). A DIRECT
COMBUSTION RAISES THE CLEANED GAS TEMPERATURE 50 DEG F BEFORE THE GAS
IS DISCHARGED THROUGH A 168 FOOT STAINLESS STEEL AND FRP LIMED STACK.
ELEMENTAL SULFUR AND SODIUM SULFATE IS PRODUCED BY THE PROCESS DEVELOPED
BY ALLIED CHEMICAL. THE SYSTEM OPERATES IN A CLOSED MATER LCCP MQ3E.
 NORTHERN INDIANA PUB SERVICE
 SCHAHFER
 17
 NEW       421 MM (GROSS)
          421 MM (ESC)
 COAL
  3.20 XS  BITUMINOUS
 DUAL ALKALI
 FMC
 ENERGY CONSUMPTION: «*»*x
 STATUS 2     STARTUP  6/83
SCHAHFER 17 OF NORTHERN INDIANA PUBLIC SERVICE IS A 3.2X SULFUR COAL FIRED
UNIT UNDER CONSTRUCTION IN MHEATFIELD, INDIANA. FMC IS INSTALLING
A DUAL ALKALI FGD SYSTEM FOR S02 EMISSION CONTROL.  PARTICULATE
MATTER MILL BE COLLECTED BY AN ESP AND THE SYSTEM HILL INCLUDE A
REHEATER.  START-UP OF THIS UNIT IS SCHEDULED FOR JUNE 1983.
 NORTHERN  INDIANA PUB SERVICE
 SCHAHFER
 18
 NEW       421 MM (GROSS)
          421 MM (ESC)
 COAL
  3.20 XS  BITUMINOUS
 DUAL ALKALI
 FMC
 ENERGY CONSUMPTION: **»»x
 STATUS 3     STARTUP  6/8S
SCHAHFER IB OF NORTHERN INDIANA PUBLIC SEPVICE IS A 3.2X SULFUR COAL FIRED
UNIT PLANNED FOR CONSTRUCTION IN MHEATFIELO, INDIANA. THE UTILITY HAS
AMARDED A CONTRACT TO FMC FOR THE INSTALLATION OF A DUAL ALKALI
FGO SYSTEM AT THIS UNIT. PARTICULATE MATTER MILL BE COLLECTED BY AN ESP
AND THE SYSTEM MILL INCLUDE A REHEATER.  START-UP OF THIS UNIT IS
SCHEDULED FOR JUNE 1985.
 NORTHERN STATES POWER
 METRO COAL
 1
.NEW       200 MM  (GROSS)
          200 MM  (ESC)
NORTHERN STATES POWER HAS PLANS TO CONSTRUCT A 190 MM (NET) PULVERIZED COA
(l.OX S, 8700 BTU/LB) FIRED UNIT, METRO COAL 1. THE UNIT IS TO UTILIZE
A LIME SPRAY DRYING SYSTEM ALONG MITH FABRIC FILTERS TO CONTROL EMISSIONS.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1990.
  1.00 XS  SUBBITUMIHOUS
 LIME
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION: *»*»x
 STATUS 6     STARTUP  0/90
 NORTHERN STATES POMER
 RIVERSIDE
 6-7
 RETROFIT   110 MM  (GROSS)
           110 MM  (ESC)
 COAL
  1.20  XS   SUBBITUMINOUS
 LIME/SPRAY DRYING
 JOY  MFG/NIRO ATOMIZER
 ENERGY CONSUMPTION: *«**X
 STATUS 1     STARTUP 11/80
RIVERSIDE 6 AND 7 ARE TWO COAL FIRED BOILERS OWNED BY NORTHERN STATES
POKER AND LOCATED IN MINNEAPOLIS, MINNESOTA.  EACH BOILER GENERATES A FLUE
GAS FLOW OF 340,000 ACFM AT 350 F. CURRENTLY, A DEMONSTRATION LIME/SPRAY
DRYING FGD SYSTEM THAT IS CAPABLE OF TREATING THE FLUE GAS FROM BOTH
BOILERS IS BEING TESTED AT THIS UNIT. THE SYSTEM MAS SUPPLIED BY NIP.O
ATOMIZER/JOY MANUFACTURING AND CONSIST OF A SPRAY CRYE3 FOLLOWED BY
A BAGHOUSE.  THE CLEAN FLUE GAS IS VENTED TO TWO 275 FT CONCRETE STACKS
MITH FIRE BRICK LINERS.  SPENT ABSORBENT IS BEING DISPOSED OF IN AN
OFF-SITE LANDFILL.  OPERATIONS COMMENCED IN NOVEMBER 1980.
                                                31

-------
 EPA UTILITY F6D SLAVEY: OCTOBER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
NORTHERN STATES POUER
SHEPBUPNE
1
NEW       740 MM (C-°OSS)
          740 MM (ESC)
COAL
   .60 XS  SUBBITUMINOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:  Z.T/.
STATUS 1     STARTUP  3/76
NORTHERN STATES POWER'S SHERBUSHE 1 IS A BALANCED DRAFT PULVERIZED SL3BI-
TUMINCUS COAL (0.80X S, 8500 BTU/LB) FIRED EOILE9 IN BECKER, MINNESOTA. A
SOX EFFICIENT (DESIGN) LIMESTONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
CCKSUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MARCH
1976. TWELVE VARIABLE THROAT ROD DECK VENTU3I/MARBLE EED A3SCSBER TRAINS
ARE FOLLOWED BY CNc CHEVRON MIST ELIMINATOR/TRAIN, AN IN-LINE HOT WATER
REHEATER, AND A 650 FOOT COS-TEN LINED STACK.  THE SLUDGE IS F03CI2LY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LCOP IS OPEN.
NORTHERN STATES POWER
SHERBURNE
2
MEM       740 MM (GROSS)
          740 MM (ESC)
COAL
  .80 XS  SU33ITUMINCUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:  2.7X
STATUS 1     STARTUP  3/77
NORTHERN STATES POWER'S SHERBURNE Z IS A BALANCED DRAFT PULVERIZED SU33I-
TUMINOUS COAL (0.80X S, 8500 BTU/LB) FIRED BOILER IN BECKER, MINNESOTA. A
SOX EFFICIENT (DESIGN) LIMESTONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MARCH
1977. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MIST ELIMINATOR/TRAIN, AN IN-LINE HOT WATER
REHEATER, AND A 650 FOOT COR-TEN LINED STACK.  THE SLUDGE IS FORCIBLY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LOOP IS OPEN.
NORTHERN STATES POWER
SHERSURNE
3
NEW       660 MM (GROSS)
          810 MM (ESC)
COAL
 1.00 XS  SUBBITUMIHOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **>«x
STATUS 6     STARTUP  0/65
NORTHERN STATES POWER HAS PLANS TO CONSTRUCT A 800 MW (NET) PULVERIZED
COAL (l.OXS, 8700 BTU/LB) FIRED BOILER,  SHERBU^HE 3, TO BE LOCATED NEXT TO
THE SHERBURNE 1 AND 2 UNITS IN BECKER, MINNESOTA. THE UTILITY IS CONSID-
ERING THE USE OF A LIME SPRAY DRYING PROCESS ALONG WITH FABRIC FILTERS TO
CONTROL EMISSIONS. THE SYSTEM IS SCHEDULED TO COMMENCE OPERATIONS IN 1985.
PACIFIC GAS
MONTEZUMA
1
NEW
            t ELECTRIC
          800 MM (GROSS)
          800 MM (ESC)
COAL
  .80 XS  SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENEPGY CONSUMPTION:  3.5*
STATUS 6     STARTUP  6/93
MONTEZUMA 1 OF PACIFIC GAS AND ELECTRIC IS A COAL (0.8X S, 12,000 BTU/LB)
FIRED BOILER PLANNED FOR COLLINSVILLE, CALIFORNIA.  THE EMISSION CONTROL
SYSTEM WILL CONSIST OF A BAGHOUSE AND A LIMESTONE FGD SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START-UP IS SCHEDULED FOR 1993.
PACIFIC GAS & ELECTRIC
MCNTEZUMA
2
NEW       800 MM (GROSS)
          800 MM (ESC)
COAL
  .80 XS  SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  3.5X
STATUS 6     STARTUP  6/94
MONTEZUMA 2 OF PACIFIC GAS AND ELECTRIC IS A COAL (0.8X S, 12,000 BTU/LB)
FIRED BOILER PLANNED FOR COLLINSVILLE, CALIFORNIA.  THE EMISSION CONTROL
SYSTEM WILL CONSIST OF A BAGHOUSE AND A LIMESTONE FGO SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START-UP IS SCHEDULED FOR 1994.
PACIFIC POWER S LIGHT
JIM BRIOGER
1
RETROFIT  550 MM (GPOSS)
          550 MM (ESC)
COAL
  .56 XS  SU33ITUMINOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»««X
STATUS 6     STARTUP  0/88
PACIFIC POWER AND LIGHT'S JIM BRIDGER 1 IS A DRY BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB.) FIRED BOILER LOCATED IN POCK
SPRINGS, WYOMING.  THE UTILITY IS CURRENTLY INVESTIGATING A RETROFIT"FSO
SYSTEM FOR S02 CONTROL.  A WET, SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED.  A COLO-SIDE ESP IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE CONTROL.  START-UP IS SCHEDULED
FOR 1988.
                                                32

-------
                                              EPA UTILITY FGD  SURVEY:  OCTOBER  -  DECEMBER  1961
                                             SECTION Z
                                       STATUS OF  FGD SYSTEMS
UHIT IDENTIFICATION
                                                                 ABSTRACT
PACIFIC PCHER 4 LIGHT
JIM BRIDGER
2
RETROFIT  550 MM (GROSS)
          550 MM (ESC)
COAL
  .56 XS  SU2BITUMINOUS
SDDIIJM CAPEGNATE
VEHCOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6     STARTUP  0/90
PACIFIC POWER AND LIGHT'S JIM ERIDGER 2 IS A DRY EOTTOM PULVERIZED SL3-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB. ) FIPED BOILER LCCATE3 IH SCCK
SPRINGS, UYOMIHG.  THE UTILITY IS CURRENTLY INVESTIGATING A RETFCrIT FGQ
SYSTEM FOR S02 CONTROL.  A WET, SODIUM CAPEOMATE SYSTEM, UrtlCH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED.  A COLO-SIDE ESP IS CUSPENT-
LY IN OPERATION FOR PPIMARY PARTICULATE CONTROL.  START-UP IS SCHEDULED
FOR 1990.
PACIFIC POWER & LIGHT
JIM BRIDGER
2A
RETROFIT  550 MM (GROSS)
          100 MM (ESC)
COAL
  .56 XS  SU33ITUMINOUS
LIME/SODIUM CARBONATE
FLAKT
ENERGY CONSUMPTION:  »»**X
STATUS 2     STARTUP  1/82
PACIFIC POWER AND LIGHT'S JIM BRIDGER 2 IS A DRY BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB) FIRED BOILER LOCATED IN ROCK
SPRINGS, WYOMING.  THE UTILITY IS CURRENTLY CONSTRUCTING A DEMONSTRATION
LIME (ALSO SODIUM CARBONATE I/SPRAY DRYING FGD SYSTEM CAPABLE OF TPEATIN3
ONE SIXTH OF THE TOTAL FLUE GAS FLOW FRCM THE BOILER.  A SLIP STREAM OF
APPROXIMATELY 400000 ACFM AT 25O F FRCM DOWNSTREAM OF THE AIR FSEKEATER
MILL BE TREATED.  OUTLET GAS FROM THE SPRAY CPYER MILL THEN EE DUCTED BACK
PRIOR TO THE PRESENT COLO SIDE ESP.  THE SYSTEM IS SUPPLIED BY FLAKT AND
A/E IS A JOINT VENTURE BETWEEN FLAKT AND PACIFIC POWER ft LIGHT.  STARTUP
IS SCHEDULED FOR JANUARY 1982.
PACIFIC POWER ft LIGHT
JIM BRIOGER
3
RETROFIT  550 MU (GROSS)
          550 MU (ESC)
COAL
  .56 XS  SUBBITUMINQUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6     STARTUP  0/86
PACIFIC POWER AND LIGHT'S JIM BRIDGER 3 IS A DRY BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB.) FIRED BOILER LOCATED IN ROCK
SPRINGS. WYOMING.  THE UTILITY IS CURRENTLY INVESTIGATING A RETROFIT FGD
SYSTEM FOR S02 CONTROL.  A WET, SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED.  A COLD-SIDE ESP IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE CONTROL.  START-UP IS SCHEDULED
FOR 1986.
PACIFIC POWER ft LIGHT
JIM BRIDGER
4
NEW       550 MU (GROSS)
          550 MU (ESC)
COAL
  .56 XS  SUB3ITUMINOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION:    .2X
STATUS 1     STARTUP  9/79
PACIFIC POWER AND LIGHT'S JIM BRIDGER 4 IS A DRY BOTTOM PULVERIZED
SU3BITUMINOUS COAL (0.56X S, 9300 BTU/LB) FIRED BOILER LOCATED IN
ROCK SPRINGS. WYOMING. A 91X EFFICIENT SCDIUM CARBONATE FGD SYSTEM FOR
THIS UNIT MAS SUPPLIED BY THE AIR CORRECTION DIVISION OF UOP. A COLD
SIDE ESP TREATS 2,720,000 ACFM OF FLUE GAS, FOLLOWED BY THREE SIEVE
TRAY ABSORBERS. THE SYSTEM OPERATES IN A CLOSED MATER LOOP TQOE. A
SYSTEM CHECK OUT WAS CONDUCTED IN JULY 1979, AND OPERATIONS BEGAN
IN SEPTEMBER 1979.
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
HEW       917 MU (GROSS)
          917 MU (ESC)
 3.00 XS  BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:   6. OX
STATUS 1     STARTUP 12/75
BRUCE MANSFIELD 1 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.OX S, 11,500 BTU/LB) IM SHIPPINGPCST,
PENNSYLVANIA. A GEESI THIOSORBIC LIME FGO SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (92.IX) FROM 3,350,000 ACFM OF FLUE GAS. THE FGO SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIX FIXED
THROAT VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TV.O DIRECT COMBUS-
TION REHEATERS (INCLUDED IN ORIGINAL DESIGN BUT LATER REMOVED FROM
SERVICE) AND A 950 FOOT FLAKEGLASS STACK SHARED BY UNITS 1 AND 2.  THE
MATER LOOP IS OPEN. AND THE CALCILOX STABILIZED SLUDGE IS DISPOSED IN
AN OFF-SITE POND.  THIS SYSTEM HAS BEEN OPERATIONAL SINCE OECEI3ER 1975.
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
NEW       917 MU (GROSS)
          917 MU (ESC)
COAL
 3.00 XS  BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  6.OX
STATUS 1     STARTUP  7/77
BRUCE MANSFIELD 2 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.OX S. 11,500 BTU/LB) IN SHIPPINSP03T,
PENNSYLVANIA. A GEESI THIOSORBIC LIME FGD SYSTEM MAS DESIGNED TO RErOVE
FLYASH AND S02 (92.IX) FPOM 3,350,000 ACFM OF FLUE GAS. THE FGD SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIX FIXED
THROAT VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT CCT3US-
TION REHEATERS (INCLUDED IN ORIGINAL DESIGN BUT LATER REMOVED FPOM
SERVICE) AND A 950 FOOT FLAKEGLASS STACK SHARED BY UNITS 1 AND 2. THE
MATER LOOP IS OPEN, AND THE CALCILOX STABILIZED SLUDGE IS DISPOSED IN
AN OFF-SITE POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
                                                33

-------
 EPA UTILITY FGD SURVEY:  OCTOBER  - DECEMBER  1961
                                             SECTION 2
                                       STATUS OF  FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
PENNSYLVANIA TOMER
BRUCE MANSFIELD
3
HEW       917 MM (GROSS)
          917 KM (ESC)
COAL
 3.00 XS
LINE
M.H. KELLOGG
ENEPGY CONSUMPTION: «»»»x
STATUS 1     STARTUP  6/80
BPUCE MANSFIELD 3 OF PENNSYLVANIA POWER IS A SUPERCRITICAL PULVERIZED
COAL (3.OX S, 11,500 BTU/LB) FIRED BOILER LOCATED IH SHIPPIN3POPT,
PENNSYLVANIA. FOUR ESP'S TREAT 3,308,000 ACFM OF FLUE GAS, FOLLOWED
BY FIVE (ONE SPARE) M. M. KELLCGG THIOSORBIC LIME ABSCRBEPS WHICH
REMOVE 92.2X OF THE S02. THE CLEANED GAS PASSES THROUGH
CHEVRON MIST ELIMINATORS AND DIRECT CCr.3USTIQM REHEATERS BEFORE
DISCHARGE THROUGH A 600 FOOT INCONEL 625 STACK FLUE. THE FLYASH STA-
BILIZED SLUDGE IS PIPED TO AN OFF-SITE LANDFILL.  OPERATIONS COMMENCED
IN JUNE, 1980.
PHILADELPHIA ELECTRIC
CROKBY
1
RETROFIT  150 HU (GROSS)
          150 MM (ESC)
COAL
 3.00 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: «»*»X
STATUS 2     STARTUP  5/83
PHILADELPHIA ELECTRIC HAS PLANS FOR THE RETROFIT OF AN FGD SYSTEM ON ONE
OF THE TMO 3.OX SULFUR COAL FIRED BOILERS AT CROMBY STATION IN PHOEHIX-
VILLE, PENNSYLVANIA.  CONSTRUCTION OF THE MAGNESIUM OXIDE SYSTEM SUPPLIED
BY UNITED ENGINEERS HAS COMMENCED.  THE START-UP DATE IS SET FOR 1983.
PHILADELPHIA ELECTRIC
EDDYSTONE
1
RETROFIT  240 MM (GROSS)
          240 MM (ESC)
COAL
 2.60 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: *«*»X
STATUS 2     STARTUP 12/82
UNIT 1 OF PHILADELPHIA ELECTRIC'S EDDYSTONE,  PENNSYLVANIA STATION IS A
BITUMINOUS COAL (2.6X S, 13,600 BTU/LB) FIRED UNIT WHICH USES ESP'S,
MECHANICAL COLLECTORS, AND THREE PARTICLE SCRUBBERS (TMO ROD DECK SPRAY
TOWERS AND ONE VENTURI) FOR PRIMARY PARTICLE  CONTROL.  THE UNIT 1 FGD
SYSTEM MILL FOLLCM THE TMO ROD DECK SPRAY TOMERS.  UNITED ENGINEEPS
IS SUPPLYING A MAGNESIUM OXIDE FGD SYSTEM FOR S02 EMISSION CONTROL
SIMILAR TO THE MAGNESIUM OXIDE PROTOTYPE SYSTEM THAT MAS PREVIOUSLY
OPERATED AT THIS UNIT. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1982.
PHILADELPHIA ELECTRIC
EDOYSTONE
2
RETROFIT  334 MM (GROSS)
          334 MM (ESC)
COAL
 2.50 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: ****x
STATUS 2     STARTUP 12/82
EDDYSTONE 2 OF PHILADELPHIA ELECTRIC IS A 2.5X SULFUR COAL FIRED BOILER
LOCATED IN EDDYSTONE, PENNSYLVANIA.  THE PLANT'S GENERATING
CAPACITY IS 334 MM.  UNITED ENGINEERS WILL SUPPLY A MAGNESIUM OXIOE
FGO SYSTEM FOR EMISSION CONTROL. START-UP IS SET FOR DECEMBER 1982.
PLAINS ELECTRIC G & T
PLAINS ESCALANTE
1
NEM       233 MM (G10SS)
          233 MM (ESC)
COAL
  .80 XS  SUBBITUMINOU3
LIMESTONE
COMSUSTION ENGINEERING
ENERGY CONSUMPTION: «»*»X
STATUS 2     STARTUP 12/83
PLAINS ESCALANTE 1 IS A PULVERIZED SUBBITUMINOUS COAL FIRf UNIT PLANNED
BY PLAINS ELECTPIC G i T COOPERATIVE TO BE LOCATED IN PRExITT, NEW MEXICO.
THE 233 MM UNIT MILL UTILIZE A MET LIMESTONE SCRUBBING PROCESS FOR S02
REMOVAL AND A FABRIC FILTER FOR PRIMARY PARTICLE CONTROL.  A CONTRACT
HAS BEEN AMARDED TO COMBUSTION ENGINEERING FOR THE MET LIMESTONE SYSTEM.
THE UNIT INITIAL START-UP IS PROJECTED FOR DECEMBER 1933.
PLATTE RIVER POWER AUTHORITY
RAWHIDE
1
NEM       279 MM (GROSS)
          279 MM (ESC)
COAL
  .25 XS  BITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****•/.
STATUS 3     STARTUP 12/83
THE PLATTE RIVER POWER AUTHORITY HAS PLANS TO CONSTRUCT RAWHIDE 1, IN
FT. COLLINS, COLORADO.  THE 279 HW PULVERIZED COAL (0.25X S, 8702 BTU/LB)
FIRED BOILER MILL BE SUPPLIED BY COMBUSTION ENGINEERING.  A CONTRACT HAS
BEEN AWARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A DRY LIME SCRUBBING
SYSTEM FOR EMISSION CONTROL.  SLUDGE MILL BE DISPOSED OF IN A LANDFILL.
THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN DECEMBER 1983.

-------
                                              EPA  UTILITY FGO  SURVEY:  OCTOBER  -  DECEKSER  1931
                                             SECTION 2
                                       STATUS OF  FGO SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
PUBLIC SERVICE INDIANA
GIBSON
5
NEM       650 KM (GROSS)
          650 MM (ESC)
COAL
 3.50 XS
LIMESTONE
n.M. KELLOGG
ENERGY CONSUMPTION:  »»«*X
STATUS 2     STARTUP  6/82
GIBSON 5 OF PU3LIC SERVICE OF INDIANA IS A 3.3X SULFUR COAL FIPE3 UNIT
UNDER CONSTRUCTION IN PRINCETON. INDIANA.  A CONTRACT WAS AV,'i=DED TO
M. W. KELLOSG FOR A LIMESTONE FGO SfSTEM CONSISTING OF FCU3 KELLC33-
WEIR ABSORBER-REACTOR MC3ULES.  SYSTEM START UP IS EXPECTED IN 1S3C.  THE
SYSTEM WILL USE KELLOGG'S PROPRIETARY MAGNESIUM-PROMOTED LIMSSTCNE.
PUBLIC SERVICE OF NEM MEXICO
SAN JUAN
1
RETROFIT  361 MU (GROSS)
          361 MM (ESC)
COAL
  .80 XS  SUB3ITUMINOUS
UELLMAN LORD
DAVY KCKEE
ENERGY CONSUMPTION:   4.4X
STATUS 1     STARTUP  4/78
SAN JUAN 1 OF PUBLIC SERVICE OF NEM MEXICO IN MATESFLOW, HEM MEXICO IS A
COAL (0.8X S, 6100 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,000 ACFM OF
FLUE GAS TO A RETROFIT UELLMAN LORD FGO SYSTEM BY DAVY FGUESGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE APRIL 1973, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUE3EP/SFRAY TOMER ABSOR-
BER TRAINS U'HICH WERE DESIGNED TO REMOVE 85X OF THE FLUE GAS SOS. AM IN-
DIRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END FRC3UCT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE WATER LCCr IS
CLOSED.
PUBLIC SERVICE OF NEW 'MEXICO
SAN JUAN
2
RETROFIT  350 MM (GROSS)
          350 MM (ESC)
COAL
  .80 XS  SU3BITUMINOUS
MELLMAH LORD
DAVY MCKEE
ENERGY CONSUMPTION:   4.6X
STATUS 1     STARTUP  8/78
SAN JUAN 2 OF PUBLIC SERVICE OF NEM MEXICO IN MATEPFLOM, NEM MEXICO IS A
COAL (0.8X S, 8100 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,000 ACFM OF
FLUE GAS TO A RETROFIT MELLMAN LORD FGD SYSTEM BY DAVY FOWEPGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE AUGUST 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUBBER/SPRAY TCWER ABSOR-
BER TRAINS WHICH MERE DESIGNED TO REMOVE 85X OF THE FLUE GAS S02. AN IN-
DIRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END PRCOL'CT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE MATER LOOP IS
CLOSED.
PUBLIC SERVICE OF NEM MEXICO
SAN JUAN
3
NEH       534 MM (GROSS)
          534 MM (ESC)
COAL
  .80 XS  SUBBITUMINOUS
UELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION:   3.6X
STATUS 1     STARTUP 12/79
SAN JUAN 3 IS A COAL (0.8X S, 8100 BTU/LB) FIRED UNIT OF THE PUBLIC
SERVICE OF NEM MEXICO AND IS LOCATED IN MATERFLCM, NEM MEXICO. THE FGD
SYSTEM, SUPPLIED BY DAVY POUERGAS, UTILIZES THE MELLMAN LCRD S02 RECOVERY
RECOVERY PROCESS AND SULFURIC ACID IS PRODUCED AS THE END PRODUCT.
FIVE (ONE SPARE) VENTURI SCRUSBER/SPRAY TOMER ABSORBER (90X DE-
SIGN S02 REMOVAL) TRAINS FOLLCM A HOT SIDE ESP. AN INDIRECT HOT AIR
REHEATER BOOSTS THE GAS TEMPERATURE 50 DEC F. THE SYSTEM OPERATES
IN A CLOSED MATER LOOP MODE. OPERATIONS COMMENCED IN DECEMBER 1979.
PUBLIC SERVICE OF NEM MEXICO
SAM JUAN
4
NEH       534 MM (GROSS)
          534 MM (ESC)
CO&L
  .80 XS  SUBBITUMINOUS
MELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION:  3.6X
STATUS 2     STARTUP  6/82
SAN JUAN 4 IS A COAL (0.8X S, 8100 BTU/LB) FIRED UNIT OF THE PUBLIC SER-
VICE OF NEM MEXICO UNDER CONSTRUCTION IN UATERFLOM, NEH MEXICO. THE FGD
SYSTEM, BEING SUPPLIED BY DAVY POUERGAS, MILL UTILIZE THE UELLMAN LCRD
S02 RECOVERY PROCESS AND SULFURIC ACID HILL BE FRCOUCED AS THE Eta
PRODUCT. FIVE (ONE SPARE) VENTURI SCRUBBER/SPRAY TOMER AESOPEER (90X DE-
SIGN S02 REMOVAL) TRAINS HILL FOLLOH A HOT SIDE ESP. AN ItJDIPECT HOT AIR
REHEATER HILL BOOST THE GAS TEMPERATURE 50 OEG F. THE SYSTEM HILL OPERATE
IN A CLOSED HATER LOOP MODE. START-UP IS EXPECTED IN JUNE 1932.
PHR AUTHORITY OF STATE OF NY
FOSSIL

HEM       700 MM (GROSS)
          700 MM (ESC)
COAL
 3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ««»<*X
STATUS 6     STARTUP  4/87
THE POWER AUTHORITY OF NEH YORK PLANS A NEM 3.OX SULFUR COAL FIRED UNIT
WHICH HILL BE LOCATED AT THE ARTHUR KILL FACILITY ON STATEN ISLAIO. THE
UTILITY IS PRESENTLY CONSIDERING FGO SYSTEMS FOR THIS UNIT. PUBLIC SERVICE
COMMISSION HEARINGS ARE CURRENTLY IN PROGRESS. START-UP IS EXPECTED IN
APRIL 1987.
                                                35

-------
 EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
SALT PIVER PROJECT
CCRONAOO
1
MEM
          SUBBITUMINOUS
          350 MM (GROSS)
          280 MM (ESC)
COAL
  .50 XS
LIMESTONE
n.U. KELLOSG
ENEPGY CONSUMPTION;   4.3X
STATUS 1     STARTUP 11/79
SALT RIVER PROJECT'S CORONAOO 1 IS A DRY BOTTOM PULVEPIZED S'JSBITL'MINOUS
COAL (0.5X S, 12,000 BTU/LB)  FIRED BOILER LOCATED  IN ST.  JOHNS.
ARIZONA.  M. 14. KELL033 SUPPLIED THE TWO LIMESTONE HORIZONTAL WEI? SP3AY
TOWERS WHICH REMOVE 82.5X OF  THE S02 FROM THE  FLUE GAS PASSED THROUGH
THEM. VERTICAL HEIL MIST ELIMINATORS PFECEDE A 500 FOOT STACK. A MINIMUM
OF 20X BYPASS PROVIDES REHEAT.  THE WATER LOOP  IS OPEN, AND THE
UNSTABILIZED SLUDGE IS DISPOSED OF IN AN UNLINED POND. START-UP WAS
IN NOVEMBER 1979.
SALT RIVER PROJECT
CORONADO
2
NEW
          350 MW (GROSS)
          280 MW (ESC)
COAL
  .50 XS  SUSBITUMINOUS
LIMESTONE
M.M. KELLOGG
ENEPGY CONSUMPTION:  4.3X
STATUS 1     STARTUP  7/80
                               SALT RIVER PROJECT'S C030NAOO  2  IS A DRY BOTTOM PULVERIZED SUSBITUMIHC'JS
                               COAL (0.5X S,  12,000 BTU/LB) FIRED BOILER  LOCATED  IN ST.  JOHNS,  ARIZONA.
                               M.  M. KELLOGG  SUPPLIED  TWO  LIMESTONE HORIZONTAL WEIR SPRAY TCWEPS
                               WHICH REMOVE 82.5X OF THE S02  FROM THE FLUE GAS PASSED THROUGH
                               THEM. VERTICAL HEIL MIST ELIMINATORS PRECEDE A 500 FOOT STACK. A MINIMUM
                               OF  20X BYPASS  PROVIDES  REHEAT. THE WATER LOOP IS OPEN, AND THE
                               UNSTABILIZED SLUDGE IS  DISPOSED  OF IN AN UNLINED POND. START-UP  WAS  IN
                               JULY I960.
SALT RIVER PROJECT
CORONAOO
3
NEW
          400 MW (GROSS)
          280 MW (ESC)
COAL
  .60 XS  SUSBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  3.8X
STATUS 6     STARTUP  0/89
                               COROHADO 3 IS A DRY BOTTOM PULVERIZED SUBBITUMINOUS COAL  1.607. S,  8300  BTU
                               /LB) FIRED UNIT PLANNED  BY SALT  RIVER PROJECT TO BE LOCATED  IN ST. JOHN'S.
                               ARIZONA. THE UTILITY IS  PRESENTLY  CONSIDERING THE  INSTALLATION OF  TWO HOR-
                               IZONTAL SPRAY TOWERS UTILIZING LIMESTONE AS THE ABSORBENT. PLANS FOR  AN
                               EMISSION CONTROL SYSTEM  HAVE  NOT BEEN FINALIZED. THE SYSTEM  HILL HAVE A
                               20X BYPASS REHEAT,  AND THE SLUDGE  WILL PROBABLY BE PONDED. SCHEDULED  OPER-
                               ATION DATE 19 1989.
SAN MIGUEL ELECTRIC
SAN MIGUEL
1
NEW       400 MM (GROSS)
          400 MM (ESC)
COAL
 1.70 XS  LIGNITE
LIMESTONE
BABCOCK 4 WILCOX
ENERGY CONSUMPTION:  5.OX
STATUS 1     STARTUP  8/81
                               SAN MIGUEL 1 OF THE SAN MIGUEL ELECTRIC COOP  IS A  LIGNITE  (1.7X S,  5000
                               BTU/LB) FIRED RADIANT BOILER  LOCATED  IN SAN MIGUEL, TEXAS.   THE
                               EMISSION CONTROL SYSTEM ON THIS UNIT  CONSISTS OF A COLD  SIDE ESP FOL-
                               LOWED BY FOUR BABCOCK AND  WILCOX 86X  EFFICIENT LIMESTONE TCA MODULES.
                               CHEVRON MIST ELIMINATORS PRECEDE AN IN-LINE REHEATEP  AND AN  ACID
                               BRICK LINED STACK.  THE WATER  LOOP IS  CLOSED,  AND THE  DEWATERED  SLURRY
                               IS MIXED WITH FLYASH BY RESEARCH COTTRELL AND DISPOSED OF  IN AN OFF-SITE
                               LANDFILL. OPERATIONS COMMENCED IN AUGUST 1981.
SEMINOLE ELECTRIC
SEMINOLE
1
NEW       620 MM (GROSS)
          620 MM (ESC)
COAL
 2.75 XS  SUBBITUMINOUS
LIMESTONE
PEABCDY PROCESS SYSTEMS
ENERGY CONSUMPTION:  »«»*x
STATUS 2     STARTUP  3/83
                               SEMINOLE 1 OF SEMINOLE  ELECTRIC  IS A COAL  (2.75X  S, 11,700'BTU/LB)  FIRED
                               UNIT PLANNED FOR LOCATION IH PALATKA. FLORIDA. THE EMISSION  CONTPOL SYSTEM
                               WILL CONSIST OF ESP'S AND A  LIMESTONE FGD  SYSTEM. THE  FGO  SYSTEM WILL BE
                               SUPPLIED BY PEABODY PROCESS  SYSTEMS. START-UP IS  EXPECTED  IN MARCH
                               1983.
SEMINOLE ELECTRIC
SEMINOLE
2
HEM
          620 MM (GROSS)
          620 MM (ESC)
COAL
 2.75 XS  SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION:  ««»«X
STATUS 3     STARTUP  1/85
                               SEMINOLE 2 OF SEMINOLE  ELECTRIC  IS A COAL  (2.75X S,  11,700 BTU/LB)  FIRED
                               UNIT PLANNED FOR LOCATION IN PALATKA, FLORIDA. THE EMISSION CCNTPCL SYSTEM
                               MILL CONSIST OF ESP'S AND A  LIMESTONE FGD  SYSTEM. THE  FGD SYSTEM  WILL BE
                               SUPPLIED BY PEABODY SYSTEMS.  START-UP IS EXPECTED IN JANUARY  1985.
                                                36

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                                              EPA UTILITY  FGO  SURVEY:  OCTOBER  - DECEMBER  1931
                                             SECTION 2
                                       STATUS OF  FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
SIERRA PACIFIC POWER
VALMY
2
NEH       276 MM (GROSS)
          276 MM (ESC)
COAL
***«» ;:s
LIME/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: WHWX
STATUS 7     STARTUP  8/8*
SIERRA PACIFIC POWER HAS PLANS TO CONSTRUCT A 276 MM UNIT TO 5E LCCATEO
IN VALMY, NEVADA.  THE FOSTER MHEELEH PULVERIZED COAL FIRED EOILER AT THE
VALMY 2 STATION MILL UTILIZE AN FGD SYSTEM OR FIRE LCW SULFUR CC',L TO
CONTROL S02 EMISSIONS.  IF FGD IS SELECTED, A CRY LIMi SYSTEM HILL SE
UTILIZED.  THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IH AUGUST 1934.
SIKESTON BRD OF MUNICIPAL UTIL
SIKESTOH
1
NEW       235 MM (GROSS)
          235 MM (ESC)
COAL
 2.80 XS  BITUMINOUS
LIMESTONE
BABCQCK » UILCOX
ENERGY CONSUMPTION:  1.7X
STATUS 1     STARTUP  6/61
THE SIKESTON BOARD OF MUNICIPAL UTILITIES' SIKESTCN 1 IS A PULVERIZED COAL
(2.6X S, 11,340 BTU/LB) FIRED BOILER LOCATED IN SIKESTON, MISSOURI.
BABCOCK AND UILCOX SUPPLIED THE EMISSION CONTROL SYSTEM CONSIST-
ING OF TWO ESP'S AND THREE SOX CAPACITY LIMESTONE VENTURI FGD MODULES. THE
CLEANED GAS PASSES THROUGH CHEVRON MIST ELIMINATORS BEFORE EXITING A
454 FOOT FRP LINED FLUE (A SECOND CARBON STEEL LINED FLUE, USED FOR EMER-
GENCY BYPASS, IS ALSO IN THE STACK). THE HATER LOCP MODE IS OPEN, AMD THE
SLUDGE IS PONDED.  THE SYSTEM STARTED OPERATIONS IN JUNE 1981.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
1
NEM       500 MM (GROSS)
          500 MM (ESC)
COAL
 1.80 XS  BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: »*»*X
STATUS 3     STARTUP  5/88
SOUTH CAROLINA PUBLIC SERVICE HAS PLANS TO CONSTRUCT TWO NEW UNITS,
CROSS 1 AND 2, TO BE LOCATED IN CROSS, SOUTH CAROLINA.  EACH 500 MM
BOILER MILL FIRE COAL WITH A SULFUR CONTENT RANGING BETWEEN 1.0 AND 2.3X.
THE UTILITY HAS SIGNED A CONTRACT WITH PEABODY PROCESS SYSTEMS FOR THE
INSTALLATION OF A MET LIMESTONE SCRUBBING SYSTEM TO CONTROL S02
EMISSIONS.  UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS IN MAY 19S8.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
2
NEM       500 MM (GROSS)
          500 MM (ESC)
COAL
 1.80 XS  BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ***»•/.
STATUS 2     STARTUP 11/83
SOUTH CAROLINA PUBLIC SERVICE HAS PLANS TO CONSTRUCT TWO MEW UNITS,
CROSS 1 AND 2, TO BE LOCATED IN CROSS, SOUTH CAROLINA.  E'-CH SCO MM
BOILER WILL FIRE COAL WITH A SULFUR CONTENT RANGING BETWEEN 1.0 AND 2.3X.
CONSTRUCTION OF THE MET LIMESTONE SCRUBBING SYSTEM BEINS SUPPLIED
BY PEABODY PROCESS SYSTEMS FOR 302 CONTROL HAS COMMENCED.  UNIT 2 IS
SCHEDULED TO COMMENCE OPERATIONS IN NOVEMBER 1983.
SCUTH CAROLINA PUBLIC SERVICE
MIHYAH
2
HEN       280 MM (GROSS)
          140 MM (ESC)
COAL
"1.10 XS  BITUMINOUS
LIMESTONE
BABCOCK & HILCOX
ENERGY CONSUMPTION:  1.1X
STATUS 1     STARTUP  7/77
WINYAH 2 OF SOUTH CAROLINA PUBLIC SERVICE IS A PULVEPIZED BITUMINOUS COAL
(1.70X S, 11,500 BTU/LB) FIRED UNIT LOCATED IN GEORGETOWN, SOUTH CAROLINA.
A COLD SIDE ESP AND A BABCOCK AND WILCOX VENTURI SCRU2SER/LIKESTCNE TRAY
TOMER ABSORBER TRAIN DESIGNED TO REMOVE 45X OF THE 502 F.=OM THE EOILE°
FLUE GAS MAKE UP THE EMISSION CONTROL SYSTEM ON THIS UNIT. THE SYSTEM
OPERATES IN AN OPEN MATER LOOP, AND THE SLUDGE IS DISPOSED IN AH CM-SITE
UNLINED POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
SOUTH CAROLINA PUBLIC SERVICE  WINYAH 3 OF SOUTH CAROLINA PUBLIC SERVICE IS A DRY BOTTOM BOILER WHICH
WINYAH
3
HEM       280 MM (GROSS)
          280 MM (ESC)
COAL
 1.10 XS
LIMESTONE
BABCOCK t HILCOX
ENERGY CONSUMPTION:  2.IX
STATUS 1     STARTUP  5/80
 FIRES  1.7X SULFUR COAL (11.500 BTU/LB) AND IS LOCATED IN GECSGiTCWN,
 SOUTH  CAROLINA. AN ESP PRECEDES A BABCOCK AND UILCOX LIMESTONE FGD
 SYSTEM AND AN INDIRECT STEAM REHEATER. THE SYSTEM OPERATES IN A CLCSE9
 MATER  LOOP MODE. OPERATIONS COMMENCED IN MAY 1980.
                                                37

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 EPA UTILITY FC-0 SURVEY:  OCTCSER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
SOUTH CAPOLIHA PUBLIC SERVICE  SOUTH CAROLINA PUBLIC SERVICE'S  UINYAH 4  IS  A   BITL'MIUCUS  COAL (1.70X  S,
WIN f AH
4
NEW       289 MM (G30SS)
          280 MM (ESC)
COAL
 1.70 XS  BITUMINOUS
LIMESTONE
AMEPTCAN AIR FILTER
ENEEJY CONSUMPTION:  z.ix
STATUS 1     STARTUP  7/81
11,500 BTU/LB) PIPED UNIT LOCATED IN GEORGETOWN, SOUTH CAPCLINA.
TWO AMERICAN AIR FILTER LIMESTONE SLUPRY SFPAY TOWERS FOLLOW AN ESP.
THE TEMPERATUPE OF THE CLEANED GAS IS PAISEO BY AN INDIRECT STEAK
PEHEATER. THE SYSTEM OPERATES IN A CLOSED HATER LOOP HC3E.   INITIAL
OPERATIONS COMMENCED IN JULY 1931.
SOUTH MISSISSIPPI ELEC PKH
R.D. MORROW, SR.
1
NEW       ZOO MM (GROSS)
          124 MM (ESC)
COAL
 1.30 XS  BITUMINOUS
LIMESTONE
ENV1ECNEERIN3, RILEY STOKER
ENERGY CONSUMPTION:   5.57.
STATUS 1     STARTUP  8/78
R.O. MORROW 1 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVERIZED COAL (1.3X
S, 12.000 BTU/LB) FIRED UNIT IN HATTISBURG, MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LIMs-
STONE VENTRI-ROD ABSORBER SUPPLIED BY RILEY STOKER/ENVIBCiJEEP.ING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATCR, IT IS
JOINED BY A 38X BYPASS REHEAT BEFORE IT IS DISCHARGED TKPC'JC-H A 403 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID ERICK LINED
FLUE). THE MATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUCGE IS
HAULED BY TRUCK TO AN OFF-SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE AUGUST 1978.
SOUTH MISSISSIPPI ELEC PMR
R.D. MORROW, SR.
2
NEM       200 MM (GROSS)
          1C4 MM (ESC)
COAL
 1.30 XS  BITUMINOUS
LIMESTONE
ENVIRCNEERING, RILEY STOKER
ENERGY CONSUMPTION:  5.57.
STATUS 1     STARTUP  6/79
R.D. MORROM 2 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVEPIZEO COAL (1.3X
S. 12.000 BTU/LB) FIRED UNIT IN HATTISSUP.G, MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-ROD ABSOPBER SUPPLIED BY RILEY STOKEP/ENVIRCNEERING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATC?, IT IS
JOINED BY A 38X BYPASS REHEAT BEFORE IT IS DISCHARGED THPOUSH A 408 FCOT
STACK SHARED BY UNITS 1 AND Z (EACH UNIT HAS ITS OWN ACID ERICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLU3GE IS
HAULED BY TRUCK TO AN OFF-SITE LANDFILL. THE SYSTEM HAS SEEN OPERATIONAL
SINCE JUNE 1979.
SOUTHERN ILLINOIS POWER
MARION
4
NEM       173 MM (GROSS)
          173 MM (ESC)
COAL/REFUS
 3.75 XS  BITUMINOUS
LIMESTONE
BAECOCK » MILCOX
ENERGY CONSUMPTION:  2.3X
STATUS 1     STARTUP  5/79
UNIT * AT SOUTHERN ILLINOIS POWER COOP'S MARION STATION IN MARION, ILLI-
NOIS IS A CYCLONE FIRED COAL (3.5X S. 9000 BTU/LB) BOILER WHICH IS SERVED
BY A 89.4X EFFICIENT (DESIGN) LIMESTONE FGD SYSTEM SUPPLIED 3Y EASCCCK AND
HILCOX. TWO SPRAY TOMERS AND A BRICK LINED STACK ARE DOWNSTREAM OF AN ESP
IN THIS SYSTEM. THE HATER LOOP IS OPEN, AND THE FLYASH STABILIZED SLU33E
IS DEHATERED AND LANOFILLEO. THE SYSTEM BECAME OPERATIONAL DURING MAY
1979.
SOUTHERN INDIANA GAS S ELEC
A.B. BROWN
1
MEM       265 MM (GROSS)
          265 MM (ESC)
COAL
 3.35 XS  BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION:    .ax
STATUS 1     STARTUP  3/79
SOUTHERN INDIANA GAS AND ELECTPIC'S A.B.BPCUN 1 IS A DRY BOTTOM PULVERIZED
COAL (3.35X S, 13,010 BTU/LB) FIRED UNIT IN WEST FRANKLIN, INDIANA. FMC
SUPPLIED A DUAL ALKALI FGD SYSTEM DESIGNED TO REMOVE 8SX OF THE FLUE GAS
S02. THE UNIT CONSISTS OF TWO THREE STAGE DISC CCNTACTOPS. A COLD SIDE ESP
PROVIDES PRIMARY PAHTICULATE CONTROL, AND ONE CHEVRON MIST ELIMINATCS/MOD-
ULE PRECEDES A 498 FOOT ACID BRICK LINED STACK. THE SYSTEM FSOSUCES A
FILTER CAKE HASTE PRODUCT WHICH IS DISPOSED IN AN CM-SITE LANDFILL. THE
HATER LOOP CAN BE EITHER OPEN OR CLOSED. THE SYSTEM HAS BEEN OPERATIONAL
SINCE MARCH 1979.
SOUTHERN INDIANA GAS t ELEC
A.B. BROWN
2
          265 MM (GROSS)
          265 MM (ESC)
COAL
 3.35 XS  BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:   .8X
STATUS 5     STARTUP  1/85
SOUTHERN INDIANA GAS AND ELECTRIC HAS PLANS TO CONSTRUCT ANOTHER UNIT,
A.B. BROWN Z, TO BE LOCATED IN WEST FRANKLIN, INDIANA.  THE 265-MM (G30SS)
UNIT HILL FIRE BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 3.35X.
A CCLD SIDE ESP HILL PROVIDE PRIMARY PARTICULATE MATTER CONTROL AND AN
FGO SYSTEM HILL BE USED TO CONTROL S02 EMISSIONS.  THE FLUE GAS HILL EXIT
THROUGH A 498-FOOT STACK.  THE SYSTEM HILL OPERATE IN A CLOSED HATER LCOP
MODE AND THE SLUDGE HILL BE DISPOSED IN AN CN-SITE LANDFILL.  OPERATIONS '-
ARE SCHEDULED TO COMMENCE IN JANUARY 1965.
                                                38

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                                              EPA UTILITY  FGO  SURVEY:  OCT03EP  -  DECEMBER  1<>81

                                             SECTION 2
                                       STATUS OF  FGO SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
SOUTHWESTERN ELECTRIC POWER
DCLET HILLS
1
NEW       720 MM (GROSS)
          720 MM (ESC)
COAL
  .70 XS  LIGNITE
LIMESTONE
AIR CCPPECTION DIVISION,  UOP
ENERGY CONSUMPTION:  »***X
STATUS 3     STARTUP  3/86
           OOLET HILLS  1 OF  SOUTHWESTERN  ELECTRIC  FOWE"  IS A  PLANNED  720 MM  LIC-NITE
           (0.7XS,  7100 BTU/LB)  FIREO BOILER TO BE LOCATED IN MANSFIELD, LCUiSIASU.
           THE  EMISSION CONTROL  SYSTEM HILL CONSIST OF AN ESP FCP  FAFTICULATE CONTROL
           AND  A MET  LIMESTONE FGD  SYSTEM FOR S02  CONTROL.  THE FLUE  GAS MILL EXIT
           THROUGH  A  525 FOOT STACK.  A CONTRACT HAS SEEN AWAFDEO  TO  UO? FCS THE FGO
           SYSTEM.  THE UNIT IS  SCHEDULED TO START-UP IN 1986.
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS
2
HEW       720 KM (GROSS)
          720 MM (ESC)
COAL
  .70 XS  LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»*»X
STATUS 6     STARTUP  0X88
           OOLET HILLS  2 OF  SOUTHWESTERN  ELECTRIC  POWER  IS A  PLANNED  720 MU  LIGNITE
           (0.7XS,  7100 BTU/LB)  FIREO  BOILER TO BE LOCATED IN MANSFIELD, LOUISIANA.
           THE  EMISSION CONTROL  SYSTEM MILL CONSIST OF AN ESP FOR  PARTICULAR CONTROL
           AND  A MET  LIMESTONE FGD  SYSTEM FOR  S02  CONTROL.  THE  FLUE  GAS MILL EXIT
           THROUGH  A  525 FOOT STACK.   THE UNIT IS  SCHEDULED TO BEGIN  OPERATIONS IN
           1988.
SOUTHWESTERN ELECTRIC POWER
HENRY M. PIRKEY
1
NEM       720 MM (GROSS)
          720 MM (ESC)
COAL
  .80 XS  LIGNITE
LIMESTONE
AIR CORRECTION DIVISION. UOP
ENEPGY CONSUMPTION: »*«»x
STATUS 3     STARTUP 12/84
            HENRY  M.  PIRKEY 1  IS A MET BOTTOM LIGNITE  (O.SX S,  6300  BTU/LB)  FIPED UNIT
            PLANNED BY SOUTHWESTERN ELECTRIC POMER  FOR LOCATION IN HALLSVILLE,  TEXAS.
            A CONTRACT HAS BEEN AWARDED TO THE AIR  CORRECTION DIVISION  OF  UOP FOR FOUR
            LIMESTONE SPRAY TOWERS (99*X EFFICIENCY).  MIST  ELIMINATION  HILL  BE  PPO-
            VIDED  BY  TWO STAGE CHEVRONS,  AND THE  STACK MILL BE  ACID  B^ICK  LIKED. NO
            REHEAT IS PLANNED. THE MATER LOOP HILL  BE  CLOSED, AND THE SLUDGE MILL BE
            POZ-0-TEC STABILIZED. START-UP IS EXPECTED BY DECEMSER 1984.
SOYLAND
SOYLAND
1
NEM
        POMER
          500 MM (GROSS)
          500 MM (ESC)
COAL
 3.00 XS  UNDECIDED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »«»*X
STATUS 6     STARTUP  6/87
            SOYLAND  POMER  COOP HAS PLANS FOR A NEH UNIT,  SOYLAND  1.  TO BE  LOCATED  IN
            ILLINOIS.   THE COAL FIRED BOILER IS TO BE  RATED  AT 500 MW (GROSS)  AND  UTI-
            LIZE A FGD SYSTEM TO CONTROL EMISSIONS. OPERATIONS ARE  SCHEDULED  TO COM-
            MENCE IN 1987.
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
NEH       194 MM (GROSS)
          194 MM (ESC)
COAL
 3.50 XS  BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION:  4.6X
STATUS 1     STARTUP  4/77
            SPRINGFIELD CITY UTILITIES'  SOUTHWEST 1  IS A PULVERIZED BITUMINOUS  COAL
            (3.5X S.  12,500 BTU/LB) FIRED BOILER LOCATED IN SPRINGFIELD,  MISSC'JPI. THE
            EMISSION  CONTPOL SYSTEM FOR  THIS UNIT CONSISTS OF A COLO SIDE ESP FOLLCWED
            BY TUO UOP LIMESTONE TCA MODULES WHICH HERE DESIGNED TO PEMOVE 60X  CF THE
            FLUE GAS  S02.  ONE CHEVRON/MODULE LEADS TO A 384 FOOT CEILCOTE LINED STACK.
            THE DRY FLYASH STABILIZED SLUDGE IS DEUATERED BY A ROTARY DRUM VACUUM FIL-
            TER AND TRUCKED TO A LANDFILL. OPERATIONS COMMENCED IN APRIL  1977.
SPRINGFIELD HATER,
OALLMAN
3
NEM
          205 KM (GROSS)
          185 KM (ESC)
COAL
 3.30 XS  BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  4.9X
STATUS 1     STARTUP 12/80
LIGHT t FHR OALLMAN 3 OF SPRINGFIELD MATER,  LIGHT,  AND POME? IS A PULVERIZED  COAL
            (3.3X S, 10,500 BTU/LB) FIRED BOILER LOCATED IN SFRIN3FIELD,  ILLINOIS.
            RESEARCH COTTRELL SUPPLIED A LIMESTONE  FGD SYSTEM DESIGNED  TO REMOVE
            95X OF THE S02 FROM 650,000 ACFM OF BOILER FLUE GAS.   A HOT SIDE  ESP
            PRECEDES TWO PACKED TOMER ABSORBERS, ONE HORIZONTAL CHEVRON PER MODULE,
            AND A 500 FOOT ACID BRICK LINED  STACK.   NO PEHEAT IS PROVIDED. SLU23E  IS
            DISPOSED OF IN A LANDFILL.  FGD  OPERATIONS COMMENCED IN OCTOBER
                                                39

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
                                             SECTION 2
                                       STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
ST. JOE ZIMC
G.F. WEATON
1
RETROFIT   60 MM (GROSS)
           60 MM (ESC)
COAL
 3.00 XS  BITUMINOUS
CITFATE
f.C=HISON & KNUDSEN/U.S.B.M.
ENERGY CONSUMPTION: **«»X
STATUS 1     STARTUP 11/79
G.F. WEATON 1, OWNED BY ST. JOE ZINC, IS A COAL (2. OX S, 12,500 BTU/LB)
FIRED BOILER LOCATED IN MCNACA, PENNSYLVANIA.  THE BUREAU OF MIMES RE-
TROFITTED A PROTOTYPE CITRATE FGO SYSTEM OH THIS UNIT, WHICH PROVIDES
POWER FOR THE LOCAL UTILITY GRID. ONE VENTUSI  SCRUSBER/ABSCSSER TPAIM
FOLLOWS A COLD SIDE ESP. TWO CHEVSON MIST ELIMINATORS APE FOLLOWED BY
A COMBINATION OF INDIRECT HOT AIR AND DIRECT COKSUSTION EEHEATERS, AMD A
102 FOOT FIBERGLASS LINED SCRUBBER STACK. THE  SYSTEM S32 PEKOVAL EFFICIEN-
CY WILL BE OVER 90X. THE HATER LOOP IS CLOSED  LOOP MODE. THE FGD SYSTEM
COMMENCED OPERATION IN NOVEMBER 1979.
SUNFLOWER ELECTRIC
HOLCOMB
1
NEW       347 MM (GROSS)
          347 MM (ESC)
COAL
  .47 XS  SU3BITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION:   .9X
STATUS 2     STARTUP  9/83
SUNFLOWER ELECTRIC COOP'S HOLCOMB 1 STATION IS A PLANNED 347 MM UNIT TO BE
LOCATED IN HOLCOMB, KANSAS.  THE PULVERIZED COAL (0.47X S, 8300
BTU/LB) FIRED BA8COCK AND HILCOX BOILER WILL UTILIZE A JOY MANUFACTURING/
NIRO ATOMIZER DRY SCRUBBING PROCESS FOR SC2 CONTROL.  A FABRIC FILTER
WILL BE UTILIZED FOR PRIMARY PARTICLE CONTROL.  THE UNIT IS SCHEDULED
TO COMMENCE OPERATIONS IN THE FALL OF 1983.
TAM°A ELECTRIC
BIG BEND
4
NEM       475 MM (GROSS)
          475 MM (ESC)
COAL
 2.35 XS
LIME/LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  2.IX
STATUS 3     STARTUP  3/85
UNIT 4 AT TAMPA ELECTRIC1S BIG BEND STATION IS A PLANNED DRY BOTTOM PUL-
VERIZED COAL (2.35X S, 10,300 BTU/LB) FIRED UNIT TO BE LOCATED IN TAMPA,
FLORIDA. A CONTRACT HAS BEEN AWARDED TO RESEARCH-COTTRELL F0
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                                              EPA UTILITY FGD  SURVEY:  OCTOBER  -  DECEMBER  1931
                                             SECTION 2
                                       STATUS OF  FG3 SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
TENNESSEE VALLEY AUTHORITY
S-IAUNEE
1C3
RETROFIT   10 MM (GROSS)
           10 MM (ESC)
COAL
 2.93 XS  BITUMINOUS
LIME/LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: *«»*X
STATUS 1     STARTUP  4/72
                               SHAWNEE 10 OF TVA IS A 2.9X SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
                               PAOUCAH, KENTUCKY. MODULE 1CB IS A RETROFIT PROTOTYPE LirE/LirESTCNH VEN-
                               TURI SCRUBBER/SPRAY TOMER ABSORBER SUPPLIED BY GEESI. THE SYSTEM, CFE=A-
                               TIONAL SINCE APRIL 1972, INCLUDES A CHEVRON MIST ELIMINATOR AN3 A BISECT
                               COMBUSTION REHEATER, AND OPERATES IN A CLOSED WATER LOOP. THIS TEST PPO-
                               GRAM MAS FUNDED BY EPA WITH TVA AS THE CONSTRUCTS AND FACILITY OPEPA-
                               TOH. THE BECHTEL CORP. OF SAN FRANCISCO WAS THE MAJCH CONTSACTOR, TEST DI-
                               RECTOR, AND REPORT WRITER.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
7
RETROFIT  575 KM (GROSS)
          575 KM (ESC)
COAL
 3.70 XS  BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »<*»X
STATUS 1     STARTUP  3/81
                               WIDOWS CREEK 7 IS A PULVERIZED BITUMINOUS COAL (3.7X S. 11,100 BTU/LB)
                               FIRED BOILER OF TVA LOCATED IN BRIDGEPORT, ALABAMA. COMBUSTION ENGINEERING
                               SUPPLIED A LIMESTONE VENTRI ROD SCRUBBER/SPRAY TCWER ABSGPBE3 FGO SYSTEM
                               ON THIS UNIT.  AN ESP PRECEDES THE SCRUBBING TRAIN, AND A COMBINATION OF
                               A BULK ENTRAINMENT SEPERATOR, TWO CHEVPCN MIST ELIMINATORS AND A FINNED
                               TUBE REHEATER FOLLOWS THE SYSTEM.  THE SCRUBBER SLUDGE IS DISPOSED OF
                               IN A SLUDGE POND.  OPERATIONS COMMENCED IN MARCH 1981.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
RETROFIT  550 KM (GROSS)
          550 KM (ESC)
COAL
 3.70 XS  BITUMINOUS
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION:  4.7X
STATUS 1     STARTUP  5/77
                               WIDOWS CREEK 8 OF TVA IS A BALANCED DRAFT, TANGENTIALLY FIRED COAL (3.7X
                               S, 10.000 BTU/LB) BOILER IN BRIDGEPORT, ALABAMA. TVA RETROFITTED THIS UNIT
                               WITH A LIMESTONE FGD SYSTEM (BOX DESIGN S02 REMOVAL EFFICIENCY) WHICH BE-
                               GAN OPERATIONS IN HAY 1977. AN ESP PRECEDES FOUR VARIABLE THROAT VENTURI
                               SCRUBBER/KULTIGRID TOMER ABSORBER TRAINS (ONE OF THE TOWERS IS PACKED).
                               ONE VERTICAL CHEVPON/TRAIN AND AN INDIRECT HOT AIR REHEATER ARE INCLUDED
                               IN THE SYSTEM. SLUDGE FROM THE FGD SYSTEM IS PONDED.
TEXAS MUNICIPAL POWER AGENCY
GIESONS CREEK
1
NEM       443 KM (GROSS)
          400 MM (ESC)
COAL
 1.06 XS  LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:  1.4X
STATUS 2     STARTUP 10/82
                               GIBBONS CREEK 1 OF THE TEXAS MUNICIPAL POWER AGENCY IS A DRY BOTTOM PUL-
                               VERIZED LIGNITE (1.06X S, 4860 BTU/LB) FIRED UNIT PLANNED FOR LOCATION IN
                               CARLOS, TEXAS. THE EMISSION CONTROL SYSTEM MILL CONSIST OF A COLD SIDE ESP
                               FOLLOWED BY THREE SOX CAPACITY LIMESTONE SPPAY TOWERS. A CONTRACT HAS BEEN
                               AMARDED TO COMBUSTION ENGINEERING FOR THE FGD SYSTEM, WHICH INCLUDES A
                               CHEVRON MIST ELIMINATOR AND A STEAK COIL REHEATER. CLEANED FLUE GAS WILL
                               BE DISCHARGED THROUGH A 465 FOOT ACID BRICK LINED STACK. THE POZ-0-TEC
                               STABILIZED SLUDGE MILL BE USED AS STRIP MINE LANDFILL. START-UP
                               IS EXPECTED IN OCTOBER 1982.
TEXAS POWER I LIGHT
SANDOM
4
NEM       545 KM (GROSS)
          382 KM (ESC)
(COAL
 1.60 XS  LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: JHHHtX
STATUS 1     STARTUP 12/80
                               SAHDOM 4 IS A PULVERIZED 1.6X SULFUR LIGNITE FIRED BOILER  OF  TEXAS POWER
                               AND LIGHT LOCATED IN RCCKDALE, TEXAS.   COMBUSTION ENGINEERING HAS SUPPLIED
                               THREE LIMESTONE SPRAY TOWERS FOR THIS UNIT.   A COLO SIDE ESP  IS PROVIDING
                               PRIMARY PARTICULATE CONTROL.  A 30X BYPASS REHEAT IS BEING USED,  AND THE
                               OVERALL S02 REMOVAL EFFICIENCY IS 75X.  THE SYSTEM OPERATES If A CLOSED
                               MATER LOOP, AND THE SLUDGE IS BEING PONDED.  OPERATIONS COMMENCED IN
                               DECEMBER 1980.
TEXAS POWER t LIGHT
TWIN OAKS
1 .
NEM       750 HVI (GROSS)
          750 KM (ESC)
COAL
  .70 XS  LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: »»**X
STATUS 3     STARTUP  8/85
                               TWIN OAKS 1 IS A 0.70X SULFUR LIGNITE FIRED BOILER PLANNED BY TEXAS POWER
                               AND LIGHT AND ALCOA FOR LOCATION IN BREMOND. TEXAS. A CONTRACT HAS BEEN
                               AMARDED TO GEESI FOR A LIMESTONE FGD SYSTEM, ON THIS UNIT. START-UP IS
                               EXPECTED IN AUGUST 1985.
                                                41

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
                                             SECTION 2
                                       STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
TEXAS POWER & LIGHT
TWIN OAKS
2
MEM       750 MM (GROSS)
          750 MM (ESC)
COAL
  .70 XS  LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: *«**X
STATUS 3     STARTUP  8/87
                  TWIN OAKS 3 IS A 0.70X SULFUR  LIGNITE FIRED BOILER  PLANNED  BY  TEXAS  PCUER
                  AND LIGHT AND ALCOA FOR LOCATION  IN BREM3NO, TEXAS. A CONTRACT HAS BE;N
                  AWARDED TO GEESI FOR A LIMESTONE  FGD SYSTEM ON THIS UNIT. START-UP IS
                  EXPECTED IN AUGUST 1987.
TEXAS UTILITIES
FOREST GROVE
1
NEU       750 MM (GROSS)
          750 MM (ESC)
COAL
  .60 XS  LIGNITE
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
EIIEPGY CONSUMPTION: »**»x
STATUS 5     STARTUP  0/87
                  TEXAS UTILITIES IS PLANNING  A  LIGNITE (0.8X S, 7000 BTU/LB)  FIRED BOILER,
                  FOREST GROVE 1, WHICH  MILL BE  LOCATED IN ATHENS, TEXAS. THE  UTILITY  IS
                  PRESENTLY  REQUESTING BIDS ON AN  FGD SYSTEM FOR THIS UNIT.  TUO  ESP'S  HILL
                  PROVIDE PRIMARY PARTICULATE  CONTROL, AND NO STACK GAS REHEAT IS  PUNNED.
                  START-UP IS EXPECTED IN LATE 1987.
TEXAS UTILITIES
MARTIN LAKE
1
NEU       793 MM (GROSS)
          595 MM (ESC)
COAL
  .90 XS  LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  i.3x
STATUS 1     STARTUP  */77
                  TEXAS UTILITIES'  MARTIN LAKE  1  IS  A  LIGNITE  (0.9X S,  7380  BTU/LB)  FI°ED
                  BOILER IN TATUM,  TEXAS. THIS  UNIT  IS EQUIPPED HITH AN EMISSION CONTROL
                  SYSTEM WHICH INCLUDES A COLO  SIDE  ESP AND A  LIMESTONE FGD  SYSTEM,  BOTH
                  SUPPLIED BY RESEARCH COTTRELL.  THE FGO SYSTEM CONSISTS OF  SIX  PACKED  SPRAY
                  TOMER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS.  THE  REMAIN-
                  ING FLUE GAS IS BYPASSED FOR  REHEAT. THE TOTAL DESIGN S02  REMOVAL  EFFICI-
                  ENCY IS 70.57..  TWO CHEVRONS/MODULE PROVIDE MIST  ELIMINATION. THE FLUE GAS
                  CLEANING HASTES ARE FLYASH  STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
                  THE SYSTEM OPERATES IN A CLOSED MATER LOOP.  INITIAL SYSTEM OPERATIONS TOCK
                  PLACE IN APRIL 1977.
TEXAS UTILITIES
MARTIN LAKE
Z
NEU       793 MM (GROSS)
          595 MM (ESC)
COAL
  .90 XS  LIGNITE
LIMESTONE
RESEARCH-COTTHELL
ENERGY CONSUMPTION:
STATUS 1
        1.3X
STARTUP  5/78
                  TEXAS UTILITIES1  MARTIN LAKE 2  IS A LIGNITE  (0.«X  S,  73SO  BTU/LB)  FIREO
                  BOILER IN TATUM,  TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
                  SYSTEM MHICH INCLUDES A COLD SIDE ESP AND A  LIMESTONE FGD  SYSTEM.  BOTH
                  SUPPLIED BY RESEARCH COTTRELL.  THE FGD SYSTEM CONSISTS OF  SIX PACKED SPRAY
                  TOMER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE  REMAIN-
                  ING FLUE GAS IS BYPASSED FOR REHEAT.  THE TOTAL DESIGN SOS  REMOVAL  EFFICI-
                  ENCY IS 70.5X.  TWO CHEVRONS/MODULE PROVIDE MIST  ELIMINATION.  THE FLUE GAS
                  CLEANING HASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
                  THE SYSTEM OPERATES IN A CLOSED HATER LOOP.  INITIAL SYSTEM OPERATIONS TOCK
                  PLACE IN MAY 1978.
TEXAS UTILITIES
MARTIN LAKE
3
NEU       793 MM (GROSS)
          595 MU (ESC)
COAL
  .90 XS  LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION
STATUS 1
                     1.3X
             STARTUP  2/79
                  TEXAS UTILITIES'  MARTIN LAKE 3 IS A  LIGNITE  (0.9X  S,  7380  BTU/LB)  PIPED
                  BOILER IN TATUM,  TEXAS. THIS UNIT IS EQUIPPED HITH AN EMISSION CONTROL
                  SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A  LIMESTONE FGO  SYSTEM,  BOTH
                  SUPPLIED  BY RESEARCH COTTRELL.  THE FGD SYSTEM CONSISTS OF  SIX PACKED  SPRAY
                  TOMER ABSORBERS WHICH TREAT  75X OF THE TOTAL BOILER FLUE GAS.  THE  REMAIN-
                  ING FLUE  GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02  REMOVAL  EFFICI-
                  ENCY IS 70.5X.  TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION.  THE FLUE GAS
                  CLEANING  HASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
                  THE SYSTEM OPERATES IN A CLOSED HATER LOOP.  INITIAL SYSTEM OPERATIONS TOOK
                  PLACE IN  FEBRUARY 1979.
TEXAS UTILITIES
MARTIN LAKE
<>
HEW       750 MM (GROSS)
          750 MM (ESC)
COAL
  .90 XS  LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: *»«*X
STATUS 3     STARTUP  0/89
                  MARTIN LAKE 4 OF TEXAS UTILITIES  IS A LIGNITE  (0.9X S,  73SO  BTU/LB)  FIRED
                  BOILER UNDER CONSTPUCTION IN TATUM, TEXAS. A CONTRACT FOR  A  LIMESTONE  FGO
                  SYSTEM FOR THIS UNIT HAS BEEN AHARDED TO RESEARCH COTTRELL.  CONSTRUCTION
                  HAS NOT YET BEGUN ON THE FGD SYSTEM. FGD START-UP IS EXPECTED  IN
                  1989.
                                                42

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER  -  DECEMBER  1981
                                             SECTION 2
                                       STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                 ABSTRACT
TEXAS UTILITIES
MILL CREEK
1
NEW       750 MVI (GROSS)
          750 KM (ESC)
COAL
.(»**» XS  LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«**x
STATUS 6     STARTUP  0/87
MILL CREEK 1 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TO 2E
LOCATED IN HEHDEPSON, TEXAS. THE UTILITY HILL INCLU3E AN FG3 SYSTEM CN
THIS UNIT, BUT NO DECISIONS HAVE BEEN MADE AS TO THE P'CCESS TYFE CR
VENDOR. ESP'S MILL PROVIDE PRIMARY PARTICLE CONTROL. START-UP IS
EXPECTED IN 1967.
TEXAS UTILITIES
MILL CREEK
2
HEM       750 rM (GROSS)
          750 KM (ESC)
COAL
**»»« XS  LIGNITE
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENEFGY CONSUMPTION: ****7.
STATUS 6     STARTUP  0/68
MILL CREEK 2 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TO BE
LOCATED IN HENDERSON, TEXAS. THE UTILITY MILL INCLUDE AN FGO SYSTEM ON
THIS UNIT, BUT NO DECISIONS HAVE BEEN MADE AS TO THE PRCCESS TYFE CR
VENDOR. ESP'S HILL PROVIDE PRIMARY PARTICLE CONTROL. START-UP IS
EXPECTED IN 1988.
TEXAS UTILITIES
MOMTICELLO
3
NEH       800 KU (GROSS)
          600 MM (ESC)
COAL
 1.50 XS  LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: V««*X
STATUS 1     STARTUP  5/78
MOMTICELLO 3 OF TEXAS UTILITIES IS A LIGNITE (1.5X S, 7000 BTU/LB) FIRED
UNIT IN MT. PLEASANT, TEXAS. THIS UNIT'S EMISSION CONTROL SYSTEM CCMSISTS
OF TWO COLD SIDE ESP'S FOLLOWED BY THREE GEESI LIMESTONE SPPAf TOWERS
{.7V/. DESIGN 502 REMOVAL EFFICIENCY), ONE HORIZONTAL CHEVPCM MIST ELIMINA-
TOR/MODULE, AND AN INDIRECT HOT AIR REHEATER. THE HATER LOO? IS CLOSED.
AND THE FLYASH STABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LANDFILL. THIS
SYSTEM HAS BEEN OPERATIONAL SINCE MAY 1978.
TUCSON ELECTRIC POMER
SPRINGERVILLE
1
NEH       370 MM (GROSS)
          370 MM (ESC)
COAL
  .61 XS  SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: **»«X
STATUS 3     STARTUP  2/65
TUCSON ELECTRIC POMER HILL BE BUILDING THO HEW UNITS IN SPFIM3EHVILLE,
ARIZONA. SPRIN3ERVILLE 1 AND 2.  THE UNITS HILL FIRE PULVEPIZED EL'SBITU-
MINOUS COAL (0.53-0.69X S AND 6500-6900 BTU/L3).  A CONTRACT HAS BEEN
AHARDED TO JOY MANUFACTURING/NIRO ATOMIZER FCR A LIME/SPRAY DRYING FGD
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS.  THE SYSTEM HILL
BE DESIGNED TO ACCOMOOATE A REHEATER (SHOULD ONE BE REQUIRED) AND UILL
OPERATE IN A CLOSED HATER LOOP.  CLEANED FLUE GAS UILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK.  START-UP IS SCHEDULED FOR FEBRUARY 1985.
TUCSON ELECTRIC POWER
SPRINGERVILLE
2
NEH       370 MM (GROSS)
          370 MM (ESC)
COAL
  .61 XS  SUE9ITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ***«x
STATUS 3     STARTUP  3/87
TUCSON GAS AND ELECTRIC HILL BE BUILDING THO HEM UNITS IN SPPINSERVILLE,
ARIZONA, SPRINGERVILLE 1 AND 2.  THE UNITS UILL FIRE PULVERIZED SU33ITU-
MINOUS COAL (0.53-0.69X S AND 8500-6900 BTU/LB).  A CONTRACT HAS BEEN
AHARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A LIME/SFP4Y CRYI','3 FGD
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS.  THE SYSTEM MILL
BE DESIGNED TO ACCCKODATE A REHEATER (SHOULD ONE BE REC'JT'ED) AND UILL
OPERATE IN A CLOSED MATER LOOP.  CLEANED FLUE GAS HILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK.  START-UP IS SCHEDULED FOR MARCH 1987.
UNITED POMER ASSOCIATION
STANTON
1A
NEH        60 MM (GROSS)
           SO MM (ESC)
COAL
  .77 XS  LIGNITE
LIME/SPRAY DRYING
RESEARCH-COTTRELL
ENERGY CONSUMPTION: »«»*X
STANTON 1A OF THE UNITED POWER ASSOCIATION IS A PULVERIZED COAL (0.77X S.
7000 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN STANTCN, H03TH DAKOTA.
A CONTRACT HAS BEEN AWARDED TO KOMLINE AND SANDERSON fOt A LIME SFPAY
DRYER.  A FABRIC FILTER SUPPLIED BY RESEARCH COTTRELL UILL BE DESIGNED
TO REMOVE 99X OF THE PARTICULATE.  THE SYSTEM UILL CPEPATE IN AN CPEN
LOOP MODE HITH SLUDGE DISPOSAL TO BE IN A CLAY LINED SETTLII.3 POND.
OPERATIONS ARE SCHEDULED TO COMMENCE IN JUNE 1932.
STATUS 2
             STARTUP  6/82

-------
 EPA UTILITY FC-0 SURVEY:  OCTOBER  -  DECEMBER  1981
                                             SECTION 2
                                       STATUS Or  FGD SYSTEMS
UNIT IDEHTIFICATIOM
                                                                ABSTRACT
UTAH POWER
HUNTER
1
MEM
           & LIGHT
          400 MW (GROSS)
          360 rM (ESC)
COAL
  .55 XS  BITUMINOUS
LIKE
GE ENVIRONMENTAL SERVICES
EN5=3Y CONSUMPTION:  ****X
STATUS 1     STARTUP 5/79
HUNTER 1 OF UTAH POWER AND LIGHT IS A COAL (0.55X S, 12.500 STU/LB) FIRED
UNIT IN CASTLEDALEi UTAH. GEESI SUPPLIED A PEEBLE LIME WET SCrL-SBIHS
SYSTEM WHICH BECAME OPERATIONAL IN MAY 1979.  THE SC'UEBIUS SYSTEM IS DE-
SIGNED TO OPEPATE IN AN OPEN WATER LOOP WITH  AN SOC REMOVAL EFFICIENCY OF
SOX. PRIMARY PAHTICULATE CONTROL IS PROVIDED  BY AN UPSTREAM ESP, AfO STACK
GAS REHEAT IS PROVIDED BY BYPASS. THE SLUDGE  IS FLfASH STABILIZED AN3 DIS-
POSED ON-SITE.
UTAH POWER & LIGHT
HUNTER
2
NEW       400 MW (GROSS)
          360 MW (ESC)
COAL
  .55 XS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  ««**X
STATUS 1     STARTUP 6/80
UTAH POWER AND LIGHT'S HUNTER 2 IS A COAL (0.55X S, 12,500 BTU/LB) FIRED
UNIT LOCATED IN CASTLEDALE, UTAH. FOR EMISSION CONTROL, GEESI SUPPLIED
A PEBBLE LIME WET SCRUBBING SYSTEM DESIGNED TO CPEPATE IN AN CPEM WATER
LOOP WITH AN S02 REMOVAL EFFICIENCY OF 80X. AN UPSTPE4M ESP PROVIDES
PRIMARY PARTICLE CONTROL, AND A BYPASS SYSTEM PROVIDES STACK GAS REHEAT.
THE SLUDGE IS FLYASH STABILIZED AND DISPOSED OF CN-SITE. START-UP OF BOTH
THE BOILER AND FGD SYSTEM TOOK PLACE IN JUNE 1980.
UTAH POWER 4 LIGHT
HUNTER
3
NEW       400 MW (GROSS)
          400 MW (ESC)
COAL
  .55 XS  BITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION'-  »**»X
STATUS £     STARTUP  6/83
HUNTER 3 OF UTAH POWER AND LIGHT IS A PULVERIZED COAL (0.55X S, 12500
BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN CASTLEDALE, UTAH.  A CONTRACT HAS
BEEN AWARDED TO GEESI FOR A LIMESTONE, NONREGENERABLE FGO UNIT FOR EMIS-
SION CONTROL.  INITIAL OPERATIONS ARE SCHEDULED TO COMMENCE IN JUNE 1933.
UTAH PCWER
HUNTER
4
NEW
           £ LIGHT
          400 MW (GROSS)
          400 MW (ESC)
COAL
  .55 XS  BITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  »»««X
STATUS 2     STARTUP  6/85
HUNTER 4 OF UTAH POWER AND LIGHT IS A PULVERIZED COAL (0.55X S, 12500
BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN CA5TELDALE. UTAH.  A CONTRACT HAS
BEEN AWARDED TO GEESI FOR A LIMESTONE, NONREGENERABLE FGD UNIT FOR EMIS-
SION CONTROL.  INITIAL OPERATIONS ARE SCHEDULED TO COMMENCE IN JUNE 1935.
UTAH POWER S LIGHT
HUNTINGTON
1
NEW       430 MW (GROSS)
          366 MW (ESC)
COAL
  .55 XS  BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:   1.6X
STATUS 1     STARTUP  5/78
HUNTINSTON 1 OF UTAH POWER IS A TANGENTIALLY FIRED PULVERIZED COAL (0.55X
S, 12,500 BTU/LB) BOILER IN PRICE, UTAH. A COLD SIDE ESP TREATS 1,742,000
ACFM OF FLUE GAS AND IS FOLLOWED BY A GEESI LIME FGO SYSTEM CONSISTING
OF FOUR SPRAY TOWERS (80X DESIGN EFFICIENCY). ONE FOUR PASS CHEVPON/MODULE
PROVIDES MIST ELIMINATION, AND A COMBINATION OF A STEAM TU3E AND 10-20X
BYPASS HEHEATERS BOOST THE GAS TEMPERATURE 45-50 DEG F. THE SYSTEM OPER-
ATES IN A CLOSED WATER LOOP, AND THE FLYASH STABILIZED SLUDGE IS TRUCKED
TO AN ON-SITE LANDFILL. THE SYSTEM INCLUDES A 600 FOOT ACID BRICK LINED
STACK, AND HAS BEEN OPERATIONAL SINCE MAY 1978.
UTAH POWER I LIGHT
NAUGHTON
3
RETROFIT  330 MW (GROSS)
          330 MM (ESC)
COAL
  .55 XS  SUBBITUMIHOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION:   1.5X
STATUS 1     STARTUP  9/81
NAUGHTON 3 OF UTAH POWER AND LIGHT IS A PULVERIZED COAL (.5X S, 9500
BTU/LB) FIRED BOILER LOCATED IN KEMMERER, WYOMING.  THE BOILER SUPPLIES
1,500,000 ACFM OP FLUE GAS TO AN ESP FOR PARTICULATE MATTER CONTROL.  THE
UNIT MAS RETROFITTED WITH A UOP MET SODA ASH FGD SYSTEM FC= S02
CONTROL.  THE FGD SYSTEM IS DESIGNED TO REMOVE 70X OF THE S02 BEFORE THE
FLUE GAS EXITS OUT A 475 FOOT STACK.  INITIAL START-UP TOOK PLACE IN
SEPTEMBER 1981.
                                                44

-------
                                              EPA  UTILITY FGO  SURVEY:  OCTOBER  -  DECEMBER  1=31
                                             SECTION 2
                                       STATUS OF  FGD SYSTEMS
UHIT IDENTIFICATION
                                                                 ABSTRACT
WASHINGTON WATER POWER
CRESTCN COAL
1
MEM       570 KM (GROSS)
          570 KM (ESC)
COAL
*«*»» xs  UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *»**x
STATUS 6     STARTUP  0/87
WASHINGTON UATER POMER HAS PLANS FOR A NEM UNIT, CRESTCN COAL 1, TO 3c
LOCATED IN CRESTON, WASHINGTON.  THE COAL PIPED BOILER WILL HAVE A G"33
GENERATING CAPACITY OF 570 MM AND MILL UTILIZE A WET LIMESTONE F33 SYSTEM
FOR CONTROL OF S02 EMISSIONS.  FGD OPERATIONS ARE SCHEDULED TO CCrT.ENCE
IN 1987.
WASHINGTON UATER POWER
CRESTON COAL
2
NEM       570 MM (GROSS)
          570 MM (ESC)
COAL
***«» XS  UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *»*»X
STATUS 6     STARTUP  0/87
WASHINGTON MATER POMER HAS PLANS FOR A NEM UNIT, CRESTON 2, TO BE LOCATED
IN CRESTCN. WASHINGTON.  THE COAL FIRED BOILER MILL HAVE A GROSS GENEPAT-
INS CAPACITY OF 570 MM AND MILL USE A MET LIMESTONE FGD SYSTEM FOP. CCMTROL
OF S02 EMISSIONS.  FGD OPERATIONS ARE SCHEDULED TO COMMENCE IN 1987.
WASHINGTON MATER POMER
CRESTON COAL
3
NEW       570 MM (GROSS)
          570 MM (ESC)
COAL
****» XS  UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 12.3X
STATUS 6     STARTUP  0/87
MASHINGTON HATER POMER HAS PLANS FOR A NEM UNIT, CPESTON 3, TO BE LOCATED
IN CRESTON, MASHINGTON.  THE COAL FIRED BOILER MILL HAVE A GROSS GENERAT-
ING CAPACITY OF 570 MM AND MILL USE A MET LIMESTONE FGD SYSTEM FC3 CONTROL
OF S02 EMISSIONS.  FGD OPERATIONS ARE SCHEDULED TO COMMENCE IN 1937.
MASHINGTON MATER POMER
CRESTON COAL
4
NEM       570 MM (GROSS)
          570 MM (ESC)
COAL
»»»*» XS  UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 12.3X
STATUS 6     STARTUP  0/87
MASHINGTON HATER POWER HAS PLANS FC3 A NEM UNIT, CRESTON 4, TO BE LOCATED
IN CRESTON, WASHINGTON.  THE COAL FIRED BOILER HILL HAVE A GROSS GENEFAT-
ING CAPACITY OF 570 MM AMD MILL USE A MET LIMESTONE FGD SYSTEM FC3 CONTROL
OF 302 EMISSIONS.  FGO OPERATIONS ARE SCHEDULED TO COMMENCE IN 1937.
WEST PENN POWER
MITCHELL
33
RETROFIT  300 MM (GROSS)
          300 MM (ESC)
COAL
 2.80 XS  BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION:  l.OX
STATUS 2     STARTUP  8/82
UNIT 33 AT ALLEGHENY POWER SYSTEM'S MITCHELL POWER STATION IN CCUPTNEY,
PENNSYLVANIA IS A 2.8X SULFUR COAL FIRED BOILER UNDER CONSTRUCTION.  A
CONTRACT MAS AWARDED TO GEESI FOR A LIME SCRUBBING PROCESS.  THE SYSTEM
WILL BE DESIGNED WITH AN S02 REMOVAL EFFICIENCY OF 95X.  START UP IS
SCHEDULED FOR AUGUST 1982.
MEST TEXAS UTILITIES
CKLAUNION
1  -
NEM       720 MM (GROSS)
          504 MM (ESC)
COAL
  .34 XS  SUBBITUMINOUS
PROCESS NOT SELECTED
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ****x
STATUS 3     STARTUP 12/86
WEST TEXAS UTILITIES HAS PLANS TO BUILD TWO PULVERIZED COAL FIRED BOILERS
TO BE LOCATED NEAR OKLAUNION, TEXAS.  THE UTILITY HAS SIGNED A CONTRACT
WITH GENERAL ELECTRIC ENVIRONMENTAL SERVICES FOR AN FGD SYSTEM TO CONTROL
S02 EMISSIONS FROM THIS UNIT.  INITIAL OPERATIONS ARE SCHEDULED FOR 12/86.
                                                45

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
                                             SECTION 2
                                       STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION                                              ABSTRACT

WEST TEXAS UTILITIES           WEST TEXAS UTILITIES HAS PLANS TO BUILD TWO PULVERIZED COAL FIRED EOILEHS
CKLAUNION                      TO BE LOCATED NEAR OKLAUNION, TEXAS.   THE  UTILITY UILL INCLUDE AN ?G3 S.3-
2                              TE.1 FOR EMISSION CONTROL FROM THE 7£0 MM UNIT.   THE OKLAC'NION 2 PLANT IS
NEW       720 mi (GROSS)       SCHEDULED TO COMMENCE OPERATIONS IN 1990.
          720 MM (ESC)
COAL
  .34 y.5  SUSSITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «***X
STATUS 6     STARTUP  0/90
                                                46

-------
Section 3, pages 47-851,
appears in Volume IT.
            47

-------
EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981
                                            SECTION 4
                                SUMMARY OF FGD  SYSTEMS 8Y COMPANY
                                               	STATUS	
                                    TOTAL      OPERATIONAL  CONSTRUCTION     CONTRACT
                                                                             AWARDED
  COMPANY NAME
                                 NO.    HW
                                               NO.    MU
                                                             NO.
                                                                           NO.    MU
   PLANNED


NO.   MM
ALABAMA ELECTRIC
ARIZONA ELECTRIC POWER
ARIZONA PU3LIC SERVICE
ASSOCIATED ELECTRIC
ATLANTIC CITY ELECTRIC
BASIN ELECTRIC POWER
BIG RIVERS ELECTRIC
CAJUN ELECTRIC POWER
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CENTRAL POWER £ LIGHT
CINCINNATI GAS t ELECTRIC
COLORADO UTE ELECTRIC
COLUMBUS 4 SOUTHERN OHIO ELEC
COMMONWEALTH EDISCN
COOPERATIVE POWER ASSOCIATION
OELKARVA POWER t LIGHT
DESERET GEN t TRANS
DUQUESHE LIGHT
EAST KENTUCKY POWER
FLORIDA POWER I LIGHT
GENERAL PUBLIC UTILITIES
GRAND HAVEN BRD OF LIGHT t PUR
HCOSIER ENERGY
HOUSTON LIGHTING I POWER
INDIANAPOLIS POWER t LIGHT
IOWA ELECTRIC LIGHT t PUR
JACKSONVILLE ELEC AUTHORITY
KANSAS CITY POWER t LIGHT
KANSAS POWER I LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LANSING BOARD OF UATER t LIGHT
LOS ANGELES DEPT OF UTR I PUR
LOUISVILLE GAS t ELECTRIC
LOWER COLORADO RIVER AUTH
MARQUETTE BOARD OF LIGHT S PUR
MICHIGAN SO CENTRAL PUR AGENCY
MICDLE SOUTH UTILITIES
MINNESOTA POWER & LIGHT
HINNKOTA POWER
MONONGAHELA POWER
MONTANA POWER
MONTANA-DAKOTA UTILITIES
MUSCATINE POWER t UATER
NEBRASKA PUBLIC POWER DISTRICT
NEVADA POUER
HEW YORK STATE ELEC I GAS
NIAGARA MOHAKK POWER
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
PACIFIC GAS t ELECTRIC
PACIFIC POWER t LIGHT
PENNSYLVANIA FOUER
PHILADELPHIA ELECTRIC
PLAINS ELECTRIC G 4 T
PLATTE RIVER POUER AUTHORITY
PUBLIC SERVICE INDIANA
PUBLIC SERVICE OF NEW MEXICO
2
2
8
1
1
5
4
6
2
1
1
1
2
3
4
1
2
4
2
2
2
2
5
1
2
3
5
1
2
3
4
3
1
1
4
10
1
1
1
6
1
1
2
4
1
1
1
8
I
1
3
5
2
5
3
3
1
1
1
4
358.
196.
2598.
670.
330.
2590.
1364.
3328.
866.
617.
600.
720.
1300.
1267.
1572.
450.
654.
730.
820.
918.
1150.
1600.
3190.
65.
882.
1992.
3012.
720.
1200.
1054.
1575.
1364.
364.
160.
3280.
3539.
435.
44.
55.
5340.
475.
185.
1336.
2120.
440.
166.
650.
2625.
625.
100.
957.
2600.
1600.
2300.
2751.
724.
233.
279.
650.
1779.
2
2
6
a
0
2
2
0
1
1
0
0
1
2
2
1
2
3
0
2
0
0
0
0
1
0
1
0
0
3
4
1
0
0
0
7
0
0
0
0
1
1
2
2
1
0
0
3
0
0
1
3
0
1
3
0
0
0
0
3
358.
196.
1088.
0.
0.
1140.
484.
0.
416.
617.
0.
0.
650.
820.
822.
450.
654.
180.
0.
918.
0.
0.
0.
0.
441.
0.
532.
0.
0.
1054.
1575.
64.
0.
0.
0.
1894.
0.
0.
0.
0.
475.
185.
1336.
720.
440.
0.
0.
375.
0.
0.
115.
1590.
0.
550.
2751.
0.
0.
0.
0.
1245.
0
0
2
1
0
3
1
0
0
0
0
0
0
1
0
0
0
0
1
0
1
0
0
1
1
1
1
0
0
0
0
0
1
0
a
i
0
1
1
0
0
0
0
2
0
1
0
0
0
1
1
0
0
1
0
3
1
0
1
1
0.
0.
1510.
670.
0.
1450.
440.
0.
a.
0.
0.
0.
0.
447.
0.
0.
0.
0.
410.
0.
500.
0.
0.
65.
441.
492.
530.
0.
0.
0.
0.
0.
364.
0.
0.
495.
0.
44.
55.
0.
0.
0.
0.
1400.
0.
166.
0.
0.
0.
100.
421.
0.
0.
100.
0.
724.
233.
0.
650.
534.
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
2
0
0
0
0
0
0
0
0
0
0
0
0
0
0
a
0
a
a
0
0
0
0
0
0
1
0
0
0
0
0
0
1
0
0
0.
0.
0.
0.
0.
0.
440.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
650.
0.
0.
0.
0.
1500.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
421.
0.
0.
0.
0.
0.
0.
279.
0.
0.
0
0
0
0
1
0
0
6
1
0
1
1
1
0
2
0
0
1
1
0
0
2
5
0
0
0
3
1
2
0
a
2
0
1
4
2
1
0
0
6
0
0
0
0
0
0
1
5
1
0
0
2
2
3
0
0
0
0
0
0
0.
0.
0.
0.
330.
0.
0.
3328.
450.
0.
600.
720.
650.
0.
750.
0.
0.
550.
410.-
0.
0.
1600.
3190.
0.
0.
0.
1950.
720.
1200.
0.
0.
1300.
0.
160.
3280.
1150.
435.
0.
0.
5340.
0.
0.
0.
0.
0.
0.
650.
2C50.
6£S.
0.
0.
1010.
1600.
1650.
0.
0.
0.
0.
0.
0.
      NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIGNEDt REQUESTING/EVALUATING BIDS,
             AND CONSIDERING ONLY FGO SYSTEMS
                                              652

-------
                                          EPA UTILITY FGO SURVEY: OCT03EP - DECEM2E3 1981
                                         SECTION 4
                             SUMMARY OF FGD SYSTEMS BY COMPANY
                                 TOTAL
	STATUS	
OPERATIONAL  CONSTRUCTION     CCNTPACT
                              AUAROED
                                                                                         PLANNED
COMPANY NAME
PUR AUTHORITY OF STATE OF NY
SALT RIVER PROJECT
SAN MIGUEL ELECTRIC
SEMINOLE ELECTRIC
SIKESTCN BPD OF MUNICIPAL UTIL
SOUTH CAROLINA PU3LIC SERVICE
SOUTH MISSISSIPPI ELEC PUR
SOUTHERN ILLINOIS POUER
SOUTHERN INDIANA GAS t ELEC
SOUTHWESTERN ELECTRIC POUER
SOY LAND POUER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD MATER. LIGHT i PUR
ST. JOE ZINC
SUNFLOWER ELECTRIC
TAMPA ELECTRIC
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POUER AGENCY
TEXAS POUER S LIGHT
TEXAS UTILITIES
TUCSON ELECTRIC POUER
UNITED PCUER ASSOCIATION
UTAH POUER i LIGHT
WASHINGTON HATER POUER
UEST PENH POUER
UEST TEXAS UTILITIES
NO.
1
3
1
2
1
5
2
1
2
3
1
1
1
1
1
1
6
1
3
a
2
i
6
4
1
2
MM
700.
640.
400.
1240.
235.
1700.
248.
173.
530.
2160.
500.
194.
165.
60.
347.
475.
2553.
400.
1882.
5585.
740.
50.
2216.
2280.
300.
1224.
NO.
0
2
1
0
1
3
2
1
1
0
0
1
1
1
0
0
4
0
1
4
0
0
4
0
0
0
MM
0.
560.
400.
0.
235.
700.
248.
173.
265.
0.
0.
194.
185.
60.
0.
0.
1145.
0.
382.
2585.
0.
0.
1416.
0.
0.
0.
NO.
0
0
0
1
0
1
0
0
0
0
0
0
0
0
1
0
2
1
0
0
0
1
2
0
1
0
MU
0.
0.
0.
620.
0.
500.
0.
0.
0.
0.
0.
0.
0.
0.
347.
0.
1408.
400.
0.
0.
0.
50.
800.
0.
300.
0.
NO.
0
0
0
1
0
1
0
0
0
2
0
0
0
0
0
1
0
0
2
1
2
0
0
0
0
1
nu
0.
0.
0.
620.
0.
500.
0.
0.
0.
1440.
0.
0.
0.
0.
0.
475.
0.
0.
1500.
750.
740.
0.
0.
0.
0.
504.
NO.
^
1
0
0
0
0
0
0
1
1
1
0
0
0
0
0
0
0
0
3
0
0
0
4
0
1
MU
700.
ZSO.
0.
0.
0.
0.
0.
0.
265.
720.
500.
0.
0.
0.
0.
0.
0.
t>.
0.
2250.
0.
0.
0.
2280.
0.
720.
TOTALS
                               222 102781.
                                              94  32683.
                                                            40  16666.
                                                                          17   9819.
                                                                                        71   43613.
    NOTE - PUNNED STATUS INCLUDES LETTER OF INTENT SIGNED,
           AND CONSIDERING ONLY FGD SYSTEMS
                                                            REQUESTING/EVALUATING BIDS,
                                            853

-------
EPA UTILITY FGO SURVEY:  OCTOBER  -  DECEMBER  1981
                                           SECTION 5
                            SUMMARY  OF  FGD  SYSTEMS BY  SYSTEM  SUPPLIER
                                                    	STATUS	
                                           TOTAL    OPERATIONAL   CONSTRUCTION   CONTPACT
                                                                                AWASOED
SYSTEM SUPPLIER/PROCESS
AIR CORRECTION DIVISION, UOP
LIME
LIMESTONE
LIME/LIMESTOHE
SODIUM CAR30NATE
TOTAL -
AMERICAN AIR FILTER
LIME
LIMESTONE
TOTAL -
BABCOCK I MILCOX
LIME
LIMESTONE
LIME/SPRAY DRYING
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLYASH
TOTAL -
DAVY MCKEE
UELLMAN LORD
TOTAL -
ENVIRONEERING, RILEY STOKER
LIMESTONE
TOTAL -
FLAKT
LIME/SODIUM CARBONATE
TOTAL -
FMC
DUAL ALKALI
TOTAL -
GE ENVIRONMENTAL SERVICES
DUAL ALKALI
LIME
LIMESTONE
LIME/ALKALINE FLYASH
LIME/LIMESTONE
LIME/SPRAY DRYING
PROCESS NOT SELECTED
TOTAL -
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
TOTAL -
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
TOTAL -
NO.

2
5
1
2
10

6
1
7

7
8
2
17

6
11
Z
2
21

8
8

3
3

1
1

3
3

1
a
8
3
1
1
1
23

7
7

2
2
MM

822.
2616.
10.
880.
4328.

1658.
280.
1938.

4211.
2521.
1017.
7749.

1160.
5075.
1480.
654.
8369.

2074.
2074.

664.
664.

100.
100.

1107.
1107.

617.
4138.
5000.
579.
10.
44.
504.
10892.

2356.
2356.

882.
882.
NO.

2
3
1
2
8

5
1
6

3
6
0
9

6
6
2
2
16

7
7

3
3

0
0

1
1

1
7
1
3
1
0
0
13

1
1

1
1
MM

822.
1176.
10.
880.
2888.

1163.
280.
1443.

1986.
2102.
0.
4088.

1160.
2532.
1480.
654.
5826.

1540.
1540.

664.
664.

0.
0.

265.
265.

617.
3838.
800.
579.
10.
0.
0.
5844.

110.
110.

441.
441.
NO.

0
0
0
0
0

1
0
1

3
2
2
7

0
3
0
0
3

1
1

0
0

1
1

1
1

0
1
5
0
0
1
0
7

3
3

1
1
MM

0.
0.
0.
0.
0.

495.
0.
495.

1575.
419.
1017.
3011.

0.
1043.
0.
0.
1043.

534.
534.

0.
0.

100.
100.

421.
421.

0.
300.
2700.
0.
0.
44.
0.
3044.

1227.
1227.

441.
441.
NO.

0
2
0
0
2

0
0
0

1
0
0
1

0
2
0
0
2

0
0

0
0

0
0

1
1

0
0
2
0
0
0
1
3

3
3

0
0
irA

0.
1440.
0.
0.
1440.

0.
0.
0.

650.
0.
0.
650.

0.
1500.
0.
0.
1500.

0.
0.

0.
0.

0.
0.

421.
421.

0.
0.
1500.
0.
0.
0.
504.
2004.

1019.
1019.

0.
0.
                                              854

-------
                                      EPA  UTILITY  FGD  SURVEY: OCTOBER  - DECEMBER 1=81
                                    SECTION  5
                     SUMMARY OF  FGO  SYSTEMS  BY  SYSTEM  SUPPLIER
                                             	STATUS	
                                    TOTAL     OPERATIONAL  CONSTRUCTION   CCMTPACT
                                                                        AWARDED
SYSTEM SUPPLIER/PROCESS
MORRISON I KNUDSEN/U.S.B.M.
CITRATE
TOTAL -
M.M. KELLOGG
LIME
LIMESTONE
TOTAL -
PEABOOY PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
RESEARCH-COTTRELL
LIMESTONE
LIME/ LIMESTONE
LIME/SPRAY DRYING
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE/SPRAY DRYING
TOTAL -
TENNESSEE VALLEY- AUTHORITY
LIMESTONE
TOTAL -
THYSSEN/CEA
DUAL ALKALI
LIME
LIME/ALKALINE FLYASH
SCOIUM CARBONATE
TOTAL -
UNITED ENGINEERS
MAGNESIUM OXIDE
TOTAL -
MHEELABRATCR-FRYE/R . I .
SODIUM CARBONATE/SPRAY DRYING
TOTAL -
NO.

1
1

1
6
7

8
i
9

14
1
1
16

1
1

1
1

1
1
5
3
10

3
3

1
1
MM

60.
60.

917.
2760.
3677.

3418.
475.
3093.

5261.
475.
50.
5786.

100.
100.

550.
550.

299.
500.
2305.
375.
3479.

724.
724.

440.
440.
NO.

1
1

1
2
3

4
1
5

11
0
0
11

0
0

1
1

1
0
3
3
7

0
0

1
1
MM

60.
60.

917.
560.
1477.

1178.
475.
1653.

3315.
0.
0.
3815.

0.
0.

550.
550.

299.
0.
005.
375.
1579.

0.
0.

440.
440.
NO.

0
0

0
3
3

2
0
2

2
0
1
3

1
1

0
0

0
1
2
0
3

3
3

0
0
MM

0.
0.

0.
1760.
1760.

1120.
0.
1120.

696.
0.
50.
746.

100.
100.

0.
0.

0.
500.
1400.
0.
1900.

724.
724.

0.
0.
NO.

0
0

0
1
1

2
0
2

1
1
0
2

0
0

0
0

0
0
0
0
0

0
0

0
0
r.M

0.
0.

0.
440.
440.

1123.
0.
1120.

753.
475.
0.
1225.

0.
0.

0.
0.

0.
0.
0.
0.
0.

0.
0.

0.
0.
TOTAL -
                                 151  59168.
                                               94 32683.
                                                            40  16666.
                                                                         17  9819.
                                       855

-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
                                           SECTION 6
                                SUMMARY OF FGD SYSTEMS BY PROCESS
                                             	STATUS	
                                   TOTAL     OPERATIONAL  CONSTRUCTION   CONTRACT
                                                                         AWARDED
  TOTALS

    SALEABLE PRODUCT PROCESS
    X OF TOTAL MM
                                 182 7750
-------
                                EPA UTILITY  FGO  SURVEY: CCTC3ER  -  DECEMBER  1961
                              SECTION 7
        SUMMARY OF OPERATIONAL FGO  SYSTEMS  BY  PROCESS  AND  UNIT
PROCESS/
UNIT NAME
CITRATE
G.F. WEATON

DUAL ALKALI
A.B. BROWN
NEUTON
CANE RUN

LIME
CONESVILLE
CONESVILLE
CANE RUN
GREEN
GREEN
GREEN RIVER
MILL CREEK
EAST BEND
PLEASANTS
PLEASANTS
CANE RUN
HAWTHORN
HAUTHORN
MILL CREEK
MILL CREEK
PADDY'S RUN
BRUCE MANSFIELD
BRUCE MANSFIELD
ELRAMA
HUNTER
HUNTER
HUNTINSTON
PHILLIPS
BRUCE MANSFIELD

LIMESTONE
PETERSBURG
POUERTON
SOUTHWEST
UINYAH
LA CYGNE
MARION
SAN MIGUEL
SIKESTON .
UINYAH
WINYAH
JEFFREY
JEFFREY
LAURENCE
LAURENCE
SANDOU
UIDOUS CREEK
DUCK CREEK
R.D. MORROH. SR.
R.D. MCRROM, SR.
KONTICELLO
UNIT NO.

1


1
1
6


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


3
51
1
4
1
4
1
1
2
3
1
2
4
5
4
7
1
1
2
3
CAPACITY
rw

60.
60.

265.
617.
299.
1181.

411.
411.
188.
242.
242.
64.
427.
650.
668.
668.
200.
90.
90.
353.
350.
72.
917.
917.
510.
360.
360.
366.
408.
917.
9886.

532.
450.
194.
230.
874.
173.
400.
235.
140.
280.
540.
490.
125.
420.
382.
575.
416.
124.
124.
800.
INITIAL
STARTUP

11/79


3/79
9/79
4/79


1/77
6/78
8/76
12/79
11/80
9/75
8/78
3/81
3/79
10/80
12/77
11/72
8/72
12/80
12/81
4/73
12/75
7/77
10/75
5/79
6/80
5/78
7/73
6/80


12/77
4/80
4/77
7/81
2/73
5/79
8/81
6/81
7/77
5/80
8/78
1/80
1/77
4/78
12/80
3/81
7/76
8/78
6/79
5/78
STARTUP

1/80


4/79
12/79
O/ 0


2/77
7/73
8/77
12/79
12/80
6/76
3/79
3/81
3/79
12/80
7/78
O/ 0
O/ 0
4/81
4/82
O/ 0
6/76
10/77
10/75
5/79
6/80
5/78
6/74
6/80


12/77
6/81
9/77
O/ 0
6/73
6/79
O/ 0
9/81
O/ 0
6/80
O/ 0
5/80
O/ 0
O/ 0
1/81
9/81
8/78
8/78
6/79
10/78
THIS TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANIES CAN BE FOUND IN SECTION 1.
                                 857

-------
EPA UTILITY FGD SURVEY:  OCTOBER  - DECEMBER 1981
                                           SECTION 7
                     SUMMARY OF  OPERATIONAL FGD SYSTEMS BY PROCESS  AND  UNIT
PROCESS/
UNIT NAME
MEROM
CCSOHADO
CC'CNAOO
CRAIG
CRAIG
TOM3IGBEE
TO"3IG3EE
APACHE
APACHE
CHOLLA
CHOLLA
CHOLLA
OALLMAN
LARAMIE RIVER
LARAMIE RIVER
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
WIDOWS CREEK

LIMESTONE/ALKALINE FLY ASH
SHERBURNE
SHER3URNE

LIME/ALKALINE FLYASH
COAL CREEK
COAL CREEK
FCUR CORNERS
FOUR CORNERS
FOUR CORNERS
CLAY BOSWELL
COLSTRIP
COLSTRIP
MILTON R. YOUNG

LIME/LIMESTONE
SHAU'NEE
SHAUNEE

LIME/SPRAY DRYING
. RIVERSIDE

SODIUM CARBONATE
JIM BRIOGER
NAUGHTCN
REID GARDNER
REID GARDNER
REID GARDNER
UNIT NO.
2
1
2
1
2
2
3
2
3
1
2
4
3
1
2
1
2
3
a


i
2


1
2
1
2
3
4
1
2
2


IDA
10B


6-7


4
3
1
2
3
CAPACITY
MM
441.
280.
280.
410.
410.
179.
179.
98.
98.
119.
264.
126.
185.
570.
570.
595.
595.
595.
550.
14098.

740.
740.
1480.

327.
327.
175.
175.
229.
475.
360.
360.
185.
2613.

10.
10.
20.

110.
110.

550.
330.
125.
125.
125.
INITIAL
STARTUP
12/81
11/79
7/80
10/80
12/79
9/78
6/79
8/78
6/79
10/73
4/73
3/81
12/80
7/80
7/81
4/77
5/73
2/79
5/77


3/76
3/77


7/79
7/80
11/79
11/79
11/79
4/80
9/75
5/76
9/77


4/72
4/72


11/80


9/79
9/81
3/74
4/74
6/76
STARTUP
2/82
12/79
10/81
O/ 0
s/ao
9/73
6/79
1/79
4/79
12/73
6/78
6/81
0/81
7/80
6/31
10/78
O/ 0
O/ 0
1/73


5/76
4/77


8/79
9/80
O/ 0
O/ 0
O/ 0
O/ 0
11/75
10/76
6/78


O/ 0
O/ 0


12/80


2/80
12/31
4/74
O/ 0
7/76
                                                     1255.

             THIS TABLE  IDENTIFIES UNITS  IN ALPHABETICAL  ORDER.
             RESPECTIVE  COMPANIES CAN BE  FOUND  IN SECTION 1.
                                             858

-------
                                EPA UTILITY FGO SURVEY:  OCTOBER  -  DECEMBER  1931
                              SECTION 7
        SUMMARY OF OPERATIONAL FGO SYSTEMS BY PROCESS AND UNIT
PROCESS/
  UNIT NAME
                          UNIT NO.
CAPACITY
   KM
INITIAL
STARTUP
CC1MEPCIAL
 STARTUP
SODIUM CARBONATE/SPRAY DRYING
  COYOTE                  1
KELLMAN LORD
  DEAN H. MITCHELL        11
  DELAWARE CITY           1
  DELAWARE CITY           2
  DELAWARE CITY           3
  SAN JUAN                1
  SAN JUAN                2
  SAN JUAN                3
                                         440.

                                         440.
   115.
    60.
    60.
    60.
   361.
   350.
   534.

  1540.
                                                   4/81
  7/76
  5/80
  5/80
  5/80
  4/78
  8/78
 12/79
                                                              5/81
   6/77
   5/80
   5/80
   5/80
   4/73
   8/78
   O/ 0
TOTAL
                                       32683.
                                 859

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
PROCESS/
UNIT HAME
                                            SECTION 8
              SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
                  	THROHAMAY	
          UNIT NO  STABILIZED   UNSTABILIZED
                                           	BYPRODUCT	
                                            TYPE             DISPOSITION
CITRATE

6.F. MEATOM

CUAL ALKALI

A.B. BROUN
NEUTON
CANE RUN

LINE
                                              ELEMENTAL SULFUR
LIMESTONE

PETERSBURG
POWERTON
SOUTHWEST
UINYAH
LA CYGNE
MARION
SAN MIGUEL
SIKESTON
UINYAH
UINYAH
JEFFREY
JEFFREY
LAURENCE
LAUPENCE
SANDOU
WIDOWS CREEK
DUCK CREEK
R.O. MORROW,
R.D. MORHCU,
MCNTICELLO
MEROH
COPONADO
CCPONADO
CRAIG
CRAIG
TC-BIGBEE
TOK3IGBEE
SR.
SR.
3
51
1
4
1
4
1
1
2
3
1
2
4
5
4
7
1
1
2
3
2
1
2
1
2
2
3
                  LANDFILL
                  LANDFILL
                  LANDFILL
CONESVILLE
CONES VI LLE
CANE RUN
GREEN
GREEN
GREEN RIVER
MILL CREEK
EAST BEND
PLEASANTS
PLEASANTS
CANE RUN
HAWTHORN
HAWTHORN
MILL CREEK
MILL CREEK
PADDY'S RUN
BRUCE MANSFIELD
BRUCE MANSFIELD
ELPAHA
HUNTER
HUNTER
KUNTINGTON
PHILLIPS
BRUCE MANSFIELD
5
6
4
1
2
1-3
3
2
1
2
5
3
4
1
2
6
1
2
1-4
1
2
1
1-6
3
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
POND
LANDFILL
POND
POND
LANDFILL
POND
POND
LANDFILL
LANDFILL
POND
POND
FCNO
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
LANDFILL

POND
LANDFILL
LANDFILL
POND
POND
POND
POND
POND
POND
POND
POND
POND
POND
LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
POND
POND
FOND
POND
POND
                                                           NONE

                                                           NONE
                                                           NONE
                                                           NONE
                                                           NONE
                                               860

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981
                                            SECTION 6
              SUMMARY OF END-PRCOUCT DISPOSAL PRACTICES FOR OPERATIONAL FGO SYSTEMS
PROCESS/
UNIT NAME
APACHE
APACHE
CHOLLA
CHOLLA
CHOLLA
OALLKAN
LARAMIE RIVER
LARAMIE RIVER
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
WIDOWS CREEK
UNIT
2
3
1
2
4
3
1
2
1
2
3
8

NO STABILIZED UNSTABILIZED TYPE DISPOSITION
POM)
POND
POND
POND
POND
LANDFILL NONE
LANDFILL
LANDFILL LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
LIMESTONE/ALKALINE FLYASH
SHERBURNE
SHERBURNE
LIME/ALKALINE FLYASH
COAL CREEK
COAL CREEK
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
CLAY BOSUELL
COLSTRIP
COLSTRIP
MILTON R. YOUNG
LIME/LIMESTONE
SHAHNEE
SHAUNEE
1
2

1
2
1
2
3
4
1
2
2

IDA
10B
POND
POND

POND
POND



POND
POND
POND
LANDFILL

LANDFILL
LANDFILL
LIME/SPRAY DRYING

RIVERSIDE

SODIUM CARBONATE

JIM BRIDGER
NAUGHTON
REID GARDNER
REID GARDNER
REID GARDNER
6-7
        LANDFILL
        POND

        POND
        POND
        POND
SODIUM CARBONATE/SPRAY DRYING

COYOTE                 1       LANDFILL

MELLMAN LORD
DEAN H. MITCHELL       11
DELAWARE CITY          1
DELAWARE CITY          2
DELAWARE CITY          3
SAN JUAN               1
SAN JUAN               2
SAN JUAN               3
        POND
        POND
        POND
ELEMENTAL SULFUR
SULFURIC ACID
SULFURIC ACID
SULFURIC :z:o
ELEMENTAL SULFUR
ELEMENTAL SULFUR
SULFURIC ACID
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
                                               661

-------
EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1901
                                           SECTION 9
                               SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT MAKE UNIT MO.
ALABAMA ELECTRIC
TOMBIGBEE 2
ALABAMA ELECTRIC
TOM3IGBEE 3
ARIZONA ELECTRIC POWER
APACHE 2
ARIZONA ELECTRIC POWER
APACHE 3
ARIZONA PUBLIC SERVICE
CHOLLA 1
ARIZONA PUBLIC SERVICE
CHOLLA 2
ARIZONA PUBLIC SERVICE
CHOLLA 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZONA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
BASIN ELECTRIC POWER
LARAMIE RIVER 1
BASIN ELECTRIC POWER
LARAMIE RIVER 2
BIG RIVERS ELECTRIC
GREEN 1
BIG RIVERS ELECTRIC
GREEN 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
CINCINNATI GAS I ELECTRIC
EAST BEND 2
COLORADO UTE ELECTRIC
CRAIG 1
COLORADO UTE ELECTRIC
CRAIG 2
COLUMBUS ft SOUTHERN OHIO ELEC
CCNESVILLE 5
COLUMBUS ft SOUTHERN OHIO ELEC
CONESVILLE 6
COMMONWEALTH EDISON
POWERTOH 51
COOPERATIVE POWER ASSOCIATION
NEW OR 1
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
IAPACITY
MM
179.
179.
98.
98.
119.
264.
126.
175.
175.
229.
570.
570.
242.
242.
416.
617.
650.
410.
410.
411.
411.
450.
327.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIMESTONE
ENVIRONEERING, RILEY STOKER
DUAL ALKALI
GE ENVIRONMENTAL SERVICES
LIME
BABCOCK < WILCOX
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
AIR CORRECTION DIVISION, UOP
LIME
AIR CORRECTION DIVISION. UCP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
START-UP
GATE
9/73
6/79
8/78
6/79
10/73
4/78
3/81
11/79
11/79
11/79
7/SO
7/81
12/79
11/80
7/76
9/79
3/81
10/80
12/79
1/77
6/78
4/80
7/79
                                                       COMBUSTION ENGINEERING
                                              862

-------
              EPA UTILITY FGO SUSVEY: CCTOSER - OECEf.SER 1981
            SECTION 9
SUMMARY OF FGO SYSTEMS IN OPERATION
COMPANY NAME/
UHIT NAME UNIT NO.
COOPERATIVE POWER ASSOCIATION
COAL CREEK Z
DELMARVA POWER S LIGHT
DELAWARE CITY 1
DELMARVA POWER ft LIGHT
DELAWARE CITY 2
DELMARVA POWER ft LIGHT
DELAWARE CITY 3
OUQUESNE LIGHT
ELRAHA 1-4
DUQUESNE LIGHT
PHILLIPS 1-6
HOOSIER ENERGY
MEROM 2
INDIANAPOLIS POWER ft LIGHT
PETERSBURG 3
KANSAS CITY POWER S LIGHT
HAWTHORN 3
KANSAS CITY POWER & LIGHT
HAWTHORN 4
KANSAS CITY POWER ft LIGHT
LA CYGNE 1
KANSAS POWER ft LIGHT
JEFFREY 1
KANSAS POWER t LIGHT
JEFFREY 2
KANSAS POWER ft LIGHT
LAURENCE 4
KANSAS POWER S LIGHT
LAURENCE 3
KENTUCKY UTILITIES
GREEN RIVER 1-3
LOUISVILLE GAS t ELECTRIC
CANE RUN 4
LOUISVILLE GAS t ELECTRIC
CANE RUN 5
LOUISVILLE GAS S ELECTRIC
CANE RUN 6
LOUISVILLE GAS ft ELECTRIC
MILL CREEK 1
LOUISVILLE GAS t ELECTRIC
HILL CREEK 2
LOUISVILLE GAS ft ELECTRIC
HILL CREEK 3
LOUISVILLE GAS t ELECTRIC
NEW OR C
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
:APACITY
MM
327.
60.
60.
60.
510.
408.
441.
532.
90.
90.
874.
540.
490.
125.
420.
64.
188.
200.
299.
358.
350.
427.
72.
PROCESS/
SYSTEM SUPPLIER
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
UELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
UELLMAM LORD
DAVY MCKEE
LIME
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
DUAL ALKALI
THYSSEN/CEA
LIME
COMBUSTION ENGINEERING
LIKE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
START-UP
DATE
7/80
s/eo
5/60
5/80
10/75
7/73
12/81
12/77
11/72
8/72
2/73
8/78
1/80
1/77
4/78
9/75
8/76
12/77
4/79
12/80
12/81
8/78
4/73
                        COMBUSTION ENGINEERING
               863

-------
EPA UTILITY FGD SURVEY:  OCTC3ER  -  DECEMBER  1981
                                           SECTION 9
                               SUMMARY  OF  FGD  SYSTEMS IN OPERATION
COMPANY HAME/
UNIT NAME UNIT NO.
MINNESOTA PQUER I LIGHT
CLAY BOSWELL 4
MINNKOTA POUER
MILTON R. YOUNS Z
MOIiONGAHELA POWER
PLEASANTS 1
MONONGAHELA POUER
PLEASANTS 2
MONTANA POUER
COLSTRIP 1
MONTANA POUER
COLSTRIP 2
MONTANA-DAKOTA UTILITIES
COYOTE 1
NEVADA POWER
REID GARDNER 1
NEVADA POUER
REID GARDNER Z
NEVADA POWER
REID GARDNER 3
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
NORTHERN STATES POUER
RIVERSIDE 6-7
NORTHERN STATES POUER
SHERBURNE 1
NORTHERN STATES POUER
SHERBURNE 2
PACIFIC POUER & LIGHT
JIM BRIDGER 4
PENNSYLVANIA POUER
BRUCE MANSFIELD 1
PENNSYLVANIA FOUER
BRUCE MANSFIELD 2
PENNSYLVANIA POUER
BRUCE MANSFIELD 3
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEM MEXICO
SAN JUAN 2
PUBLIC SERVICE OF NEU MEXICO
SAN JUAN 3
SALT RIVER PROJECT
CORONAOO 1
SALT RIVER PROJECT
CORONAOO 2
NEU OR (
RETROFIT
NEU
NEU
NEU
NEU
NEU
NEU
NEU
RETROFIT
RETROFIT
NEU
RETROFIT
RETROFIT
NEU
NEU
NEU
NEU
NEU
NEU
RETROFIT
RETROFIT
NEU
NEU
NEM
:APACITY
MU
475.
IBS.
663.
668.
360.
360.
440.
125.
125.
125.
115.
110.
740.
740.
550.
917.
917.
917.
361.
350.
534.
280.
280.
PROCESS/
SYSTEM SUPPLIER
LIME/ALKALINE FLYASH
PEABODY PROCESS SYSTEMS
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIME
BABCOCK * UILCOX
LIME
BABCOCK t UILCOX
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIME/ALKALINE FLYASH
THYSSEN/CEA
SODIUM CARBONATE/SPRAY DRYING
MHEELABRATCR-FRYE/R . I .
SODIUM CARBONATE
THYSSEN/CEA
SODIUM CARBONATE
THYSSEN/CEA
SODIUM CARBONATE
THYSSEN/CEA
UELLMAN LORD
DAVY MCKEE
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
SODIUM CARBONATE
AIR CORRECTION DIVISION. UOP
LIME
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
LIME
M.U. KELLOGG
UELLMAN LORD
DAVY MCKEE
UELLMAN LORD
DAVY KCKEE
UELLMAN LORD
DAVY MCKEE
LIMESTONE
M.U. KELLOGG
LIMESTONE
M.U. KELLOGG
STAPT-UP
DATE
6/80
0/77
3/79
10/80
9/75
5/76
4/61
3/74
4/74
6/76
7/7&
11/80
3/76
3/77
9/79
12/75
7/77
6/80
4/78
8/78
12/79
11/79
7/80
                                             864

-------
              EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
            SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
SAN MIGUEL ELECTRIC
SAN MIGUEL 1
SIKESTON BPD OF MUNICIPAL UTIL
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 2
SOUTH CAROLINA PUBLIC SERVICE
MINYAH 3
SOUTH CAROLINA PUBLIC SERVICE
HINYAH 4
SOUTH MISSISSIPPI ELEC PUR
R.O. MORROW, SR. 1
SOUTH MISSISSIPPI ELEC PUR
R.D. MORROW. SR. 2
SOUTHERN ILLINOIS POWER
MARION 4
SOUTHERN INDIANA GAS i ELEC
A.B. BROUN 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
SPRINGFIELD MATER. LIGHT I PUR
DALLMAN 3
ST. JOE ZINC
G.F. WE ATOM 1
TENNESSEE VALLEY AUTHORITY
SHAKNEE 10A
TENNESSEE VALLEY AUTHORITY
SHAUNEE 10B
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 8
TEXAS POUER ft LIGHT
SANDOM 4
TEXAS UTILITIES
MARTIN LAKE 1
TEXAS UTILITIES
MARTIN LAKE 2
TEXAS UTILITIES
MARTIN LAKE 3
TEXAS UTILITIES
MONTICELLO 3
UTAH POUER S LIGHT
HUNTER 1
UTAH POWER t LIGHT
HUNTER 2
NEU C«J CAPACITY
RETROFIT MM
NEW
NEM
NEW
NEM
NEM
NEW
NEU
NEU
NEU
NEH
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEU
NEU
NEH
NEU
NEU
NEU
NEU
400.
235.
140.
280.
280.
124.
124.
173.
265.
194.
185.
60.
10.
10.
575.
550.
382.
595.
595.
595.
800.
360.
360.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
BABCOCK & UILCOX
LIMESTONE
BABCOCK & MILCOX
LIMESTONE
BABCOCK t UILCOX
LIMESTONE
BABCOCK 1 UILCOX
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
ENVIRONEERING, RILEY STOKER
LIMESTONE
ENVIRONEERING, RILEY STOKER
LIMESTONE
BABCOCK t UILCOX
DUAL ALKALI
FMC
LIMESTONE
AIR CORRECTION DIVISION. UOP
LIMESTONE
RESEARCH-COTTRELL
CITRATE
MORRISON t KNUDSEN/U.S.B.M.
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
STAKT-U?
DATE
8/51
6/81
7/77
5/80
7/81
8/73
6/79
5/79
3/79
4/77
12/80
11/79
4/72
4/72
3/81
5/77
12/80
4/77
5/78
2/79
5/78
5/79
6/80
                865

-------
EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1931
                                           SECTION 9
                               SUMMARY OF FGD SYSTEMS IN OPERATION
   COMPANY NAME/                    NEW OR   CAPACITY  PROCESS/                       START-UP
   UNIT NAME             UNIT NO.  RETROFIT     MM     SYSTEM SUPPLIER                  DATE


   UTAH POWER t LIGHT              NEW          366.    LIME                             5/78
   HUHTINGTON             1                            GE ENVIRONMENTAL SERVICES

   UTAH POWER t LIGHT              RETROFIT     330.    SODIUM CARBONATE                 9/81
   HAUGHTON               3                            AIR CORRECTION DIVISION.  UOP


   TOTAL                                      3Z683.
                                              866

-------
                 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1931
               SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
ASSOCIATED ELECTRIC
THOMAS HILL 3
BASIN ELECTRIC POWER
ANTELOPE VALLEY 1
BASIN ELECTRIC POUER
ANTELOPE VALLEY 2
BASIN ELECTRIC POUER
LARAMIE RIVER 3
BIG RIVERS ELECTRIC
D.B. UILSON 1
COLORADO UTE ELECTRIC
CRAIG 3
DESERET GEN ft TRANS
BONANZA 1
EAST KENTUCKY POUER
SPUR LOCK 2
GRAND HAVEN BRD OF LIGHT t PMR
J.B. SIMS 3
HOOSIER ENERGY
MEROM 1
HOUSTON LIGHTING ft POUER
U.A. PARISH 8
INDIANAPOLIS POUER ft LIGHT
PETERSBURG 4
LAKELAND UTILITIES
MCINTOSH 3
LOUISVILLE GAS ft ELECTRIC
MILL CREEK 4
MARQUETTE BOARD OF LIGHT t PUR
SHIR AS 3
MICHIGAN SO CENTRAL PUR AGENCY
PROJECT 1
MONTANA POWER
COLSTRIP 3
MONTANA POUER
COLSTRIP 4
MUSCATINE POUER ft UATER
MUSCATINE 9
NIAGARA MOHAWK POUER
CHARLES R. HUNTLEY 66
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
NEU OR
RETROFIT
RETROFIT
RETROFIT
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
RETROFIT
NEW
CAPACITY
755.
755.
670.
440.
440.
570.
440.
447.
410.
500.
65.
441.
492.
530.
364.
495.
44.
55.
700.
700.
166.
100.
421.
PROCESS/
SYSTEM SUPPLIER
LIME
BABCOCK ft UILCOX
LIME
BABCOCK t UILCOX
LIMESTONE
M.M. KELLOGG
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
BABCOCK ft UILCOX
LIMESTONE
M.U. KELLOGG
LIME/SPRAY DRYING
BABCOCK ft UILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIME
THYSSEN/CEA
LIME
BABCOCK ft UILCOX
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
BABCOCK ft MILCOX
LIME
AMERICAN AIR FILTER
LIME/SPRAY DRYING
GE ENVIRONMENTAL SERVICES
LIMESTONE
BABCOCK ft MILCOX
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIMESTONE
RESEARCH-COTTRELL
AQUEOUS CARBONATE/SPRAY DRYING
ROCKUELL INTERNATIONAL
DUAL ALKALI
FMC
START-UP
DATE
12/34
12/84
1/32
10/83
10/85
LI/82
7/34
4/33
9/84
1/83
1/63
5/82
11/82
10/84
1/62
6/82
9/82
6/82
10/83
0/34
9/62
4/62
6/83
                  667

-------
EFA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
                                           SECTION 10
                            SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
PACIFIC FCWEH & LIGHT
JIM BRIDGE!? 2A
PHILADELPHIA ELECTRIC
CROM3Y 1
PHILADELPHIA ELECTRIC
EODYSTONE 1
PHILADELPHIA ELECTRIC
EODYSTONE 2
PLAINS ELECTRIC G S, T
PLAINS ESCALANTE 1
PUBLIC SERVICE INDIANA
GIBSON 5
PUBLIC SERVICE OF NEM MEXICO
SAN JUAN 4
SEMINOLE ELECTRIC
SEMINOLE 1
SOUTH CAROLINA PUBLIC SERVICE
CROSS 2
SUNFLOWER ELECTRIC
HOLCOMB 1
TENNESSEE VALLEY AUTHORITY
PARADISE 1
TENNESSEE VALLEY AUTHORITY
PARADISE 2
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
UNITED POWER ASSOCIATION
STANTON 1A
UTAH POWER t LIGHT
HUNTER 3
UTAH POWER t LIGHT
HUNTER 4
WEST PENN POWER
MITCHELL 33
NEM OR (
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEM
NEW
NEM
NEM
NEW
NEW
RETROFIT
RETROFIT
NEM
NEM
NEM
NEM
RETROFIT
:APACITY
MW
100.
150.
240.
334.
233.
650.
534.
620.
500.
347.
704.
704.
400.
50.
400.
400.
300.
PROCESS/
SYSTEt SUPPLIER
LIME/SODIUM CARBONATE
FLAKT
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
M.M. KELLOGG
MELLMAN LORD
DAVY MCKEE
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
RESEARCH-COTTRELL
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
START-UP
DATS
1/82
5/63
12/82
12/82
12/83
8/82
6/82
3/83
11/83
9/83
0/83
0/83
10/82
6/82
6/83
6/85
8/82
   TOTAL
                                              16666.
                                              868

-------
                                          EPA UTILITY  FGO SURVEY: OCTOBER - DECEMBER 1=31
                                        SECTION  11
                          SUMMARY  OF  CONTRACT  AWARDED  F6D SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
BIG RIVERS ELECTRIC
0.8. WILSON 2
EAST KENTUCKY POWER
J.K. SMITH 1
HOUSTON LIGHTING I PCWER
LIMESTONE 1
HOUSTON LIGHTING S POWER
LIMESTONE 2
NORTHERN INDIANA PUB SERVICE
SCHAHFER 18
PLATTE RIVER POWER AUTHORITY
RAWHIDE 1
SEMINOLE ELECTRIC
SEMIHOLE 2
SOUTH CAROLINA PUBLIC SERVICE
CROSS 1
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS 1
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY 1
TAMPA ELECTRIC
BIG BEND 4
TEXAS POWER & LIGHT
TWIN OAKS 1
TEXAS POWER t LIGHT
TWIN OAKS 2
TEXAS UTILITIES
MARTIN LAKE 4
TUCSON ELECTRIC POWER
SPRINSERVILLE 1
TUCSON ELECTRIC POWER
SPRINGERVILLE 2
WEST TEXAS UTILITIES
OKLAUNION 1
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MM
440.
650.
750.
750.
421.
279.
620.
500.
720.
720.
475.
750.
750.
750.
370.
370.
504.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
M.W. KELLOGS
LIME
BABCOCK & WILCOX
LIMESTONE
CCM5USTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
DUAL ALKALI
FMC
LIME/SPRAT DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
RE5EARCH-COTTRELL
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
RESEARCH-COTTRELL
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
PROCESS NOT SELECTED
GE ENVIRONMENTAL SERVICES
START-UP
DATE
O/ 0
8/37
12/86
12/87
6/85
12/83
1/85
5/88
3/66
12/84
3/85
8/85
8/87
0/89
2/85
3/87
12/86
TOTAL
                                            9819.
                                           869

-------
EPA UTILITY FGD SURVEY:  OCTOBER  -  DECEMBER  1931
                                           SECTION  12
                                 SUTOARY OF PLANNED FGO SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
NEW OR
RETROFIT
CAPACITY
MW
PROCESS/
SYSTEM SUPPLIER
STA3T-UP
DATE
LETTER OF INTENT SIGNED
IOWA ELECTRIC LIGHT 1 PUR
GUTHRIE CO. 1
KENTUCKY UTILITIES
HANCOCK 1
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE 5
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE 6
MIDDLE SOUTH UTILITIES
UNASSIGNED 1
MIDDLE SOUTH UTILITIES
UHASSIGNED 2
MIDDLE SOUTH UTILITIES
MILTON 1
MIDDLE SOUTH UTILITIES
MILTON Z
NEVADA POWER
REID GARDNER 4
NEW YORK STATE ELEC I GAS
SOMERSET 1
TOTAL
REQUESTING/EVALUATING
CAJUN ELECTRIC POWER
OXBOW 1
DESERET GEN ( TRANS
BONANZA Z
GENERAL PUBLIC UTILITIES
COAL 1
GENERAL PUBLIC UTILITIES
SEMARD 7
JACKSONVILLE ELEC AUTHORITY
ST. JOHNS RIVER PUR PARK1
JACKSONVILLE ELEC AUTHORITY
ST. JOHNS RIVER PKR PARK2
LOUISVILLE GAS I ELECTRIC
TRIMBLE COUNTY 1
LOUISVILLE GAS i ELECTRIC
TRIM3LE COUNTY 2
SOUTHERN INDIANA GAS I ELEC
A.B. BROWN 2
TEXAS UTILITIES
FOREST GROVE 1
TOTAL

NEW
NEW
NEW
NEW
HEW
NEW
NEW
NEW
NEW
NEW

BIDS
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW

NEW


720.
650.
890.
890.
890.
890.
890.
890.
250.
625.
7585.

540.
410.
625.
690.
600.
600.
575.
575.
265.
750.
5630.
870
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK I WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
SODIUM CARBONATE
THYSSEH/CEA
LIMESTONE
PEABOOY PROCESS SYSTEMS


PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED


11/87
4/39
0/90
0/92
0/89
0/93
0/83
0/91
4/83
6/84


0/85
0/88
5/91
5/89
12/85
6/87
7/85
7/89
1/85
0/87



-------
                                          EPA UTILITY FCO SURVEY:  'C'CSEH - DECEM5EB 19S1
                                        SECTICN 12
                              SUMMARY OF PLANNED FGO SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
CONSIDERING FGO SYSTE
ATLANTIC CITY ELECTRIC
CUMBERLAND 1
CAJUM ELECTRIC POWER
CHICOT 1
CAJUN ELECTRIC POWER
CHICOT 2
CAJUM ELECTRIC POWER
CHICOT 3
CAJUN ELECTRIC POWER
CHICOT 4
CAJUN ELECTRIC POWER
OXBOW 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
CENTRAL MAINE POWER
SEARS ISLAND 1
CENTRAL POWER I LIGHT
COLETO CREEK 2
CINCINNATI GAS I ELECTRIC
EAST BEND 1
COLUMBUS t SOUTHERN OHIO ELEC
POSTON 5
COLUMBUS t SOUTHERN OHIO ELEC
POSTON 6
OELMARVA POWER « LIGHT
VIENNA 9
FLORIDA POWER * LIGHT
MARTIN 3
FLORIDA POWER I LIGHT
MARTIN 4
GENERAL PUBLIC UTILITIES
COAL 2
GENERAL PUBLIC UTILITIES
COAL 3
GENERAL PUBLIC UTILITIES
COAL 4
INDIANAPOLIS POWER 1 LIGHT
PATRIOT 1
INDIANAPOLIS POWER ft LIGHT
PATRIOT 2
INDIANAPOLIS POWER ft LIGHT
PATRIOT 3
KENTUCKY UTILITIES
NEW CR
RETROFIT
MS
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW .
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW

330.
562.
562.
562.
562.
540.
450.
600.
720.
650.
375.
375.
550.
aoo.
800.
625.
625.
625.
650.
650.
650.
650.
FPCCESS/
SYSTEM SUPPLIER

PPOCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VEN3CH NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
STAHT-uP
GATE

l/e3
3/36
0/53
0/92
0/94
0/85
1/87
11/89
9/92
0/38
s/ee
0/89
5/90
0/87
0/89
5/93
5/95
5/96
0/87
O/ 0
O/ 0
4/94
HANCOCK
                                                    VENDOR NOT SELECTED
                                           871

-------
EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981
                                           SECTION 12
                                 SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
LANSING BOARD OF MATER & LIGHT
ERICKSON 2
LOS ANGELES DEPT OF MTH 8 PWR
INTERMOUHTAIN 1
LOS AN5ELES DEPT OF WTR i PWR
INTERMOUNTAIN Z
LOS ANGELES DEPT OF WTR & PWH
INTERMOUNTAIN 3
LOS ANGELES DEPT OF WTR t PMR
INTERMOUNTAIN 4
LOMER COLORADO RIVER AUTH
FAYETTE POWER PROJECT 3
NEBRASKA PUBLIC POMER DISTRICT
FOSSIL III 1
NEVADA POMER
HARRY ALLEN 1
NEVADA POMER
HARRY ALLEN Z
NEVADA POMER
HARRY ALLEN 3
NEVADA POMER
HARRY ALLEN 4
NORTHERN STATES PCMER
METRO COAL 1
NORTHERN STATES POMER
SHERBURNE 3
PACIFIC GAS A ELECTRIC
MONTEZUMA 1
PACIFIC GAS * ELECTRIC
MOHTEZUMA Z
PACIFIC POMER t LIGHT
JIM BRIDGER 1
PACIFIC POMER t LIGHT
JIM BRIOGER Z
PACIFIC PCMER ft LIGHT
JIM BRIDGER 3
PMR AUTHORITY OF STATE OF NY
FOSSIL
SALT RIVER PROJECT
CORONAOO 3
SOUTHMESTERN ELECTRIC POMER
DOLET HILLS Z
SOYLAND POMER
SOYLAND 1
TEXAS UTILITIES
MILL CREEK 1
HEW OR (
RETROFIT
NEM
NEW
NEW
NEW
NEM
NEW
NEM
NEM
NEM
NEM
NEM
NEH
NEM
NEH
NEW
RETROFIT
RETROFIT
RETROFIT
NEM
NEM
NEM
NEH
NEM
:APACITY
MU
160.
820.
620.
820.
820.
435.
650.
500.
500.
500.
500.
ZOO.
810.
aoo.
800.
550.
550.
550.
700.
280.
720.
500.
750.
PROCESS/
SYSTEM SUPPLIER
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
START-UP
DATE
1/87
0/86
0/87
0/88
0/89
0/83
3/92
6/86
6/87
6/88
6/89
0/90
0/85
6/93
6/94
0/88
0/90
0/86
4/87
0/89
0/88
6/87
0/87
                                              872

-------
                                          EPA UTILITY  FCO SURVEY:  OCTOBER  - DECEASES  1981
                                        SECTION 12
                              SUMMARY OF PLANNED FGD  SYSTEMS
COMPANY NAME/ NEW OR
UNIT NAHE UNIT HO. RETROFIT
TEXAS UTILITIES NEH
HILL CREEK 2
WASHINGTON UftTER POWER HEW
CRESTON COAL 1
WASHINGTON HATER POWER NEW
CHESTON COAL 2
WASHINGTON MATER POWER HEW
CRESTON COAL 3
WASHINGTON WATER POWER NEW
CRESTON COAL 4
WEST TEXAS UTILITIES NEW
OKLAUNION Z
CAPACITY PROCESS/
KM SYSTEM SUPPLIER
750. PROCESS NOT SELECTED
VENDOR NOT SELECTED
570 . LIMESTONE
VENDOR NOT SELECTED
570. LIMESTONE
VENDOR NOT SELECTED
S70. LIMESTONE
VENDOR NOT SELECTED
570. LIMESTONE
VENDOR NOT SELECTED
720. PROCESS NOT SELECTED
VENDOR NOT SELECTED
STA3T-UP
OWE
o/aa
0/87
0/67
0/87
0/37
0/90
TOTAL
                                           30398.
                                           873

-------
EPA UTILITY F6D SURVEY:  OCTOBER - DECEMBER 1981
                                           SECTION 13
                        TOTAL FGD UNITS AND CAPACITY (Mill INSTALLED BY YEAR
YEAR
1966
1969
1973
1973
197*
1975
1976
1977
197B
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
UNDEFINED
HEW
MO.
1
0
9
5
3
7
7
11
14
20
20
11
18
16
9
13
8
20
12
11
5
2
4
3
3
1
1
8
ON LINE
MM
140.
0.
674.
1568.
416.
2182.
2699.
4589.
4958.
6360.
6704.
4397.
6005.
6760.
5211.
6806.
4781.
12200.
7117.
6930.
2910.
1515.
2822.
2315.
2012.
625.
625.
2246.
TERMINATED
MO. MM
0
1
0
1
3
5
4
4
0
2
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

0.
140.
0.
10.
340.
628.
1014.
2049.
0.
143.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.

TOTAL ON LIME
NO. m
I
0
9
13
13
15
18
25
39
57
77
88
106
122
131
144
152
172
184
195
200
202
£06
209
212
213
214

140.
0.
674.
2232.
2308.
3862.
5547.
6087.
13045.
19262.
25966.
30363.
36368.
43128.
48339.
55145.
59926.
72126.
79243.
86173.
89083.
90598.
93420.
95735.
97747.
98372.
98997.

                                              874

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEM2E3
                                           SECTION 14
                  DESIGN AND PERFORMANCE DATA FOS OPERATIONAL PARTICLE SCRU3BERS
C0.1PANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MVI
G°OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
COMMONWEALTH EDISON
MILL COUNTY
1
ROMEOVILLE
ILLINOIS
E
   86.         I   .200 LB/MM3TU)
  774.         (  l.BOO LB/MMBTU)
******         (****** L8/MM37U)
 1147
  167
  137
  144
  167
 »» UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

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

•HI* PARTICLE CONTROL

 «• MECHANICAL COLLECTOR
     NUMBER
     TYPE

 «« FABRIC FILTER
     NUMBER
     TYPE

 *« ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - X

 «« PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     GAS CONTACTING DEVICE TYPE
     LIQUID RECIRCULATION RATE - LITER/S
     L/G RATIO - LITER/CU.M
     PH CONTROL ADDITIVE
     PRESSURE DROP - KPA
BABCOCK & MILCOX
CYCLONE
CYCLING
  363.36
  179.4
  107.
******
    3.B
                 770000 ACFM)
                 355 F)
                 350 FT)
               ( 12.4 FT)
               (  9570 BTU/LB)
                9100-10500
COAL
******
22260.

    7.40
3.0-16.0
********
******
    1.50
0.3-4.5
«*»««»»*
******
 0
NONE
 0
NONE
COLD SIDE
WESTERN PREC. DIVISION, JOY
  179.4        (   355 F)
   90.0
 2
 4/72
VEHTURI TOWER
VARIABLE-THROAT/SIDE-MOVABLE BLADES
N/A
BABCOCK t MILCOX
a.O X 26.0 X 16.0
NONE
               ( 5600 GPM)
               (18.0 GAL/1000ACF)
  365.4
    2.4
LIMESTONE
    2.2
                                                               (  9.0 IH-H20)
                                               875

-------
 EPA UTILITY FGD SLAVEY:  OCTOBER  - DECEMBER  1981

COMMONWEALTH EDISON:  MILL COUNTY  1 (CONT.)

     SUPERFICIAL GAS VELOCITY - M/S
     INLET GAS FLOW PATE  - CU.M/S
     INLET GAS TEMPERATURE -  C
     PARTICLE PEKOVAL EFFICIENCY  - X
     ENERGY CCNSJMPTION - X
                          36.6
                         181.7
                         179.4
                          98.0
                           4.2
(   120.0 FT/S)
(  385000 ACFM)
(   355 F)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION
                                                               X REMOVAL   PER  BOILER  FGD   CAP.
                                                               S02  PART. HOURS HOURS  HOURS  FACTOR
 2/72  SYSTEM

       »« PROBLEMS/SOLUTIONS/COMMENTS
                                                                            696
                         IN FEBRUARY  1972 THE BABCOCK & UILCOX MET LIMESTONE FGO SYSTEM AT MILL
                         COUNTY  COMMENCED OPERATION.  THE  LONGEST PERIOD OF CONTINUOUS OPERATION
                         HAS 23  DAYS  WITH ONE OF THE TWO MODULES.  THE S02 REMOVAL EFFICIENCY UAS
                         ABOUT 85X AND THE  PAHTICULATE MATTER REMOVAL EFFICIENCY UAS ABOUT 93X.
                         THE SYSTEM MAS  PLAGUED WITH MANY  MECHANICAL PROBLEMS.  THE MAIN
                         PROBLEMS  ASSOCIATED MITH THE FGD  SYSTEM HEPE PLUGGING OF THE MIS-
                         ELIMINATORS, CORROSION OF THE REHEATER TUBES AND SLUDGE DISPOSAL.  TO
                         SOLVE THE MIST  ELIMINATOR AND REHEATER PROBLEMS, A CONSTANT UNCE3SPPAY AND
                         INTERMITTENT OVERSPRAY HERE USED  TO MASH ALL THE MIST ELIMINATOR COMPART-
                         MENTS.  THE  REHEATER UNIT MAS ALSO RETUBED.
                         DURING  THE FIRST TMO MONTHS OF 1975 MODULE A MAS OPERATIONAL WHEN NEEDED
                         WHILE MODULE B  MAS UNDERGOING MODIFICATIONS.
 3/72  A
       B
       SYSTEM
        .0
      35.0
                                                                            744
       *» PROBLEMS/SOLUTIONS/COMMENTS
                         IN MARCH  1972 MODULE A UAS DOWN FOR REPAIRS AND MODIFICATION OF THE MIST
                         ELIMINATOR MASH PIPING ASSEMBLY.  MODULE B MAS REMOVED EVERY TWO OR THREE
                         DAYS TO HAND MASH THE MIST ELIMINATOR.

                         OTHER  PROBLEMS ENCOUNTERED DURING THE MONTH INCLUDED VIBRATION OF THE
                         REHEATER  TUBE BUNDLES, RAPID EROSION OF THE SCRUBBER SPRAY NOZZLES, AND
                         PLUGGING  OF THE VENTURI NOZZLES.
 4/72  A
       B
       SYSTEM
      34.0
      14.0
                                                                            720
          PROBLEMS/SOLUTIONS/COMMENTS
                        MODULE A MAS OUT OF SERVICE FOR SIX DAYS IN APRIL BECAUSE OF A NEAR-
                        RUPTURE OF A VENTURI PIPE EXPANSION JOINT AND HEAVY BUILDUP OF SOLIDS
                        ON THE MIST ELIMINATOR.

                        MODULE B UAS OUT OF SERVICE MOST OF THE TIME FOR SIMILAR REPAIR OF THE
                        VENTURI PIPE EXPANSION JOINT, AND FOR MODIFICATION OF THE REHEATER UNIT
                        AND MIST ELIMINATOR MASH SYSTEM.
 5/72   A
       B
       SYSTEM
      70.0
      32.0
                                                                            744
       «*  PROBLEMS/SOLUTIONS/COMMENTS
 6/72   A
MODULE B UAS OUT OF SERVICE FOR TMO WEEKS IN MAY TO REBPACE THE REHEAT,
INSTALL UNDERSPRAY NOZZLES ON THE MIST ELIMINATOR,  AND TO INSTALL HEAVIER
SCREENS IN THE SUMP.

REHEATER PLUGGING DURING THE MONTH CAUSED ADDITIONAL OUTAGES.

       8.0
                                              876

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER  1981
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER   BOILER   FGD   CAP.
                                                                S02  PART.  HOURS HOURS  HOURS FACTOR
       B
       SYSTEM
                               31.0
                                                                             720
       *» PROBLEMS/SOLUTIONS/COMMENTS
 7/72  SYSTEM

 8/72  A
       B
       SYSTEM
                         DURING JUNE BOTH MODULES MERE OUT OF SERVICE PART OF THE MONTH  DUE TO
                         A HIGH DIFFERENTIAL PRESSURE ACROSS THE MIST ELIMINATORS AND PLU3GINS
                         OF THE MIST ELIMINATORS DUE TO A LEAKING BYPASS VALVE.

                         THE RUBBER LINER IN MODULE A MAS REPLACED DURING THE MONTH.

                                                                             744
79.0
21.0
                                                                             744
       *« PROBLEMS/SOLUTIONS/COMMENTS
                         A TWO DAY OUTAGE DURING AUGUST MAS NECESSARY TO UNPLUG THE VENTURI NOZZLES
                         AND THE MIST ELIMINATOR OF MODULE A.

                         MODULE B HAS OUT OF SERVICE 22 DAYS FOR CLEANING OF THE MIST ELIMINATOR
                         AND REHEATER. INSTALLATION OF OVERHEAD SPRAY NOZZLES AND REPLACEMENT CF
                         SECTIONS OF THE MIST ELIMINATOR.

                         THE BOILER MAS SHUTDOWN FOR TWO DAYS TO REPAIR THE TURBINE/GENERATOR.
 9/72  A
       B
       SYSTEM
  .0
30.0
                                                                             720
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         THE BOILER HAS OFF LINE FROM SEPTEMBER 1 TO SEPTEMBER 5 DUE TO A LACK OF
                         DEMAND.

                         AN ID FAN PROBLEM CAUSED UNSTABLE OPERATION DURING THE MONTH.

                         MODULE A HAS OUT OF SERVICE IN SEPTEMBER DUE TO THE NECESSARY  MODIFICATION
                         OFTHE REHEATER AND TO REPAIR THE RECYCLE TANK SCREENS.
10/72  A
       B
       SYSTEM
  .0
  .0
                                                                             744
       o* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING OCTOBER THE BOILER HAS OUT OP SERVICE THE ENTIRE MONTH.

                         MODULES A AND B HERE OUT OF SERVICE DUE TO THE INSTALLATION OF  THE REKEATER
                         BAFFLE PLATES TO DAMPEN VIBRATIONS AND ALSO THE INSTALLATION OF AN EXPERI-
                         MENTAL MIST ELIMINATOR HASH SYSTEM.
11/72  A
       B
       SYSTEM
  .0
  .0
                                                                             720
       ** FROBLEMS/SOLUTIONS/CCMflENTS

                         THE BOILER REMAINED OUT OF SERVICE DURING THE MONTH OF NOVEMBER.

                         MODULES A AND B REMAINED OUT OF SERVICE DUE TO UNSTABLE OPERATIONS OF THE
                         BOILER.
                                               877

-------
 EPA UTILITY F60 SURVEY: OCTOBER - DECEMBER 1981

COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILZTY RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER   FGO    CAP.
                                                                S02  PART. HOUFS  HOURS  HOo'PS FACTOR


12/72  A                       22.0
       B                       30.0
       SYSTEM                                                                744

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         MODULES A AND B OPERATED INTERMITTENTLY DURING  DECEMBER  DUE  TO  TESTING OF
                         THE ESP AND MISCELLANEOUS INSTRUMENT PROBLEMS.

 1/73  A                         .0
       B                         .0
       SYSTEM                                                                744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING JANUARY MODULES A AND B MERE OUT OF  SERVICE  THE ENTIRE MONTH  TO
                         PERFORM SOME NECESSARY REPAIRS AND MODIFICATIONS TO THE  SYSTEM.

 2/73  A                       22.0
       B                       24.0
       SYSTEM                                                                672

       »* FROBLEMS/SOLUTIONS/COMMENTS

                         DURING FEBRUARY MODULES A AND B REMAINED OUT  OF SERVICE  DUE  TO  CRACKS
                         IN THE INLET DUCTWORK OF THE BOOSTER FAN.

                         THE IMPROPER INSTALLATION OF THE MIST ELIMINATOR IN MODULE B CAUSED
                         PLUGGING IN THE REHEATER.

 3/73  A                       65.0
       B                       11.0
       SYSTEM                                                                744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         MODULE A HAS OUT OF SERVICE FOR FIVE DAYS IN  MARCH  DUE TO PLUGGING OF THE
                         MIST ELIMINATOR.

                         DURING MARCH THE BOILER HAS OUT OF SERVICE  FOR  APPROXIMATELY FOUR DAYS
                         DUE TO AN INSPECTION.

                         MODULE B MAS OUT OF SERVICE PART OF THE MONTH DUE TO REHEATER TUBE LEAKS.

 4/73  A                        6.0
       B                       13.0
       SYSTEM                                                                720

       «« PROBLEMS/SOLUTIONS/COMMENTS

                         DURING APRIL PROBLEMS OCCURRED DUE TO THE DEPOSITS  OF CALCIUM SULFATE
                         SCALE ON THE REHEATER TUBES OF MODULE A.

                         PERSISTING PROBLEMS WITH THE MIST ELIMINATOR  MERE ENCOUNTERED DURING THE
                         MONTH.

 5/73  A                         .0
       B                         .0
       SYSTEM                                                                744
                                               878

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER - OECEMSER 1981

COMMONWEALTH EOI30M:  MILL COUNTY 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                S03  PART.  HOU3S HOUPS  HOURS FACTCR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                         MODULES A AND B MERE OUT OF SERVICE FOR THE ENTIRE MONTH OF MAY.

 6/73  A                       16.0
       B                         .0
       SYSTEM                                                                7ZO

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING JUNE BOILER-RELATED PROBLEMS MERE RESPONSIBLE FOR MOST OF THE
                         OUTAGE TIME OF MODULE A.  MODULE B UAS TAKEN OUT OF SERVICE TO ALLOV4
                         CONCENTRATION ON THE PROBLEMS OF MODULE A.

 7/73  A                       51.0
       B                         .0
       SYSTEM                                                                7

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         DURING OCTOBER MODULE A TRIPPED SEVERAL TIMES DUE TO BAD LIMIT SWITCHES
                         IN THE BYPASS AND THE BLOCK DAMPERS.

                         THE BOILER MAS TAKEN OUT OF SERVICE TO BALANCE THE BOOSTER 1.0. FAN.

11/73  A                       51.0
       B                         .0
       SYSTEM                                                                720

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING NOVEMBER  PROBLEMS OCCURRED WITH THE MIST ELIMINATOR DUE TO POOR GAS
                         DISTRIBUTION.
                                               679

-------
 EPA UTILITY FGD SURVEY:  OCTOBER  -  DECEMBER  1981

COMMONWEALTH EDISON:  MILL COUNTY  1  ICONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY DURABILITY RELIABILITY UTILIZATION   X REMOVAL   PER  BOILER   FGD    CAP.
                                                                S02  PART. HOURS HOLPS  HOURS  FACTC3

                         MODULE  A  MAS TAKEN  OUT OF SERVICE  FOR  AN INSPECTION.  CLEANING AND MODI-
                         FICATIONS MERE ALSO DONE DURING NOVEMBER.

12/73  A                         .0
       B                         .0
       SYSTEM                                                               744

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         MODULES A AND B MERE OUT OF SERVICE DURING DECEMBER DUE TO MODIFICA-
                         TIONS AMD MAINTENANCE TO THE ISOLATION VALVES, PUMPS. VENTURI THROATS AND
                         THE  MIST  ELIMINATOR.

 1/7*  A                         . 0
       B                         .0
       SYSTEM                                                               7**

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         MODULES A AND B HERE OUT OF SERVICE DUE TO FREEZING IN THE 10-INCH-DIAME-
                         TERi 4400 FT. LINE  BETWEEN THE MODULES AND THE POND.

                         DAMAGE  OCCURRED TO  THE SUMP PUMPS  AND  ALSO SOME OTHER INSTRUMENTS DUE TO
                         THE  FREEZING.

 2/74  A                         .0
       B                         .0
       SYSTEM                                                               672

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         DURING  FEBRUARY THE FROZEN PIPELINES MERE THAWED. REAMCHCRED AND RETURNED
                         TO SERVICE.  THE INSTRUMENTS DAMAGED BY THE FREEZING WERE REPAIRED.

                         MODULE  A  REMAINED OUT OF SERVICE UNTIL THE ARRIVAL OF THE SECOND-STAGE
                         MIST ELIMINATOR.

 3/74  A                      21.0
       B                         .0
       SYSTEM                                                               744

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         MODULE  A  HAS OPERABLE MARCH 20, BUT HAS NOT RETURNED TO SERVICE  UNTIL
                         MARCH 27  DUE TO THE BOILER BEING CUT OF SERVICE.

 4/74  A                      72.0
       B                         .0
       SYSTEM                                                               720

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING  APRIL MODULE A OPERATED ON  LOW-SULFUR COAL FCR 23 CONSECUTIVE  DAYS.
                         TWO  SHORT INSPECTION OUTAGES OCCURRED  DURING THAT TIME.

                         THE  SUMP  SCREEN FROM MODULE B HAS  SUBSTITUTED FOR THE DAMAGED SCREEN  IN
                         MODULE  A.

 5/74  A                      93.0
       B                         .0
       SYSTEM                                                               744
                                               880

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1931
COMMONWEALTH EDISON: HILL COUNTY 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FC-0   CAP.
                                                                S02  PART.  HOURS HOUPS  HCL'=S FACTOR
       *« PROBLEMS/SOLUTIONS/COMttENTS
                         DURING MAY MODULE A OPERATED MOST OF THE TIME ON HIGH-SULFUR COAL.
                         THIS TIME A FEW SHORT OUTAGES OCCURRED FOR INSPECTIONS.
                                                                                             DURING
 fr/74  A
       B
       SYSTEM
55.0
  .0
                                              720
          PHOBLEMS/SOLUTIONS/COMMENTS

                         DURING JUNE MODULE A OPERATED FOR APPROXIMATELY 300 HOURS.

                         TWO WEEKS OF' OUTAGE TIME WAS NECESSARY TO MAKE REPAIRS TO THE VENTURI
                         THROAT DRIVE.
 7/74  A
       B
       SYSTEM
96.0
  .0
                                              744
       
-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

COMMONWEALTH EOISCT. MILL COUNTY 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  '/. REMOVAL   PER  BOILER  FG3   CAP.
                                                                S02   PART.  HOU3S HOUSS  HO'JSS FACTC3


       *» PHOBLEMS/SOLUTIONS/COMMENTS

                         MODULE A MAS SHUT DOWN THREE TIMES DURING NOVEMBER.   TWICE DUE TO LACK OF
                         DEMAND AND ONCE FOR AN INSPECTION.

12/7*  A                       99.0
       B                         .0
       SYSTEM                                                                744

       WN PROBLEMS/SOLUTIONS/COMMENTS

                         MODULE A MAS TAKEN OFF LINE PART OF THE MONTH  TO REPAIR THE VALVE IN THE
                         SPENT LIQUOR LINE TO THE POND AND ALSO FOR  AN  INSPECTION.

 1/75  A                       99.0
       B                         .0
       SYSTEM                                                                744

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         MODIFICATIONS OF MODULE B ARE STILL CONTINUING.

                         DURING JANUARY MODULE A HAS OUT OF SERVICE  TWICE;   ONCE FOR AN INSPECTION
                         AND ONCE DUE TO LACK OF DEMAND.

 2/75  A                       99.0
       B                         .0
       SYSTEM                                                                672

       «<> PROBLEMS/SOLUTIONS/COMMENTS

                         DURING FEBRUARY MODULE A WAS OUT OF SERVICE TWO  TIMES DUE  TO LACK OF DE-
                         MAND AND ALSO FOR AN INSPECTION.  THE INSPECTION SHOWED THAT CONDITION'S
                         INSIDE THE MODULE MERE THE SAME AS BEFORE.

                         DURING THE MONTH A SMALL REHEATER LEAK IN A STAINLESS STEEL BUNDLE CAUSED
                         THE SYSTEM. TO SHUT DOWN.

                         DURING THE INSPECTION OF MODULE A. THE UNDER WASH NOZZLES HERE CLEANED ANT)
                         A SMALL SECTION FO THE MIST ELIMINATOR MAS  REPLACED.

                         CHICAGO FLYASH IS TREATING MATERIAL FROM THE SYSTEM WITH PORTLAND
                         CEMENT AND FLYASH AND DUMPING THE TREATED MATERIAL INTO THE NORTH HALF
                         OF THE HOLDING BASIN.

 3/75  A           94.0        99.2                    81.2
       B             .0          .0                      .0
       SYSTEM                                                                744   609

       «» PROBLEMS/SOLUTIONS/COMMENTS

                         A VENTURI HOSE LEAK FORCED MODULE A OUT ONCE.

                         MODULE B MAS OUT OF SERVICE TWICE FOR NO DEMAND  AND  ONCE AS A RESULT OF AN
                         ACCIDENTAL 50 MINUTE TRIP.

                         COAL BURNED THIS MONTH AVERAGED LESS THAN ONE  PERCENT SULFUR.

 4/75  A           37.0        39.5                    35.0
       B             .0          .0                      .0
       SYSTEM                                                                720   633
                                               602

-------
                                              EPA UTILITY  FGO  SURVEY:  OCTOBER  -  OECEH3ER  1981

COMMONWEALTH EDISON:  MILL COUNTY 1 (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER   FG3    CAP.
                                                                S02  PART.  HO'J=S HOURS   HOU7S FAC7C3


       ** PRGBLEMS/SOLUTIONS/COMMENTS

                         CHICAGO FLY ASH IS TREATING MATERIAL FROM THE  SCRUBBER  WITH  LIME AKD FLY
                         ASH AND DUMPING IT INTO THE HOLDING BASIN.

                         A BOILER OUTAGE FORCED MODULE A OUT OF SERVICE ONCE THIS MONTH  (MODULE B
                         MAS ALREADY OUT OF SERVICE).

                         COAL BURNED THIS MONTH HAS RECLAIM COAL AND  VARIED IN SULFUR CONTENT.

 5/75  A           64.5        84.5                    84.5
       B           37.1        37.1                    37.1
       SYSTEM                                                                744   744

       ** PH03LEMS/SOLUTIONS/COMMENTS

                         MODULE B MAS IN SERVICE ON MAY 20 FOR THE FIRST TIME SINCE APRIL 13, 1973.

                         RECIRCULATION TANK MIXERS.

                         MODULE A (WHICH MAS THE ONLY  ONE OPERATING I  MAS FORCED  OUT TWICE IN  APRIL
                         TO AVOID POND OVERBOAROING INTO THE DES PLAINES RIVER.  THE SECCND OUTAGE
                         LASTED UNTIL MAY 5. DURING THE PAST SEVERAL  MONTHS OF GENERALLY COHTINUCUS
                         OPERATION OF MODULE A. IT HAS BECOME APPARENT  THAT THE  PRESENT  LIQUID
                         CIRCULATING SYSTEM CANNOT BE  OPERATED IN A CONTINUOUSLY CLOSED  CYCLE.  THE
                         MATER IMBALANCE POSES A HIGH  RISK OF OVERBOAROING FPCM  THE SLUDGE F3ND
                         DURING LONG PERIODS OF SUSTAINED OPERATON. THE FOLLOWING REVISIONS HAVE
                         BEEN MADE TO REDUCE THE HATER IMBALANCE:
                              1. THE PUMP GLAND MATER  FLOWS HAVE BEEN CUT  FROM 10 GPM TO 5 GPM.
                              2. THE SCRUBBER HOUSE SERVICE MATER FILTER BACKWASH HAS BEEN RCUTED
                                 OUT OF THE SYSTEM.
                              3. THE CONTINUOUS UNDERSPRAY HAS BEEN CHANGED TO AN INTERMITTENT
                                 SPRAY 5 MINUTES ON, 5 MINUTES OFF.

                         THE THICKENER HAS BEEN DOWN SINCE APRIL 21 DUE TO A BROKEN GEAR AND  A STUCK
                         SMEEP ARM. THE THICKENER HAS  BEEN BYPASSED AND THE SLUDGE IS GOING TO THE
                         POND.

                         DURING MAYi MODULE A HAS OUT  FOR 45 MINUTES  DUE TO A DAMPER  TRIP.

                         MODULE A HAS OUT ONCE FOR SPRAY NOZ2LE CLEANING.

                         MODULE B MAS OUT TWICE AFTER  START UP, ONCE  FOR A VENTURI PUMP  TRIP  AW
                         ONCE FOR A RECIRCULATION TANK LEVEL TRIP.

                         CHICAGO FLY ASH IS TREATING THE MATERIAL FROM  THE SCRUBBER WITH LIME AND
                         FLY ASH AND DUMPING IT INTO THE HOLDING BASIN. A  MIXER  HAS BEEN INSTALLED
                         AT THE THICKENER, WHICH ENABLES THEM TO SUBSTITUTE SEALED DUMP  TPL'CKS FCR
                         THE CEMENT TRUCKS WHICH MERE  USED IN THE PAST  FOR MIXING AND TRANSPORTING
                         THE MASTE MATERIAL TO THE HOLDING BASIN.

                         COAL BURNED THIS MONTH VARIED GREATLY IN SULFUR CONTENT, RANGING FKCM LEW
                         SULFUR WESTERN COAL TO HIGH SULFUR ILLINOIS  COAL.

 6/75  A           64.1        60.6                    54.1
       B           85.5        84.6                    75.4
       SYSTEM                                                                720   642

       «* PROBLEMS/SOLUTIONS/COHMENTS

                         A REHEATER PLUGGAGE INSPECTION FORCED ONE MODULE  A OUTAGE.

                         A LOM LEVEL TRIP CAUSED A 35 MINUTE OUTAGE,  AND NO DEMAND ACCOUNTED  FOR TWO
                                               883

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981

COMMONWEALTH EDISON: WILL COUNTY 1 (COHT.)
			PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X  REMOVAL    PER   BOILER  FGO   CAP.
                                                                S02   PART. HOIRS  HC'JSS  HC'JHS FACTOR

                         MORE MODULE A OUTAGES.

                         MODULE B HAS OUT FOR 95 HOURS TO CLEAN THE  BOOSTER  FAN AND  OEMISTSS.

                         HIGH BOOSTER FAN VIBRATIONS CAUSED  MODULE B TO  SHUT DOWN ON JUNE 30.

                         DURING THIS MONTH HIGH  SULFUR COAL  MAS BURNED IN A  TWO WEEK TEST.  AND LOW
                         SULFUR COAL MAS BURNED  THE REST OF  THE MONTH.
 7/75  A
       B
       SYSTEM
  .0
79.2
   .0
 79.4
  .0
73.5
                                                                             744    689
          PROBLEMS/SOLUTIONS/COMMENTS
                         CHICAGO FLY ASH IS TREATING THE SCRUBBER  HASTE  MATERIAL WITH  LIME  AND FLY
                         ASH AND DUMPING IT INTO THE ON SITE HOLDING BASIN. THE MATERIAL FROM THE
                         HOLDING BASIN IS BEING TRUCKED TO AN OFF  SITE DUMP.

                         MODULE B MAS OUT ONCE (30 MINUTES) TO REPAIR A  MINOR  STEAM HEADER  LEAK.

                         MODULE B MAS OUT ONCE DUE TO NO DEMAND.

                         LOU SULFUR COAL MAS BURNED MOST OF THIS MONT, WITH HIGH SULFUR  COAL BEING
                         BURNED DURING THE LAST MEEK OF THE MONTH.
 8/75  A
       B
       SYSTEM
  .0
93.5
   .0
100.0
  .0
76.4
                                                                             744    565
       *» PROBLEMS/SOLUTIONS/COMMENTS
                         IN JUNE,  MODULE A ENCOUNTERED PLUGGAGE  IN THE OEMISTER.  WHICH  REQUIRED ITS
                         REPLACEMENT.  THE WORK MAS COMPLETED IN  AUGUST.

                         MODULE A WENT OUT OF SERVICE ON JUNE 20 AND REMAINED OUT THROUGH AUGUST DUE
                         TO MASSIVE REHEATER LEAKS. THERE IS PRESENTLY A HOLD ON  THE  NEM REHEATER
                         ORDER BECAUSE OF MATERIAL FAILURES EXPERIENCED IN MODULE B'S CARBON STEEL
                         REHEATER.

                         MODULE B SUFFERED TWO OUTAGES IN JULY AND ONE IN AUGUST  BECAUSE OF REHEATER
                         TUBE LEAKS. THE FAILURES MERE DUE TO VIBRATION FATIGUE.  THE  REHEATER,  UHICH
                         MAS INSTALLED IN MAY, HAS LOST SIX OF ITS TMELVE TUBE  BUNDLES  SO FAR.  THE
                         LENGTH OF TIME THAT THE TUBES HAVE LASTED MOULD SEEM TO  INDICATE THAT  TKE5E
                         IS A DIESIGN RELATED MATERIAL DEFICIENCY. THREE OF THE TUBE  BUNDLES MERE
                                 REPLACED MITH MARGINAL BUNDLES  LEFT OVER FROM  MODULE A.

                         A SMALL STEAM HEADER LEAK CAUSED ONE MODULE B OUTAGE.

                         MODULE B MAS OUT FOUR TIMES FOR NO DEMAND AND ONCE FOR A LOW FLOW TRIP.

                         HIGH SULFUR COAL MAS BURNED ALL MONTH,  CAUSING AN INCREASE IN  SLUDGE
                         PRODUCTION UHICH HAS FORCED A MINIMUM SIX DAY A WEEK,  TEN HOL'R A DAY
                         SLUDGE DISPOSAL OPERATION. THE SLUDGE IS BEING TREATED HITH  LIME AMD
                         FLY ASH AND BEING DUMPED INTO THE ON SITE HOLDING POND.  STABILIZED
                         MATERIAL IS BEING TRUCKED FROM THE POND TO AN OFF SITE DISPOSAL AREA.
 9/7S  A
       B
       SYSTEM

10/75  A
       B
       SYSTEM
  .0
32.3
   .0
100.0
  .0
26.6
                                                          720
                                                                            744    194
                                               884

-------
                                              EPA UTILITY F60 SURVEY: OCTOBER  - DECEMBER  1991
COMMONWEALTH EDISON:  MILL COUNTY  1  (COOT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY  UTILIZATION   X  REMOVAL    PER   BOILER   FED    CAP.
                                                                S02   PART.  HOURS  HOLKS   HO'J'S  FACTC3
       *» PROBLEMS/SOLUTIONS/COMMENTS
                         MODULE  A MAS OFF  THE  ENTIRE  11  DAYS  THE  BOILER  OPERATED  THIS  MONTH,  WAITING
                         FOR  ITS NEW REHEATER,  WHICH  HAS NOW  BEEN RELEASED  FOR  MANUFACTURING  3Y
                         5MED.

                         MODULE  B HAD TWO  OUTAGES.  ONE FOR  NO DEMAND  AND ONE  MINOR  IS  MINUTE  TRIP.

                         HIGH SULFUR COAL  MAS  BURNED  THIS MONTH WHEN  THE SCRUBBER WAS  IN SERVICE.

                         THE  SLUDGE IS BEING TREATED  WITH LIME AND FLY ASH  AND  HAULED  TO AN OFF  SITE
                         DISPOSAL AREA.
11/75  A
       B
       SYSTEM

12/75  A
       B
       SYSTEM

 1/76  A
       B
       SYSTEM

 8/76  A
       B
       SYSTEM

 3/76  A
       B
       SYSTEM
  .0
  .0
30.1
 a.a
45.2
20.4
                          .0
                          .0
18.3
 8.5
                                                          720
                                                          744
                                                          744
                                                          696
                                                                             744   309
          PROBLEMS/SOLUTIONS/COMMENTS
                         UNIT 1 MAS DOWN FROM OCTOBER 11 THROUGH MARCH 19 FOR ITS BOILER TURBINE
                         AND SCRUBBER OVERHAUL. THE MAJOR ITEMS TO BE ACCOMPLISHED DURING THE
                         OUTAGE MERE:
                              1. SIMPLIFICATION OF THE MILLING SYSTEM CONTROL.
                              2. PULLING AND CLEANING OF THE MODULE B REHEATER AND RETURNING IT
                                 REPLACED WITH MARGINAL BUNDLES LEFT OVER FROM MODULE A.
                              3. CLEANING OF THE POND PUMP BAY.
                              4. REMOVAL OF THE VENTURI AND ABSORBER PUMP CHECK VALVES (ONE OF THEM
                                 FAILED LAST SPRING AND DESTROYED A PUMP LINER AND IMPELLER).
                              5. CLEANING AND REPAIR OF THE VENTURI NOZZLES AHD SUPPORTS.
                              6. REPAIR OF CORRODED REHEATER SUPPORTS.
                              7. RESETTING AND ADJUSTMENT OF ALL DAMPERS.
                              8. REVISION OF SCRUBBER CONTROLS BY REMOVING THE CONTROLS NO LONGER
                                 USED OR NEEDED.
                              9. INSPECTION AND CLEANING OF THE ENTIRE SCRUBBER AND RELATED
                                 EQUIPMENT.

                         MODULE A MAS PUT INTO THE GAS PATH ON MARCH 22 AND REMAINED AVAILABLE F09
                         SERVICE THE REST OF THE MONTH.

                         MODULE B HAD TO REMAIN OUT OF SERVICE UNTIL MARCH 29 WHILE ITS REPAIRED
                         REHEATER MAS INSTALLED.
 4/76  A
       8
       SYSTEM
                   23.0
            20.0
            49.3
                        19.2
                        47.3
                                                                             720   691
                                               885

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981

COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
	PERFORMANCE  DATA	
PERICD MODULI: AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X REMOVAL    PER  BOILER   FGD    CAP.
                                                                S02   PART. HOURS HOUPS   HOURS FACTOR


       ** PR03LEMS/SOLUTIOMS/COMMENTS

                         UNIT 1 RETURNED TO SERVICE APRIL Z  AFTER A  SHORT TURBINE  CONTROL OUTAGE.
                         BOTH MODULES CAME ON LINE  JUST BEFORE  THE BOILER.

                         A FIVE DAY OUTAGE OF MODULE B MAS DUE  TO REHEATER TUBE BUNDLE LEAKS.

                         SEVEPAL MODULE B OUTAGES MERE DUE TO PLUGGED ABSORBER TANK  SCREENS CAUSED
                         BY MILL AND CLASSIFIER FAILURES WHICH  ALLOWED ROCK  TO GET INTO  THE SYSTEM.
                         MODULE B MAS THOROUGHLY CLEANED.

                         ONLY ONE ABSORBER PUMP IS  BEING USED IN MODULE B, SINCE THE 182 PUMP LINER
                         FAILED AS A RESULT OF A BROKEN DISCHARGE VALVE. A REPLACEMENT LIt.'EH  IS
                         BEING INSTALLED.

                         A SCRUBBER TESTING AND EVALUATING PROGRAM UAS STARTED THIS  MONTH.  MUCH OF
                         THE LATTER TWO WEEKS OF THE MONTH WERE SPENT TRAINING THE TESTING PERSON-
                         NEL. THE PROGRAM WILL PROVIDE CHEMISTRY DATA AND OPERATING  CHARACTERISTICS.

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

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         A VENTRUI HOSE LEAK FORCED MODULE B OFF ONCE THIS MONTH.

                         MODULE B MAS TAKEN OUT OF  SERVICE ONCE BECAUSE OF A PLUGGED ABSORBER TANK
                         SCREEN.

                         MODULE B MAS OFF ONCE DUE  TO  A FOULED  I.D.  FAN.

                         MODULE B WAS OUT OF THE GAS PATH ONCE  DUE TO NO DEMAND.

 6/76  A           52.0        44.Z                    37.6
       B           86.2        84.5                    71.9
       SYSTEM                                                                720   612

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         MODULE A SUFFERED VENTURI  PUMP LINER FAILURES ON APRIL 78 WHEN  AH INLET 16
                         INCH BUTTERFLY ISOLATION VALVE BROKE APART  AND FELL INTO  THE VENTUSI PUMP.
                         BOTH THE A AND BACKUP AB VENTURI PUMP  LINERS WERE DESTROYED. MODULE  A
                         REMAINED OUT SERVICE UNITL JUNE 9,  WHEN THE LINERS  WERE REPLACED.

                         MODULE A WAS OFF ONCE FOR  SHEARED BYPASS DAMPER PINS.

                         I.D. BOOSTER FAN FOULING FORCED MODULE A OFF ONCE THIS MONTH FOR ABOUT
                         164 HOURS.

                         BOTH MODULES MERE OFF TWICE DUE TO  NO  DEMAND. DURING THESE  OUTAGES,  THE
                         OEMISTERS WERE MASHED AND  ABSORBER  TRAY SCALE, IP ANY, WAS  KNOCKED OFF.

                         MODULE B MAS OUT OF THE GAS PATH FOR SEVERAL SHORT  VENTURI  LOW  FLOW  TRIP
                         OUTAGES DUE TO A PLUGGED,  SCALED VENTURI TANK SCREEN. AT  THE END OF  THE
                         MONTH. THE MODULE WAS TAKEN OUT TO  CLEAN THE SCREEN.

                         THE MODULE B I.D. BOOSTER  FAN REQUIRED CLEANING DURING THE  MONTH.

                         THE REHEATER TUBES ARE SCALING, WHICH  RESULTS IN A  LOWER  HEAT TRANSFER RATE
                         RATE, AND THEREFORE INCREASES 1.0.  BOOSTER  FAN FOULINS. THE ONLY WAY TO
                         CLEAN THE REHEATERS EFFECTIVELY IS  TO  REMOVE THEM,  WHICH  DEMANDS A SUBSTAN-
                         TIAL OUTAGE.
                                               886

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1931

COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
	PERFORMANCE DATA			
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART.  HCU
-------
 EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981

COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X  REMOVAL    PER  BOILER   FGD    CAP.
                                                                S02   PART. HOURS HCU3S  HOUSS  FtCTCR

       B           76.4        56.2                    54.8
       SYSTEM                                                                744    726

       *» FPCBLEMS/SOLUTIONS/COMIENTS

                         HIGH SULFUR ILLINOIS COAL MAS BURNED  IN THE  BOILER  FROM MARCH THROUGH
                         OCTOBER.

                         THE SCRU3BER MASTE MATERIAL MAS TREATED WITH LIME AND FLY  ASH AND  HAULED  TO
                         AN OFF SITE DISPOSAL AREA.

                         MODULE A  OPERATED ON ONE ABSORBER  PUMP, ALLOWING TESTING ON  A LOWER
                         ABSORBER  FAN.

                         MODULE A  MAS OUT OF THE GAS PATH ONCE FOR AN I.D. BOSOOSTER  FAN  TRIP.

                         WORK ON RECIRCULATION TANK LEVEL CONTROLS CAUSED A  MODULE  A  OUTAGE.

                         MODULE B  MAS FORCED OFF ONCE  TO REPAIR A  REHEATER HEADER LEAK.

                         ONE MODULE B OUTAGE MAS FOR VENTURI NOZZLE CLEANING.

                         MODULE B  WENT OFF FOR A VENTURI LOW FLOM  TRIP.

                         MODULE B  REMAINED OUT OF SERVICE WHILE MODULE A MAS BEING  TESTED TO AVOID
                         THICKENER-POND OVERLOADING.

                         A VACUUM  FILTER HAS TIED IN AT THE THICKENER.

11/76  A           20.1        25.6                    20.1
       B           72.2        69.6                     4.7
       SYSTEM                                                                720    566

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         MODULE A  OPERATED ON ONE ABSORBER  PUMP DURING MODULE B OUTAGE.

                         MODULE B  MAS FORCED OUT OF THE GAS PATH ONCE FOR A  MILLING SYSTEM  FAILURE.

                         MODULE B  ENCOUNTERED A VENTURI HEADER LEAK.

                         THE VENTURI NOZZLES REQUIRED  CLEANING DURING THE MONTH.

                         REPLACEMENT OF THE SPENT SLURRY VALVE NECESSITATED  A MODULE  OUTAGE.

                         MODULE B  MAS OFF ONCE DUE TO  A CHEMICAL SYSTEM UPSET.

                         MODULE B  HAS OUT OF THE GAS PATH THICE DUE TO NO DEMAND  (MODULE  A  MAS NOT
                         IN SERVICE AT THE TIME OF THE OUTAGE).

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

       *» PROBLEMS/SOLUTIONS/CCMMENTS

                         DURING THE LAST MEEK OF NOVEMBER,  THE 1A2 ABSORBER  PUMP MAS  TAKEN  OUT OF
                         SERVICE FOR OVERHAUL. THE REPAIRS  HERE COMPLETED ON DECEMBER 6.  WHEN  THE
                         MODULE ASSUMED A ONE ABSORBER PUMP STANDBY CAPABILITY UNTIL  THE  1A1 ABSOR-
                         BER PUMP  CAN BE REPAIRED.

                         DURING THE LAST HALF OF THE MONTH, MODUELE A OPERATED WHILE  MODULE B  HAS
                         BEING REPAIRED.
                                               688

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931

COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.J
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD   CiP.
                                                                S02  PART.  HOUPS HOURS  KOU°S FACTOR

                         MODULE B PERFORMED SATISFACTIORILY DURING THE FIRST HALF OF THE KCNTH.
                         EXPERIENCING ONLY ONE NO DEMAND OUTAGE. OH THE 17TH, HOWEVER, THE SPENT
                         SLURRY VALVE FAILED AND THE MODULE HAS REMAINED OUT OF SERVICE.

 1/77  A           98.2        98.7                    95.8
       B           13.5         1.1                     1.1
       SYSTEM                                                                744   722

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         THE 1A1 ABSORBER PUMP WENT OUT IN LATE SEPTEMBER WITH BURNED OUT BEARINGS
                         AND REMAINED OUT THROUGH JANUARY WAITING FOR PARTS.

                         LOM SULFUR COAL WAS BURNED IN THE BOILER FROM NOVEMBER THROUGH JANUARY.

                         DUE TO THE LOU VOLUME OF SLUDGE PRODUCED WHILE BURNING LOW SULFUR COAL,
                         MUCH OF THE SLUDGE HANDLING TIME MAS SPENT DIGGING OUT THE ACCUMULATED
                         SLUDGE IN THE RECIRCULATION PONDS. THIS MATERIAL,  ALONG WITH SCRU2BER
                         WASTE MATERIAL, WAS TREATED WITH LIME AND FLYASH AND HAULED TO AN OFF
                         SITE DISPOSAL AREA.

                         MODULE A MAS FORCED OUT ONCE BY A FAILED SPENT SLURRY VALVE.

                         PLUGGED OEMISTER UNDERSPRAYS CAUSED ANOTHER MODULE A OUTAGE.

                         MODULE A WENT OUT ONCE BECAUSE OF NO DEMAND AND ONCE DUE TO A BOILER OUTAGE
                         (MODULE B MAS ALREADY OUT OF SERVICE FOR REPAIRS).

                         MODULE B BECAME AVAILABLE FOR SERVICE ON JANUARY 27, AFTER REPAIRS TO THE
                         SPENT SLURRY VALVE WERE COMPLETED. DUE TO SEVERE WEATHER CONDITIONS, THE
                         MODULE MAS PLACED IN THE GAS PATH JANUARY 31.

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

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         THERE MAS VERY LITTLE DIGGING IN THE RECIRCULATION PONDS. CHICAGO FLYASH
                         SPENT MOST OF THEIR TIME ON CLEANING AND MAINTENANCE.

 3/77  A           96.9        66.7                    64.2
       B           80.9        75.5                    73.9
       SYSTEM                                                                744   728

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         AN ERT S02 ANALYZER MAS INSTALLED ON THE DISCHARGE SIDE OF MODULE B 1.0.
                         BOOSTER FAN. THIS IS AN "IN SITU" ON-DISPERSIVE ANALYZER THAT CONTINUALLY
                         MEASURES AND READS OUT CONCENTRATIONS OF S02, CO.  C02. AND NO.

                         AN ABSORBER SUCTION HEADER LEAK FORCED MODULE B FROM THE GAS PATH.

                         MODULE B WAS FORCED OUT DUE TO A SLURRY VALVE GASKET LEAK.

                         A PLUGGED FEED SLURRY RECIRCULATION LINE MAS ENCOUNTERED IN MODULE B.

                         HIGH SULFUR COAL MAS BURNED FOR SEVEN DAYS THIS MONTH TO PROVIDE HIGH
                         SULFUR SLUDGE FOR THE UOP SLUDGE TEST.

                         CHICAGO FLYASH SPENT 75X OF THEIR TIME DIGGING IN THE POND. THE REST MAS
                         SPENT ON THE THICKENER AND VACUUM FILTER IPERATION. THE SCRUBBER WASTE
                         MATERIAL MAS TREATED WITH LIME FLYASH AND HAULED OFF SITE.
                         DISPOSAL AREA.
                                               889

-------
 EPA UTILITY FGD SURVEY:  OCTC3ER  -  DECEMBER  1981

COMMONWEALTH EDISON:  WILL COUNTY  1  (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPESABILITY RELIABILITY UTILIZATION
                                                                X REMOVAL
                                                                502  PART.
                                                         PER   BOILER  FGO   CAP.
                                                       HOU3S  HOURS  HO'JSS FACTOR
 4/77  A
       B
       SYSTEM
86.1
45.5
67.7
30.2
61.2
27.3
                                                                            720   650
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         THE PERFORMANCE OF  THE  ERT S02 ANALYZER TO DATE HAS BEEN. AT BEST, UNRELIA-
                         BLE AND  INCONSISTENT. THE ERT TECHNICIANS ARE CUT TO SERVICE THE  ANALYZER
                         ALMOST EVERY OTHER  DAY.  THE  PROBLEM, ACCOPDING TO ERT TECHNICIANS, IS  Or A
                         "THERMAL NATURE". WHEN  THE ANALYZER REACHES A CERTAIN TEMPERATURE, A CHIP
                         SHORTS OUT. THEY HAVE NOT BEEN ABLE TO LOCATE THE FAULTY INTEGRATED CIRCUIT
                         YET.

                         A BOILER TUBE  LEAK  REPAIR FORCED MODULE A OUT OF THE GAS PATH ONCE THIS
                         MONTH (MODULE  B WAS ALREADY  DOWN FOR REPAIRS).

                         MODULE B MAS FORCED OUT OF THE 6AS PATH TWICE FOR AN ABSORBER SUCTION
                         HEADER LEAK REPAIR.

                         MODULE B HAS OUT OF SERVICE  ONCE TO MASH THE I. 0. BOOSTER FAN.

                         CHICAGO  ADMIXTURES  SPENT MOST OF THEIR TIME DIGGING IN THE SMALL  POND,
                         GETTING  READY  FOR THE MGO ADDITION AND FORCED OXIDATION TEST. THE SCRUS3ER
                         WASTE MATERIAL MAS  TREATED WITH LIME AND FLYASH AND HAULED TO AN  CFF SITE
                         DISPOSAL AREA.
 5/77  A
       B
       SYSTEM
89.4
98.0
 2.2
50.9
 2.0
47.3
                                                                            744   691
          PROBLEMS/SOLUTIONS/COMMENTS
                         THE ERT SOS  ANALYZER  HAS  BEEN REMOVED  FROM SERVICE DUE TO A  POOR  FERFCPM-
                         ANCE RECORD  OVER  THE  LAST THREE MONTHS.  ERT IS IN THE PROCESS OF  RE-
                         ENGINEERING  THEIR ANALYZER.

                         THE MGO ADDITION  TEST MENT HELL.  ALTHOUGH THE MGO INCREASED  S02 PEKCVAL
                         EFFICIENCY ABOUT  10X, IT  DID  PRACTICALLY NOTHING FOR THE TWO MORE SiRIGUS
                         PROBLEMS,  SINCE THICKENER AND SLUDGE PRODUCTION AND LIMESTONE CONSUMPTION
                         RATE HERE  ABOUT THE SAME.

                         MODULE  A MAS FORCED OUT OF THE GAS  PATH  ONCE THIS MONTH WHEN THE  INLET
                         VALVE ON 1AZ ABSORBER PUMP FAILED.

                         MODULE  B HAS TAKEN OFF TO CLEAN AND INSPECT THE REHEATER TUBES.

                         BOTH MODULES WERE FORCED  OFF  FOR  THE FIRST FIFTEEN DAYS OF THE MONTH  DUE  TO
                         A FAILED 120V CONTROL TRANSFORMER FOR  THE POND RETURN PUMPS. THE  TRANSFORM-
                         ER HAD  TO  BE ORDERED  FROM HESTINGHOUSE.

                         HIGH SULFUR  COAL  HAS  BURNED FOR ELEVEN DAYS DURING THE MONTH.
 6/77  A
       B
       SYSTEM
31.8
93.2
13.3
93.4
10.5
73.5
                                                                            720   566
       tH* PROBLEMS/SOLUTIONS/COMMENTS
                         THE 1A1  ABSORBER  PUMP IS  STILL OUT OF SERVICE WAITING FOR PARTS  1A3
                         ABSORBER PUMP'S ISOLATION VALVES  FORCED MODULE A OFF FOR MOST OF TIE MONTH.

                         MODULE A HAD ONE  NO DEMAND AND ONE BOILER OUTAGE THIS MONTH.
                                               890

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
COMMONWEALTH EDISON: HILL COUNTY 1 (CONT.)
------------------------------------------ PERFORMANCE DATA ------------------------------------------
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART. HCLPS HC'JSS  HC'.?S FACTCR

                         MODULE B MAS ALSO FORCED OFF TO CLEAN THE 1.0. BOOSTER FAN.

                         NO HIGH SULFUR COAL MAS BURNED THIS MONTH.

                   70.3        41.4                    31.0
 7/77
       B
       SYSTEM
                                                                             744   377
          PROSLEMS/SOLUTIONS/COMMENTS
                         HIGH SULFUR COAL HAS BURNED FOR EIGHT DAYS THIS MONTH. LIMESTONE OPERATION
                         HAS NORMAL FOR HIGH SULFUR OPERATION.

                         MODULE B MAS FORCED OUT OF THE GAS PATH ONCE TO REMOVE A PLU33EO DIFFUSES.
                         THE FINAL TEST, FORCED OXIDATION SEEMOD TO BE THE MOST SUCCESSFUL C' ALL.
                         USING LIQUID OXYGEN, UP TO 12,000 CFM OF GASEOUS 02 HAS FED INTO EACH
                         VENTURI DOHNCOMER, OXIDATION OF SULFITE TO SULFATE MAS INCREASED FROM
                         35 TO 90 '/.

                         MODULE B MAS ALSO FORCED OFF DUE TO A LOM LEVEL IN THE SLURRY STORAGE TANK.

                         MODULE B HAS ALSO FORCED OFF DUE TO REHEATER TUBE BUNDLE LEAKS.
 fl/77
       A
       B
       SYSTEM
            99.8
             9.7
99.6
12.0
            BO.3
             9.7
                                                                             744   604
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         MODULE A MAS AVAILABLE THE ENTIRE MONTH WITH JUST THE VENTURI PUMP OPERAT-
                         ING.
 9/77
       A           61.0
       B           52.3
       SYSTEM
                        77.B
                        75.4
                        54.0
                        52.3
                                                                             rzo   499
       *« PROBLEMS/SOLUTIONS/COMMENTS
                         MODULE B ENCOUNTERED HIGH VIBERATIOJ4S IN ITS BOOSTER FAN DURING THE FIRST
                         MEEK OF THE MONTH. AFTER THE FAN MAS BALANCED, THE MODULE OPERATED INTIL
                         THE UNIT OUTAGE ON SEPTEMBER 21.
10/77
11/77
A
B
SYSTEM

A
B
SYSTEM
                     .0
                     .0
                     .0
                    8.8
                               50.1
                          .0
                          .0
                          .0
                         8.8
                                                                             744
                                                                             720   126

       M* PROBLEMS/SOLUTIONS/COMMENTS

                         UNIT ONE CAME UP ON NOVEMBER 25 AFTER A SIXTY-THREE DAY OUTAGE.

                         MODULE B IS IN THE GAS PATH FATER EXPERIENCING SCME DIFICULTY IN BALANCES
                         ITS BOOSTER FAN.
12/77
       A
       B
       SYSTEM
            42.5
            84.1
42.5
64.1
47.8
94.6
42.5
84.1
                                                                             744   661
                                               891

-------
 EPA UTILITY FGO SURVEY:  OCTOBER -  DECEMBER 1981

COMMONWEALTH EDISON:  WILL COUNTY 1  ICONT.J
	PERFORMANCE  DATA	
PERIOD M03ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL    PER  BOILE3   FGD    CAP.
                                                               S02  PART. HOURS HOURS  HOUSS  FACTOR


       *» PROBLEMS/SOLUTIONS/COKMENTS

                         PLUGSAGE MAS ENCOUNTERED IN THE MODULE B REHEATER.  BECAUSE  NO SPARE  REHEAT
                         COILS WERE AVAILABLE.  THE UTILITY  TRIED TAKING SOME COILS  FROM M03LJLE A
                         MODULE B APPEARED  TO BE MORE  ORE SEVERELY PLUGGED THAN ORIGINALLY  THOUGHT.

                         MODULE A MAS OOHN  HALF THE  MONTH BECAUSE OF A MAIN  STEAM LEAK WHICH COULD
                         NOT BE ISOLATED.

                         MODULE A OPERATED  UNTIL SEPTEMBER  19, WH E A COMBINATION OF  MUD  AND SCALE
                         BUILD-UP ON THE SUMP FLOOR  STRUCTURALLY DAMAGED THE MODULE.  REPAIRS PUT
                         THE MODULE OUT OF  SERVICE UNTIL MID  DECEMBER.

 1/78  A           69.0        89.9                    66.3
       B           22.0        29.8                    22.0
       SYSTEM                                                               744    549

       ** PRCBLEMS/SOLUTIONS/COMMENTS

                         ON JANUARY 7, THE  MODULE B  I.D. BOOSTER FAN DISCHARGE DUCT STARTED VIBRAT-
                         ING MILDLY. THIS FORCED THE BOILER OFF WHILE THE SHOP MADE REPAIRS TO THE
                         DUCTWORK AND BALANCED  THE FAN WITH AN I.R.O. MACHINE.

                         WHEN THE UTILITY ATTEMPTED  TO PUT  MODULE B BACK IN  THE GAS PATH, A LEAK  IN
                         THE SLUSHY LINE FORCED IT BACK OFF.

                         A PLUGGED VENTURI  PUMP FORCED MODULE B OFF THE REST OF THE MONTH.

                         DURING THE OUTAGE, THE REHEATER COILS MERE CLEANED  WITH A  HIGH  PRESSURE
                         (5000 LB) SPRAYER.

                         MODULE A MAS FORCED OFF WHEN  A STEAM REGULATING VALVE BLEU ITS  PACKING.

                         OM THE 23RD, BOTH  MODULES WERE TAKEN OFF AND DRAINED TO ALLOW THE  SHOP TO
                         INSTALL NEW ISOLATION  VALVES  IN THE  ABSORBER AND VENTURI PUMPS.

                         TOWARD THE END OF  THE  MONTH,  SOME  PROBLEMS WERE ENCOUNTERED  UITH THE  POND
                         RETURN PUMPS FREEZING.

 2/78  A           40.9        56.5                    34.4
       B           69.5        92.9                    56.5
       SYSTEM                                                               672    409

       «« PROBLEMS/SOLUTIONS/COMMENTS

                         MODULE A RAN INTO  DIFFICULT OPERATIONG CONDITIONS THIS MONTH DUE'TO RAPID
                         PLUGGING OF THE REHEAT COILS.

                         INSPECTION AND SUBSEQUENT CLEANING OF MODULE A UNCOVERED PLUGGED SPRAY
                         NOZZLES AND DEMISTER TRAYS  DUE TO  NOZZLE INEFFICIENCY.

                         MODULE B OPERATED  VERY HELL AND AN INSPECTION SHOWED THE MODULE  TO BE VERY
                         CLEAN.

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

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THIS MONTH, DUE TO COAL CONSERVATION, UNIT 1 MAS ON THE SYSTEM  VERY  LITTLE.

                         MODULE B HAD DIFFICULTY FOR SEVERAL DAYS BECAUSE OF A CRACKED SHEAVE  CM  THE
                                               892

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER  - DECEMBER 1981
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                                X REMOVAL
                                                                S02  PART.
                                                          PER   BOILER   FSD    CAP.
                                                         HOURS  HOU=S  HOL'=S FACTOR
                         VENTUHI PUMP.

                         HIGH PRESSURE  CLEANING ON BOTH MODULES DURING THE COAL CONSERVATION ALONG
                         WITH REMOVING  THE VENTURI THROAT RESTRICTOR BLOCKS PROVED  BENEFICIAL IN
                         MAINTAINING BETTER CONTROL OF THE DRAFT CONDITIONS IN THE  SCRUESER.
 4/78
       A
       B
       SYSTEM
 99.9
100.0
 99.7
 99.9
                                                       92.0
                                                                             720   665
       «* PROBLEMS/SOLUTIONS/COMMENTS
                         THE PRESSURE DIFFERENTIAL ACROSS THE VENTURIS HAS BEEN REDUCED BY AP«CXI-
                         MATELY 40X AT 140 MM BY REMOVING THE VENTURI RESTRICTOR BLOCKS. PASTiCULATE
                         REMOVAL AND SOLIDS CARRYOVER COULD BE ADVERSELY AFFECTED BY THIS ACTION.
                         SINCE PARTICULATE REMOVAL AT THE VENTURI IS A FUNCTION OF KATES DROPLET
                         SIZE. WHICH IN TURN IS A FUNCTION OF PRESSURE DROP.  INCREASED SOLIDS CARRY-
                         OVER COULD POSSIBLY COMPUNO REHEATER PLUGGING PROBLEMS. THE UTILITY IS
                         KEEPING A CLOSE MATCH FOR PLUGGING, BUT HAS NOT YET  FOUND ANYTHING UNUSUAL.

                         MODULE A MAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH FOR A VENTURI PIPE
                         LEAK.
 5/78
       A
       B
       SYSTEM
  9.5
 69.a
 99.4
100.0
55.2
56.1
                                                                             744   413
       »* PROBLEMS/SOLUTIONS/COMMENTS
                         DURING THE LAST PART OF THE MONTH BOTH MODULES WERE FORCED OUT CF THE GAS
                         PATH DUE TO REHEATER LEAKS. IT REQUIRED A TWO DAY OUTAGE TO PEMOVE THE
                         LEAKING REHEATER BUNDLES. ADDITIONAL REHATERS ARE ON ORDER AND ARE EXPECT-
                         ED TO ARRIVE IN JUNE.
 6/78
       A
       B
       SYSTEM
 87.1
 85.6
 94.5
100.0
23.7
25.1
                                                                             720   181
       *« PROBLEMS/SOLUTIONS/COMMENTS
                         DURING A SCRUBBER INSPECTION, 25X DIEMISTER AND 75X ABSORBER SPRAY PLUG3AGE
                         MAS DISCOVERED IN MODULE A. MODULE B MAS NOT AS BAD.

                         HIGH VIBRATION HAS ENCOUNTERED IN THE TURBINE BEARINGS DURING BOILER START
                         UP, CAUSING THE BOILER TO SHUT BACK DOWN.

                         THE PUG MILL FOR CHICAGO ADMIXTURES HAS BEEN APPROVED. AND THE NEM SLL-DGE
                         TREATMENT SYSTEM SHOULD BE OPERATING BY FALL.

                         THE SCRUBBER MAS FORCED OUT OF THE GAS PATH CNCE THIS MONTH WHEN THE 1B1
                         ABSORBER DISCHARGE VALVE FAILED TO OPEN.

                         THE BOILER MAS FORCED OFF THE LAST FOUR DAYS OF THE MONTH FOR CYCLONE
                         LEAKS. DURING THIS OUTAGE. THE A AND B MODULE SPENT SLURRY VAL/ES
                         MERE REPLACED.
 7/78  A
       B
       SYSTEM
 97.0
 99.2
100.0
100.0
11.6
11.6
                                                                             744
                                                                                    77
                                               893

-------
 EPA UTILITY FGO SURVEY:  OCTOBER -  DECEMBER  1981

CCMHOIWEALTH EOISCN:  WILL COUNTY I  (CCMT.)
	PERFORMANCE DATA	
PERIOO MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  7.  REMOVAL   PER  BOILER   FGO   CAP.
                                                               S02  PART. HOURS HOURS  HCU3S  FACTOR


       «* PROBLEMS/SOLUTIONS/CCMMENTS

                         THE BOILER WAS PLAGUED  ALL MONTH BY CYCLONE CASING LEAKS. BECAUSE OF  THE
                         CYCLONE PROBLEMS AND THE COAL  CONSERVATION PROGRAM, THE BOILER HAS ONLY
                         OPERATED SEVENTY-SEVEN  HOURS FCR THE MONTH.

                         THE BOILER DOWN TIME MAS USED  FOR  PREVENTATIVE MAINTENAtCE ON THE SCRU3BER.
                         SIX NEW REHEATEfiS  WERE  INSTALLED AND A DRAIN VALVE ON THE SPENT  SLURRY LINE
                         UAS REPAIRED.

                         A VALVE FAILURE ON THE  1A1 ABSORBER PUMP  FORCED THE SCRUBBER FROM THE GAS
                         PATH CMCE DURING THE MOUTH.
                         MODULE B EXPERIENCED A LEAKING VENTURI  HEADER.
 8/78  A
       B
       SYSTEM
97.8
99.6
100.0
100.0
59.1
59.1
                                                          744    440
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME OPERATING OUT OF  THE  THICKENER.
                         THE SCRUBBER HASTE MATERIAL MAS TREATED WITH  LINE  AND FLY ASH AMD HAULED
                         OFF TO AN OFF SITE DISPOSAL AREA.

                        •REPAIRS TO THE VENTURI EMERGENCY SPRAY VALVE  CAUSED  ONE  BOILER OUTAGE
                         DURING THE MONTH.

                         A REHEATER FLANGE  LEAK UAS RESPONSIBLE FOR FORCING THE UNIT OFF.

                         MODULE A MAS FORCED OFF ONCE DUE TO HIGH VIBRATION OF THE 1.0. BOOSTER FAN.
                         THE PROBLEM MAS CORRECTED BY REPACKING THE COUPLING  ON THE FAN.
 9/78
       A
       B
       SYSTEM
77.7
77.7
 95.9
 96.0
55.4
55.5
                                                          720   416
       «« PROBLEMS/SOLUTIONS/COMMENTS
                         CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME OPERATING OUT OF THE THICKENER.
                         THE SCRUBBER MASTE MATERIAL MAS TREATED WITH LIME AND FLY ASH AND HAULED TO
                         AN OFF SITE DISPOSAL AREA.

                         REHEATER TUBE LEAKS, ONE IN MODULE A AND FOUR IN MODULE B, CAUSED CHE
                         BOILER OUTAGE AND CAUSED THE FGO SYSTEM TO BE UNAVAILABLE FCP A TOTAL
                         OF NINETY HOURS. SAMPLES OF THE TUBES HAVE BEEN SUBMITTED TO O.A.O.  ?OR
                         METALLURGICAL EXAMINATION.

                         A RUPTURED AIR LINE ON A VENTURI PUMP ISOLATION VALVE MOULD NOT ALLOW THE E
                         VALVE TO GO COMPLETELY CLOSED.

                         MHEN THE A VENTURI PUMP UAS STARTED, A VENTURI SPRAY HOSE RUPTURED.

                         IT MAS DISCOVERED THAT THE MODULE A VENTURI TANK LEVEL PRESSURE SHITCH MAS
                         NOT MORKINS PROPERLY.

                         THE PUGMILL ORDERED FOR CHICAGO ADMIXTURES HAS ARRIVED OH SITE. Ill OCTOBER,
                         THEY MILL FINISH THE CONVERSION, WHICH HILL ALLOM THE MATERIAL SERVICE
                         MIXER TRUCKS TO BE ELIMINATED.

                         IN OCTOBER, THE THICKENER MILL HAVE TO BE BYPASSED WHILE THE UTILITY DOES
                         MAINTENANCE ON THE RAKE AND REPLACES SOME LEAKING VALVES.
                                               894

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER - OECEMSER 1981

COMMONWEALTH EDISON: HILL COUNTY 1 ICONT. I
	PERFORMANCE  DATA			
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER   FGO   CAP.
                                                                SOB  PART.  HCU3S HCL'HS  HCU'S FAC7C3


10/78  A          100.0       100.0                    35.0
       B          100.0       100.0                    35.0
       SYSTEM                                                                744   CS1

       »* PR09LEMS/SOLUTIONS/CCMMENTS

                         LOW BOILER HOURS MERE DUE  TO  FOUR OUTAGES CAUSED BY HIGH 8EARIN3 METAL
                         TEMPERATURES AND EXCESSIVE VIBRATION IN THE 1-B FORCED DRAFT FAN.

                         THE BOILER DOWN TIHE MAS UTILIZED FOR CLEANING AMD REPAIR OF THE VENTUHI
                         THROAT, SUMP AND SUMP SCREENS, AND INLET BLOCK DAMPERS OF MODULE A, AS
                         HELL AS THE VENTURI AND ABSORBER TANKS AND SCREENS AND ALL ABSORBER SPRAY
                         NOZZLES OF BOTH MODULES.

                         ON INSPECTION, IT HAS DISCOVERED THAT THE B MCCULE ABSCRBER DEPARTMENTAL
                         DAMPER HAD SLIPPED SOX CLOSED. THE DAMPERS MERE JACKED OPEN AND MELDED
                         IN PLACE.

                         TO CORRECT A HIGH PRESSURE DROP ACROSS THE MODULE B REHEATER, A NEH METHC3
                         HAS EMPLOYED WHEREBY ONLY  THE MIDDLE TUBES HERE REMOVED, ALLOWING THE TOP
                         AND BOTTOM TUBES TO BE SEEN AND CLEANED, ELIMINATING THE REMOVAL OF ALL THE
                         TUBES. THIS PROCEDURE CUT  OUTAGE TIME FROM ONE GR TWO HEEKS TO TWO DAYS.

11/78  A           96.2       100.0                    48.3
       B           65.2       100.0                    48.3
       SYSTEM                                                                720   348

       «« PROBLEMS/SOLUTIONS/COMMENTS

                         THE UNIT HAS DOWN THREE TIMES THIS MONTH DUE TO A VENTURI PUMP AND TWO
                         BOOSTER FAN OUTAGES.'

12/78  A           65.3       100.0                    64.5
       B           64.5       100.0                    64.5
       SYSTEM                                                                744   480

       *« PROBLEMS/SOLUTIONS/COHMENTS

                         REHEATER TUBE LEAKS CAUSED TWO OUTAGES.

                         THE MODULE B SPENT SLURRY  DRAIN HAS REPAIRED.

 1/79  A           83.5       100.0                    61.3
       B           62.2        87.1                    53.4
       SYSTEM                                                                744   456

       *» PHOBLEMS/SOLUTIONS/COKMENTS

                         THE S02 PLANT HAS FORCED OFF  TWICE THIS MONTH DUE TO REHEATER TUBE LEAKS.
                         TWO TUBES ON MODULE A AND  FOUR TUBES ON MODULE B MERE REPLACED.

                         THE I.D. BOOSTER FAN ON MODULE B MAS FOULED AND HAD TO BE REPLACED.

                         TWO SPECIAL SECTIONS OF VENTURI PIPING, A SIXTEEN TO EIGHT IS'CH ECCENTRIC
                         REDUCER AND AN OFFSET TEE  HERE PREPARED BY LOCKFCRT FABRICATING AND INSTAL-
                         LED THIS MONTH. THE ORIGINAL  REDUCER AND TEE HAD BEEN PATCHED AND WELCEO SO
                         MANY TIMES THAT THEY HERE  BEYOND REPAIR.

 2/79  A           93.0        91.3                    54.2
       B           93.0        91.3                    54.2
       SYSTEM                                                                672   399
                                               895

-------
 EPA UTILITY FGD SURVEY:  OCTOBER -  DECEMBER  1981

COMMON-WEALTH EDISCN:  MILL COUNTY 1  (CONT. I
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  '/. REMOVAL   PEP  BOILE3   FGO    CAP.
                                                                S02  PART. HOURS HOURS  HOURS  FACTOR


       •« PRC8LEMS/SOLUTIONS/CCMMENTS

                         THE UNIT MAS FGRCED  OFF ONCE FOR A  MAIN STEAM HEADER  LEAK.

 3/79  A          100.0       100.0                    46.0
       B           68.6       100.0                    46.0
       SYSTEM                                                               744   343

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         THE SYSTEM WAS FORCED  OUT TWICE IN  FEBRUARY AND FOUR  TIMES IN MARCH DUE    E
                         TO A VENTURI HEADER  LEAK. A TEN FOOT  SECTION OF PIPE  MILL HAVE TO  BE
                         REPLACED DUE TO EXTENSIVE CORROSION.

                         THE SYSTEM MAS DOWN  ONCE FOR A SPRAY  HEADER LEAK.

                         MODULE B EXPERIENCED A LEAK IN THE  VENTURI DOUNCOMER. A FIVE FOOT  SECTION
                         OF THE PIPE MILL HAVE  TO BE REPLACED.

 4/79  A
       SYSTEM                                                               720

 5/79  A                                                 .0
       B                                                 .0
       SYSTEM                                                               744     0

       «« PROBLEMS/SOLUTIOHS/COMHENTS

                         UNIT 1 HAS OUT OP  SERVICE THE ENTIRE  MONTH DUE TO A BOILER OVERHAUL.

                         CHICAGO ADMIXTURES MILL STOCKPILE THE FIXED SLUDGE ON STATION PHOPEPTY.

 6/79  SYSTEM                                                               720     0

 7/79  SYSTEM                                                               744     0

 8/79  SYSTEM                                                               744     0

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         UNIT 1 MAS OUT OF  SERVICE TO REPLACE  THE AIR HEATER TUBES. TUBE  SHEET AND
                         HOPPERS.  DURING THIS  OUTAGE. THE MORN VENTURI SFPAY  NOZZLES AMD OEMISTERS
                         MERE REPLACED.  MELDING LEAKS AND GENERAL CLEANING OF THE S02 INTERNALS
                         MAS ALSO DONE AT THIS  TIME.

                         THE BOILER AND THE SCRUBBER ARE SCHEDULED TO RETURN TO SERVICE OCTOBER 1,
                         1979.

                                                                            720     0

                                                                            744     0

                                                       £5.4
                                                       85.4
                                                       85.4                  720   336    336

       *» PROBLErtS/SOLUTICNS/COMMENTS

                         ON NOVEMBER S, UNIT  1  RETURNED TO SERVICE AFTER A SIX MONTH OUTAGE TO
                         REPLACE THE AIR HEATER TUBES. TUBE  SHEET AND HOPPERS.

                         DURING THE OUTAGE, SEVERAL LENGTHS  OF VENTURI PIPING  HAD TO BE REPLACED
                         WITH NEW RUBBER LINED  PIPE.
                                               896
9/79
10/79
11/79
SYSTEM
SYSTEM
A
B
SYSTEM


53.3
53.3
53.3


100.0
100.0
100.0

-------
                                              EPA UTILITY FGO  SURVEY:  OCTOBER  -  OECErSER  1<=31

COMMONWEALTH EDISON:  MILL COUNTY 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGO    CA=.
                                                                502   PART.  HOURS HOUPS  KOU'S FACTCS

                         THE UNIT DID NOT FORCE THE BOILER OFF AT ANY TIME  DURING NOVEMBER.

12/79  A           77.0        99.5                    57.5
       B           64.9       100.0                    57.8
       SYSTEM      77.0        99.5                    57.5                  744   431    428

       «« PROBLEKS/SOLUTIONS/COKKENTS

                         ON DECEMBER 4, UNIT 1 CAME OFF LINE  SO THAT THE AIR HEATER HOPPEPS AMD
                         PRECIPITATOR HOPPERS COULD BE EMPTIED OF CARBON CARRY-OVER AND  DEBRIS.
                         DURING THIS OUTAGE THE SHOP REPAIRED A LEAK IN THE POND RETURN  LINE.

                         ON DECEMBER 10, THE A-MCOULE DEVELOPED A SERIOUS STEAM LEAK (£5.000  MAKE-
                         UP) IN A LOWER REHEAT BUNDLE.  THE LEAKING  BUNDLE  HAD TO BE REMOVED  AND
                         REPLACED.  THIS RESULTED IN A TWO DAY FORCED OUTAGE.  LATER IN  THE MONTH
                         THE A-MODULE BLEW ANOTHER REHEATER TUBE FORCING THE BOILER OFF  FOR AN
                         ADDITIONAL 25 HOURS AND 12 MINUTES.

                         THE A-MODULE HAS REMOVED FROM THE GAS PATH  ON DECEMBER 29, FOR  THREE HC'JHS
                         TO ALLOW THE MAINTENANCE SHOP TO WELD A LEAKING REHEATER FLANGE.

                         THE S02 PLANT FORCED THE BOILER OFF  TWICE THIS MONTH.  TOTAL FORCED  OUTAGE
                         TIME ATTRIBUTED TO THE SCRUBBER MAS  54 HOURS AND 39 MINUTES.

 1/80  A           91.0        87.5                    63.0
       B           88.6        84.1                    60.6
       SYSTEM      88.6        84.1                    60.6                  744   536    451

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THE FIRST SIX DAYS OF JANUARY, UNIT  1 BOILER MAS OFF THE SYSTEM BECAUSE
                         OF A SLAG SCREEN TUBE LEAK.  THE UNIT RETURNED TO  SERVICE ON JANUARY 7.

                         ON JANUARY 16, THE UTILITY HAD TO DEPATE UNIT 1 TO 50 MM BECAUSE THE RE-
                         HEATER SECTIONS ON A AND B MODULES MERE PLUGGING.   ON JANUARY 17, THE
                         MODULES MERE TAKEN OUT OF THE GAS PATH TO BEGIN REMOVING AHO CLEANING THE
                         REHEATER SECTIONS WITH A HIGH PRESSURE (4000 PSD  MATER SPPAY.   UNIT 1
                         BOILER MAS LEFT ON TO PROVIDE STABILITY FOR THE 133 KV SYSTEM.

                         IN THE PAST, ALL 42 BUNDLES CONSISTING OF SEVEN TUBES PER BUT-IDLE,
                         HAD TO BE TAKEN OUTSIDE TO BE CLEANED ON A  CONCRETE SLAB.  IN THIS CASE
                         SINCE TIME MAS THE MOST IMPORTANT FACTOR, A DIFFERENT APPROACH  WAS USED.
                         ONLY THE MIDDLE SIX BUNDLES ON EACH  MODULE  MERE REMOVED.  THIS  PROVIDED  A
                         LARGE ENOUGH SPACE SO THAT A LANCE WITH AN  EXTENSION ON IT COULD BE  USED
                         TO CLEAN THE BOTTOM OF THE TWO TOP BUNDLES  AND THE TOP OF THE TWO BOTTOM
                         BUNDLES.  THERE ARE DOORS THAT ALLOW EASY ACCESS TO THE TOP AND BOTTOM
                         OF THE REHEATER.  USING THIS METHOD, ONLY 12 OR THE 42 BUNDLES  MERE
                         REMOVED.  IN THE PAST, THIS JOB HAS TAKEN AS LONG  AS TWO WEEKS  TO
                         COMPLETE.  USING THE NEM METHOD, ALL THE REHEATER  BUNDLES WERE  CLEANED IN
                         20 HOURS.

                         THE B-MODULE HAS FORCED OFF LINE ON TWO OTHER OCCASIONS IN JANUARY.   BOTH
                         THESE OUTAGES MERE CAUSED BY THE REHEATER (A COIL  LEAK AND A FLANGE  LEAK)
                         TOTALING 18 HOURS AND 24 MINUTES.

 2/80  A           79.7        90.5                    79.7
       B           78.6        69.2                    78.6
       SYSTEM      74.1        84.2                    74.1                  696   613    516

       »» PRCBLEMS/SOLUTIOM3/COMMENTS

                         SCRUBBER PROBLEMS IN FEBRUARY HERE CAUSED FROM LEAKS IN THE VENTUPI  SPPAY
                         HEADER.  THESE LEAKS DEVELOP WHERE THE RUBBER LINING INSICE THE VENTUrl
                         PIPING HAS MORN AMAY SO THAT THE BARE METAL IS EXPOSED.  THIS EXPOSED METAL
                                               697

-------
 EPA UTILITY FED SURVEY:  OCTOBER - DECEMBER 1981

COMMONWEALTH EDISCN:  MILL COUNTY 1 (CONT.)
	.	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X  REMOVAL'   PER  BOILER   FGO    CAP.
                                                                S02  PART. HCU3S HOU3S   HCUES  FACTOR

                         IS THEN SUBJECT TO ERROSION/CORHOSION.  THE LINING  IS TOST  LIKELY TO  WEAR
                         AT THE WELD HEAD OF THE SPRAY NOZZLE TO THE MAIN HEADER.  ALL THE VENTUHI
                         SPRAY PIPING IS BEING REPLACED.

                         TUBE LEAKS IN THE STEAM COIL  REHEAT SYSTEM CAUSED SCRUBBER  PROBLEMS THIS
                         MONTH. MODULE A MAS FORCED OUT ONCE AND  MODULE B UAS FORCED OUT THREE
                         TIMES. THESE TUBES MILL BE REPLACED DURING THE NEXT OUTAGE.

 3/80  A           83.9                                  .0
       A           83.9                                  .0
       SYSTEM      83.9                                  .0                  744     0      0

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER MAS OUT OF SERVICE FOR ALL OF  MARCH DUE  TO BOILER TUBE LEAKS  IN
                         THE REHEAT SECTION OF THE  BOILER.

 4/80  A          100.0        71.0                    17.3
       B           87.7        71.0                    17.3
       SYSTEM      93.9        71.4                    17.3                  720   175    125

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE FIRST 15 DAYS OF APRIL THE BOILER MAS OUT OF SERVICE DUE TO
                         TUBE LEAKS IN THE AIR PREHEATER.

                         WHEN ATTEMPTS MERE MADE TO BRING THE BOILER ON LINE ON THE  16 THE
                         B-MODULE  OF THE S02 SYSTEM DEVELOPED REHEATER TUBE  LEAKS.   THIS CAUSED
                         A FORCED  OUTAGE OF 53 HOURS AND 40 MINUTES.

                         WHEN ATTEMPTS MERE MADE TO RETURN THE BOILER TO SERVICE AGAIN,  THE AUXIL-
                         IARY LOW  PRESSURE GOVEMOR  DEVELOPED AN  OIL LEAK CAUSING A FOUR  DAY OUTAGE,
                         FOLLOWED  BY ANOTHER REHEATER  TUBE LEAK  OUTAGE ON THE B MODULE.   THIS
                         OUTAGE LASTED 35 HOURS. THE  UNIT RETURNED TO SERVICE ON APRIL  £4 AMD
                         MAS AVAILABLE FOR THE REST OF APRIL.

 5/80  SYSTEM                                                               744

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         INFORMATION UAS NOT AVAILABLE FOR THE MONTH OF MAY.

 6/80  A           86.5       100.0                    81.2
       B           86.5       100.0                    81.2
       SYSTEM      86.5       100.0                    81.2                  720   584    584

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         THE SCRUBBING SYSTEM FOPCED THE BOILER  OUT OF SERVICE FROM  JUNE 6 TO
                         JUNE 10.   THE OUTAGE MAS CAUSED BY PLUGGED REHEATERS ON BOTH MODULES.
                         THIS MAS  THE ONLY FORCED OUTAGE EXPERIENCED DURING  JUNE.

 7/80  A           87.8        78.3                    55.0
       B           87.8        78.3                    55.0
       SYSTEM      87.8        78.3                    55.0                  744   522    409

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE MONTH OF JULY THERE MERE NO  FORCED SCRUBBER OUTAGES.

                         TWO SLAG  LINE OUTAGES,  ONE FORCED DRAFT FAN AND ONE BOILER  SCREEN WALL
                         TUBE OUTAGE OCCURRED.  THIS ACCOUNTED FOR 193 HOURS OF BOILER-RELATED
                         OUTAGE TIME DURING THE MONTH.
                                               898

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER  -  DECEMBER  1981

COMMONWEALTH EDISON:  MILL COUNTY 1 (CONT.)
	PERFORMANCE  DATA	
PEPIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER   BOILER   FG3    CiP.
                                                                S02   PART.  HOURS HOURS  HCt'^3  FACTOR

                         ON NINE OCCASIONS  IN JULY THE SCRUBBER  MAS  BY-PASSED  SO THAT THE BOILER
                         COULD CARRY MAXIMUM LOAD (163 MM).   THE UNIT MAS LIMITED TO 135 MVJ AFTER
                         A RECENT STACK EMISSION TEST.

 6/80  SYSTEM                                                               744

 9/80  SYSTEM                                                               720

       «« PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION HAS AVAILABLE  FOR THE MONTHS OF AUGUST AND SEPTEMBER.

10/80  A           69.9       100.0                    60.9
       B           69.9       100.0                    60.9
       SYSTEM      69.9       100.0                    60.9                  744   453    453

       *« PROBLEMS/SOLUnONS/COMMENTS

                         DURING OCTOBER THERE MAS ONE  FORCED OUTAGE  DUE TO PROBLEMS MITH THE AB-
                         SORBER RECIRCULATION PUMP CM  MODULE B.   DURING THIS OUTAGE THE  MALL MASH
                         HEADERS MERE REPLACED ON BOTH MODULES.

                         DURING OCTOBER THE BOILER HAS SHUT  DOWN TWICE DUE TO  A  LACK OF  DEMAND.
                         THIS ACCOUNTED FOR APPROXIMATELY 51 HOURS OF DOWN TIME.  ADDITIONAL UNIT
                         OUTAGE TIME MAS DUE TO INTERCEPT VALVE  AND  AIR HEATER PROBLEMS.

11/80  A           92.4       100.0        63.4        33.0
       B           9Z.4       100.0        83.4        33.0
       SYSTEM      92.4       100.0        63.4        33.0                  720   238    233

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED THAT HO  MAJOR  PROBLEMS WITH THE  SCRUBBING  SYSTEM WERE
                         ENCOUNTERED DURING NOVEMBER.

12/80  A           77.9       100.0        31.5        31.5
       B           77.9       100.0        31.5        31.5
       SYSTEM      77.9       100.0        31.5        31.5                  744   234    234   20.3

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING DECEMBER AVAILABILITY  OF THE FGO SYSTEM HAS LOU  DUE TO PLUGGED
                         VENTURI NOZZLES AND HEADER, WHICH HAD TO BE HIGH-PRESSURE JETTED.

 1/81  A           82.4       100.0        60.8        60.8
       B           82.4       100.0        80.8        80.8
       SYSTEM      82.4       100.0        80.8        60.8    80.00        744   601    601

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         DURING JANUARY THE MIST ELIMINATOR  TRAY MAS REPLACED  ON MODULE  A.

 2/81  A           75.4       100.0        66.9        68.9
       B           75.4       100.0        68.9        68.9
       SYSTEM      75.4       100.0        68.9        66.9    80.00        672   463    463   59.3

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING FEBRUARY THE BOILER MAS OUT  OF SERVICE APPROXIMATELY 209 HOURS CUE
                         TO TUBE LEAKS.

                         THE SCRUBBING SYSTEM HAS OUT  OF SERVICE 164 HOURS DUE TO CLEANING AND A
                         TWO HOUR INSPECTION.
                                               899

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981

COmOHMEALTH EOISCN: WILL CCUNTY 1 (CONT.)
	PERFORMANCE  DATA	
PERIOD MCDULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION   7.  REMOVAL   PER  BOILER   FGD    CAP.
                                                                S02  PART. HOU3S HCU2S   HC'JPS  FAC7G9
3/31 A 70. 3 100.0 68.2 68.2
B 70.2 100.0 68.2 68.2
SYSTEM 70.2 100.0 68.2 68.2 60.00


744 507 507 63.1
       »« PROBLEMS/SOLUTIONS/CCKMENTS

                         DURING MARCH DOWNTIME  OCCURRED DUE TO MISCELLANEOUS CLEANING TO THE BOILER
                         AND THE SCRUBBER.

 4/31  A           32.9       100.0         32.9       32.9
       B           32.9       100.0         32.9       32.9
       SYSTEM      32.9       100.0         32.9       32.9                  7CO    237     237   30.1

       ** FROBLEMS/SOLUTIONS/COHMENTS

                         DURING MAY  THE  SCRUBBING MODULES AND THE SCRUBBER PIPING HERE CLEANED.
                         THIS ACCOUNTED  FOR THE OUTAGE TIME DURING THE MONTH.

 5/81  A           59.1       100.0         51.0       48.1
       B           59.1       100.0         51.0       48.1
       SYSTEM      59.1       100.0         51.0       48.1    80.00         744    353     358   42.7

       ** PROBLEMS/SOLUTIONS/COHMENTS

                         DURING MAY  THE  BOILER  MAS DOWN FOR 11 DAYS FGR A SCHEDULED OUTAGE.

                         IN MAY 41 HOURS OF OUTAGE TIME MAS DUE TO A LACK OF DEMAND.

                         LEAKS IN THE CYCLONE TUBES CAUSED THE SYSTEM TO SHUT DOWN  FCR 53  HOURS.

                         TOWARD THE  END  OF  MAY, THE SYSTEM WAS SHUTDOWN FOR 30 HOURS TO PREPARE
                         FOR AN EMISSION TEST.

 6/81  A          100.0       100.0       100.0       63.7
       B          100.0       100.0       100.0       63.7
       SYSTEM     100.0       100.0       100.0       63.7                  720   458     458   49.4

       »« PROBLEMS/SOLUTIONS/COHMENTS

                         DURING JUNE NO  MAJOR PROBLEMS WERE ENCOUNTERED.
                                              900

-------
                                              EPA UTILITY FGD SURVEY: OCT03E3 - DECEMBER 1931

                                           SECTION 14
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCPU2BERS
COMPANY NAME
PL."NT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
HOX EMISSION LIMITATION - N3/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MU
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MU

 «* WIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     60ILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 *» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHL03ICE CONTENT - 7.
     RANGE CHLORIDE CONTENT - X

**« PARTICLE CONTROL

 «* MECHANICAL COLLECTOR
     NUMBER
     TYPE

 *» FABRIC FILTER
     NUMBER
     TYPE

 «• ESP
   •  NUMBER
     SUPPLIER
     PARTICLE REMOVAL EFFICENCY - X

 *« PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     LIQUID RECIPCULATION RATE - LITER/S
     L/G RATIO - LITER/CU.H
     PH CONTROL ADDITIVE
DETROIT EDISON
ST. CLAIR
6
BELLE RIVER
MICHIGAN
C
   66.
 1376.
******
 1798
  260
«**«*
*****
  163
COMBUSTION ENGINEERING
******
PEAK
  465.77
  132.2
  130.
******
*******
               (   .200
               (  3.200
               (****** LB/MK3TU)
               ( 987000 ACFM)
               ( 270 Fl
               ( 425 FT)

               (»«*** FT)
               (  9600 BTU/LB)
                9500-9600
COAL
SUBBITUMINOUS
22330.

    4.00
3.0-4.0
   22.60
22.0-24.0
     .35
0.3-0.4

**»»»«
 0
NONE
 0
NONE
MHEELABRATOR-FRYE
   90.0
 2
 9/75
VENTURI TOMER
VARIABLE-THROAT/AOJUSTABLE DRUM
RADIAL FLOW VENTURI
PEABODY-LURGI
STAINLESS STEEL
AUSTENITIC
ORGANIC
RUBBER
NONE
               ( 4420 GPM)
               (20.0 GAL/1000ACF)
  278.5
    2.7
LIMESTONE
                                               901

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER  1981

DETROIT EDISCN:  ST.  CLAIR 6 (CONT.)

     PRESSURE CROP - KPA                             3.5        (14.0  IN-H20)
     SUPERFICIAL GAS VELOCITY - M/S                28.3        (    °3.0  FT/S)
     INLET GAS FLOW RATE  - CU.M/S                 116.6        (  £47000  ACFM)
     INLET GAS TEMPERATURE - C                    133.2        (   270 F)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPEHABILITY RELIABILITY  UTILIZATION   X  REMOVAL    PER  BOILER   FGO    CAP.
                                                                S02   PART. HOURS HOURS   HCVS  FACTOR


11/74  SYSTEM                                                                720

12/74  SYSTEM                                                                744

 1/75  SYSTEM                                                                744

       K* PROBLEMS/SOLUTICNS/COMMENTS

                         INSTALLATION OF THE FGO SYSTEM HAS ESSENTIALLY  COMPLETED  BY THE NOVEMBER,
                         1974 THROUGH JANUARY 1975  PERIOD.

                         A FAULTY INSTRUMENT PANEL  WHICH MAS INCORRECTLY HIRE3 HAS BEEN  RETURNED  TO
                         THE MANUFACTURER FOR REPAIR.

                         TO OATEi THE UTILITY HAS MATER TESTED  ALL THE AUXILIARY EQUIPMENT.  THE  ID
                         FAN HAS BEEN TESTED AND AIR BALANCE HAS BEEN CHECKED.

 2/75  SYSTEM                                                                672

 3/75  SYSTEM                                                                744

 4/75  SYSTEM                                                                720

       «* PRCBLEMS/SOLUTIONS/COraiENTS

                         A COLD FLUE GAS RUN HAS SUCCESSFULLY CONDUCTED  MARCH 22 AND 23.  DURING
                         THIS PERIOD THE RUBBER-LINED  PUMPS MERE REPAIRED  AND THE  LIMESTONE  FREARA-
                         TION SYSTEM MAS CALIBRATED.

 5/75  SYSTEM                                                                744

 6/75  SYSTEM                                                                720

 7/75  SYSTEM                                                                744

       «« PROBLEMS/SOLUTIONS/COMMENTS

                         THE FIRST HOT FLUE GAS RUN MAS CONDUCTED  ON JUNE  22, 1975.  THE RUN LASTED
                         FOR A PERIOD OF 22 HOURS.   DURING  THIS RUN,  THE SCRUS9ER  MAS PURPOSELY
                         TRIPPED OFF AT LOADS OF 40 AND 80  PERCENT.   THIS  MAS PERFORMED  TO OBSERVE
                         IF ANY DETRIMENTAL EFFECTS TO THE  STEAM GENERATION  OPERATIONS RESULTED.
                         NONE HERE DETECTED.  THE SYSTEM MAS TAKEN CUT OF  SERVICE  FOLLOMINS  THIS
                         GAS RUN TO CORRECT THE FOLLOWING MAJC3 OPERATION  AREAS:
                               GAS CIRCUIT: LUGI THROAT POSITIONAL FAILURE;  DETERIORATION OF THE
                               DAMPER SEALS; SEVERE VIBRATIONS; 502  ANALYZERS INOPERATIVE.
                               LIQUID CIRCUIT: FAILURE OF PH CONTROL SYSTEM; TARGET FLOW METER
                               TARGETS HAVE BEEN BROKEN OFF; PUMP  SEAL MATER LCM FLOW ALARM  TRIPS.

 8/75  SYSTEM                                                                744

 9/75  SYSTEM                                                                720

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         A SECOND HOT FLUE  GAS RUN  MAS INITIATED ON  AUGUST 6 AND LASTED  27 HOURS.
                         THE RUN HAS TERMINATED BECAUSE OF  A REHEATER THERMOCOUPLE FAILURE.  A
                         SUBSEQUENT INSPECTION OF THE  SCRUBBING SYSTEM REVEALED NO APPARENT
                         ABNORMALITIES OR MALFUNCTIONS.
                                               902

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - OECEM3ER

DETROIT EDISON: ST. CLAIR 6 (CCNT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILED  F6D   CAP.
                                                                SO2  PART. HCUHS HOURS  HOURS FACTO?

                         A THIRD HOT FLUE GAS PUN OF 41 HOURS DURATION HAS COMPLETED OCT02ES 9.   THE
                         MAIM OBJECTIVE OF THIS RUN WAS TO EVALUATE VARIOUS CCrtPCNEHTS OF THE FRESH
                         HATER SPRAT SYSTEM AND EFFECTS ON SYSTEM OPERATION.  THE TEST fij!l HAS
                         PREMATURELY TERMINATED BECAUSE OF A BOILED FEED PUMP NALFLCiCTIO.'l. RESJLTIM5
                         IN A REDUCED BOILER LOAD CAUSING SUBSEQUENT WEEPING OF THE MASH TRAY.

10/75  SYSTEM                                                                744

11/75  SYSTEM                                                                720

12/75  SYSTEM                                                                744

       ** PHOBLEMS/SOLUTION3/COMMENTS

                         A FOURTH FLUE GAS RUN OF 23 DAYS DURATION UAS TERMINATED DUE TO EXCESSIVE
                         VIBRATION IH THE 1.0. & BOOSTER FAN.  ONE OTHER SCRCEBER-RELATED CUTAuS
                         OCCURRED WHEN THE PACKING OF ONE OF THE SCRUBSER RECIRCULATICN FU1FS HEEDED
                         MAINTENANCE.  SOZ REMOVAL DURING THIS PERIOD WAS 90 PERCENT AIJD PARTICULAR
                         OUTLET LOADING MAS 0.1 IB/1000 LBS OF FLUE GAS FOR 1-3 PERCENT SULFUR COAL.

 1/76  SYSTEM                                                                744

 2/76  SYSTEM                                                                696

 3/76  SYSTEM                                                                744

 4/76  SYSTEM     100.0       100.0                                          720

       «* PROBLEMS/SOLUTIONS/COtlMENTS

                         THE 30-DAY VENDOR QUALIFICATION RUN AND FINAL ACCEPTANCE TEST MERE
                         COMPLETED BY MAY 29.  THE QUALIFICATION RUM UAS CONDUCTED OH A "HANDS OFF"
                         BASIS USING PLANT PERSONNEL EXCLUSIVELY.  THE SYSTEM UAS IN SERVICE 100
                         PEPCENT OF THE TIKE THE BOILER UAS OPERATIONAL.  THE FINAL ACCEPTANCE TEST
                         CONSISTED OF SIX 4-HR. TEST RUNS CONDUCTED IN THE SPACE OF ONE KEEK.  THE
                         S02 REMOVAL EFFICIENCY FOR HIGH SULFUR COAL UAS 90.9 PERCENT.  PARTICULATE
                         REMOVAL ALSO EXCEEDED DESIGN LEVELS.  NO MAJOR CHEMICAL OR MECHAMICAL-
                         RELATED PROBLEMS HERE ENCOUNTERED.

 5/76  SYSTEM                                                                744

 6/76  SYSTEM                                                                7EO

 7/76  SYSTEM                                                                744

 6/76  SYSTEM                                                                744

       «* PROBLEMS/SOLOTIONS/COMMENTS

                         THE UTILITY IS NOW PREPARING TO CONDUCT A 2 MONTH MINIMUM IHTEPNAL SCRUBBED
                         DEMONSTRATION PROGRAM TO ACQUIRE OPERATING DATA AND INFORMATION.  FOLLOV4IN3
                         THE COMPLETION OF THIS PROGRAM THE BOILERS WILL FIRE LCW SULFUR DECKER
                         COAL (0.3 TO 4.0 PERCENT) TO MEET S02 EMISSION REGULATIONS.  THE SCHU36ERS
                         MILL CONTINUE TO OPERATE IN THE PARTICULATE REMOVAL MODE.

 9/76  SYSTEM                                                                720

10/76  SYSTEM                                                                744

       »» PROBLEMS/SOLUTIONS/COHMEHTS

                         THE INTERNAL SOZ SCRUBBING DEMONSTRATION PROGRAM COMMENCED ON OCTOBER 14.
                         THE SCRUBBERS OPERATED CONTINUOUSLY FOR 10 DAYS.
                                               903

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981

DETROIT EDISON: ST. CLAIR 6 (COMT.)
	PERFORMANCE DATA	
PERIOD MCCULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER   BOILER   FCO   CAP.
                                                                502   PART.  HOURS HOURS  HOURS FACTOR

                         OPERATION ON THE DEMONSTRATION PROGRAM MAS  INTERRUPTED  BY  A FORCED  SCRUESER
                         OUTAGE RESULTING FPOM SCALE AND SOLIDS CARRYOVER FROM THE  WASH  TPAY AND
                         MIST ELIMINATOR TO THE SCRUBBER 1.0.  BOOSTER FAN ASSEMBLY,  CAUSING  VIBRA-
                         TION AND BALANCE PROBLEMS.  IT MAS DECIDED  TO SANDBLAST THE FAN TO  REMOVE
                         SOLIDS BUILDUP ON THE FAN ASSEMBLY.

                         THE UTILITY PLANS TO MODIFY THE COMPONENT'S MASH SYSTEM FOR GPEATER FLOW
                         CAPABILITY AFTER COMPLETION OF THE SO2 SCRUBBING PROGRAM.   DECO ALSO PLANS
                         TO CONTINUE PARTICULATE SCRUBBING FOLLOWING THE  TERMINATION OF  THE  S32
                         PROGRAM BY UNCOUPLING THE SPRAY TOWERS AND  MAINTAINING  THE PEABCDY-LURG!
                         VENTURI SCRUBBERS IN THE FLUE GAS STPEAM.  SOME  LIMESTONE  MAY HAVE  TO BE
                         ADDED TO THE PARTICULATE SCRUBBING SOLUTION IM ORDER TO PREVENT LOW PH
                         SWINGS AND MINIMIZE THE POSSIBILITY OF ACID CORROSION DAMAGE TO THE
                         INTERNAL COMPONENTS.

11/76  SYSTEM      60.0                                                     720

       *» PROBLEMS/SOLUTIOHS/COMMEHTS

                         FOLLOWING THE COMPLETION OF SAND BUSTING OPERATIONS TO SCRUBBER'S  I.D.
                         BOOSTER FAN FOR REMOVAL OF SOLIDS BUILO UP. OPERATIONS  RESUMED  ON NOVEMBER
                         7 AND CONTINUED THROUGHOUT THE MONTH.   THE  SYSTEM'S AVAILABILITY INDEX fCR
                         THE MONTH MAS 80 PERCENT.  THE MAJORITY OF  THE OUTAGE TIME MAS  CONSUMED
                         PROCURING SAND BLASTING SERVICES.  THE OPERATION ITSELF REQUIRED ONLY 3
                         HOURS.

13/76  SYSTEM      51.0                                                     744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE SOS DEMONSTRATION PROGRAM CONTINUED THROUGHOUT DECEMBER. THE SYSTEM'S
                         AVAILABILITY INDEX FOR THE PERIOD MAS 51 PERCEN".

                         SCRUBBER OUTAGES RESULTED FROM LIMESTONE FEEDER  PROBLEMS.

                         SCRUBBER OUTAGES RESULTED FROM DENSE  SLURRY TRAVERSE PUMP  PROBLEMS.

                         SCRUBBER OUTAGES RESULTED FROM DENSE  SLURRY TANK AGITATOR  MALFUNCTIONS.

                         PH SAMPLING LINE PLUGGING RESULTED IN SOME  OUTAGE  TIME.

 1/77  SYSTEM        .0                                                     744

 3/77  SYSTEM        .0                                                     672

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE S02 DEMONSTRATION PROGRAM HAS OFFICIALLY TERMINATED OH DEC.  31, 1976.
                         THE SCRUBBER PLANT MAS SHUT DOWN AT THIS POINT AND FLUE GAS MAS BY-PASSED
                         AROUND THE SYSTEM.

 3/77  SYSTEM        .0                                                     744

       N* PRCBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER REMAINS IN SERVICE, FIRING LOM SULFUR (0.3X)  WESTERN COAL.
                         CURRENT PLANS CALL FOR THE SCRUBBER PLANT TO REMAIN OUT OF  SERVICE  UNTIL
                         MID-JUNE FOR DESIGN AND OPERATING MODIFICATIONS.   RESUMPTION OF SCRL'SBER
                         OPERATIONS WILL OCCUR IN THE PRIMARY  PARTICULATE-REMOVAL MODE.   THE
                         PEABODY-LURGI VENTURI SCRUBBERS AND SPRAY TOWER  ABSORBERS  MILL  PEMAIN III
                         THE GAS STREAM.   SOLUTION WILL BE CIRCULATED THROUGH THE VENTURI'S  MASH
                         TRAYS,  AND MIST ELIMINATORS.   NO SOLUTION WILL BE  CIRCULATED THROUGH THE
                         SPRAY ZONE OF THE ABSORBER TOWERS.  LIMESTONE REAGENT WILL BE ADDED TO THE
                         SCRUBBING SOLUTION IN ORDER TO PREVENT LOM  PH SWINGS AND SUBSEQUENT
                                               904

-------
                                              EPA UTILITY F60 SURVEY:  OCTOBER  - DECEMBER 1931
DETROIT EDISON:  ST.  CLAIR 6 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                             X REMOVAL   PEP  BOILE3  FG3   CAP.
                                             SOZ  PART.  HCUPS HOUSS  HCL."?S FACTOR
                         KATE-IALS DAMAGE TO THE SCRUBBER'S INTERNALS.   S02  PECOVAL SHOULD  RESIDE
                         IN THE  35 TO SOX RANGE IN THIS MODE Or  OPERATION BECAUSE  OF THE  SOLUTICN'S
                         ALKALINITY DUE TO THE FLY ASH AND LIMESTONE.   ALSO  OECO PLANS TO MAINTAIN
                         A HIC-HEF  L/G RATIO IN THE SCRUBBER MODULES.   THIS MODE  OF OPERATION IS
                         PROJECTED TO CONTINUE FOR A ONE TO THREE YEAR  PERIOD  FOLLOWING THE
                         MID-JUNE  RESTART.
 4/77  SYSTEM

 5/77  SYSTEM

 6/77  SYSTEM

 7/77  SYSTEM

 8/77  SYSTEM

 9/77  SYSTEM

10/77  SYSTEM
  .0

  .0

  .0

  .0

  .0

  .0
                                                    7ZO

                                                    744

                                                    7£0

                                                    744

                                                    744

                                                    7ZO

                                                    744
          PROBLEMS/SOLUTIONS/COMMENTS
11/77  SYSTEM

1Z/77  SYSTEM

 1/78  SYSTEM

 3/78  SYSTEM

 3/78  SYSTEM

 4/78  SYSTEM

 5/78  SYSTEM
96.0

85.6

90.0

74.6
THE UNIT HAS PULLED OFF LINE IN DECEMBER 1976 AND DID NOT PESTART UNTIL
OCTOBER 1977.  WHILE THE UNIT HAS DOWN THE UTILITY INSTALLED BUILOIN33
AROUND PUMPS THAT MERE EXPOSED TO SEVERE WEATHER CONDITIONS.

                                                    7ZO

                                                    744

                                                    744

                                                    67Z

                                                    744

                                                    7ZO
                                                                             744
       «» PROBLEMS/SOLUTIONS/COMMENTS
                         THE UNIT EXPERIENCED SPRAY HEADER PROBLEMS IN THE ABSORBER TOMER.
                         BROKEN NOZZLES MERE DISCOVERED.
                                                                                            SOME
                         THERE MERE SOME I.D. BOOSTER FAN PROBLEMS.  THE UTILITY MUST SAND BLAST THE
                         FAN EVERY 4 TO 5 WEEKS WHEN THE MAGNITUDE OF VIBRATION OF THE FAN BECOMES
                         EXCESSIVE FROM SCALE FORMATION; HOWEVER, IN THIS INSTANCE THE FPC3LEM HAS
                         A RESULT OF A LOU FAN OIL LEVEL.

                         THE UTILITY NOW OPERATES 3 RECYCLE TANK AGITATORS.  PREVIOUSLY CNLY Z WERE
                         OPERATED.  IT WAS FELT THAT PART OF THE TANK PLUGGING MAS A RESULT OF
                         INSUFFICIENT AGITATION.

                         THE SLURRY SPRAY SURGE TANK ENCOUNTERED CONTINUAL OVERFLCM PROBLEMS WHEN
                         THE ABSORBER SUMP PUMP WAS OPERATING.  THIS HAS BELIEVED TO BE A RESULT OF
                         A BROKEN SECTION IN THE SPRAY NOZZLE LINES.  SPRAY WAS BEING DIPECTEO
                         UPWARD TO THE BOTTOM OF A TRAY INSTEAD OF DOWN, COUNTERCURRENT TO THE
                         GAS FLOW AS INTENDED.

                         REHEATER PROBLEMS OCCURRED WITH THE FORMATION OF OIL CLINKERS IN THE
                         BURNER AREA.  IT WAS DISCOVERED THAT THE AIR SUPPLY TO THE BURNER WAS
                         INSUFFICIENT.
                                               905

-------
 EPA UTILITY FGD  SURVEY I  OCTOBER - DECEMBER  1931

DETROIT EDISON:  ST.  CLAIR 6 CCOMT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABIUTY RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER   FGO   CAP.
                                                                S02  PART. HC'JOS  HO'JOS   HC'JSS  FACTOR

                         SOME SPRAY HEADER PROBLEMS MERE ENCOUNTERED.  THE FP.P PIPING HAS RUFTUSIHG.
                         IT MAS SUSPECTED THAT THE RUPTURES HEPE A RESULT OF "MATE?  H4HHER"  I.E.
                         THE SURGE THAT OCCUSRS IN THE PIPE WITH A SUDDEN FLOW SATE  CHAH3E.

                         THE SPRAY HEADERS HERE PLUGGING.   WHEN THE HEADERS  ARE DRAINED  (E.G.
                         SYSTEMS SKUTOOMN) SCME SLURRY SETTLES IN THE HEADER LINES ETC.   PINSE LIMES
                         ARE NOW BEING INSTALLED TO FLUSH OUT  HEADERS DURING FUTURE  SHUTDOWNS.

 6/78  SYSTEM      87.9                                                      720

       »* PRCBLEMS/SOLUTXOHS/COnMENTS

                         CNE OF THE BLADES CAME LOOSE FROM  AN  1.0. BOOSTER FAN A HO PASSED THROUGH
                         THE HOUSING.  REPAIRS MERE MADE WITHOUT SERIOUS COMPLICATIONS.

 7/78  SYSTEM      96.0                                                      V*

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         THE INSTALLATION OF RINSE LINES HAS NOT YET BEEN COMPLETED.

                         PROBLEMS WITH RUPTURED SPRAY HEADER PIPING CONTINUED.  IT HAS BEEN  POSSIBLE
                         TO OPERATE THE SCRUBBER WITH THE RUPTURED LIMES WITHOUT  SERIOUS
                         CONSEQUENCES.  IT IS NOT CRUCIAL THAT REPAIRS BE MADE IMMEDIATELY.

 8/78  SYSTEM      90.*                                                      7V*

 9/78  SYSTEM      69.0                                                      720

10/78  SYSTEM        .0                                                      7*4

11/78  SYSTEM        .0                                                      720

12/78  SYSTEM        .0                                                      7*4

 1/79  SYSTEM                                                                744

       »» PRCBLEMS/SOLUTIONS/COMMENTS

                         DURING THIS PERICO RECYCLE TANK AGITATORS MERE BREAKING  LOOSE AND SIMILAR
                         PROBLEMS MERE ENCOUNTERED WITH THE SLURRY STORAGE TANK AGITATORS.  THE
                         SCRUBBING SYSTEM MAS REMOVED FROM  SERVICE FROM SEPTEMBER TrirOUSH JANUARY.
                         STEADY BEARINGS UEPE INSTALLED AT  THE BOTTOM OF THE RECYCLE TANK SOLVING
                         THE RECYCLE TANK AGITATOR PPOBLEM. THE SLURRY STORAGE TAfK SYSTEM  ALREADY
                         HAD STEADY BEARINGS.  THESE MERE REWORKED TO IMPROVE OPERATIONS.

 2/79  SYSTEM                                                                672

 3/79  SYSTEM                                                                74$

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         SOME REHEATER PROBLEMS OCCURRED.

 4/79  SYSTEM                                                                720

 5/79  SYSTEM                                                                744

 6/79  SYSTEM                                                                720

 7/79  SYSTEM                                                                744

 8/79  SYSTEM                                                                744

 9/79  SYSTEM                                                                720
                                               906

-------
                                              EPA UTILITY FGO SURVEY'   "noEH - C=CE"2E= 1931

DETROIT EDISON: ST.  CLAIH 6 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   FE3  BOILER  FCO   CAP.
                                                                S02  PART.  HCU3S KCL-PS  HC'-'S FACTC3


10/79  SYSTEM                                                                7M

       *« PRCBLEMS/SOLUTIONS/COMMEMTS

                         THE SYSTEft IS CURRENTLY DOWN BUT IS EXPECTED TO BE BACK ON LIME SOCM.  THE
                         SCRUBBING SYSTEM HAS OPERATED ONLY 1 MEEK SINCE MAY 18. 1979 BECAUSE OF
                         SUMP PROBLEMS.
                         THE AGITATOR BEARING SYSTEM HAS POORLY DESIGNED.  THE BEARING SYSTEM HAS
                         MOM BEEN COMPLETELY REDESIGNED.  THE AGITATORS HAVE NOW OPERATED 2000 HOU=S
                         ON THE NEH BEARINGS.  THE UTILITY WILL PROBABLY DRAIH THE TAW AFTER AECUT
                         500 MORE HOURS TO INSPECT AND READJUST THE BEARINGS.  THE MEW BEARIN3
                         SYSTEM IS COMPOSED OF STAINLESS STEEL PARTS.
                         100X OF THE ST. CLAIH FLUE GAS PASSES THHOUSH THE ESP.  SOX CF THAT FLUE
                         GAS ENTERS THE SCRUBBER.  THE UNIT IS REQUIRED TO MEET A 55X OPACITY,
                         HOWEVER, A VARIANCE HAS BEEN GRANTED ALLOWING A 65X OPACITY UNTIL TriE
                         SCRUBBER IS AGAIN OPERATIONAL.  THE UTILITY IS PREPARING TO INSTALL A
                         MEM ESP WHICH WOULD BE OPERATIONAL IN 2 YEARS.  KHEN THE NEW ESP IS IN-
                         STALLED THE SCRUBBING SYSTEM AND OLD ESP MILL BE SCRAPPED.  TriE UNIT MILL
                         THEN BE REQUIRED TO MEET A 20X OPACITY.

11/79  SYSTEM      90.0                                                      720

12/79  SYSTEM      90.0                                                      74*

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         THE UNIT CAME BACK ON LINE AROUND MID-NOVEMBER.

                         NEW DENVER PUMPS WITH EJECTORS WERE INSTALLED TO ASSIST THE SUMP FUtlPS
                         UNTIL THE ESP'S COME ON LINE.

                         THE ABSORBER PUMPS HAVE BEEN A PROBLEM RESULTING IN A CAPACITY TUSNOCXN
                         TO 225 MM (FROM 230 MWI.

                         ONE OF THE COAL MILLS HAS BEEN DOWN CAUSING LIMITED OPERATIONS.

  1/60  SYSTEM                                                                7<»
-------
 EPA UTILITY FG3 SURVEY:  OCTOBER - DECEMBER 1961

DETHOIT EDISCN: ST. CLAIR 6 (COMT.)
	PERFORMANCE DATA	
PSPIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILES  FGD   CAP.
                                                                SOZ  PART.  HOLRS KCU3S  HOL'=S FACTCS


       »* PROaLEMS/SOLUTIONS/CCMHENTS

                         THE SCRUBBER HAS OUT OF SERVICE THROUGH APRIL WHILE REPAIRS CONTINUED CM
                         THE SCRUBBER 10 FAN HOUSING.  BECAUSE BOILER OPERATED AT LCM LOAD THE
                         SCRUBBER SERVICES MERE NOT REQUIRED IN APRIL.

 5/80  SYSTEM                                                                7
-------
                                              EPA UTILITY FGO SURVEY:  CCTC8ER - DECEMBER 1931

DETROIT EDISON: ST. CLAIR 6 (CONT.l
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART. HCL'PS HCUSS  HC'JPS FiCTCS


       *» PR03LEHS/SOLUTIONS/COMMENTS

                         THE SCRUBBER DID NOT OPERATE DURING JANUARY, FEBRUARY OR MARCH.  DURING
                         THIS TIME U'ORK MAS CONTINUING CM THE AGITATORS.   THE STATCR 3EARIN3S WERE
                         MALFUNCTIONING CHRONICALLY.  THE BEARINGS HAVE NCH BEEN REMOVED.  THE
                         AGITATOR IS NOW COMPLETELY FREE STANDING AND THE SHAFT HAS EEEM SHORTENED.

                         GENERAL MAINTENANCE MAS PERFORMED CM THE SCRUBBER DURING THE LAST TV3 WEEKS
                         OF MARCH.  MCRK IS TO CONTINUE THROUGH THE FIRST HALF OF AF3IL.  THE
                         SCRUBBING SYSTEM IS SCHEDULED FOR DECOMMISSIONING OU3IN3 THE FIRST hEEK OF
                         SEPTEMBER 1981.

 2/81  SYSTEM        .0                                  .0                  672            0
                                               909

-------
 EPA UTILITY FC-D SURVEY: OCTOBER - DECEMBER 1981
                                           SECTION 1*
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - N3/J
NOX EMISSION LIMITATION - H3/J
tin PLANT GENERATING CAPACITY - MM
C-POSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY H/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM
MINNESOTA POWER
CLAY BOSMELL
3
COHASSET
MINNESOTA
E
258.
1720.
***<**«
1000
364
347
350
350
& LIGHT





( .600 LB/MM3TU)
( 4.000 LB/KMBTU)
(****** LB/MM3TU)





 »* UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYF1
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 ** FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTU9E CONTENT - 7.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFU9 CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - 7.

*** PARTICLE CONTROL

 *« MECHANICAL COLLECTOR
     NUMBER

 <•« FABRIC FILTER
     NUMBER
     TYPE

 *« ESP
     NUMBER
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
  613.47       (1200000 ACFM)
  123.3        ( 254 F)
  213.         ( 700 FT)
CONCRETE
    7.9        f £6.0 FT)
COAL
SUBBITUniNOUS
19538.

    9.00
4.8-16.0
   26.00
24.0-2B.O
     .92
0.5-1.5
     .01
0.00-0.07
(   8400 BTU/LB)
 7500-9900
 0
NONE
 ** PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCULATION RATE - LITER/S
     L/G RATIO - LITER/CU.M
     PH CONTROL ADDITIVE
     PRESSURE DROP - KPA
 1
 5/73
IMPINGEMENT TOMER
NR
NR
KREBS ENGINEERS
18.0 X 126.0 X 52.0
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
 1
  714.4
    1.1
ALKALINE FLYASH
(11240 GPM)
(  8.3 GAL/1000ACF)
                                                    1.0
                                                               (  4.0 IN-H20)
                                               910

-------
                                              EPA UTILITY FGO SURVEY:  OCTC3EH - CECiKEER 1<»31

MINNESOTA POWER » LIGHT:  CLAY BOSMELL 3 ICONT. J
     SUPERFICIAL GAS VELOCITY - M/S
     INLET GAS FLOW RATE - CU.M/S
     INLET GAS TEMPERATURE - C
     S32 REMOVAL EFFICENCY - X
     PARTICLE REMOVAL EFFICIENCY - X
     ENERGY CONSUMPTION - X
                                                    2.4
                                                 613.5
                                                 123.3
                                                     .0
                                                  98.7
                                                     .8
                                (    8.0 FT/S)
                                (1300000 ACFM)
                                (  254 F)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                                X  REMOVAL
                                                                S02   PART.
                                             PER  BOILER  FGD   CAF
                                            HOU=S hCURS  HCL'^S FAC7C?
 5/73  SYSTEM
       *» PROBLEMS/SOLUTIONS/COMMENTS
10/79  SYSTEM

11/79  SYSTEM
                         SINCE STARTUP IN MAY 1973 SCALING AND PLUGGING HAVE OCCURRED IN NOZZLES,
                         NOZZLE TREES, STRAINERS, ON PUNCH PLATE BAFFLES, IN THE WET/CRY ZONE, AND
                         ON THE FAN AND THE MIST ELIMINATOR.  PLUGGING HAS ALSO RESULTED AS DEPOSITS
                         HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SCRL'SSES.  DUE TO THE
                         CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL Bl'PNED, THE SCALING
                         IS AGGRAVATED.  THE UTILITY HAS CONTROLLED SCALE BY BLCXCOUN OF THE
                         SCRUBBING SYSTEM.  THIS HAS MAINTAINED THE PROCESS CHEMISTRY SELOVJ SATURA-
                         TION WITH RESPECT TO CALCIUM SULFITE.  A VERY HIGH LEVEL OF MAINTENANCE
                         HAS BEEN MAINTAINED ALSO TO MINIMIZE SCALE ACCUMULATION AND PLUGGING. THIS
                         HAS INCLUDED MASHING OF THE MET FAN WHICH HAS RESULTED IN A STACK MIST
                         PROBLEM.  THE USE OF SOOT BLOWERS IN PLACE OF MASHING WAS ATTEMPTED 5UT
                         WAS UNSUCCESSFUL.  THE UTILITY HAS REDUCED THE AMOUNT OF WASHING AND HAS
                         CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION CF A NEW LOW-VELOCITY
                         STACK.

                                                                             744

                                                                             720
12/79  SYSTEM                                                                744

       «« PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION MAS AVAILABLE FOR THE FOURTH QUARTER 1979.

  1/80  SYSTEM                                                                744

  2/80  SYSTEM                                                                696

  3/80  SYSTEM                                                                744

       «» PRC3LEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
                         1ST QUARTER OF 1980.
  4/80

  5/80-

  6/80
       SYSTEM

       SYSTEM

       SYSTEM

       »• PROBLEMS/SOLUTIONS/COMMENTS
                                               720

                                               744

                                               720
                          THE UTILITY REPORTED THAT  NO  SCRUBBER-RELATED OUTAGES OCCURPED DURING THE
                          SECOND  QUARTER OF  1980.  DOWN TIME  FOR  MAINTENANCE WAS NOT REQUIRED  SINCE
                          GENERAL MAINTENANCE CAN  BE PERFORMED ON THE MINNESOTA POWER AND  LIGHT PAR-
                          TICLE SCRUBBERS  WHILE  THEY ARE  IN SERVICE.
  7/80

  8/80

  9/80
       SYSTEM

       SYSTEM

       SYSTEM
100.0

100.0

100.0
100.0

100.0

100.0
90.3

78.0

84.0
720   650

744   530

744   625
650  60.2

580  52.3

625  54.8
                                                911

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1<>81

HIHTIESOTA POWER £ LIGHT:  CLAY BOSWELL 3 (COOT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPEHABILITY RELIABILITY UTILIZATION  7. REMOVAL    PEP   SAILER  FG3   CAP.
                                                                S02   PART.  HCURS hl'JHS  KOLSS FACTOR


       «» PROBLEMS/SOLUTION5/CCMMENTS

                         NO OPERATIONAL PROBLEMS MERE REPORTED FOR THE  JULY THROUGH SEPTEMBER
                         PERIOD.
10/80
11/80
12/80
SYSTEM
SYSTEM
SYSTEM
100
100
100
.0
.0
.0
100.0
100.0
100.0
100.0
100
100
.0
.0
85.9
81.5
81.6
744
720
744
639
587
607
639
587
607
62.3
64.6
60.9
*» PROBLEMS/SOLUTIONS/COMMENTS

1/81
2/81
3/81

SYSTEM
SYSTEM
SYSTEM

100
100
100

.0
.0
.0
THE UTILITY
THE FOURTH
100.0
100.0
100.0
REPORTED THAT NO
QUARTER 1980.
100
100
100
.0
.0
.0
SCRUBBER
94.3
97.0
79.0
PROBLEMS MERE ENCOUNTERED
744
672
744
702
651
585
DURING
702
651
585
69.1
73.2
65.1
       »» PROSLEMS/SOLUTIONS/COMKENTS

                         THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS  MERE ENCOUNTERED
                         DURING THE FIRST QUARTER 1981.

                         DURING MARCH THE BOILER MAS OUT OF  SERVICE  APPROXIMATELY 159 HCURS TO RE-
                         PAIR STEAK LEAKS AND TO PERFORM MAINTENANCE.

                                                                             720   447    447  50.9

                                                                             744   709    709  79.3

                                                                             7CO   696    696  75.7

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED THAT NO MAJOR  PROBLEMS WERE  ENCOUNTERED DURING THE
                         SECOND QUARTER 1981.
4/81 SYSTEM
5/81 SYSTEM
6/81 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
62.1
95.3
96.7
                                               912

-------
                                              EPA UTILITY F60 SURVEY: OCTCSER - DECEMBER 1<=31

                                           SECTION 14
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCPU2BERS
CCMPANY HAKE
PUNT MAKE
UMIT NUMBER
CITY
STATE
REGULATCHY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
£02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
C.OQSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - KM

 »» UHIT DATA - BOIISR AHD STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - ft

 »* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RAN3E ASH CONTENT - X
     AVERAGE MOISnjPE CONTENT - X
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - X

««» PARTICLE CONTROL

 ** MECHANICAL COLLECTOR
     NUMBER
     TYPE

 «» FABRIC FILTER
     NUMBER
     TYPE

 «» ESP
     NUMBER
     TYPE

 *» PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER JENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCULATION RATE - LITER/S
     L/G RATIO - LITER/CU.M
               (   .600 LB/MM3TU)
               (  4.000 LB/KT.STU)
               (*****» LB/r.."3TU)
MINNESOTA POVJER S LIGHT
SYL LASKIN
1
AURORA
MINNESOTA
E
  £58.
 1720.
«*«**«
  116
   62
   57
   58
   58
COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
  141.57       (
  171.1        (
   91.         (
CONCRETE
    3.2
                 300000 ACFM)
                 340 F)
                 300 FT)
COAL
SUBBITUMINOUS
20469.

    9.00
4.8-16.0
   26.70
24.0-28.0
    1.00
0.5-1.5
     .01
0.00-0.07
 0
NONE
 0
NONE
 0
NONE
 1
 6/71
IMPINGEMENT TOUER
NR
NR
KREBS ENGINEERS
34.0 X 18.0 X £3.0
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
 1
  151.2        (
    1.1        (
               ( 10.5 FT)
               (  8800 BTU/LS)
                7509-9923
                 2400 GPM)
                 8.3 GAL/1000ACF)
                                               913

-------
 EPA UTILITY FGD SLAVEY:  OCT03ER - DECEMBER 1981

MINNESOTA POMES & LIGHT:  STL LASKIN 1 (CONT.)

     PH CONTROL ADDITIVE
     PRESSURE DROP - KPA
     SUPERFICIAL GAS VELOCITY - M/5
     INLET GAS FLCy RATE  - CU.M/S
     INLET G4S TErTE°ATURE - C
     S02 REMOVAL EFFICENCY - X
     PARTICLE REMOVAL EFFICIENCY - X
     ENERGY CONSUMPTION - 7.
ALKALINE FLYASH
.6 (
2.1 (
137. •* (
171.1 (
.0
97.3
1.6

2.5 IN-H20)
7.0 FT/SJ
291160 ACFM)
540 F)



PERIOD MODULE AVAILABILIT
                                          PERFORMANCE  D4TA	
                           OPERABILITY RELIABILITY  UTILIZATION
                                                                X PEMOVAL    PES  BOILER   FG3    CAP.
                                                                S02   PART. HOURS HOURS   HOURS FACTC9
 6/71  SYSTEM

       *» FROBLEnS/SOLUTICNS/CCMHENTS
10/79  SYSTEM
                         SINCE STARTUP IN JUNE 1971  SCALING  AND  PLUSSIN3 HAVE  OCCURPEO  IN NOZZLES,
                         NOZZLE TREES, STRAINERS,  ON PUNCH PLATE BAFFLES,  IN THE UET/DPY  ZONE,  AND
                         ON THE FAN AMD THE MIST ELIMINATOR.   PLUGGING HAS ALSO RESULTED  AS  CEPCSITS
                         HAVE FALLEN INTO THE DRAINS AT THE  BOTTOM OF THE  SCFU3BER.   DUE  TO  THE
                         CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL  BUPNED, THE SCALING
                         IS AGGRAVATED.  THE UTILITY HAS CONTROLLED SCALE  BY BLOWDCWJ OF  THE
                         SCRUBBING SYSTEM.  THIS HAS MAINTAINED  THE PROCESS CHEMISTRY BELCVI  SATURA-
                         TION WITH RESPECT TO CALCIUM SULFITE.   A VERY HIGH LEVEL OF  MAINTENANCE
                         HAS BEEN MAINTAINED ALSO TO MINIMIZE SCALE ACCUMULATION AND  PLUGGING,  THIS
                         HAS INCLUDED MASHING OF THE WET FAN l.'HICH HAS RESULTED IN A  STACK MIST
                         PROBLEM.   THE USE OF SOOT BLOHEPS IN PLACE OF HASHING HAS ATTEMPTED BUT
                         HAS UNSUCCESSFUL.  THE UTILITY HAS  PECUCED THE AtlC'JNT OF HASHING AND HAS
                         CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEU LOW-VELOCITY
                         STACK.
                         THE PROBLEMS AT SYL LASKIH  ARE NOT  AS SEVEPE AS THE PPC3LEMS AT  CLAY
                         BOSHELL DUE TO THE FACT THAT THE RECYCLE LOOP IS  NOT  CLOSED  TO THE  SAME
                         EXTENT.  THE MIST CARRYOVER PPC3LEM IS  LESS SEVERE CWIN3 TO  OPERATION  Or
                         THE UNIT AT PARTIAL LOAD RESULTING  IN A LCWER STACK VELOCITY.
                                                                             720
11/79  SYSTEM

12/79  SYSTEM                                                                744

       «« PROBLE.1S/SOLUTIONS/COMMENTS

                         NO INFORMATION HAS AVAILABLE  FOR  THE  FOURTH QUARTER  1979.

 1/80  SYSTEM                                                                744

 2/80  SYSTEM                                                                696

 3/80  SYSTEM                                                                744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED  THAT THE SCRUBBER  EXPERIENCED NO PROBLEMS DURING  THE
                         1ST QUARTER OF 1980.
 4/30  SYSTEM

 5/80  SYSTEM

 6/30  SYSTEM

       *« PROBLEMS/SOLUTIONS/COMMENTS
720
720
                         THE  UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCUPRED DURING  THE
                         SECOND  QUARTER  OF  1980.   DOHM TIME  FCR MAINTENANCE HAS NOT REQUIRED  SINCE
                         GENERAL MAINTENANCE  CAN  BE PERFORMED ON  THE MINNESOTA POWER AND  LIGHT  PAR-
                                               914

-------
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
100.0
100.0
100.0

100.0
100.0

100.0
100.0
.0
24.3
64.1
                                              EPA UTILITY FGO SUUVEY: CCTC3E:? - DECSMSEH 1931

MINNESOTA POWER S LIGHT: SYL LASKIN 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  EOIL;3  =GD   CAP.
                                                                S02  PART. HOURS HC'JPS  HC'JPS FACTOR

                         TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.

 7/SO  SYSTEM     100.0       100.0       100.0        56.6                  744   421    421  25.2

 8/80  SYSTEM     100.0       100.0       100.0        19.0                  744   140    140  12.0

       »* PROBLEMS/SOLUTIONS/COKMENTS

                         THE UTILITY REPORTED THAT NO BOILER OR FGD-RELATEO PROBLEMS WERE ENCOUNTER-
                         ED DURING JULY AND AUGUST.  LOW UTILIZATION FACTORS WERE DUE TO A LACK
                         OF POWER DEMAND.

 9/80  SYSTEM     100.0       100.0       100.0         4.4                  720    33     33   1.9

       »* FRCBLEMS/SOLUTIONS/COMMENTS

                         NO SCRUBBER OUTAGES OCCURRED DURING SEPTEMBER.  THE LOW UTILIZATION FACTOR
                         HAS AGAIN THE RESULT OF A LACK OF DEMAND FOR POWER.

                                                                             744     0    744    .0

                                                                             730   175    175  10. Z

                                                                             744   477    477  23.4

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS OCOJRFEO DURING
                         THE FOURTH QUARTER 1960.  LOW UTILIZATION FACTORS WERE CAUSED BY A LACK
                         OF POWER DEMAND.

 1/81  SYSTEM      78.5       100.0       100.0        78.5                  744   524    524  £3.3

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         CURING JANUARY THE BOILER MAS OUT OF SERVICE APPROXIMATELY 160 HCURS DUE
                         TO A TURBINE STEAM LEAK.  THE BOILER WAS OUT OF SERVICE AM ACDITICNAL 63
                         HOURS DUE TO A LACK OF POWER DEMAND.

 2/81  SYSTEM       5.4       100.0       100.0         5.4                  672    36     36  17.4

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING FEBRUARY THE BOILER REMAINED OFF LINE FOR APPROXIMATELY 708 HCURS
                         TO REPAIR A TURBINE STEAM LEAK.

 3/81  SYSTEM      99.1       100.0       100.0        79.0                  744   583    533  44.3

       ** PROBLEMS/SOLUTICNS/COMMENTS

                         DURING MARCH THE BOILER WAS OUT OF SERVICE SEVEN HOURS TO CLEAN THE ID FANS
                         AND 77 HOURS DUE TO A LACK OF DEMAND.

 4/81  SYSTEM     100.0       100.0       100.0       100.0                  720   720    723  46.0

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING APRIL 10 HOURS OF OUTAGE TIME WAS NECESSARY TO WORK ON THE EXCITER.

 5/81  SYSTEM      64.1       100.0       100.0        64.0                  744   476    476  31.3
                                               915

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

MINNESOTA POWER & LIGHT: SYL LASKIN 1 (CONT.)
	PERFORMANCE DATA	
FERIC3 I'.C^'JLE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  SOILED  rGD   CAP.
                                                                S02  PART. HCU'PS KCU=S  HO'JPS FACTC3


       »* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING MAY THE UNIT MAS OUT OF SERVICE £09 HOURS FOR AN OVERHAUL.

                         SYSTEM DOWN TIME WAS NEEDED TO REPAIR A STEAM DRIVEN OIL PUMP.

                         FOLLOWING A TEST THE SYSTEM MAS TAKEN OFF-LINE FOR SANCBUSTINS 10 FANS.

 6/81  SYSTEM     100.0                                  .0                  720     0      0

       ** FRC3LEMS/SOLUTIONS/COMMENTS

                         IN JUNE THE UNIT MAS DOWN DUE TO A LACK OF DEMAND.  DURINS THIS PERIOD
                         GENERAL MAINTENANCE MAS PERFORMED.
                                               916

-------
                            EPA UTILITY  FGD SURVEY:  OCTCSEiJ - CECEr-3E= 1=31

                         SECTION 14
DESIGN AND PERFORMANCE DATA PCS OPERATIONAL PARTICLE SCP'JISERS
COMD«NY NAME
PLiNT NAME
L'MIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
F4STICULATE EMISSION LIMITATION - NG/J
EC2 EMISSION LIMITATION - NG/J
HGX EMISSION LIMITATION - NG/J
>!ET PLANT GENERATING CAPACITY - MW
C-SOSS UNIT GENEPATINS CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
*« UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
SOI LER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - ft
STACK SHELL
STACK TOP DIAMETER - M
»< FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
HAt.'SE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
**<• PARTICLE CONTROL
»» MECHANICAL COLLECTOR
NUMBER
TYPE
*« FABRIC FILTER
NUMBER
TYPE
«» ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
MINNESOTA POWER
SYL LASKIN
2
AURORA
MINNESOTA
E
258. (
1720. (
*4**«tt (
116
62
57
56
58

& LIGHT





.600 LB/MMSTU)
4.000 '.S/KMSTU)
»<«•>-,•» (.3/riflSTU)






COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
141.57 (
171.1 (
«1. (
CONCRETE
3.2 (

COAL
SUBBITUMINOUS
20469. (

9.00
4.8-16.0
26.70
24.0-28.0
1.00
0.5-1.5
.01
0.00-0.07


0
NONE

0
NONE

0
NONE

1
6/71


330000 ACFM)
340 F)
300 FT)

10.5 FT)



6800 BTU/LB)
7509-9923





















IMPINGEMENT TOWER
NR
NR
KREBS ENGINEERS
34.0 X 18.0 X 23
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
1
151.2 (
1.1 (



.0






2400 GPM)
6.3 GAL/1000ACF)
                             917

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

MINNESOTA FOH5R t LIGHT: SYL LA5KIN Z (CONT.)

     PH CO'fTFOL ADDITIVE
     FPESSIPE DPO? - KFA
     SUPERFICIAL GAS VELOCITY - M/S
     INLET GAS FLOW BATE - C'J.M/S
     INLET j£S -CXPE^ATU^E - C
     S3! RLMOV1L ErrlCEI.'CY - '/.
     PARTICLE PSKOV,L EFFICIENCY - 7.
     EI1EPGY CONSUMPTION - V.
ALKALINE FLYASH
     .6        <
    2.:        (
  137.4
  171.1
     .0
   97.8
    1.6
<  2.5 IN-K20)
(     7.0 FT/S)
(  291160 ACFM)
(   340 F)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OFERABILITY RELIABILITY UTILIZATION
                                                                X REraVAL
                                                                S02  PART.
                            PER  BOILER
                           HOURS HOURS
                          FG3   CAP.
                         HCUSS FACTC3
 6/71  SYSTEM
       *» FRCBLEMS/SOLUTIONS/COMMENTS
                         SINCE STARTUP IN JUNE 1971 SCALIHG AMD  PLUGGING  HAVE  OCCURRED IH KOZZLES.
                         NOZZLE TREES, STRAINERS,  ON PUNCH PLATE BAFFLES,  IN THE  WET/DRY Z3NE ANO
                         ON THE FAN AND THE MIST ELIMINATOR.  PLUGGING  HAS ALSO RESULTED AS DEPOSITS
                         HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SC=U23ER.   DUE TO THE
                         CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN  COAL  BUSKED, THE SCALING
                         IS AGGRAVATED.  THE UTILITY HAS CONTROLLED SCALE BY SLOWDOWN OF THE
                         SCRUBBING SYSTEM.  THIS HAS MAINTAINED  THE PROCESS CHEMISTRY BELOW S4TU3A-
                         TIOM WITH RESPECT TO CALCIUM SULFITE.   A VERY  HIGH LEVEL OF MAINTENANCE
                         HAS BEEN MAINTAINED ALSO TO MINIMIZE SCALE ACCUMULATION  AND PLUGGING, THIS
                         HAS INCLUDED MASHING OF THE MET FAN WHICH HAS  RESULTED IN A STACK MIST
                         PROBLEM.  THE USE OF SOOT BLOWERS IN PLACE OF  WASHING MAS ATTEMPTED BUT
                         HAS UNSUCCESSFUL.  THE UTILITY HAS REDUCED THE AMOUNT Or HASHIUS AH3 HAS
                         CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEH LOU-VELOCITY
                         STACK.
                         THE FROSLEMS AT SYL LASKIN ARE NOT AS SEVERE AS  THE PHC9LEMS AT CLAY
                         BOSWcLL DUE TO THE FACT THAT THE RECYCLE LOOP  IS NOT  CLOSED TO THE SAME
                         EXTENT.  THE MIST CARRYOVER PROBLEM IS  LESS SEVEPE OWING TO OPERATION
                         OF THE UNIT AT PARTIAL LOAD RESULTING IN A LOWER STACK VELOCITY.
10/79  SYSTEM
11/79  SYSTEM                                                                720

12/79  SYSTEM                                                                744

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION HAS AVAILABLE FOR  THE  FOURTH QUARTER  1979.

 1/80  SYSTEM                                                                74*

 2/80  SYSTEM                                                                696

 3/80  SYSTEM                                                                744

       *"• FRCBLEMS/SOLUTIONS/COMMENTS

                         THE UTILITY  REPORTED  THAT THE SCRUBBER  EXPERIENCED NO  PROBLEMS  DURING  THE
                         1ST QUARTER  OF 1980.
 */80  SYSTEM

 5/80  SYSTEM

 6/80  SYSTEM

       »» PROBLEMS/SOLUTIONS/COMMENTS
                             720

                             74*

                             720
                         THE UTILITY REPORTED  THAT NO  SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
                         SECOND QUARTER OF  1980.  DOWN TIME FOR MAINTENANCE WAS HOT REQUIRED SINCE
                         GENERAL MAINTENANCE CAN  BE  PERFORMED ON THE MINNESOTA POWER AND  LIGHT PAR-
                                               918

-------
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
26.3
76.0
70.8
                                              EPA UTILITY FGO SURVEY:  OCTOBER - DECEIVES 1931

MINNESOTA POWER S LIGHT:  SYL LASKIN 2 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X PEMOVAL   PER  BOILER  FG3   CiP.
                                                                S02  PART.  HOURS HG'JRS  I-OL~S FACTC"

                         TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.

 7/80  SYSTEM     100.0       100.0       100.0        24.5                  744   162    132  12.3

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER DID NOT OPERATE MOST OF JULY DUE TO A BOILER INSPECTION.  NO
                         PROBLEMS MERE ENCOUNTERED WITH THE FGD UNIT.

 e/60  SYSTEM     100.0       100.0       100.0        15.0                  744   115    115   5.0

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER OPERATED ONLY 115 HOURS DURINS AUGUST DUE TO A LACK OF DEMAND.

 9/80  SYSTEM     100.0       100.0       100.0         5.2                  720    39     39   2.4

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORT THAT NO SCRUBBER OUTAGES OCCUPIED DURINS SEPTEMBER.
                         THE LOW UTILIZATION FACTOR RESULTED FROM A LACK OF DEMAND FOR
                       - POUER.

                                                                             744   195    195  15.0

                                                                             720   547    547  37.2

                                                                             744   527    527  34.9

       *« PRCBLEMS/SOLUTIONS/CCMMENTS

                         THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS WERE ENCOUNTERED
                         DURING THE FOURTH QUARTER.

 1/61  SYSTEM     100.0       100.0       100.0        45.3                  744   337    337  23.8

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         DURINS JANUARY THE BOILER MAS OUT OF SERVICE APPROXIMATELY 407 HOURS DUE
                         TO A LACK OF POWER DEMAND.

 2/81  SYSTEM     100.0       100.0       100.0        97.4                  672   653    653  28.5

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING FEBRUARY THE UTILITY REPORTED THAT NO SCRUBBER-RELATED FR03LEMS
                         OCCURRED.

 3/81  SYSTEM     100.0                                   .0                  744     0      0     .0

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING MARCH THE BOILER MAS OUT OF SERVICE TO FIND THE CAUSE OF A TURBINE
                         VIBRATION.

 4/61  SYSTEM      88.2       100.0       100.0        56.4                  720   406    406  £6.9

       *« FROBLEMS/SOLUTIONS/COMMENTS

                         DURINS APRIL 229 HOURS OF DOWN TIME MAS DUE TO A  LACK OF DEMAND.

                         THE UNIT MAS DOWN 109 HOURS FOR A BEARING CHECK AND REPAIR DUE TO HIGH
                         VIBRATION.

 5/81  SYSTEM      94.1       100.0       100.0        55.0                  744   409    409  28.7
                                               919

-------
 EPA UTILITY FGO SURVEY: OCTOBER - OKI" ~°. i981

MINNESOTA POWER S LIGHT: SYL LASKIN Z ICONT.l
	PERFORMANCE DATA	
PERIOD tlCDULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATIOM  X REMOVAL   FEP  BOILER  FGO   CiP.
                                                                S02  PART. HCL'RS HCUPS  HCUP.S FACTCR


       *« PROBLEMS/SOLUTICN5/CCMMENTS

                         THE BOILER HAS OFF-LINE APPROXIMATELY 210 HOURS IN MAY DUE TO A LACK OF
                         DEMAMD.

                         FOLLOWING A TEST CONDUCTED IN JUNE THE UNIT MAS SHUTCCVIN FC3 SAHD3LASTIMG
                         THE ID FANS.

 6/81  SYSTEM     100.0                                  .0                  720     0      0

       ** PRCBLEHS/SOLUTICNS/COMnENTS

                         DURING JUNE THE UNIT WAS OFF-LINE DUE TO A LACK OF DEMAND.  CURING THIS
                         PERIOD GENERAL MAINTENANCE HAS PERFORMED.
                                               920

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

                                           SECTION 14
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCIL'EEEKS
CCflPANY NAME
PLANT NAME
L'MIT NUMBER
CITY
S.ATE
PECULATOR CLASSIFICATION
PAOTICULATE EMISSION LIMITATION - NG/J
£02 EMISSION LIMITATION - NG/J
HOX EMISSIC'l LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - KM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY HO/FGD - KW
EQUIVALENT SCRUBBED CAPACITY - KM

 ** UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     EOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLCM - CU.tl/S
     EOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 •Ht FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - '/.
     RANGE MOISTURE CONTENT - V.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

»*» PARTICLE CONTROL

 «» KECHANICAL COLLECTOR
     NUMBER
     TYPE
     SUPPLIER
     INLET PLUS GAS CAPACITY - CU.M/S
     INLET FLUE GAS TEMPERATURE - C
     PRESSURE CROP - KFA
     PARTICLE REMOVAL EFFICENCY -X

 »« ESP

 *» PARTICLE SCRUSBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON HAKE
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIPCL'LATIOH RATE - LITER/3
     L/G RATIO - LITER/CD.M
     PH CONTROL ADDITIVE
     PRESSURE DROP - KPA
     INLET GAS FLOW RATE - CU.M/S
MONTANA-DAKOTA UTILITIES
LEWIS & CLA"!K
1
SIDNEY
MONTANA
E
   86.         (
  433.         (
******
                  .:oo
                 1.003 LB/MM3TU1
               (**»*** L3/Mr-.3TU)
   50
   55
   50
   52
   55
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
  153.37
  215.6
   76.
NONE
    4.4
               (  325000 ACFM)
               (  423 F)
               (  250 FT)

               (  14.5 FT>
               (  6450 BTU/LB)
                6200-6700
COAL
LIGNITE
15003.

    7.80
7.2-9.3
   36.20
34.3-38.2
     .61
0.3-1.4
     .03
MULTICLONES
WESTERN PREC. DIVISION, JOY
  106.2        ( 2=5000 ACFM)
  176.7        (  350 F)
     .4        (  1. IN-H20)
   85.7
VENTURI TOMER
VARIABLE-THROAT/BOTTOM-ENTHY LIQUID DISTRIBUTION
FLOODED DISC SCRUBBER
RESEARCH-COTTRELL
10.5 OIA X 27.0
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NONE
  212.6
    1.7
LIMESTONE
    3.2
  148.0
               ( 3374 GPM)
               (13.0 GAL/1000ACF)

               (13.0 IN-H20)
               ( 313730 ACFM)
                                               921

-------
 EPi UTILITY FG3 SURVEY:  OCTOBER - DECEMBER 1981

M3NTANA-OAKOTA UTILITIES: LEWIS £ CLARK 1 (CCNT.)

     INLET GAS TEMPEPATU?E - C                    215.6        (   420  F )
     ENERGY CQNSUflPTICN - 7.                         3.6
	PERFORMANCE DATA	
FERIC3 M02ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PE1?  BOILER  FG3   CAP.
                                                                S02   PART.  HO'J'S HOL'^S  KOU~S FACT03


10/79  SYSTEM                                                                720

       <•* FRC3LEMS/SCLUTION5/COMMENTS

                         DURING A SCHEDULED BOILER OUTAGE GENERAL SCRUBBER  MAINTENANCE MAS
                         PERFORMED.

11/79  SYSTEM                                                                720

       «* PROSLEMS/SOLUTIONS/COMMENTS

                         DURING NOVEMBER THE SCRUBBER UAS TEMPORARILY BYPASSED  TO ALLOW FOR REPAIPS
                         NECESSITATED BY A LEAK IN THE FLOODED DISC  SCRU33ES.

12/79  SYSTEM                                                                744

       ** PP03LEMS/SOLUTICNS/COMMENTS

                         THE  UTILITY REPORTED THAT NO SCRUBBER PROBLEMS  OCCURRED DURING DECEMBER.

 1/80  SYSTEM                                                                744

 2/80  SYSTEM                                                                696

 3/80  SYSTEM                                                                744

       *» FSCBLEMS/SOLUTIONS/COMMEHTS

                         DURING THE  JANUARY THROUGH MARCH PERIOD THE SCRUBBER UAS AVAILABLE MORE
                         THAN 95X OF THE TIME.

                         THE  EROSION PROBLEM MENTIONED DURING NOVEMBER CONTINUED.  SECTIONS OF THE
                         EXTERIOR CARBON STEEL LINED COLUMN WALL SUPPORTING THE FLOODED DISC WERE
                         ERODING. FILLING THE INNER CHAMBER WITH SLUPRY  AND ULTIMATELY PENDERIN'S THE
                         DISC MOVEMENT MECHANISM INOPERATIVE.   THE UTILITY  HAS  MANAGED TO KEEP THE
                         SCRUBBER OPERATING AS A STOP-GAP MEASURE BETWEEN UNIT  SHUTDOWNS BY INSERT-
                         ING  A GARDEN HOSE IN THE COLUMN HOLES AND CONTINUALLY  FLUSHING THE INNER
                         CHAMBER. THE UTILITY HAS HAD SOME SUCCESS  IN OTHER EROSICN  APEAS BY
                         MAKING REPAIRS WITH A HASTELLOY MATERIAL.  PLANS ARE BEING MADE TO JACKET
                         THE  ENTIRE  DISC SUPPORT COLUMN WITH HASTELLOY G.

 4/80  SYSTEM                                                                720

 5/80  SYSTEM                                                                744

 6/80  SYSTEM                                                               720

       »« PROaLEMS/SOLUTIONS/COMHENTS

                         THE  BOILER  WAS SHUT DOWN FOR TWO WEEKS IN MAY.

                         CREWS INSPECTING THE SCRUBBING SYSTEM DISCOVERED THAT  THE NIME FCOT SCRUB-
                         BER  LINER SECTION AT THE BOTTOM OF THE CYCLONIC MIST ELIMINATOR WtS SEVE=E-
                         LY EPRODEO.   THE LINER HAS LASTED THREE YEARS.  THE UTILITY  CONSICEPS THIS
                         A NORMAL MAINTENANCE PROBLEM.   AT ONE TIME  LINERS  IN THIS SECTION WE=E RE-
                         PLACED EVERY SIX MONTHS.  REPLACEMENT WORK  ON THE  LATEST FAILURE IS EXPECT-
                         ED TO BEGIN BY JULY 21.

                         THE  ENTIRE  SCRUBBER COLUMN SUPPORTING THE DISC  WHICH WAS ERODING AS REPORT-
                         ED DURING THE PREVIOUS TWO QUARTERS HAS BEEN CLAD  WITH HASTELLOY G.
                                               922

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1'Sl

rONTANA-OAKOTA UTILITIES:  LEWIS S CLARK 1  (COHT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OFEHABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  ?33   CAP.
                                                                S02  PART.  HOURS HC-'.S  HOURS FACTOR

                         THE UTILITY REPORTED THAT THE SCRUBBER HAS EXPERIENCED PLL'33IH3 AT WET/3?Y
                         INTERFACES WITHIN  THE STRUCTURE.   IT APPEARS THAT  THIS IS RELATED T3 CCAL
                         SULFUR CONTENT.  WHEN THE SULFUR  CONTENT IS RELATIVELY HISH (0.7 TO l.C/: AT
                         LEWIS AND CLARK) THE PLUGGING DOES NOT OCCUR.  LIMESTONE IS AC3ED AS RE-
                         QUIRED TO PREVENT  THE OCCURRANCE  OF LOW FH LEVELS.  WHEN THE SULrU= CCNTS'IT
                         FALLS TO THE 0.3X  PAUSE THE PH RISES AS A RESULT OF THE ALKALINE CCIISTITU-
                         EHTS IN THE FLY ASH UNTIL SOFT SCALE PLUGGING RESULTS.  THE UTILITY HAS
                         CONSIDERED ADDING  ACID TO STABILIZE THE PH WHEN THE COAL SULFUR CONTENT
                         DROPS.

 7/80  SYSTEM                                                                744

       *» PROBLEMS/SOLUTIONS/CCMMENTS

                         DURING JULY TWO WEEKS OF DOWN TIME WAS NECESSARY TO REPLACE THE MIST
                         ELIMINATOR LINER.

                         THE PPCBLEM WITH  THE FLOODED DISC BUILDUP MENTIONED EARLIER CONTINUED.
                         THE UTILITY PERFORMS THE NECESSARY REPAIRS IN THREE TO FOUR HGU3S WHEN
                         THIS OCCURS.

 8/80  SYSTEM                                                                ~44

 9/80  SYSTEM                                                                "20

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH SMU3SIN3
                         OPERATIONS DURING THE MONTHS OF AUGUST AND SEPTEMBER.

10/80  SYSTEM                                                                744

11/80  SYSTEM                                                                720

12/80  SYSTEM                                                                744

       »« PR03LEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH THE
                         SCRUBBING OPERATIONS DURING THE OCTOBER THROUGH DECEMBER PERIOD.

                         SCRUBBING OPERATIONS WERE SHUTDOWN FOR ONE WEEK DURING THE LAST PART OF
                         OCTOBER FOR A SCHEDULED MAINTENANCE OVERHAUL AND NO PP03LEMS WERE FOUND.

 1/81  SYSTEM                                                                744

       «* FROSLEMS/SOLUTIOHS/COMMENTS

                         THE UTILITY REPORTED THAT NO MAJOR SCRUBBER PROBLEMS OCCURRED DURING
                         JANUARY.

 2/81  SYSTEM                                                                672

       ** PRC9LEHS/SOLUTICN3/COMMENTS

                         CM FEBRUARY 10 THE  SCRUBBER WAS SHUT DOWN FOR FIVE HOURS DUE TO A PLUGGED
                         VENTURI.

                         OH FEBRUARY 23 A  LEAK WAS DISCOVERED ON THE t  f£R WALL OF THE SCRUBBER,
                          LOCATED BELOW THE VENTURI.  THE  LEAK WAS  TEMPORARILY REPAIRED F.=CM THE
                         OUTSIDE WHILE THE SCRUBBER  REMAINED ON-LINE.  THE UTILITY PLANNED TO REPAIR
                         THE  LEAK DURING THE SCHEDULED  OUTAGE IN MARCH.

 3/81  SYSTEM                                                                744
                                                923

-------
 EPA UTILITY FGD SU=VEV: CC7C3E3 - DECEMBER 1981

MONTANA-DAKOTA UTILITIES: LEWIS t CLARK 1 (CONT.)
	PERFORMANCE DATA	
PERIOD HC3ULE AVAILABILITY CFERA3ILITY RELIABILITY UTILIZATICN  X REMOVAL   PER  BCILER  ?GD   CA=.
                                                                S02  PART. HO'JSS HOURS  HCL'SS FACTOR


       «» FHC3LEMS/SOLUTIC^;S/CC^;nE!ITS

                         THE SCHEDULED OUTAGE PERIOD WAS HELD FROM MARCH 3 TO 15.  DURING THIS TIKE
                         THE VEHTU3I AND SUMP HERE INSPECTED.  THE LEAK DISCOVERED EARLIER IN FEB-
                         RUARY MAS REPAIRED CORRECTLY.
                                               924

-------
                                              EPA UTILITY F63 SURVEY: CCT03ER - DECEMBER 1931

                                           SECTION 14
                  DESIGN AND PERFORMANCE DATA FOR OPEPATICNAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
£02 EMISSION LIMITATION - NG/J
HOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 «« UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 ** FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - V.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTUSE CONTENT - X
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

*»* PARTICLE CONTROL

 «» PARTICLE SCRUBBER
     NUM3ER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC IATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     LIQUID RECIRCULATION RATE - LITER/S
     L/G RATIO - LITER/CU.M
     PH CONTROL ADDITIVE
     PRESSURE DROP - KPA
     INLET GAS FLCVt RATE - CU.M/S
     INLET GAS TEMPERATURE - C
     S02 REMOVAL EFFICENCY - X
     PARTICLE REMOVAL EFFICIENCY - X
     ENERGY CONSUMPTION - X
PACIFIC FC'rJEP t LIGHT
DAVE JOHNSTON
4
GLEN90CK
WYOMING
0
   90.
  215.
*»•«***
               (   .210 LB/W.3TU)
               (   .500 LB/rrSTU)
               (•«***** LB/MMSTU)
*****
  330
  3C7
  330
  330
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
  707.85       (1500000 ACFM)
  132.2        ( 270 F)
   76.         ( 250 FT)
******
*******        (***** FT)
               (  7430 BTU/L3)
                5000-9000
COAL
SU3BITUMINOUS
17282.

   12.00
******
   26.00
******
     .50
******
     .04
******
 3
 4/72
VENTUHI TOWER
VARIABLE-THROAT/TOP-ENTHY PLUMB BOS
N/A
GE ENVIRONMENTAL SERVICES
CAPBON STEEL
AISI 1110
ORGANIC
POLYESTER
N/A
  409.5        ( 6500 GPM)
    1.7        (13.0 GAL/1000ACF)
LIME/ALKALINE FLYASH
    2.5        (10.0 IH-HSO)
  327.5        ( 694000 ACFM)
  135.0        (  275 F)
   40.0
   99.7
     .9
                                               925

-------
 EPA UTILITY FGD SL'=VEY: OCTOBER - DECEMBER 1981

PACIFIC POWER I LIGHT: DAVE JOHNSTON 4 (CCNT.)
			PERFORMANCE DATA			
PESIC3 KC3ULE AVAILABILITY CPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PE=>  BOILER  FED   CAP.
                                                                S02  PART. HOL'=S HOJ?S  HCtPS FACTOR


 4/72  SYSTEM

       ••» PRCBLEMS/SOLUTIONS/COMMENTS

                         5IMCS STARTUP IN APRIL 197Z, THE SCRUBBING UNIT HAS EXPERIENCED MAJOR
                         SCALING PROBLEMS.  HARD GYPSUM SCALE ACCUMULATES IN THE SC^U35E
-------
                                              EPA UTILITY F60 SURVEY: OCTOBER - DECEMBER 1°31

PACIFIC POWER I LIGHT: DAVE JOHNSTON 4 (CONT.)
	PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  SOILED  FC-D   CAP.
                                                                SOZ  PART. HC'JPS HO'JSS  HOL-'S FACTC


       *« PROBLEMS/SOLUTIONS/COniENTS

                         THE UTILITY REPORTED THAT NO MAJOR PROBLEMS HERE ENCOUNTERED WITH THE
                         SCRUBBING OPERATIONS DURING THE OCTOBER THROUGH DECEMBER FESIC3.

 1/81  SYSTEM                                                                744

 2/81  SYSTEM                                                                672

 3/81  SYSTEM                                                                744

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION HAS AVAILABLE FOR THE FIRST QUARTER 1981.

-------
 EPA UTILITY FGD SURVEY: OCTC3ER - DECEMBER 1981
                                           SECTION 14
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
FEuULATORY CLASSIFICATION
PATriC'JLATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
H3X EMISSION LIMITATION - NS/J
NET PLANT GENERATING CAPACITY - KVI
G5CS5 UNIT GEHE°ATIHG CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY HO/FGD - MW
EQUIVALENT SCRU33EO CAPACITY - MM

 *» UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     E'-ILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M
                  POTOMAC ELECTRIC POWER
                  OICKERSON
                  DICKERSON
                  MARYLAND
                  ******
                  ******
                  ******
                  ******
                   1348
                    190
                    183
                  *****
                    190
        I****** LB/MMBTU)
        (**•*»** L3/MMBTU)
        (****** LB/MM3TU)
                  COMBUSTION ENGINEERING
                  PULVERIZED COAL
                  ******
                  ********       (****»** ACFM)
                  *******        ( **»* p)
                    213.         1  700 FT)
                  CONCRETE
                  *******        (***•** FT)
 *» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - '/.
     RANGE CHLORIDE CONTENT - X

*** PARTICLE CONTROL

 M ES»
     TYPE

 *» PARTICLE SCRUBBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
                  COAL
                  ******
                  27214.         ( 11700 BTU/LB)
                                  ******
                     14.00
                  ******
                  *******»
                  6.0-7.0
                      2.00
                  ******
                  ********
                  ******
                  COLD SIDE
                   0/78
                  VENTUHI TOWER
                  VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
                  N/A
                  CARBON STEEL
                  AISI 1110
                  NONE
                   2
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART. HOURS HOURS  HOURS FACTOR
10/79  SYSTEM

11/79  SYSTEM

12/79  SYSTEM
100.0

 96.0

100.0
83.6

80.1

87.4
744   622

720   601

744   650
62C

577

650
                                               928

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - DECEM3ER 1931

POTOMAC ELECTRIC POWER: OICKERSON 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PE°  BOILER  FGD   CA?.
                                                                S02  PART. HOL-SS HCL'SS  riO'JSS FACTC"


       »* PROSLEMS/SOLUTZOMS/COMMENTS

                         DURING THIS PERIOD ONLY ONE SCRUBSER RELATED OUTAGE OCCL'PRED.  THE CUTAGE
                         MAS FCR AN ID FAN INSPECTION WHICH LASTED ONE DAY.

 1/80  SYSTEM     100.0       100.0                   100.0                  744   744    744

 2/80  SYSTEM      94.3        95.8                    94.3                  696   665    656

 3/80  SYSTEM     100.0       100.0                   100.0                  744   744    744

       *« FROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE FIRST QUARTER OF 1980 ONLY CHE SCRUBBER OUTAGE CCCUSPED.  IN
                         FEBRUARY OUTAGE TIME MAS NECESSARY TO REPAIR A SLURRY RECYCLE LINE LEAK.

 4/80  SYSTEM                                                                720

 5/30  SYSTEM                                                                744

 6/80  SYSTEM                                                                720

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         OICKERSON 1 SCRUBBER DEPENDABILITY FACTORS MERE UNAVAILABLE FOR THE APRIL-
                         JUNE PERIOD.  THESE FIGURES SHOULD BE AVAILABLE BY THE THIRD QUARTER
                         REPORT.  THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED THE ENTISE
                         SECOND QUARTER WITH ESSENTIALLY 100X AVAILABILITY.  NO,SCHU25ER-RELATED
                         PROBLEMS MERE REPORTED.

 7/80  SYSTEM                                                                744

 8/80  SYSTEM                                                                744

 9/80  SYSTEM                                                                720

       *» PRCBLEMS/SOLUTIONS/COKMENTS

                         THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS CLAIMS THE
                         JULY-SEPTEMBER PERIOD.

                         THE BOILER CAPACITY MAS REDUCED DURING PART OF THE PERIOD DUE TO A LINING
                         FAILURE IN THE SCRUBBING SYSTEM PIPING.

lO/SO  SYSTEM                                                                744

IT/80  SYSTEM                                                                720

12/80  SYSTEM                                                                744

       «« PR03LEMS/SOLUTIONS/COMMENTS

                         DURING THE OCTOBER THROUGH DECEMBER PERIOD THE BOILER MAS OPERATED AT A
                         60X (110 MM) CAPACITY DUE TO A LINING FAILURE IN THE SCRL3BIIIS SYSTEM
                         PIPING.

 1/81  SYSTEM      97.0        88.1        91.9        82.1                  744   694    611

       *» PROBLEMS/SOLUTIONS/COKMENTS

                         DURING JANUARY APPROXIMATELY 53 HOURS OF OUTAGE TIKE MAS CAUSED BY PRC3LEKS
                         WITH THE RECYCLE LINE REDUCER AND THE BLEED LINE SPOOL.

 2/81  SYSTEM        .0                                  .0                  672     0      0
                                               929

-------
 EPA UTILITY FGD SUPVEY:  CCT03ER - DECEMBER 1981

POTCMAC ELECTRIC PCWER:  DICKEHSCN 1 (COHT.)
	PERFORMANCE DATA	
PERIC3 MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER   BOILE*  FGD   CAP.
                                                                S02  FART.  HG'jaS HOU3S  HCU=S FACTOR


 3/fil  SYSTEH        .0                                  .0                  7*4     0      0

       ** FROSLEMS/SOLUTICMS/'COmENTS

                         DICKERSCN UNITS 1,  2 AND 3 ME=E SHUT COWN SO THAT  THE STACK AND THE COMMON
                         DUCT LEADING TO THE STACK CCULD BE PELIMED WITH  PLASITE.   UNIT 1 HAS SHUT
                         DOWN ON JANUARY 31  AND REMAINED DCMN THROUGHOUT  FEBRUARY AND MARCH DUE TO
                         THESE REPAIRS.
                                               930

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - OECEM2ER 1931

                                           SECTION 14
                  DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUE3ERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOC EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - N3/J
NrT PLANT GENERATING CAPACITY - MM
G^OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATINS CAPACITY U/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - KM

 x» UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 «» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/6
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - V.
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUB CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

*** PARTICLE CONTROL

 *» ESP
     TYPE

 »» PARTICLE SCRUSBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
                  POTOMAC ELECTRIC POWER
                  DICKERSON
                  DICKEHSON
                  MARYLAND
                  ******
                  ******
                  ******
                  *»•***»
                   1348
                    190
                    103
                  ******
                    190
               (**»*** LB/MM3TU)
               (****** LB/MKSTU)
               (****** LB/MM3TU)
                  COMBUSTION ENGINEERING
                  PULVERIZED COAL
                  ******
                  ********       (******* ACFM)
                  *******        (<•«** F )
                    213.         (  700 FT)
                  CONCRETE
                  *******        («**»* FT)
                                 (  11700 BTU/LB)
                                  ******
COAL
**»**•
27214.

   14.00

********
6.0-7.0
    2.00
******
******<(*
******
                  COLO SIDE
                   0/78
                  VENTURI TOMER
                  VARIABLE-THROAT/TOP-ENTRY PLUMB BC3
                  N/A
                  CARBON STEEL
                  AISI 1110
                  NONE
                   Z
	PERFORMANCE DATA			
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FED   CAP.
                                                                S02  PART.  HOURS HOUPS  HOU3S FACTOR
10/79  SYSTEM

11/79  SYSTEM

12/79  SYSTEM
100.0

 96.4

100.0
       97.0

       88.9

      100.0
744   722

720   664

744   744
722

640

744
                                               931

-------
 EPA UTILITY FGO  SURVEY:  CCTC3ER  -  DECEMBER  1981

POTOMAC ELECTRIC  FOVJER: DICKEPSON 2 (CONT. )
	PERFORMANCE  DATA	
PEHIC3 K03ULE A"AILABILITY  OPERABILITY  RELIABILITY UTILIZATION   X FEMOVAL   PER   BOILES   FC-3    CAP.
                                                                S32  PART. HOUPS  HOURS   HCL^S FACTOR


       ** PRGBLEMS/SOLUTICNS/COMMEHTS

                         A  CHE  DAY  OUTAGE OCCURRED. DUE  TO  A  FAN LIMING PROBLEM.  NO  OTHER
                         SCSUB3ER UNIT  PROBLEMS HERE ENCOUNTERED DURING THE PERIOD.

 1/60  SYSTEM      95.*        96.*                   95.*                  7**    736    710

       ** PROBLEMS/SOLUTICNS/COMMENTS

                         IN JANUARY THE SCRUBBER HAS DOWN FOR THREE HOURS TO  REPAIR A SLURRY
                         RECYCLE  LINE LEAK.

                         31 HOURS OF THE OUTAGE TIME IN  JANUARY  HAS NECESSARY TO  REPAIR  A RECYCLE
                         PUMP.

 2/80  SYSTEM     100.0      100.0                   100.0                  696    696    696

 3/80  SYSTEM      96.9        96.9                   96.9                  74*    7**    721

       «» PROBLEMS/SOLUTIOKS/CCMMEHTS

                         IN MARCH THE SCRUBBER MAS DOWN  FOR A SCRUBBER LINING WARRANTY INSPECTION.
                         NO REPAIR  UCRK MAS  NECESSARY.

 4/80  SYSTEM                                                                720

 5/80  SYSTEM                                                                7**

 6/80  SYSTEM                                                                720

       *» PROBLEMS/SOLUTIONS/CCMMENTS

                         DICKEPSON  2 SCRUBBER DEPENDABILITY FACTORS WERE UNAVAILABLE  FOR THE  APRIL-
                         JUNE PERIOD.   THESE FIGURES SHOULD BE AVAILABLE BY THE THIRD QUARTER
                         REFCST.  THE UTILITY REPORTED THAT THE  FGO SYSTEM OPERATED THE  ENTIRE
                         SECOND QUARTER WITH ESSENTIALLY 100X AVAILABILITY.   NO SCRUBBER-RELATED
                         PROBLEMS MERE  REPORTED.

 7/80  SYSTEM                                                                7**

 8/80  SYSTEM                                                                7**

 9/80  SYSTEM                                                                720

       »» PROBLEMS/SOLUTIOHS/COMMENTS

                         THE UTILITY HAS NOT FIGURED OUT THE  DEPENDABILITY FIGURES  AS YET.

                         THE UTILITY REPORTED HAVING MINIMAL  SCRUBBING SYSTEM PROBLEMS DURING THE
                         JULY-SEPTEMBER PERIOD.

                         THE BOILER CAPACITY MAS PEOUCED DURING  PART OF THE PERIOD DUE TO A LINING
                         FAILURE  IN THE SCRUBBING SYSTEM PIPING.

10/80  SYSTEM                                                                7**

11/80  SYSTEM                                                                720

12/80  SYSTEM                                                                7**
                                               932

-------
                                              fA. UTILITY FG3 SURVEY: OCTOBER - DECEMBER 1931

POTOMAC ELECTRIC POUEP:  OICKERSOH 2 CCONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   FES  BOILER  FG3   CAP.
                                                                SOS  PART. HOL'-S KC'J'S  KC'J?S FACTC3


       •» PR03LEMS/50LUTIONS/COKMENTS

                         DURING THE OCTOBER THROUGH DECEMBER PERIOD THE EOILER MAS OPERATED AT A
                         60X (110 MM) CAPACITY DUE TO A LINING FAILURE IN THE SC3U3BIN3 SI STEM
                         PIPING.

 1/81  SYSTEM      96.9        92.6       100.0        61.9                  744   654    607

 2/81  SYSTEM        .0                                  .0                  672     0      0

 3/81  SYSTEM        .0                                  .0                  744     0      0

       ** PRC3LEMS/SOLUTIONS/CCMMENTS

                         DICKERSOM UNITS 1. 2 AND 3 HERE SHUT OOV1N SO THAT THE STACK At.'D THE CCM::CN
                         DUCT LEADING TO THE STACK COULD BE RE LIKED WITH PLASITE.  UNIT Z WAS SHUT
                         DOWN ON JANUARY 31 AND REMAINED DCMN THROUGHOUT FESRUARY AND MARCH DUE TO
                         THESE REPAIRS.
                                                933

-------
 EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981
                                           SECTION 14
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PAPTICLE SCFU5BERS
COMPANY HAKE
PLANT NAr=
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATICN - NG/J
NOX EMISSION LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - MM
G'OSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGO - MW
NET UNIT GENERATING CAPACITY UO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 ** UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SEPVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.tt/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 *» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RAUSE ASH CONTENT - 7.
     AVERAGE MOISTUPE CONTENT - X
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     PANGE SULFUR CONTENT - 7.
     AVEPAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - 7.
POTOMAC ELECTRIC POWER
DICKERSON
DICKERSON
MARYLAND
******
***•«**
  688.
******
  543
  190
  178
  182
   95
(*»**»* LB/MM3TU)
(  1.600 LB/KM3TU)
(****** LS/KM3TU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
  278.42       ( 590000 ACFM)
  126.1        ( £59 F)
  213.         ( 700 FT)
CONCRETE
*******        (***** FT)
COAL
BITUMINOUS
27214.

   14.00
******
********
6.0-7.0
    2.00
******
********
******
(  11700 BTU/LB)
**» PARTICLE CONTROL

 v* MECHANICAL COLLECTOR
     HUKSER
     TYPE

 »* FABRIC FILTER
     NUMBER
     TYPE

 t* PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     L/G RATIO - LITER/CU.M
     PRESSURE DROP - KPA
     INLET GAS FLC'rl RATE - CU.M/S
     INLET GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICIENCY - 7.
     ENERGY CONSUMPTION - 7.
 0
NONE
 0
NONE
 1
 9/75
VENTURI TOWER
VARIABLE-THROAT/TCP-ENTRY PLUM3 BOB
N/A
GE ENVIRONMENTAL SERVICES
CARBON STEEL
AISI 1110
FIBER-REINFORCED POLYESTER
NONE
    2.7        CO.O GAL/1000ACF)
    2.7        (11.0 IN-H20)
  139.2        ( 295000 ACFM)
  126.1        (  259 F)
   99.0
    2.1
                                               934

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEK2EH 19S1

POTOMAC ELECTRIC FCWER: OICKERSCN 3 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PE<3  BOILER  FGD   CAP.
                                                                S02  PAPT. HOL'PS HCU=S  HO'.PS FAC"R


 9/73  SYSTEM                                                                720

10/73  SYSTEM                                                                744

11/73  SYSTEM                                                                720

12/73  SYSTEM                                                                7**

 1/74  SYSTEM                                                                7**

       ** PRCBLEMS/SOLUTIONS/COMMENTS

                         PROBLEMS DURING THIS PERIOD RANGED FROM CCRRCSICN LEAKS IN EXPANSION JOINTS
                         TO PROBLEMS IN MATERIAL HANDLING EQUIPMENT, FEEDIN3 AND SLAKING CF r.SQ,
                         PLL'GSiriS IN THE MGO MIX TAW AND SUCTION LINES TO THE MGO MAKE-UP PUKFS.

 2/7*  SYSTEM                                                                672

 3/74  SYSTEM                                                                744

 4/74  SYSTEM                                                                720

 4/74  SYSTEM                                                                720

       *» PHOBLEMS/SOLUTIONS/COMMENTS

                         MAINTENANCE AND MODIFICATIONS MERE PERFORMED ON THE SYSTEM.  THE MAJOR
                         SYSTEM REVISION MADE DURING THIS PERIOD MAS THE ADDITION CF A FRE-HIX TANK
                         IN THE MSO SYSTEM.

 5/74  SYSTEM                                                                744

 6/74  SYSTEM                                                                720

 7/74  SYSTEM                                                                744

       «» PROBLEMS/SOLUTIONS/COMMENTS

                         LIMITED OPERATION OCCURRED BECAUSE THE UTILITY DID NOT HAVE ACCESS TO THE
                         EPA CALCINING FACILITY AT THE ESSEX CHEMICAL COMPANY SULFURIC ACID PLANT.
                         BY THE END OF JUNE 1974. ALL THE MGO AT DICKERSCN HAD BEEN USED AND A SILO
                         PLUS THREE CARS MERE FULL OF MGS03.

 8/74  SYSTEM                                                                744           87

 9/74  SYSTEM                                                                720

10/74  SYSTEM                                                                744
 2,
11/74  SYSTEM                                                                720

12/74  SYSTEM                                                                744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THIS PERIOD THE SYSTEM GENERALLY OPERATED AT 75 PERCENT CF THE
                         DESIGN GAS FLOW.

 1/75  SYSTEM                                                                744
                                               935

-------
 EPA UTILITY FGO SURVEY:  CCT03ER - DECEMBER 1981

POTOMAC ELECTRIC POWER: OICKERSCN 3 (CONT. )
		PERFORMANCE  DATA	
PEPIC3 MC2ULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X REMOVAL   PER  BOILER   FGD    CAP.
                                                                502  PART. HOURS HOURS  HQ-3S  FACTCR


       ** PROBLEMS/SOLLTICNS/COMMENTS

                         PPCBLEMS DEVELOPED IN THE  BUCKET ELEVATOR TRANSPORTING THE MGSC3 FROM THE
                         CRYER  TO THE STORAGE  SILO.

 2/75  SYSTEM                                                               672

 3/75  SYSTEM                                                               7*4

 4/75  SYSTEM                                                               720

 5/75  SYSTEM                                                               744

 6/75  SYSTEM                                                               7CO

 7/75  SYSTEM                                                               744

       ** PROBLEMS/SOLUTIONS/COMMEHTS

                         UNIT NO. 3 WAS TAKEN  OUT OF SERVICE  FOR AN 8 TO 12 KEEK TUPBINE  OVERHAUL.
                         THE SCRUBSER MAS INSPECTED, MAINTENANCE AND MODIFICATIONS WERE MADE.

 8/75  SYSTEM                                                               744

       ** PROBLEMS/SOLUTIONS/COMKENTS

                         THE FGD SYSTEM CONSISTS OF A  SINGLE, TWO-STAGE SCRUSSER/ABSC33ER,  WHICH
                         INCORPORATES AN ADJUSTABLE-THROAT  VENTURI SCRUBBER FOS.-JARTICULATE PE*!CVAL
                         AND A  SECOND STAGE ABSORBER WITH A FIXED VENTURI TO REMOVE S02.   THE  LIQUOR
                         STREAMS FOR BOTH STAGES ARE SEPARATE AND OPERATE IN A CLOSED-LOOP MCCE.
                         UNTIL  MID-1975 THE MAGNESIUM  SULF1TE GENERATED WAS TRANSFERRED TO AN  EPA
                         FINANCED FACILITY  AT  THE ESSEX CHEMICAL CCMPANY SULFURIC ACID MANUFACTURING
                         PLANT  IN RUMFORD,  RHODE ISLAND WHERE MAGNESIUM OXIDE WAS REGENERATED  AMD
                         SC2 FROM THE REGENERATION  PROCESS  WAS CONVERTED TO SULFURIC  ACID.  THE
                         RUMFCRO FACILITY HAS  SINCE BEEN CLOSED  DOW).

                         CONSTRUCTION MAS COMPLETED IN AUGUST AND THE SYSTEM STARTED  UP IN SEPTEMBER
                         1973.   DURING INTERMITTENT OPERATIONS FOR SHAKEDOWN THROUGH  JANUARY 1974,
                         THE SYSTEM'S LONGEST  CONTINUOUS RUN WAS 271 HOURS.  THE/SYSTEM HAS RE-
                         STARTED FROM JULY  THROUGH  DECEMBER 1974, AND AGAIN ON AUGUST 11,  1975, FC3
                         APPROXIMATELY 87 HOURS.

                         FGD UNIT OUTAGES WERE CAUSED  PRIMARILY  BY PIPE AMD PUMP CORROSION AND
                         MAJOR  TURBINE OVERHAUL OF  THE BOILER.   PARTICULATE AND S02 REMQVA.
                         EFFICIENCY GUARANTEES WERE CORROBORATED CURING OPERATIONAL PHASES.

                         THE FGD SYSTEM MAS RESTARTED  IN AUGUST.  STEAM WAS LOST TO THE KGO MIX
                         TANK,  RESULTING IN A  VERY  MOIST PRODUCT FROM THE CENTRIFUGE.  CAKIN3  IN THE
                         DRYER  OCCURRED.  AT THIS POINT, THE UTILITY DECIDED TO TEST  ONLY THE  FIRST-
                         STAGE  OF THE SCRUBBING SYSTEM.  TAKING GAS AHEAD OF THE PRECIPITATCR.   FGD
                         OPERATION AT DICKERSON TERMINATED  AT THIS POINT.

                         THE REMAINING SUPPLY  OF MAGNESIUM  OXIDE, ABOUT 100 TONS (10  DAYS), HAS
                         BEEN DEPLETED, AND THE DICKERSON UNIT HAS BEEN TERMINATED AS A FGD SYSTEM.

 9/75  SYSTEM                                                               720

10/75  SYSTEM                                                               744

11/75  SYSTEM                                                               720

12/75  SYSTEM                                                               744

 1/76  SYSTEM                                                               744
                                               936

-------
                                              EPA UTILITY FGD SURVEY: C"C3ER  - DECSr2i"  1"31

PCTCMAC ELECTRIC POWER:  OICKERSCN 3 (CONT.)
	PERFORMANCE DATA	
PE3ICD K30ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REnC-AL    FE3   EOIL:=   FGO    CAP.
                                                                S02   PAi«T. KCL'-S  HC'J=S  HC'-'S  FAC7C3


 2/76  SYSTEM                                                                 6«6

 3/76  SYSTEM                                                                 744

 4/76  SYSTEM                                                                 710

 5/76  SYSTEM                                                                 744

 6/76  SYSTEM                                                                 720

 7/76  SYSTEM                                                                 744

 fl/76  SYSTEM                                                                 744

 9/76  SYSTEM                                                                 7£0

10/76  SYSTEM                                                                 744

11/76  SYSTEM                                                                 720

12/76  SYSTEM                                                                 744

 1/77  SYSTEM                                                                 744

 2/77  SYSTEM                                                                 672

 3/77  SYSTEM                                                                 744

 4/77  SYSTEM                                                                 720

 5/77  SYSTEM                                                                 744

 6/77  SYSTEM                                                                 720

 7/77  SYSTEM                                                                 744

 8/77  SYSTEM                                                                 744

 9/77  SYSTEM                                                                 720

10/77  SYSTEM                                                                 744

11/77  SYSTEM                                                                 720

12/77  SYSTEM                                                                 744

 1/78  SYSTEM                             -                                   744

 2/78  SYSTEM      38.0        38.0                     38.0                   672    672     252

       *» PROBLEMS/SOLUTIONS/COKHENTS

                         THERE HAVE BEEN MANY  MAINTENANCE PROBLEMS  AND PROBLEMS WITH LINER FAILURES.
                         SINCE SHIFTING FROM S02  TO  PARTICULATE SCRUs3I!.'S ONLY, PLUESIK3 PRCSLE'IS
                         HAVE NOT  OCCURRED.  LCU  PH  HAS CAUSED  CCFKOSICN WHICH WAS AG:-3.V/ATE3  BY
                         PARTICULATE ERROSION.  THE  UTILITY  MILL FRC2ABLY FELINE  WITH A FLAKc  GLASS
                         TYPE LINER.   NO CHEMICALS (E.G. LIME I  ARE  ACDEO TO THE CIRCULATIN5 LI31C3
                         FOR PH BALANCE.

                         OUTAGE TIME MAS CAUSED BY LEAK REPAIRS IN  SLURRY PIPING.

 3/78  SYSTEM      21.0        22.0                     21.0                   744    717    156
                                                937

-------
 EPA UTILITY FED SLAVEY: CCTOSER - DECEMBER 1961

FQTCMAC ELECTRIC FO'^E?:  DICKEFSON 3 tCONT.)
	PERFORMANCE DATA	
FE"?IC3 MC^.ljLEl A/AIU3ILITY OFERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  20ILER  FGO   :A?.
                                                                502  PART.  HCUSS HOURS  HOU.
-------
                                              EPA UTILITY F6D SURVEY:  OCTOBER - DECEMBER 1981

POTOMAC ELECTRIC POWER:  OICKERSON 3 (CONT.)
	PERFORMANCE DATA		-	-
FERICO MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FG3   CAP.
                                                                S02  PART.  HO'JSS KCU?S  HC'JSS FAC7C3

                         UNIT REMAINS IN COMPLIANCE.
                         THERE HAVE BEEN HO PROBLEMS  REPORTED FOR THE LAST  FEW MONTHS.  THE UTILITY
                         IS KEEPING AHEAD OF PROBLEMS WITH A CONSCIENTIOUS  INSPECTION AND MAINTEN-
                         ANCE PROGRAM.

 6/79  SYSTEM                                                                720

 7/79  SYSTEM                                                                7*4

 8/79  SYSTEM                                                                744

 9/79  SYSTEM                                                                7£0

10/79  SYSTEM                  98.6                    95.*                  744   720    710

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         A TEN HOUR OUTAGE OCCURRED FOR REPAIRS OF A LEAD LINE LEAK.

11/79  SYSTEM                  95.2                    88.8                  720   672    640

       *» FROBLEMS/SOLUTION5/COMMENTS

                         IN NOVEMBER, 8 HOURS OUTAGE TIME MAS REQUIRED TO REPAIR A LEAK IN A
                         RECYCLE LINE.

12/79  SYSTEM                  96.1                    93.5                  74*   72*    696

       »* PROBLEMS/SOLUTICNS/COMMENTS

                         AN OUTAGE FOR GENERAL INSPECTION TOOK PLACE DURING DECEMBER.

 1/80  SYSTEM      78.7        88.2                    78.7                  7**   66*    506

       ** PROBLEMS/SOLUTIOHS/COMMENTS

                         DURING JANUARY THE SCRUBBER WAS DOWN TO REPAIR THE FLAKEGLASS LINING.'

 2/80  SYSTEM     100.0       100.0                   100.0                  696   696    696

 3/80  SYSTEM     100.0       100.0                   100.0                  7**   7**    744

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING FEBRUARY AND MARCH THE SCRUBBER OPERATED WITH NO MAJOR Pr~3LEMS.

 4/80  SYSTEM                                                                720

 5/80  SYSTEM                                                                744

 6/80  SYSTEM                                                                720

       *« PROBLEMS/SOLUTIONS/COKMENTS

                         THE UNIT 3 SCRUBBER EXPERIENCED SOME DOWN TIME DURING THE APRIL-JUNE PERIOD
                         AS A RESULT OF THE CONTINUING DETERIORATION OF THE SCRU3SER FLAKEGLASS
                         LINING.  THE UTILITY REPORTED THAT MAINTENANCE CREWS ARE PATCHING OLD
                         PATCHES.  A STUDY WILL BEGIN IN LATE JULY TO ESTABLISH THE OPTIMUM LINER
                         MATERIAL AND APPLICATION STRATEGY FOR THE UNIT 3 SCRUBBING SYSTEM.

 7/80  SYSTEM                                                                744

 8/80  SYSTEM                                                                744

 9/80  SYSTEM                                                                720
                                               939

-------
 EFA UTILITY FGD SURVEY:  OCTC3EH -  DECEMBER  1981

FOTCMAC ELECTRIC POWER: DICKEKSCN 3 (CONT.)
	PERFORMANCE DATA	
PERIOD MC3ULE AVAILABILITY OFERA8ILITY RELIABILITY UTILIZATION   7. REMOVAL   PER  EOILER   FGD    CAP.
                                                                S02  PART. HOURS HOURS  HOURS  FACTOR


       «* FHC3LEMS/SOLUTICHS/COHMENTS

                         THE UTILITY  HAS NOT FIGURED OUT THE DEPENDABILITY FIGURES AS YET.

                         THE UTILITY  REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS DURING  THE
                         JULY-SEPTEMBER PERIOD.

                         THE BOI1 ER CAPACITY MAS REDUCED TO 1/2  LOAD DURING PART OF THE PERIOD DUE
                         TO THE -ECESSABY PATCHIH3 OF THE SCKU23ER LINING.  THE UTILITY IS  PRESENTLY
                         STUDYING THE POSSIBILITY OF REPLACING THE FLAKEGLASS LINER WITH  A  P.UESiR
                         LINER.

10/80  SYSTEM                                                               744

11/80  SYSTEM                                                               720

12/80  SYSTEM                                                               744

       ** PROBLEMS/SOLUTIOMS/COKMENTS

                         DURING THE OCTOBER  THROUGH DECEMBER PERIOD THE BOILER WAS OPERATED AT A
                         60X (110 MM) CAPACITY DUE TO A LINING FAILURE IN THE SCRUBBING SYSTEM -
                         PIPING.

                         UNIT 3 MILL  BE SHUTDOWN ON FEBRUARY 2,  1981 TO REPLACE THE FLAKEGLASS
                         LINING.

 1/81  SYSTEM      96.8        96.9        97.5        94.2                  744   723    701

 2/81  SYSTEM        .0                                  .0                  672     0      0

 3/81  SYSTEM        .0                                  .0                  744     0      0

       *» FROBLEnS/SCLUTIONS/COMMENTS

                         DICKERSCN UNITS 1.  Z AND 3 WERE SHUT DOWN SO THAT THE STACK AND  THE CCKKGN
                         DUCT LEADING TO THE STACK CCULO BE RELINED KITH PLASITE.  UNIT 3 HAS  SHUT
                         DOWN ON JANUARY 30  AND REMAINED DOWN THROUGHOUT FEBRUARY AND MARCH DUE TO
                         THESE REPAIRS.
                                               940

-------
                                               EPA UTILITY FGD SURVEY: OCTCSER - DECEMBER 1931

                                            SECTION 14
                   DESIGN AND PERFOPMANCE DATA FOR OPERATIONAL PARTICLE SC3U2BEPS
 COMP4NY NAHE
 FLAHT NAME
 UNIT NUMBER
 CITY
 STATE
 RE3ULATORY CLASSIFICATION
 PARTICULATE EMISSION LIMITATION - NG/J
 S02 EMISSION LIMITATION - HG/J
 NOX EMISSION LIMITATION - NG/J
 NET PLANT GENERATING CAPACITY - MM
 GROSS UNIT GENERATING CAPACITY - MM
 NET UNIT GENERATING CAPACITY M/FGD - MM
 NET UNIT GENERATING CAPACITY UO/FGD - MM
 EQUIVALENT SCRUBBED CAPACITY - MM

  *« UNIT DATA - BOILER AND STACK
      BOILER SUPPLIER
      BOILER TYPE
      BOILER SERVICE LOAD
      DESIGN BOILER FLUE GAS FLOW - CU.M/S
      BOILER FLUE GAS TEMPERATURE - C
      STACK HEIGHT - M
      STACK SHELL
      STACK TOP DIAMETER - M

  ** FUEL DATA
      FUEL TYPE
      FUEL GRADE
      AVERAGE HEAT CONTENT - J/G
      RANGE HEAT CONTENT - BTU/LB
      AVERAGE ASH CONTENT - 7.
      RANGE ASH CONTENT - 7.
      AVERAGE MOISTURE CONTENT - 7.
      RANGE MOISTURE CONTENT - 7.
      AVERAGE SULFUR CONTENT - 7.
      RANGE SULFUR CONTENT - 7.
      AVERAGE CHLORIDE CONTENT - 7.
      RANGE CHLORIDE CONTENT - 7.

  ** FUEL DATA
      FUEL TYPE
      FUEL GRADE
      AVERAGE HEAT CONTENT - J/G
      RANGE HEAT CONTENT - BTU/LB
      AVERAGE ASH CONTENT - 7.
      RANGE ASH CONTENT - 7.
      AVERAGE MOISTURE CONTENT - 7.
      RANGE MOISTURE CONTENT - 7.
      AVERAGE SULFUR CONTENT - X
      RANGE SULFUR CONTENT - 7.
      AVERAGE CHLORIDE CONTENT - 7.
      RANGE CHLORIDE CONTENT - 7.

j*** PARTICLE CONTROL

  *» MECHANICAL COLLECTOR
      NUMBER

  «* FABRIC FILTER
      NUMBER
      TYPE

  i« ESP
      NUMBER

  *» PARTICLE SCRUBBER
      NUMBER
      INITIAL START-UP DATE
      GENERIC TYPE
               (   .100 L3/T.M3TU)
               I****** LB/r.M3TU)
               (»***** LB/Mr,3TU)
PUBLIC SERVICE OF COLORADO
ARAPAHOE
4
DENVER
COLORADO
B
   43.
******
******
*****
  112
  109
*****
  112
******
PULVERIZED COAL
******
  245.39
  148.9
******
******
*******
               ( 520000 ACFM)
               ( 300 F)
               f***« FT)

               (**«*« FT)
COAL
SU33ITUMINOUS
23725.

    9.30
******
   13.70

      .95
0.6-1.0
      .01
******
COAL
BITUMINOUS
23493.

   12.50

   11.20
******
     .65
******
     .01
               (  10200 BTU/LB)
                ******
               (  10100 BTU/LB)
                ******
 0
NONE
 1
 9/73
PACKED TOMER
                                                941

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981
FU3LIC SERVICE OF COLORADO:  ARAPAHOE 4 (CONT.)

     SPECIFIC TYPE
     T'ADE NAME/CCmON NAME
     £UPDLIER
     r.ELL GHfJEHIC MATEPIAL
     SrtELL SrEC:c:C MATERIAL
     LINE? GEkl=-5IC MATEPIAL
     LIHcR SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NL'IiEER OF CONTACTING ZONES
     L/G FATIO - LITER/CU.M
     FH CONTROL ADDITIVE
     PRESSURE CPO? - KPA
     SUPERFICIAL GAS VELOCITY - M/S
     IliLET GAS FLOU RATE - CU.M/S
     INLET GAS TEMPERATURE - C
     S02 PEMOVAL EFFICENCY - 7.
     PARTICLE REMOVAL EFFICIENCY - X
MOBILE BED PACKING
TUFBULEHT CONTACT ABSORBER
AIR CORRECTION DIVISION,  UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL
 3
    7.5        (56.0 GAL/1000ACF)
ALKALINE FLYASH
    3.0        (13.0 IN-H20)
    3.*        (    11.0 FT/S)
  245.4        (  520000 ACFM)
  151.7        (   305 F)
   30.0
   93.0
		PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OFERAS1LITY RELIABILITY UTILIZATION
                                                                7, REMOVAL   PER  BOILER  FGO   CAP.
                                                                S02  PART.  HOURS HCUPS  HOURS FACTOR
 9/77  SYSTEM
       »* PROBLEMS/SOLUTIONS/COMMENTS

                         SINCE STARTUP IN SEPTEMBER 1977 SCALING AND PLUGGING AT THE UET/ORY ZONE,
                         CN THE FIRST STAGE 6PIDS, AND IN THE REHEATERS HAVE BEEN THE MOST P°OMINENT
                         PROBLEM AREAS CHARACTERIZED BY THIS SYSTEM.  VARIOUS CHEMICAL ADDITIVES
                         HAVE BEEN TESTED FOR CONTROL OF SCALING, INCLUDING PHOSPHATED ESTERS, BUT
                         WITHOUT SIGNIFICANT IMPROVEMENT.  SLOWDOWN IS MAINTAINED AT A HIGH LEVEL
                         TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FOR TESTING PURPOSES, NO
                         CHEMICAL CONTROL METHOD HAS BEEN USED TO CONTROL SCALE ACCUMULATION.
                         OTHER OPERATING EXPERIENCES INCLUDE HEAR AND PERI03IC REPLACEMENT OF THE
                         MOBILE BALLS, EROSION OF LINING AND CORROSIVE FAILURE OF REHEATERS.  THE
                         EROSION AND LINING FAILURE HAVE NOT BEEN A SERIOUS PROBLEM EXCEPT III THE
                         RECIRCULATING PUMPS.

10/79  SYSTEM                                                                744

11/79  SYSTEM                                                                720

12/79  SYSTEM                                                                744

       *« PR03LEMS/SOLUTIONS/COMMENTS

                         DURING THE FOURTH QUARTER REHEATER FAILURES OCCURRED.

                         LEAKAGE IN THE INLINE STEAM TUBES HAS BEEN ENCOUNTERED.  CORROSION
                         IS KNOWN TO OCCUR AFTER LEAKS ARE EXPERIENCED.

                         THE PRIMARY PROBLEM WITH THE SYSTEM IS THE INABILITY TO ISOLATE MODULES.
                         IF A PROBLEM OCCURS NO MODULE MAINTENANCE CAM BE PERFORMED UNLESS THE
                         UNIT LOAD IS CUT BACK OR THE UNIT IS SHUT DOWN.
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM
                             744

                             696

                             744
       *« PROBLEMS/SOLUTIONS/COMMENTS
                         THE MOCULE ISOLATION PROBLEMS CONTINUED THROUGH THE FIRST QUARTER OF 1930.
                         USE OF THE CARBON STEEL DAMPERS HAS BEEN ABANDONED.  THE PFOG3AM FOR RE-
                         PLACING THE DAMPERS HAS BEEN SUSPENDED INDEFINITELY.  THE UNIT IS SHUTDOWN
                         WHEN MAJOR SCRUBBER PROBLEMS OCCUR.
                                               942

-------
                                              EPA UTILITY F6D SUBVEY:   ;7C3EH  - DECREES  •-'531

PUBLIC SERVICE OF COLORADO:  ARAPAHOE 4 (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER   EOILER   FG3    CAP.
                                                                S02  PART.  HCL'HS HOU=S  hOL'f-S FACTOR

                         REHEATER STEAM TUBE LEAKS ARE STILL CAUSING PROBLEMS.   THE  SIX  STEAM COI'.S
                         ON THIS IN-LINE REHEAT SYSTEM, TWO OF WHICH ARE 516S3 AND FCL1?  OF  WHICH
                         AFE CARBON STEEL, ARE EXPERIENCING CCHROSICN PROBLEMS.   A S3LUTICN 70 THE
                         PROBLEM HAS NOT YET BEEN DETERMINED.

                         IN FEBRUARY THE UTILITY REPLACED THE SCRUBBER BALLS AND GRIDS.   THE  CLD
                         BALLS WERE REPLACED WITH THE  NEW HOLLOW HAPD PLASTIC-WALLED BALLS  WITH
                         NOTCHED SEAMS.  THE GRIDS UEPE ORIGINALLY 316L SS, CERAMIC, POLYrFCPYLiNE,
                         AND RUBBER LINED CARBOH STEEL, BUT HAVE BEEN REPLACED WITH  317L SS GRIDS.

                         THE SCRU3BERS OPERATED CONTINUOUSLY THROUGHOUT THE QUARTER  EXCEPT  FOR THE
                         BALL AND GRID REPLACEMENT DOWNTIME.

 4/80  SYSTEM                 100.0                   100.0                  720  720   7CO

 5/80  SYSTEM                 100.0                   100.0                  744  744   744

 6/60  SYSTEM                 100.0                   100.0                  720  720   720

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         BOTH BOILER AND SCRUBBERS OPERATED THE ENTIRE APRIL-JUNE PERIOD.

                         THE ISOLATION DAMPERS ARE STILL EFFECTIVELY INOPERABLE  AND  A REPLACEMENT
                         PLAN AS YET HAS NOT BEEN REESTABLISHED.

                         THE UTILITY REPORTED THAT THE REHEATER TUBE LEAK PROBLEM CONTINUED THROUGH
                         THE SECOND QUARTER.  THE TUBES MILL EE ENTIRELY REPLACED WITH NEW  316L SS
                         BUNDLES DURING THE NEXT SCHEDULED OUTAGE IN NOVEMBER AND DECEMBER.  OURINS
                         THE SECOND QUARTER MORE TUBES WERE BLANKED OFF AFTER STcAM  LEAKS OCCUPIED.
                         TO DATE ROUGHLY SOX OF THE TUBES ARE SEALED OFF AMD ARE OUT OF  SERVICE
                         BECAUSE OF LEAKS THAT OCCURRED OVER THE PAST MONTHS.

 7/80  SYSTEM     100.0       100.0       100.0       100.0                  744  744   744

 6/80  SYSTEM     100.0       100.0       100.0       100.0                  744  744   744

 9/80  SYSTEM     100.0       100.0       100.0       100.0                  720  720   720

       «» PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER AND SCRUBBERS OPERATED ACCEPTABLY DURING THE JULY-SEPTEMBER PER-
                         IOD.  NO PLANS HAVE BEEN MADE TO REPAIR THE ISOLATION OAf.PEPS.   THE  FAULTY
                         REHEATER TUBES MILL BE REPLACED DURING THE SCHEDULED CUTAGE NOW SET  FOR  THE
                         FIRST THREE WEEKS OF DECEMBER.

10/80  SYSTEM                                                                744

11/80  SYSTEM                                                                720

12/80  SYSTEM                                                                744

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE OCTOBER THROUGH DECEMBER PERIOD THE REHEATER TUBES WERE NOT RE-
                         PLACED AND THE UNIT IS OPERATING WITHOUT REHEAT UNTIL THE NEXT  SCHEDULED
                         OUTAGE PERIOD IN FEBRUARY 1981.

                         NO MAJOR SCRUSSER RELATED PROBLEMS HERE ENCOUNTERED, EXCEPT THE REPLACE-
                         MENT OF THE DISCHARGE VALVE ON THE RECIRCULATION PUMP.

 1/81  SYSTEM                                                                744

 2/81  SYSTEM                                                                672
                                               943

-------
 E°A UTILITY FGD SUPVEY:  CCTC9ER -  DECEMBER 1981

PUBLIC SERVICE OF COLORADO:  ARAPAHOE 4 (CCNT.)
	PERFORMANCE DATA	
PEHICD MODULE AVAILABILITY OPERA3ILITY RELIABILITY UTILIZATION  7. REMOVAL   FE=  EOILE5  FC-D   CAP.
                                                                S02  PART.  HCL'SS HOL'SS  HC'uSS FAC7C3


 3/fll  SYSTEM                                                                744

       «* PROBLEHS/50LUTIONS/COMMENTS

                         DURING THE SCHEDULED FOL"? WEEK OUTAGE STARTING JANUAPY 30 AND ENDING FEc=U-
                         ARY 24, TWO NEW A-SIDE REHEATER BUNDLES MERE INSTALLED.  THE UNIT WAS THEN
                         RESTARTED.

                         THE UNIT HOWEVER HAD TO BE SHUT DOWN ON FEBRUARY £4 ONLY AFTEP OPERATING 3
                         HOURS DUE TO OPERATOR ERROR.  THE SCOSTER FAN MAS RESTARTED UIThC'JT ITS OIL
                         BEARING CCOLINS SYSTEM.  CONSEQUENTLY, THE FAN BEARINGS WERE DAMAGE WO THE
                         BOOSTER FAN HAD TO BE SHUT DO^'N.  THE UTILITY HAS SINCE REPAIRED THH FAN
                         SHAFT BUT STILL AWAITS FCR THE REPAIRED FAN BEARINGS BEFORE T.HE UNIT CAN 3E
                         RESTARTED.
                                               944

-------
                                              EPA UTILITY  FGO  SURVEY:  OCTOBER  -  DECEMBER  1931
                                           SECTION  14
                  DESIGN AMD PERFORMANCE  DATA  FOR OPERATIONAL  PARTICLE  SCSU53ERS
COMPANY NAME
PLANT NAME
UNIT NUK3ER
CITY
STATE
PEGULATCRY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SQ2 EMISSION LIMITATION - HG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GKCSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY KO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MU
PUBLIC SERVICE
CHEROKEE
1
DENVER
COLORADO
B
43.
******
*«»»»»
710
115
100
105
102
OF COLORADO





( .100 LB/MMSTU)
( ***»ii* LB/MM3TU )
(»»««*« LB/MM3TU)





 ** UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW-- CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - ft
     STACK SHELL
     STACK TOP DIAMETER - M

 »» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - V.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - 7.

*** PARTICLE CONTROL

 »* MECHANICAL COLLECTOR
     NUMBER

 ** FABRIC FILTER
     NUMBER
     TYPE

 *« ESP
     NUMBER

 ** PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     L/G RATIO - LITER/CU.M
     PH CONTROL ADDITIVE
     PRESSURE DROP - KPA
     SUPERFICIAL GAS VELOCITY - M/S
     INLET GAS FLOU RATE - CU.M/S
BABCOCK ft UILCCX
PULVERIZED COAL
******
  245.39
  146.1
******
******
*******
COAL
BITUMINOUS
23493.

   12.50
9.4-12.5
   11.30
******
     .65
******
     .01
******
(  520000 ACFM)
(  295 F)
(**** FT)

(***** FT)
C  10100 BTU/LB)
 ******
 0
NONE
 1
 6/73
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION. UOP
CARBON STEEL
AISI 1110
CPGANIC
RU3BER
STAINLESS STEEL
 3
    7.5        (56.0 GAL/1000ACF)
ALKALINE FLYASH
    3.2        (13.0 IN-H20)
    3.4        (
                                                  164.4
                   11.0 FT/S)
               I 346400 ACFM)
                                               945

-------
 cPA UTILITY FC-D SURVEY:  CCT03ER - DECEMBER 1901

PUBLIC SERVICE OF COLCRACQ: CHEPCKEE 1 (CONT.)

     INLET GAS TEnFEDAT'J^E - C                    146.1        t   295  f)
     sea REro/AL EFFICE»;:Y - x                     I6.o
     PARTICLE REMOVAL EFFICIENCY - X               97.0
     E.'iiKGY CONSUMPTION - V.                         4.3
	PERFORMANCE DATA	
PERIOD M03ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X PEK3VAL   PER   BOILER   FGO    CAP.
                                                                S02   PART.  HOURS HOPS  HOL'RS FACTOR


 6/73  SYSTEM

       »» PROBLEMS/SOLUTICHS/COMMENTS

                         SINCE STARTUP IN JUNE 1973 SCALING AND  PLUGGING AT THE  MET/DRY  ZONE,
                         ON THE FIRST STAGE GRIDS. AI.'O IN THE  REHEATERS  HAVE BEEN THE MOST PROMINENT
                         FR03LEM AREAS CHARACTERIZED BY THIS SYSTEM.   VARIOUS CHEMICAL AC3ITIVES
                         HAVE BEEN TESTED FOR CONTROL OF SCALING. INCLUDING PH03FHATEO ESTEPS.  BUT
                         WITHOUT SIGNIFICANT IMPROVEMENT.  SLOWDOWN  IS MAINTAINED AT A HICH LEVEL
                         TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FOR  TESTING FUSFOSES NO
                         CHEMICAL CONTROL METHOD HAS BEEN USED TO CONTROL SCALE  ACCLT.ULATICN.
                         OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT OF TH5
                         MOBILE BALLS. EROSION OF LINING AND CORROSIVE FAILURE OF REHEATERS.   THE
                         EROSION AND LINING FAILURE HAVE NOT BEEN A  SERIOUS PROBLEM EXCEPT IN THE
                         RECIRCULATING PUMPS.

10/79  SYSTEM                                                                744

11/79  SYSTEM                                                                720

12/79  SYSTEM                                                                744

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE PERIOD ID FAN FAILURES HAVE  OCCURRED DUE TO  EROSION  FROM  THE
                         FLY ASH.

                         THE ISOLATION DAMPER HAS BEEN A PROBLEM DUE  TO  FREEZE UPS MAKING IT
                         INOPERATIVE.

                         REHEATER FAILURES HAVE OCCURRED DUE TO  PLUGGING OF THE  HOT AIR  INJECTION
                         STEAM COILS.

                         THE SCRUBBER EXIT DUCTWORK HILL BE REPAIRED  TEMPORARILY WITH A  SPRAY OS
                         FIBERGLASS-LIKE MATERIAL.

 1/80  SYSTEM                 100.0                   100.0                  744   744    744

 2/80  SYSTEM                 100.0                   100.0                  696   696    696

 3/80  SYSTEM                 100.0                   100.0                  744   744    744

       t* FRC3LEMS/SOLUTICNS/COMMENTS

                         THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT  THE FIRST QUARTER OF  1980.

                         THE ISOLATION DAMPERS HAVE NOT CAUSED ANY PROBLEMS BECAUSE MODULE
                         ISOLATION HAS NOT REQUIRED DURING THE PERIOD.

                         THE FANS ARE STILL EXPERIENCING EROSION PROBLEMS.

                         IN MARCH A BOILER/SCRUBBER OVERHAUL BEGAN.   DURING THIS TIME THE CARBON
                         STEEL ISOLATION DAMPERS WILL BE REPLACED WITH 316  SS.   THE HEM  FANS
                         WILL BE INSTALLED IN THE OLD HOUSINGS.   THE  NSM HIGH STRENGTH CiRBCN STEEL
                         FANS MILL BE EQUIPPED WITH REPLACABLE CHROMIUM  ALLOY WEAR PLATE BLADE
                         TIPS.

 4/80  SYSTEM                                                                720

 5/80  SYSTEM                                                                744
                                               946

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - CECEK3EH 1531

PUBLIC SERVICE OF COLCRADQ: CHEROKEE 1 (COHT.)
	PERFCRHAHCE DATA			
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   Pet  BOILES  FG3   CAP.
                                                                S02  PART.  HOUPS HO'JSS  hQ'JFS F4.C7CT


 6/80  SYSTEM                                                                7£0

       *» PRC3LEMS/SOLUTICNS/COMMENTS

                         THE IB ID FAN MAS SEVERELY ERRODED.   THE FAN MAS RE2UILT DURING THE OUTAGE.

                         THE OLD CARBON STEEL ISOLATION DAMPERS HERE REPLACED WITH 316 S3 DAKFESS
                         DURING THE CONTINUING MAY-JULY OUTAGE.

 7/80  SYSTEM                                                                744

 9/80  SYSTEM                                                                744

 9/80  SYSTEM                                                                7ZO

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         SHAFT BEARING FAILURES ON THE RECIRCULATION PUMP CAUSED SCRUBBER SYSTEM
                         PROBLEMS THROUGHOUT THE JULY-SEPTEMBER PERIOD.

10X80  SYSTEM                                                                744

11/80  SYSTEM                                                                7EO

12/80  SYSTEM                                                                744

       *» PHOBLEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED NO MAJOR PROBLEMS WERE ENCOUNTERED DURING THE OCTCSER
                         THROUGH DECEMBER PERIOD.  HOWEVER, SHAFT BEARING REPAIRS WERE MADE TO THE
                         RECIRCULATION PUMPS.

 1/81  SYSTEM                                                                744

       o* PHOBLEHS/SOLUTIONS/COMMENTS

                         DURING THE MONTH OF JANUARY THE UNIT HAS SHUT DOWN FCR THE ENTIRE MCMTH FC3
                         A GENERAL SCRUBBER OVERHAUL.  THE OVERHAUL INCLUDED THE REPLACEMENT OF THE
                         SCRUBBER BALLS AND REPAIR WORK TO THE SCRUBBER  BALL PARTITIONS.

 2/81  SYSTEM                                                                672

       ** PHOBLEMS/SOLUTIONS/COMMENTS

                         UTILITY REPORTED THAT NO SCRUBBER RELATED PROBLEMS OCCURRED DURING THE
                         MONTH OF FEBRUARY.

 3/61  SYSTEM                                                                744

       »* FROBLEMS/SOLUTIONS/COMMENTS

                         DURING PART OF MARCH THE UNIT HAS FORCED TO SHUT DOWN DUE TO A FROZEN
                         GUILLOTINE INLET DAMPER.
                                               947

-------
 EPA UTILIT' FGD SURVEY:  CCTCBER - DECEMBER 1981
                                           SECTION 14
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCEU3BE=S
CCMPANY NAME
PUNT HAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART:CULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GP3SS UNIT GENERATING CAPACITY - KM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY MO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 *» UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 »* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANSE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - Y.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - 7.

»»« PARTICLE CONTROL

 ** MECHANICAL COLLECTOR
     NUMBER

 »* FABRIC FILTER
     NUMBER
     TYPE

 »» ESP
     NUMBER

 *» PARTICLE SCRUBBER
     NUM3ER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     HUrSER OF CONTACTING ZONES
     L/G RATIO - LITER/CU.M
     PH CONTROL ADDITIVE
     PRESSURE DROP - KPA
     SUPERFICIAL GAS VELOCITY - M/S
     S02 REMOVAL EFFICEHCY - 7.
               I  .100 LB/MMBTU)
               (*»**** LB/MM3TJ)
               («»«**» LB/MM3TU)
PUBLIC SERVICE OF COLORADO
CHEROKEE
4
DENVER
COLORADO
B
   43.
******
******
  710
  375
  350
  375
  356
COMBUSTION ENGINEERING
PULVERIZED COAL
******
  717.29       (1520000 ACFM)
  135.0        ( C75 F)
******         (**** FT)
******
*******        (***** FT)
COAL
BITUMINOUS
23493.

   12.50
9.4-12.5
   11.30
******
      .65
******
      .01
******
               ( 10100 BTU/LB)
                ******
 0
NONE
 4
 7/74
PACKED TOMER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL
 3
    7.5        (56.0 GAL/1000ACF)
ALKALINE FLYASH
    3.2        (13.0 IN-H20)
    3.4        (   11.0 FT/S)
   16.0
                                               948

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER  - DECEASES  1931

PUBLIC SERVICE OF COLORADO:  CHEROKEE 4 (COMT.)

     PARTICLE REMOVAL EFFICIENCY - 7.               97.0
     ENERGY CONSUMPTION - X                         6.7
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER   BOILER   FGD    CAP.
                                                                S02  FART.  HCUSS HOURS  HC'JPS  FAC7CH


 7/74  SYSTEM

       ** PR08LEMS/SOLUTIONS/COMMENTS

                         SINCE STARTUP IN JULY 1974 SCALING AND PLUGGING AT THE  HET/CPY  ZCNE.
                         Otl THE FIRST STAGE GRIDS, AI.'D IN THE REHEATERS HAVE BEEN THE  MOST  PROMINENT
                         PROBLEM AREAS CHARACTERIZED BY THIS SYSTEM.   VARIOUS CHEMICAL ADDITIVES
                         HAVE BEEN TESTED FOR CONTROL  OF SCALING. INCLUDING FKCSPHATEO ESTERS,  BUT
                         WITHOUT SIGNIFICANT IMPROVEMENT.  BLCWDCUN IS MAINTAINED AT A HIGH LEVEL
                         TO CHECK THE BUILDUP OF  SALTS BUT, OTHER THAN FCR  TESTING ?U=POSES KO
                         CHEMICAL CONTROL METHOD  HAS BEEN USED TO CONTROL SCALE  ACCUr.JLATICN.
                         OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT  OF  THE
                         MOBILE BALLS, EROSION OF LINING AND COPROSIVE FAILURE OF REriEATERS.   THE
                         EROSION AND LINING FAILURE HAVE NOT BEEN A SERIOUS PROBLEM EXCEPT  IN  THE
                         RECIRCULATING PUMPS.

10/79  SYSTEM                                                                744

11/79  SYSTEM                                                                720

12/79  SYSTEM                                                                744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE PERIOD ID FAN FAILURES HAVE OCCURRED DUE TO  EROSION  FROM THE
                         FLY ASH.

                         THE ISOLATION DAMPER HAS BEEN A PROBLEM DUE TO FREEZE UPS MAKING IT
                         INOPERATIVE.

                         REHEATER FAILURES HAVE OCCURRED DUE TO PLUGGING OF THE  HOT AIR  INJECTION
                         STEAM COILS.

                         THE SCRUBBER EXIT DUCTWORK MILL BE REPAIRED TEMPORARILY WITH  A  SPRAY  ON
                         FIBERGLASS LIKE MATERIAL.

 1/80  SYSTEM                                                                744

 2/80  SYSTEM                                                                696

 3/80  SYSTEM                                                                744

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         THE OUTLET DUCT WORK IS  BEING REBUILT INTERNALLY WITH FIBERGLASS FOR
                         STRUCTURAL SUPPORT AND ACID RESISTANCE.  WITH REGULAR MAINTENANCE  THE
                         UTILITY EXPECTS THIS TO  PROVE TO BE A PERMANENT SOLUTION TO THE ERCSICH/
                         CORROSION PROBLEM.

                         THE OLD FANS ARE BEING REPLACED WITH HIGH STRENGTH CARBON STEEL FANS  HAVING
                         REPLACABLE CHROMIUM ALLOY WEAR PLATE BLADE TIPS.

 4/80  SYSTEM                                                                720

 5/80  SYS'EM                                                                744

 6/80  SYSTEM                                                                720
                                               949

-------
 EPA UTILITY FGD SURVEY:  CCTC3ER  - DECEMBER  1981

PUBLIC SERVICE OF COLORADO:  CHEROKEE 4 (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X  REMOVAL    PER   BOILER   FGO    CAP.
                                                                S02   PART. HOURS  KCL'PS  HCL'S FACTCS


       ** FROBLEMS/SOLUTICNS/CCMMENTS

                         THE NEVI FANS  DESCRIBED DUPING THE LAST  REPORT  PERIOD  UE°E  INSTALLED  IN CUE
                         OF THE  FOUR MODULES.   NEW FANS MILL BE  INSTALLED IN THE  OTHER THREE  MODULES
                         DURING  A SCHEDULED  LATE SEPTEMBER OUTAGE  UNLESS THE UTILITY  HAS AN OPPOR-
                         TUNITY  TO MAKE THE  REPLACEMENTS SOONER.

 7/80  SYSTEM                                                               744

       «<* PROBLEMS/SOLUTIONS/COMMENTS

                         THE SCRUBBER  RETURNED TO SERVICE IN MID JULY AFTER  A  TWO MEEK OUTAGE.
                         DURING  THIS TIME.  THE FIBERGLASS INSIDE THE  OUCTVJC°K  WAS REPLACED, AH3 A
                         VERTICAL GRID MAS  INSTALLED ON THE SECOND LEVEL OF  THE M03ILE BED TOWER TO
                         IMPROVE SYSTEM PERFORMANCE.

 8/80  SYSTEM                                                               744

 9/80  SYSTEM                                                               720

       »» PROBLEMS/SOLUTICNS/CCMMENTS

                         THE BOILER AND FGD  SYSTEM WENT DOWN ON  SEPTEMBER 15,  1980  FCR A SCHEDULED
                         OVERHAUL.  DURING  THIS TIME,  FANS MERE  INSTALLED ON MODULES  A,  C, AND  D.

                         THE UTILITY IS CURRENTLY EVALUATING THE VERTICAL GRID OH THE SECOND  LAYER.
                         IF THE  GRID IMPROVES SYSTEM PERFORMANCE,  THEY  MILL  INSTALL ANOTHER ONE
                         ON THE  THIRD  LEVEL.

10/80  SYSTEM                                                               744

11/80  SYSTEM                                                               7CO

12/80  SYSTEM                                                               744

       «» PROBLEMS/SOLUTIONS/COMMENTS

                         UNIT 4  EXPERIENCED  SOME MINOR REHEATER  LEAKAGE PROBLEMS  DURING  THE PERIOD.

                         DURING  THE FOURTH  QUARTER OF  1980 THE UTILITY  REPORTED THAT  PROBLEMS WERE
                         ENCOUNTERED WHEN VERITICAL GRIDS MERE INSTALLED ON  THE SCRUBBER BED.  THIS
                         MAS INTENDED  TO SOLVE THE PROBLEM OF KEEPING THE SCRUBBER  BALLS FRCM MOVING
                         HORIZONTALLY, RESULTING IN PILES OF SCP.U3BER BALLS  IN LOCALIZED AREAS, BUT
                         CCRPOSION AND SYSTEM PERFORMANCE DID NOT  IMPROVE.

 1/81  SYSTEM                                                               744

 2/81  SYSTEM                                                               672

 3/81  SYSTEM                                                               744

       *» PH08LEMS/SOLUTIONS/COMMENTS

                         THROUGHOUT THE JANUARY-MARCH  PERIOD THE UTILITY INTERMITTENTLY  SHUT  DOWN
                         THE SCRUBBER  MODULES (ONE MCDULE AT A TIME)  TO REPLACE SCRUBBER BALLS AND
                         REPAIR  SCRUBBER BALL PARTITIONS.

                         THE UTILITY REPORTED EXPERIENCING CORROSION  PROBLEMS  WITH  THE FOUR SCRUBBER
                         BOOSTER FANS.
                                               950

-------
                                              EPA UTILITY FG3 SURVEY:  CCTC3E3 - DECEPSER 1=31

                                           SECTION 14
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCSU33EPS
COMPANY NAME
PUNT NAME
UNIT NUKSEH
CITY
STATE
PEGULATOHY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOC EMISSION LIMITATION - NG/J
HOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GTCSS UNIT GENERATING CAPACITY - KM
NET UNIT GENERATING CAPACITY M/FGO - MM
NET UNIT GENERATING CAPACITY MO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MM

 ** UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     SOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - fl

 *« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANSE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - X

»»» PARTICLE CONTROL

 »» MECHANICAL COLLECTOR
     NUMBER
     INLET FLUE GAS CAPACITY - CU.M/S

 »» FABRIC FILTER
     NUMBER
     TYPE

 «» ESP
     NUMBER
     TYPE
     INLET FLUE GAS CAPACITY - CU.M/S

 »» PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     L/G RATIO - LITER/CU.M
     PH CONTROL ADDITIVE
                  .100 L2/rrsTu)
                     « LS/MMBTU)
               I****** LB/MH3TU)
PUBLIC SERVICE OF COLCRASO
VAU10NT
5
VALMONT
COLORADO
E
   43.
*»»**»
******
  274
  166
  157
  163
  166
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
  436.98       ( 926000 ACFM)
  126.7        ( 260 F)
*K»*ft*         (»*»* FT)
»»K*tt*
«*«*«**        (»«*«* FT)
COAL
SUBBITUMINOUS
25131.

    6.00
5.4-7.0
   15.00
12.7-13.3
     .70
0.6-0.7
«*****«*
***»*»
  218.5
 0
NONE
COLD SIDE
  218.5
               (  10800 BTU/LB)
                »•«*«**
               ( 463000 ACFM)
               ( 463000 ACFM)
 2
11/71
PACKED TOMER
MOBILE BED PACKINS
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBCN STEEL
AISI 1110
ORGANIC
RU33EP
STAINLESS STEEL
 3
    7.8        (53.3 GAL/1000ACF)
LIMESTONE/ALKALINE FLYASH
                                               951

-------
 EPA UTILITY FGO  SURVEY:  OCTC3ER  - DECEMBER  1981

PUBLIC SERVICE OF COLCPADO:  VALMONT  5  (COHT.)

     FPESSU=E 0=OP -  KPA
     SUPERFICIAL  GAS  VELOCITY  - M/S
     INLET GAS FLCU RATE  - CU.M/S
     INLET GAS 7Er?ERATUPE - C
     S02 FEKCVAL  EFFICENCY - X
     PARTICLE REMOVAL EFFICIENCY  - X
     ENERGY CCNSUMPTICN - X
  3.7
  3.4
109.2
132.8
 45.0
 06.0
  3.6
(15.0 IH-U2C)
(    11.0 rT/S)
(  231500 ACFtt)
(   C71 F)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  CPERABILITY RELIABILITY UTILIZATION
                                                               X REMOVAL   PER  30ILER  FGD   CAP.
                                                               S02  PART. KCURS HOURS  KO'JPS FACTOR
11/71  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS
                           720
                         THE  FIRST  PARTICLE MATTER SCPUBBEH COMMENCED OPERATION IN NOVEMBER 1971.
                         THE  SCPUBBEH MAS ORIGINALLY INSTALLED FCR PARTICLE MATTES REMOVAL SINCE THE
                         PLANT  BURNS LOU SULFUR COAL! HOWEVER, 45X OF THE SO2 IS REMOVED-AS WELL
                         BECAUSE  OF THE ALKALINITY OF THE FLYASH.

                         DURING THE FIRST YEAR OF OPERATION PRC3LEMS INCLUDED DIFFICULTIES WITH THE
                         MODULE PACKING GRID SUPPORT, GENERAL VESSEL SCALE FORMATION, FLOW DISTRI-
                         BUTION PROBLEMS. BALL BREAKAGE, SCALING IN THE MIST ELIMINATOR SECTION,
                         AND  PLUGGING OF THE REHEATER.  SCALE FORMATION MAS THE MOST PREDOMINANT
                         CONTINUING MAJOR CAUSE OF DOWNTIME IN THE SCRUBBER.  SCALE ACCUMULATION
                         MAS  NOTED  ON THE UET-ORY INTERFACE IMMEDIATELY DCMISTREAM OF THE PRESATU-
                         RATION NOZZLES.  SCALE ALSO ACCUMULATED HEAVILY ON THE UNDERSIDE OF THE
                         FIRST  LAYER OF GRID BARS.
                         SCALE  ON THE UPPER GRID BARS WAS LESS PREVALENT AS THE ACTION OF THE "PINS
                         PONG"  BALLS TENDED TO KEEP THE SCALE OFF OF THESE SECTIONS.  SCALE ALSO
                         COLLECTED  ON THE WALLS OF THE VESSEL AND INTERMITTENTLY SLCUC-HED OFF AND
                         FELL INTO  THE SUMP IN LAPGE PIECES CAUSING BLOCKAGE OF THE RECIRCULATIOM
                         PUMP SUCTION SCREENS.  SCALING OF THE HIST ELIMINATOR ABATED SCMEMHAT WITH
                         THE  INTRODUCTION OF A CLEAR RINSE MATER WASH.  SCALE FORMATION IN THE RE-
                         HEAT SECTION SOMETIMES REQUIRED SUPPLEMENTAL CLEANING OF THE REUEATER IN
                         ADDITION TO THE CLEANING OBTAINED BY THE USE OF THE SCOT3LOWERS WHICH UEHE
                         INSTALLED  AS A PART OF THE HEHEATER EQUIPMENT.  UNDER NORMAL OPERATION,
                         THE  SOOTBLOWERS LOCATED IN THIS REHEAT SECTION WERE FAIRLY SUCCESSFUL IN
                         REMOVING THE ACCUMULATION OF THE SCALE IN THE REHEATER.
                         ALTHOUGH MANY OF THE INITIAL START-UP PROBLEMS WERE SOLVED OVER A PEPIOD
                         OF TIME, THE CALCIUM SULFATE-FLYASH SCALING CONTINUED TO BE A SIGNIFICANT
                         OPERATING  PROBLEM AT THE VALMONT INSTALLATION.  Ill ADDITION TO THESE
                         SCALING  RELIABILITY PROBLEMS, A WATER QUALITY CONCERN ALSO SURFACED THAT
                         MAS  A  DIRECT RESULT OF THE PARTICLE SCRUBBER OPERATION.  THE RELATIVELY
                         HIGH CAO CONCENTRATION IN THE VALMONT FLYASH RESULTED IN FAIRLY HIGH £02
                         REMOVAL  RATES (45-50 PERCENT) WITHIN THE UNITS.  SINCE NO PH CONTROL CAPA-
                         BILITY FOR EITHER THE RECIRCULATING SLURRY OR THE SYSTEM BLOHOCWN SLURRY
                         WAS  DESIGNED INTO THE SYSTEM, AN iCID CONDITION WAJ CPEATED IN THE SLURRY
                         AND  THE  SLOWDOWN STREAM.  PH LEVELS OF THE BLCWOOHN NORMALLY RANGED BETWEEN
                         1.7  AND  2.0.  ALTHOUGH THE STREAM WAS NEUTRALIZED TO A DEGREE BY ALKALINE
                         FLYASH,  PSCC FELT THAT IT WAS IMPORTANT TO INVESTIGATE VARIOUS CONTROL
                         MEASURES WHICH COULD BE APPLIED TO THIS STPEAM.  THE CALCIUM SULFATE
                         SCALING  PROBLEM WAS THOUGHT TO BE THE PESULT OF A SUPER-SATURATED CALCIUM
                         SULFATE  CONDITION IN THE RECIRCULATING SLURRY.  BECAUSE OF THIS IT WAS FELT
                         THAT CONTINUOUS PH CONTROL OF THE RECIRCULATING SLUSHY, CONVERSION Or THE
                         SYSTEM TO  CLOSED LOOP OPERATION AND ESTABLISHING A HIGHER CONCENTRATION OF
                         SEEDING  SOLIDS IN THE RECIRCULATION SLURRY (THEREBY CONTROLLING THE SCALING
                         PROBLEMS WITHOUT CHEMICAL ADDITIVES) WOULD BE NECESSARY MEASURES.
                         FOR  PH CONTROL, LIMESTONE WAS TESTED INITIALLY, THEN LIME WAS UTILIZED FCR
                         THE  ALKALI REAGENT.  IN THE FIRST TEST, SIHCE LIMESTONE UTILIZATION WAS A
                         MAJOR  CONCEFM, A SPECIAL EFFORT WAS MADE TO REDUCE THE POTENTIAL FOR THE
                         SHORT  CIRCUITING OF THE ADDED LIMESTONE AND TO PPOVIOE SUFFICIENT RESIDENCE
                         TIME IN  THE REACTOR SECTION OF THE SYSTEM.  BY UTILIZING FOUR REACTION MIX
                         TANKS  IN SERIES. PLUG FLOW WAS EXPECTED TO BE MORE CLOSELY SIMULATED.  TO
                         MAINTAIN A CLOSED LOOP SYSTEM WHERE THE QUANTITY OF WATER REMOVED FPCM THE
                         SYSTEM WAS HELD TO A MINIMUM, FOUR SYSTEM DESIGN FEATURES WERE UTILIZED.
                             1.  UTILIZATION OF A COMBINATION OF POND SUPERNATANT AND MAKE-UP WATER
                                              952

-------
                                              EPA  UTILITY  FGD  SURVEY:  OCTOBER  -  DECEMBER  1931

PUBLIC SERVICE OF COLOR ADO:  VAU10NT 5 (COMT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  X  REMOVAL   PER  BOILER   FCD   CAP.
                                                                SOZ   PAPT.  HOURS HG'JKS  HC'JSS  FACTCR

                                 FOR  RECYCLE  WATER.
                              2.  PHESATUHATION  OF THE  INCOMING FLUE  GAS  WITH HECIFCULATIHG SLURRY.
                              3.  INTERMITTENT HIST  ELIMINATOR  MASH.
                              4.  PROPER SELECTION OF MATERIALS OF  CONSTRUCTION TO  PROTECT AGAINST
                                 ATTACK CAUSED  BY HIGH CHLORIDE CONCENTRATIONS.
                         THE SCRUBBERS  R i  D  FACILITY  MAS NOT  EQUIPPED WITH A MECHANICAL  THICKENER
                         FOR CONTROL  OF THE SUSPENDED  SOLIDS CONCENTRATION  OF THE  RECIPCULATIN3
                         SLURRY (ALL  PURGED MATERIAL WAS SENT  TO THE SLUDGE POND).   WITH  A SCO PPM
                         502 CONCENTRATION  IN THE FLUE GAS,  IT IS  EXPECTED  THAT THE  RECIPCULATIN3
                         SLURRY SOLIDS  COULD  BE REALLY CONTROLLED  IN THE 5  TO 7 PEPCENT RANGE. DUE
                         TO THE MIXED FUEL  FIRED AT THE UNIT DURING  THE  TEST FERIC3,  HCUEVEP,  THE
                         S02 CONCENTRATIONS EMITTED FROM THE BOILER  AND  HENCE PRESENT IN  THE FLUE
                         GAS STPEAM VARIED  SIGNIFICANTLY AND FINALLY FELL TO SUCH  LCVI LEVELS (OFTEN
                         100-COO PPM) THAT  SUSPENDED SOLIDS  CONCENTRATIONS  IN THE  SLURRY  CCULD NOT
                         BE MAINTAINED.  IT IS  ALMOST  CERTAIN  THAT A THICKENER, HITH THE  SU3SE-
                         QUENT RETURN OF SOLIDS TO  THE SCRU2BEH LIQUOR,  COULD HAVE BEEN USED TO
                         GOOD ADVANTAGE DURING  THIS TIME PERIOD.   GENERALLY SPEAKING, THE SEVEPE
                         SCALING CONDITIONS PLAGUING THE TEST  MODULE MERE INTENSIFIED DUSIN3 THESE
                         PERIODS OF LOM INLET S02 CONDITION.

11/74  SYSTEM                                                                720

12/7$  SYSTEM                                                                744

 1/75  SYSTEM                                                                744

 2/75  SYSTEM                                                                672

 3/75  SYSTEM                                                                744

       «» PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGD SCRUBBING  SYSTEM HAS  OPERATED FOR A TOTAL  OF FOUR AND ONE-HALF
                         MONTHS, FROM MID-OCTOBER 1974 TO MARCH 1975. THE  OVERALL RELIABILITY OF
                         THE SYSTEM MAS APPROXIMATELY  75X.

 4/75  SYSTEM                                                                720

 5/75  SYSTEM                                                                744

 6/75  SYSTEM                                                                720

 7/75  SYSTEM                                                                744

 8/75  SYSTEM                                                                744

 9/75  SYSTEM                                                                720

10/75  SYSTEM                                                                744

11/75  SYSTEM                                                                720

12/75  SYSTEM                                                                744

 1/76  SYSTEM                                                                744

 2/76  SYSTEM                                                                696

 3/76  SYSTEM                                                                744

 4/76  SYSTEM                                                                720

 5/76  SYSTEM

 6/76  SYSTEM                                                                720
                                               953

-------
 EPA UTILITY FGD SURVEY:  OCTOBER  - DECEMBER 1931

PUBLIC SERVICE OF COLORADO:  VALMGNT 5 (CONT.)
	PERFORMANCE  DATA	
PEPIC3 KC3ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION   X  REMOVAL   PE3  BOILER   FGD    CAP.
                                                                S0£  PART. HOURS HO'JPS   HCIPS  FACTOR


 7/76  SYSTEM                                                               744

 8/76  SYSTEM                                                               74*

 9/76  SYSTEM                                                               720

10/76  SYSTEM                                                               744

11/76  SYSTEM                                                               730

12/76  SYSTEM                                                               74*

 1/77  SYSTEM                                                               744

 2/77  SYSTEM                                                               672

 3/77  SYSTEM                                                               74*

 4/77  SYSTEM                                                               720

 5/77  SYSTEM                                                               744

 6/77  SYSTEM                                                               720

 7/77  SYSTEM                                                               744

 8/77  SYSTEM                                                               744

 9/77  SYSTEM                                                               720

10/77  SYSTEM                                                               744

11/77  SYSTEM                                                               720

12/77  SYSTEM                                                               744

 1/78  SYSTEM                                                               744

 2/78  SYSTEM                                                               672

 3/78  SYSTEM                                                               744

       «» PR03LEMS/SOLUTIONS/COMMENTS

                         THERE  HAVE  BEEN  RECURRING PROBLEMS  ASSOCIATED WITH BALL MIGRATION  IN  THE
                         BALL COMPARTMENT AS WELL  AS HECIRCULATICN FUKP KOTOS BEARING FAILUPE,  AND
                         WEAR AND  FAILURE IN THE BALL  COMPARTMENT  LINING.  THERE HAVE BEEN  CONTINUAL
                         PROBLEMS  WITH REHEATER PLUGGING.  THERE ALSO HAVE BEEN EXPANSION JOINT
                         FAILURES  AT BOTH THE INLET AMD OUTLET OF  THE SCRUBBER.
                         MORE RECENTLY THERE WAS A PINCH BELT FAILL'PE.
                         THE  SCRUBBING SYSTEM HAS  HAD  AN AVAILABILITY RANGE OF 50 TO 78X WITH  AN
                         AVERAGE OF  66X.

 4/78  SYSTEM                                                               720

 5/78  SYSTEM                                                               744

       ** PRCBLEMS/SOLUTIONS/COMMENTS

                         NO SIGNIFICANT PROBLEMS WERE  ENCOUNTERED.

 6/78  SYSTEM                                                               720

 7/78  SYSTEM                                                               744
                                               954

-------
                                              EPA  UTILITY  F6D  SURVEY:  OCTOBER  -  DECEMBER  1981

PUBLIC SERVICE OF COLORADO:  VALKONT 5 (CONT.)
	PERFORMANCE  DATA		-
PERIOD KCOULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7.  REMOVAL   PER   BOILER   FGD    CAP.
                                                                S02   PART.  HCUKS HO'JSS   HCLPS  FACTOR


 8/78  SYSTEM                                                                744

       ** FROBLEMS/SOLUTION5/CCMMENTS

                         THE UTILITY HAD NO COMMENTS FOR  THIS  PERIOD.

 9/78  SYSTEM                                                                720

10/78  SYSTEM                                                                744

11/78  SYSTEM                                                                720

12/78  SYSTEM                                                                744

 1/79  SYSTEM                                                                744

 2/79  SYSTEM                                                                672

 3/79  SYSTEM                                                                744

 4/79  SYSTEM                                                                720

 5/79  SYSTEM                                                                744

 6/79  SYSTEM                                                                720

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         AVERAGE SCRUBBER AVAILABILITY FROM START  UP THROUGH APRIL 1979  MAS 64.42X.
                         AVERAGE SCRUBBER AVAILABILITY FOR  1978 MAS  66.85;.
                         AVERAGE SCRUBBER AVAILABILITY FROM JANUARY  1,  1979 THROUGH HAY, 1979  MAS
                         APPROXIMATELY 80X.

                         BALL MIGRATION, ALTHOUGH NOT  SERIOUS, IS  A  CHRONIC PROBLEM FOR  VALMCNT 5.

                         EROSION AND CORROSION HAVE OCCURRED ON THE  SCRUBBER GRID BAR AREA (PACKING
                         SUPPORT).

                         EROSION/CORROSION IS EVIDENT  IN  THE MIST  ELIMINATOR SECTION.

                         EROSION/CORROSION OCCURRS  IN  THE REHEATER AREA AND SOOT BLOWER.

                         THE UTILITY HAD TO REPLACE INLET AND  OUTLET EXPANSION JOINTS.

                         REHEATER PLUGGING HAS BEEN A  PROBLEM.

                         RECYCLE PUMP BEARING FAILURES OCCURRED.

                         THE JACK SCREW DRIVE HAS BEEN MALFUNCTIONING ON INLET AND OUTLET ISOLATION
                         DAMPERS.

 7/79  SYSTEM                                                                744

 8/79  SYSTEM                                                                744

 9/79  SYSTEM                                                                720

       »* PROBLEMS/SOLUTIONS/COKMENTS

                         DURING THE ANNUAL SHUTDOWN IN SEPTEMBER THE OLD SCRUBBER BALLS  MERE
                         REPLACED WITH A NEM BRAND.  DUE  TO BALL MOTION THE RU33ER LINER ERCDED.

                         IN THE MIST ELIMINATOR SECTION EROSION AND  CORROSION OCCURRED.
                                               955

-------
 EPA UTILITY FGD SUPVEY:  OCTOBER  - DEC:  1EH  1981

FU3LIC SERVICE OF COLORADO:  VALM3MT 5 (CONT. )
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X  REMOVAL    PER   BOILER   FGD    CAP.
                                                               S02   PART. HOURS  HOURS   HOURS FACTOR


10/79  SYSTEM     100.0                                                      744

11/79  SYSTEM      92.3                                                      720

12/79  SYSTEM      98.1                                                      744

       *» FRCBLEMS/SOLUTIOHS/CCKMENTS

                         ONE OF THE MAJOR SCRUBBING SYSTEM  PROBLEMS  IS THE SCRUBBER  WALL HEAR WHICH
                         HAS TO BE PATCHED  DURING THE  SPRING AND FALL.

                         HEHEATER PLUGGING  HAS BEEN A  CHRONIC PROBLEM.

                         THE UTILITY HAS REPORTED THE  FOLLOWING ANNUAL AVAILABILITIES FOR THE UNIT.
                             1972 - 1978: 64.3X
                             1972 - 1979: 65.9X
                                    1978: 66.6X
                                    1979: 80.5X

 1/80  A           98.5
       B           oa. 5
       SYSTEM      98.5                                                      744

 2/80  A           84.4
       B           94.9
       SYSTEM      89.7                                                      696

 3/80  A           90.8
       B           87.7
       SYSTEM      89.0                                                      744   615

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE FIRST QUARTER OF 1980,  NO MAJOR  PROBLEMS WERE ENCOUNTERED WITH
                         THE SCRUBBER.

 4/80  A           88.1
       B           68.1
       SYSTEM      88.1                                                      720   716

       »« PROBLEMS/SOLUTIOHS/COttMENTS

                         THE SCRUBBER MAS SHUT DOWN ON APRIL 14 FOR  A WEEK TO HAKE REPAIRS TO A HOLE
                         IN THE SCRUBBER RUBBER LINING,  RECYCLE PUMP LININGS AND  A STEAM REGULATOR
                         ON ONE OF THE REHEATERS.

 5/80  A           96.8
       B          100.0
       SYSTEM      98.4                                                      744   744

       »» PROBLEMS/SOLUTIONS/COHMENTS

                         NO PROBLEMS WERE REPORTED FOR MAY.

 6/80  A            8.0
       B            8.0
       SYSTEM       8.0                                                      720   720

       *» PRCBLEMS/SOLUTIONS/COMMENTS

                         DURING JUNE THE SCRUBBER HAS  FORCED OUT OF  SERVICE  WHEN  AN  INBOARD FAN
                         PEDISTLE BEARING FAILED.  THE BEARING SECTION WAS REBUILT.
                                               956

-------
                                              EPA UTILITY f-3 SURVEY: CCTCBEH - OECEf.3EH 1981

PUBLIC SERVICE OF COLORADO: VAU10NT 5 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  EOILE?  FG3   CAP.
                                                                SOZ  PART. HCU3S HBUSS  HCU3S FACTC5

                         WHILE FAN REPAIRS MERE IN FPC3HESS EXTENSIVE MAINTENANCE HAS FE=FCPttEO CM
                         THE SCRUBBER.  MAINTENANCE WORK INCLUDED COMPLETE BiLL REPLACEMENT. ADDI-
                         TIONAL REPAIR WORK OH THE SCKUB3ER LINER. REPAIR OF HOLES IN THE T^ES
                         SHELL AND OF A RUPTURED MIST ELIMINATOR HASH LINE ANO THE REHEATEH WAS
                         CLEANED.

                         DAMPER JAMMING AT VALMOHT HAS OCCURRED PERIODICALLY.  SOMETIMES 0*r.?E7S DO
                         HOT READILY CLOSE.  THE OPERATOR KUST MOVE THE DAMPER UP AND OCXH UNTIL THE
                         GUILLOTINE SEATS.  BECAUSE OF CONTINUOUS FLY ASH ACOJ!"'LATICH IT APPEARS
                         THAT THE OAMPEHS MUST BE EXERCISED FREQUENTLY TO PREVENT JAMMING.

 7/80  5A                      48.3                    46.6
       SB                      46.3                    46.6
       SYSTEM                  48.3                    46.6                  744   719    347

       •w PROBLEMS/SOLUTIONS/COMHENTS

                         THE SCRUBBER SYSTEM MAS SHUT DOWN BECAUSE OF 5CRU3BER BOOSTER FAN
                         BEARING FAILURE.

 8/80  5A                      87.5                    84.8
       SB                      95.6                    92.6
       SYSTEM                  91.5                    87.7                  744   721    660

       x* PRC3LEMS/SOLUTIONS/COMMENTS

                         THE RECIRCULATION PUMP MOTOR BEARING FAILED CAUSING SOME MINOR OUTAGE
                         TIKE IN AUGUST.

 9/80  SYSTEM                                            .0                  720     0      0

       »» PROBLEMS/SOLUTIONS/COMT1ENTS

                         THE BOILER AND SCRUBBER MERE SHUT DOWN DURING SEPTEMBER FCR SCHEDULED
                         MAINTENANCE.

10/80  SYSTEM                                                                744

11/80  SYSTEM                                                                720

12/80  SYSTEM                                                                744

       *« PRC3LEMS/SOLUTIONS/CGMHENTS

                         THE SCRUBBER REMAINED OUT OF SERVICE THROUGHOUT THE OCTOBER-DECEIVER PERIOD
                         AND IS EXPECTED TO START UP AT THE END OF JANUARY.  LATE START UP OF THE
                         SCRUBBER IS DUE TO A MANPOWER SHORTAGE.  THE BOILER AND TURBINE RETURNED TO
                         SERVICE IN MID-DECEMBER.

 1/81  SYSTEM                                                                744

 2/81  SYSTEM                                                                672

 3/61  SYSTEM                                                                744

       *» P30BLEMS/SOLUT1CNS/CCMMENTS

                         SCRUBBER CAME BACK ON-LIKE AT THE END OF JANUARY AND OPERATED THPCUSHOUT
                         THE MONTHS OF FEBRUARY AND MARCH WITHOUT ANY MAJOR SCRUBBER RELATED PROB-
                         LEMS.
                                               957

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
                                           SECTNtf  14
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCPU3SERS
COMPANY NAME
PLANT IIAM3
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NCX EMISSION LIMITATION - NG/J
NET HUNT GENERATING CAPACITY - MW
GFOSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 *v UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 ** FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - Y.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - 7.

»«* PARTICLE CONTROL

 ** ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS CAPACITY - CU.M/S
     INLET FLUE GAS TEMPERATURE - C
     PRESSURE DROP - KPA
     PARTICLE REMOVAL EFFICENCY - 7.

 »* PARTICLE SCRUBBER
     KUK3EH
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUKSER OF CONTACTING ZONES
     LIQUID RECIRCULATICN RATE - LITER/S
     L/G RATIO - LITER/CU.M
     FH CONTPOL ADDITIVE
     SUPERFICIAL GAS VELOCITY - M/S
     INLET GAS FLOW RATE - CU.M/S
     INLET GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICIENCY - 7.
SOUTHWESTERN PUBLIC SERVICE
HARHIN3TON
AMARILLO
TEXAS
B
   43.
  516.
******
  360
  360
  320
*****
  360
(   .100 LB/KKBTU)
(  1.ZOO LB/MMSTU)
(****»» LB/HK3TU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
  778.63       (1650000 ACFM)
  176.7        (  350 Fl
   76.         (  250 FT)
CONCRETE
    8.2        (  27.0 FT)
COAL
SUBBITUMINOUS
19538.

    5.00
4.5-6.0
   27.10
25.0-30.0
     .42
0.4-0.5
********
(   8400 BTU/LB)
 8000-8900
COLD SIDE
RESEARCH-COTTRELL
  778.6        (1650000 ACFM)
  168.3        (   335 F)
     .1        I   1. IN-H20)
   95.0
PACKED TOMER
STATIC BED PACKING
MARBLE-BED SCRUBBER
COMBUSTION ENGINEERING
24.0 X 25.0
CARBON STEEL
AISI 1110
ORGANIC
GLASS MARBLES
 1
  444.1
    3.1
LIMESTONE
    2.4
  141.6
   60.0
   50.0
I  7050 GFM)
123.0 GAL/1000ACF)
     8.0 FT/S)
  300000 ACFM)
   140 F)
                                               958

-------
                                              EPA UTILITY FGD SURVEY:  OCTCSEa - DECEM2ER 1=81

SOUTHWESTERN PUBLIC SERVICE:  HARRINGTON 1  (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  EOILE3  FGD   CAP.
                                                                S02  PART.  HO'JRS HOUPS  HCL'.-S FACTOR


10/79  SYSTEM                                                                744

11/79  SYSTEM                                                                7=0

12/79  SYSTEM                                                                744

       »» FROBLEMS/SOLUTIONS/COMMENTS

                         DURING OCTOBER THROUGH DECEMBER, TWO SPRAY PUMP MOTORS FAILED.

                         THE FRP FLUSH PIPING HAS FAILED CAUSING SOME LEAKING.

                         PLUGGING IN ONE MARBLE BED UAS ENCOUNTERED WHEN THE CHEMISTRY CONTROL UAS
                         TEMPORARILY LOST.

                         THE CONE SHAPED EXPANDED METAL (316L SS) SCREENS COVERING THE BED CRAIM
                         PIPES HAVE ERODED AWAY FROM BALL MOVEMENT.  THE MAF8LE BALLS HAVE BEEN
                         DROPPING INTO THE RECYCLE TANK.  WHERE THE UTILITY HAS REPLACED THE METAL
                         SCREEN WITH EXPANDED PLASTIC SCREEN. EROSION HAS NOT OCCURRED.

 1/80  SYSTEM                                                                744

 2/80  SYSTEM                                                                696

 3/80  SYSTEM                                                                744

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE FIRST QUARTER OF 1980 THE MIST ELIMINATOR WASH PIPING RUPTURED
                         CAUSING PLUGGING IN SCRUBBERS 4 AND 5.  THE UTILITY PLANS TO REPLACE
                         ALL FRP PIPING WITH STEEL.  THE RUPTURE ON NO. 5 ALSO DAMAGED THE WATER
                         SUPPLY HEADER.

                         THE MARBLE BED PLUGGING REPORTED DURING THE LAST QUARTER IS NOT YET
                         COMPLETELY CLEARED.  THE SOFT SCALE IS GRADUALLY GOING BACK INTO THE
                         SOLUTION.  THE PLATE AREA IS CLEAN.

                         THE DUCT BENEATH THE REHEATER TUBING ON ONE OF THE MODULES HAS CCPRCDED TO
                         THE POINT THAT HOLES HAVE FORMED.  SCALE AND MOISTURE V.ERE FOUND ON THE
                          PLATE WHERE THE CORROSION FORMED.  THE PLATE WAS REMOVED AND A NEW CARBON
                         STEEL PLATE WAS WELDED IN.  NO OTHER REHEATER DUCTS HAVE EXPERIENCED ANY
                         SCALE OR MOISTURE ACCUMULATION.

 4/80  SYSTEM                                                                720

       ** PRCBLEMS/SOLUTIONS/COMMENTS

                          A PUMP  LINER  FAILURE OCCURRED IN APRIL.  THE IMPELLER SHAFT LINER WAS RE-
                          PAIRED  AND REPLACED.

 5/80  SYSTEM                                                                744

       ** F303LEMS/SOLUTIONS/COMMEHTS

                          THE BOILER WAS SHUT DOWN A  FEW  DAYS  IN  LATE APRIL  AND  12 TO 14 DAYS IN
                          EARLY MAY FOR AIR  FREHEATER REPAIRS.

                          DURING  APPIL AND MAY  THE SCRUBBING SYSTEM EXF  4IENCED  AGITATOR PROBLEMS.
                          THE RECENT  PROBLEMS HAVE BEEN RELATED TO  BEARING  FAILURE, HOWEVER, THE
                          SEALS HAVE  BEEN  LEAKING  AS  WELL.   THE AGITATORS AT THIS FACILITY ARE  SIDE
                          MOUNTED.  THE AGITATOR SHAFT ENTERS  THE TANK AT ROUGHLY 12 FT BELOW THE
                          FLUID SURFACE.   IT APPEARS  THAT THE  SEAL  LEAKING  MAY  BE ATTRIBUTABLE  TO
                          FAULTY  INSTALLATION.
                                                959

-------
  E?A UTILITY  FGD SUKVEY: OCTOBER - DECEMBER 1981

 SOUTHWESTERN  PUBLIC  SERVICE: HARRINGTON 1  (CONT.)
 	PERFORMANCE DATA	
 PEHIC3 KC2ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  20ILE3  FG3   CAP.
                                                                S02  PAST. HOURS HOPS  HCUPS FACTOR


 6/60  SYSTEM      92.1                                                      720   696         79.3

       «* PRC3LEMS/SOLUTIONS/COKMENTS

                         DURING JUNE THE SCRUBBER EXHIBITED AN AVAILABILITY OF 92.IX.  THERE MAS
                         GREATER SCRUBBER CAPACITY AVAILABLE THAN REQUIRED BY THE BOILER.  NO
                         PROBLEMS WERE REPORTED FOR JUNE.

                         DAMPER PROBLEMS REPORTED PREVIOUSLY HAVE BEEN ELIMINATED.  THE OLD CPERATCR
                         MECHANISMS MERE REPLACED WITH OPERATORS SUPPLIED BY ANOTHER MANUFACTURER.

                         ONE OF THE MARBLE BEDS IS STILL PARTIALLY PLUGGED.  THE MATERIAL SEEMS TO
                         BE HARD CALCIUM SULFATE SCALE.  THE SCALE MILL P3C3ABLY NOT CLEAR FLSTHEH
                         THROUGH DISSOLUTION DURING NORMAL SCRUBBER OPERATIONS AS HAD 3EEV HOPED.
                         ALTHOUGH THE MODULE MUST OPERATE AT LCHEH THAN OESIGN GAS FLCH SCRU2QEH
                         OPERATIONS ARE NOT HAMPERED OVERALL BECAUSE THE SYSTEM HAS SOME DESIGN
                         SPARE CAPACITY..

                         THE REHEATER PROBLEM REPORTED PREVIOUSLY HAS OCCURRED ON THFEE PEHEATEPS
                         NOW.  THE FAILURE OF THE REHEATER DUCT BOTTOM PANELS MAY BE A PESULT OF AN
                         UNDERSIZED DEFLECTION SHIELD BENEATH THE TUBE BANKS.  IT IS ALSO POSSI3LE
                         THAT THE DUCTING HAS IMPROPERLY UELCED.

 7/80  SYSTEM                                                                74*

 8/80  SYSTEM                                                                744

 9/flO  SYSTEM                                                                720

       »* PRCBLEMS/SOUJTICNS/COMMENTS

                         THE UTILITY REPORTED THAT NO MAJOR SCRUBBING SYSTEM PROBLEMS OCCURRED
                         DURING THE THIRD QUARTER 1980.

                         THE PROBLEM REPORTED EARLIER WITH THE MIST ELIMINATOR HASH PIPING IS
                         PRESENTLY BEING SOLVED BY REPLACING THE PIPING WITH CARBON STEEL.

10/80  SYSTEM                                                                744

11/80  SYSTEM                                                                720

12/80  SYSTEM                                                                744

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE OCTOBER  THROUGH DECEMBER PERIOD REPLACEMENT OF THE  MIST ELIMI-
                         NATOR HASH PIPING WITH CARBON STEEL CONTINUED;  AS THE OLD PIPIN3  UEARS  CUT
                         AND  MAINTENANCE  TIME PERMITS.

                         DURING LATE DECEMBER.  THE SLURRY SPRAY PUMP HOUSING CRACKED  DURING A BACK
                         FLUSH.  THIS MAS THE SECOND  TIME IN THO YEARS  THAT THIS PROBLEM HAD
                         OCCURRED.

 1/31  SYSTEM                                                                744

       »» PRCBLEKS/SOLUTIONS/COMMENTS

                         THE  UTILITY REPORTED THAT AT THE BEGINNING OF  THE  YEAR THE SCSUEBE? SYSTEM
                         BEGAN TO SEE VOLUMES OF FLUE GAS GREATER  THAN  THAT PRODUCED  BY  THE  BOILER.
                         IT MAS LATER DISCOVERED THAT THE EXPANSION JOINTS  LOCATED AT THE  ESP HAD
                         CRACKED AND MERE  ALLOWING AMBIENT AIR  TO  ENTER THE SYSTEM.   THE UTILITY
                         REPORTED THEY HAD ORIGINALLY ORDERED VITROU EXPANSION JOINTS BUT INSTEAD
                         RECEIVED CHLOROBUTYL JOINTS  WHICH SUBSEQUENTLY FAILED.   DUE  TO THE  ZN-
                                               960

-------
                                              EPA UTILITY  F6D  SURVEY:  OCTOBER - DECEMBER 1981

SOUTHWESTERN PUBLIC SERVICE:  HARRINGTON 1 (CONT.)
	PERFORMANCE DATA	
FERICD MCDULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PEP  BOILE3  FGD   CAP.
                                                                302  PART.  HCUP.S HCL'SS  HC'JRS FAC7C3

                         CREASED GAS LOAD THE UTILITY HAS HAD TO PUN MCRE MCDULES THAN NORMALLY
                         NECESSARY FOR A GIVEN BOILER LOAD.   THE UTILITY PLANS TO REPLACE THE
                         EXPANSION JOINTS DURING THE NEXT SCHEDULED OUTAGE  IN MAY.

 3/81  SYSTEM                                                                67C

 3/81  SYSTEM                                                                744

       »« PROBLEMS/SOLUTIONS/COMMENTS

                         MODULE 3 MAS SHUT DOWN FOR 24 HOURS TO REPLACE A RU3BER PUMP LINER WHICH
                         HAD BEEN WORN AWAY BY THE PUMP IMPELLERS.

                         EXCEPT FOR THE PUMP LINER AND EXPANSION JOINT FAILURES THE SCRU2SER SfSTEM
                         OPERATED WELL THROUGHOUT THE JANUARY-MARCH PERIOD.
                                                961

-------
 EPA UTILITY FG3 SURVEY: OCTC3ER - OECEM3ER 1981

                                           SECTION 15
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUM3ER
CIT
COUNTHY
ECGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NCX EMISSION LIMITATICN - NG/J
NET PLANT GENERATING CAPACITY - MM
G=OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 «* UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BCILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

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

**» PARTICLE CONTROL

 *» MECHANICAL COLLECTOR
     TYPE
     SUPPLIER

 »* FABRIC FILTER
     NUMBER
     TYPE

 «» ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS CAPACITY - CU.M/S
     INLET FLUE GAS TEMPERATURE - C
     PRESSURE CROP - KPA

 *« PARTICLE SCRUBBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LII1EH SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
CHUGOKU ELECTRIC
SHIMONOSEKI
1
SHIMONOSEKI
JAPAN
******
******
  219.
******
  575
  175
****»
*****
  175
MITSUBISHI
PULVERIZED COAL
BASE
  £66.27
  130.0
  200.
CONCRETE
    3.0
               (****»« LB/M13TU)
               (   .510 L3/MK3TU)
               («***»* LB/MM3PJJ
               (  564255 ACFM)
               (  £66 F)
               (  656 FT)
               (  9.7 FT)
               ( 10766 BTU/LB)
                ******
COAL
******
25046.

   24.60
******
    2.30
******
     .59
******
     .04
0.01-0.11
MULTICLONES
MITSUBISHI
 0
NONE
COLO SIDE
MITSUBISHI HEAVY INDUSTRIES
  246.1        ( 521589 ACFM)
  140.0        (  284 F)
     .6        (  3. IN-H20)
SPRAY TOMER
NR
H3
MITSUBISHI
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
NONE
 1
                                               962

-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEASE? 1S81
CHUGCXU ELECTRIC:  SHIMONOSEKI i ICONT.)

     LIQUID RECIRCULATICN RATE - LITER/S
     L/G PATIO - LITE=/CU.M
     SUPERFICIAL GAS VELOCITY - M/S
     INLET GAS FLOW «ATE - CJ.M/S

**» FGD SYSTEM

 *» GENERAL DATA
     SALEABLE FR03UCT/THRCWAUAY PRODUCT
     S02 PEMOVAL MODE
     FPCCESS TYPE
     PROCESS ADDITIVES
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     UNIT DESIGN S02 REMOVAL EFFICIENCY  - X
     CURRENT STATUS
     COMMERCIAL START-UP
     INITIAL START-UP
     CONTRACT AWARDED

 ft* DESIGN AND OPERATING PARAMETERS

 ** QUENCHER/PRESATURATOR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «* ABSORBER
     NUMBER
     NTJMSER OF SPARES
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TPAOE NAME/COMMON TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCULATICN RATE - LITER/S
     GAS-SIDE PRESSURE DROP - KPA
     SUPERFICAL GAS VELOCITY - M/SEC
     INLET GAS FLOW - CU. M/S
     INLET GAS TEMPERATURE - C
     S02 REMOVAL EFFICIENCY - 7.
     PARTICLE REMOVAL EFFICENCY - 7.

 *» MIST ELIMINATOP
     PRE-MIST .LIM1NATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     NUM3ER OF STAGES
     PRESSURE DROP - KPA
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     WASH WATER SOURCE
     WASH HATE - L/S

 ** REHEATER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     TEMPERATURE INCREASE - C
     INLET FLUE GAS FLOW RATE - CU. M/S
     INLET FLUE GAS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
    544.3
      3.0
     13.1
    203.7
(  6S40 G?M)
(22.5 GAL/lOOOACr)
(    63.0 FT/S)
(  431725 ACFM)
  SALEABLE PRODUCT
  WET SCRUBBING
  LIMESTCNE
  NONE
  MITSUBISHI HEAVY INDUSTRIES
  MITSUBISHI
  FULL SCALE
  RETROFIT
     85.00
   1
   7/79
   5/79
   5/77
  NR
  NR
   1
   0
  COMBINATION
  NR
  N/A
  MITSUBISHI
  CARBON STEEL
  AISI 1110
  H/A
  ORGANIC
  NR
  NR
   2722.
      1.0
      3.0
    203.73
     50.0
     69.0
     90.0
(43200 GPM)
(  3.9 IN-H20)
(   9.3 FT/S)
(  431725 ACFM)
(   122 F)
  PRIMARY COLLECTOR
  IMPINGEMENT
  BAFFLE
  CLOSED VANE
      2
       .1
  NR
  NR
  FRESH
    200.0
(   .6 IN-H20)
                 (  3170 GAL/MIN)
  WASTE HEAT RECOVERY
  NR
  NR
    157.8
    203.73
    105.0
  NR
  NR
(   264 F)
(  431725 ACFM)
I   221 F)
 963

-------
 EPA UTILITY FGO SUSVEf: CCTC3ER - DECEMBER 1981

chusoKu ELECTRIC: SHIHCNOSEKI i ICONT.)
 *» FANS
     SUPPLIER
     FLUE GAS FLOW PATE - CU.M/S
     FLUE GAS TEMPERATURE - C

 ** DAKPEPS
     FUNCTION
     GENERIC TYPE
     S°EC:FIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LIMES GENEPIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 ** REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 »» SOLIDS CONCENTHATINS/DEHATERING
     DEVICE
     NUMBER
     NUMBER OF SPARES
     FEED STREAM CHARACTERISTICS
     OUTLET STREAM CHARACTERISTICS

 ** SOLIDS CCNCENTRATING/DEMATERIHG
     DEVICE
     NUMBER
     NUMBER OF SPARES
     DIMENSIONS - FT
     FEED STREAM CHARACTERISTICS
     OUTLET STREAM CHARACTERISTICS

**» SALEABLE BYPRODUCTS
     NATURE
     FULL LOAD QUANTITY - M T/H
     QUALITY - X

*»» SLUDGE

 *» TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 ** DISPOSAL
     NATURE
     TYPE
     SITE TREATMENT

 *« WATER BALANCE
     WATER LOOP TYPE
     EVAPORATION MATER LOSS - LITER/S
     POND SEEPAGE/RUNOFF HATER LOSS - LITERS/S
     MAKEUP WATER ADDITION - LITERS/S
MITSUBISHI HEAVY INDUSTRIES
  £94.04       ( 623103 ACrM)
  140.0        (  284 F)
NR
NR
US
NR
NR
NR
NR
MET BALL MILL
NR
NR
CENTRIFUGE
 5
0
ZS7. SOLIDS
90X SOLIDS
THICKENER
 1
0
33.0 DIA X 10.0
57. SOLIDS
25X SOLIDS
GYPSUM
    6.98
   99.0
NR
NR
NR
NR
NR
MR
C  7.70 TPHI
OPEN
54
    3.0
                                                    6.8
(    47 GPM)

C   108 GPM)
                                               964

-------
                                              EPA UTILITY F6D SURVEY:  OCTOSER  - DECETOsR 1931

CHU3CKU ELECTRIC: SHIKONOSEKI i CCOHT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERA6IHTY RELIABILITY UTILIZATION  X REMOVAL   PE=?  EOILE5  FCO   CAP.
                                                                502  PART.  HOUSS HOVJSS  HCUS5 FACTCR
7/79
6/79
9/79
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100
100
100
.0
.0
.0
50.
100.
100.
0
0
0
744
744
720
372
744
7CO
372
744
7:0
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
100.0
100.0
100.0
100.0
100.0
93.5
100.0
100.0
100.0
100.0
100.0
93.5
          FROBLEMS/SOLUTIONS/COMMENTS

                         COMMERCIAL OPERATIONS BEGAN IN THE KIDDLE OF JULY 1979.  THE FGD LIMIT HAS
                         OPERATED CONTINUOUSLY THROUGH THE THIRD QUARTER WITH NO PROBLEMS.

                                                                             744   744    744

                                                                             720   720    7CO

                                                                             744   744    696

       »« PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGD UNIT OPERATED CONTINUOUSLY THROUGH THE FOURTH QUARTER EXCEPT FCR A
                         2 DAY SHUTDOWN TO INSPECT THE GAS-GAS HEATER DURING DECEMBER.  THE 3CILEH
                         WAS OPERATED FIRING A LOU SULFUR OIL DURING THE TUO DAYS.

 1/80  SYSTEM     100.0       100.0       100.0       100.0                  744   744    744

 2/80  SYSTEM     100.0       100.0       100.0        53.4                  696   372    372

       ** FHOSLEMS/SOLUTION5/COKMENTS

                         DURING JANUARY AND THE FIRST HALF OF FEBRUARY THE FGD UNIT OPERATED WITH
                         NO FROSLEHS.  THE BOILER MAS TAKEN OFF-LINE ON FEBRUARY 8 F03 SCHEDULED
                         MAINTENANCE.

 3/80  SYSTEM     100. a                                  .0                  744     0      0

       *» PRCBLEMS/SOLUTIONS/CDKMENTS

                         THE BOILER REMAINED DOHN THROUGH MARCH FOR ANNUAL MAINTENANCE.

 4/80  SYSTEM     100.0       100.0       100.0       182.4                  720   593    593

       »* PRCBLEMS/SOLUTIONS/COKMENTS

                         DURING THE ANNUAL MAINTENANCE THE SCR (SELECTIVE CATALYTIC REDUCTICM OF
                         MOX) UNIT MAS CONNECTED BETWEEN THE BOILER AND AIR FRtHEATER.  AFTE3 THE
                         STARTUP OH APRIL 6, COAL ONLY HAS BEEN USED IBEFCRE FEBRUARY, COAL ANO
                         OIL HERE USED 50:50).  EXCEPT FOR A 2 HOUR SHUTDOWN FOR A TURBINE TEST CM
                         APRIL 7. THE FGO SYSTEM HAS OPERATED CONTINUOUSLY WITH HO PROBLEMS.

 5/80  SYSTEM     100.0       100.0       100.0        90.3                  744   672    672

       *« PROBLEMS/SQLUTIONS/COHMENTS

                         THE FGD SYSTEM OPERATED CCNTINOUSLY WITH NO PROBLEMS.  A THPEE DAY
                         SHUTDOWN FCR INSPECTION OF THE SCR UNIT FROM MAY 16 TO MAY 19 MAS THE
                         ONLY DOWN TIME EXPERIENCED DURING HAY.

 6/30  SYSTEM     100.0       100.0       100.0       100.0                  7ZO   7£0    7ZO  99.4
                                               965

-------
 EPA UTILITY FGD SURVEY:  OCTCEER - DECEMBER 1981
CHUGOKU ELECTRIC: sxir:cr:os£Ki i ICCHT.I
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FGD   CAP.
                                                                502   PART.  HOURS HOURS  HOURS FACTOR


       *» PROBLEMS/SOLUTIONS/COMHENTS

                         THE FGO SYSTEM OPERATED CQNTINOUSLY WITH NO PROBLEMS DURING JUNE.

 7/80  SYSTEM     100.0       100.0       100.0       100.0                  744   744    744  98.9

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGD SYSTEM OPERATED DURING JULY WITH NO PROBLEMS.

 8/80  SYSTEM      83.7        88.7        88.7        88.7                  744   744    660  99.5

       *« PRGBLEMS/SOLUTICNS/COMMENTS

                         CURING AUGUST THE FGO SYSTEM HAS SHUT DOWN FOR 64 HOURS DUE TO SOME PLUS-
                         GINS IN THE REHEATER.  DURING THIS TIME THE REHEATER MAS MATER HASHED AND
                         THE SOOT BLOWER SYSTEM HAS IMPROVED.

 9/60  SYSTEM      89.0        69.0        89.0        89.0                  720   720    641  97.3

       »« PHOBLEMS/SOLUTICNS/COMttENTS

                         DURING SEPTEMBER PROBLEMS WITH PLUGGING IN THE REHEATER RECURRED.  THE
                         TROUBLE WAS CAUSED BY ESP PROBLEMS. BY WHICH A LARGE AMOUNT OF FLYASH
                         WENT INTO THE REHEATER.

10/80  SYSTEM     100.0        97.4       100.0        88.0                  744   673    655  83.5

       *» PR03LEMS/SOLUTIONS/COMKENTS

                         DURING OCTOBER THE BOILER MAS TAKEN OFF LINE FOR THREE DAYS FOR AM
                         INSPECTION OF THE NOX REMOVAL SYSTEM.

11/80  SYSTEM     100.0       100.0       100.0       100.0                  720   720    720  99.4

12/80  SYSTEM     100.0       100.0       100.0       100.0                  744   744    744  99.6

       ** PR03LEMS/SOLUTIONS/COMMENTS

                         NO PROBLEMS WERE ENCOUNTERED DURING THE MONTHS OF NOVEMBER AHO DECEMBER.

 1/81  SYSTEM                                                                "44

 2/81  SYSTEM                                                                672

 3/81  SYSTEM                                                                744

       «» PROBLEM5/SOLUTIONS/COMMENTS

                         THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME!  HOWEVER THE
                         DATA MILL BE AVAILABLE IN THE SECOND QUARTER 1961 REPORT.
                                               966

-------
                                              EPA UTILITY FGO SUPVEY:  OCTCSEH - DECEMEE= 1«31

                                           SECTION 15
                DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT HUK3ER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - HS/J
SC2 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GPOSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - KM
NET UNIT GENERATING CAPACITY HO/FGO - MM
EQUIVALENT SCRU3BED CAPACITY - MM

 *« UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SEPVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 ** FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - '/.
     RANGE CHLORIDE CONTENT - 7.

*** PARTICLE CONTROL

 *» MECHANICAL COLLECTOR
     NUMBER
     TYPE

 »* ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS CAPACITY - CU.M/S
     INLET FLUE GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - X

 ** PARTICLE SCRUBBER
     NUMBER
     NUMBER OF SPARES
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCULATION RATE - LITER/S
     L/G RATIO - LITER/CU.M
ELECTRIC POWER DEVELOPMENT
ISC30
1
YOKOHAMA
JAPAN
   20.
   58.
*******
  238
  265
  238
*****
  265
IHI
PULVERIZED COAL
BASE
  405.36
  170.0
  122.
CAPBON STEEL
    3.7
   .046 L3/MMBTU)
   .135 LS/MM3TU)
  650000 ACFM)
  333 F)
  400 FT)
               ( 12.0 FT)
(  11160 BTU/L3)
 11160-11520
COAL
******
25958.

   16.00
15.0-17.0
    7.00
6.0-8.0
      .60
0.2-0.6
****»**«
*******
 0
NONE
COLD SIDE
TOYO ENGINEERING
  353.2        ( 743362 ACFM)
  150.0        (  302 F)
   98.0
 1
 0
VENTURI TOWER
N3
NS
IHI-CHEMICO
43.6 DIA X 101.4
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
HONE
 1
 £194.1        (34827 G?M)
    9.4        (70.0 GAL/10COACF)
                                               967

-------
 EPA UTILITY FGD SL'WEY:  CCTC3ER - DECEMBER 1961

ELECTRIC PCHER DEVELOPMENT:  ISOGO 1 (CONT.)

     F35SSIPE DROP - KPA
     SUPEPFICIAL GAS VELOCITY - M/S
     INLET GAS FLOW KATE  - CU.M/S
     INLET GAS TEMPERATURE - C

*** FGO SYSTEM
 <* GENERAL DATA
     SALEABLE FRODUCT/THROMAMAY PRODUCT
     S02 REM3VAL MCCE
     F3CCESS T^PE
     SYSTEM SLVPLIEH
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
     UMIT DESIGN S02 REMOVAL EFFICIENCY - 7.
     CURRENT STATUS
     COMMERCIAL START-UP
     INITIAL START-UP

 ** DESIGN AND OPERATING PARAMETERS

 *» CUENCHER/FRESATURATOH
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 *» ABSORBER
     NUMBER
     NUJ13ER OF SPARES
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LIMER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCUUTION RATE - LITER/S
     L/G RATIO - L/CU.M
     GAS-SIDE PRESSURE DROP - KPA
     SUPERFICAL GAS VELOCITY - M/SEC
     INLET GAS FLOW - CU. M/S
     INLET GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - 7.

 «» MIST ELIMINATOR
     PPE-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONFIGURATION
     NUMBER OF STAGES
     NUMBER OF PASSES PER STAGE
     PRESSURE DPOP - KPA
     SUPEHFICAL GAS VELOCITY - H/S
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     WASH FREQUENCY

 ** REHEA-ER
     GENERIC TYPE
     SPECIFIC TYPE
     TPADE NAME/COMMON TYPE
     TEMPERATURE INCREASE - C
     INLET FLUE GAS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     1.5
     3.3
   424.6
   170.0
( 5.9 IN-H20)
(   10.0 FT/S)
( 69936* ACFM)
(  333 F)
 SALEABLE PRODUCT
 MET SCRUBBING
 LIMESTCNE
 IHI-CHEMICO
 FULL SCALE
 RETROFIT
7.   97.00
    95.00
  1
  3/76
 12/75
 NR
 NR
  1
  0
 VENTURX TOMER
 NR
 NR
 IHI/CHEMICO
 43.5 DIA X 76.8
 CARBON STEEL
 NR
 N/A
 ORGANIC
 GLASS FLAKE-FILLED POLYESTER
 NR
 NONE
  1
  2194.
     9.4
     1.5
     3.0
   566.28
    55.0
    96.7
(34827 GPM)
(  70.0 GAL/1000 ACPI
(  5.9 IN-H20)
(  10.0 FT/S)
(1200000 ACFM)
(   131 F)
 PRIMARY COLLECTOR
 IMPINGEMENT
 BAFFLE
 CLOSED VANE
 HORIZONTAL
     4
     4
      .5        (
     3.0        (
 ORGANIC
 NR
 INTERMITTENT
  2.0 IN-H20)
   9.8 FT/S)
DIRECT COMBUSTION
NR
OIL
83.9
120.0
NR


( 151 F)
( 248 F)

                                               968

-------
                                              EPA UTILITY  F6D  SURVEY:  OCTCSER  -  DECEM2ER  1°S1
ELECTRIC POWER  DEVELOPMENT:  ISOGO  1  (COHT.)

     CONSTRUCTION MATERIAL  SPECIFIC  TYPE

 «» FANS
     NUMBER
     NUMBER OF  SPARES
     FUNCTION
     FLUE GAS FLOW RATE  - CU.M/S
     FLUE GAS TEMPERATURE - C

 «» FANS
     NUMBER
     NUMBER OF  SPARES
     APPLICATION
     FLUE GAS FLOW RATE  - CU.M/S
     FLUE GAS TEMPERATURE - C

 ** DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL  GENERIC TYPE
     CONSTRUCTION MATERIAL  SPECIFIC  TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 «* REAGENT PREPARATION  EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 ** TANKS
     SERVICE
     OXIDATION TOMER FEED
     RECYCLE
     SLURRY
     THICKENER OVERFLOW
     FILTRATE

 ** PUMPS
     SERVICE
     SLURRY MAKEUP
     ABSORBER RECIRCULATICN
     OXIDATION TCUER SUPPLY TRANSFER
     FILTRATE

 ** SOLIDS CONCENTRATING/DEWATERING
     DEVICE
     NUMBER
     NUMBER OF SPARES
     FEED STREAM CHARACTERISTICS
     OUTLET STREAM CHARACTERISTICS

 *« SOLIDS CCNCENTRATING/OEUATERING
     DEVICE
     NUMBER
     NUMBER OF SPARES
     DIMENSIONS - FT
     FEED STREAM CHAPACTERISTICS
     OUTLET STREAM CHARACTERISTICS

»** SALEABLE BYPRODUCTS
     NATURE
     FULL LOAD QUANTITY - M T/H
     DISPOSITION
NR
 Z
 0
BOOSTER
  36Z.14
  170.0
(  767400 ACFM)
(   336 F)
 1
 0
OXIDATION BLOWER
     .86       (
   10.0        (
NR
NR
NR
NR
NR
NR
NR
MET BALL KILL
NR
NR
                                                NUMBER
    1830 ACFM)
    50 F)
   Z
«**»
   1
   1
   1
NUMBER

   3
   8
   2
   Z
CENTRIFUGE
 4
1
18.SX SOLIDS
90X SOLIDS
THICKENER
  1
0
20.0 OIA X  10.0
6.SX SOLIDS
18.6X  SOLIDS
 GYPSUM
     4.53
 MARKETED
(  5.00 TPH)
                                               969

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

ELECTRIC POHER DEVELOPMENT: ISOSO 1 ICONT.)


*•*« SLUDGE

 ** TPEATMEMT
     r.ETHO?                                     FC3CEO OXIDATION
     CEVICE                                     OXIDATION TANK
     PROPRIETARY PROCESS                        N/A

 »* DISPOSAL
     MATURE                                     NR
     TYPE                                       NR
     SITE TREATMENT                             KR

 ** PROCESS CONTROL AND INSTRUMENTATION
     CHEMICAL PARAMETERS                        PH
     PROCESS CONTROL MANNER                     AUTOMATIC
     PROCESS CHEMISTRY MODE                     FEEDBACK

 *» WATER BALANCE
     HATER LOOP TYPE                            OPEN
     POND SEEFAGE/FUNOFF HATER LOSS - LITERS/S  40
     MAKEUP WATER ADDITION - LITERS/S              22.3        (   354 GPM)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  EOZLER  FGD   CAP.
                                                                S02  PART. HOURS HOURS  HOIRS FACTOR


 4/78  SYSTEM                                                                720

 5/78  SYSTEM                                                                744

 6/78  SYSTEM                                                                720

 7/78  SYSTEM                                                                744

 8/78  SYSTEM                                                                744

 9/78  SYSTEM                                                                720

10/78  SYSTEM                                                                744

11/78  SYSTEM                                                                7£0

12/78  SYSTEM                                                                744

 1/79  SYSTEM                                                                744

 2/79  SYSTEM                                                                672

 3/79  SYSTEM                                                                744

       *« PR09LEMS/SOLUTIONS/COMMENTS

                         100X AVAILABILITY FOR THE FGD SYSTEM HAS REPORTED DURING THE PERIOD APRIL
                         1978 THROUGH MARCH 1979.  THE SYSTEM S02 REMOVAL EFFICIENCY WAS PEPCRTEDLY
                         AVERAGING 95X.

 4/79  SYSTEM                                                                720

 5/79  SYSTEM                                                                744

 6/79  SYSTEM                                                                720

 7/79  SYSTEM                                                                744

 8/79  SYSTEM                                                                744
                                               970

-------
                                              EPA UTILITY FGO  SURVEY:  OCTOBER - DECEASES i«81

ELECTRIC POWER DEVELOPMENT:  ISOSO 1 (CONT.J
	PERFORMANCE DATA	
PERIOD MOBULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL   FE3  BOILED  FG3   CAP.
                                                                SOI  PART.  HOU3S HOLSS  HOURS FAC7C3


 9/79  SYSTEH                                                                7CO

10/79  SYSTEH                                                                744

11/79  SYSTEH                                                                720

12/79  SYSTEH                                                                744

 1/80  SYSTEM                                                                744

 2/80  SYSTEM                                                                696

 3/80  SYSTEM                                                                744

       ** PHOSLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION MAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 FERIC3.

 4/60  SYSTEM     100.0       100.0       100.0       100.0                  720   7CO    720

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGO SYSTEM OPERATED ALONG WITH THE BOILER FOR  THE ENTIRE MONTH OF
                         APRIL.

 5/80  SYSTEM     100.0       100.0       109.0        52.B                  744   393    593

 6/80  SYSTEH     1QO.O       100.0       109.0        10.0                  7CO    7£     72

       »* PROBLEMS/SOLUTIOHS/COMMENTS

                         THE BOILER MAS SHUT DOWN FROM MAY 17 TO JUNE 27 FOR ANNUAL MAINTEN-
                         ANCE.  THE FGD SYSTEM MAS OPERATED DURING ALL OF THE EDILER OPiRATICN
                         IN MAY AND JUNE.
7/80
6/80
9/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100.0
100.0
100.0
100.0
100.0
99. a
95.30
95.70
96. ZO
744
744
720
744
744
710
744
744
716
90.9
91.9
90.4
       ** PROBLEMS/SOLUTIOHS/COMMENTS
                         DURING SEPTEMBER THE BOILER HAS OUT OF SERVICE FOR APPROXIMATELY TWO HOURS
                         TO CHANGE THE TAP ON THE MAIN TRANSFORMER.
10/80
11/80
12/60
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100.0
100.0
100.0
91.4
100.0
100.0
96.00
95.50
95.00
744
720
744
680
7EO
744
680
720
744
S4.5
91.7
93.2
       *» PROBLEMS/SOLUTIONS/COMKENTS

                         DURING JULY THROUGH DECEMBER THE FGD SYSTEH EXPERIENCED NO OPERATIONAL
                         PROBLEMS.

 1/81  SYSTEM                                                                744

 2/81  SYSTEH                                                                672

 3/81  SYSTEM                                                                744
                                               971

-------
 EPA UTILITY FGO SURVEY:  CC7CBER - DECEMBER 1981

ELECTRIC POWER DEVELOPMENT:  ISCGO 1 (CONT.)
	PERFORMANCE DATA			
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  Y. REMOVAL   PE=J  BOILER  FGO   CAP.
                                                                SOZ   PART.  HCU'S HOUSS  HC'J'S FACTOR


       «» PROBLEHS/SOLUTICNS/COMMENTS

                         THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME;   HOWEVER THE
                         DATA MILL BE AVAILABLE IN THE SECOND QUARTER 1981  REPORT.
                                               972

-------
                                              EPA UTILITY FGD SURVEY: OCTCSER - DECEMBER 1931

                                           SECTION IS
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY MAKE
PLANT HArS
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
rARTICULATE EMISSION LIMITATION - NG/J
£02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY MO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - KU

 *» UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     E'JILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 *« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     PAHGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

**» PARTICLE CONTROL

 *« MECHANICAL COLLECTOR
     NUMBER
     TYPE
ELECTRIC POWER DEVELOPMENT
ISCGO
YOKOHAMA
JAPAN
******
   20.
   58.
******
  23d
  265
  233
  246
  265
(   .046 LS/MMBTU)
(   .135 LB/Mr,3TU)
(»***** L3/MM3TU)
IHI
PULVERIZED COAL
BASE
405.36 (
170.0 (
140. (
CARBON STEEL
3.7 (



859000 ACFM)
333 r)
460 FT)

12.0 FT)
COAL
******
25958.

   16.00
15.0-17.0
    7.00
6.0-8.0
     .60
0.2-0.6
******»»
******
 0
NONE
(  11160 BTU/LB)
 11160-11520
 *« ESP
     NUM3ER
     INLET FLUE GAS CAPACITY - CU.M/S
     INLET FLUE GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - X

 *» PARTICLE SCRUBBER
     NUMBER
     NUMBER OF SPARES
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIHCULATION RATE - LITER/S
     L/G RATIO - LITER/CU.M
     PRESSURE DROP - KPA
     SUPERFICIAL GAS VELOCITY - ft/3
  356.6
  150.0
   98.0
(  755654 ACFM)
(   302 F)
 1
 0
VENTURI TOMER
NR
NR
IHI-CHEMICO
43.6 OIA X 101.4
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NONE
 1
 2194.1        (34827 GPM)
    9.4        (70.0 GAL/1000ACF)
    1.5        (5.9 IN-H20)
    3.0        (   10.0 FT/S)
                                               973

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1961
ELECTRIC POWER DEVELOPMENT: ISOGO 2 (CONT.)

     INLET GAS FLOW RATE - CU.M/S
     INLET GAS TEMPERATURE - C

*»* FGO SYSTEM

 »* GENERAL DATA
     SALEABLE PPQOUCT/THROUAUAY PRODUCT
     502 REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     HEW/RETSOFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
     UNIT DESIGN S02 REMOVAL EFFICIENCY - X
     ENERGY CONSUMPTION - X
     CURRENT STATUS
     COMMERCIAL START-UP
     INITIAL START-UP

 <*« DESIGN AND OPERATING PARAMETERS

 *» QUENCHER/PPESATURATOR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 ** ABSORBER
     NUMBER
     NUKSER OF SPARES
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECALCULATION RATE - LITER/S
     L/G PATIO - L/CU.M
     GAS-SIDE PRESSURE DROP - KPA
     SUPERFICAL GAS VELOCITY - M/SEC
     INLET GAS FLOW - CU. M/S
     INLET GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - X

 ** MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONFIGURATION
     NUM3EP OF STAGES
     NUMBER OF PASSES PER STAGE
     PRESSURE DROP - KPA
     SUPERFICAL GAS VELOCITY - M/S
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     WASH FREQUENCY

 *» REHEATER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     TEMPERATURE INCREASE - C
     INLET FLUE GAS FLOW RATE - CU. M/S
     INLET FLUE GAS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
   424.6
   170.0
(  899364 ACFM)
(   333 F)
 SALEABLE PRODUCT
 WET SCRUBBING
 LIMESTONE
 IHI-CHEMICO
 FULL SCALE
 RETROFIT
X   97.00
    95.00
     3.0
  1
  5/76
  3/76
 NR
 NR
  1
  0
 VENTURI TOMER
 NR
 NR
 IHI/CHEMICO
 43.5 DIA X 76.8
 CARBON STEEL
 NR
 N/A
 ORGANIC
 GLASS FLAKE-FILLED POLYESTER
 NR
 NONE
  1
  2194.
     9.4
     1.5
     3.0
   566.28
    55.0
    96.7
(34327 GPM)
(  7C.O GAL/1000 ACF)
(  5.« IN-H20)
(  10.0 FT/S)
(1200000 ACFM)
(   131 F)
 PRIMARY COLLECTOR
 IMPINGEMENT
 BAFFLE
 CLOSED VANE
 HORIZONTAL
     4
     4
      .5
     3.0
 ORGANIC
 NR
 INTERMITTENT
 DIRECT COMBUSTION
 NR
 OIL
    83.9
   132.50
   120.0
 NR
(  2.0 IN-H20)
(   9.8 FT/S)
(   151 F)
(  280733 ACFM)
(   248 F)
                                               974

-------
ELECTRIC POWER DEVELOPMENT: ISOSO 2 (CONT.)

     COMSTRUCTICM MATERIAL SPECIFIC TYPE

 ** FANS
     NUMBER
     NUMBER OF SPARES
     FUNCTION
     FLUE GAS FLOW RATE - CU.M/S
     FLUE GAS TEMPERATURE - C

 ** FANS
     NUMBER
     N'-MSER OF SPARES
     APPLICATION
     FLUE GAS FLOW PATE - CU.M/S
     FLUE GAS TEMPERATURE - C

 *» DAMPERS
     FUNCTIQ>4
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 »* REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 ** TANKS
     SERVICE
     OXIDATION TOWER FEED
     SLURRY
     THICKENER OVERFLOW
     FILTRATE

 «* PUMPS
     SERVICE
     SLURRY MAKEUP
     ABSORBER RECIRCULATION
     OXIDATION TOWER SUPPLY TRANSFER
     FILTRATE

 «* SOLIDS CONCESTRATING/OEVIATERING
     DEVICE
     NUMBER
     NU.-3ER OF SPARES
     FEED STREAM CHARACTERISTICS
     OUTLET STREAM CHARACTERISTICS

 ** SOLIDS CONCENTRATING/OEHATERING
     DEVICE
     NU."SER
     NUMBER OF SPARES
     DIMENSIONS - FT
     FEED STREAM CHARACTERISTICS
     OUTLET STREAM CHARACTERISTICS

**» SALEABLE BYPRODUCTS
     NATURE
     FULL LOAO QUANTITY - M T/H
     DISPOSITION

««* SLUDGE
                                              EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
NR
 2
 0
BCDSTER
  252.14
  170.0
(  767430 ACFM)
(   333 F)
 1
 0
OXIDATION BLOWER
     .66       (   1830 ACFM)
   10.0        (   50 F)
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
NR
NR
                                                NUMBER
NUMBER

   2
   8
   2
   2
CENTRIFUGE
 4
0
18.5X SOLIDS
90X SOLIDS
THICKENER
 1
0
20.0 DIA X 10.0
8.SX SOLIDS
18.6X SOLIDS
GYPSUM
    4.53
MARKETED
(   5.00 TPH)
                                               975

-------
 EPA UTILITY FGO SURVEY:  OCTCSER - DECEMBER 1981

ELECTRIC POWER DEVELOPMENT: ISQGO 2 (CONT.)
 <•» TREATMENT
     METHOD                                     FORCED OXIDATION
     DEVICE                                     OXIDATION TANK
     FBOFRIETARY PROCESS                        N/A

 M* DISPOSAL
     NATURE                                     NR
     TY"»E                                       MS
     SITE TREATMENT                             N3

 ** P70CESS CONTROL AND INSTRUMENTATION
     CHEMICAL PARAMETERS                        PH
     PROCESS CONTROL MANNER                     AUTOMATIC
     PROCESS CHEMISTRY MODE                     FEEDBACK

 *» MATER BALANCE
     WATER LOOP TYPE                            OPEN
     POND SEEPAGE/RUNOFF MATER LOSS - LITERS/S  40
     MAKEUP MATER ADDITION - LITERS/S              22.3        (   354 GPM)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  V. REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART. HOURS HOURS  HOURS FACTOR


 4/78  SYSTEM                                                                720

 5/78  SYSTEM                                                                744

 6/78  SYSTEM                                                                720

 7/78  SYSTEM                                                                744

 8/78  SYSTEM                                                                744

 9/78  SYSTEM                                                                720

10/78  SYSTEM                                                                744

11/78  SYSTEM                                                                720

12/78  SYSTEM                                                                744

 1/79  SYSTEM                                                                744

 2/79  SYSTEM                                                                672

 3/79  SYSTEM                                                                744

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         1002 AVAILABILITY FOR THE FGD SYSTEM WAS REPORTED DURING THE PSRIC3 AF'IL
                         1978 THROUGH MARCH 1979.   THE FGO SYSTEM LOGGED A TOTAL OF 1,689 HOURS OF
                         OPERATION.

 4/79  SYSTEM                                                                720

 5/79  SYSTEM                                                                744

 6/79  SYSTEM                                                                720

 7/79  SYSTEM                                                                744

 8/79  SYSTEM                                                                744

 9/79  SYSTEM                                                                720

10/79  SYSTEM                                                                744
                                               976

-------
                                              EPA UTI-     rcO SURVEY:  CCTC3=3 - DECEKE=P 1931

ELECTRIC POWER DEVELOPMENT:  ISOGO 2 (CCNT.)
	PERFORMANCE DATA	
PERIOD r.C3ULE AVAILABILITY OPEHABILITY RELIABILITY UTILIZATION  X PEMOVAL   PER  SOILED  FG3   Ci=.
                                                                S02  PART.  KCL"S HC'JRS  hC'J^S FACTCa


21/79  SYSTEM                                                                720

1C/79  SYSTEM                                                                74*

 1/80  SYSTEM                                                                744

 2/60  SYSTEM                                                                696

 3/60  SYSTEM                                                                744

       ** PHOBLEMS/SOLUTIONS/COrfflENTS

                         NO INFORMATION UAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH I960 PERIOD.

 4/80  SYSTEM     100.0       100.0       100.0        31.3                  720   225    2:5

       <•* PROBLEMS/SOLUTIOHS/COMMENTS

                         OH MARCH 30 THE BOILER MAS SHUTDOWN FOR ANNUAL MAINTENANCE.  THE W4IT
                         REMAINED DOWN THROUGH APRIL 20.  WHEN OPERATIONS COMMENCED THE FGO SYSTEM
                         OPERATED WITH THE BOILER FOR THE REST OF THE MONTH.

 5/80  SYSTEM     100.0       100.0       100.0       100.0                  744   744    744

 6/80  SYSTEM     100.0       100.0       100.0       100.0                  720   720    720

       ** PROBLEMS/SOLUTIONS/COKMENTS

                         BURINS MAY AND JUNE THE FED SYSTEM OPERATED WITH NO REPCRTED PHC3LEMS.

 7/80  SYSTEM     100.0       100.0       100.0        S3.2    94.90         744   656    656  82.0

       »* PHC3LEMS/SOLUTIONS/COKMENT3

                         CUBING JULY THE BOILER WAS OFF LINE APPROXIMATELY 88 HOURS FCR MAINTEN-
                         ANCE.

 6/80  SYSTEM     100.0       100.0       100.0       100.0    96.00         744   744    744  91.9

 9/80  SYSTEM     100.0       100.0       100.0        99.8    95.70         720   713    713  92.1

       *« FROBLEMS/SOLUTIONS/COMKENTS

                         APPROXIMATELY TWO HOURS OF BOILER OUTAGE TIME UAS NECESSARY TO CHAU3E
                         THE TAP OF THE MAIN TRANSFORMER.
10/80
11/80
12/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100.0
100.0
100.0
100.0
100.0
100.0
95.30
95.20
95.00
744
720
744
744
720
744
744
720
744
92.2
92.7

       »» PROBLEMS/SOLUTIONS/COMMEMTS

                         DURING JULY THROUGH DECEMBER THE FG3 SYSTEM OPERATED WITH NO PROBLEMS.

 1/81  SYSTEM                                                                744

 2/81  SYSTEM                                                                672

 3/81  SYSTEM                                                                744
                                               977

-------
 E=A UTIL:TY FGD SURVEY:  OCTOBER -  DECEMBER 1981
ELECTRIC FCWER DEVELOPMENT:  ISCGO 2 (CONT.)
	PERFORMANCE DATA	
PERICD MODULE  AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FG3   CAP.
                                                                S02  PART.  HCLIrS HOUPS  HO'JPS riCTO=


       *» FRCBLEMS/SOLUTIONS/COMMEHTS

                         THE  FIPST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME;   HOUEVET THE
                         DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981  REPORT.
                                               978

-------
                                              EPA  UTILITY  FGD  SURVEY:  OCTOBER  -  DECEMBER  1961

                                           SECTION 15
                DESIGN AND PERFORMANCE  DATA FOR  OPERATIONAL FOREIGN FGD  SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSICN LIMITATION - NG/J
S02 EMISSION LIMITATION - MG/J
HOX EMISSICN LIMITATION - NG/J
NET PLANT GcNEPATINS CAPACITY - MU
G=OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - MM
NET UNIT GENERATING CAPACITY U'O/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 ** UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 *« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - 7.

«*<* PARTICLE CONTROL

 *« MECHANICAL COLLECTOR
     NUMBER
     TYPE

 *» ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS CAPACITY - CU.M/S
     INLET FLUE GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - 7.

 «* PARTICLE SCRUBBER
     NUMBER
     NUMBER OF SPARES
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCULATICN RATE - LITER/S
     L/G RATIO - LITER/CU.M
     PRESSURE DROP - KPA
ELECTRIC POUER DEVELOPMENT
TAKASAGO
1
TAKASAGO
JAPAN
               (  .086 LB/M^3TU)
               (  .350 LB/MH5TU)
               (****** LB/MM5TU)
               ( 774000 ACFM)
               ( 310 F)
               ( 590 FT)
               ( 11.9 FT)
               ( 11160 BTU/LB)
                11160-11520
   37.
  150.
**«*«*
  230
  250
  230
  238
  250
MITSUBISHI
*•«*»•**
BASE
  3o5.25
  154.4
  ISO.
CARBON STEEL
    3.6
COAL
*«***»
25958.

   22.00
******
    7.00
******
    1.80
******
********
******
 0
NONE
COLO SIDE
MITSUBISHI HEAVY INDUSTRIES
  344.3        ( 729507 ACFM)
  154.4        (  310 F)
   99.5
 1
 0
VENTURI TOWER
NR
NR
MITSUI-CHEMICO
37.7 DIA X 62.3
CARBON STEEL
AISI 1110
COSRISION RESISTANT
NONE
 1
 1228.8        (19505 GPM)
    6.5        (48.6 GAL/1000ACF)
    1.5        ( 5.9 IN-H20)
                                               979

-------
 EPA UTILITY FGO SURVEY:  CCT03ER - DECEMBER 1981

ELECTRIC POWER DEVELOPMENT:  TAKASAGO 1 (CONT.)

     INLET GAS FLOW RATE  - CU.M/S
     INLET GAS TEMPEFATUPE - C
     SOS REMOVAL EFFICE.'JCY - X
     PARTICLE REMOVAL EFFICIENCY - X

»«* FGO SYSTEM
  260.5
  154.4
   56.0
   50.0
  552000 ACFM)
   510 F)
 ** GENERAL DATA
     SALEABLE FRCOUCT/THROWAUAY PRODUCT
     S02 REMOVAL MCDE
     FPOCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     HEM/RETROFIT
     UNIT DESIGN SOS REMOVAL EFFICIENCY - X
     ENERGY CONSUMPTION - X
     CURRENT STATUS
     INITIAL START-UP

 *« DESIGN AND OPERATING PARAMETERS

 *« QUENCHER/PRESATURATCR
     CONSTRUCTION MATERIAL GFNERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 ** ABSORBER
     NUMBER
     NUMBER OF SPARES
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TPADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCULATION RATE - LITER/S
     L/G RATIO - L/CU.M
     GAS-SIDE PRESSURE DROP - KPA
     INLET GAS TEMPERATURE - C
     S02 REMOVAL EFFICIENCY - X

 ** ABF-3RBEH
     Nli,~.2ER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TPADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTING OE-/:C£ TYPE
     NUMSER OF CONTACTING ZONES
     LIQUID RECIRCULATION RATE - LITER/S
     INLET GAS FLO'J - CU. M/S
     INLET GAS TEMPERATURE - C
     S02 REMOVAL EFFICIENCY - X

 »* ABSORBER
     NUM5ER
     GENERIC TYPE
     SPECIFIC TYPE
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
MITSUI-CHEMICO
FULL SCALE
RETROFIT
   93.00
    3.2
 1
 2X75
NR
NR
 1
 0
VENTURI TOMER
NR
NR
MITSUI/CHEMICO
45.9 OIA X 78.7
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
 1
 2566.
    6.5
    1.5
   55.0
   85.0
(40727 GPM1
(  48.6 GAL/1000 ACF)
(  5.9 IN-H20)
(   131 F)
VENTURI TOMER
NR
NR
MITSUI/CHEMICO
26.2 OIA X 62.3
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
 1
  610.
   69.37
  154.4
   63.0
SPRAY TOWER
NR
(  9689 GFtt)
(  147000 ACFM)
(   310 F)
                                               980

-------
                                              EPA UTILITY F6D SURVEY: OCTOBER - DECEH5ES 1?31
ELECTRIC POWER DEVELOPMENT:  TAKASASO 1 ICONT.)

     TPADE NAME/COMMON TYPE
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SFFCIFIC MATERIAL
     LINER MATERIAL TPADE NAME/COMMON TYPE
     GAS CCNTACTIK3 DEVICE TYPE
     NUMBER OF CONTACTINS ZONES
     LIQUID RECIRCULATION RATE - LITER/S
     INLET GAS FLOW - CU. tl/S
     INLET GAS TEMPERATURE - C

 ** MIST ELIMINATOR
     FRE-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     NUtiEER OF STAGES
     NUMSER OF PASSES PER STAGE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     WASH MATER SOURCE

 »* REHEATER
     NUMSER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE HAME/CCMMOH TYPE
     INLET FLUE GAS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «* FANS
     FUNCTION

 *« FANS
     APPLICATION

 ** DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 »« REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 ** TANKS
     SERVICE
     CENTRIFUGE OVERFLOW
     ABSOPBENT MAKEUP
     CENTRIFUGE FEED
     PRIMARY LICL'OR
     ABSORBER FEED

 ** PUMPS
     SERVICE
MITSUI/CHEMICO
19.7 DIA X 65.0
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
 1
 9936.
   18.26
  154.4
(»*»»» GPM)
(   38666 ACFM)
(   310 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
    4
    4
NR
NR
BLENDED
DIRECT COMBUSTION
NR
OIL
  120.0         (  248 F)
NR
NR
BOOSTER
OXIDATION BLOWER
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
NR
NR
                                                NUMBER
     CIRCULATION
     PH ADJUSTER CIRCULATION
     REACTOR CIRCULATION
NUMBER

    5
    3
    3
                                               981

-------
 EPA UTILITY F6D SURVEY:  CCTC3ER - DECEMBER 1981

ELECTRIC POWER DEVELOPMENT:  TAKASAGO 1 (CONT.)


 ** SOLIDS CONCEHTRATIHG/DEHATERIN3
     DEVICE                                     CENTRIFUGE
     HUK3ER                                      7
     OUTLET STREAM CHARACTERISTICS              90X SOLIDS

 «* SOLIDS CmiCENTRATING/DEHATERING
     DEVICE                                     THICKENER
     CUTLET STREAK CHARACTERISTICS              20X SOLIDS

*•»« SALEABLE BYPRODUCTS
     NATURE                                     GYPSUM
     FULL LOAD QUANTITY - M T/H                     8.62       (   9.50 TFH>

**» SLUDGE

 «» TREATMENT
     METHOD                                     FORCED OXIDATION
     DEVICE                                     OXIDATION TANK
     PROPRIETARY PROCESS                        N/A

 «* DISPOSAL
     NATURE                                     NR
     TYPE                                       NR
     SITE TREATMENT                             NR

 »* PROCESS CONTROL AND INSTRUMENTATION
     CHEMICAL PARAMETERS                        FLUE GAS VOLUME & S02 CONCENTRATION

 »» MATEP BALANCE
     WATER LOOP TYPE                            OPEN
     POND SEEPAGE/RUNOFF MATER LOSS - LITERS/S  40
     MAKEUP MATER ADDITION - LITERS/S              13.1        (   208 GPM)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FGD   CAP.
                                                                SOS  PART. HOIPS HOURS  HOUPS FACTCR


 2/75  SYSTEM                  96.9                    68.8                  672   616    597

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGO SYSTEM MAS DOWN ONCE DUE TO A PIPING FLANGE LEAK.

 3/75  SYSTEM                 100.0                    48.4                  744   360    360

 4/75  SYSTEM                 100.0                    44.1                  720   318    318

       ** PR03LEMS/SOLUTICNS/COMMENTS

                         THE BOILER MAS TAKEN OFF-LINE FOR ANNUAL MAINTENANCE DURING MARCH AND
                         APRIL.

 5/75  SYSTEM                 100.0                    96.4                  744   717    717

 6/75  SYSTEM                  97.9                    97.9                  720   720    705

 7/75  SYSTEM                  98.0                    97.8                  744   743    723

 8/75  SYSTEM                  98.0                    98.0                  744   744    729

 9/75  SYSTEM                  95.7                    91.7                  720   690    660
                                               982

-------
                                              EPA UTILITY FGO SURVEY: OCTC3E= - OECEM2E1? 1931

ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
	PERFORMANCE DATA	
PE3IOD MODULE AVAILABILITY OPERA3ILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BCILZR  FGD   CAP.
                                                                S02  PART. KSL'SS HCURS  HOtJ=S FACTOR


       *» PROBLEMS/SOLUTIONS/COMMENTS

                         SYSTEM DOWN TIME FROM JUNE THROUGH SEPTEMBER WAS DUE TO MIST ELIMINATOR
                         SCALING.

10/75  SYSTEM                  95.2                    95.2                  744   744    708

       *» PROBLEMS/SOLUTICNS/COMMENTS

                         FAN VIBRATIONS CAUSED A SYSTEM OUTAGE DURING THE MONTH.

11/75  SYSTEM                  98.5                    98.5                  720   720    709

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         MIST ELIMINATOR SCALING MAS ENCOUNTERED IN NOVEMBER.

12/75  SYSTEM                  95.9                    92.2                  74*   715    636

 1/76  SYSTEM                 100.0                   100.0                  744   744    744

 2/76  SYSTEM                  95.2                    90.8                  696   664    632

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING FEBRUARY, THE SYSTEM AGAIN ENCOUNTERED MIST ELIMINATOR SCALING.

 3/76  SYSTEM                 100.0                    92.3                  744   687    637

 4/76  SYSTEM                 100.0                    30.4                  720   219    219

 5/76  SYSTEM                 100.0                   100.0                  744   744    744

 6/76  SYSTEM                 100.0                   100.0                  720   720    720

 7/76  SYSTEM                 100.0                   100.0                  744   744    744

 8/76  SYSTEM                                                                744   744

 9/76  SYSTEM                 100.0                   100.0                  720   720    7CO

10/76  SYSTEM                  91.7                    91.7                  744   744    682

       ** PROBLEMS/SOLUTIONS/COHMENTS

                         THE SYSTEM MAS TAKEN OFF-LINE FOR CLEANING OF THE FIRST STAGE SCRUBBER.

11/76  SYSTEM                  99.3                    99.3                  720   720    715

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         REPAIR OF A DUCT FORCED ONE SYSTEM OUTAGE DURING THE MONTH.

12/76  SYSTEM                  98.9                    98.9                  744   744    736

       *« PR03LEMS/SOLUTIONS/COMMENTS

                         A DECEMBER OUTAGE MAS DUE TO THE REPAIR OF A SPRAY PIPE.

 1/77  SYSTEM                  99.3                    99.3                  744   744    739
                                               983

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981

ELECT? 1C POWER DEVELOPMENT:  TAKASAGO 1 (COMT.J
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  e :D   CAP.
                                                                SOS  PART.  HOURS HOURS  HC'.iS FACTOR


       ** PRC3LcMS/SOLUTIONS/COMMENTS

                         THE SYSTEM WAS TAKEN OFF-LINE ONCE FOR CLEANIN6 OF THE FIRST STAGE
                         SCRUBBER.

 2/77  SYSTEM                 100.0                   100.0                  672   672    672

 3/77  SYSTEM                                            .0                  744     0      0

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         THE SYSTEM MAS OFF OURIN6 MARCH FOR ANNUAL BOILER  MAINTENANCE.

 4/77  SYSTEM                 100.0                    71.3                  7CO   513    513

 5/77  SYSTEM                  98.7                    98.7                  744   744    734

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         FAN VIBRATIONS CAUSED ONE SYSTEM OUTAGE DURING MAY.

 6/77  SYSTEM                 100.0                   100.0                  720   720    720

 7/77  SYSTEM                 100.0                    96.4                  744   717    717

       »« PROBLEMS/SOLUTIONS/COMflENTS

                         THE FIRST STAGE ABSORBER MAS CLEANED DURING JULY.

 8/77  SYSTEM                 100.0                   100.0                  744   744    744

 9/77  SYSTEM                 100.0                   100.0                  720   720    720

10/77  SYSTEM                  94.Z                    94.2                  744   744    701

       *« PR03LEMS/SOLUTIONS/COKMENTS

                         THE SYSTEM MAS OFF LINE PART OF THIS MONTH FOR CLEANIMS OF THE SCRU23ERS
                         AND REACTORS.

11/77  SYSTEM                 100.0                   100.0                  720   720    720

12/77  SYSTEM                 100.0                   100.0                  744   744    744

 1/78  SYSTEM                 100.0                   100.0                  744   744    744

       »» PHOBLEMS/SOLUTIONS/COMHENTS

                         THE FIRST REACTOR HAS CLEANED THIS MONTH.

 4/73  SYSTEM                                                                720

 5/78  SYSTEM                                                                744

 6/78  SYSTEM                                                                720

 7/78  SYSTEM                                                                744

 8/78  SYSTEM                                                                744

 9/78  SYSTEM                                                                7CO

10/78  SYSTEM                                                                744
                                               984

-------
                                              EPA UTILITY FGO SURVEY:  OCTCBEB  - DECEMBER  1931

ELECTRIC POWER DEVELOPMENT:  TAKASAGO 1 (COHT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OrERABILITY RELIABILITY UTILIZATION  7. REMOVAL   FER  BOILER   FG3    CAP.
                                                                S02  PART.  HOURS HOUPS  hC./'S FACTOR


11/78  SYSTEM                                                                720

12/78  SYSTEM                                                                744

 1/79  SYSTEM                                                                7**

 3/79  SYSTEM                                                                672

 3/79  SYSTEM                                                                74*

       «» PHOBLEMS/SOLUTIONS/COHMENTS

                         DURING APRIL 1978 THPOUSH MARCH 1979 HO FCRCED OUTAGES CCCU7KED.   THE FGD
                         SYSTEM AVAILABILITY HAS 99.9X. AND LOG3ED A TOTAL OF 7823.4 HOURS Or
                         OPERATION WITH 6.1 HOURS OF SCHEDULED OUTAGE TIKE.

 4/79  SYSTEM                                                                720

 6/79  SYSTEM                                                                710

 7/79  SYSTEM                                                                744

 8/79  SYSTEM                                                                744

 9/79  SYSTEM                                                                720

10/79  SYSTEM                                                                744

11/79  SYSTEM                                                                720

12/79  SYSTEM                                                                744

 1/80  SYSTEM                                                                744

 2/80  SYSTEM                                                                696

 3/80  SYSTEM                                                                744

       «« PROBLEMS/SOLUTICNS/COMtlENTS

                         NO INFORMATION MAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.

 4/80  SYSTEM     100.0       100.0       100.0        31.1                  720   224    £24

       *» PROBLEMS/SOLUTIONS/COMHENTS

                         THE BOILER HAS SHUTDOWN ON MARCH £9 F03 ANNUAL MAINTENANCE.  THE UNIT
                         REMAINED OFF LINE THROUGH APRIL 21.  WHEN OPERATIONS CO^EilCED  THE FGD
                         SYSTEM OPERATED WITH THE BOILER FOR THE REST OF THE MONTH.

 5/80  SYSTEM     100.0       100.0       100.0       100.0                  744   744    744

 6/80  SYSTEM     100.0       100.0       100.0       100.0                  720   720    720

       *» PHOBLEHS/SOLUTIONS/CCKMENTS

                         THE FGO SYSTEM EXPERIENCED NO PROBLEMS OLHING THE KAY-JUNE PERIOD.

 7/80  SYSTEM     100.0       100.0       100.0       100.0    93.00         744   744    744  83.4

 8/80  SYSTEM     100.0       100.0       100.0       100.0    92.30         744   744    744  33.6

 9/80  SYSTEM     100.0       100.0       100.0       100.0    95.00         720   720    720  83.3
                                               985

-------
 EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981

ELECTRIC POWER DEVELOPMENT:  TAKASAGO 1 (CONT.)
	PERFORMANCE DATA	
PERIOO MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FC-3   CAP.
                                                                SOZ  PART.  HOURS HCU3S  HO'J=S FACTOR


       M* FROBLEHS/SOLUTIONS/CCrtMENTS

                         NO PROBLEMS MERE ENCOUNTERED DURING THE THIRD QUARTER 1980.

10/80  SYSTEM      99.5        99.5        99.5        99.5    92.70         744   744    740  85.3

       »« PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGO SYSTEM MAS SHUT DOWN FOR APPROXIMATELY FOUR HOURS IN CCTCSER FOR
                         AH INSPECTION OF THE SECOND SCRUBBER OUTLET DUCT AND THE MIST ELIMINATOR.
                         THE INSPECTION REVEALED THAT NO PROBLEM EXISTED.

11/80  SYSTEM     100.0       100.0       100.0       100.0    92.70         720   720    7£0  85.0

12/80  SYSTEM     100.0       100.0       1CO.O       100.0    92.70         744   744    744  89.9

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         NO PROBLEMS MERE ENCOUNTERED DURING NOVEMBER AND DECEMBER.

 1/81  SYSTEM                                                                744

 2/81  SYSTEM                                                                672

 3/81  SYSTEM                                                                744

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME!  HOUEVER THE
                         DATA MILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
                                               986

-------
                                              EPA UTILITY FGO SURVEY:  OCTC3HH  -  OECEttScP  1981

                                           SECTION 15
                DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU

 «» UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     EOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     EOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 *« FUEL DATA
     FUEL TYPE
     FUEL GPAOE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - V.
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUP CONTENT - X
     AVERAGE CHLCRIOE CONTENT - X
     RANGE CHLORIDE CONTENT - X

*»» PARTICLE CONTROL

 «» MECHANICAL COLLECTOR
     NUMBER
     TYPE

 «» ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS CAPACITY - CU.M/S
     INLET FLUE GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - X

 ** PARTICLE SCRUBBER
     NUM2ER
     NUMBER OF SPARES
     GENERIC TYPE
     SPECIFIC TYPE
     TPADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZCNES
     LIQUID RECIRCULATICN RATE - LITER/S
     L/G RATIO - LITER/CU.M
     PRESSURE DROP - KPA
ELECTRIC POWER DEVELOPMENT
TAKASAGO
TAKASAGO
JAPAN
******
   37.
  150.
******
  230
  250
  230
  238
  250
               (   .056 LB/MM3TU)
               (   .350 LB/ri3TU)
               (»•**»** L3/MM3TU)
                 774300 ACFM)
                 310 F)
               ( 590 FT)

               ( 11.9 FT)
               ( 11160 BTU/LB)
                11160-11520
MITSUBISHI
******
BASE
  365.25
  154.4
  180.
CARBON STEEL
    3.6
COAL
******
25953.

   22.00

    7.00
******
    i.ao
******
********
******
 o
NONE
COLD SIDE
MITSUBISHI HEAVY INDUSTRIES
  344.3        ( 729507 ACFM)
  154.4        (  310 FI
   99.5
 1
 0
VENTURI TOMER
NR
NR
MITSUI-CHEMICO
37.7 OIA X 62.3
CARBON STEEL
AISI 1110
CORRISION RESISTANT
NONE
 1
 1542.2        (24480 GPM)
    6.5        (48.6 GAL/1000ACF)
    1.5        (  5.9 IN-H20)
                                               987

-------
 EPA UTILITY FGD SURVEY:  OCTOBER  -  DECEMBER 1981

ELECTRIC PCHER DEVELOPMENT:  TAKASAGO 2  (CONT.)

     IMLET GAS FLOW PATE  - CU.tt/S
     INLET GAS T£MFE=ATUPE - C
     SOS PEMOVAL EFFICENCY - X
     PARTICLE REMOVAL EFFICIENCY  -  X

»<•» FGD SYSTEM
*» GENERAL DATA
    SALEABLE PRODUCT/THROMAUAY PRODUCT
    SCC PEMCVAL MCOE
    PROCESS TYPE
    SYSTEM SUPPLIER
    DEVELOPMENT LEVEL
    HEU/RETRCFIT
    UNIT DESIGN S02 REMOVAL EFFICIENCY - X
    ENERGY CONSUMPTION - X
    CURRENT STATUS
    INITIAL START-UP

ft* DESIGN AND OPERATING PARAMETERS

*« QUEHCHER/P'ESATURATOH
    CONSTRUCTION MATERIAL GENERIC TYPE
    CONSTRUCTION MATERIAL SPECIFIC TYPE

»» ABSORBER
    NUMBER
    NUTBER OF SPARES
    GENERIC TYPE
    SPECIFIC TYPE
    TRADE NAME/COMMON TYPE
    SUPPLIER
    DIMENSIONS - FT
    SHELL GENERIC MATERIAL
    SHELL SPECIFIC MATERIAL
    SHELL MATERIAL TRADE NAME/COMMON TYPE
    LINER GENERIC MATERIAL
    LINER SPECIFIC MATERIAL
    LINER MATERIAL TRACE NAME/COMMON TYPE
    GAS CONTACTING DEVICE TYPE
    NUMBER OF CONTACTING ZONES
    LIQUID RECIRCULATION RATE - LITER/S
    L/G RATIO - L/CU.M
    GAS-SIDE PRESS'JPE DROP - KPA
    INLET GAS FLOW - CU. M/S
    INLET GAS TEMPERATURE - C
    S02 REMOVAL EFFICIENCY - X

*» ABSORBER
    NUMBER
    GENERIC TYPE
    SPECIFIC TYPE
    TRADE NAME/COMMON TYPE
    SUPPLIER
    DIMENSIONS - FT
    SHELL GENEPIC MATERIAL
    SHELL SPECIFIC MATERIAL
    SHELL MATERIAL TRADE NAME/COMMON TYPE
    LINER GENEPIC MATERIAL
    LINER SPECIFIC MATERIAL
    LINER MATERIAL TRADE MAME/COMMON TYPE
    GAS CONTACTING DEVICE TYPE
    NUMBER OF CONTACTING ZONES
    LIQUID RECIPCULATION RATE - LITER/S
    INLET GAS FLOW - CU. M/S
    INLET GAS TEMPERATURE - C
    S02 REMOVAL EFFICIENCY - X

** ABSORBER
    NUMBER
    GENERIC TYPE
£60.5
154.4
 56.0
 50.0
                                                              (  553000  ACFM)
                                                              (   310 F)
                                                SALEABLE PRODUCT
                                                WET SCRUBBING
                                                LIMESTONE
                                                MITSUI-CHEMICO
                                                FULL SCALE
                                                RETROFIT
                                                   93.00
                                                    3.2
                                                 1
                                                 3/76
                                                MR
                                                NR
                                                 1
                                                 0
                                                VENTURI TOMER
                                                NR
                                                NR
                                                MITSUI/CHEMICO
                                                45.9 DIA X 78.7
                                                CARBON STEEL
                                                NR
                                                N/A
                                                NR
                                                NR
                                                NR
                                                NCNE
                                                 1
                                                 2066.
                                                    6.5
                                                    1.5
                                                  280.24
                                                   55.0
                                                   85.0
             (32801 GPM)
             (  48.6 GAL/1000 ACF)
             (  5.9 IN-H20)
             (  593855 ACFM)
             (   131 F)
                                                VENTURI TCUER
                                                NR
                                                NR
                                                MITSUI/CHEMICO
                                                26.2 DIA X 82.3
                                                CARBON STEEL
                                                NR
                                                N/A
                                                NR
                                                NR
                                                NR
                                                NONE
                                                 1
                                                  743.
                                                   69.37
                                                  154.4
                                                   63.0
                                                SPRAY TOWER
             (11799 GPM)
             (  147000  ACFM)
             (   310 F)
                                               988

-------
                                             EPA UTILITY FGO SURVEY: OCTOBER - DECEfSER 1981
ELECTRIC POWER DEVELOPMENT:  TAKASAGO 2  (CONT.)

     SPECIFIC TYPE
     TPADE NAME/COMMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRACE NAME/COMMON TYPE
     LINE1? GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TPADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     NUriEEH OF CONTACTING ZONES
     LIQUID RECIPCULATION RATE - LITER/S
     INLET GAS FLOW - CU. M/S
     INLET GAS TEMPERATURE - C

 »* MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/CCMMON TYPE
     NUMBER OF STAGES
     NUMBER OF PASSES PER STAGE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     UASH MATER SOURCE

 ** REHEATER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     INLET FLUE GAS TEMPERATURE  - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 ** FANS
     FUNCTION
                                               NR
                                               NR
                                               MITSUI/CHE^ICO
                                               CAFBON STEEL
                                               NR
                                               N/A
                                               NR
                                               NR
                                               NR
                                               NONE
                                                1
                                               19639.
                                                  36.51
                                                 154.4
               (»»»<* GPMI
               (   77372 ACFM)
               I   310 F)
                                               PRIMARY COLLECTOR
                                               IMPINGEMENT
                                               BAFFLE
                                               CLOSED VANE
                                                   4
                                                   4
                                               NR
                                               NR
                                               SLEWED
                                               DIRECT COMBUSTION
                                               NR
                                               OIL
                                                 120.0        (  248 F)
                                               NR
                                               NR
                                               BOOSTER
»* FANS
    APPLICATION

«« DAMPERS
    FUNCTION
    GENERIC TYPE
    SPECIFIC TYPE
    CONSTRUCTION MATERIAL GENEPIC TYPE
    CONSTRUCTION MATERIAL SPECIFIC TYPE
    LINER GENERIC MATERIAL TYPE
    LINER SPECIFIC MATERIAL TYPE

»» REAGENT PREPARATION EQUIPMENT
    FUNCTION
    DEVICE
    DEVICE TYPE

*» TANKS
    SERVICE
    CENTRIFUGE OVERFLOW
    ABSORBENT MAKEUP
    CENTRIFUGE FEED
    PRIMARY LICUOR
    ABSORBER FEED

«* PUMPS
    SERVICE
OXIDATION BLCMER
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
NR
NR
                                               NUMBER
    CIRCULATION
    PH ADJUSTER CIRCULATION
    REACTCR CIRCULATION
NUMBER

   5
   Z
   1
                                              989

-------
 EPA UTILITY FGO SURV='   •TC.-ER - DECEMBER 1981

ELECTRIC POWER OEVELCFI.iNT:  TAKASAGO 2 (CONT.)


 ** SOLIDS CCNCENTRATING/OEWATERING
     DEVICE                                     CENTRIFUGE
     NUM3EP                                      7
     CUTLET STREAM CHARACTERISTICS              90X SOLIDS

 «*» SOLIDS CCNCEHTRATING/DEHATERIMS
     DEVICE                                     THICKENER
     CUTLET STREAM CHARACTERISTICS              20X SOLIDS

**« SALEABLE BYPRODUCTS
     NATURE                                     GYPSUM
     FULL LOAD QUANTITY - M T/H                     8.62       (  9.50 TPH)

**tt SLUDGE

 ** TREATMENT
     METHOD                                     FORCED OXIDATION
     DEVICE                                     OXIDATION TAHK
     PROPRIETARY PROCESS                        N/A

 »* DISPOSAL
     MATURE                                     NR
     TYPE                                       NR
     SITE TREATMENT                             NH

 ** PROCESS CONTROL AND INSTRUMENTATION
     CHEMICAL PARAMETERS                        FLUE GAS VOLUME & S02 CONCENTRATION

 »« WATER BALANCE
     MATER LOOP TYPE                            OPEN
     POND SEEPAGE/RUNOFF MATER LOSS - LITERS/S  40
     MAKEUP MATER ADDITION - LITERS/S              13.1        (  208 GFM)
	PEPFOPMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART. HCURS HOURS  KOU.7S FACTOR
3/76
4/76
5/76
6/76
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100
100
100
100
.0
.0
.0
.0
100
100
29
67
.0
.0
.0
.8
744
720
744
720
744
720
216
632
720
7CO
216
632
       *» PR03LEMS/SOLUTIONS/COMMENTS

                         THE SYSTEM HAS DOWN FOR PART OF MAY AND JUNE FOR ANNUAL BOILER MAINTENANCE.

 7/76  SYSTEM                 100.0                   100.0                  744   744    744

 8/76  SYSTEM                 100.0                   100.0                  744   744    744

 9/76  SYSTEM                 100.0                   100.0                  720   720    720

10/76  SYSTEM                  94.2                    94.2                  744   744    701

       »» PROBLEMS/SOLUTIOHS/CCMMENTS

                         OUTAGE TIME DURING OCTOBER MAS NECESSARY FCR DUCT CLEANING.

11/76  SYSTEM                 100.0                   100.0                  720   720    720

12/76  SYSTEM                  99.3                    99.3                  744   744    739
                                               990

-------
                                              EPA UTILITY F6D SURVEY:  CCTC3ER - DECEASE"? 1981

ELECTRIC PCUER DEVELOPMENT: TAKASAGO 2 (CONT.)




	PERFOPKAHCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FG3   CAP.
                                                                £02  PART. HOURS HOURS  HC'JOS FACTCR


       ** PR03LEMS/SOLUTICNS/COKMENTS

                         THE SYSTEM MAS DOMN BRIEFLY FOR REPAIR OF A GYPSUM CONVEYOR.

 1/77  SYSTEM                 100.0                   100.0                  744   744    744

 2/77  SYSTEM                  88.2                    88.2                  672   672    593

 3/77  SYSTEM                  98.7                    98.7                  744   744    734

       ** PRCBLEMS/SOLUTIONS/COMMENTS

                         OUTAGE TIME IN FEBRUARY I MARCH MAS NEEDED FOR CLEANING CF A PH CONTROLLER.

 4/77  SYSTEM                 100.0                   100.0                  720   720    720

 5/77  SYSTEM                 100.0                    51.6                  744   384    234

 6/77  SYSTEM                 100.0                     3.3                  720   240    240

 7/77  SYSTEM                 100.0                   100.0                  744   744    744

 8/77  SYSTEM                 100.0                   100.0                  744   744    744

 9/77  SYSTEM                 100.0                   100.0                  720   720    720

10/77  SYSTEM                 100.0                   100.0                  744   744    744

11/77  SYSTEM                  89.2                    89.2                  720   720    642

       *» PROBLEMS/SOLUTICNS/COMMENTS

                         CLEANING OF THE PH CONTROLLER CAUSED ONE OUTAGE DURING NOVEMBER.

                         A REACTOR MAS ALSO CLEANED THIS MONTH.

12/77  SYSTEM                 100.0                   100.0                  744   744    744

 1/78  SYSTEM                                                                744   744

 2/78  SYSTEM                                                                672

 3/78  SYSTEM                                                                720

 4/78  SYSTEM                                                                720

 5/78  SYSTEM                                                                744

 6/78  SYSTEM                                                                720

 7/78  SYSTEM                                                                744

 8/78  SYSTEM                                                                744

 9/78  SYSTEM                                                                720

10/78  SYSTEM                                                                744

11/78  SYSTEM                                                                720

12/73  SYSTEM                                                                744

 1/79  SYSTEM                                                                744
                                               991

-------
 EPA UTILITY FGO SL'PVEY: OCTOBER - DECEMBER 1981

ELECTRIC PCWER DEVELOPMENT: TAKASAGO 2 (CONT. )
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY CPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FG3   CAP.
                                                                S02  PART.  HOU3S HCL'RS  hCUHS FACTOR


 2/79  SYSTEM                                                                672

 3/79  SYSTEM                                                                744

       »* FR03LEMS/SOLUTIOMS/COMMENTS

                         DURING THE PERIOD FPOM APRIL 1978 THROUGH MARCH 1979 THE FG3 SYSTEM
                         OPERATED WITH 99.OX AVAILABILITY.  THERE WERE NO FORCED OUTAGES DURING THIS
                         TIME.   A TOTAL OF 8147.4 HOURS OF FGD SYSTEM OPERATION WEPE LC3GED WITH
                         19.5 HOURS OF SCHEDULED OUTAGE TIME.

 4/79  SYSTEM                                                                720

 5/79  SYSTEM                                                                744

 6/79  SYSTEM                                                                720

 7/79  SYSTEM                                                                744

 8/79  SYSTEM                                                                744

 9/79  SYSTEM                                                                720

10/79  SYSTEM                                                                744

11/79  SYSTEM                                                                720

12/79  SYSTEM                                                                744

 I/SO  SYSTEM                                                                744

 2/30  SYSTEM                                                                696

 3/30  SYSTEM                                                                744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION HAS AVAILABLE FOR THE  APRIL 1979 THROUGH MARCH I960 PERICD.

 4/80  SYSTEM     100.0      100.0       100.0       100.0                  720   720    720

 5/80  SYSTEM     100.0      100.0       100.0       100.0                  744   744    744

       »« PRCBLEMS/SOLUTIONS/COMMENTS

                         DURING APRIL AND MAY THE UTILITY EXPERIENCED NO PROBLEMS WITH THE FGD
                         SYSTEM.

 6/80  SYSTEM     100.0      100.0       100.0        24.6                  720   177    177

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER MAS SHUTDOWN FROM JUNE 3 TO JUNE 24 FOR  ANNUAL MAINTENANCE.
                         THE FGD SYSTEM OPERATED ALONG WITH THE BOILER THE REMAINDER  OF THE TIMS.
7/80
8/80
9/80
10/60
11/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100
100
100
100
100
.0
.0
.0
.0
.0
100.0
100.0
100.0
100.0
100.0
92.80
92.80
93.10
92.60

744
744
720
744
720
744
744
720
744
720
744
744
720
744
7CO
83.0
83.3
83.4
65.1
84.8
                                               992

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER  -  DECEXSsR  1931

ELECTRIC POHE9 DEVELOPMENT:  TAKASAG3 2 (COHT.)
	PERFORMANCE  DATA	
PERIOD MODULE  AVAILABILITY OFERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PcP   EOILER   FG3    CAP.
                                                                S02   PART.  HCU'S HOL'SS   HCL3S  FACTO?


12/30  SYSTEM      100.0        100.0      100.0         67.3    92.60          744   649     649   78.4

       *» PSOBLEMS/SOLUTIC.NS/COKMENTS

                         DURING JULY THROUGH  DECEMBER  NO FGD-RELATED  PROBLEMS MERE  EXPERIENCED.

                         IN DECEMBER THE BOILER  WAS OUT OF SERVICE APPROXIMATELY FOUR DAYS FOR
                         GENERAL MAINTENANCE.

 1/81  SYSTEM                                                                 744

 2/81  SYSTEM                                                                 672

 3/81  SYSTEM                                                                 744

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THE FIRST QUARTER  1981  DATA IS NOT AVAILABLE AT THIS TIP*; HOWEVER THE
                         DATA MILL BE AVAILABLE  IN THE SECOND QUARTER 1981  REPORT.
                                               993

-------
 EPA UTILITY FC-0 S'.'-VEY:  OCTOBER - DECEMBER 1981

                                           SECTION 15
                DESIGN AND PEPFC3MANCE DATA FOR OPERATIONAL FOREIGN FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
FEGULATCRY CLASSIFICATION
PANICULATE EMISSION LI 'ITATICN - NG/J
S02 EMISSION LIMITATION - N3/J
UOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GPOSS UNIT GENERATIN3 CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY UO/FGO •• MM
EQUIVALENT SCRUBBED CAPACITY - KM

 «* UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 «t* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

»»» PARTICLE CONTROL

 »» MECHANICAL COLLECTOR
     NUMBER
     TYPE

 *» ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS CAPACITY - CU.M/S
     INLET FLUE GAS TEMPEPATURE - C
     PARTICLE REMOVAL EFFICENCY - X

 »« PARTICLE SCRUBBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     LINER GENERIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCULATION RATE - LITER/S
     L/G RATIO - LITER/CU.M
     PRESSURE DROP - KPA
     INLET GAS FLOW RATE - CU.M/S
     INLET GAS TEMPERATURE - C
               (  .130 LB/MM3TU)
               (  .630 LB/MM3TU)
               (»**«** LB/MM3TUJ
ELECTRIC POWER DEVELOPMENT
TAKEHARA
1
MIHARA
JAPAN
******
   56.
  271.
******
  231
  250
  231
  239
  250
BABCOCK-HITACHI
PULVERIZED COAL
BASE
  577.13
  140.0
  201.
CARBON STEEL
    3.6
               (1223000 ACFM)
               ( 284 F)
               ( e60 FT)

               ( 11.9 FT)
               ( 10804 BTU/LB)
                10804-11520
COAL
******
25130.

   23.00
******
    9.05
******
    2.00
******
     .05
******
 0
NONE
COLD SIDE
SUMITOMO HEAVY INDUSTRIES
  333.2        ( 706000 ACFM)
  140.0        (  284 F)
   98.0
VENTURI TOWER
NR
NR
HITACHI
ORGANIC
NONE
 1
  533.7
    2.5
    2.3
  168.0
  140.0
               ( 8471 GPM)
               (18.7 GAL/1000ACF)
               ( ".I IN-H20)
               ( 356000 ACFM)
               (  284 F)
                                               994

-------
                                              EPA  UTILITY FGD  SURVEY:  CCTC£EH  -  DEC=K3ER  1«31
ELECTPIC POWER DEVELOPMENT:  TAKEHARA 1  (COMT.>
*»» FGO STSTEtl

 ** GENEPAL DATA
     SALEABLE PPCDUCT/THROUAWAY PRODUCT
     302 REMOVAL MCDE
     FFCCESS TYPE
     PROCESS ADDITIVES
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
     UNIT OESIC-N S02 REMOVAL EFFICIENCY - X
     EHEfiGY CONSUMPTION - X
     CURRENT STATUS
     COMMERCIAL START-UP
     INITIAL START-UP

 «» DESIGN AKO OPERATING PARAMETERS

 ** CUENCKER/FRESATURA70R
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »* ABSORBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE MAME/CCKMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC HATERIAL
     LINER SPECIFIC MATERIAL
     LTMER MATERIAL TRADE NAKE/COMHON TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCULATION RATE - LITER/S
     L/G RATIO - L/CU.M
     GAS-SIDE PRESSURE DROP - KPA
     INLET GAS FLOU - CU. M/S
     INLET GAS TEMPERATURE - C

 ** MIST ELIMINATOR
     FRE-MIST ELIMINATOR/MIST ELIMINATOR
     NUMBE9 PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/TOW.ON TYPE
     CONFIGURATION
     PRESSURE DROP - KPA
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     WASH MATER SOURCE
     WASH FREQUENCY
     WASH RATE - L/S

 ** R EM EATER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     ZNLET FLUE GAS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» FANS
     NUMBER
     FUNCTION
     APPLICATION
     SERVICE
 SALEABLE FB03UCT
 MET SCRU33IMG
 L:MESTCNE
 NC>:=
 BAE.SCK-HITACHI
 FULL SCALE
 RETROFIT
X   91.70
    94.20
     3.2
  1
  2/79
  2/77
 Kt?
 NR
 TRAY TOMER
 MR
 NR
 BABCOCK-KITACHI
 CARBON STEEL
 NR
 H/A
 ORGANIC
 POLYESTER
 NR
  5
   721.
     7.0
     3.0
   164.76
    52.2
(11446 GFM)
(  52.4 GAL/1000 ACF)
(15.2 IN-H20)
(  340142 ACFM)
(   126 F)
 PRIMARY COLLECTOR
  Z
 IMPINGEMENT
 TUBE BANK
 VERTICAL PARALLEL TUBE BANK
 HORIZONTAL
      .1
 NR
 NR
 FRESH
 CONTINUOUS
(   .4 IN-H20)
     1.3
                (   ZO GAL/MIN)
 DIRECT COMBUSTION
 NR
 OIL
   120.0        I  24S F)
 KR
 NR
  2
 BOOSTER
 INDUCED DRAFT
 WET
                                               995

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

ELECTRIC FCHER DEVELOPMENT: TAKEHARA 1 ICONT.)
 ** DAMPEPS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 *« REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 »« TA»«S
     SERVICE
     PRESCRUBBEH RECYCLE
     SCRUBBER RECYCLE
     FILTER LIQUID
     SLURRY
     OXIDATION TOMER FEED

    PUMPS
     SERVICE
     COOLER RECYCLE
     ABSORBER RECYCLE

 «* SOLIDS CCNCENTRATING/OEMATERING
     DEVICE
     NUMBER
     NUMBER OF SPARES
     CAPACITY
     FEED STREAM CHARACTERISTICS
     OUTLET STREAM CHARACTERISTICS

 *« SOLIDS CONCENTRATING/OEWATERING
     DEVICE
     NUMBER
     CONFIGURATION
     DIMENSIONS - FT
     FEED STREAM CHARACTERISTICS
     OUTLET STREAM CHARACTERISTICS

«»» SALEABLE BYPRODUCTS
     NATURE
     FULL LOAD QUANTITY - M T/H
     QUALITY - 7.
     DISPOSITION

**« SLUDGE

 ** TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PPOCESS

 «» DISPOSAL
     NATURE
     TYPE
     SITE TREATMENT

 *« PPOCESS CONTROL AND INSTRUMENTATION
     CHEMICAL PARAMETERS
     CONTROL LEVELS
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
NR
NR
                                                NUMBER
««**
   2
NUMBER

   2
   4
CENTRIFUGE
 9
1
4 GPM
ZOX SOLIDS
88X SOLIDS
THICKENER
 1
HORIZONTAL
45.0 OIA X 10.0
12X SOLIDS
20X SOLIDS
GYPSUM
    9.89
   95.0
MARKETED
(  10.90 TPH)
FORCED OXIDATION
OXIDATION TANK
N/A
NR
NR
NR
PH. GAS FLOW
PH 5.0-6.0
                                               996

-------
                                              EPA UTILITY FGO SURVEY: CCTC3ER - DECEMBER 1«S1

ELECTRIC POWER DEVELOPMENT: TAKEHARA 1 (CONT.)

     PPOCESS CONTROL MANNER                     AUTOMATIC

 ** UATER BALANCE
     WATEP LCOP TYPE                            OPEN
     POilD SEEPAGE/RUNOFF MATER LOSS - LITERS/S  60
     MAKEUP MATER ADDITION - LITERS/S              14.9        (  237 GFtl)



	PERFORMANCE DATA	
FERICD MODULE AVAILABILITY OPEHABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FCD   CA?.
                                                                S32  PART. HOL-'SS HC'J?S  KCL"S FACTCH


 4/78  SYSTEM                                                                720

 5/78  SYSTEM                                                                74*

 6/78  SYSTEM                                                                720

 7/78  SYSTEM                                                                744

 8/78  SYSTEM                                                                744

 9/78  SYSTEM                                                                720

10/78  SYSTEM                                                                744

11/78  SYSTEM                                                                720

12/78  SYSTEM                                                                744

 1/79  SYSTEM                                                                744

 2/79  SYSTEM                                                                672

 3/79  SYSTEM                                                                744

       *» PH03LEMS/SOLUTIONS/COMMENTS

                         99.95X AVAILABILITY WAS REPORTED FOR THE PERIOD FROM APRIL 1978 THROUGH
                         MARCH 1979.

 4/79  SYSTEM                                                                720

 5/79  SYSTEM                                                                744

 6/79  SYSTEM                                                                720

 7/79  SYSTEM                                                                744

 8/79  SYSTEM                                                                744

 9/79  SYSTEM                                                                720

10/79  SYSTEM                                                                744

11/79  SYSTEM                                                                720

12/79  SYSTEM                                                                744

 1/80  SYSTEM                                                                744

 2/80  SYSTEM                                                                696

 3/80  SYSTEM                                                                744
                                               997

-------
 EPA UTILITY FG3 SURVEY:  CCTC3ER - DECEMBER 1931

EL:CT3XC FCXER DEVELOPMENT:  TAKEHARA 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MC3ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FG3   CAP.
                                                                S02  PART.  HOL.SS HOUPS  HC'J=S FACTOR


       M* FSC3LEMS/SOLUTICNS/COKMENTS

                         NO INFORMATION WAS AVAILABLE F0!7 THE APRIL 1979 THROUGH MARCH 1989 PERIOD.

 4/80  SYSTEM     100.0        100.0       100.0       100.0                  723   720    7CO

 5/80  SYSTEM     100.0        100.0       100.0       100.0                  744   744    744

 6/80  SYSTEM      87.9        100.0       100.0        87.9    90.10         720   633    633  82.4

       *» PH03LEMS/SOLUTIONS/COKKENTS

                         THE FGD SYSTEM MAS OUT OF SERVICE FOR APPROXIMATELY 3 DAYS IN JUNE TO
                         REMOVE  THE SCALE ACCUMULATION IN THE F6D CUTLET DUCT.
7/80
8/80
9/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100.0
100.0
100.0
100.0
100.0
100.0
91.00
91.70
93.10
744
744
720
744
744
720
744
744
720
95.5
55.3
95.3
       ** PROBLEMS/SOLUTIONS/COMMENTS

                         NO PROBLEMS HERE ENCOUNTERED DURING THE THIRD  QUARTER 1980.

10/80  SYSTEM     100.0       100.0       100.0       100.0    93.40         744   744    744  94.5

11/80  SYSTEM     100.0       100.0 .      100.0       100.0    93.70         720   720    720  95.2

12/80  SYSTEM     100.0       100.0       100.0        27.7    91.70         744   £06    £06  22.4

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER MAS OUT OF SERVICE FROM DECEMBER 1  THROU3H DECEMBER 25 FOR
                         SCHEDULED MAINTENANCE.

 1/81  SYSTEM                                                                744

 2/81  SYSTEM                                                                672

 3/81  SYSTEM                                                                744

       ** PHOSLEMS/SOLUTIOMS/COMMENTS

                         THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT  THIS TIME;   HCWEVER THE
                         DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981  REPORT.
                                               998

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER - OECEM3ES 19£1

                                           SECTION 15
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOPEIGN FGD SYSTEMS
C3MPANY NAME
PLANT HAKE
UNIT NUM3ER
CITY
C3UNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOI EMISSION LIMITATION - NG/J
HOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGD - MW
MET UNIT GENERATING CAPACITY KO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 »* UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.tl/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - fl

 *» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - 7.

*«» PARTICLE CONTROL

 «» ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS CAPACITY - CU.M/S
     INLET FLUE GAS TEMPERATURE - C
     PRESSURE DROP - KPA
     PARTICLE REMOVAL EFFICENCY - X

 »« PARTICLE SCRUBBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     GAS CONTACTING DEVICE TYPE
     INLET GAS FLOM RATE - CU.M/S
     INLET GAS TEMPERATURE - C

»«« FGD SYSTEM

 *« GENERAL DATA
     SALEABLE FROOUCT/THROMAWAY PRODUCT
     S02 REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     NEW/RETROFIT
HOKKAIDO ELECTRIC PCWER
TOMATOATSUMA THERMAL POM
1
TOMAKOMAI
JAPAN
******
****««
******
******
  350
  350
  175
  175
  350
BABCOCK-HITACHI
PULVERIZED COAL
BASE
  503.21
  121.1
  170.
CARBON STEEL
    4.5
(***»** LB/MP3TU)
(*»**** LB/FM3TU)
(*****» LB/r.KSTU)
(1076939 ACFM)
(  250 F)
(  553 FT)

(  14.6 FT)
COAL
BITUMINOUS
******

   20.50
***»»«
    7.00
*»**»»
     .30

********
******
 4
HOT SIDE
HITACHI
  628.6
  363.9
     .2
   99.8
(108000 BTU/LB)
 ******
(1756252 ACFM)
(   687 F)
(   1. IN-HZO)
VENTURI TOMER
NR
NR
BABCOCK-HITACHI
NONE
  198.7        (
   47.2        (
  421036 ACFM)
   117 F)
SALEABLE PRODUCT
MET SCRUBBING
LIMESTONE
BABCOCK-HITACHI
FULL SCALE
RETROFIT
                                               999

-------
 EPA UTILITY FG3 SURVEY: CCTC3ER - DECEMBER 1981

HOKKAIDO ELECTRIC POWER: TOMATOATSUMA THERMAL POM 1 (CONT.)
     UNIT OESI3J1 S02 REMOVAL EFFICIENCY - 7.
     ENERGY CCJiUMPTICN - X
     CU7.-ENT STATUS
     CCMMEPCIAL START-UP
     INITIAL START-UP

 »» DESIGN AND OPERATING PARAMETERS

 <** qUENCHES/P=ESATURATCR
     CCMSTPUCTICN MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «* ABSORBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE HAME/COMKON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRiCE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     INLET GAS FLOM - CU. M/S
     INLET GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - X

 *« MIST ELIMINATOR
     PRE-MIST ELIMINATOR/HIST ELIMINATOR
     NUMBEf. PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONFIGURATION
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» REHEATEH
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     PERCENT GAS BYPASSED - AVG
     TEMPERATURE INCREASE - C
     INLET FLUE GAS FLOU RATE - CU. M/S
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 *« FANS
     HUM3ER
     DESIGN
     SUPPLIER
     FUNCTION
     FLUE GAS FLOU RATE - CU.M/S
     FLUE GAS TEMPERATURE - C

 »« DAMPERS
     FUNCTION
     GENEOIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 ** REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE
     NUMBER
   90.00
     .0
 1
10/60
 7/30
NR
MR
 1
NR
NR
NR
BABCOCK-HITACHI
NR
NR
MR
NR
NR
NR
  198.69
   47.2
   90.0
  421036 ACFM)
   117 F)
PRIMARY COLLECTOR
 1
IMPINGEMENT
BAFFLE
NR
VERTICAL
NR
NR
WASTE HEAT RECOVERY
GAS-GAS
WHEEL TYPE
   14.3
   65.6
  199.17
NR
NR
(   118 F)
(  422057 ACFM)
CENTRIFUGAL
HITACHI.LOT.
BOOSTER
  254.47
  137.2
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
m
NR
 1
(  530247 ACFM)
(   279 F)
                                              1000

-------
                                              EPA UTILITY FGD SURVEY: OCTC3ER - DECEM2ER 1981

HOKKAIDO ELECTRIC POWER: TCMATOATSUMA THERMAL POM 1 (COHT.)

     PRODUCT QUALITY - X SOLIDS                    92.0

 ** SOLIDS CONCENTRATING/DEMATERING
     DEVICE                                     THICKENER
     NUM3ER                                      2

 «» SCLIOS CONCENTRATING/DEUATERING
     DEVICE                                     CENTRIFUGE
     IIUM3ER                                      3
     NUMBER OF SPARES                           1

««« SALEABLE BYPRODUCTS
     NATURE                                     GYPSUM
     QUALITY - •/.                                   45.0
     DISPOSITION                                MARKETED

*»« SLUDGE

 »>* TREATMENT
     METHOD                                     Nft
     DEVICE                                     NR
     PROPRIETARY PROCESS                        NR

 ** DISPOSAL
     NATURE                                     NR
     TYPE                                       NR
     SITE TREATMENT                             NR

 *» MATER BALANCE
     MATER LOOP TYPE                            CLOSED
     MAKEUP MATER ADDITION - LITERS/S               4.0        (   63 GPM)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART. HOURS HOURS  HC'JRS FACTOR


10/80  SYSTEM     100.0       100.0       100.0        70.3    94.40         744   523    523  46.0

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         OPERATIONS AT THE TOMATOATSUMA STATION COMMENCED IN OCTOBER 1980.

11/80  SYSTEM     100.0       100.0       100.0        85.1    92.40         720   613    613  61.1

12/80  SYSTEM     100.0       100.0       100.0       100.0    94.10         744   744    744  94.7

       «» PROBLEMS/SOLUTIONS/COMMENTS

                         DURING DECEMBER SCALE FORMATION MAS OBSERVED IN THE PIPING AND IN A PUMP OF
                         THE HASTE MATER TREATMENT FACILITY.  A WATER MASH LINE MAS INSTALLED PCS
                         THE PIPING AND A PUMP MAS ADDED TO ELIMINATE SCALE.  THE FGD SYSTEM
                         OPERATION MAS NOT AFFECTED DURING THIS TIME.
                                              1001

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT HAKE
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
H3X EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
MET UNIT GENERATING CAPACITY U/FGD - MM
NET UNIT GENERATING CAPACITY KO/F60 - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 »» UNIT DATA - EOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     EOILE9 SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 *« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANSE HEAT CONTENT - BTU/LB
     AVERAGE ASH CCNTENT - 7.
     RANGE ASH CCNTENT - 7.
     AVERAGE MOISUPE CONTENT - X
     RANSE MOISTURE CONTENT - X
     AVERAGE SULFUR CCNTENT - X
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - X
     RANSE CHLORIDE CONTENT - 7.

•«» PARTICLE CONTROL

 »« MECHANICAL COLLECTOR
     NUMBER
     TYPE

 »• ESP

 »* PARTICLE SCRUBBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

»«» FGD SYSTEM

 «• GENERAL DATA
     SALEABLE PROOUCT/THROHAHAY PRODUCT
     SOS REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     ENEPGY CONSUMPTION - 7.
     CURRENT STATUS
     TERMINATION
     INITIAL START-UP
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5A
FARMINGTON
NEW MEXICO
D
   21.
  258.
»»**»»
 2089
  755
                  .050 LB/MMBTU)
                  .600 LB/MMBTU)
                       LB/MMBTU)
I
(
(»**»»*
**«*»
  755
»*»»»»
PULVERIZED COAL
BASE
«*«••»»»
»•»****
»**»«»
**»»*»
•««*«*«
               («*«»*»* ACFM)
               (»**» F)
               («»»» FT)

               («»*«« FT)
COAL
SUBBITUMINOUS
22562.         (  9700 BTU/LB)
                *«*»*»
   24.00
•*»»•»»
   11.00
*»»*«*
     .61
**«»»*«*
•*»»•»
 0
NONE
NONE
N/A
N/A
N/A
THROUAUAY PRODUCT
WET SCRUBBING
LIME
SOUTHERN CALIFORNIA EDISON
BECHTEL
EXPERIMENTAL
RETROFIT
     .0
 a
12/76
 2/76
                                              1002

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1961

ARIZONA PUBLIC SERVICE:  FOUR CORNERS 5A CCONT.)
 »* DESIGN AND OPERATING PARAMETERS

 »* OUENCHER/PPESATURATOR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «* ABSORBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/CCHMCN TYPE
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES

 »« MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     NUMBER PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» REHEATER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» FANS
     NUMSER
     FUNCTION
     APPLICATION
     CONSTRUCTION MATERIAL GENERIC TYPE

 «« DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 «» DUCTWORK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 «« REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE
     NUMBER

 »» PUMPS
     SERVICE
     SLURRY RECIRCULATION
NR
NR
SPRAY TOWER
OPEN CROSSCURRENT SPRAY
HORIZONTAL SPRAY CHAMBER
60.0 X 28.0 X 17.0
CARBON STEEL
AISI 1110
N/A
ORGANIC
NATURAL RUBBER, GLASS FLAKE-FILLED POLYESTER
BLACK NATURAL RUBBER. NR
NONE
 5
PRIMARY COLLECTOR
 1
IMPINGEMENT
BAFFLE
CLOSED VANE
STAINLESS STEEL, CARBON STEEL
NR
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLE
KR
NR
 1
BOOSTER
FORCED DRAFT
MANGANESE, VANADRUM STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
SLAKER
OETENTSN
N/A
 1
NUMSER

  12
                                              1003

-------
 EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981

ARIZONA PUBLIC SERVICE:  FOUR CORNERS 5A (CONT.)
                                                   Reproduced from
                                                   best available co
 »* SOLIDS CONCENTRATING/DEUATEHING
     DEVICE
     NUMBER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL TYPE
     OUTLET STREAM CHARACTERISTICS

•«» SLUDGE

 «» TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 «* DISPOSAL
     NATURE
     TYPE
     SITE TREATMENT
                       THICKENER
                        1
                       60.0 DIA
                       CARBON STEEL
                       302 SOLIDS
                       NR
                       NR
                       NR
                       NR
                       NR
                       NR
	...	PERFORMANCE  DATA—-
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION
                                       X REMOVAL   PEA  BOILER  FGO   CAP.
                                       302  PART. HOURS HOURS  HOURS FACTOR
 2/76  SYSTEM
                                                                            692
       *« PROBLEMS/SOLUTIONS/COMMENTS
 3/76  SYSTEM

 4/76  SYSTEM
UNIT NO. 5 HAS FIRST PLACED IN COMMERCIAL OPERATION IN JULY 1970.  THE FGD
SYSTEM WHICH HAS RETROFITTED ON UNIT NO. 5 UAS A UEIR HORIZONTAL CROSSFLOW
SPRAY ABSORBER WHICH UAS FORMERLY INSTALLED AND OPERATED IN A TEST PROGRAM
AT THE MOHAVE GENERATING STATION OF THE SOUTHERN CALIFORNIA EDISON CCMPAHY.
THE HORIZONTAL MODULE UAS A FOUR-STAGE SCRUBBINS CHAMBER.  EACH STAGE
CONTAINED A ROU OF 36 EXTERNALLY, MOUNTED NOZZLES.  THE SLUPRY MAS CYCLED
THROUGH THE SCRUBBER IX A COUNTERCURRENT MANNER AT A RATE OF 36,000 GPM/
STAGE.  THE FRESH LIME SLURRY UAS SPRAYED ACROSS THE FLUE GAS AT THE FOURTH
STAGE. WHICH UAS THE DISCHARGE END OF THE SCRUBBING CHAMBER.  THE SCRUS3IN3
SOLUTION UAS THEN COLLECTED AND RECYCLED SUCCESSIVELY TO THE THIRD, SECOND,
AND FIRST STAGES OF THE SCRUBBING MODULE.  THIS ALLOWED COMPLETE DEPLETION
OF ANY CONCENTRATION.  THE CLEANED 6ASES THEN PASSED THROUSH A MIST ELIMI-
NATOR AND HERE 'REHEATED BEFORE BEING DISCHAR5ED TO THE STACK.  THE SPENT
SLURRY UAS DISCHARGED FROM THE SCRUBBING SYSTEM TO A THICKENER AND THE
UNDERFLOW UAS PUMPED TO AN ON-SITE SETTLING POND.  UATER UAS RETURNED TO
THE PROCESS FOR FURTHER USE.

INSTALLATION OF THE MODULE AT THE FOUR CORNERS GENERATING STATION UAS
COMPLETED AND THE SYSTEM UAS PLACED IN SERVICE ON FEBPUARY 17, 1976, FOR
INITIAL OPERATION.

                                                    744

                                                    720
       «* PROBLEMS/SOLUTIONS/COMMENTS
 5/76  SYSTEM

 6/76  SYSTEM

 7/76  SYSTEM

 8/76  SYSTEM

 9/76  SYSTEM
THE FGD SYSTEM UAS TAKEN OFF LINE IN MID-APRIL FOR A SCHEDULED BOILER
OVERHAUL.  THE SYSTEM UAS SCHEDULED TO COME BACK ON LINE IN JULY 1976.

                                                    744

                                                    720

                                                    744

                                                    744

                                                    720
                                              1004

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER  -  DECEMBER  1981

ARIZONA PUBLIC SERVICE:  FOUR CORNERS 5A (COHT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION  X REMOVAL   PER   BOILER   FGD    CAP.
                                                                S02   PART.  HOUPS HOLRS  HCU'S FACTOR


       «» PROBLEMS/SOLUTICNS/COMMENTS

                         THE SYSTEM REMAINED OUT OF SERVICE THROUGH  MID-APRIL 1976 DUE TO AN  EXTEN-
                         SIVE OVERHAUL OF THE NO. 5 BOILER PLUS THE  DEVELOPMENT  OF PROBLEMS WITH
                         THE SCRUBBER MODULE'S REHEATER.

10/76  SYSTEM                                                                744

11/76  SYSTEM                                                                720

1Z/76  SYSTEM                                                                744

       »» PR09LEMS/SOLUTIONS/CCMMENTS

                         THE PROTOTYPE WAS IN SERVICE THROUGHOUT THE MONTH  OF NOVEMBER.   ON
                         DECEMBER 6 THE TEST PROGRAM MAS  CONCLUDED AND THE  UNIT  MAS DISMANTLED.
                                              1005

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
=LANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOZ EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/FGO - MW
NET UNIT GENERATING CAPACITY HO/FGO - MK
EQUIVALENT SCRUBBED CAPACITY - MW

 »« WIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 »• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/6
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTUPE CONTENT - 7.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUP CONTENT - X
     AVERAGE CHLORIDE CCNTENT - X
     RANGE CHLORIDE CONTENT - 7.

•wi PARTICLE CONTROL

 «* MECHANICAL COLLECTOR
     NUMBER
     TYPE

 «• FABRIC FILTER
     NUMBER
     TYPE

 •• ESP

 «» PARTICLE SCRUBBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

»"« FGO SYSTEM
BOSTON EDISON
MYSTIC
6
EVERETT
MASSACHUSETTS
»*»*••
*«»0tt*
*•««»*
**»•»
  150
•*•*«
«**«*
  150
COMBUSTION ENGINEERING
OIL FIRED
«««*«»
  273.70
  148.9
   99.
               («*«*«• LB/MM3TU)
               (*»»««» LB/MM3TU)
               (*«««»« LB/M.-.BTU)
               ( 580000 ACFMI
               ( 300 F)
               ( 325 FT)
»»»«•»*
OIL
NO. 6
•*•*«»

     .07
»*•»••
    1.00
••*••»
    z.oo
*«««»«
•«*••*«*
               (*»»«» FT)
               (»**•** BTU/LB)
                »«**»*
 0
NONE
 0
NONE
NONE
N/A
N/A
N/A
 *• GENERAL DATA
     SALEABLE PRODUCT/THROHAHAY PRODUCT
     SOZ REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY - X
     UNIT DESIGN SOZ REMOVAL EFFICIENCY - X
SALEABLE PRODUCT
MET SCRUBBING
MAGNESIUM OXIDE
GE ENVIRONMENTAL SERVICES
DEMONSTRATION
RETROFIT
   55.00
   90.00
WARNING MUNNORMALIZED NUMBERCSI BEING EDITED FOR OUTPUT**
     ENERGY CONSUMPTION - X                          .0
                                                  1006

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - OECEK3ER 1981
BOSTON EOISON: MYSTIC 6 (CONT.)

     CURRENT STATUS
     TERMINATION
     COMMERCIAL START-UP
     INITIAL START-UP

 •» DESIGN AND OPERATING PARAMETERS

 «» QUENCHER/PRE5ATURATOR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» ABSOPBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     WK3ER CF CONTACTING ZCNES
     LIQUID RECIRCULATIOH RATE - LITER/S
     L/G RATIO - L/CU.M
     INLET GAS FLOW - CU. M/S
     INLET GAS TEMPERATURE - C

 «* MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     NU.-.3ER PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     NUMBER OF PASSES PER STAGE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     WASH MATER SOURCE

 «» REHEATER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» FANS
     NUMBER
     APPLICATION

 »» DAMPEPS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 «« DUCTWORK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 v* REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE
 8
 7/74
 4/7Z
 4/7Z
NR
MR
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
CARBON STEEL
NS
N/A
ORGANIC
EPOXY
NR
N/A
 1
  945.         (15000 GPM)
    4.4        (  33.0 GAL/1000 ACF)
  200.56       (  425000 ACFM)
  148.9        (   300 F)
PRIMARY COLLECTOR
 1
IMPINGEMENT
BAFFLE
CLOSED VANE
    6
NR
NR
FRESH
 0
NONE
N/A
N/A
NONE
N/A
INDUCED DRAFT
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
SLAKER
NR
NR
                                              1007

-------
 EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1961

BOSTON EDISON:  MYSTIC 6 (CONT.)


 «« SOLIDS CONCENTRATING/OEHATERING
     DEVICE                                     CENTRIFUGE
     tAIKSER                                      1
     SHELL GENERIC MATERIAL TYPE                CARBON STEEL
     FEED STREAM CHARACTERISTICS                102 SOLIDS

**• SLUDGE

 »• TREATMENT
     METHOD                                     MR
     DEVICE                                     NR
     PROPRIETARY PROCESS                         NR

 ** DISPOSAL
     MATURE                                     N/A
     TYPE                                       NONE
     SITE TREATMENT                             NR

 »» PROCESS CONTROL AND INSTRUMENTATION
     CHEMICAL PAPAMETERS                         PH, FLUE GAS INLET TEMP.,  SCRUBBER  OUTLET TEMP.
     CONTROL LEVELS                             PH 6.8
     MONITOR LOCATION                           PH - BLEED LINE  FROM ABSORBER  TO  CENTRIFUGE
     PROCESS CONTROL MANNER                     MANUAL
     PROCESS CHEMISTRY MODE                     FEEDBACK

 «• WATER BALANCE
     HATER LCOP TYPE                            CLOSED
	-.	.	PERFORMANCE DATA	
PERIOD MCCULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER   FGO    CAP.
                                                                S02   PART.  HOURS  HOURS   HOURS FACTOR


 4/72  SYSTEM

       «• PROBLEMS/SOLUTIONS/COMMENTS

                        •THIS EXPERIMENTAL MAGNESIUM OXIDE SCRUBBING  UNIT UAS RETROFITTED ON  A 155
                         MU, OIL FIRED  BOILER.   THE SULFUR DIOXIDE AND  PARTICLE MATTER REMOVAL
                         OCCURRED IN THE  VENTURI SCRU33EH  MODULE. THE  S02  UAS CAPTURED  AND CON-
                         VERTED TO MAGNESIUM SULFITE IN THE VENTURI.  THE PRODUCT SLL'PRY UAS  THEN
                         FILTERED AND DRIED.  THE DRY MATERIAL CALCINED AT  HIGH TEMPERATURES  TO
                         DRIVE OFF THE  SO2 AND  REGENERATE  MAGNESIUM OXIDE.   THE 502  STREAM UAS
                         PROCESSED IN A SULFURIC ACID PLANT TO PRODUCE  SULFURIC ACID.  THE UTILI-
                         TY AND THE EPA PROVIDED THE MAJOR PORTION OF THE FUNDING FOt THIS
                         REGENERABLE DEMONSTRATION PROJECT.

 5/73  SYSTEM

       «• PR03LEMS/SOLUTIONS/COMMENTS

                         FROM INITIAL STARTUP IN APRIL 1972 UNTIL HAY 1973  THE SCRUBBER  OPERATED
                         INTERMITTENTLY BECAUSE OF MECHANICAL  DIFFICULTIES.  THE  MAJ03 PROBLEM
                         ENTAILING DESIGN AND OPERATION OF THE MAGNESIUM SULFITE  CRYSTAL DRYER,
                         APPARENTLY UAS RESOLVED BY REDESIGN AND FUEL CHANGE.

 6/73  SYSTEM                  67.9                    55.8                 720   592     402

 7/73  SYSTEM                  61.0                    47.2                 744   575     351

       •« PROBLEMS/SOLUTIONS/COMMENTS

                         DURING JUNE AND  JULY THE LONGEST  PERIOD OF CONTINUOUS OPERATION OCCURRED.
                         THE SYSTEM OPERATED 7.5 DAYS.

 8/73  SYSTEM                                            .0                 744     0
                                              1008

-------
                                              EPA  UTILITY  FGD  SURVEY:  OCTOBER  -  DECEMBER  1961
BOSTCN EDISON:  MYSTIC 6  ICONT. )
	PERFORMANCE  DATA	
PEPIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  7. REMOVAL    PER   BOILER   FGD   CAP.
                                                                S02   PART.  HOURS HCUSS  HOURS  FACTOR


       •» PROBLEMS/SOLUTIONS/CORMENTS

                         DURING AUGUST THE  BOILER HAS  TAKEN OFF-LINE  FOR AN ANNUAL  OVERHAUL.

 9/73  SYSTEM                  36.1                    33.8                  720   637     243

10/73  SYSTEM                  60.1                    50.7                  744   627     377

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         DURING SEPTEMBER AND OCTOBER  HEAVY EROSION/CORROSION IN THE LIGUCR RECIR-
                         CULATION PUMPS AND CENTRIFUGE DECREASED THE  AVAILABILITY OF THE  FGD SYSTZM.

11/73  SYSTEM                  £5.6                    22.5                  720   629     162

12/73  SYSTEM                  13.1                    11.6                  744   656     66

 1/74  SYSTEM                  27.4                    20.4                  744   555     152

 2/74  SYSTEM                  25.5                    20.5                  672   541     133

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         IN JANUARY AND FEBRUARY FREQUENT SHUTDOWNS DUE TO BOILER-RELATED PROBLEMS
                         LIMITED SYSTEM OPERATION.

 3/74  SYSTEM                  86.5                    47.4                  744   408     353

       »* PR08LEMS/SOLUTIONS/COHMENTS

                         SINCE FEBRUARY 1974 THE AVAILABILITY OF THE  BOILER HAS INCREASED.

 4/74  SYSTEM                  80.5                    65.4                  720   585     471

       «» PRCBLEMS/SOLUTIONS/COKMENTS

                         DURING APRIL> TWO  7-DAY CONTINUOUS OPERATION PERIODS OCCURRED.

 5/74  SYSTEM                  57.4                    37.6                  744   468     280

       »» PROBLEMS/SOLUTIONS/COMMENTS

                         DURING MAY, A TWO  WEEK OUTAGE OF THE ACID PLANT MAS THE CAUSE  OF A  LOU
                         FGD SYSTEM OPERABILITY FIGURE.

 6/74  SYSTEM                  51.5                    40.0                  720   559     288

       «« PROBLEMS/SOLUTIONS/COMMENTS

                         DURING JUNE 1974 THE DEMONSTRATION PROGRAM MAS COMPLETED AND THE FGD
                         SYSTEM WAS SHUTDOWN.  EPA FUNDING  OF THE CALCINING PORTION OF  THIS  OPERA-
                         TION EXPIRED.  THERE WERE NO DEFINITE PLANS FOR RESTARTING THIS UNIT.
                         MAJOR PROBLEM AREAS ENCOUNTERED DURING THE OPERATION OF THIS PROTOTYPE
                         UNIT INCLUDED TRIHYORATE INSTEAD OF HEXAHYDRATE SULFITE CRYSTAL FORMATION.
                         DUST PROBLEMS IN THE DRYER, LACK OF STACK GAS REHEAT CAUSING CONDENSATION
                         IN THE STACK, LOUVER DAMPER PROBLEMS, EROSION OF PUMPS, PIPING,  AND
                         CENTRIFUGE, AND MINOR ANCILLARY EQUIPMENT FAILURES.
                                              1009

-------
 EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1961

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
MET PLAN' GENERATING CAPACITY - MM
G=OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENEPATING CAPACITY U/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 «» UNIT DATA - EOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SEPVICE LOAD
     DESIGN EOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 «» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RAN3E ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RAN3E SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

»«« PARTICLE CONTROL

 «» MECHANICAL COLLECTOR
     tiUKSER
     TYPE

 « FABRIC FILTER
     NUMBER
     TYPE

 »» ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - X

 «* PARTICLE SCRUBBER
     NUMEEH
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
COMMONWEALTH EOISCN
MILL COUNTY
1A
ROUE OVULE
ILLINOIS
E
   86.
  774.
*«
-------
                                              EPA UTILITY F6D SURVEY:  OCTC9ER - DECEMBER 1931
CCMMONHEALTH EDISON:  MILL COUNTY 1A (CONT.l

     LIQUID RECIRCULATION RATE - LITER/S
     L/6 RATIO - LITER/CU.M
     PRESSURE DROP -  KPA
     SUPERFICIAL GAJ  VELOCITY - M/S
     INLET GAS FLOW RATE - CU.M/S
     INLET GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICIENCY - 7.

*** FGD SYSTEM

 «* GENERAL DATA
     SALEABLE FRODUCT/THROWAMAY PRODUCT
     SO: REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     A-E FIR.1
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
     UNIT DESIGN S02  REMOVAL EFFICIENCY - 7.
     ENERGY CONSUMPTION - 7.
     CURRENT STATUS
     TERMINATION
     COMMERCIAL START-UP
     INITIAL START-UP

 »» DESIGN AND OPERATING PARAMETERS

 »• QUENCHER/PRESATURATCR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» ABSORBER
     NUM2ER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TPAOE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     LIQUID RECIRCULATION RATE - LITER/S
     L/G RATIO - L/CU.M
     GAS-SIDE PRESSUPE DROP - KPA
     SUPERFICAL GAS VELOCITY - M/SEC
     INLET GAS FLOW - CU. M/S
     INLET GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - 7.

 *• MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     NUMBER PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TPADE NAME/COMMON TYPE
     CONFIGURATION
     NUMBER OF STAGES
     NUMBER OF PASSES PER STAGE
     FREEBOARD DISTANCE - M
     DISTANCE BETWEEN VANES - CM
     VANE ANGLES - DEGREES
     PRESSURE DROP -  KPA
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     UASH HATER SOURCE
   365.4
     2.4
     2.2
    36.6
   181.7
   179. it
    98.0
(  5800 GPM)
(18.0 GAL/1000ACF)
(  9.0 IN-H20)
(   120.0 FT/SI
(  385000 ACFM)
(   355 F)
 THROMAUAY PRODUCT
 WET SCRUBBING
 LIMESTONE
 BABCOCK t WILCOX
 BECHTEL
 FULL SCALE
 RETROFIT
7.   98.00
    76.00
      .0
  8
  7/77
  2/73
  2/72
 NR
 NR
 TRAY TOMER
 SIEVE TRAY
 N/A
 BABCOCK I HILCOX
 16.0 X 24.0 X 60.0
 CARBON STEEL
 HIGH STRENGTH LOU ALLOY
 COR-TEN
 ORGANIC
 NATURAL RUBBER
 BLACK NATURAL RUBBER
 PERFORATED TRAYS
  2
   693.
     4.7
     2.5
     3.0
   181.68
   179.4
    76.0
(11000 GPM)
(  35.0 GAL/1000 ACF)
(10.0 IH-H20)
(  10.0 FT/S)
(  3S5000 ACFM)
(   355 F)
 PRIMARY COLLECTOR
  2
 IMPINGEMENT
 BAFFLE
 CLOSED VANE
 HORIZONTAL
     2
     3
     3.05
     3.8
   45
      .2
 ORGANIC
 FIBER-REINFORCED POLYESTER
 BLENDED
(10.0 FT)
(  1.50 IN)

(  1.0 IN-H20)
                                              1011

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

COMMONWEALTH EDISON: MILL COUNTY 1A (CONT.)
     MASH FREQUENCY
     HASH RATE - L/S

 »» REKEATER
     NUN3EH
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     TEMPERATURE INCREASE - C
     INLET FLUE GAS FLOW RATE - CU. H/S
     INLET FLUE GAS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «» FANS
     NUMBER
     FUNCTION
     APPLICATION
     FLUE GAS TEMPERATURE - C

 *» DAMPERS
     FUNCTION
     GENEPIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 »* OUCTW01K
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 ** REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE
     NUMBER
     FULL LOAD DRY FEED CAPACITY - M.TONS/HR
     PRODUCT QUALITY - X SOLIDS

 «« TANKS
     SERVICE
     SCRUBBER RECYCLE

 *» PUMPS
     SERVICE
     VENTURI RECIPCULATION
     ABSORBER RECIRCULATION

 »« SOLIDS CONCENTRATING/DEUATERING
     DEVICE
     NUMBER
     CONFIGURATION
     DIMENSIONS - FT

 *» SOLIDS CONCENTRATING/DEUATERING
     DEVICE
     NUMBER
     CAPACITY

•»« SLUDGE
UNOERSPRAY-CONTINUOUS; OVERSF3AY-INTESMITTEHT
   71.0        ( 1125 GAL/MIN)
 2
IN-LINE
STEAM
NR
   28.9        (
  179.32       (
   53.3        (
STAINLESS STEEL
AUSTENITIC
  52 F)
38000C ACFM)
 2
BOOSTER
INDUCED DRAFT
   62.2        (
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
COMPAHTMENTED
NR
 2
   10.9        (
   27.5
NUMBER

   2


NUMBER
                  160 F)
 12 TPH)
THICKENER
 1
CIRCULAR. SLOPED BOTTOM
65.0 DIA X 15.0
VACUUM FILTER
 1
90TON/DAY
                                              1012

-------
COMMONWEALTH EDISON:  MILL COUNTY 1A (CONT.)
                                              EPA UTIL"Y FGO SURVEY:  OCTCSER - DECEASES  1981
 »» TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 «* DISPOSAL
     NATURE
     TYPE
     LOCATION
     SITE TREATMENT

 »« DISPOSAL
     NATURE
     TYPE
     LOCATION
     SITE TRANSPORTATION METHOD

 »« PROCESS CONTROL AMD INSTPUMENTATION
     CHEMICAL PARAMETERS
     PROCESS CONTROL MANNER

 *» MATER BALANCE
     WATER LOOP TYPE
FIXATION
PUS MILL
CHICAGO ADMIXTURES
INTERIM
POND
OH-SITE
CLAY LINING
FINAL
LANDFILL
OFF-SITE
TRUCK
PRESSURE, LIMESTONE FEED, PH
AUTOMATIC
                                                CLOSED
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                                •/. REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART. HOURS HOURS  HOURS FACTCR
 0/72  SYSTEM

       *» PROBLEMS/SOLUTIONS/COMMENTS
                         REFER TO THE PERFORMANCE UPDATE INFORMATION FOR MILL COUNTY LOCATED IN
                         SECTION 14 OF THIS REPORT.
                                              1013

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAf.E
UVIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NS/J
NET PLANT GENERATING CAPACITY - MM
G"OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - MM
NET UNIT GENERATING CAPACITY UO/FGD - MM
EQUIVALENT SCRUE3EO CAPACITY - MM

 N» UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 *• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/S
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RAMSE ASH CONTENT - 7.
     AVERAGE MOISTUPE CONTENT - 7.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUS CONTENT - 7.
     PANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - 7.

«»« PARTICLE CONTROL

 «» ESP
     NUMBER

 *» PARTICLE SCRUBBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

«*« FGO SYSTEM

 *« GENERAL DATA
     SALEABLE PRCDUCT/THROUAUAY PRODUCT
     S02 REMOVAL MCOE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
DAIRYUND POMER
ALMA
5
ALMA
WISCONSIN:
«•«•*»
**•«•*
*«*«»*
«*»*«»
  210
   60
»•*«•
•»*«»
   80
»*»*«»
•»*«**
*••*•»
»«»*«•»*
(»»«««» LB/MK8TU)
(»«*«*• LB/TK3TU)
(««**«* LB/MMBTU)
*»*»M»
•««*•»
***»»*»
COAL
•»•*••
(»»tHHHH. ACFM)
(»h«« F)
(MHt« FT)

(»*««« FT)
               (*«*»«» BTU/LB)
                10500-11000
•**••««<»
12.0-20.0
«**«»**»
3.0-3.5
•*«****•
•»*«»*
*»•«••«•
NONE
N/A
N/A
N/A
THROHAUAY PRODUCT
MET SCRUBBING
LIME
FOSTER WHEELER
EXPERIMENTAL
RETROFIT
   32. SO
WARNING «*UNNORMALIZEO NUMBER!S) BEING EDITED FOR OUTPUT**
     ENERGY CONSUMPTION - 7.
     CURRENT STATUS
     TERMINATION
     COMMERCIAL START-UP

 •» DESIGN AND OPERATING PARAMETERS
                                                     .0
 8
 8/74
 6/71
                                                 1014

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
DAIRYUND POWER: ALMA 5 (CONT. )
 «* (JUENCHER/PRESATURATOR
     CONSTRUCTION MATERIAL GENEPIC TYPE         NR
     CONSTRUCTION MATERIAL SPECIFIC TYPE        NH

 ft* ABSORBER
     GENERIC TYPE                               KR
     SPECIFIC TYPE                              NH
     TRADE NAME/COMMON TYPE                     MR
     SHELL GENERIC MATERIAL                     NR
     SHELL SPECIFIC MATERIAL                    NR
     SHELL MATERIAL TRADE NAME/COMMON TYPE      NR
     LINER GENERIC MATERIAL                     NR
     LINER SPECIFIC MATERIAL                    NR
     LINER MATERIAL TRADE NAME/COMMON TYPE      NR

 «» MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR        NR
     GENEPIC TYPE                               NR
     SPECIFIC TYPE                              NR
     TRADE NAME/COMMON TYPE                     NR
     CONSTRUCTION MATERIAL GENERIC TYPE         NR
     CONSTRUCTION MATERIAL SPECIFIC TYPE        NR

 «» REHEATER
     GENERIC TYPE                               NR
     SPECIFIC TYPE                              NR
     TRADE NAME/COMTO.M TYPE                     NP
     CONSTRUCTION MATERIAL GENERIC TYPE         NR
     CONSTRUCTION MATERIAL SPECIFIC TYPE        NR

 «« DAMPERS
     FUNCTION                                   NR
     GENERIC TYPE                               NR
     SPECIFIC TYPE                              NR
     CONSTRUCTION MATERIAL GENERIC TYPE         NR
     CONSTRUCTION MATERIAL SPECIFIC TYPE        NR
     LINER GENERIC MATERIAL TYPE                NR
     LINER SPECIFIC MATERIAL TYPE               NR

 *» DUCTWORK
      SHELL GENERIC MATERIAL TYPE               NR
      SHELL SPECIFIC MATERIAL TYPE              NR
      LINER GENERIC MATERIAL TYPE               NP
      LINER SPECIFIC MATERIAL TYPE              NR

 »» REAGENT PREPARATION EQUIPMENT
     FUNCTION                                   SLAKER
     DEVICE                                     NR
     DEVICE TYPE                                NR

 «* SOLIDS CONCENTRATING/DEMATERINS
     DEVICE                                     NA

««* SLUDGE

 «* TREATMENT
     METHOD                                     NA
     DEVICE                                     NA
     PROPRIETARY PROCESS                        NA

 *« DISPOSAL
     NATURE                                     NR
     TYPE                                       NH
                                              1015

-------
 EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981

DAIRYLAND POWER: AU1A 5 (CONT.)
	PERF09MAHCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION   X REMOVAL   PER  BOILER   FG3    CAP.
                                                                S02  PART. HOURS HOUPS  HOU=?S  FACTOR


 6/71  SYSTEM

       « PROBLEMS/SOLUTIONS/COMMENTS

                         THIS EXPERIMENTAL MET LIME FURNACE SYSTEM COMMENCED OPERATIONS IN  JUNE
                         1971 AND WAS OPERATIONAL FOR  PERIODS UP TO 30 DAYS.  IN AU5UST 1974 THE
                         UNIT MAS TESTED FOR TWO DAYS  USING WESTERN LOU-SULFUR COAL.  THE TEST
                         SHOWED ABOUT SOX S02 REMOVAL  EFFICIENCY, BUT ESP PERFORMANCE WAS ADVERSELY
                         AFFECTED.  THE FGO PROJECT HAS BEEN SHUT DOWM INDEFINITELY SINCE AUGUST
                         1974, AND THERE ARE NO PLANS  FOR FUTURE OPERATION.
                                              1016

-------
                                              EPA UTILITY FGD  SURVEY:  OCTOBER  -  DECEMBER  1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FCR DISCONTINUED  DOMESTIC  FG3  SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
N3X EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGO - MM
NET UNIT GENERATING CAPACITY UO/FGD - HW
EQUIVALENT SCRUBBED CAPACITY - MM

 ** UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.H/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 «» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RAI.'SE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     RAH3E MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUR CONTENT - X
     AVERAGE CHLORI3E CONTENT - X
     RANGE CHLORIDE CONTENT - X

•*» PARTICLE CONTROL

 «* MECHANICAL COLLECTOR
     NUMBER
     TYPE

 »» FABRIC FILTER
     NUMBER
     TYPE

 *• ESP
     NUMBER
     SUPPLIER
     PARTICLE REMOVAL EFFICENCY - X

 *« PARTICLE SCRUE9ER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     LIQUID HECIHCULATION RATE - LITER/S
     L/G RATIO - LITER/CU.M
     PRESSURE DROP - KPA
DETROIT EDISON
ST. CLAIR
6A
BELLE RIVER
MICHIGAN
C
   86.
 1376.
»***»«
 1798
  325
  154
  163
  163
COMBUSTION ENGINEERING
               (   .200 LB/MKBTU)
               (  3.200 LB/rr&TU)
               (««**•» LB/MKBTU)
PEAK
  465.77
  132.2
  130.
*•«»»»
««»»»**        (•*«*« PT)
               ( 987000 ACFM)
               ( 270 F)
               ( 425 FT)
               (  9600 BTU/LB)
                9500-9600
COAL
SUSBITUMINOUS
22330.

    4.00
3.0-4.0
   22.60
22.0-24.0
     .35
0.3-0.4
«•»«•«**
««»«*•
 0
NONE
 0
NONE
MHEELABRATOR-FRYE
   90.0
 2
 9/75
VFNTURI TOWER
VARIABLE-THROAT/ADJUSTABLE DRUM
RADUL FLOW VENTURI
PEAEODY-LURG:
STAINLESS STEEL
AUSTENITIC
ORGANIC
RUBBER
NONE
  276.5        ( 4420 GPM)
    2.7        (20.0 GAL/1000ACF)
    3.5        (14.0 IN-H20)
                                              1017

-------
 EFA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981

DETROIT EDISON: ST.  CLAIR 6A (CONT.)

     SUPERFICIAL GAS VELOCITY - H/S
     IMLET GAS FlOU RATE  - CU.M/S
     INLET GAS TEMPERATURE - C

»•» FGD SYSTEM
    28.3
   116.6
   132.2
(    93.0  FT/SJ
(  247000  ACFK)
(   270  F)
 •» GENEPAL DATA
     SALEABLE PRODUCT/THROUAUAY PRODUCT
     502 REMOVAL MQ3E
     P3CCES5 TYPE
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
     UNIT DESIGN S02 REMOVAL EFFICIENCY - X
 THROUAMAY PRODUCT
 WET SCRUBBING
 LIMESTONE
 PEABODY PROCESS SYSTEMS
 BECHTEL
 DEMONSTRATION
 RETROFIT
X   99.70
    90.00
WARNING *«UNNORMALIZED NUMSER(S) BEIN5 EDITED FOR OUTPUTS-
     ENERGY CONSUMPTION - X
     CURRENT STATUS
     TERMINATION
     COMMERCIAL START-UP
     INITIAL START-UP

 «* DESIGN AND OPERATING PARAMETERS

 »• GUENCHER/PRESATIRATGR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 *» ABSORBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTINS DEVICE TYPE
     L/G RATIO - L/CU.M
     GAS-SIDE PRESSURE DROP - KPA
     SUPERFICAL GAS VELOCITY - M/SEC
     INLET GAS FLOW - CU. H/S
     INLET GAS TEMPERATUPE - C
     S02 REMOVAL EFFICIENCY - X

 *» MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     NUMBER PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONFIGURATION
     FREEBOARD DISTANCE - M
     DISTANCE BETWEEN VANES - CM
     VANE ANGLES - DEGREES
     PRESSURE DROP - KPA
     SUPERFICAL GAS VELOCITY - H/S
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «» REHEATER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TPAOE NAME/COMMON TYPE
     PERCENT GAS BYPASSED - AVG
     TEMPERATURE INCREASE - C
     INLET FLUE GAS FLOU RATE - CU. M/S
                                                     .0
  8
 12/76
  9/75
  6/75
 NR
 NR
 SPRAY TOWER
 OPEN COUNTERCURRENT SPRAY
 N/A
 PEABODY PROCESS SYSTEMS
 STAINLESS STEEL
 AUSTENITIC
 TYPE 316L
 NONE
 N/A
 N/A
 NONE
    10.7        (80.0 GAL/1000 ACF)
     2.3        (io.o IN-H:OI
     2.9        (  9.5 FT/S)
   101.46       ( 215000 ACFM)
    47.a        (  118 F)
    90.0
 PRIMARY COLLECTOR
  2
 CENTRIFUGAL
 RADIAL VANE
 RADIAL BAFFLE
 HORIZONTAL
     1.37       ( 4.5 FT)
    20.3        ( 8.00 IN)
   45
      .0        (  .2 IN-HZO)
     3.0        ( 10.0 FT/S)
 STAINLESS STEEL
 AUSTENITIC
 DIRECT COMBUSTION
 EXTERNAL COMBUSTION CHAMBER
 OIL
      .0
    27.8        (    50 F)
   187.20       (  396700 ACFM)
                                                 1018

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
DETROIT EDISON:  ST.  CUIR 6A (CONT.)

     INLET FLUE  GAS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 *• FANS
     NUMBER
     SUPPLIER
     FUNCTION
     APPLICATION
     SERVICE
     CONSTRUCTION MATERIAL GENERIC TYPE

 »* DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 «« DUCTUORK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 •* REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE
     NUMBER
     PRODUCT QUALITY - 7. SOLIDS

 »« PUMPS
     SERVICE
   50.0
NR
NR
               (  122 F)
     VENTURI RECIRCULATION
     SPRAY TOMER RECIRCULATION

 »» SOLIDS CONCENTRATING/DEWATERING
     DEVICE
     NUMBER

**» SLUDGE

 »« TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 «» DISPOSAL
     NATURE
     TYPE
     SITE TRANSPORTATION METHOD
     SITE TREATMENT
     SITE SERVICE LIFE - YRS

 •» PROCESS CONTROL AND INSTRUMENTATION
     CHEMICAL PARAMETERS
     CONTROL LEVELS
     MONITOR LOCATION
     PROCESS CONTROL MANNER
     PROCESS CHEMISTRY MODE

 •• MATER BALANCE
     WATER LOOP TYPE
PEABODY ENGINEERING
BOOSTER
INDUCED DRAFT
WET
TYPE 316L STAINLESS STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NONE
N/A
N/A
 1
   35.0
                                                NUMBER
   3
   6
NONE
 0
BLEED
N/A
N/A
FINAL
POND
PIPE LINE
NONE
  1
PH. SOLIDS
PH 5.8-6.0. SOLIDS 15X
RECYCLE TANK
AUTOMATIC
FEEDBACK
                                                OPEN
                                              1019

-------
 EPA UTILITY fGD SURVEY:  OCTOBER - DECEMBER 1981

DETROIT EDISON:  ST.  CLAIR 6A (CONT.)
	.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER   FG3    CAP.
                                                               SOZ  PART. HOURS  HOUPS  HCU'S  FACTOR


 0/75  SYSTEM

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         REFER TO THE PERFORMANCE UPDATE INFORMATION FOR ST. CLAIR 6  LOCATED IN
                         SECTION 14 OF THIS REPORT.
                                              1020

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1931

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
C:TY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - MW
NET UNIT GENERATING CAPACITY UO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 «* UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.H/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 «* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTUPE CONTENT - X
     AVERAGE SULFU3 CONTENT - X
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - X

«»« PARTICLE CONTROL

 •» ESP
     NUMBER

 ** PARTICLE SCRUBBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME

••* FGO SYSTEM

 ** GENERAL DATA
     SALEABLE PROOUCT/THROUAUAY PRODUCT
     S02 REMOVAL MCOE
     PROCESS TYPE
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     NEK/RETROFIT
GULF POWER
SCHOLZ
1
SNEADS
FLORIDA
E
*««»**
«*«»*«
»«**««
   60
   20
•»**»
(««»«»« LB/MMSTU)
(«»««*« LB/MM3TU1
(»*»*«» LB/MM3TU)
   20
BABCOCK t UILCOX
PULVERIZED COAL
BASE
   50.02
*******
******
**»»«*
•*«•«»»
COAL
«*«««*
30905.

«*»•**»«
«**»«»
**««***»
******
    3.25
3.0-3.5
«*«*****
»»*»**
(  106000 ACFM)
(»*»« F)
(»«»* FT)

(»»»*« FT)
(  12900 BTU/LB)
 ••*»*«
NR
NR
NR
THROHAUAY PRODUCT
WET SCRUBBING
DUAL ALKALI/LIMESTONE
THYSSEN/CEA
A.O. LITTLE
DEMONSTRATION
RETROFIT
WARNING "UNNORMALIZEO NUMBER(S) BEINS EDITED FOR OUTPUT**

     ENERGY CONSUMPTION - X                          .0
     CURRENT STATUS                              8
     INITIAL START-UP                            8/80

 »* DESIGN AND OPERATING PARAMETERS

 *» QUENCHER/PRESATUBATOS
     CONSTRUCTION MATERIAL GENERIC TYPE         NR
     CONSTRUCTION MATERIAL SPECIFIC TYPE        NR
                                                        1021

-------
 EPA UTILITY F63 SURVEY: OCTOBER - DECEMBER 1981

GULF POWER: SCHOLZ 1 (CCNT.)
 «» ABSO'BER
     GENERIC TYPE                               TRAY TOWER
     SPECIFIC TYPE                              NR
     TRADE NAME/COMMON TYPE                     NR
     SHELL GENERIC MATERIAL                     NR
     SHELL SPECIFIC MATERIAL                    NR
     SHELL MATERIAL TRADE NAME/COMMON TYPE      NR
     LINER GENERIC MATERIAL                     NR
     LINER SPECIFIC MATERIAL                    NR
     LINER MATERIAL TRADE NAME/COMMON TYPE      NR
 »» MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 ** REHEATER
     GENERIC TYPE
     SPECIFIC TYPE
     TiJAOE NAME/COMMON TYPE
     TEMPERATURE INCREASE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 ** FANS
     DESIGN
     FUNCTION
     APPLICATION
     SERVICE

 «» DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENEPIC MATERIAL T1PE
     LINER SPECIFIC MATERIAL TYPE

 *n DUCTWORK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENEPIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 »» REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 *» SOLIDS CONCENTRATING/OEWATERING
     DEVICE
     NUMBER
     SHELL GENERIC MATERIAL TYPE
     SHELL SPECIFIC MATERIAL TYPE

 •• SOLIDS CONCENTRATING/DEUATERING
     DEVICE
     NUM5ER
     SHELL SPECIFIC MATERIAL TYPE
     FEED STREAM CHARACTERISTICS

*«« SLUDGE
NR
NR
NR
NR
NR
NR
INDIRECT HOT AIR
NR
NR
   22.2        (   40 F)
NR
NR
CENTRIFUGAL
BOOSTER
INDUCED DRAFT
WET
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
THICKENER
 1
CARBON STEEL
FLAKE REINFORCED LINING
VACUUM FILTER
 1
FIBERGLASS
20X SOLIDS
                                              1022

-------
                                              EPA UTILITY  FGD  SURVEY: OCTOBER  - DECEMBER 1961
GULF POWER: SCHOLZ 1 (CONT.)
 «» TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 ** DISPOSAL
     NATURE
     TYPE
     SITE TREATMENT

 *« WATER BALANCE
     WATER LOOP TYPE
OEUATERED
N/A
N/A
FINAL
POND
CLAY LINING.
                                                CLOSED
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                                X REMOVAL    PER   BOILER  FGD   CAP.
                                                                S02   PART. HOUPS  HOURS  HOURS FACTOR
 8/80  SYSTEM
                                                                             744
       «* PROBLEMS/SOLUTIONS/COMMENTS
                         INITIAL OPERATION OF THIS DEMONSTRATION LIMESTONE  DUAL ALKALI SYSTEM BEGAN
                         ON AUGUST 20.   OPERATIONS DURING THE  REST OF  THE MONTH WERE  INTERMITTENT
                         AS MECHANICAL PROBLEMS MERE RECTIFIED.
 9/60  SYSTEM

10/80  SYSTEM

11/80  SYSTEM

       »» PROSLEMS/SOLUTIOHS/COMMENTS
                             720

                             744

                             720
                         THE FGD SYSTEM CONTINUED TO OPERATE THROUGH NOVEMBER IN A DEBUGGING  MODE
                         OF OPERATION.
12/60  SYSTEM
                                                       75.9
                                                                             744
                                                                                          565
       •* PRC3LEMS/SOLUTIOHS/COMMENTS
                         DURING DECEMBER THE DEMONSTRATION FGD SYSTEM OPERATED CONTINUOUSLY FOR
                         TWO EIGHT DAY PERIODS.   DURING THIS TIME THE SYSTEM S02 REMOVAL EFFICIENCY
                         WAS FOUND TO BE GREATER THAN 90X.

                         THE FGD SYSTEM MAS FORCED TO REMAIN OFF LINE FOR 6-6 DAYS IN DECEMBER
                         DUE TO AN UNAVAILABILITY OF RAM MATERIALS.
 1/81  SYSTEM

       »« PRCBLEMS/SOLUTIONS/COMMENTS
                                                       43.4
                                                                             744
                                                                                          323
                         AT THE END OF JANUARY THE SYSTEM HAS SHUT DOWN TO MAKE COPRECTICNS TO THE
                         THICKENER.  REPAIRS HERE CONDUCTED ON THE OVERFLOW WEIR AND RETURN LINES
                         TO THE THICKENER CENTERUELL.
 2/81  SYSTEM
                   86.2
                               86.2
                                                       66.2
                                                                             672   672
                                                                                          579
       «» PROBLEMS/SOLUTIONS/COMMENTS
                         THE SYSTEM HAS STARTED UP ON FEBRUARY 2 AT NOONTIME.  AFTER CORRECTIONS HERE
                         COMPLETED ON THE THICKENER.   FAN MAINTENANCE REQUIRED A BRIEF 10  MINUTE
                         SHUT DOWN LATER ON THAT DAY.  AFTER TWO DAYS OF OPERATION, THE SYSTEM HAS
                         SHUT DOWN ON FEBRUARY 4 FOR  11 HOURS.  THIS HAS A PREVENTIVE MEASUPE TO
                         ALLOW SOLIDS IN THE THICKENER TO SETTLE (THICKENER OVERFLOW UAS CLOUDY).
                         THE SYSTEM HAS RESTARTED ON  FEBRUARY 5 AND OPERATED FCR 3 DAYS BEFC3E IT
                         MAS SHUT DOWN DUE TO THE INABILITY TO TRUCK AWAY SOLID HASTE MATERIAL.
                         HEAVY RAINS HASHED OUT THE ROADS TO THE PONDS AND THE TRUCKS COULD NO LONG-
                                              1023

-------
 EPA UTILITT FGD SURVEY:  OCTOBER  -  DECEMBER  1981

GULF POKER: SCKOLZ 1 CCQNT.)
	PERFORMANCE DATA	
PERIOD HCOULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X REHOVAL   PER  BOILER  FG3   CAP.
                                                               SOZ  PART. HOURS HOURS  HOWS FACTOR

                         ER HAUL  THE HASTE MATERIAL DISCHARGED BY THE VACUUM FILTER.  IMPROVEMENT IN
                         WEATHER  COOITIOM5 AND  THE  SFPEADIKG OF SOME PCCKS ON THE PCNO BANKS MADE
                         IT POSSIBLE TO RESUME  WASTE DISPOSAL; THE SYSTEM UAS RESTARTED OH FESRUA3Y
                         10 AFTER 39 HOURS OF INTERRUPTION.  IT OPEPtTED UNTIL THE ENO OF THE MOUTH
                         WITH  ONE OUTAGE  ON  FEBRUARY 27 DUE TO A FAILURE IN THE SCRUS5E? PUMPS.
                         THE AVERAGE SOZ  REMOVAL EFFICIENCY FOR THE flOHTH UAS 95.7 PERCENT.

 3/81  SYSTEM      58. Z                               46.5                  744          346

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         TWO SEPERATE  OUTAGES OCCURRING ON MARCH Z AND MARCH 3 TOTALING 7.8 HOURS
                         WERE  DUE TO PROBLEMS WITH  THE SCRUBBER PUMPS.  THE MOTOR IN ONE PUMP UAS
                         INOPERATIVE AND  THE IMPELLER IN  THE OTHER PUMP HAD TO BE REPLACED.

                         A THIRD  OUTAGE LASTING 190 HOURS WAS REQUIRED TO REPAIR THE VACUUM FILTER.
                         THE PERFORMANCE  OF  THE VACUUM FILTER HAD BEEN DETERIORATING STEADILY.
                         LEAKS HAD BEEN DETECTED IN THE INTERNAL PIPINS OF THE FILTER DRUM AND BY
                         THE TIKE THE  FILTER WAS REMOVED, ONLY HALF OF THE PANELS WERE ABLE TO PULL
                         CAKE. THE SYSTEM UAS  RESTARTED  ON MARCH 13 AFTER THE FILTER HAD SEEM FIXED
                         AND REINSTALLED.  ALTHOUGH ALL 12 PANELS HERE PULLING CAKE. THE QUALITY OF
                         THE SOLID CAKE PRODUCED BY THE FILTER DID NOT IMPROVE SIGNIFICANTLY
                         (PERCENT SOLIDS  CONCENTRATION UAS ABOUT 40 PERCENT 1.  THE VACUUM REMAINED
                         LOU,  5 TO 10  INCHES OF H6, VERSUS THE DESIGNED VACUUM OF 5 TO 10 INCHES HG.

                         THE SOLIDS LEFT  IN  THE THICKENER DETERIORATED AS FAR AS SETTLING CHARAC-
                         TERISTICS ARE CONCERNED. WHILE THE FILTER UAS BEING REPAIRED.  THESE SOLIDS
                         SLOWLY RESU5PENDED  DURING  THE 8  DAY OUTAGE.  WHEN THE SYSTEM WAS RESTARTED
                         ON MARCH 13.  THE RESUSPENSIOM OF SOLIDS UAS AUGMENTED BY THE CIP.CULATICM
                         OF LIQUOR THROUGHOUT THE SYSTEM.  THIS PROBLEM CAUSED 3 OUTAGES TOTALING
                         94 HOURS. A  FLOCCULANT WAS USED TO HELP IN THE SETTLING OF THESE SOLIDS.

                         OH MARCH 23,  THE RAKE  LOCKED IN  PLACE.  ROTATION OF THE RAKE WAS STOPPED
                         TO PREVENT RESUSPENSION OF SOLIDS WHILE GOOD SETTLING SOLIDS BEING GENER-
                         ATED  IN  THE REACTORS WERE  BEIKS  USED TO FOPM A BLANKET TO COVER THE PCC3
                         SETTLING SOLIDS.  AM AIR-LIGU09  SPARGER UAS USED TO FREE THE RAKE.  THE
                         OUTAGE LASTED 23 HOURS. THE SYSTEM RESTARTED AND OPERATED UNTIL NOON,
                         MARCH 28. TESTING  OF  THE  SYSTEM CONCLUDED AT THAT TIME.  THE AVERAGE S02
                         REMOVAL  EFFICIENCY  DURING  THE OPERATING TIME IN THE MONTH OF MARCH UAS
                         96.8  PERCENT.

                         THE DECISION  CONCERNING THE FUTURE OF THE FGD SYSTEM IS LEFT UP TO THE
                         SOUTHERN COMPANY WHICH CONSISTS  OF FOUR POWER COMPANIES I GULF, ALABAMA.
                         GEORGIA. AND  MISSISSIPPI).
                                              1024

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
PEGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOC EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENEF4TING CAPACITY - MM
GROSS UNIT GENe3ATIN3 CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - KM
NET UNIT GENERATING CAPACITY UO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU

 *« UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BCILEP FLUE GAS FLOU - CU.M/S
     EOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 »« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - V.
     AVEPAGE MOISTURE CONTENT - X
     PASSE MOISTURE CONTENT - X
     AVEPAGE SULFUR CONTENT - X
     RANGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RAN3E CHLCRIOE CONTENT - X

»«» PARTICLE CONTROL

 «« ESP
     NUMBER
     TYPE
     SUPPLIER
     PARTICLE REMOVAL EFFICENCY - X

 •« PARTICLE SCRUBBER
     NUMBER
     INITIAL STAPT-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TPAOE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE

*«* FGD SYSTEM

 «* GENERAL DATA
     SALEABLE PRODUCT/THROUAUAY PRODUCT
     S02 REMOVAL RODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     NEW/RETROFIT
GULF POWER
SCHOLZ
1A
SNEAOS
FLORIDA
C
**«»««
  516.
****»•
   60
   43
   40
•«»*•
   48
BABCOCK t HILCOX
PULVERIZED COAL
BASE
(«»»««* LB/MM3TU)
(  1.200 LB/MM3TU)
(»*«»*« LB/MM3TU)
»*«*«««*
  146.1
**»«M»
NR
«*•«»««
COAL
**»•»•
«««**»


•«*»**»»
«»»*»«
«**•**»«
«*«»«•
    5.00
(«***•»« ACFM)
(  295 F)
(**«» FT)

(«»»«* FT)
(»««••• BTU/LB)
 ******
»«»«»***
******
COLO SIDE
BUELL DIVISION,
   99.5
 ENVIROTECH
 1
 8/75
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
THYSSEN/CEA
CARBON STEEL
AISI 1110
INORGANIC
HYDRAULICALLY-BOHDED CEMENT
NONE
THROUAUAY PRODUCT
MET SCRUBBING
DUAL ALKALI
THYSSEN/CEA
FPOTOTYPE
RETROFIT
                                              1025

-------
 EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981
GULF POWER; SCHOLZ IA ICONT.>
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY - X   99.70
     UNIT DESIGN S02 REMOVAL EFFICIENCY - X        95.00
HARMING «*UNNORMALIZED NUHBER(S) BEING EDITED FOR OUTPUT**
                                                     .0
     ENERGY CONSUMPTION - X
     CURRENT STATUS
     TERMINATION
     COMMERCIAL START-UP

 »• DESIGN AND OPERATING PARAMETERS

 ** CUEMCHER/PRESATURATOR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »tt ABSQPBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE

 «« MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COnrCN TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «« REHEATER
     KUKSER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     PERCENT GAS BYPASSED - AVG
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 *• DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CC.'STPUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 •« DUCTUQRK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 »» REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 «» SOLIDS COHCENTRATING/OEUATERINS
     DEVICE
     NUMBER
     CONFIGURATION
     SHELL SPECIFIC MATERIAL TYPE
 8
 7/76
 Z/7S
KR
NR
VENTURI TOMER
NR
NR
THYSSEN/CEA
CARBON STEEL
AISI 1110
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
KR
HOME
NR
I1R
KR
NR
NR
NR
 1
NR
NR
NR
    5.0
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
VACUUM FILTER
 1
ROTARY DRUM
PLASTIC t FIBERGLASS
                                                    1026

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER  -  DECEMBER  1981
GULF POWER: SCHOLZ 1A CCONT.)
*»» SLUDGE

 »• TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 »» DISPOSAL
     MATURE
     TYPE
     LOCATION
     SITE TREATMENT

 •• WATER BALANCE
     WATER LOOP TYPE
                  DEUATERED
                  N/A
                  N/A
                  FINAL
                  POND
                  ON-SITE
                  CLAY  LINING
                                                CLOSED
	PEPFOHMAHCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                                7. REMOVAL
                                                                S02  PART.
                                              PER   B'JILES  FGD    CAP.
                                             HOURS HOURS  HOUPS FACTOP
 2/75  SYSTEM
                               98.9
                                                       67.6
                                                                             672   459
                                                                                          454
       »* PROBLEMS/SOLUTIONS/COMMENTS
 3/75  SYSTEM

 4/75  SYSTEM

 5/75  SYSTEM

 6/75  SYSTEM

 7/75  SYSTEM
                         THIS PROTOTYPE FGD SYSTEM INSTALLED AT THE SCHOLZ STEAM PLANT WAS IN-
                         STALLED ON THE NO. 1 BOILER.  THE SYSTEM WAS DESIGNED TO HANDLE APPROXI-
                         MATELY SOX OF THE FLUE GAS FROM THE BOILER.  THE BOILER MAS RETROFITTED
                         WITH A SECTIONALIZED, HIGH EFFICIENCY ESP INSTALLED UPSTREAM OF THE FGO
                         SYSTEM AND CAPABLE OF 99.T/. PARTICLE MATTER REMOVAL.
                         THE PROTOTYPE SYSTEM INCORPORATED A HIGH DEGREE OF FLEXIBILITY FCR GENERA-
                         TION OF DESIGN AND OPERATINS INFORMATION FOR A HIDE VARIETY OF APPLICA-
                         TIONS.  ALTHOUGH THE BASIC MODE OF SYSTEM OPERATION MAS DUAL ALKALI V.ITH
                         LIME REGENERATION. THE SYSTEM UAS DESIGNED TO ACCOMMODATE LIMESTONE
                         REGENERATION AND LIME/LIMESTONE REGENERATION.  THE SYSTEM CONSISTED OF A
                         VENTURI SCRUBBER AND AN ABSORPTION TOWER, WITH AN ADDITIONAL STORAGE SILO
                         FOR LIMESTONE. A MIX TANK, AND OTHER ASSORTED TANKS, PUMPS, CONTROLLERS.
                         PIPING, AND A LINED DISPOSAL POND.

                         THE PROTOTYPE DUAL ALKALI SCRUBBING SYSTEM UAS COMPLETED AND PUT IN
                         OPERATION IN EARLY FEBRUARY 1975.
 95.7

 55.6

 62.7

100.0

 32.4
 65.2

 46.7

 50.4

100.0

 29.7
744   507

720   604

744   593

720   720

744   683
485

33*

375

7ZO

C£l
       «* PROBLEMS/SOLUTIONS/COMMENTS
                         THE SYSTEM MAS OPERATED FROM FEBRUARY 8. 1975 UNTIL JULY 18 WHEN IT UAS
                         TAKEN OUT OF SERVICE FOR TUO MONTHS FOR MODIFICATIONS, REPAIRS AND REPLACE-
                         MENT OF PARTS.  THE SYSTEM UAS UNAVAILABLE FCR A 491 HOUR PERIOD DUE TO
                         SOME NECESSARY ADJUSTMENTS AND MODIFICATIONS FCR A FORMAL EPA TEST PRO-
                         GRAM IN MID-MAY.
 8/75  SYSTEM

 9/75  SYSTEM
   .0

 44.0
   .0

 35.3
744   744

7CO   577
  0

254
                                              1027

-------
 EPA UTILITY FGD SUPVEY:  OCTOBER - DECEMBER 1981
GULF POWER: SCHOLZ u tcoirr.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION   X REMOVAL   PER  BOILER   FGD   CAP.
                                                                S02  PART. HOURS HOURS  HOURS  FACTOR


       »» PROBLEMS/SOLUTIONS/COMMENTS

                         THE SYSTEM WAS SHUT DOWN FROM MID-JULY  TO MID-SEPTEMBER FOR A MECHANICAL
                         OVEPHAUL INVOLVING REPLACEMENT OF  VALVE PARTS THAT HAD FAILED.   THE SYSTEM
                         MAS PUT BACK IN OPERATION ON  SEPTEMBER  16.

10/75  SYSTEM                 100.0                    75.1                 744   559    559

       *« PROBLEMS/SOLUTIONS/COMMENTS

                         FROM MID-SEPTEMBER UNTIL MID-OCTOBER THE AIR PREHEATER MAS REPAIRED AND
                         BOILER  OPERATION MAS ADJUSTED TO REDUCE OXYGEN  LEVELS IN THE FLUE GAS TO
                         THE 5-6X RANGE.   THE SYSTEM OPERATED APPROXIMATELY 600 HOURS DURING THIS
                         PERIOD.

11/75  SYSTEM                  90.3                    77.6                 720   620    560

12/75  SYSTEM                 100.0                    96.4                 744   732    732

 1/76  SYSTEM                                                               744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE SYSTEM RAH CONTINUOUSLY FOR THE REMAINDER OF THE TEST PERIOD THROUGH
                         JANUARY 2, 1976.   S02 LEVELS  DURING THIS PERIOD RANGED FROM 600  TO 1700
                         PPM.  THE SYSTEM OPERATED IN  THE CONCENTRATED MCCE THROUGHOUT THE REMAINDER
                         OF THE  TEST PERIOD.   IN  THE PERIOD FROM MID-SEPTEMBER TO JANUARY 2. 1976
                         THE SYSTEM OPERATED ABOUT 2100 HOURS. WITH AN OPERABILITY FACTOR OF 97*.

 2/76  SYSTEM                                                               696

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGO SYSTEM AND BOILER WERE SHUT DOWN FOP A  SCHEDULED OVEPHAUL.  THE
                         SYSTEM  MAS SCHEDULED TO  RESTART IN MID-MARCH AND WAS TO CONTINUE UNTIL
                         JUNE.   DURIN5 THIS OPERATING  PERIOD HIGH-SULFUR COAL (3.5-4.OX)  WAS TO
                         BE BURNED TO ALLOW EVALUATION OF SYSTEM PERFORMANCE ON HIGH SULFUR COAL.

 3/76  SYSTEM                 60.0                    59.6                 744   742    445

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         THE SYSTEM MAS RETURNED  TO SERVICE ON MARCH 12. 1976.  THE SYSTEM OPERATED
                         A TOTAL OF 445 HOURS.

 5/76  SYSTEM                 68.6                    67.5                 744   735    651

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING  APRIL AND  MAY SOME MINOR MECHANICAL PROBLEMS WITH THE AGITATOR
                         SHAFT HERE ENCOUNTERED.

                         SOME PROBLEMS WERE EXPERIENCED WITH THE CONTROL VALVES DURING APRIL AN3 HAY
                         ACCOUNTING FOR SOME  FGD  OUTAGE TIME.

                         SINCE THE SYSTEM  RESTART IN MARCH, S02  INLET CONCENTRATION LEVELS RANGED
                         FROM 2000 TO 2500 PPM DUE TO  THE BURNING OF HIGH SULFUR COAL.

 6/76  SYSTEM                 97.7                    69.0                 720   656    641
                                              1028

-------
                                              EPA UTILITY F6D SURVEY:  OCTOBER - DECEASES 1981

GULF POWER: SCHOLZ 1A (COMT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART.  HOURS HOURS  HOURS FACTOR


       «» PHOBLEMS/SOLUTIONS/COMMENTS

                         DURING THE LAST PHASE OF OPERATION.  THE SYSTEM UAS TREATING FLUE GAS OF
                         VARYING PARTICULATE MATTER LOADS.  THE UPSTREAM ESP MAS SELECTIVELY DE-EN-
                         ERGIZED. BOTH PARTIALLY AND TOTALLY. WITH NO MAJOR UPSETS IN THE FPCCESS
                         CHEMISTRY RESULTING.  BOILER LOAD VARIATION RANGED FROM 30 TO 100/C.

 7X76  SYSTEM                 100.0                     7.3                  744    54     54

       «« PROBLEMS/SOLUTIONS/COMHENTS

                         ON JULY 3, 1976 THE PROTOTYPE TEST PROGRAM MAS CONCLUDED.
                                              10Z9

-------
 EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FG9 SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PANICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
N3X EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GPOSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - KM
NET UNIT GENERATING CAPACITY MO/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - MH
 »* UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW
     BOILER FLUE GAS TEMPERATURE
     STACK HEIGHT - M
     STACK SHELL
     STACK TCP DIAMETER - M
cu.n/s
c
«* FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT CONTENT - J/G
    RANGE HEAT CONTENT - BTU/LB
    AVERAGE ASH CONTENT - X
    RANGE ASH CONTENT - 7.
    AVERAGE MOISTUPE CONTENT - I
    RANGE MOISTURE CONTENT - X
    AVERAGE SULFUR CONTENT - 7.
    RANGE SULFUR CONTENT - X
    AVERAGE CHLORIDE CONTENT
    RANGE CHLORIDE CONTENT -
                              - 7.
                              7.
«** PARTICLE CONTROL
 «« ESP
     NUMBER
     TYPE
     SUPPLIER
     PARTICLE REMOVAL EFFICENCY - 7.

 •» PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMCN NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE

»•» FGD SYSTEM

 ** GENERAL DATA
     SALEABLE PRODUCT/THROHAUAY PRODUCT
     502 REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     NEW/RETROFIT
                            (*«»*** LB/MMBTU)
                            ( 1.200 LB/MK3TU)
                            («»*«»« LB/MM3TU)
                                               GULF POWER
                                               SCHOLZ
                                               1B,2B
                                               SNEADS
                                               FLORIDA
                                               C
                                               #*«»»»
                                                 516.
                                               »*««»*
                                                  80
                                                  48
                                                  40
                                               »»*•«
                                                  48
                                               BABCOCK I UILCOX
                                               PULVERIZED COAL
                                               BASE
                                               «*«»***»       (*»•*«** ACFM)
                                                 146.1        ( 295 F)
                                                  23.         (  76 FT)
                                               FIBER-REINFORCED POLYESTER
                                               **»»*»»        (»«»»* FT)
                                                COAL
                                                »«**Ht»
                                                *•**»•
                                                               («»«»«« BTU/LB)
                                                                »**•**
                                                *«*•»»
             ««*»•*
                 5.00
             **««**
             •»»«**«*
             •****•
             COLO SIDE
             BUELL DIVISION.
                99.5
                                                               ENVIROTECH
              1
              2/75
             VENTURI TOUER
             VARIABLE-THROAT/aOP-ENTRY PLUMS BOS
             N/A
             CHIYODA INTERNATIONAL
             CARBON STEEL
             AISI 1110
             INORGANIC
             HYDRAULICALLY-BONOEO CEMENT
             NONE
             THROUAWAY PRODUCT
             NET SCRUBBING
             THOROUGHBRED 101
             CHIYODA INTERNATIONAL
             PHOTOTYPE
             RETROFIT
                                              1030

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
GULF POWER: SCHOLZ 13,28 (CONT.)

     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
     UNIT DESIGN SOS REMOVAL EFFICIENCY - X
     ENERGY CONSUMPTION - X
     CURRENT STATUS
     TERMINATION
     COMMERCIAL START-UP

 ** DESIGN AND OPERATINS PARAMETERS

 »* OUENCHEP/PRESATURATCR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »• ABSORBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TPAOE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE

 «» MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     NUMBER PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TPADE HAME/COMHSN TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «» REHEATER
     GENERIC TYPE
     SPECIFIC TYPE
     TPAOE NAME/COMMON TYPE
     PERCENT GAS BYPASSED - AVG
     CCNSTPUCTICN MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» DAMPEPS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 «« OUCTU3PK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 «* REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICi
     DEVICE TYPE

 «« SOLIDS CONCEKTRATING/OEHATEHING
     DEVICE
     NUMBER
     CONFIGURATION

««« SLUDGE
7.   99.70
    90.00
 «*»•»»*
  a
  3/77
  2/75
 NR
 NR
 PACKED TOMER
 NR
 NR
 CHIYODA INTERNATIONAL
 STAINLESS STEEL
 AUSTENITIC
 TYPE 316L
 NONE
 N/A
 N/A
 PRIMARY COLLECTOR
  2
 IMPINGEMENT
 BAFFLE
 CLOSED VANE
 NR
 NR
 NR
 NR
 NR
     5.0
 NR
 NR
 NR
 NR
 NR
 NR
 NR
 NR
 NR
 NR
 NR
 NR
 NR
 MIX TANK
 M/A
 AGITATED TANK
 CENTRIFUGE
  1
 CONTINUOUS SCREU-OECANTER/SOLID SOUL
                                              1031

-------
 EPA UTILITY FGO SURVEY:  OCTOBER - DECEIVER  19B1

GULF POWER: SCHOLZ 1B.2B (CCNT. I
                                                DEWATERED
     DEVICE                                     N/A
     FPOPRIETARY PROCESS                        N/A

 •» DISPOSAL
     NATURE                                     FINAL
     TYPE                                       POI«)
     SITE TREATMENT                             CLAY LINING

 »» WATER BALANCE
     MATER LOOP TYPE                            OPEN
	.,	PERFORMANCE DATA—	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FC-3   CAP.
                                                                SOZ  PART.  HCU3S HOURS  HOURS FACTOR


 2/75  SYSTEM                                                                672   672

       «» PROBLEHS/SOLUTIONS/CCKMENTS

                         THE F6D SYSTEM AT SCHOLZ IB AND 2B WAS DESIGNED FOR TESTING AND PROCESS
                         DEMONSTRATION OF THE THROUGHBREO 101 PROCESS ON A  COAL-FIRED APPLICATION.
                         THE PROCESS IS USED IN JAPAN EXCLUSIVELY ON OIL-FIRED AND GAS-FIRED ECIL-
                         ERS. AND TAIL GAS FROM CLAUS UNITS.  THE SYSTEM WAS DESIGNED TO HANDLE
                         SOX OF THE LOAD FROM EITHER OF THE TWO BOILERS. VARIOUS TEST COALS WITH
                         SULFUR CONTENTS RANGING UP TO 57. MERE SCHEDULED FCP BU=NIK5.
                         THE PARTICLE MATTER 1.0ACS FROM THE ESP RANGSO FROM 0.02 TO 0.1 GR/SCF.
                         FLUE GAS FROM THE ESP WAS QUENCHED WITH COOLINS WATER TO REMOVE ADDITIONAL
                         FLY ASH AMD TO COOL THE GAS BEFORE IT ENTERED THE  ABSCPBER.  THE SOC HAS
                         ABSORBED IN WATER AfJD CATALYTICALLY OXIDIZED WITH  AIR TO FORM SULFURIC
                         ACID.  THE DILUTE ACID WAS RECIRCULATED THROUGH THE ABSOR3ER.  A PORTION
                         OF THE AGIO WAS NEUTRALIZED WITH LZHESTONE TO PRODUCE GYPSUM AS A BY-
                         PRODUCT.

                         THE INITIAL SHAKEDOWN A HO DEBUGGING OPERATIONS AT  THIS PILOT PUNT SIZE
                         DEMONSTRATION UNIT COMMENCED ON FEBRUARY 11, 1975.  PROBLEMS ENCOUNTERED
                         INCLUDED CRACKS IN THE FRP LINIKS AT THE OXIDIZING TOWER.

 3/75  SYSTEM                                                                744

       •« PROBLEMS/SOLUTICNS/COMflENTS

                         AFTER INITIAL OPERATION FOR BREAK-IN TESTS IN MARCH, THE SYSTEM MAS
                         SHUTDOWN FOR INTERNAL INSPECTION.

 4/75  SYSTEM                  27.6                    27.8                  7ZO   720    £00

 5/75  SYSTEM                  13.4                    13.4                  744   744    100

 6/75  SYSTEM                 100.0                    95.1                  720   685    665

 7/75  SYSTEM                  83.9                    83.9                  744   744    624

       «» PROSLEHS/SOLUTIONS/COrinENTS

                         RELIABILTY TESTS HERE PERFORMED IN JULY ALTHOUGH EMISSION TESTS HAD NOT
                         BEEN RUN AT THIS TIME.

                         UP TO THIS POINT, SOUS PUMP AND INSTRUMENTATION FAILURES HAD OCCURRED.

                         DURING JULY ONE CENTRIFUGE BECAME UNBALANCED, REQUIRING THE SPARE TO BE
                         PLACED IH SERVICE.

 6/75  SYSTEM                                                                74*

 9/7S  SYSTEM                  46.6                    46.8                  720   720    337
                                              1032

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER  1981

GULF POWER: SCHOLZ 13,28 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD    CAP.
                                                                S02  PART.  HOUPS HOURS  HOUFS FACTOR


       «» PROBLEMS/SOLUTIONS/COMMENTS

                         DURING THE MONTH OF AUGUST BOTH CENTRIFUGES BECAME UNBALANCED REQUIRING
                       .  A FORCED OUTAGE WHICH EXTENDED INTO MID-SEPTEMBER.

                         THE UNIT OPERATED AT A 95X SOZ REMOVAL EFFICIENCY  DURING THE MONTH OF
                         SEPTEMBER.

10/75  SYSTEM                 100.0                   100.0                  744   744    744

       «« PRC3LEMS/SOLUTIONS/COMMENTS

                         THE DISCHARGE OF WASTE MATER FROM THIS SYSTEM WAS  A CONTIUOUS PROBLEM
                         AREA.

11/75  SYSTEM                 100.0                   100.0                  720   720    720

       «» PROBLEMS/SOLUTIONS/COMMENTS

                         A MINOR OUTAGE OF LESS THAN ONE HOUR WAS NECESSARY TO REPAIR A PINHOLE
                         IN THE PRESCRUBBER FRP LINER AND TO REPAIR A BROKEN FLUE GAS BLOWER  INLET
                         VANE.

12/75  SYSTEM                  97.6                    97.6                  744   744    726

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         SCRUBBER OUTAGES DURING DECEMBER RESULTED FROM CONTINUING REPAIRS TO THE
                         PINHOLE IN THE PRESCRUBBER FRP LINER.

 1/76  SYSTEM                  66.2                    60.5                  744   680    450

 2/76  SYSTEM                  11.2                    11.1                  696   690     77

       «« PROBLEMS/SOLUTIONS/COMMENTS

                         OUTAGE TIME IN JAWARY AND FEBRUARY WAS PRIMARILY  FOR REPAIR AND MODIFI-
                         CATION OF THE SUCTION AND DISCHARGE PIPING ON THE  ABSORBENT CIRCULATING
                         PUMPS.  THESE FRP LINES FAILED IN JANUARY AT SOME  WEAK JOINTS.

                         SOZ REMOVAL EFFICIENCY UP TO THIS PERIOD HAS BEEN  AS HIGH AS 95X.

 3/76  SYSTEM                  99.6                    99.6                  744   744    741

 4/76  SYSTEM                  14.0                    14.0                  720   720    101

       «« PROBLEMS/SOLUTIONS/COMMEHTS

                         THE SYSTEM WAS SHUTDOWN ON APRIL 5 TO ALLOW SYSTEM MODIFICATIONS FOR
                         REDUCING THE QUANTITY OF LIQUID WASTE FROM THE SYSTEM.

                         THE SYSTEM WAS SHUTDOWN ON APRIL 24 BECAUSE OF EXTENSIVE FIRE DAMAGE IN
                         THE OXIDIZING TOWER.  THE FIRE. CAUSED BY A WELDING ACCIDENT, DAMAGED FRP
                         AND POLYPROPYLENE COMPONENTS IN THE OXIDIZING TOWER.

 5/76  SYSTEM                                            .0                  744           0

 6/76  SYSTEM                                            .0                  723           0

 7/76  SYSTEM                                            .0                  744           0
                                              1033

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER  1981

GULF POWER: SCHOLZ 18.2B (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  7. REMOVAL    PE9   BOILER   FGD    CAP.
                                                                S02   PART. HOURS  HOL'RS   HOURS  FACTOR


       *• PROBLEMS/SOLUTIONS/COHMENTS

                         THE SYSTEM REMAINED  OUT OF SERVICE  DURING MAY, JUNE AND  JULY TO REPAIR THE
                         FIRE DAMAGED AREAS.

 8/76  SYSTEM                  66.1                    66.1                   744    744     492

       •* PROBLtHS/SOLUTICNS/COKMENTS

                         THE SYSTEM CAME  BACK ON LINE  IN AUGUST;  BUT, HAS BROUGHT DOWN OUPIH3  THE
                         MONTH TO COMPLETE ADDITIONAL  REPAIRS  WHICH UEMT UNDETECTED DURING THE
                         PREVIOUS OUTAGE.   THESE ADDITIONAL  REPAIRS ACCOUNTED FCR APPROXIMATELY 242
                         HOURS OF OUTAGE  TIME.

                         THE MATERS SAVINGS PROGRAM MAS TESTED DURING AUGUST. THE  TEST  PROGRAM
                         CALLED FOR A REDUCTION IN  HASTEIUTER  SLOWDOWN AND FRESH  MATER MAKEUP
                         REQUIREMENTS BY  RECYCLING  THE MOTHER  LIQUOR  BLEED BACK TO  THE PROCESS FOR
                         ADDITIONAL SERVICE.

 9/76  SYSTEM      99.3        68.9        99.3        68.9                   720    720     496

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE SYSTEM MAS FORCED OUT  OF  SERVICE  APPROXIMATELY  FIVE  HOURS OURINS
                         SEPTEMBER.

10/76  SYSTEM      70.6        48.0        62.0        48.0                   744    744     357

       «• PROSLEMS/SOLUTICNS/COMMENTS

                         DURINS OCTOBER SYSTEM DOWN TIME AMOUNTED TO  APPROXIMATELY  387 HOURS.   OF
                         THIS TOTAL 218 HOURS MERE  REPORTED  TO REPAIR ANTICIPATED DAMAGES INCURRED
                         IN THE PRESCRUBBER RESULTING  FPOM OPERATIONS IN THE WATER  SAVINGS PPOSRArt.
                         SPECIFICALLY, THE LINING HAD  SUFFERED FROM EXTENSIVE COPROSICN  D-AMAGE
                         BECAUSE OF HIGH  ACID CONCENTRATIONS WHICH DEVELOPED IN THE SCRUBBER
                         SOLUTION.

                         DURING OCTOBER SYSTEM DOWN TIME AMOUNTED TO  APPROXIMATELY  387 HOURS.   OF

11/76  SYSTEM      99.6        99.6        99.6        99.6                   720    723     717

12/76  SYSTEM      99.6        99.6        99.6        99.6                   744    744     741

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING NOVEMBER  AND  DECEMBER  SCRUBBER OUTAGES TOTALLED 6.5 HOURS. PROBLEMS
                         INCLUDED A MALFUNCTION OF  A LEVEL INDICATOR. A BROKEN GUIDE VANE, AND AN
                         OPERATOR ERROR RESULTING IN A LEAK  OF SLURRY INTO THE MATER HEADER.

                                                                             744    744     744

                                                                             672    672     672

                                                                             744    744     514

       »• PR03LEMS/SOLUTIONS/COMMENTS

                         THE CT-101 TESTING AND DEMONSTRATION  PROGRAM MAS CONCLUDED ON MARCH 22.
                         DURING JANUARY,  FEBRUARY AND  MARCH  THE TOTAL SCRUBBER OUTAGE TIME MAS
                         0.33 HOUR.  THE  SYSTEM HAD OPERATED ON A VIRTUALLY  CONTINUOUS BASIS SINCE
                         OCTOBER 17,  1976.
1/77 SYSTEM
2/77 SYSTEM
3/77 SYSTEM
100.0
100.0
100.0
100.0
100.0

100.0
100.0
100.0
100.0
100.0

                                              1034

-------
                                              EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1931

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGO - MM
NET UNIT GENERATING CAPACITY WO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM
 «« UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILEP TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM
     BOILER FLUE GAS TEMPERATURE
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M
     CU.M/S
     C
 «» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT
     RANSE MOISTUPE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT
     RANGE CHLORIDE CONTENT -
- X
- X
                              X
»»» PARTICLE CONTROL
 «» ESP
     NUMBER
     TYPE
     SUPPLIER
     INLET FLUE GAS TEMPERATURE - C
     PARTICLE REMOVAL EFFICENCY - X

 *» PARTICLE SCPUB3ER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

«•« FGD SYSTEM

 »• GENERAL DATA
     SALEABLE PRODUCT/THROMAMAY PRODUCT
     S02 REMOVAL MODE
     PROCESS TYPE
     PROCESS ADDITIVES
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
     UNIT DESIGN SOS REMOVAL EFFICIENCY - X
GULF POMER
SCHOLZ
1.2
SMEADS
FLORIDA
C
««>»»«*
«*«**•
*«•**»
   80
   23
   23
                                 (»»*»•« LB/MKBTU)
                                 (*«»»*» LB/MKBTU)
                                 (**«««* LB/Mr.3TU)
                                                   23
BABCOCK S MILCOX
PULVERIZED COAL
BASE
****»««»       (**»*«*
COAL
BITUMINOUS
£9075.

   11.00
«»*«»«
    5.00
*«»*»»
    2.50
2.5-5.0
*»»•*»*»
**««»*
                  COLD SIDE
                  BUELL DIVISION. ENVIROTECH
                    151.7        (   305 F)
                     99.5
                  NONE
                  N/A
                  N/A
                  N/A
                  THPCUAUAY PRODUCT
                  KET SCRUBBING
                  LIMESTONE/THOROUGHBRED 121
                  NONE
                  CHIYODA INTERNATIONAL
                  CHIYODA CHEMICAL ENG'R 1 CONSTION
                  FPOTOTYPE
                  RETROFIT
                 X   99.50
                     90.00
WARNING "UNNOHMALIZED NUMBER!S) BEING EDITED FOR OUTPUT**

     ENERGY CONSUMPTION - X                          .0
     CURRENT STATUS                              6
                                               1035

-------
 EPA UTILITY FGO SURVEY:  OCT03ER - DECEMBER 1981

GULF POWER: SCHOLZ l.C (CONT.>

     TERMINATION
     INITIAL START-UP

 »• DESIGN AND OPERATING  PARAMETERS

 ** QUENCHER/P5ESATURATOR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» ABSORBER
     N'JfSEH
     GSNEPIC TYPE
     SPECIFIC TYPE
     TPAOE NAKE/COnnON TYPE
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LIMER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     INLET GAS FLOW - CU. M/S
     INLET GAS TEMPERATURE - C
     S02 REMOVAL EFFICIENCY - X

 «* MIST ELIMINATOR
     PRE-KIST ELIMINATOR/MIST ELIMINATOR
     NUnSER PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONFIGURATION
     NUMBER OF STAGES
     NUrSEP OF PASSES PER STAGE
     PRESSURE DROP - KPA
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »« REHEATER
     GENERIC TYPE
     SPECIFIC TYPE
     TPADE NAME/COMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «» FANS
     NUMBER
     APPLICATION
     FLUE GAS FLOW RATE - CU.M/S
     FLUE GAS TEMPERATURE - C

 «» DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 »* OUCTUCRK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE
 6/79
 6/78
NR
NR
MECHANICALLY-AIDED TOMER
GAS SPARGER
JET BUBBLER REACTOR
CHIYODA INTERNATIONAL
24.0 DIA
STAINLESS STEEL
AUSTENITIC
NR
ORGANIC
FIBER-REINFORCED POLYESTER
HR
N/A
 1
   37.73       (  80000 ACFM)
  148.9        (  300 F)
   95.0
PRIMARY COLLECTOR
 1
IMPINGEMENT
BAFFLE
CLOSED VANE
VERTICAL
    2
     .Z
               I 1.0 IN-HZO)
NR
NR
NONE
N/A
N/A
NONE
N/A
FORCED DRAFT
   25.01
  148.9
NR
NR
NR
N<>
NS
NR
NR
NR
NR
NR
NR
53000 ACFM)
300 F)
                                              1036

-------
GULF POWER:  SCHOLZ 1,2 (CONT.)
                                              EPA UTILITY  F60  SURVEY:  OCTOBER  - DECEMBER  1981
 «» PEAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 «« SOLIDS CONCENTRATING/OEWATEHING
     DEVICE

«*« SALEABLE BYPRODUCTS
     NATURE
     DISPOSITION

««* SLUDGE

 «» TREATMENT
     METHCO
     DEVICE
     PROPRIETARY PROCESS

 »« DISPOSAL
     NATURE
     TYPE
     SITE TREATMENT

 «* PROCESS CONTROL AND INSTRUMENTATION
     PROCESS CONTROL MANNER

 «• WATER BALANCE
     HATER LOOP TYPE
UET BALL MILL
COMPARTMENTEO
NR
NONE
GYPSUM
STACKED IN PONO
FORCED OXIDATION
JET BUBBLER
N/A
FINAL
POND
CLAY LINING
MANUAL


CLOSED
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FGD    CAP.
                                                                SOS  PART.  HOURS HOUPS  HOURS FACTOR


 6/78  SYSTEM                                                                744

       «« PRC3LEMS/SOLUTIONS/COMMENTS

                          OPERATION BEGAN ON AUGUST 30. 1978.

                          NO INITIAL OPERATIONAL PROBLEMS MERE REPORTED.

 9/78  SYSTEM                                                                720

10/78  SYSTEM                 100.0                                          720

       «» PRCBLEMS/SOLUTIONS/COMMENTS

                          NO MAJOR OPERATIONAL PROBLEMS WERE REPORTED.

                          A 130 HOUR SCHEDULED OUTAGE OCCURRED IN OCTOBER.

11/78  SYSTEM                  94.8                                          720

12/78  SYSTEM                 100.0                                          744

       «e PR03LEMS/SOLUTIONS/COMMENTS

                          THERE HERE NO UNPLANNED SHUTDOWNS DURING DECEMBER AND JANUARY.

                          THE SYSTEM HAS BEING OPERATED IN WHAT MAS CALLED PHASE II OF THE TESTING.
                          THE SYSTEM HAS DELIBERATELY BEING UPSET FROM EQUILIBRIUM (FH, OXIDIZING AI
                          INPUT, ETC.) TO SEE HOM IT RESPONDED.
                                              1037

-------
 EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981

G'JLF POWER: SCHOLZ 1.2 (CCNT. J
	PERFORMANCE DATA	
PERIOD M33ULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                               S02  PART. HCbSS HOURS  HOURS FACTOR


 1/79  SYSTEM                 100.0                                          744            0

 3/79  SYSTEM                  98.3                     98.4                  672   672    661

 3/79  SYSTEM     100.0       100.0        100.0       100.0                  744   744    744

 4/79  SYSTEM     100.0       100.0        100.0       100.0                  720   720    720

       *» PR03LEHS/SOLUTIONS/COMMENTS

                         ONE PUMP FAILURE  CAUSING A 5 MINUTE OUTAGE HAS REPORTED BY THE UTILITY.

                         HIGH PARTICULATE  LOADING TESTS WERE DONE IN APRIL.  THE ESP MAS TOTALLY
                         SHUT DOWN.   THE S02  REMOVAL WAS NOT AFFECTED BUT THE GYPSUM PRODUCT WAS
                         TEMPORARILY  AFFECTED.   HIGH CHLORIDE TESTS UERE ALSO PERFORMED BY ADDING
                         CALCIUM CHLORIDE  TO  THE SYSTEM.  A RESULTANT CONCENTRATION OF 6000 PPM
                         CHLC3IDE UAS FOUND IN THE  UNDERFLOW.  NO SIGNIFICANT SCALING UAS ENCOUNT-
                         ERED.

 5/79  SYSTEM                                                               744

 6/79  SYSTEM                                                               720

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGD SYSTEM OPERATED THROUGH THE 24TH OF MAY WHEN THE SYSTEM UAS RE-
                         MOVED FROM SERVICE BECAUSE THE EPRI STUDIES HERE COMPLETED.
                         JUNE:
                         AFTER SHUTDOWN THE UNIT UAS MODIFIED TO SIMULATE A SMALLER JET BUE3LER
                         REACTOR UITH THE  SAME AMOUNT OF FLUE GAS.  THIS UAS DONE BY PLUGGING SOME
                         OF THE SPAPGERS AND  RISER  TUBES.  THE UNIT UAS OPERATED LIKE THIS F»C;1
                         JUNE 8 UNTIL JUNE 29 UITH  RESULTS THAT INDICATED SLIGHTLY REDUCED PEHOVAL
                         EFFICIENCIES.  DURING THE  21 DAYS OF OPERATION THE UNIT UAS DOWN ONLY
                         ONCE FCR NINE  HOURS  FOR ROUTINE INSPECTION.
                         OURIKS THE EPRI STUDY A TOTAL  OF 4448 HOURS OF OPERATION UERE LOGGED UITH
                         A TOTAL OF 123.3  HOURS  OF  SHUTDOWN.  THE AVERAGE AVAILABILITY FOR SIX
                         MONTHS UAS 99.53X.
                         ALL STUDIES  UERE  COMPLETED AND THE SYSTEM HAS BEEN TERMINATED.
                                             1038

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NQ/J
N3X EMISSION LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - MM
GPOSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MM

 «• UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOM - CU.I1/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 «« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANSE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANSE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTURE CONTENT - V.
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RANSE CHLORIDE CONTENT - X

««« PARTICLE CONTROL

 »« MECHANICAL COLLECTOR
     NUMBER
     TYPE

 «» ESP
     NUMBER

 v« PARTICLE SCRUBBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

*«» FGD SYSTEM

 «» GENERAL DATA
     SALEABLE PRODUCT/THROWAHAY PRODUCT
     S02 REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     NEM/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
     UNIT DESIGN S02 REMOVAL EFFICIENCY - X
 GULF  POMEB
 SCHOLZ
 £A
 SNEADS
 FLORIDA
 C
 •**»»*
 «**»*•
               (»•»»»»
               (»*«*»* LB/MM3TU)
               (*»<*«• L8/MMBTU)
    60
    48
    40
 »***«
    48
 BABCOCK t UILCOX
 PULVERIZED COAL
 BASE
««»»*»*«
  146.1
««»»*»
«»***«
»»*»»•»
 COAL
 BITUMINOUS
                (»««»»«« ACFM)
                (  295 F)
                (««»» FT)

                (»«»»« FT)
                («»»»«« BTU/LB)
                 •**»«*
 «•»»«*•*
 *»*««»
 «»**««*»
 ******
     3.50
 «««*««
 »*«•**»»
  0
 NONE
 NONE
 N/A
 N/A
 N/A
 SALEABLE PRODUCT
 DRY AO^RPTICN
 ACTIVATED CARBON
 FOSTER UHEELER/BEPGBAU
 DEMONSTRATION
 RETROFIT
X   99.70
    74.50
MAPNING «»UNNORMALIZEO NUKBER(S) BEING EDITED FOR OUTPUT"*
     ENERGY CONSUMPTION -
     CUPRENT STATUS
     TERMINATION
     COMMERCIAL START-UP
  8
  5/76
  2/76
                                                1039

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 19S1

JULF POWER: SCHOLZ 2A (CONT.)

     INITIAL START-UP
     CONTRACT AWARDED

 «» DESIGN AND OPERATING PARAMETERS
 8X75
 1/73
 ** QUENCHER/PRESATURATOR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «» ABSORBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATEPIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE

 »» MIST ELIMINATOR
     FRE-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 •» REHEATER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAttE/COMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «« DAMPEPS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 «« DUCTWORK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 •» REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 »» SOLIDS CONCENTRATINS/DEUATEHIN3
     DEVICE

««» SLUDGE

 »« TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS
NR
NR
PACKED TOKER
NR
KR
FOSTER UHEELER/BERG8AU
NR
NR
NR
NR
NR
NR
MR
NR
NR
NR
NR
NR
 0
NONE
N/A
N/A
NONE
N/A
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
N/A
N/A
N/A
NONE
N/A
N/A
N/A
                                              1040

-------
                                              EPA UTILITY F60 SURVEY:  OCTOBER - DECEMBER 1961
GULF PC-ER: SCHOLZ ZA ICOHT.)
 «» DISPOSAL
     NATUPE
     TYPE
     SITE TREATMENT
                       FINAL
                       POND
                       CLAY LINING
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                                X REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART.  HOURS HOURS  HOURS FACTOR
 5/7S  SYSTEM

       «« PROBLEMS/SOLUTIONS/COMMENTS
                                                    744
                         THE DEMONSTRATION SYSTEM AT SCHOLZ £A CONSISTED OF A 20-MW ADSORBER  SECTION
                         AMD A 47.5 MW REGENERATION AND REDUCTION SECTION.   THE ZO MM ADSC'EER
                         MAS DESIGNED TO HANDLE SOX OF THE MAXIMUM FLUE GAS FLOW.   THE PURPOSE  OF
                         THE ADSORPTION SECTION OF THE DRY REMOVAL SrSTEM WAS TO REMOVE SULFUR
                         DIOXIDE; NITROGEN OXIDES. AND PARTICLE MATTER FROM THE FLUE GAS WITH
                         ACTIVATED CHAR, CONVERTING THE CAPTURED POLLUTANTS TO SULFURIC ACID.  THE
                         REGENERATION SECTION PROVIDED CONTINUOUS ON-SITE REGENERATION OF THE CHAR,
                         WHICH MAS LOADED WITH SULFUR DIOXIDE IN THE FORM OF SULFL'PIC ACID.   THE
                         REGENERATED CHAR AND A LOU VOLUME. SULFUR DIOXIDE-RICH OFF-GAS STREAM  WAS
                         FED TO A RESOX REACTOR, WHICH REDUCED THE SULFUR DIOXIDE  STREAM
                         TO GASEOUS ELEMENTAL SULFUR THAT HAS COLLECTED AND STORED IN AN INSULATED
                         TANK.
 6/75  SYSTEM

 7/75  SYSTEM

       *» PROBLEMS/SOLUTIONS/COMMENTS
                                                    720

                                                    744
                         COMPLETION OF CONSTRUCTION WAS FOLLOWED BY A THREE MONTH COMMISSIONING
                         PERICD DURING WHICH VARIOUS PIECES OF EQUIPMENT WERE OPERATED INDIVIDUALLY
                         AND THEN IN COMBINATIONS TO SIMULATE SUBSYSTEM OPERATION.
 6/75  SYSTEM
                                                                             744
       «« PROBLEMS/SOLUTIONS/COMMENTS
                         SUBSYSTEM OPERATIONS WERE INTEGRATED INTO SECTION OPERATIONS AND FLUE GAS
                         WAS PASSED THROUGH THE ABSORBER AND REGENERATOR FOR A TEN DAY PERIOD
                         BEGINNING AUGUST 11.  RESOX CONSTRUCTION UAS INCOMPLETE AT THIS TIME.
 9/75  SYSTEM

10/75  SYSTEM

       »« PROBLEMS/SOLUTIONS/COMMENTS
                                                    720

                                                    744
                         DURING OCTOBER TWO CONSECUTIVE RUNS WERE CONDUCTED ON THE RESOX PORTION OF
                         THE SYSTEM ON FRONT-END PROCESS OFF-GAS AT FULL OPERATING TEMPERATURES.
                         THIS OPERATIONAL PERIOD LASTED FIVE DAYS.
11/75  SYSTEM

12/75  SYSTEM

 1/76  SYSTEM

       «» PROBLEMS/SOLUTIONS/COMMENTS
                                                    720

                                                    744

                                                    744
 2/76  SYSTEH
A PROGRAM OF MODIFICATIONS ON THE SYSTEM BEGAN IN LATE AUGUST 1975 AN3
CONTINUED THROUGH JANUARY 1976, WITH THE EXCEPTION OF FIVE DAYS OF RESOX
OPERATION IN OCTOBER.

                                                    696
                                              1041

-------
 EPA UTILITY FG3 SURVEY:  OCTOBER  -  DECEMBER  1981

GULF POWER: SCHOLZ 2A (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERA3ILITY  RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER   FGD   CAP.
                                                               S02  PART. HOURS HOURS  HOURS  FACTCR


       »» PP08LEMS/SOLUTIONS/COMMENTS

                         MODIFICATIONS  HERE  COMPLETED AND PRE-STARTUP TESTIN5 UAS CONDUCTED IN LATE
                         JA'JUARY  AND EARLY FEBRUARY.  A THREE DAY CONTINUOUS RUN UAS SUCCESSFULLY
                         COMPLETED.

                         DUPIN5 FEBRUARY  THE MATERIALS HANDLING LOOPS AND THE RESOX LOOPS WERE
                         OPERATED AT FULL OPERATING TEMPERATURES AND PRESSURES.  REINTH03UCTION OF
                         FLUE GAS INTO  THE SYSTEM COMMENCED. AND A FOUR MONTH FORMAL TEST PPOGRAM
                         CONDUCTED BY SOUTHERN  SERVICES AND FOSTER WHEELER BEGAN.

 3/76  SYSTEM                                                               744

 4/76  SYSTEM                                                               720

       «» FR08LEMS/SOLUTIONS/COMMENTS

                         THREE OPERATIONAL PERIODS  HERE LOGGED BY THE PROTOTYPE SYSTEM DURING  MAPCH
                         AND APRIL.  THE  RESOX  SECTION OPERATED INTERMITTENTLY BECAUSE OF PLU3GIN3
                         PROBLEMS IN THE  SULFUR CONDENSER.  ALSO, THE FRONT END OF THE SYSTEM  UAS
                         TAKEN CUT OF SERVICE AT ONE POINT DUE TO FREQUENT HIGH TEMPERATURE
                         EXCURSIONS.  THIS PROBLEM  UAS CORRECTED BY MODIFYING SYSTEM OPERATING
                         PROCEDURES.  WORK BEGAN ON THE SOLUTION OF THE SULFUR CCN3EN5ER  PR03LEM.

 5/76  SYSTEM                                                               744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGD  SYSTEM COMPLETED AN OPERATIONAL PERIOD IN EARLY MAY WHICH HAD
                         COMMENCED ON APRIL  26.  THE SYSTEM UAS TAKEN OUT OF SERVICE AT THIS POINT
                         DUE TO THE DEPLETION OF CHAR SUPPLY, HIGH CHAR CONSUMPTION RATES DUE  TO
                         MECHANICAL ATTRITION AND TO CORRECT/MODIFY THE CHAR/SAND SCREEN  SEPARATOR.

                         DURING MAY A DECISION  UAS  HADE TO PREMATURELY TERMINATE THE SYSTEM
                         DEMONSTRATION  PROGRAM  RATHER THAN SHUT DOWN, DEBUS AND RESTART THE SYSTEM
                         AGAIN.   THE SYSTEM  SUPPLIER UAS PURSUING ADDITIONAL FUNDING FCR  THE
                         CONTINUATION OF  THE PROTOTYPE DEMONSTRATION PROGRAM.
                                             1042

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER  - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT HAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GPOSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGD - HU
NET UNIT GENERATING CAPACITY KO/FGO - KM
EQUIVALENT SCRUBBED CAPACITY - KM

 «* UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOU - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - H

 «* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVEPAGE HEAT CONTEND - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUP CONTENT - X
     RANGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

««» PARTICLE CONTROL

 «* MECHANICAL COLLECTOR
     NUMBER

 •« FABRIC FILTER
     NUMBER
     TYPE

 «• ESP
     NUMBER
     SUPPLIER
     PARTICLE REMOVAL EFFICENCY - X

 «« PARTICLE SCRUBBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

»« FGD SYSTEM

 *« GENERAL DATA
     SALEABLE PRCDUCT/THROWAHAY PRODUCT
     SOS REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
 ILLINOIS POWER COMPANY
 UOOD RIVER
 EAST ALTON
 ILLINOIS
 D
 «»*»•*
   774.
 *»**«*
   651
   110
   103
(»««»»» LB/MMSTU)
(  1.800 LB/MM3TU)
(«*»*«» LB/MMBTU)
   110
 COMBUSTION ENGINEERING
 PULVERIZED COAL
 BASE
 fc»««»*«*       (**»«*** ACFM)
   154.4        (  310 F)
    76.         (  250 FT)
 *««**»
 »»»«»»»        (•*»»» FT)
 COAL
 ******
 25121.

    10.00
 *«»»**
     4.30
 **«*««
     3.10
 «*»««»
 ««»*•***
 «*»*»*
(  10800 BTU/LB)
  0
 NONE
 RESEARCH-COTTRELL
    99.6
 NONE
 N/A
 N/A
 N/A
 SALEABLE PRODUCT
 WET SCRUBBING
 CATALYTIC OXIDATION
 MONSANTO ENVIRO CHEM SYSTEMS
 DEMONSTRATION
 RETROFIT
X   99.90
                                              1043

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER  1961

ILLINOIS POWER COMPANY: WOOD RIVER 4 (CONT.)

     UNIT DESIGN SOI REMOVAL EFFICIENCY - X
     ENERGY CONSUMPTION - X
     CURRENT STATUS
     TERMINATION
     COMMERCIAL START-UP
     INITIAL START-UF
     CONTRACT AWARDED

 »« OESISN AND OPERATING  PARAMETERS

 «* QUENCHER/PSESATURAT08
     CONSTRUCTION MATEPIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
      85.00
        .0
    6
    0/74
   10/72
    9/72
    6/70
   NR
   NR
 «» ABSORBER
     NUT'S ER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/CCMMON TTPE
     DIMENSIONS - FT
     SHELL GENERIC MATEPIAL
     SHELL SPECIFIC MATEPIAL
     SHELL MATERIAL TRADE  NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE  NAME/COMMON TYPE
     NUM3ER OF CONTACTING  ZONES
     DISTANCE BETWEEN GAS  CONTACTING ZONES
     GAS-SIDE PRESSURE DROP - KPA
     INLET GAS TEMPERATURE - C
     SOS REMOVAL EFFICIENCY - X

 •« ABSOPBER
     MUKSER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATEPIAL TRADE  NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE  NAME/COMMON TYPE
     INLET GAS TEMPERATURE - C

 «» MIST ELIMINATOR
     FRE-MIST ELIMINATOR/MIST ELIMINATOR
     NUKSER PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     PRESSURE DROP - KPA
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     MASH FREQUENCY

 »* REHEATER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     PERCENT GAS BYPASSED  - AVG
     TEMPERATURE INCREASE  - C
     INLET FLUE GAS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUC.ION MATERIAL SPECIFIC TYPE

 ** FANS
     NUMBER
     APPLICATION
   PACKED TOMER
   NR
   NR
   30.0 DIA X 65.0
   CARBON STEEL
   AISI 1110
   N/A
   NR
   NR
   NR
    8
CM    30.5
       1.0
     454.4
      85.0
(    12.0IN)
(  4.0 IN-H20)
(   830 F)
   PACKED TOMER
   NR
   NR
   CAPBON STEEL
   AISI 1110
   N/A
   INORGANIC
   PREFIREO BRICK/SHAPES
   ACID-RESISTANT BRICK [LOU H20 ABSORPTION!
     121.1        (  250 F)
   PRIMARY COLLECTOR
    1
   IMPINGEMENT
   MESH
   KNITTED HIRE MESH PAD
       4.5        (18.0 IN-H20)
   HIGH ALLOY
   NR
   INTERMITTENT
    1
   IN-LINE
   NR
   NR
      14.5
     247.8        (  446 F)
     176.7        (  350 F)
   NR
   NR
                                                INDUCED DRAFT
                                              1044

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
ILLINOIS POWER COMPANY: WOOD RIVER 4 (CONT.)
 »* FANS
     CONSTRUCTION MATERIAL GENERIC TYPE

 »» CAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 »» OUCTWCHK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 «» REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 «» TAWS
     SERVICE
     PRODUCT ACID

 «« PUMPS
     SERVICE
     ACID RECIRCULATION
     PRODUCT ACID

 *• SOLIDS COHCENTRATING/DEUATERIN5
     DEVICE
     NUMBER

»»« SLUDGE

 »» TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 »« DISPOSAL
     NATURE
     TYPE
     SITE TREATMENT

 »» PROCESS CONTROL AN9 INSTRUMENTATION
     CHEMICAL PARAMETERS
 STAINLESS STEEL
 KB
 NR
 NR
 NR
 NR
 HR
 NR
STAINLESS STEEL
NR
NONE
N/A
N/A
N/A
N/A
NUMBER

   2


NUMBER
ita
 o
N/A
N/A
N/A
N/A
NONE
NR
                                                TEMPERATURE,  ASH LOADINGS.  ACID CONCENTRATION
	^	PERFORMANCE  DATA	
PERIOD tlODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02   PART.  HOURS HOURS  HOURS FACTCR
 9/72   SYSTEM

       ** PHCBlEHS/SOLUTIONS/CCrCIENTS
       33.9
                             7CO
                                          £44
                         THE  EMISSION CONTROL  EQUIPMENT AT  THE  HOOD RIVER  SITE  INCLUDED  MECHANICAL
                         COLLECTOPS, A HIGH  EFFICIENCY  ESPi  AND A MONSANTO CATALYTIC  OXIDATIOM
                         (CATOX)  FGD SYSTEM  FOR  THE CONTROL OF  PARTICLE  MATTER  AND  SULFUR  DICXIDE.
                         FOLLOWING  PASSAGE THROUGH THE  PARTICLE MATTER REMOVAL  SYSTEM, THE FLUE  GAS
                                              1045

-------
 EPA UTILITY FGO SURVEY:  OCTOBER  - DECEMBER  1981

ILLINOIS POWER  COMPANY: WOOD  RIVER 4 (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7.  REMOVAL    PE9  BOILER   FGO    CAP.
                                                                S02   PART. HOUPS HOUPS  HOUPS  FACTOR

                         ENTERED THE SCRUBBINS SYSTEM  AliO WAS HEATED  TO A TEMPERATURE OF  650F  AND
                         THEM PASSED THROUGH  A VANADIUM PENTOXIOE  FIXED-BED  CATALYTIC CCNVEPTER,
                         WHERE THE SULFUR DIOXIDE  HAS  OXIDIZED TO  SULFUR TPIOXI3E.  THE GAS  THEN
                         FLOWED  THROUGH AN  ACID ABSORPTION  TOWER >  k'HEPE THE  SULFUR  TRIOXIDE  IN THE
                         GAS WAS CONVERTED  TO SULFURIC ACID.   AN ACID HIST ELIMIHVT09 EHSJSE3
                         REMOVAL OF ENTRAINED ACID MIST FROM  THE GAS  STREAM.   THE CLEANED GAS  WAS
                         DISCHARGED TO THE  STACK AND THE PRODUCT ACID HAS COOLED AND STORED  IN
                         TANKS.

10/72  SYSTEM                                          23.9                  744           17S

       •• PROBLEnS/SOLUTIONS/COMMENTS

                         THE WOOD RIVER SYSTEM WAS STARTED-UP IN SEPTEMBER 1972 BUT WAS SHUTDOWN
                         ALMOST  IMMEDIATELY (IN OCTOBER) TO CONVERT THE BURNERS TO  OIL FIRING.

 7/73  SYSTEM                                          21.2                  744           158

       «* PROBLEMS/SOLUTIONS/COMMENTS

                         IN JUNE 1973 THE CONVERSION TO OIL FIRING HAS COMPLETED AND A SUCCESS-
                         FUL PERFORMANCE TEST WAS  MADE. A  CATALYST PLUGGING HAZARD CAUSED THE
                         SYSTEM  TO SHUTDOWN AGAIN  TO INSTALL  AN EXTERNAL BURNER SYSTEM.

                         IN APRIL 1974 THE  INSTALLATION OF  THE EXTERNAL BURNERS WAS COMPLETED.
                         VARIOUS OTHER PROBLEMS OCCURRED, WITH THE RESULT THAT ONLY 657 HOURS
                         OF OPERATING TIME  WAS LOGGED  IN TWO  YEARS.

                         SEVERAL OTHER MAJOR PROBLEM AREAS  ENCOUNTERED DURING THE INTERMITTENT
                         OPERATION OF THIS  REGENERA8LE SYSTEM INCLUDED: FROZEN DAMPERS CN REHEAT
                         BURNEPS, CRACKS IN THE TEFLON LINER  ON THE ACID PUMP'S DISCHARGE HEADER
                         CRACKS  IN THE REHEAT DUCTIN5, FALL OF REFRACTORY BRICKS FROM THE REHEATER
                         BURNER  DOME, AND NEED FOR REINFCPCEMEHT OF THE STRUCTURE SUPPORTING THE
                         HIGH TEMPERATURE  FLUEGAS  DUCT TO THE CATALYTIC CONVERTER.
                                              1046

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - OECErBER 1931

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUM3ER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - KS/J
SOZ EMISSION LIMITATION - HG/J
KOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - HU
GPOSS UNIT GENERATING CAPACITY - MU
MET UNIT GENERATING CAPACITY U/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGO - MU
EQUIVALENT SCRUBBED CAPACITY - M!4
             KEY WEST UTILITY BOARD
             STOCK ISLAND
             1
             KEY WEST
             FLORIDA
               473.
             ******
                42
                42
                37
             «*•**
                37
(»»*•«» LB/MMSTU)
(  1.100 LB/r-.3TU)
(««««»* LB/fuM.3TU)
    UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SEPVICE LOAD
     DESIGN BOILER FLUE GAS FLOW
     BOILER FLUE GAS TEMPERATURE
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M
cu.n/s
c
             ERIE CITY
             OIL FIRED
             BASE
             *««**»*
                34.
             GUNITE
             «**»*«»
(»•»»««* ACFM)
(«««« F)
(  110 FT)

(«««»« FT)
 »« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANSE ASH CONTENT - 7.
     AVERAGE MOISTU°E CONTENT - 7.
     RANSE MOISTUPE CONTENT - 7.
     AVERAGE SULFUR CONTENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RANGE CHLORIDE CONTENT - 7.

«»« PARTICLE CONTROL

 •« MECHANICAL COLLECTOR
     NUM5ER
     PRESSURE DROP - KPA

 •« FABRIC FILTER
     NUMBER
     TYPE

 «« ESP
     NUMBER
     TYPE

 «« PARTICLE SCRUBBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

••« FGD SYSTEM

 »• GENERAL DATA
     SALEABLE PRODUCT/THROUAMAY PRODUCT
     SC2 REMOVAL MOOE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     HEM/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
             OIL
             NO. 6
             *«»<•*«

                  .04
             «•**«*
             «»»*««««
(«»»»•• BTU/LB)
 «»**»*
                 2.01
             2.0-3.0
             «•«»»*•»
             «*»*»«
                             (   3.  IN-HZO)
              0
             NONE
              0
             NONE
             NONE
             N/A
             N/A
             N/A
             THPOKAMAY  PRODUCT
             WET ECRUSBIN3
             LIMESTONE
             ZURN AIR SYSTEM
             DEMONSTRATION
             NEW
            7.   90.00
                                              1047

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

KEY WEST UTILITY BOARD: STOCK ISLAND 1 (CONT.)

     UNIT DESIGN  32 REMOVAL EFFICIENCY - X        85.00

HARMING ««UNNORMAL:ZEO NirsER(S) BEING EDITED FOR OUTPUT**
     ENERGY CONSUMPTION - X
     CURRENT STATUS
     TERMINATION
     INITIAL START-UP

 »» DESIGN AND OPERATING PARAMETERS

 »* OUENCHER/FHESATUPATO'?
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 •• ABSOPBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRAOE NAME/COMMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GtS CONTACTING DEVICE TYPE
     LIQUID RECIRCULATICN RATE - LITER/S
     GAS-SIDE PRESSURE DROP - KPA
     INLET GAS FLOW - CU. M/S
     INLET GAS TEMPERATURE - C

 »* MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TPAOE NAME/CCMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «« REHEATER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONSTRUCTION MATERIAL GENEPIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »* FANS
     NUMBER
     APPLICATION

 »* DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 *» DUCTWORK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 »» REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE
*»»**«*
 a
 1/75
10/73
NR
NR
VENTURI TOMER
NR
NR
ZURN AIR SYSTEMS
STAINLESS STEEL
AUSTENITIC
TYPE 304L
NONE
N/A
N/A
SCRUBBING TUBE
   25.         (
    1.5        (
   58.04       C
   62.3        C
 400 GPM)
6.0 IN-H20)
123000 ACFM)
 145 F>
PRIMARY COLLECTOR
IMPII.'SEMENT
CURVED DEFLECTOR PLATE
GULL WING
ORGANIC
FIBER-REINFORCED POLYESTER
 0
NONE
N/A
N/A
NOME
N/A
INDUCED DRAFT
NR
NR
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
NR
NR
                                               1046

-------
                                              EPA UTIL"  Y  FGD  SURVEY:  OCTOBER  -  DECEMBER  1981

KEY WEST UTILITY BOARD:  STOCK ISLAND 1 (CONT.)


 «« SOLIDS CONCEKTRATING/DEUATERING
     DEVICE                                     NA

»»» SLUDGE

 »* TREATMENT
     METHOD                                     BLEED
     DEVICE                                     N/A
     PROPRIETARY PROCESS                        N/A

 »« DISPOSAL
     NATURE                                     FINAL
     TYPE                                       POND
     SITE TREATMENT                             NONE

 ** PROCESS CONTROL AND  INSTRUMENTATION
     CHEMICAL PARAMETERS                        TEMPERATURE. PARTICLE  LOADING. PH

 •« MATER BALANCE
     MATER LOOP TYPE                            OPEN
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FGO   CAP.
                                                                502  PART.  HOURS HCURS  HOURS FiCTCR


 6/73  SYSTEM                   3.6                                          744

       »» PROBLEMS/SOLUTIONS/COKMENTS

                         THE EMISSION CONTROL SYSTEM AT THE STOCK ISLAND PLANT CONSISTED OF A
                         MULTIPLE TUBE MECHANICAL COLLECTOR INSTALLED UPSTREAM OF TMO SULFUR DIOXIDE
                         MET SCRUEBERS. THIS DEMONSTRATION FACILITY EMPLOYED LIMESTONE IN A SEAHATER
                         SOLUTION FOR THE REMOVAL OF SOZ.  THE LIMESTONE ABSORBENT MAS OBTAINED
                         FROM CORAL DREDGED FROM THE OCEAN.  THE CORAL CONSISTED PRIMARILY OF
                         CAC03 MITH LITTLE OR NO MGC03.  THE CORAL MAS GROUND TO A FINE PCKOER IN A
                         HAMHERMILL CRUSHER TO 90X MINUS 325 MESH AND SLURRIEO IN SEAH4TEP.

                         THE SCRUBBING SYSTEM MAS SCHEDULED TO START UP IN JULY 1972, BUT DID NOT
                         OPERATE UNTIL AUGUST 1973.  DURING THE INTERIM, THE PRIMARY CPUSHIH3
                         SYSTEM BECAME FROZEN BECAUSE OF SALT AIR CORROSION TAKING PLACE FROM
                         DISUSE.

 9/73  SYSTEM                    .0                                          720

10/73  SYSTEM                   4.6                                          744

11/73  SYSTEM                   5.6                                          720

12/73  SYSTEM                   9.7                                          744

       •« PROBLEMS/SOLUTIONS/COMMENTS

                         FROM STARTUP IN AUGUST 1973 UNTIL DECEMBER 10. 1973 THE LONGEST SCFU3BER
                         RUN MAS FIVE DAYS; ASIDE FROM THAT, THE SCRUBBER MAS UP AND OCXN C.'IE
                         DAY AT A TIME FOR SHAKEDOWN TESTING.

                         ON DECEMBER 12 A HIGH PRESSURE DROP (15 IN. H20) CAUSED THE SCRUBBER TO
                         SHUTDOWN.

                         A CHANGE IN THE BOILER LOAD, PROBLEMS UITH THE GRID. AND A HIGH PRESSURE
                         DROP CAUSED THE SYSTEM TO SHUTDOWN ON DECEMBER 17.  THE SYSTEM REMAINED
                         DOWN THROUGH THE END OF THE MONTH SO THE SYSTEM COULD BE CLEANED.

 1/74  SYSTEM                  33.5                                          744
                                              1049

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

KEY WEST UTILITY BOARD: STOCK ISLAND 1 (CONT.>
	PERFORMANCE DATA	
PERIOD KCOULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER   BOILER  FGO   CAP.
                                                                S02  PART.  HO'JPS HOURS  HOURS FACTOR


       »» PROBLEMS/SO LUTIONS/COMMEMTS

                         ON JANUARY 2 THE 1A SCRUBBER EXPERIENCED PLUGGING  CAUSING THE SYSTEM TO
                         SHUTOOMN.

                         A HIGH PRESSURE DROP CAUSED SOME OUTAGE TIME IN JANUARY.

                         THE ENTIRE PLANT SHUTDOWN FOR SEVEN DAYS DURING JANUARY DUE TO A MAIN
                         BEARING FAILURE.

                         THE HIGH PRESSURE ALARM AND THE SENSING DEVICE  TRIPPED  DUE TO SLUC3E
                         BUILDUP.  THIS KEPT THE SYSTEM OUT CF SERVICE FOR  APPROXIMATELY FOUR DAYS.

                         ON JANUARY 22 THE SYSTEM MAS TAKEN OUT OF SERVICE  FOR ABOUT THREE HOIPS
                         DUE TO A RUPTURED LINE ON ONE OF THE PUMPS AND  A DECREASE IN THE PRESSURE
                         CROP.  CORRODED LOOSE NUTS AND BOLTS HERE FOUND IN THE  LINE.

                         ON JANUARY £8 THE SYSTEM MAS SHUTDOWN FOR MODIFICATIONS WHICH INCLUDED;
                         REPLACEMENT OF THE CYCLONE BY A BAGHOUSE AND REPLACEMENT OF THE VI33ATCPY
                         FEEDER BY A SCREW FEEDER.

 2/74  SYSTEM                    .0                                          672

 3/74  SYSTEM                    .0                                          74*

 4/74  SYSTEM                    .0                                          720

 5/74  SYSTEM                    .0                                          744

 6/74  SYSTEM                    .0                                          720

 7/74  SYSTEM                    .0                                          744

 8/74  SYSTEM                   4.4                                          744

 9/74  SYSTEM                    .0                                          7CO

10/74  SYSTEM                  37.5                                          744

11/74  SYSTEM                  43.1                                          720

12/74  SYSTEM                  16.1                                          744

 1/75  SYSTEM                    .0                                          744

       »• PROBLEMS/SOLUTIONS/COMMENTS

                         AFTER STARTUP IN AUGUST 1973, ENSUING OPERATION PROCEEDED ON AN INTERMIT-
                         TENT BASIS.  THE MAJOP PROBLEM AREAS ENCOUNTERED INCLUDED:
                             •SEVERE CORROSION OF THE GAS QUENCH DUCT AND DAMPER SEALING FANS ON
                              THE INLET AND OUTLET OF THE SCRUBBERS
                             ••PLUGGING AT THE BOTTOM OF THE SCRUBBER TUBES
                             •LIQUID LEVEL CONTROL FAILURES IN THE SCRUSBER MODULES
                             • POOR LIMESTONE UTILIZATION I APPROXIMATELY  20X)
                             •INDUCED DRAFT FAN REPAIRS
                             •REPLACEMENT OF INTERNAL STAINLESS STEEL PARTS WITH HONEL COMPONENTS
                             •BOILER FOUNDATION AND BOILER TUBE PROBLEMS
                             •LIMESTONE SUPPLY SHORTAGES

                         AS OF MARCH 1977 IT HAD NOT BEEN DECIDED WHETHER THERE  WOULD BE FUTURE
                         FGO OPERATIONS AT THE STOCK ISLAND PLANT.  DURING  OPERATION THE SCRUBBING
                         SYSTEM LOGGED 1579 HOURS FOR A TOTAL OPERABILITY OF 8X.
                                              1050

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1=81

                                           SECTION 16
               DESIGN AND  PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PUNT NAME
UNIT NUMBER
CITY
STATE
PEC-ULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENEPATINS CAPACITY - MM
GROSS UNIT GENEPATINS CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 «« UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN EOILER FLUE GAS FLOM - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK S»ELL
     STACK TOP DIAMETER - M
PHILADELPHIA ELECTRIC
EODYSTONE
1A
ECOYSTOME
PENNSYLVANIA
D
«•»«»»         (*»•***
»»•»»«         (««»»»» LB/KM3TU)
«»«»•*         (*»*»*« LB/MM3TU)
 1395
  120
  120
  120
COMBUSTION ENGINEERING
***»*»
BASE
  437.45
  157.2
   76.
CONCPETE
    5.6
                 927000 ACFM)
                 315 F)
                 249 FT)
                                                               ( 18.5 FT)
 »» FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/6
     RAN3S HEAT CONTENT - BTU/Lfi
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - 7.
     RANGE MOISTURE CONTENT - 7.
     AVERAGE SULFUR CO'ITENT - 7.
     RANGE SULFUR CONTENT - 7.
     AVEPAGE CHLORIDE CONTENT - 7.
     RAN3E CHLORIDE CONTENT - 7.

«»* PARTICLE CONTROL

 »* MECHANICAL COLLECTOR
     HUrSER
COAL
BITUMINOUS
31634.

    9.40
*»***»
    5.90
«»«*«*
    2.60
               ( 13600 BTU/LB)
                ««»**«
«**«*««*
 «« ESP
     NUHBER

 »» PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUT.3ER OF CONTACTING ZONES
     L/G RATIO - LITER/CU.M
     PRESSURE DROP - KPA
     INLET GAS FLOW RATE - CU.M/S
     INLET GAS TEMPERATURE - C

 •• PARTICLE SCRUBBER
     NUMBER
     INITIAL START-UP DATE
  2
  9/75
VENTURI  TOMER
VARIABLE-THROAT/VERTICALLY-AOJUSTABLE ROD DECKS
ROD SCRUBBER
ENVIRONEERING
14.0 X 25.0 X  53.0
STAINLESS  STEEL
AUSTENITIC
NONE
N/A
NONE
  1
      .6         (
      .0         (
  145.8         (
  157.2         (
  1
  9/75
                  4.8 GAL/1000ACF)
                   .1 IN-H20)
                  309000  ACFM)
                   315 F)
                                               1051

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981
PHILSCELPHIA ELECTRIC:  EODYSTONE 1A (CONT.)

     GENERIC TYF
     SPECIFIC TY?i
     TRADE NAME/COMMON NAME
     SUPPLIER
     DIMENSIONS - FT
     SniLL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CC! -ACTING DEVICE TYPE
     NUMBER JF CONTACTING ZONES
     L/G RATIO - LITER/CU.M
     PRESSURE DPOP - KPA
     INLET GAS FLOW RATE - CU.M/S
     INLET GAS TEMPERATURE - C

••* FGD SYSTEM

 »» GENERAL DATA
     SALEABLE PRODUCT/THROUAUAY PRODUCT
     SO: REMOVAL MODE
     PROCESS TYPE
     PROCESS ADDITIVES
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
     UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
     ENERGY CONSUMPTION - 7.
     CU3PEHT STATUS
     TERMINATION
     COMMERCIAL START-UP
     INITIAL START-UP

 ** DESIGN AND OPERATING PARAMETERS

 »* GUENCHER/PRESATUPATOR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 
-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
PHILADELPHIA ELECTRIC:  EDDYSTONE 1A ICONT.)

     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL £-=CIFIC TYPE
     WASH WATER SOL'PCE
     WASH FREQUENCY

 *« REHEATER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE HAtlE/COrmON  TYPE
     TEMPERATURE INCREASE - C
     INLET FLUE GAS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 •* FANS
     NUMBER
     SUPPLIER
     FUNCTION
     APPLICATION
     SERVICE
     FLUE GAS FLOW RATE - CU.M/S
     FLUE GAS TEMPERATURE - C

 ** DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 »« DUCTWORK
     LOCATION
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 »« DUCTUSSK
     LOCATION
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 •« REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 «« PUMPS
     SERVICE
     ABSORBER RECIRCULATION

 ** SOLIDS CONCENTHATING/DEWATERING
     DEVICE
     NUMBER
     DIMENSIONS - FT
     OUTLET STREAM CHARACTERISTICS

 »« SOLIDS CONCENTRATING/DEUATERING
     DEVICE
     NUMBER

*«* SLUDGE
ORGANIC
FIBER-REINFORCED POLYESTER
FRESH
INTERMITTENT
DIRECT COMBUSTION
IN-LINE BURNER
OIL
   57.2        (   103 F)
   51.7        (   125 F)
NR
NR
BUFFALO FORGE
BALANCED DRAFT
INDUCED DRAFT
DRY
  107.2
                 268000 ACFM)
                  225 F)
NR
NR
NR
NR
NR
NR
NR
SCRUBBER INLET
STAINLESS STEEL
AUSTENITIC
NONE
N/A
SCRUBBER OUTLET
STAINLESS STEEL
AUSTENITIC
NCNE
N/A
SLAKER
NR
Hit
                                                NUMBER

                                                   2
THICKENER
 1
40.0 DIA
25X SOLIDS
CENTRIFUGE
 1
                                              1053

-------
 EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981

PHILADELPHIA ELECTRIC:  EDDYSTOHE 1A (CONT.)


 «» TREATMENT
     METHC3                                    DEUATERED
     DEVICE                                    N/A
     PROPRIETARY PROCESS                        N/A

 *» DISPOSAL
     NATURE                                    N/A
     TYPE                                      NONE
     SITE TREATMENT                            N/A

 
-------
                                              EPA UTILITY  FGO  SURVEY:  OCTOBER  -  DECEMBER  1931

PHILADELPHIA ELECTRIC:  EDDYSTONE 1A (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PEP   BOILER   FGD    CAP.
                                                                S02   PART.  HOURS HOURS  HOURS  FACTOR

                          MSO REGENERATION FACILITY FIRST PROCESSED  MAGNESIUM SULFITE FROM  THE EDDY-
                          STONE SCRUBBER OH OCTOBER 26,  1975.  THE C-SIOE  PARTICULATE SCPU2SEP  OPEPA-
                          TED A TOTAL OF 2831 HOURS THROUGH  JANUARY  31, 1976. FCR AN OPEPABILITY  OF
                          70X.  THE B-SIDE TPAIN HAS OPERATED  A TOTAL OF  1933 HOURS THPC'JC-H
                          JANUARY 31, 1976 FCR AN OPERABILITY  OF 55X.  THE A-SIDE TRAIN OPERA-
                          TED A TOTAL OF 626 HCUPS THROUGH JANUARY 31,  1976,  FOR AN OPERABILITY OF
                          24X. THE C-SIDE S02 ABSOPBER HAS IN  SERVICE A TOTAL OF 556 HOURS
                          THROUGH DECEMBER 31. 1975. KITH AN OPERABILITY  OF 33X  SINCE START
                          UP. PROBLEMS ENCOUNTERED IN THE OPERATION  OF  THE THPEE SCRUS5INS  TRAINS
                          INCLUDED UNDER-DESIGNED RECIRCULATIOH PUMPS,  MALFUNCTION OF THE FLUE GAS
                          BY-PASS DAMPER DRIVE UNITS AMD FAILURE OF  THE DOUBLE-BRICK REFRACTORY
                          LINING IN THE REHEAT COMBUSTION CHAMBER.

 8/75  SYSTEM                                                                744

 9/75  SYSTEM                                                                720

10/75  SYSTEM                                                                744

11/75  SYSTEM                                                                720

12/75  SYSTEM                                                                744

       «• PROBLEMS/SOLUTIONS/COMMENTS

                          OPERATION OF THE S02 SCRUBBING SYSTEM AT EDDYSTONE MAS TEMPORARILY HALTED
                          BECAUSE THE ACID PLANT REGENERATION  FACILITY AT THE OLIN CHEMICAL SULFURIC
                          ACID PLANT IN PAULSBORO, NEW JERSEY  PERMANENTLY CEASED OPERATIONS. THE
                          UTILITY WAS INVESTIGATING ALTERNATIVE REGENERATION SITES. A MINIMUM
                          PEPIOD OF SIX MONTHS WAS REQUIRED  FCR RELOCATION ONCE  A CHOICE  WAS MADE.
                          THE UTILITY ANNOUNCED PLANS FOR RELOCATION OF THE REGENERATION  FACILITY AT
                          THE ESSEX CHEMICAL PLANT IN NEWARK,  NEW JERSEY.

                          THE PARTICULATE SCRUBBERS MERE CONTINUING  TO OPERATE AND THESE  UNITS
                          UEREARE CONTINUING TO EXPERIENCE PROBLEMS  WITH  THE FANS, REHEAT BURNERS,
                          DAMPERS AND EXPANSION JOINTS.

 1/76  SYSTEM                                                                744

 2/76  SYSTEM                                                                696

 3/76  SYSTEM                                                                744

 4/76  SYSTEM                                                                720

 5/76  SYSTEM                                                                744

 6/76  SYSTEM                                                                720

       «• PROBLEMS/SOLUTIONS/COMMENTS

                          RESUMPTION OF SO2 SCRUBBING OPERATIONS WAS SCHEDULED FOR DECEMBER
                          1976. THE RELOCATION OF THE REGENERATION FACILITY WAS  IN PROGRESS. THE
                          PARTICULATE SCRUBBERS WERE OPERATIONAL. THE C-SIOE BOOSTER  FAN  DEVELOPED
                          A MATERIALS FAILURE BETWEEN THE HUB  AND SHAFT (IDENTICAL TO THE
                          B-SIDE UNIT MENTIONED EARLIER).

 7/76  SYSTEM                                                                744

 8/76  SYSTEM                                                                744

 9/76  SYSTEM                                                                720
                                              1055

-------
 EPA UTILITY FGD SURVEY:  OCTOBER  -  DECEMBER  1981

PHILADELPHIA ELECTRIC:  EDOYSTONE  1A (CONT. )
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION  7. REMOVAL   PER  BOILER  FGO   CAP.
                                                               SOZ  PART. HOURS HOURS  HOURS FACTOR


       «» PROBLEMS/SOLUTIONS/COMMENTS

                         ALL  THREE BOOSTER  FANS DOWNSTREAM OF THE REHEATEPS DEVELOPED MATERIALS
                         FAILURE BETWEEN THE HU3 AND SHAFT (AS IDENTIFIED EARLIER FOR THE B-SICE
                         UNIT I.  THESE UNITS MERE RETURNED TO THE MANUFACTURER FOR MODIFICATIONS
                         AND  REPAIRS.  ONE  OF  THE PARTICULATE SCRUBBERS UAS IN THE FLUE GAS
                         STREAM.  TO DATE,  THE THREE MET PARTICULATE SCRUBBERS HAD ACHIEVED
                         LITTLE SIMULTANEOUS SERVICE TIME.

10/76  SYSTEM                                                               744

11/76  SYSTEM                                                               720

1Z/76  SYSTEM                                                               744

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         MGO  SCRUBBING OPERATIONS HERE SCHEDULED TO RESTART IN MAY 1977.  RE-
                         GENERATION FACILITY RELOCATION MAS BEING COMPLETED, AND MODIFICATIONS TO
                         THE  ID BOOSTER FANS BEING  EFFECTED CONSISTED OF CONVERSION FROM A
                         SLIP FIT TO A SHRINK  FIT.  THESE MODIFICATIONS MERE EXPECTED TO ELIMINATE
                         RECURRING VIBRATION PROBLEMS.

 1/77  SYSTEM                                                               744

 2/77  SYSTEM                                                               672

 3/77  SYSTEM                                                               744

       fc» PRCBLEMS/SOLUTIONS/COMMENTS

                         THE  MGO SCRUBBING  SYSTEM AT EODYSTONE 1A HAS STILL SCHEDULED FOR
                         RESTART IN MAY 1977.  THE START-UP OF THE HEM MAGNESIUM SULFITE REGENER-
                         ATION FACILITY AT  THE ESSEX CHEMICAL PLANT AT NEWARK. N.J. MAS ALSO SCHED-
                         ULED FOR MAY 1977. THE THREE PARALLEL VENTL'RI SCRUS3ERS CONTROLLING PAR-
                         TICULATE EMISSIONS ON EODYSTONE 1 UENT BACK INTO SERVICE IN MARCH 1977.

 4/77  SYSTEM                                                               720

 5/77  SYSTEM                                                               744          206

       •« PROBLEMS/SOLUTIONS/COMMENTS

                         RESUMPTION OF MAGNESIUM OXIDE SCRUBBINC OPERATIONS OCCURRED DUPING THE
                         REPORT PERIOD. THE UTILITY REPORTED THAT SOZ SCRUBBING OPERATIONS MEPE
                         NOT  CONTINUOUS THROUGHOUT  THE PERIOD. THE ABSORBER MAS IN SERVICE APPROXI-
                         MATELY 206 HOURS DURING MAY. REGENERATION OPERATIONS AT THE ESSEX FACILITY
                         MERE NOT CONDUCTED DURING  THE PERIOD. PECO PLANNED TO INITIATE S02 RE-
                         COVERY AND MAGOX REGENERATION OPERATIONS DURING THE MONTH OF JUNE. THE S32
                         MODULE CONTAINED TMO  ABSORBER SECTIONS IN SERIES (EACH SECTION CONSISTING
                         OF AN ADJUSTABLE ROD  DECK  MITH UHDERSPHAYS). ONLY ONE OF THE ABSORBER
                         SECTIONS MAS BEING USED FOR S02 REMOVAL. SOZ REMOVAL EFFICIENCY HAS NOT
                         MEASURED. MAGNESIUM OXIDE  LOSSES IN THE SYSTEM (ABSORPTION AND
                         REGENERATION) HERE ESTIMATED AT 10X.

 6/77  SYSTEM                                                               720

 7/77  SYSTEM                                                               744
                                             1036

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - DECEASES 1931

PHILADELPHIA ELECTRIC: EOOYSTCNE 1A (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FCC   CAP.
                                                                502  PART.  HOURS HO'J=S  HO'JPS FACTOR


       •« PROBLEtlS/SOLUTIONS/COmENTS

                          FAILURE OF MINOR ANCILLIAHY EQUIPMENT CAUSED SOME SCRUSBER SHUTDOWNS.
                          LATER. THE BOILER ITSELF WAS SHUT DOWN. OVER THIS FEHIC3  THE EOTiRY VALVE
                          C!< THE MAG SULFITE DRIER OISCHAPGE PLUGGED REPEATEDLY.  ALSO THE BELTS ON
                          THE AGITATOR OF THE MAG-OX PRESLAKER FAILED.

 8/77  SYSTEM                                                                744

 9/77  SYSTEM                                                                720

       ** PRCBLEHS/SOLUTlONS/CCmENTS

                          THE ROTARY VALVE PROBLEM APPEARED TO BE SOLVED. CUMULATIVE OPERABILITY
                          SIHCE MAY MAS ESTIMATED TO BE ROUGHLY 33X. PECO REPORTED  131 HCURS OF
                          CONTINUOUS OPERATION FOR THE SCRU5BER AND THICKENER CENTRIFUGE DRYING
                          LOOP. DURING THE AUGUST-SEPTEM5ER REPORT PERIOD CONTINUAL FRC3LEMS WITH
                          THE GLAND PACKING ON THE FGD SYSTEM CIRCULATION PUMPS (STUFFING BOX) WERE
                          ENCOUNTERED.  PECO CHANGED THE GLAND CONFIGURATION. THERE ALSO WAS A
                          PROBLEM WITH HIGH SOLIDS FORMATION IN THE THICKENER.

10/77  SYSTEM                  41.0                                          744

11/77  SYSTEM                  41.0                                          720

       *« PROBLEHS/SOLUTIONS/CCMHENTS

                          CUMULATIVE OPERABILITY FOR MAY THROUGH NOVEMBER 1977 WAS  39X.  DURING  THE
                          OCTOBER-NOVEMBER PERIOD THE FGO SYSTEM ACHIEVED A 213 HOUR CONTINUOUS
                          RUN.  THIS WAS THE LCNGEST CONTINUOUS RUN SINCE KAY 1977.

                          GLAND PACKING PROBLEMS PERSISTED AND MECHANICAL SEALS WERE BEIMS
                          CONSIDERED AS POSSIBLE ALTERNATIVES.  EVEN WITH HEAT TRACING THE SEAL
                          HATER FROZE-UP CAUSING HOTAMETERS TO BURST.   HIGH SOLIDS  ACCUMULATION  IN
                          THE THICKENER MAS STILL A PROBLEM AREA.

12/77  SYSTEM                  41.0                                          744

 1/7B  SYSTEM                                                                744             0

       «« PROBLEMS/SOLUTIONS/COMMENTS

                          THE UNIT MAS SHUT DOWN DECEMBER 22 FOR A TURBINE  OVERHAUL.  DURING THE
                          OUTAGE MAINTENANCE AND MINOR MODIFICATIONS WERE BEING MADE ON THE SCRUB-
                          BERS.  THE UNIT WAS EXPECTED TO BE BACK ON LINE THE FIRST MEEK IN MAPCH.
                          THE CUMULATIVE OPERABILITY FACTOR FOR THE FOURTH  QUARTER  OF 1973 HAS 41X.
                          DURING THIS PERIOD SOME OF THE HEAT TRACING  FAILED  AND  OTHER PHCSLEKS
                          OCCURRED WHEN LINES FROZE AT THE ACID PLANT  CAUSING THE FACILITY TO BE
                          OPERATED INTERMITTENTLY.   THE GLAND PACKING  PROBLEMS  HAD  NOT BEEN
                          SOLVED AND MECHANICAL SEALS MERE STILL BEINS CONSIDERED.

                          THE UTILITY MAS STUDYING THE MAG-SULFIDE TO  MAG-OXIDE RECOVERY EFFICIENCY.

 2/78  SYSTEM                                            .0                  672             0

 3/78  SYSTEM                                            .0                  744             0

       »» PROBLEMS/SOLUTIONS/COMMENTS

                          THE TURBINE OVERHAUL CONTINUED DURING THE FEBRUARY-MARCH  PERIOD.   DURING
                          THE SHUTDOWN PERIOD IT WAS FOUND THAT SOME HIGH PRESSURE  STEAM TUBES
                          MERE CRACKED.  SO UNIT MAINTENANCE TOOK LONGER THAN  EXPECTED.   SOME
                          MINOR FGO SYSTEM MODIFICATIONS WERE INCORPORATED  IN THE COURSE OF
                                              1057

-------
 EPA UTILITY F6D SUS.EY:  OCTOBER -  DECEMBER  1981

PHILADELPHIA ELECTRIC:  EODYSTOME 1A (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERASILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FG3   CAP.
                                                                S02   PART. HOURS HOU^S  HOURS  FACTOR

                          THE SHUTDOWN PERIOD.   START  UP  HAS EXPECTED IN MID-APRIL 1976.

 4/73  SYSTEM                                            .0                  720            0

 5/78  SYSTEM                                            .0                  744            C

       «* PROBLEMS/SOLUTIONS/COMMENTS

                          THE UNIT CAME BACK  ON LINE JUNE 1  AFTER AN  EXTENSIVE SYSTEM MODIFICATION
                          OUTAGE WHICH BEGAN  DECEMBER  22. THE UNIT UAS EXPECTE3 BACK OH LIME IN MID-
                          APRIL. BUT THERE  UAS  A PPOBLEM  KITH A  SUPER PRESSURE STEAM TUHSIKE.

 6/78  SYSTEM                  49.0                                         720

 7/78  SYSTEM                  51.0                                         744

       *» PROBLEMS/SOLUTICNS/COKriENTS

                          DURING JUNE THE FGD SYSTEM ACHIEVED A  49Z OPERABILITY. OPERABILITY FOR
                          JULY UAS SIX. PROBLEMS OCCURRED IN LATE JUNE UITH THE H3S03 SLU=RY
                          CIRCULATION PUMP  WHEN THE UTILITY  DISCOVERED THE RUBBER LINER UAS TORN
                          AUAY. THERE HERE  SOME PROBLEMS  UITH THE MGO SECTION UHERE THE MSO
                          MIXES UITH THE SYSTEM LIQUOR. FIRE BRICK UAS REMOVED FROM THE FLUID  BED
                          REACTOR CHAMBER TO  REPLACE THE  ACID BARRIER PLATES UHICH UERE FAILING.
                          THE FIRE BRICK UAS  THEN REPLACED.  THE  SLOW  PIECE BY PIECE PROCEDURE  UAS
                          TIME CONSUMING AI
-------
                                              EPA UTILITY  F6D SURVEY: OCTOBER  - DECEM3EH 19S1

PHILADELPHIA ELECTRIC:  EDOYSTONE 1A (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION  X REMOVAL    PER  BOILER  FG3   CAP.
                                                               S02   PART. HOIRS HOURS  KCUSS  FACTOR


 5/79  SYSTEM                                                                7*4

 6/79  SYSTEM                                                                710

 7/79  SYSTEM                                                                744

 8/79  SYSTEM                                                                744

 9/79  SYSTEM                                                                720

10/79  SYSTEM                                                                744

11/79  SYSTEM                                                                720

12/79  SYSTEM                                                                744

       «« PROBLEMS/SOLUTIONS/COMMENTS

                         INFORMATION FOR THIS UNIT HAD  NOT  BEEN AVAILABLE  SINCE OCTOBER 1978.

 1/80  SYSTEM                                                                744      0

 2/80  SYSTEM                                                                696      0

 3/80  SYSTEM                                                                744      0

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER AND TURBINE MERE DOWN DURING  THE FIRST QUARTER 1980 FOR TUPBINE
                         MAINTENANCE.

                         OPERATION OF THIS PROTOTYPE MAGNESIUM  OXIDE SYSTEM. WHICH TREATED ONE
                         THIRD OF THE FLUE GAS FROM  THE EDDYSTONE  1  BOILER.  WAS TERMINATED.
                         THE S02 REMOVAL EQUIPMENT WILL BE  REPLACED  WITH A SIMILAR MAG-OX  SYSTEM
                         DESIGNED TO TREAT 100X OF THE  BOILER FLUE GAS.   THE EXPECTED START
                         DATE OF THIS SYSTEM IS DECEMBER 1982.  CURRENT  REGULATIONS 00 NOT
                         REQUIRE CONTROL OF S02 EMISSIONS UNTIL THE  NEW  SCHUSSER  IS AVAILABLE
                         FOR OPERATION.
                                              1059

-------
 EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTIC'JLATE EMISSION LIMITATION - N6/J
£02 EMISSION LIMITATION - NG/J
NCX EMISSION LIMITATION - NS/J
NET PLANT GENERATING CAPACITY - HH
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - KU
NET UNIT GENERATING CAPACITY UO/FGO - MW
EQUIVALENT SCRUE3EO CAPACITY - MM

 «» UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - H
     STACK SHELL
     STACK TOP DIAMETER - M

 »« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVEPAGE ASH CONTENT - X
     RANGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTUPE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RAN'GE SULFUR CONTENT - X
     AVERAGE CHLG9IDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

»»» PARTICLE CONTROL

 «» MECHANICAL COLLECTOR
     NUMBER
     TYPE

 »* FABRIC FILTER
     NUM3ER
     TYPE

 »• ESP
     NUMBER
     SUPPLIER
     PARTICLE REMOVAL EFFICENCY - X

 «» PARTICLE SCRU2SER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

»»» FGD SYSTEM

 «* GENERAL DATA
     SALEABLE PRODUCT/THROWAWAY PRODUCT
     SOS REMOVAL MODE
     PROCESS TYPE
     PROCESS ADDITIVES
     SYSTEM SUPPLIER
     A-E FIRM
               (»««««* LB/~M3TU)
               (  1.600 LB/MM3TU)
               («*«»** IB/KKBTU)
POTOMAC ELECTRIC POWER
DICKERSON
3A
DICKERSON
MARYLAND
E
««»*•*
  668.
»»»»»*
  548
  190
  178
  182
   95
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
  278.42       (  590000 ACFM)
  126.1        I  259 F)
  122.         (  400 FT)
CONCRETE
*«*««•*«        («**•* FT)
               I 11700 BTU/LB)
                •«*•««
COAL
BITUMINOUS
27214.

   14.00
••»*«*
**»««»*»
6.0-7.0
    2.00
««*»**
«*«*«*«»
*«*«•*
 0
NONE
 0
HONE
RESEARCH-COTTRELL
   97.5
VEMTURI TCWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
NONE
SALEABLE PRODUCT
WET SCRUSBIt.'S
MAGNESIUM OXIDE
NCME
GE ENVIRONMENTAL SERVICES
GE ENVIRONMENTAL SERVICES
                                              1060

-------
                                              EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981
POTOMAC ELECTRIC POWER:  OICKERSON 3A (COKT.)

     DEVELOPMENT LEVEL
     NEH/RETPCFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
     UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
     ENERGY CONSUMPTION  - X
     CURRENT STATUS
     TERMINATION
     CCriERCIAL STA3T-UP
     INITIAL START-UP
     CONTRACT AWARDED

 »« DESIGN AND OPERATING PARAMETERS

 «» GUENCHER/PRESATURATOH
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 •• ABSORBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     L/G RATIO - L/CU.n
     GAS-SIDE PRESSURE DROP - KPA
     SOI REMOVAL EFFICIENCY - X

 «« MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     •NUMBER PER SYSTEM
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     NUMBER OF STAGES
     NUMBER OF PASSES PER STAGE
     DISTANCE BETWEEN VANES - CM
     VANE ANGLES - DEGREES
     PRESSUPE DROP - KPA
     SUPE9FICAL GAS VELOCITY - M/S
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «•> REHEATER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »" FANS
     NUMBER
     FUNCTION
     SERVICE
     CONSTRUCTION MATERIAL GENERIC TYPE

 ** DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE
 DEMONSTRATION
 RETROFIT
X   99.30
    90.00
      .0
  a
  8/75
  7/74
  9/73
  7/71
 NR
 NR
 VENTURI TOWER
 VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
 N/A
 GE ENVIRONMENTAL SERVICES
 CARBON STEEL
 AISI 1110
 N/A
 ORGANIC
 GLASS FLAKE-FILLED POLYESTER
NONE
    5.3
    2.2
   90.0
                ( 40.0 GAL/1000 ACFI
                ( 9.0 IN-H20)
 PRIMARY COLLECTOR
 IMPINGEMENT
 BAFFLE
 CLOSED VANE
     3
     2
     5.1
   45
      .2
     3.0
 ORGANIC
               C 2.00 IN)

               ( 1.0 IN-H20)
               ( 10.0 FT/S)
 FIBER-REINFORCED POLYESTER
  0
 NONE
 N/A
 N/A
 NONE
 N/A
  1
 UNIT
 MET
 HIGH ALLOY
 NR
 NR
 NR
 NR
 HP
 NR
 NR
                                              1061

-------
 EPA UTILITY F6D SURVEY' "CTXER - DECEMBER 1981

POTOMAC ELECTRIC POWER: ..ICKERSON 3A (CONT.)
 »« DUCTWORK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 «* PEAGENT PREPARATION EQUIPMENT
     FUIJCTICN
     DEVICE
     DEVICE TYPE

 «* TANKS
     SERVICE
 »* SOLIDS CONCENTRATING/OEUATERINS
     DEVICE
     NUMBER

*»» SLUDGE

 «t TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 » DISPOSAL
     NATURE
     TYPE
     SITE TREATMENT

 »* PROCESS CONTROL AND INSTRUMENTATION
     CHEMICAL PARAMETERS
     CONTROL LEVELS
     MONITOR LOCATION
     PROCESS CCMTROL MANNER
     PROCESS CHEMISTRY MODE
MR
NR
NR
in
N9
NR
NR
                                                NUMBER

                                                   1
THICKENER
 2
THICKENED
N/A
N/A
N/A
NOME
N/A
PH, PRESSURE DROP
PH 7
IN SECOND STAGE SYSTEM
AUTOMATIC
FEEDBACK
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                                7. REMOVAL   PER  BOILER   FSO   CAP.
                                                                S02  PART. HOIRS HOURS  HOU3S  FACTOR
 0/75  SYSTEM

       «« PROBLEMS/SOLUTIONS/COMMENTS
                         REFER TO THE PERFORMANCE UPDATE INFORMATION FOR DICKERSON 3 LOCATED IN
                         SECTION 14.
                                              106Z

-------
                                              EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGD - MM
NET UNIT GENERATING CAPACITY HO/FGO - KM
EQUIVALENT SCRUBBED CAPACITY - MM

 »* UNIT DATA - BOILER AND STACK
     EOILER SUPPLIER
     BOILER TYPE
     GOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TO? DIAMETER - H

 •* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RAII3E SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

««* PARTICLE CONTROL

 »« MECHANICAL COLLECTOR
     NUMBER
     INLET FLUE GAS CAPACITY - CU.M/S

 •» FABRIC FILTER
     NUMBER
     TYPE

 »• ESP
     NUMBER
     TYPE
     INLET FLUE GAS CAPACITY - CU.M/S

 «« PARTICLE SCRUBBER
     MUVSER
     INITIAL START-UP DATE
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     GAS CONTACTING DEVICE TYPE
     NUMBER OF CONTACTING ZONES
     L/G RATIO - LITER/CU.n
     PRESSURE DROP - KPA
               (  .100 LB/MHSTU)
               («***»» LB/MrSTU)
               (»*«»»»* LB/MK3TU)
PUBLIC SERVICE OF COLORADO
VALMONT
5A
VALMONT
COLORADO
B
   43.
»*»*«*
**«»«»
  274
  166
  157
  163
  166
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
  436.98       ( 926000 ACFM)
  126.7        ( 260 F)
«*««*»         (***» FT)
»•*«**
««»«»»«        (««»«« FT)
COAL
SUEBITUMINOUS
25121.

    6.00
5.4-7.0
   15.00
12.7-18.3
     .70
0.6-0.7
*«**«««»
«««««*
  218.5
 0
NONE
COLD SIDE
  218.5
               ( 10800 BTU/LB)
                ******
               ( 463000 ACFM)
               (  463000 ACFM)
 1
11/71
PACKED TOMER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION. UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL
 3
    7.8        (58.3 GAL/1000ACF)
                                                    3.7
                                                               (15.0 IN-H20)
                                              1063

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981

PUBLIC SERVICE OF COLORADO: VALMONT 5A CCONT.)

     SUPERFICIAL GAS VELOCITY - M/S
     INLET GAS FLOW RATE - CU.M/S
     INLET GAS TEMPERATURE - C
     S02 REMOVAL EFFICENCY - X
     PARTICLE REMOVAL EFFICIENCY - X

*** FGD SYSTEM
     3.4
   109.2
   132.6
    45.0
    96.0
(    11.0 FT/S)
(  231500 ACFM)
(   271 F)
 «» GENERAL DATA
     SALEABLE PRODUCT/THROWAHAY PRODUCT
     S02 REMOVAL MODE
     PROCESS TYPE
     PROCESS ADDITIVES
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     HEU/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
     UNIT DESIGN S02 REMOVAL EFFICIENCY - X
 THROUAUAY PRODUCT
 MET SCRU3BIN5
 LIMESTONE/ALKALINE FLYASH
 NONE
 L'OP/PUSLIC SERVICE OF COLORADO
 STEARNS-ROGEH
 EXPERIMENTAL
 RETROFIT
Y.   95.00
    85.00
MARKING ««UNMORMALIZED NUMBERCSJ BEINS EDITED FOR OUTPUT**
     ENERGY CONSUMPTION - X
     CUPRENT STATUS
     TERMINATION
     INITIAL START-UP

 *« DESIGN AND OPERATING PARAMETERS

 *« QUEMCHER/FRESATUSATCH
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «« ADSOP3ER
     NUTSER
     UUM2ER OF SPARES
     GENERIC TYPE
     SPECIFIC TYPE
     TPAOE NAME/COMMON TYPE
     SUPPLIER
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     S02 REMOVAL EFFICIENCY - X

 »* MIST ELIMINATOR
     FHE-HIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COraON TYPE
     CONFIGURATION
     MUM5ER OF STAGES
     NUM3ER OF PASSES PER STAGE
     PRESSURE DPOP - KPA
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     WASH WATER SOURCE

 *• REHEATER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     TEMPERATURE INCREASE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 ** FANS
     FUNCTION
     APPLICATION
     SERVICE
                                                     .0
  8
  3/75
 10/74
 NR
 NR
  1
  0
 PACKED TOHEP
 MOBILE BED PACKING
 TURBULENT CONTACT AESOR3ER
 AIR CORRECTION DIVISION, UOP
 CARBON STEEL
 AISI 1110
 N/A
 ORGANIC
 SYNTHETIC RUBBER
 NEOFRENE LS-576
    77.5
 PRIMARY COLLECTOR
 IMPINGEMENT
 BAFFLE
 CLOSED VANE
 HORIZONTAL
     2
     7
      .1        (  .5 IN-H20)
 STAINLESS STEEL
 NR
 SUPERNATANT
  1
 IN-LINE
 STEAM
 NR
    36.1        (    65 F)
 NR
 HR
 BOOSTER
 FORCED DRAFT
 DRY
                                              1064

-------
                                              EPA UTILITY FGD  SURVEY:  OCTOBER  - DECEMBER 1931

PUBLIC SERVICE OF COLORADO:  VALMOST 5A ICONT.I

     CONSTRUCTION MATERIAL GENERIC TYPE         CARBON STEEL
 «* DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 «• DUCTWORK
     LOCATION
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 «» REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 •* TANKS
     SERVICE
     RECYCLE WATER

 «• SOLIDS CONCENTRATING/DEUATERING
     DEVICE

»*» SLUDGE

 «» TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 «« DISPOSAL
     NATURE
     TYPE
     SITE TREATMENT

 ** WATER BALANCE
     MATER LOO? TYPE
     EVAPORATION MATER LOSS - LITER/S
NR
NR
NR
HR
NR
HR
NR
OUTLET
CARBON STEEL
AISI 1110
NCNE
N/A
MET BALL MILL
NR
NR
NUMBER

   1


THICKENER
BLEED
N/A
N/A
FINAL
POND
NONE
CLOSED
    5.5
               (   88 GPM)
	—PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                7. REMOVAL   PER  BOILER  FGD   CAP.
                SOZ  PART. HOURS HOURS  HOURS FACTCR
10/7*  SYSTEM

       «» PROBLEMS/SOLUTIONS/COMMENTS
                         REFER TO PERFORMANCE UPDATE INFORMATION FOR VALMONT 5 LOCATED IN SECTICN
                         14 OF THIS REPORT.
                                              1065

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1961

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT HAKE
WIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SC2 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
MET PUNT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY M/FGD - MU
NET UNIT GENEPATIN3 CAPACITY UO/FGO - KU
EQUIVALENT SCRUBBED CAPACITY - MU

 »» UNIT DATA - BOILER AND STACK
     EOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOU - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - tt
     STACK SHELL
     STACK TGP DIAMETER - M

 ** FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - V.
     RANGE HOI STIPE CONTENT - 7.
     AVERAGE SULFUR CONTENT - X
     RAN3E SULFUR CONTENT - X
     AVERAGE CHLCRI3E CONTENT - X
     RANGE CHLOPIDE CONTENT - X

«»» PARTICLE CONTROL

 «» MECHANICAL COLLECTOR
     NUMBER
     TYPE

 »* FABRIC FILTER
     NUMBER
     TYPE

 «» ESP
     NUMBER
     SUPPLIER
     PARTICLE REMOVAL EFFICENCY - X

 «« PARTICLE SCRUBBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

**» FGO SYSTEM

 »« GENERAL DATA
     SALEABLE PRODUCT/THROUAUAY PRODUCT
     502 REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     NEU/RETROFIT
               t   .C64 LB/MMSTU)
               (   .150 LB/MMBTU)
               («*»»*« LB/MMSTU)
SOUTHERN CALIFORNIA EDISON
MOHAVE
1A
LAUGHLIN
NEVADA
B
   20.
   64.
******
 1580
  790
  790
  790
  170
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
********       I******* ACFM)
  132.2        (  270 F)
  152.         (  500 FT)
****<•»
«»»*«*«        (***»» FT)
               ( 11500 BTU/LB)
                11000-12000
COAL
******
26749.

   10.00
******
««****««
«»**»»
     .40
******
********
******
 0
NONE
 0
NONE
RESEARCH-COTTRELL
   97.2
NONE
N/A
N/A
N/A
THROUAUAY PRODUCT
MET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
PROTOTYPE
RETROFIT
                                              1066

-------
                                              EPA UTILITY FGD SURVEY: CCTC3ER - DECIKEEH 1«31
SOUTHERN CALIFORNIA EDISON:  M3HAVE 1A (CONT.)

     UMIT DESIGN PARTICLE REMOVAL EFFICIENCY - X   97.20
     ENEPGY CONSUMPTION - Y.                          .0
     CL'SPEJIT STATUS                              8
     7EK«:?.'ATICN                                 7/75
     CCflKESCIAL START-UP                         1/74

 ** DESIGN AND OPERATING PARAMETERS
 »• GUENCHER/PPESATUPATCH
     CSI.'ST^UCTIOV nATEPIAL GENERIC TYPE
     CC  TRUCTICH MATERIAL SPECIFIC TYPE
 »•
     NUK3EP
     GENERIC TYPE
     SPECIFIC TYPE
     TRA" NAHE/CCKMCN TYPE
     SUFr.IER
     DIVISIONS - FT
     SHE... GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATEPIAL TRADE NAnE/COKflON TYPE
     LIliEP GEt.'cRIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATE3IAL TRA3E NAME/COMMON TYPE
     GAS CCHTACTIKS DEVICE TYPE
     K-JMSE^  OF CCNTACTItiG ZONES
     L/G PATIO - L/CU.M
     SUrEHFICAL GAS VELOCITY -  MXSEC
     INLET GAS FLC'J -  C'J. tt/S
     £02 PEMOVAL EFFICIEfffiY - 7.
     PARTICLE REMOVAL  EFFICENCY - V.

 «» HIST ELIMINATOR
     PPE-niST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE HAtlE/CCnrOM TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     HASH FREQUENCY

 «» REHEATER
     HUM3ES
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE JIAKE/CCMMCN TYPE
     TEHPERATUOE INCREASE - C
     INLET FLUE 6AS TEMPERATURE - C
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «» FANS
     NUMBER
     APPLICATION

 *• DAMPERS
     FUNCTION
     GENEPIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 »• DUCTWORK
     SHELL  GENERIC MATERIAL TYPE
     SHELL  SPECIFIC MATERIAL TYPE
     LIMcR  GENERIC MATERIAL TYPE
     LIMES  SPECIFIC MATERIAL TYPE
NR
NR
PACKED TCUER
KC3ILE BED PACKING
TURBULENT CONTACT ABSD°EER
AIR CORRECTION DIVISION. UOP
13.0 X 40.0 X 90.0
CARBON STEEL
AISI 1110
N/A
CPGANIC
NATL'PAL PUS3ER
BLACK MATUPAL RUBBER
PLASTIC/RUBBER M03ILE BALLS
 4
   11.1        ( 63.0 GAL/1000 ACF)
    3.8        I 12.6 FT/S)
  312.35       ( 450000 ACFM)
   95.0
   93.0
PRIMARY COLLECTOR
NR
NR
MR
W?
NP
CONTINUOUS
IN-LINE
STEAM
NR
   30.6        (   55 Fl
   51.7        (  125 Fl
HR
NR
BOOSTER
MR
NR
NR
NR
NR
NR
KR
NR
NR
1,'P
NR
                                              1067

-------
 EPA UTILITY FGO SURVEY:  OCTOBER  - DECEMBER  1981

SOUTHERN CALIFORNIA EDISON:  H3HAVE 1A  (COMT.)
 »» REAGEIJT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE
     NUMBER

 «» SOLIDS CONCENTRATINS/DEMATERING
     DEVICE

 «* SOLIDS CONCENTRATING/OEHATERING
     DEVICE

 »« SOLIDS CONCENTRATING/DEWATEHING
     DEVICE

**» SLUDGE

 «» TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 »<* DISPOSAL
     NATURE
     TYPE
     LOCATION
     SITE TRANSPORTATION METHOD
     SITE TREATMENT
KET BALL HILL
COMPARTMENTED
NR
 1
CENTRIFUGE


THICKENER


VACUUM FILTER
FIXATION
PUG MILL
CONVERSION SYSTEMS
FINAL
POND
ON-SITE
TRUCK
NR
	.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  7.  REMOVAL   PER  BOILER   FGD   CAP.
                                                               S02  PART. HOURS HOURS  HOURS FACTOR
10/7*  SYSTEM
                                                                            744
       »* PROSLEMS/SQLUTIONS/COMMENTS
                         TWO PROTOTYPE  SULFUR  DIOXIDE  ABSORBER MODULES MERE INSTALLED IN  1973 AT
                         THE MOHAVE  GENERATING STATION.  THE  VERTICAL MODULEi A UNIVERSAL  OIL PPO-
                         OUCTS TUPBULENT CONTACT ABSORBER  (TCA)  WAS TESTED  IN TWO KCDES!  FIRST  AS
                         A TCA UNIT, FROM NOVEMBER  2,  1974 TO APRIL 30, 1975, AMD SECOND  AS A POLY-
                         GRID PACKED ABSORBER  (PPA). UHEN  THE "PINS PONG BALLS" MERE REPLACED WITH
                         A PLASTIC "EGGCRATE"  PACKING  WITH TESTING CONTINUOUS TO JULY 2,  1975.

                         STARTUP OF  THE MOHAVE 1A EXPERIMENTAL SYSTEM COMMENCED ON OCTOSER 31.  1974
                         AND OPERATED WITH AN  AVAILABILITY OF 72X THROUGH EIGHT MONTHS  OF TESTING.

                         THROUGH THE EIGHT MONTHS OF OPERATION,  THE SYSTEM WAS OUT OF SERVICE
                         APPROXIMATELY  1565 HOURS.  THE  OUTAGE TIME MAS CAUSED BY NECESSARY REPAIRS
                         TO THE G3IDS,  NOZZLES.  TRAP-OUT TRAY AND TO REPAIR/REALIGN PPA PACKING.
                         ADDITIONAL  OUTAGE TIME  MAS NECESSARY TO REDISTRIBUTE THE TCA BALLS. CLEAN
                         SCALE FROM  THE SCRUBBER INTERNALS,  CORRECT BOOSTER FAN TRIP PROBLEMS.
                         CONDUCT INSPECTIONS FOR EXTENDED  OPERATIONS AND REMOVE A HARDHAT FROM
                         THE THICKENER.

                         SYSTEM OPERATIONS HERE  TERMINATED ON JULY 2, 1975.  UP TO THIS TIME.
                         THE SYSTEM  LOGGED 4226  HOURS  OF OPERATION.
                                              1066

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1961

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
HCX EMISSION LIMITATION - NG/J
NET PLANT GENERATES CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY U/FGO - tlU
NET UNIT GENERATING CAPACITY UO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MU

 «« UNIT DATA - BOILER US STACK
     BOILER SUPPLIER
     EOILEB TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.tt/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 »« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RAMSE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTEXT - 7.
     RAMSE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTEXT - X
     RAMSE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - X
     RANEE CHLORIDE CONTENT - X

*•« PARTICLE CONTROL

 »* MECHANICAL COLLECTOR
     NUMBER
     TYPE

 »» FABRIC FILTER
     NLT.BEH
     TYPE

 *• ESP
     NUMBER
     SUPPLIER
     PARTICLE REKOVAL EFFICENCY - Y.

 «» PARTICLE SCPUBSER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

••* FGD SYSTEM

 »« GENERAL DATA
     SALEABLE PROOUCT/THROUAVIAY PRODUCT
     SC2 REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
SOUTHERN CALIFORNIA EDISON
MCHAVE
2A
LAUGHLIN
NEVADA
B
   28.
   64.
               t  .064 LB/MMBTU)
               <  .150 LB/M.-3TU)
               («»*»«» LB/MM3TU)
 1580
  790
  790
  790
  160
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
***«»«»»       (»«*»**» ACFMJ
  132.2        ( 270 F)
  152.         ( 500 FT)
»»***»
»•»*»»•        (»»4m» FT)
COAL
»»»»*•
26749.

   10.00
»*•«*•
               ( 11500 BTU/LB)
                11000-12000
»*»»•»
     .40
 0
NOME
 0
NONE
RESEARCH-COTTRELL
   97.2
NONE
N/A
N/A
N/A
THROUAUAY PRODUCT
WET SCRUBBING
LIME
SO. CALIFORNIA EOISON/STEARN5-
STEARNS-ROGER
PROTOTYPE
                                              1069

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981

SOUTHERN CALIFORNIA EDISON: MOHAVE 2A (CCNT.)

     NEW/RETROFIT                               RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY - X   97.20

WARNING *»UHNORMALIZED NUMBER(S) BEING EDITED FOR OUTPUT**
     ENERGY CONSUMPTION - X
     C'JSRENT STATUS
     TERMINATION
     COMMERCIAL START-UP

 »» DESIGN AND OPERATIC PARAMETERS

 «» CUENCHER/FRESATURATOR
     CCMSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 •« ABSORBER
     NUMBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SUPPLIER
     DIMENSIONS - FT
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TRADE NAME/COMMON TYPE
     LINER GENERIC MATERIAL
     LINER SPECIFIC MATERIAL
     LINER MATERIAL TRADE NAME/COMMON TYPE
     GAS CONTACTING DEVICE TYPE
     NUKBEH OF CONTACTING ZONES
     L/G RATIO - L/CU.M
     SUFERFICAL GAS VELOCITY - M/SEC
     INLET GAS FLOW - CU. M/S
     SOZ REMOVAL EFFICIENCY - X
     PARTICLE REMOVAL EFFICEHCY - X .

 »» MIST ELIMINATOR
     PRE-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TPAOE HAMS/COMMON TYPE
     CONFIGURATION
     MUII5ER OF STAGES
     CONSTRUCTION MATERIAL GENERIC TYPE
     CCMSTRUCTION MATERIAL SPECIFIC TYPE

 «* REHEATER
     KttiSER
     GENEPIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     TEMPERATUPE INCREASE - C
     INLET FLUE GAS TEMPERATURE - C
     CONSTPUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «» FANS
     NUMBER
     APPLICATION

 »» DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 »» DUCTWORK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC MATERIAL TYPE
                                                     .0
 a
 2/75
11/73
NR
NR
SPRAY TOWER
OPEN CROSSCURRENT SPRAY
HORIZONTAL SPRAY CHAMBER
SO. CALIFORNIA EDISON/STEARNS-ROGER
15.0 X 30.0 X 60.0
CARSON STEEL
AISI 1110
N/A
NR
NR
m
NONE
    6.6
  212.35
   95.0
   93.0
(  30.0 GAL/1000 ACF)
(  21.6 FT/S)
(  450000 ACFM)
PRIMARY COLLECTOR
NR
NR
NP
VERTICAL
    1
NR
NR
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLE
   30.6        (   55 F)
   48.9        (  120 F)
NR
NR
 1
BOOSTER
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
                                                1070

-------
                                              EPA UTILITY FGO  SURVEY:  OCTOBER  -  DECEMBER  1981
SOUTHERN CALIFORNIA EDISON:  HOHA/E ZA (CONT.)

      LINER SPECIFIC MATERIAL TYPE              NR

 «« REAGENT PREPARATION EQUIPMENT
     FUNCTION                                   SLAKER
     DEVICE                                     NR
     DEVICE TYPE                                NR

 »* SOLIDS CONCENTRATIHG/DEUATERINS
     DEVICE                                     NR

»»» SLUDGE

 »* TREATMENT
     METHOD                                     FIXATION
     DEVICE                                     MIX TAW
     PROPRIETARY PROCESS                        DRAVO

 *« DISPOSAL
     NATURE                                     FINAL
     TYPE                                       POND
     SITE TREATMENT                             CLAY LINED

 «* UATER BALANCE
     WATER LOOP TYPE                            CLOSED
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
•/. REMOVAL   PER  BOILER  FGD   CAP.
S02  PART. HOURS HOURS  HOURS FACTOR
11/73  SYSTEM

       «* PHOBLEMS/SOLUTIONS/COMMENTS
                         TWO PROTOTYPE SULFUR DIOXIDE ABSORBER MODULES WERE INSTALLED IN 1973 AT THE
                         MOHAVE GENERATING STATION.  A FOUR-STAGE HORIZONTAL CHOSSFLOW SPRAY
                         SCRUBBER MAS INSTALLED ON UNIT Z.

                         IN NOVEMBER 1973 THE UTILITY OPERATED THE FGO SYSTEM AT MOHAVE £A IN A
                         SHORT SERIES OF STARTUP TESTS THAT ENDED ON JANUARY 16. 1974 WHEN A FORMAL
                         TEST PROGRAM WAS INITIATED TO ACCESS PERFORMANCE AND RELIABILITY
                         CHARACTERISTICS OF THE SCRUBBING SYSTEM.

                         DURING THE 13 MONTHS OF EXPERIMENTAL OPERATION THE SYSTEM EXPERIENCED A
                         NUMBER OF PROBLEMS WHICH ACCOUNTED FOR APPROXIMATELY 1757 HOURS OF OUTAGE
                         TIME.  THESE OUTAGES WERE CAUSED BY PUMP REPAIRS. HOPPER LEAKS. BOOSTER
                         FAN BALANCE PROBLEMS. MODIFICATIONS AND REPAIR OF THE PLASTIC MIST
                         ELIMINATOR BLADES, SPRAY NOZZLE REPLACEMENT, GAS INLET FLOW DISTRIBUTION
                         MODIFICATIONS, SLAKING WATER MODIFICATIONS FOR SCALE PREVENTION, AN INSPEC-
                         TION FOR EXTENDED OPERATIONS AND REMOVAL OF A HARDHAT FROM THE THICKENER.

                         THE TEST PROGRAM MAS TERMINATED ON FEBRUARY 9, 1975 FOLLOWING 5°27 HOURS
                         OF OPERATION.  THE MODULE MAS SUBSEQUENTLY DISMANTLED, TRANSPORTED, AND
                         REASSEMBLED AT THE FOUR CORNERS PLANT OF ARIZONA PUBLIC SERVICE WHERE
                         ADDITIONAL TESTING HAS CONDUCTED AND COMPLETED (DECEMBER 1976).
                                              1071

-------
 EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT N.M5ER
CITY
STATE
PECULATOR CLASSIFICATION
PABTICULATE EMISSION LIMITATION - NG/J
SC2 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENEPATIN3 CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM

 «« UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESISN B3ILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 •« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVEPAGE ASH CONTENT - 7.
     RANGE ASH CONTENT - X
     AVERAGE MOISTU3E CONTENT
     RANGE MOISTL'PE CONTENT -
     AVERAGE SULFU3 CONTENT -
     RAN3E SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT
     RAN3E CHLORIDE CONTENT -
- 7.
X
X

- X
X
TENNESSEE VALLEY AUTHORITY
SHAKNEE
IOC
PAOUCAH
KENTUCKY
B
   43.
  516.
««•*»*
                                 I  .100 LB/MM3TU)
                                 ( 1.200 LB/MMBTU)
                                 (»**»*<• LB/MKSTU)
                   1750
                     10
                  ««»•*
                     10
                  BABCOCK « MILCOX
                  PULVERIZED COAL
                  BASE
                  *«**»**»
                  ««**»**
                    Z44.
                  «««**»
                  «»«*»»«
COAL
BITUMINOUS
•*«•*«

«»»»««*»
••*»*»
*••»***«
*•**»«
    2.90
««»•«*
               (»»**»»« ACFM)
               (»»»» F)
               < BOO FT)

               (»«»«* FT)
                                 (*»«««» BTU/LB)
                                  *»***«
»*» PARTICLE CONTROL

 •« PARTICLE SCPU2BER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

•»» FGD SYSTEM

 ** GENERAL DATA
     SALEABLE PPOOUCT/THROMAMAY PRODUCT
     S02 REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     NEM/RETROFIT
                  PACKED TOWER
                  MOBILE BED PACKING
                  TURBULENT CONTACT ABSORBER
                  PLASTIC SPHERES
                  THROUAMAY PRODUCT
                  MET SCRUSBING
                  LIME/LIMESTONE
                  COMBUSTION ENGINEERING
                  BECHTEL
                  PROTOTYPE
                  RETROFIT
WARNING ««UNNORMALIZED NUMBER!S) BEING EDITED FOR OUTPUT»«
     ENERGY CONSUMPTION - X
     CLTCPEUT STATUS
     TERMINATION
     INITIAL START-UP

 •* DESIGN AND OPERATING PARAMETERS

 »* QUENCHER/PPESATURATOR
     CONSTPUCTICN MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
                                                     .0
                   a
                   7/73
                  NR
                  NR
                                               1072

-------
                                              EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981

TENNESSEE VALLEY AUTHORITY: SHAUNEE IOC (CONT.)
 ** ABSORBER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     SHELL GENERIC MATERIAL
     SHELL SPECIFIC MATERIAL
     SHELL MATERIAL TPADE NAME/COMMON TYPE
     LINER GENEPI- MATERIAL
     LINER SPECIF:C MATERIAL
     LINER MATERIAL TRADE MM1E/COMMON TYPE
     GAS CONTACTIN3 DEVICE TYPE
     INLET GAS FLOW - CU. tt/S

 »« MIST ELIMINATOR
     FSE-MIST ELIMINATOR/HIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COHKCN TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »* REHEATER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 «» DAMPERS
     FUNCTION
     GENERIC TYPE
     SPECIFIC TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATEPIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 •» OUCTWOFK
      SHELL GENERIC MATERIAL TYPE
      SHELL SPECIFIC MATERIAL TYPE
      LINER GENERIC KATEPIAL TYPE
      LINE? SPECIFIC MATERIAL TYPE

 »» REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 «« SOLIDS CONCENTRATING/DEUATERINS
     DEVICE

«** SLUDGE

 »« TREATMENT
     METHOD
     DEVICE
     PROPRIETARY PROCESS

 *« DISPOSAL
     NATURE
     TYPE
     SITE TREATMENT
PACKED TOMER
STATIC BED PACKING
MARBLE-BED SCRUBBER
NR
NR
NR
NR
NR
NR
GLASS MARBLES
   14.16       (  30000 ACFM)
NR
NR
NR
NR
NR
NR
DIRECT COMBUSTION
N3
OIL
NR
r
-------
 EPA UTILITY FGD SURVEY: OCTC3ER - DECEMBER 1981

TENNESSEE VALLEY AUTHORITY: SHAU'NEE IOC CCONT. >
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL    PER  BOILER  FGD   CAP.
                                                                S02  PART.  HOURS HOURS  HOURS FACTOR


 4/72  SYSTEM                                                                720

       «* PROBLEnS/SOLUTIONS/COMMENTS

                         IN JUNE I960, THE EPA INITIATED A PROGRAM TO TEST  PROTOTYPE MET LINE AND
                         LIMESTONE SCRUBBING SYSTEMS FOR REMOVAL OF SULFUR  DIOXIDE AND PARTICLE
                         MATTER FROM FLUE GAS.  THREE PARALLEL MET SCRU33ER SYSTEMS WEPE SELECTED
                         FOR THE TEST PROJECT: 1) A VENTURI WITH A SPRAY TOWER  AFTER THE ABSCRSER;
                         £) A TURBULENT CONTACT ABSORBER (TCA); AMD 5) A MAFBLE-BED AESORBEP.
                         THE MAPBLE-BEO A6SOPBER TESTED ON SHAWNEE IOC USED A PACKIUS OF 3/4 INCH
                         GLASS MARBLE SPHERES AND A TURBULENT LAYER OF LIQUID AliO GAS ABOVE THE
                         MARBLE LAYER TO ENHANCE MASS TRANSFER.
                         THE TEST FACILITY HAS DESIGNED SO THAT MODIFICATIONS AND VARIATIONS OF
                         SCRUS3ER INTERNALS AND PIPING COULD BE READILY EMPLOYED FOR EACH SCRUS3ER
                         SYSTEM.

                         THE MARBLE BED ABSORBER AT SHAWNEE IOC COMMENCED OPERATIONS IN APRIL
                         1972.

                         THIS MARBLE-BED ABSORBER MAS DISCONTINUED EARLY IN THE TEST PROGRAM. JULY
                         1973. BECAUSE OF CONTINUED OPERATING PROBLEMS MITH NOZZLE FAILURE AND
                         SUBSEQUENT PLUGGING OF THE MARBLE-BED.
                                              1074

-------
                                              EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931

                                           SECTION 16
               DESIGN AND PERFORMANCE DATA FOR OISCT'ITINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PUNT MAKE
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS t'KIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - HU
NET UNIT GENERATING CAPACITY UO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MM

 »* UNIT DATA - BOILER AND STACK
     BOILER SUPPLIER
     BOILER TYPE
     BOILER SERVICE LOAD
     DESIGN BOILER FLUE GAS FLOW - CU.M/S
     BOILER FLUE GAS TEMPERATURE - C
     STACK HEIGHT - M
     STACK SHELL
     STACK TOP DIAMETER - M

 »« FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVEPASE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - BTU/LB
     AVERAGE ASH CONTENT - V.
     RAM3E ASH CONTENT - 7.
     AVERAGE MOISTURE CONTENT - X
     RAC3E MOISTUPE CONTENT - 7.
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUR CONTENT - 7.
     AVERAGE CHLORIDE CONTENT - 7.
     RAN3E CHLORIDE CONTENT - X

*»« PARTICLE CONTROL

 »» PARTICLE SCRUSSER
     GENERIC TYPE
     SPECIFIC TYPE
     TRADE NAME/COMMON NAME
     GAS CONTACTING DEVICE TYPE

•«* FGD SYSTEM

 *« GENERAL DATA
     SALEABLE FRODUCT/THROMAMAY PRODUCT
     SOC REMOVAL MODE
     PROCESS TYPE
     SYSTEM SUPPLIER
     DEVELOPMENT LEVEL
     NEU/RETROFIT
     UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
     UNIT DESIGN SOS REMOVAL EFFICIENCY - 7.
     ENERGY CONSUMPTION - X
     CURRENT STATUS
     TERMINATION
     INITIAL START-UP

 «» DESIGN AND OPERATING PARAMETERS

 ** (SUENCHER/FRESATUHATOR
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
UNION ELECTRIC
MEREMAC
2
*«»***
MISSOURI
*»»«»«
»»»*»«
«<.**»•«
««»**»
 4135
  140
  125
                (*»»«*» LB/MMBTU)
                (»*»»»« LB/M.13TU)
                (»»«*»» LB/MMBTU)
   140
 **»«**
 PULVERIZED COAL
 BASE
 *»«»•«»»       (*«*•»»* ACFM)
 •«•«<»»        («««* F)
 *«»•»»         («*»» FT)
 »»»**»
 «»»«»*•        (•»««* FT)
COAL
«*<**«»
«»»»»*

»*«*»**»
»*«*«*
**«*»**»
«»»*«»
    3.40
»««»*»
                (»**«*» BTU/LB)
                 *«»**»
 PACKED TCUER
 STATIC BED PACKING
 MARBLE-BED SCRUBBER
 PLASTIC SPHERES
 THROUAUAY PRODUCT
 WET SCRUBBING
 LIMESTONE
 COMBUSTION ENGINEERING
 FULL SCALE
 RETROFIT
X   99.00
    83.00
       <*
  8
  0/69
  3/68
 NR
 NR
                                              1075

-------
 EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981

UNICN ELECTRIC: MEREMAC z ICONT.)
 «» ABSCP3ER
     GZ'JE'IC TYPE
     SPECIFIC TYPE
     T=AOE NAME/CCT.MON TYPE
     SHELL GENc"IC MATEPIAL
     SHELL SPECIFIC MATERIAL
     EhELL MATERIAL TRADE NAME/COMMON TYPE
     LINE:? GEHEPIC MATEPIAL
     LINER SPECIFIC r.ATEP-iL
     LINER MATERIAL TRADE NAME/COMMON TYPE

 »« r.IST ELIMINATOR
     F=E-MIST ELIMINATOR/MIST ELIMINATOR
     GENERIC TYPE
     SPECIFIC TYPE
     T5AOE HATE/CCrMON TYPE
     CONSTRUCTION MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »« REHEATE?
     GENERIC TYPE
     SPECIFIC TYPE
     TPADE NArE/CCmCN TYPE
     CONSTRUCTION MATEPIAL GENEPIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE

 »» DAMFE-S
     FUNCTION
     GENSSIC TYPE
     SPECIFIC TYPE
     CONSTPUCTIOM MATERIAL GENERIC TYPE
     CONSTRUCTION MATERIAL SPECIFIC TYPE
     LINER GENERIC MATERIAL TYPE
     LINER SPECIFIC MATERIAL TYPE

 »« DUCTHC-K
      SHELL GENSPIC MATE"IAL TYPE
      SHELL SPECIFIC MATEPIAL TYPE
      LINER GENERIC MATEPIAL TYPE
      LINER SPECIFIC MATERIAL TYPE

 »» REAGENT PREPARATION EQUIPMENT
     FUNCTION
     DEVICE
     DEVICE TYPE

 »» SOLIDS CCNCENTRATING/OEUATERING
     DEVICE

»«» SLUDGE

 »« TREATMENT
     METriCD
     DEVICE
     PPOPPIETAHY PROCESS

 *» DISPOSAL
     H4TU3E
     TYPE
     SITE TREATMENT

 »* UATER BALANCE
     HATER LOOP TYPE
PACKED TOUER
STATIC BED PACKING
MA7BLE-6EO SCRUS3ER
m
NR
t&
NR
NR
NR
NR
NR
KR
NR
NP
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL

NR


NR
NR
NR
NR
FINAL
NR
NR
                                                CLOSED
                                              1076

-------
                                              EPA UTILITY FGO SURVEY: CCTC3ER - DECEASES 1931
UNION ELECTRIC: MEREKAC 2 ICONT.>
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART.  HCL'SS HOL'SS  KC'-^S FACTCP


 3/66  SYSTEM                                                                744

       i* PROBLEHS/50LUTIONS/CCMMENTS

                         THE FIRST COMMERCIAL SCRUBBER APPLICATION ON A UTILITY COAL-FIRED BOILER
                         OCCURRED AT THIS STATION IN EARLY 1968.

                         THE PROBLEMS ENCOUNTERED DURING OPERATION OF THIS  SYSTEM INCLUDED BOILER
                         TUBE FOULINS BECAUSE OF THE CLOSE TUBE SPACING, WIDESPREAD SCALING, SEVERE
                         CORROSION, INEFFICIENT MIST ELIMINATOR AND PROBLEMS WITH HASTE DISPOSAL.

                         THE SCRUBBING PROGRAM MAS EVENTUALLY TERMINATED AND THE INSTALLATION MAS
                         ABANDONED.
                                              1077

-------
                         APPENDIX A




FGD SYSTEM COST DATA:  OPERATIONAL AND NONOPERATIONAL SYSTEMS
                             A-l

-------
                          INTRODUCTION





     The cost of flue gas desulfurization (FGD)  systems is an



area of intense interest and substantial controversy and few



realistic cost figures have been established.   Many cost figures



(both capital and annual) are largely site-sensitive values.



Such figures cannot be compared from one system to another be-



cause they refer to different FGD battery limits and different



years in which the expenditures were made.  This cost analysis



was undertaken because of these concerns and the lack of compar-



able cost data.



     Analysis is made only for operating FGD systems in this



study because they potentially have complete and accurate econom-



ic data.  Adjustments are made to provide comparable, accurate



cost data for the sulfur dioxide portion of the emission control



system.  This, in effect, eliminates much of the confusion that



exists concerning the reported data, and it provides a common



basis for the reported costs.



     The reported figures are acquired from various sources.



Much of the information was obtained from a previous cost study



initiated by PEDCo Environmental in March 1978.   In this first



study each utility having at least one operational FGD system at
                              A-2

-------
the time was given a cost form containing all available cost in-
formation then in the PEDCo files.  The utility was asked to ver-
ify the data and fill in any missing information.  The PEDCo En-
vironmental staff made a follow-up visit to complete and verify
the data collected.  Results of the cost analysis were then for-
warded to each participating utility for final review and comment.
     For this cost analysis, the primary source of reported cost
information was the 1978 DOE Form 67 (a number of 1979 and 1980
forms were also used as available).  Utilities are generally re-
quired to complete this form, which includes capital and annual
costs, once per year for operating stations.  Although the infor-
mation included in the DOE Form 67 is not as specific and is for-
matted differently from the PEDCo forms, the figures were fitted
as well as possible.
     Some costs were also taken from FGD cost survey question-
naires developed by Edison Electric Institute.  The EEI forms
contain useful capital cost information, however, in some cases
the costs were projections rather than actual dollar expendi-
tures.
     In addition to the sources just mentioned, some 1978, 1979,
and 1980 annual costs were made available by a few utilities via
written transmittals and te-lephone communications.
     Draft forms were assembled based on these sources and sent
to each utility involved in this study.  Each utility was then
contacted and asked to respond as to the validity of the figures.
                               A-3

-------
included in the drafts.  Corrections were then made and it was

assumed that the figures collected provided a firm base to make

adjustments.  In general, it was possible to determine the scope

of the reported costs so that estimates could be made for missing

costs, and non-FGD-related costs could be deleted.  In cases

where this was not possible, assumptions were made as to what

items were and what were not included in the total figures, and

the adjustments were based on these assumptions.

     The adjustment procedure is summarized below:


CAPITAL COSTS

     0    All costs associated with control of particulate matter
          emissions are deducted.

     0    Capital costs for modifications necessitated by instal-
          lation of an FGD system are added if they were not in-
          cluded in the reported costs.

     0    Sludge disposal costs are adjusted to reflect a 20-year
          life span for retrofit FGD systems and a 30-year life
          span for new FGD systems.

     0    Any unreported direct and indirect costs incurred are
          estimated and included.

     0    All capital costs are escalated to 1981 dollars.

     0    All $/kW values reflect the gross generating capacity
          of the unit.


ANNUAL COSTS

     0    All non-labor costs are adjusted to a common 65 percent
          capacity factor.

     0    Direct costs that were not reported are estimated and
          added.

     0    Overhead and fixed costs that were not reported are
          estimated and added.
                               A-4

-------
     0    All annual costs are escalated to 1981 dollars.

     0    The final mills/kWh figure for each cost study is based
          on a standard 65 percent capacity factor and the net
          generating capacity of the unit.

     A more complete description of the cost adjustment procedure

may be found in the section titled Cost Adjustment Procedure and

Background of this Appendix (Page A-9).  The results of the cost

analysis are listed in the section that follows.  Section A-l

summarizes the reported and adjusted capital and annual costs for

all the operational FGD systems that were addressed in the cost

study.  Section A-2 summarizes available cost data for nonopera-

tional FGD systems.
                               A-5

-------
                  RESULTS OF THE COST ANALYSIS





     The results of the operational FGD system survey are sum-



marized in Tables A-l and A-2.  Table A-l summarizes the reported



and adjusted capital and annual costs for all the operational FGD



systems addressed in the survey.  Table A-2 provides a summary of



a categorical analysis of the reported and adjusted capital and



annual costs for the operational FGD systems addressed in the



survey.  Included in this categorical analysis are the ranges,



means, and standard deviation for all the various types and



categories of FGD systems examined.
                              A-6

-------
   TABLE A-l.   REPORTED AND ADJUSTED CAPITAL AND
     ANNUAL COSTS FOR  OPERATIONAL FGD SYSTEMS

4l»m ClMlrlc
Totoigntt 2
TcwigMt 1
•riront Cltclric Povtr
4o.ent 2
404cnt 1
Arisen! PuDlfc Strvfct
Cnolli I
f»11« 2
Cmtril Illlnolt llgnt
Oucl CrMi 1
Ctntr.l Illlitoti Futile fonlct
•nton 1
Colorado UU Cltctric
Crilg I
Crilg 2
Column 4 Southm Onto Cltctric
Conttvlllo S
Conti.lllt 6
Cooptrttlra >OOTr Alieclitlwi
CMl Crwk 1
Coil CrM» 2
Ououttnt llgnt
IlriM 1-4
PMIllpi 1-C
iMIintoolll POMr 1 llgnt
••tiriturg 1
Until City POMr t Llgnt
Kntnorn 1
Mvtnorn (
HCygn. 1
Uni» roMr i llgnt
Jlffroy 1
Jiffriy t
MntuCky Utllltlll
Cr»on llnr 1-1
Loulf»lllt CM t Cltctric
Cm «un 4
Ciiw »un i
ClM lun I
Hill Crwk 1
•111 Crnt 1
Pudy'i lun 6
Nlnnttetl Ponr A Light i
City loiMll •
Nlnnutl tntr
•11 ton II young 2
Honongintla POMVF
Pllttinti 1
Pltlltntl 2
Hontlnt Pcxtr
Colitrlo 1
Colitrlo 2
Hnidl Poxtr
Illd Girmr 1
Itla GirBur t
Illd Ctrentr ]
Rortntrn Inalino Public Strvlct
Our. H NIUMll 11
Narthtrn SUtol POMOF
SMrtnirno 1
Sntrauntt 2
PKifie POMF I light
Jli Brtdgtr 4
Nnniylvond POMP
8rm Hintffold 1
Bruct Hinifltld 2
Bruct Hintfttld 1
Public Strvlct of HM Ntilco
Son Jvin 1
Itn Jutn 2
Slit Ilnr Projtct
CorOMdo 1
Cormooo 2
loutn Ctrellnt Public lonln
•Injtn 2
Wnyoh 1
Soutn Mtlllllppl Eloctrle fOMr
1 D Horra.. Sr 1
1 0 Nora. Sr 2
Soutntm Illlnoli PMr
Kirlon 4
Southtrn Indlon Gil 4 (loctrlc
• 1 Iram 1
Sprlngri(1d City Utllltltl
SOUUMMt 1
Iprlngflold UUr. light 4 Pe«tr
Oillm 1
TtnntiiM Vollty telMrlty
Waoiri Crwk a
uun Pc««r 4 Llgnt
Humor 1
IMlur t
HoRtlngtan 1
•»po»l»a
^"TtSTtST""

(.121.100
t.*92.100

a.na OM
7.21I.OU

4.tM.ODO
44.1S2.0M

ii.m.oco

107.111,000

U.ill.UO
U.I10.SOO

20.4U.MO
I0.4U.900

11. (SO. 000
21.MO.OOO

(1.120.000
il, 015. 000

u. en. ooo

1.220.000
1.220.000
44.900.000

2I.106.NO
n.4sa.aoo

1.944.1SS

U.MT.OOO
11.7S1.000
20.S9f.WO
17.U1.900
u.Mf.aao
4.1ZO.OOO

H.SOO.OOO

44.119.400

11.IS2.400
(1.4S2.400

M.SOO.OOO
14.SOO.OOO

S.UI.17S
S.141.17S
12.S99.KO

U. 192 .040

M,a92.020
M.U2.020

4*.441.000
iu.tn.ooo
UO.flt.OOO
199.fS7.200

47.944.400
I7.9BS.OOO

12.424. SOO
12.424.900

(. 644.098
10.742.SOO
10.fM.000
10. 194,000

1S.200.9M
12.4tS.000
lf.744.SOO
M.9I),tOO

47.900.000
24.400.000
2J.UO.OOO
2.709.000
I/tw

27 I
27 1

41 a
17 0

S2 0
Iff 0

74 a

174 a

at s
71 S

SO 1
SO 1

41 4
41.4

120 2
127 0

104 9

29 4
29 4
S) 7

17 9
17 a

U 0

(f f
ff f
71 S
SS 0
42 f
(1.7

171 t

100 1

11) 1
119 1

101 4
101 4

42 9
42 9
100 f

157 4

49 1
49.)

90.1
120 7
120 f
211 f

112 t
117 1

794
79 4

21. 7
If 4
S) 7
SI. 7

17. 9
47 2
ff.l
170.4

87.1
Sf 7
H 2
f 1 0
Annul I

4M.929
414.129

S1.7H
91. 7M

W
1. 001.SU

10,151.000

m

4(2.400
1.121.400

t.f70.S10
a.f7D.S10

1.144.200
1.W.200

21.0Z7.4S1
ia.ioi.ooo

m

144.441
141.441
a.o».o47

121.000
949.900

144,005

940.101
741.44]
W
HA
121.441
H*

18.444.51J

754.445

s.su.aoo
5,532.800

6.178. 000
(.128,000

2S1.S14
251.914
Ill.t24

2.414. M»

2.7K.7S9
2,716.759

M
9.979.900
9.979.900
11.575.UO

M
HA

1.788.000
1.748.000

527,000
HA
H*
HA

fSI.451
i.aso.su
771.749
4. ni. 500

14.57(.400
HA
1.072.400
2.944.400
Hllli/Mfn

0 11
0 11

0 10
0 10

HA
0 75

S 04

HA

0 91
0 48

S 52
5.52

0 41
0 41

7.18
11 00

HA

1 IS
1 IS
S If

0 11
0 29

S 20

1 29
0 92
HA
HA
1 25
HA

S If

0 51

1 41
1 44

2 97
2 97

0 48
0 46
0 21

11 02

0 75
0 75

HA
1 28
1 28
1 11

HA
HA

o as
o as

0 29
HA
HA
HA

0 98
1.10
1.20
4.U

7 74
HA
0 12
1 27
44
^ioiltl

9.754.200
9. 754. 200

11.171. 700
11.W1.900

10.244.100
42.7II.UO

9S.001.000

1(2. 447, (00

49.179.000
41.070.100

40.f57.200
40.857.200

28. (11, 100
2t.411.100

9S.79S.400
ff. 097. 900

M. 227,500

(.909.850
(.909.850
17,498.400

19.710.900
28.840.100

7.510.600

21.882.500
20.474.400
25.290.600
21.127.800
29.U1.000
9.107.100

102.115.100

68.487.500

104.5(2.000
104.512.000

92.S19.fSO
92.SI9.1SO

io.esi.jso
10.891.150
18.866,171

29.411.808

7i.a54.4at
7i.as4.4af

(S.1U.7U
112. 214. OH
112.214.019
14f.041.400

100.111.471
9t.777.St9

I9.StO.700
IS.SfO.TOO

11.141.872
It.f4f.700
24.047.200
24.047.200

20.906.447
2i.4i4.nt
27.t22.U7
19.129.200

tf.9U.12B
12.294.620
11.229.000
J8.H8.607
I/KM

U 1
18 1

(7 5
59 t

81 1
1(2 1

112 2

2U 9

109 9
90 1

99 4
99 4

52 S
92. 1

187 1
210.0

142 1

62 t
62 t
100 1

SS 9
41 2

117 1

US 2
102 4
67 1
(0 4
(4 0
111 0

114 4

US 7

152 9
152 9

145 9
14S 9

17 1
87 1
190 9

294 f

102 f
102 f

118.4
144 2
144 2
111 1

277 9
262 2

ff S
16.5

47 0
ff t
lit S
lit S

120.1
U 4
141 4
194 1

191.1
75 1
72 t
90 0
jkttfl
Annual

4,249 (50
4.249. (SO

1.719 900
1 719 900

4 Ml fOO
10.99fl.100

U. 411. 100

4S.4il.900

u.ne.joo
10.U2.700

14.479.100
14.475.100

8. 411.350
f. 414. ISO

15.711.700
JS.7J1.700

28.565.000

2.912.100
2.112,100
52.715.100

9.151.200
6. 3*6.400

1.754.800

(.422 400
5.784 100
11.071.000
8.107.100
9. (16. 200
4.430.300

40.417.100

14.W6.000

27 951.100
27.951.100

15.642.050
15.442.050

3.617.450
1. (17. 450
4.(17.1fl

11.129J.211

21.0U.19S
21.0U.19S

19.U1.160
S1.122.9U
51.122.918
48.255.200

29 8J6.802
29.423.764

15.119.100
15.119.100

2.697.B96
(.926.700
7.115.990
7.115.990

7.107.121
7.094.110
I.092.2U
15.911.700

tl. 179.071
10.614.532
10.115.700
11.411.652
Mf i| ikl

1 18
1 If

1 75
1 75

4 79
t 22

S 71

11 94

1 11
4 M

( 78
( 78

2 99
2 99

12 89
17 65

9 74

9 25
S 25
11 29

2 42
1 fl

10 99

f 20
S 10
7 21
4 2t
4 OJ
12 2!

14 09

t 44

7 14
7 94

t 27
1 27

1 78
5 78
7 40

20 79

1 41
5 41

t fl
11.11
11 11
10 27

11 (9
16 (9

7 70
7 70

1 84
4 (1
t 94
f 94

7 79
4 98
1 21
14 56

7.28
4 f f
4 SS
S 89
•I coitl not ••llltolt frou tno utility
                          A-7

-------
                          TABLE A-2.   CATEGORICAL RESULTS OF THE  REPORTED AND ADJUSTED
                              CAPITAL AND ANNUAL COSTS FOR OPERATIONAL  FGD SYSTEMS

All
New
Retrofit
Saleable
Throwaway
Alkaline
flyash/llne
Alkaline flyash/
lines tone
Dual alkali
Line
Limestone
Sodium carbonate
Uellnan Lord
Reported
Capital
Range. J/kW
23.7-213.6
23.7-213.6
29.4-IS7.4
132.8-18S.O
23.7-213.6
43.4-I73.B
49.3- 49 3
47.2-174.8
29.4-213 6
23.7-170.4
42.9-100.8
132.8-185.0
Average,
t/kW
80.2
80.4
79.7
153.1
75.8
93.9
49.3
97.8
81.8
67.9
69.2
153.1
o
44 3
46.1
39.4
20.6
41.5
44.0
0.0
55.3
43.7
37.2
26.6
20.6
Annual
Range.
nllls/kWh
0 1-13.0
0.1- 5.5
0.5-13.0
13.0-13.0
0.1-11.3
0.4- 5.4
0.8- 0.8
1.3- 1.3
0.3-11.3
0.1- 7.8
0.2- 0.5
13.0-13.0
Average,
ntlls/kUh
2.3
1.7
4.5
13.0
2.1
2.1
0 8
1.3
3.2
1.6
0.4
13.0
o
2.8
1.8
4.4
0.0
2.4
1.9
0.0
0.0
2.7
2.2
0.1
0.0
Adjusted
Capital
Range. J/kM
38.3-282.2
38.3-263.9
60.4-282.2
254.6-282.2
38.3-263.9
52.S-184.4
102.6-102.8
87.8-263.9
60.4-210.0
38.3-194.3
87.1-150.9
254.6-282.2
Average ,
J/kW
118.8
110.8
139.3
271.6
110.9
122.8
102.6
146.7
116.5
98.9
110 9
271.6
a
58.1
48.4
73.8
12.1
47.6
51.4
0.0
82.9
44.2
44.0
26.4
12.1
Annual
Range.
mllls/kWh
1.6-20.8
1.6-14.6
4.3-20.8
16.7-20.8
1.6-17.6
3.0-14.1
5.4- 5.4
5.0-13.9
4.0-17.6
1.6-14.6
5.8- 7.4
16.7-20.8
Average,
mills/Mm
7 6
6.8
9.7
18.1
7.0
7.2
5.4
8 7
8 1
6.1
6.4
18.1
0
4.1
3.2
5.3
1.9
3.4
3.8
0.0
3.8
3 6
3.1
0 7
1.9
CO

-------
            COST ADJUSTMENT PROCEDURE AND BACKGROUND


     The cost data were treated solely to establish accurate

costs for FGD systems, on a common basis, not to critique the

design or reasonableness of the costs reported by any utility.

Adjustments focus primarily on the following items:

     0    All capital costs are adjusted to mid-1981 dollars
          using the escalation factors shown in Table A-3.
          Actual costs were reported by utilities in dollar
          values for years 1970 to 1981.  The total figure  is
          broken down into dollars/year and each year total is
          escalated to 1981 dollars and totaled again.  All
          capital costs, represented in dollars/kilowatt ($/kW),
          are expressed in terms of gross megawatts (MW).

     0    Gross unit capacity is used to express all FGD capital
          expenditures because the capital requirement of an FGD
          system is dependent on actual boiler size before  derat-
          ing for auxiliary and air quality control power re-
          quirements.

     0    Particulate control costs are deducted.  Since the pur-
          pose of the study is to estimate the incremental  cost
          for sulfur dioxide control, particulate control costs
          deducted using either data contained in the costs
          breakdowns or as a percentage of the total direct cost
          (capital and annual).  The percentage reduction varies
          depending upon system design and operation.

     0    The capital costs associated with the modification or
          installation of equipment not part of the FGD system
          but needed for its proper functioning, are included
          (e.g., stack lining, modification to existing ductwork
          or fans, etc.).

     0    Indirect charges are adjusted to provide adequate funds
          for engineering, field expenses, legal expenses,
          insurance, interest during construction, allowance for
          startup, taxes, and contingency expenditures.


                               A-9

-------
                   TABLE  A-3.
ESCALATION FACTORS
Year3
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
Capital
Investment0
0.537
0.576
0.600
0.624
0.738
0.825
0.875
0.934
1.000
1.090
1.188
1.295
1.412
1.539
1.677
1.828
Utilities0
0.238
0.277
0.321
0.372
0.496
0.665
0.762
0.873
1.000
1.100
1.210
1.331
1.464
1.611
.1.772
1.94S
Chemicals
0.550
0.584
0.603
0.624
0.733
0.819
0.866
0.928
1.000
1.075
1.156
1.242
1.335
1.436
1.543
1.659
O&M
labor6
0.540
0.583
0.630
0.681
0.735
0.794
0.857
0.926
1.000
1.080
1.166
1.260
1.360
1.470
1.587
1.714
Construction
laborf
0.542
0.613
0.669
0.704
0.768
0.824
0.887
0.937
1.000
1.080
1.166
1.260
1.360
1.470
1.587
1.714
aCost index is for mid year (June).
 Reference:  Marshall  and Swift.
clncludes fuel and electricity;  reference:   Department of Commerce.
 Reference:  Bureau of Mines.
Reference:  Department of Labor.
 Reference:  Engineering News  Record.
                                   A-10

-------
          All annual costs,  represented in mills/kilowatt-hour
          (mills/kWh),  are expressed in terms of net meaawatts
          (MW) .

          Net unit capacity is used to express all FGD annual
          expenditures  because the annual cost requirement of an
          FGD system is dependent on the actual number of kilo-
          watt-hours (kWh) produced by the unit after derating
          for auxiliary and air quality control power require-
          ments.

          All non-labor annual costs are adjusted to a common 65
          percent capacity factor.

          Replacement power costs for retrofitted FGD systems*
          are not included since only a few utilities reported
          such costs and these were presented using a variety of
          methods.

          Sludge  disposal costs are adjusted to reflect the costs
          of sulfur dioxide waste disposal only (i.e., excluding
          fly ash disposal except where usable as a sludge stabi-
          lizing  agent)  and to provide for disposal over the
          anticipated lifetime of the FGD system,  '''his latter
          correction is necessary since several utilities report-
          ed costs for  sludge disposal capacity that would last
          only a  fraction of the FGD system life.  The adjust-
          ments are based on a land cost of $2000/acre with a
          sludge  depth  of 50 ft in a clay-lined pond (clay is
          assumed to be available at the site).

          A 30-year life is assumed for all process and economic
          considerations for all new systems that were installed
          for the life  of the unit.  A 20-year life is assumed
          for all process and economic considerations for retro-
          fit systems that were installed for the remaining por-
          tion of the life of the unit.**
 *If an FGD system is retrofitted to an existing boiler the new
  electrical power demand of the FGD equipment will decrease the
  boiler net MW rating.   Since the boiler was originally sized
  and designed to accommodate a certain grid demand, the utility
  may be forced to buy make-up power from the grid and/or in-
  crease the design capacity of planned boilers.
**The use of a 30-year service life for new units coincides with
  the conclusion of the National Power Survey of the Federal Power
  Commission which recognized this value as reasonable for steam-
  electric plants.  A 20-year service life was assumed for all
  retrofit units even if the remaining life of the units is less
  than this value.  Thus, two different rates are used and should
  be noted when making comparisons between new and retrofit systems.

                              A-ll

-------
     0    Regeneration and by-product recovery facility costs are
          added for those regenerable systems not reporting such
          costs.
     To the extent possible, all cost adjustments are made using
the previous assumptions developed by PEDCo Environmental.  When
cost data are inadequate, adjustments are made using process
design data in conjunction with the previous cost assumptions.
In some cases, adjustments are not possible because of insuffi-
cient data.

DESCRIPTION OF COST ELEMENTS
     Capital costs consist of direct costs, indirect costs, and
other capital costs (including contingency).  Direct costs in-
clude the "bought-out" cost of the equipment, the cost of instal-
lation, and site development.  Indirect costs include interest
during construction, contractor's fees and expenses, engineering,
legal expenses, taxes, insurance, allowance for start-up and
shakedown, and spares.  Contingency costs include those costs
resulting from malfunctions, equipment alterations, and similar
unforeseen sources.  Other capital costs include the nondepreci-
able items of land and working capital.
     Annual costs consist of direct costs, fixed costs, and over-
head costs.  Direct costs include the cost of raw materials,
utilities, operating labor and supervision, and maintenance and
repairs.  Fixed costs include those of depreciation, interim
replacement, insurance, taxes, and interest on borrowed capital.
Overhead costs include those of plant and payroll expenses.  The
                               A-12

-------
various capital and annual cost components are discussed and de-

fined in greater detail in the text that follows.


CAPITAL COSTS

Direct Capital Costs

     The direct capital costs include the following elements:

     0    Equipment required for the FGD system.  Table A-4 pro-
          vides a summary of the major process equipment used in
          FGD systems.

     0    Installation of equipment, including foundations; steel
          work for support, buildings, piping and ducting for
          effluents, slurries, sludge, and make-up water, control
          panels, instrumentation, insulation of ducting, build-
          ings, piping, and other equipment, painting and piling.

     0    Site development may include clearing and grading, con-
          struction of access roads and walkways, establishment
          of rail, barge, and/or truck facilities, and parking
          facilities.

Indirect Capital Costs

     Indirect capital costs include the following elements:

     0    Interest accrued on borrowed capital during construc-
          tion"!

     0    Contractor's fee and expenses, including costs for
          field labor payroll; field office supervision; person-
          nel; construction offices; temporary roadways; railroad
          trackage; maintenance and welding shops; parking lot;
          communications; temporary piping and electrical and
          sanitary facilities; safety security  (fire, material,
          medical, etc.); construction tools and rental equip-
          ment; unloading and storage of materials; travel ex-
          penses; permits; licenses; taxes; insurance; overhead;
          legal liabilities; field testing of equipment; start-
          up; and labor relations.

     0    Engineering costs, including administrative, process,
          project, and general; design and related functions for
          specifications; bid analysis; special studies; cost
          analysis; accounting; reports; consultant fees; pur-
          chasing; procurement; travel expenses; living expenses;
          expediting; inspection; safety; communications;
          modeling; pilot plant studies  (if required because of

                               A-13

-------
             TABLE A-4.
MAJOR FGD SYSTEM EQUIPMENT SUMMARY
            Category
                   Description
Material handling - raw materials
Feed preparation - raw materials
Sulfur dioxide absorption
Flue gas reheat
Gas handling
Sludge disposal
Utilities
By-product handling
(continued)
       Equipment for the handling  and transfer of
       raw materials includes  unloading facili-
       ties, conveyors,  storage areas and silos,
       vibrators, atmospheric  emission control
       associated with these facilities, and
       related accessories

       Equipment for the preparation of raw
       material to produce  a feed  slurry consists
       of feed weighers, crushers, grinders,
       classifiers, ball mills, mixing tanks,
       pumps, agitators, and related accessories

       Equipment for treating  the  flue gas includes
       absorbers, mist eliminators,  hold tanks,
       agitators, circulating  pumps, pond water
       return pumps, and related accessories

       Equipment required includes air, steam, or
       hot water heaters, condensate tanks, pumps,
       soot blowers, fans,  fuel storage facilities,
       gas bypass equipment, and related acces-
       sories

       Equipment to handle  the boiler flue gas in-
       cludes booster fans, ductwork, flue gas
       bypass system, turning  vanes, supports,
       platforms, and related  accessories

       FGO systems that  do  not generate a salable
       product require solids/water separation
       equipment such as clarifiers, vacuum fil-
       ters, centrifuges, sludge fixation equip-
       ment, and related accessories

       Equipment to supply  power and water to the
       FGO equipment consists  of switch-gear,
       breakers, transformers, piping, and related
       accessories

       Equipment for processing the by-product of
       regenerable FGD systems may include a ro-
       tary kiln, fluid  bed dryer, conveyor,
       storage silo, vibrator, combustion equipment
       and oil storage tanks,  waste heat boilers,
       hammer mills, evaporators,  crystallizers,
       strippers, tanks, agitators,  pumps, com-
       pressors, sulfuric add absorber and cooling,
       mist eliminator,  pumps, acid coolers, tanks,
       etc.
                                  A-14

-------
TABLE A-4   (continued)
            Category
            Description
Regeneration
Purge treatment
Auxiliary
Equipment for regeneration of the absorbing
medium of an FGD system may consist of re-
actor vessels, material handling system,
storage, weigh feeder, conveyor, rotary
kiln, fluid bed calciner, dust collector,
storage silo, vibrator, combustion equip-
ment and oil storage tanks, waste heat
boiler, hammer mill, evaporators, crystal-
lizers, strippers, tanks, agitators, pumps,
compressors, sulfuric acid absorber and
cooling, mist eliminator, pumps, acid
coolers, tanks, etc.

Equipment for the removal of purge material
(e.g., sodium sulfate) includes refrigera-
tion, pumps, tanks, crystallizer, centrifuge,
dryer, dust collector, conveyors, storage,
and related equipment

Equipment not directly related to the FGD
system, but which may require design or
modification to accommodate an FGD system
may include such items as existing fans,
ducts, or stack.  If new fans, ducts, or
stacks are added to improve boiler perfor-
mance and accommodate the FGD system, the
costs are prorated to the boiler and FGD
system
                                    A-15

-------
          process design or application novelty); royalty pay-
          ments during construction; training of plant personnel;
          field engineering; safety engineering; and consultant
          services.

     0    Legal expenses, including those for securing permits,
          right-of-way, etc.

     0    Taxes, including sales, and excise taxes.

     0    Insurance covering liability for equipment in transit
          and at site; fire, casualty, injury, and death; damage
          to property; delay; and noncompliance.

     0    Allowance for start-up and shakedown includes the cost
          associated with system start-up.

     0    Spare parts including pumps, valves, controls, special
          piping and fittings, instruments, spray nozzles, and
          similar items.

Other Capital Costs

     Other capital costs include the following elements:

     0    Contingency funds set aside for.any necessary repairs
          and/or modifications not covered in projected direct
          expenditures.

     0    Land required for the FGD process, waste disposal, re-
          generation facility, and storage.

     0    Working capital, including the total amount of money
          invested in raw materials and supplies in stock, fin-
          ished products in stock, and unfinished products in the
          process of being manufactured;  accounts receivable;
          cash kept on hand for payment of operating expenses
          such as salaries, wages, and raw materials purchases;
          accounts payable; and taxes payable.


ANNUAL COSTS

     The annual cost of an FGD system includes the following

direct, fixed and overhead charges:

Direct Costs

     0    Raw materials, including those required by the FGD
          process for sulfur dioxide control, absorbent

                              A-16

-------
          regeneration, sludge treatment, sludge fixation,
          flocculants, etc.

          Utilities, including water for slurries, cooling and
          cleaning; electricity for pumps, fans, valves, lighting
          controls, conveyors, and mixers; fuel for reheating of
          flue gases; and steam for processing.

          Operating labor, including supervision, skilled, and
          unskilled labor required to operate, monitor, and
          control the FGD process.

          Maintenance and repairs, consisting of both manpower
          and materials to keep the unit operating efficiently.
          The function of maintenance is both preventive and
          corrective to keep outages to a minimum.

          Byproduct sales, credit from the sale of byproducts
          regenerable FGD processes (e.g., sulfur, sulfuric acid)
          is a negative charge deducted from the annual direct
          cost to obtain the net annual direct cost of the FGD
          system.
Overhead
     Plant and administrative overhead is a business expense that
     is not charged directly to a particular part of a project,
     but is allocated to it.  Overhead costs include administra-
     tive, safety, engineering, legal and medical services; pay-
     roll; employee benefits; recreation; and public relations.
Fixed Charges
          Depreciation - the annual charge to recover direct and
          indirect costs of physical assets over the life of the
          asset.

          Interim replacement - costs expended for temporary or
          provisional replacement of equipment that has failed or
          malfunctioned prematurely.

          Insurance - including the costs of protection from loss
          by a specified contingency, peril, or unforeseen event.
          Required coverage could include losses due to fire,
          personel injury or death, property damage, explosion,
          lightning, or other natural phenomena.

          Taxes - including franchises, excise, and property
          taxes levied by a city, county, state, or Federal
          government.

          Interest - on borrowed funds.

                              A-17

-------
     Table A-5 provides a summary of the means used to deter-



mine the missing cost elements if the costs were not reported or



insufficient information prevented their actual determination.



The assumptions and cost bases for determining the capital and



annual costs of FGD systems were developed by the PEDCo staff



based upon previous economic studies conducted for the U.S. EPA



(Flue Gas Desulfurization Process Cost Assessment, May 1975;



Simplified Procedures for Estimating Flue Gas Desulfurization



System Costs, June 1976, EPA-600/2-76-150; Particulate and Sulfur



Dioxide Emission Control Costs for Large Coal-Fired Boilers,



March 1978, EPA-600/7-78-032).





STANDARDIZED ADJUSTED ANNUAL COST



     In an attempt to promote further comparability of the



figures, the adjustment procedure was carried one step further



and standardized adjusted figures were developed.  This was done



by modifying the fixed annual cost rates such that they would be



identical for each unit (i.e., cost of depreciation, interim



replacement, taxes, insurance, and capital costs).  The newly



adjusted total fixed annual cost rate was applied to the total



adjusted capital cost in each case and a standardized adjusted



annual cost was obtained.
                               A-18

-------
                       TABLE A-5.
COST ELEMENT FACTORS
          Category
             Value
Indirect capital costs:
  Interest during construction
  Field overhead
  Contractor's fee and expenses
  Engineering
  Taxes
  Spares
  Shakedown allowance
Other capital costs:
  Contingency3
Direct annual costs:
  Raw materials:
    Fixation chemicals
    Lime
    Lime (magnesium promoted)

    Limestone
    Magnesium oxide
    Sodium carbonate
    Salt cake (credit)
    Sulfur (credit)
    Sulfuric acid (credit)
  Utilities:
    Electricity
    Mater
    Steam

(continued)
   10% of total direct capital  costs
   10% of total direct capital  costs
   5% of total  direct capital  costs
   10% of total direct capital  costs
   2% of total  direct capital  costs
   1% of total  direct capital  costs
   5% of total  direct capital  costs
   20% of total  direct and indirect
     capital  costs
   $60/ton
   $46/ton
   S62/ton
   $52/tonc
   $12/ton
   $300/ton
   $130/tond
   $50/ton
   $87/ton
   $75/ton
   $33 mills/kWh
   $0.26/103 gal
   $1.60/106 Btu
                                   A-19

-------
TABLE A-5   (continued)
          Category
          Value
  Operating labor:
    Direct -labor
    Supervision
  Maintenance:
    Labor and materials
    Supplies
  Overhead:
    Plant
    Payroll

Fixed annual costs:
  Depreciation
  Interim replacement6
  Taxes
  Insurance
  Capital costs
$14.40/man-hour
15% of direct labor costs
4% of total direct capital costs
15% of labor and materials costs
50% of operation and maintenance costs
20% of operating labor costs
3.33% or 5% (new or retrofit)
0.7% or 0.35%
4%
0.3%
9%
  Contingency costs  are  used  only when  the  cost data supplied are  incomplete
  (such as equipment costs  or direct  costs  only)  and a contingency cost must
  be factored in  to  give an accurate  estimate of  the total capital cost.
  Estimated cost  for carbide  lime used  by Louisville Gas and Electric was
  S13.30/ton in 1978.  This was  escalated to S15.40/ton for 1980.
  Long term contract (e.g., Dravo contract).
  Nevada Power reported  a January 1982  soda ash cost of $115/ton delivered
  (transported from  Trona,  California to Moapa, Nevada).  Montana-Dakota
  Utilities reported a cost of $151/ton (October  1981 dollars^  delivered
  (transported from  Green River, Wyoming to Beulah, North Dakota).
  Some system components have life spans less than the expected service life
  of the system.   Interim replacement is an allowance factor used  in estimat-
  ing annual  revenue requirements to  provide for  the replacement of these
  short-lived items.  An average allowance  of 0.35% of the total investment
  is normally provided anri  used  for systems with  an expected service life of
  20 years or less.   A higher allowance of  0.70%  of the total investment is
  provided and used  for  systems  with  an expected  service life of 30 years or
  more.
                                   A-20

-------
              EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
           SECTION A-I
COSTS FOR OPERATIONAL F6D SYSTEMS

13IIT DESCRIPTION

ALABAMA ELECTRIC
TCM3IGSEE 2
t'i'A £55MU (G303S)
STARTUP 9/78 179KH (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
FEA20DY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3. IX
ALABAMA ELECTRIC
TC"3IGBEE 3
NEU 2S5MW (GROSS)
STARTUP 6/79 179MW (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
FEABC3Y PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.1X
ARIZONA ELECTRIC POWER
APACHE 2
NEU 195MU (GROSS)
STARTUP 8/78 96MU (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4. IX
ARIZONA ELECTRIC POWER
APACHE 3
NEU 195MU (GROSS)
STARTUP 6/79 9CMU (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4. IX
ARIZONA PUBLIC SERVICE
CHOLLA 1
RETROFIT 119MH (GROSS)
STARTUP 10/73 119KM (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 3.4X
ARIZONA PUBLIC SERVICE
CHOLLA 2
NEU 264KU (GROSS)
STARTUP 4/78 264MM (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: «*»*x

COST DESCRIPTION

CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 9
TOTAL CAPITAL, 5/KUIYEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KKH(YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL. S/KU(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHI YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KU(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, RILLS/KUH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KH(YEAR>
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHC YEAR )
CAPACITY FACTOR, V.
DIRECT CAPITAL, 4
INDIRECT CAPITAL, »
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KUH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KUIYEAR]
DIRECT ANNUAL, $
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHt YEAR)

REPORTED

65
5826750.
1 i A?^t»n
aos J9U •
**•»**»*««**
27.411978)
434929.
**********
**********
.3(1978)
65
5826750.
1165350.
**********
27.4(1978)
**********
434929.
**********
.3(1978)
65
6154982.
1895044.
78949.
41.8(1977)
48237.
3547.
**********
.1(1979)
65
5449433.
1677814.
69399.
37.0(1977)
48237.
3547.
**********
.1(1979)
*»»
**»**»***»
**********
**********
52.0(1973)
**********
**********
**********
«*****{ 1978 )
65
**********
**********
**********
163.0(1977)
1003566.
**********
**********
.8(1978)

ADJUSTED

65
«**««*»!,*«
«!!*««*!£**
23.3(1931)
2:26150.
132750.
1690750.
3.2(1931)
65
**********
***«»**)t*4
**********
38.3(1931)
2226150.
332750.
1690750.
3.2(1931)
65
**********
**********
****•«*«»»*
67.5(1981)
1568150.
19000.
2151850.
3.8(1931)
65
***********
**********
«.«<(««*****
59.8(1931)
1568150.
19900.
2151850.
3.8(1981)
65
**********
»********,*
**»«**««<<*
81.3(1981)
2049200.
561600.
1993000.
4.8(1931)
65
**********
**********
*»**.< ««***
162.1(1031)
30314...
551300.
7415100.
8.2(1931)

STAf,3A!?CIZi3
ADJ'JSTID
65
**'""""'**»
***»..«»»»
-.-«4rf,*( 0)
»»•••***»*•«»»
*-4«-«**«*4
"•***••»*••*
«»**„*< gj
65

M**.,******
»**,(K«4*4V
******( 0)
**tf)t *>***«
4*4<«(4K4Klf
i*********
*****»( 01
65

**********
*-«*•«* *****
**«***< Q )
**********
y^^4**aiy«t(
**********
******< 0 )
65
K*********
»***»•***«*
**•"*•******
*^»+**( 0 )
**•**-+*****
**-f**,****
**«*^4****
****** ( 0 ]
65
**********
it*********
**********
****«*( Q]
**********
**********
* -'***»**»-»
»*****( 0]
65
**********
**********
**********
***•»*»( 01

*******»*•«
**********
**«**.«( (j )
  INDICATES COST FIGURES NOT YET AVAILABLE

           A-  21

-------
EPA UTILITY F6D SURVEY:  OCTOBER  - DECEMBER  1981
                                          SECTION A-l
                               COSTS FOR  OPERATIONAL FGD  SYSTEMS

UNIT DESCRIPTION
^IZCNA PUBLIC SERVICE
MEW 37SMM (GROSS)
STARTUP 3/81 1C6MM (ESC)
COAL
.50 XS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: «*»»X
3ASIN ELECTRIC PCUER
LARAMIE RIVER 1
NEU 57CMW (GROSS)
STARTUP 7/80 570^ (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: *»»»•/.
BASIN ELECTRIC POUEH
LARAMIE RIVER 2
NEM S70MU (GROSS)
STARTUP 7/81 570MW (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: »«»«X
BIG RIVERS ELECTRIC
GREEN 1
NEU 242MM (GROSS)
STARTUP 12/79 242MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: »***x
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
NEU 416MU (GROSS)
STARTUP 7/76 416MU (ESC)
COAL
3.66 XS BITUMINOUS
LIMESTONE
ENVIPONEERING, RILEY STOKER
ENERGY CONSUMPTION: 2.9X
CENTRAL ILLINOIS PUBLIC SERV
NEUTON 1
NEU 617MU (GROSS)
STARTUP 9/79 617MJ4 (ESC)
COAL
2.25 XS BITUMINOUS
O'JIL ALKALI
GE ENVIRONMENTAL SERVICES
EME3GY CONSUMPTION: 2.4X

COST DESCRIPTION
CAPACITY FACTOR. X
INDIRECT CAPITAL. 4
OTHER CAPITAL. 4
TOTAL CAPITAL. 4/KUI YEAR )
DIRECT ANNUAL. 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHf YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KU(YEAR)
DIRECT ANNUAL. 4
OVERHEAD COST, $
FIXED CHARGES, 4
TOTAL ANNUAL. MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, S/KWCYEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL. 4
OTHER CAPITAL. 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES. 4
TOTAL ANNUAL, MILLS/KMHI YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL. 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KUH( YEAR)
CAPACITY FACTOR. X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES. 4
TOTAL ANNUAL. MILLS/KUHI YEAR)

RE-OSTED
*«*
*******•«-**
83.01 0)
**********
**********
**»**<•( Q )
***
33600000.
**********
**********
56.0(1930)
2818530.
.9(7300)
***
33600000.
**********
**********
56.0(1980)
2816530.
**********
**********
.9(7800)
10454400.
»*«****»*»
43.2(1976)
**********
**********
******( 0 )
65
***»*****»
74.8(1977)
5163000.
5.0(1980)
**********
174.8(1978)
**********
******( Q)

ADJUSTED
65
**********
******( o )
65
**********
**********
**********
******( Q )
**********
******( o )
65
**********
*»****( Q)
**********
**********
»*****( o )
65
**********
**********
******( Q)
65
**********
132.2(1981)
5634500.
600000.
6198600.
5.8(1981)
65
**»»#«»*«»
**********
263.9(1931)
13332000.
4017400.
28221500.
13.9(1931)

AOJL'STsO
65
*•*•>"•*•*-•)»*
1H*****!*( 0 )
65
«***«**«**
*<****( 0 )
****»*( 0 )
65
**********
**********
*»****( 0 )
a*********
**********
**********
***»**( Q)
65
**********
**********
**********
******( Q )
**********
**********
******( Q )
65
**********
******( 0 )
**********
******( o )
65
**********
**********
******( Q)
**********
***»*»****
******< 0 )
                                 INDICATES COST FIGURES NOT YET AVAILABLE

                                           A-  22

-------
                     EPA UTILITY F6D SURVEY: CCT03EB  - DECEMBER 1931
                  SECTION A-l
       C3STS  FOR  OPERATIONAL FGO SYSTEMS

UNIT DESCRIPTION
CINCINNATI GAS i ELECTRIC
EAST BEND 2
ti~i i ACPMU i f*"oec i
NCH ODUnH I wf*Loo J
STARTUP 3/81 650MH (ESC)
COAL
3.00 XS
LIME
EA5CCCK £ UILCOX
ENERGY CONSUMPTION: 2.9X
COLORADO UTE ELECTRIC
CRAIG 1
NEU 455MV4 (GROSS)
STARTUP 10/80 410MH (ESC)
CCAu
.45 XS SU33ITUMINCUS
LIMESTONE
PEA3C3Y PROCESS SYSTEMS
ENERGY CONSUMPTION: i.sx
COLCPAOO UTE ELECTRIC
CRAIG 2
NEU 455MM (GROSS)
STARTUP 12/79 410MVI (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
PEABCDY PROCESS SYSTEMS
ENERGY CONSUMPTION: -2. OX
COLUMBUS i SOUTHERN OHIO ELEC
CCNESVILLE 5
NEW • 411MW (GROSS)
STARTUP 1/77 411MW (ESC)
COAL
4.67 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION. UOP
ENERGY CONSUMPTION: 3.9X
COLUMBUS » SOUTHERN OHIO ELEC
CCNESVILLE 6
NEW 411MW (GROSS)
STARTUP 6/78 411MH (ESC)
COAL
4.67 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION. UOP
ENERGY CONSUMPTION: 3.9X
COMMONWEALTH EDISON
POMERTCN 51
RETROFIT 450MM (GROSS)
STARTUP 4/80 450MM (ESC)
COAL
3.53 XS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 5.6X

COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL. S
OTHER CAPITAL, 5
TOTAL CAPITAL, $/KH(YEAR)
DIRECT ANNUAL, $
nv/CDuc tn POQT 4
UVCrflCAU I*UO 1 i 9
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHl YEAR)
CAPACITY FACTOR, X
DIPECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, 9
TOTAL CAPITAL, S/KVUYEAR)
DIRECT ANNUAL, S
OVERHEAD COST, »
FIXED CHARGES. $
TOTAL ANNUAL. MILLS/KHH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL. $
INDIRECT CAPITAL. *
OTHER CAPITAL. »
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST. *
FIXED CHARGES, »
TOTAL ANNUAL, MILLS/KWW YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, «
OVERHEAD COST, $
FIXED CHARGES. *
TOTAL ANNUAL, MILLS/KKH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, »
OTHER CAPITAL, *
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, $
FIXED CHARGES, 9
TOTAL ANNUAL. MILLS/KWHl YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, $
OTHER CAPITAL, *
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUA.., MILLS/KUH( YEAR )

REPORTED
***
78000000.
**********
120.01 0)
11718252.
»««**»«***
3.4(7800)
**»
38613500.
**********
**********
86.5(1979)
462600.
**********
**********
.5(1980)
***
32810500.
**********
**********
73.5(1979)
1128400.
**********
**********
.5(1980)
48
20663500.
**********
**********
50.3(1975)
4724280.
443800.
**********
5.5(1978)
48
20663500.
**********
**********
50.3(1975)
4724230.
443800.
**********
5.5(1978)
***
56250000.
**********
**********
125.0(1979)
**********
**********
**********
******( o )

ADJUSTED
65
V*********
***********
*•<*•***.( 0)
***<*»****
**********
******( Q)
65
**»-******
**********
**********
105.9(1981)
3&24500.
174400.
C34«400.
5.3(1931)
65
**********
**********
**********
90.3(1931)
3036100.
229200.
7117400.
4.6(1981)
65
32044850.
8812350.
**********
09.4(1931)
6973350.
559200.
6937550.
6.8(1981)
65
32044850.
8812350.
*******•<**
99.4(1981)
6973350.
559200.
6937550.
6.811S81)
65
*»*>»*****
***********
**********
******( Q )
«»***«*»*»
**********
**********
******( Q )

ST-D'^3?l3ED
65
**•*•«.*•*•*.*•#»
*k,..».,,*
*.„„***( g)
**•»*••»•**•***
**•«*•<»•<•*»
*•»•*••»•*( 0)
65
**********
»***4**4**
******»*-**
******( Q)
*i»***f4rf»*
*•»**•*•****
***********
******( Q)
65
**********
**********
***********
*****»( Q)
*****•#****
**********
**********
******( Q )
65
***•*<****»
*)l»H«*»'«*'«»
*«->*,(*****
**,**»< Q)
**•»*»*****
**********
**********
******( Q)
65
**********
«*****»***
H*#v******
*»****( 0)
**********
**********
**********
******( Q)
65
**********
v*********
**********
*»»***( Q )
**********
**********
**********
******( 0 )
*»***»   INDICATES COST FIGURES NOT YET AVAILABLE

                   A-  23

-------
EPA UTILITY FGO SLAVEY:  CCTC2ER - DECEMBER 1981
                                          SECTION A-l
                               COSTS FOR OPERATIONAL FGO SYSTEMS

UNIT DESCRIPTION

COOPERATIVE POWER ASSOCIATION
COAL CPEEK 1
N=W 545MW (GROSS)
STARTUP 7/79 327MW (ESC)
COAL
.65 XS LIGNITE
LIME/ALKALINE FLYASH
CCMSUSTION ENGINEERING
ENERGY CONSUMPTION: *»**X
COOPERATIVE POUER ASSOCIATION
COAL CREEK 2
NEW 545MW (GROSS)
STARTUP 7/80 327MW (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »«*»X
OUQUESNE LIGHT
ELRAMA 1-4
RETROFIT 510MM (GPOSS)
STARTUP 10/75 510MW (ESC)
COAL
Z. 20 XS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 3.SX
DL'QUESME LIGHT
PHILLIPS 1-6
RETROFIT 40SMW (GROSS)
STARTUP 7/73 408MW (ESC)
COAL
2.05 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 3.4X
HOOSIER ENERGY
KEROM 2
NEW 490MW (GROSS)
STARTUP 12/81 441MU (ESC)
COAL
3.50 XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****Y.
INDIANAPOLIS POUER » LIGHT
PETERSBURG 3
NEW 532MW (GROSS)
STARTUP 12/77 532MW (ESC)
COAL
3. £5 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 2.4X

COST DESCRIPTION

CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, *
OTHER CAPITAL, *
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, »
FIXED CHARGES, «
TOTAL ANNUAL, MILLS/KWW YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, S/KHtYEAR)
DIRECT ANNUAL. *
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWW YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, 9
TOTAL CAPITAL. «/KM(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KUHIYEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL. 9
OTHER CAPITAL, $
TOTAL CAPITAL, »/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KUHI YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL. «
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, «
FIXED CHARGES. $
TOTAL ANNUAL. MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIPECT CAPITAL, »
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, «/KU(YEAR)
DIRECT ANNUAL, «
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWHI YEAR )

REPORTED

***
23650000.
******•»*»*
**********
43.4(1979)
1166200.
««««««««*»
«*»*»**»**
.4(1981)
***
23650000.
**««**»***
**4*«K*»»4
43.4(1979)
1166200.
«*****«*«»
ft«*»*»KKtt*
.4(1981)
69
»*«»****«<•
*»«»*»»<«»*
*«**«****»
120.2(1976)
13441451.
«*»*«»**»*
*»«**«***«
7.2(1979)
55
»****«****
**********
Kt*W*»»»*
«***>(»( Q )
**»
*»)(«««*««»
»«**«*»«**
»*«**««**»
104.9(1976)
tt««N»»**)Ht
»»*»*»*»»»
**********
KiH»«)HH 1978 )

ADJUSTED

65
23469750.
5163350.
ONN044W-***
52.5(1981)
3156450.
295800.
4962100.
3.0(1981)
65
23469750.
5163350.
Kl"f*>f*»*i»*IH»«»
ttffN*«««»
*»***»( 0 )
65
*W»•«<»( 0 )
"*»*»»•«"•'*»*
M»4<»>*Wk^4
»*-*-»X^)C«r«*
*»**«*( 0 )
65
»*-**•«** «MH»
****)»•«<>»=»*
*«»*-«*#»*»
«W(4M( 0 )
<»»)•******>»
»»**•*****»
**•! •*»*<««««
!««****( Q )
65
•»********
*#)»)»»**»*«
tHt***W*>H»»
***#*»( Q)
KOXyNVKMt*
*#**)«<«»*»'»
**»«»*«*»»
**»*-«•*( Q)
65
«t-«V<|«lf)»(«
**********
*»*******»
*****»( 0)
*«**<>XN***
**********
»**#*»*<•**
******( 0 )
65
**********
**•««***»**
**********
**»***( 0 )
**********
it*********
**********
******( 0)
65
**********
**********
**********
**»***( 0)
**»*<«*****
**********
**********
******( Q)
                        ******   INDICATES COST FIGURES NOT YET AVAILABLE

                                           A-  24

-------
                     EPA UTILITY  FGD  SURVEY:  OCTOBER  -  DECEMBER  1981
                  SECTION A-l
       COSTS FOR  OPERATIONAL FGD  SYSTEMS

UNIT DESCRIPTION

KANSAS CITY POWER & LIGHT
HAWTH03N 3
RETROFIT 90MW (GROSS)
STARTUP 11/72 90KM (ESC)
COAL
.60 XS BITUMINOUS
LIKE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.2X
KANSAS CITY POWER I LIGHT
HAWTHORN 4
PETPOFIT 90MM (GROSS)
STARTUP 8/72 90KM (ESC)
COAL
.60 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.2X
KANSAS CITY POWER ft LIGHT
LA CYGNE 1
NEW 674MH (GROSS)
STARTUP 2/73 874MM (ESC)
COAL
5.39 XS SUBBITUMINOUS
LIMESTONE
BABCOCK i WILCOX
ENERGY CONSUMPTION: 3.2X
KANSAS POWER 4 LIGHT
JEFFREY 1
NEW 720MW (GROSS)
STARTUP 8/78 540MW (ESC)
COAL
.32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *»««X
KANSAS POWER & LIGHT
JEFFREY Z
NEW 70CMW (GROSS)
STARTUP 1/80 490MW (ESC)
COAL
.30 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: **»»X
KENTUCKY UTILITIES
GREEN RIVER 1-3
RETROFIT 64HW (GROSS)
STARTUP 9/75 64MW (ESC)
COAL
4.00 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 3. IX

COST DESCRIPTION

CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, «
OTHER CAPITAL, $
TOTAL CAPITAL, S/KWIYEAR)
DIRECT ANNUAL, S
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL. MILLS/KUHI YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL. $
INDIRECT CAPITAL. »
OTHER CAPITAL. $
TOTAL CAPITAL, S/KWfYEAR)
DIRECT ANNUAL. $
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHC YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL. *
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, «/KM(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, *
FIXED CHARGES, »
TOTAL ANNUAL, MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL. $
INDIRECT CAPITAL, 4
OTHER CAPITAL, $
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL. »
OVERHEAD COST, $
FIXED CHARGES, 9
TOTAL ANNUAL. MILLS/KUH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, $/KH(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWH( YEAR)

REPORTED

35
*HMf JUMUMHfW
**********
»**•***«•«**
£9.4(1972)
346441.
**********
**********
1.1(1978)
35
*****«***«
«***«*****
M«***tt**K*
29.4(1972)
346441.
****»*»»*«
tt««»*»**«*
1.1(1978)
21
«*****«**»
***»***»**
**********
53.7(1972)
8060047.
**N*«**X*)t
**********
5.4(1979)
50
25530000.
1776900.
**********
37.9(1978)
321000.
**********
**********
.1(1978)
55
**********
**********
**********
37.8(1980)
**********
**********
**********
.3(1980)
13
**********
**********
**********
62.0(1975)
364005.
******»*««
***y*tt»***
5.2(1978)

ADJUSTED

65
**********
**********
62.8(1981)
1466330.
31'«700.
1131100.
5.2(1981)
65
**********
**********
**********
62.8(1981)
1466300.
314700.
1131100.
5.2(1981)
65
*****»***»
**>«*******
**********
100.1(1981)
28360400.
9211400.
15163500.
11.3(1981)
65
**********
**********
**********
55.9(1981)
2350100.
121300.
6881800.
2.4(1981)
65
ft*********
**********
**********
41.2(1981)
1083000.
315400.
49«8000.
1.6(1981)
65
**********
**»******-»
**********
117.8(1981)
2012200.
430500.
1312100.
11.0(1981)

STANCAPCIIED
ADJUSTED
65
***********
«*VK»4**»*
*-t**~*{ 0 )
**********
******•*•*•**
«*««•**•«***
****+*( Q )
65
**********
**********
**********
******( Q )
**********
***********
**********
******( 0 1
65
**»*»***«*
**********
**********
******( 0 )
**********
**********
**********
*«•«***( 0 )
65
K*********
**********
**********
****»*( Q)
**********
**********
**********
******( Q)
65
«»H»****ft*
WKVfMXrf**
*»»»*»>•<*»
******( Q )
**********
**********
**********
«««*«it( Q )
65
»***»*»»**
**********
**********
******( Q )
WKINKWKtVt
»*<«#»lt)t»)»
WKgtKtVCt**
******( 0 )
•«•«»•   INDICATES COST FIGURES NOT YET AVAILABLE

                   A-  25

-------
EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981
                                          SECTION A-l
                               COSTS FOR OPERATIONAL FGD SYSTEMS

UNIT DESCRIPTION

LOUISVILLE GAS 4 ELECTRIC
CANE RUN 4
RETROFIT 188MM (GROSS)
STARTUP 8/76 188MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6X
LOUISVILLE GAS ft ELECTRIC
CANE RUN 5
RETROFIT 200MU (GROSS)
STARTUP 12/77 200MVI (ESC)
COAL
3.75 XS BITUMINOUS
LIKE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: i.sx
LOUISVILLE GAS I ELECTRIC
CANE RUN 6
RETROFIT 299MW (GROSS)
STARTUP 4/79 299MW (ESC)
COAL
4.80 XS BITUMINOUS
DUAL ALKALI
THYSSEN/CEA
ENERGY CONSUMPTION: l.OX
LOUISVILLE GAS t ELECTRIC
MILL CREEK 1
RETROFIT 358MM (GROSS)
STARTUP 12/80 358MM (ESC)
COAL
3.75 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: i.4X
LOUISVILLE GAS & ELECTRIC
MILL CREEK 3
NEW 427MU (GROSS)
STARTUP 8/78 427MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENESGY CONSUMPTION: *«»*/£
LOUISVILLE GAS t ELECTRIC
PADDY'S RUN 6
RETROFIT 72MU (GROSS)
STARTUP 4/73 72MW (ESC)
COAL
2.50 XS BITUMINOUS
LIME
CCM2USTIOH ENGINEERING
ENERGY CONSUMPTION: 2.8X

COST DESCRIPTION

CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KM(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST. 9
FIXED CHARGES. 9
TOTAL ANNUAL. MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWH< YEAR >
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KM(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES. 9
TOTAL ANNUAL, MILLS/KMH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL. 9
TOTAL CAPITAL. 9/KH(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST. 9
FIXED CHARGES. 9
TOTAL ANNUAL, MILLS/KWHt YEAH )
CAPACITY FACTOR. X
DIRECT CAPITAL. 9
INDIRECT CAPITAL. 9
OTHER CAPITAL. 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL. 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWW YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL. 9/KM(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWHt YEAR)

REPORTED

47
10847000.
1800000.
**********
66.6(1975)
96C301.
**********
**********
1.3(1978)
SO
**********
**********
**********
68.8(1977)
763443.
**********
**********
.9(1978)
***
**********
**********
**********
71.5(1973)
**********
**********
**********
******( 1978)
**»
17661500.
**********
**********
55.0(1980)
**********
***********
**********
******( Q )
70
**********
**********
****«»*»**
42.6(1977)
321463.
**********
**********
1.3(1978)
***
**********
**********
**********
61.7(1973)
**********
**********
**********
****»»( 1978)

ADJUSTED

65
**********
**********
**********
115.2(1931)
2853600.
373300.
3190500.
6.2(1981)
65
**********
**********
**********
102.4(1931)
C050900.
283100.
3450300.
5.3(1931)
65
**********
**********
**********
87.8(1981)
5465000.
691300.
4716700.
7.2(1981)
65
**********
**********
**********
60.4(1931)
' 3925700.
433300.
3748100.
4.3(1981)
65
**********
**********
**********
66.0(1931)
4335300.
247000.
5053900.
4.0(1981)
65
**********
**********
**********
133.0(1981)
2201900.
562400.
1666000.
12.2(1981)

c,.>rn. „.,,., E.j
AC-UST30
65
**********
*»«-• r*v***
*****»•**>*»
*»*»*•«( Q)
**********
**********
**********
**«***( Q)
65
**********
**********
**********
******( Q )
************
**********
ft*********
*»****( 0 )
65
**********
**********
**********
*****»( Q)
**********
**********
**********
******( Q)
65
**********
**********
**********
******( Q)
**********
**v**»**»*
**********
******( 0 )
65
**********
**********
**********
******( o )
***********
**********
**********
******( 0 )
65
**********
**********
**********
******( Q)
*******)>**
**********
**********
»*****( Q)
                        «**««»   INDICATES COST FIGURES NOT YET AVAILABLE

                                           A-  26

-------
                    EPA UTILITY FGD SURVEY: OCTOBER - DECEASES 1931
                 SECTION A-l
       COSTS  FOR OPERATIONAL FGD SYSTEMS

UNIT DESCRIPTION

MINNESOTA POWER & LIGHT
CLAY BCSWELL 4
LICU CR&MLJ r Rcn^Q i
ntH SanrH 1 unU39 J
CTl DTI ID &./Afl &TRMU f P^f* \
3 1 AK 1 U" H/OU **y 3riM 1 C9U 1
COAL
.94 xs SUSBITUMINCUS
LIME/ALKALINE FLYASH
PEAS03Y PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.3X
HIU'iKOTA POWER
MILTON R. YOUNG 2
NEW 440MW (GROSS)
STARTUP 9/77 ISSM'rl (ESC)
COAL
.70 XS LIGNITE
LIKE/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 1.6X
MONCNGAHELA POWER
PLEASANTS 1
NEH 668MVI (GROSS)
STARTUP 3/79 668MV4 (ESC)
COAL
3.00 XS BITUMINOUS
LIME
BAECOCK ( UILCOX
ENERGY CONSUMPTION: MMHfX
MONONGAHELA POWER
PLEASANTS 2
MEM 668MU (GROSS)
STARTUP 10/80 668MW (ESC)
COAL
3.00 XS BITUMINOUS
LIME
BABCOCK t MILCOX
ENERGY CONSUMPTION: «***X
MONTANA POWER
COLSTRIP 1
NEW 360MW (GROSS)
STARTUP 9/75 360MW (ESC)
COAL
.77 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 3.3X
MONTANA POWER
COLSTRIP Z
HEM 360MW (GROSS)
STARTUP 5/76 360MW (ESC)
COAL
.77 XS SU2BITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 3.3X

COST DESCRIPTION

CAPACITY FACTOR, X
DIRECT CAPITAL. *
TJJTtTDCPT PAQTTAI ft
IHUXKCI* 1 vArl 1 ALt 9
flTWJTD CADTTAI A.
U 1 ilCK \.Arl 1 AL f 9
TOTAL CAPITAL. S/KWCYEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KHH( YEAH )
CAPACITY FACTOR. X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL. S/KU(YEAR)
DIRECT ANNUAL. $
OVERHEAD COST, $
FIXED CHARGES, »
TOTAL ANNUAL, MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, »
OTHER CAPITAL, $
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST. *
FIXED CHARGES. $
TOTAL ANNUAL. MILLS/KWH( YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL. »
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL. «/KM(YEAR)
DIRECT ANNUAL. *
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL. MILLS/KWHl YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, »/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, »
TOTAL ANNUAL, MILLS/KWHl YEAH )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, t
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES. 4
TOTAL ANNUAL. MILLS/KWHt YEAR)

REPORTED

ao
e&oooooo.
ft Jt^lf Mff# V4tV

173.8(1979)
<«•*<«*:«*#*»«
»*»**»««**
**********
5.4(1980)
40
30066200.
14052400.
**********
100.3(1976)
754445.
***********
*****»*»**
.5(1978)
70
**********
**********
**********
119.1(1978)
5532800.
**********
**********
1.5(1980)
70
**********
**********
**********
119.1(1978)
5532800.
**********
**********
1.5(1980)
71
**********
**********
**********
101.4(1975)
**********
**********
•tttfKVW***
3.0(1979)
71
**********
**********
**********
101.4(1975)
**********
**********
**********
3.0(1979)

A3.,bs :ED

65
€6530300.
1 S C^iC^fl
15 3 0*0 UU •
1S4. 4(1981)
15544100.
7123COO.
17705200.
14.1(1981)
65
**********
**********
***»*»****
155.711981)
C481COO.
616100.
11868900.
6.4(1981)
65
**********
**********
***»**»*»*
152.9(1981)
8857900.
972800.
181206CO.
7.9(1981)
65
**********
**********
KMMVftNt**
152.9(1981)
6857900.
972800.
18120600.
7.9(1981)
65
**********
**********
**********
145.9(1981)
5275300.
1265050.
9101700.
8.3(1981)
65
**********
**********
**********
145.9(1931)
5275300.
1265050.
9101700.
8.3(1981)

STAI 3£'3IZEO
ADJ'JSTsO
65
«*•»**«««*«

*»*)>*•*( 0)
y»**4-**4*«
****•****•«»
**•«*•**»*»*
»**.**.*( Q )
65
**********
**********
***********
**•»-**( Q)
*•»*•«**•**#*
**********
**4«#**4**
******( Q )
65
**********
**********
**********
******( Q)
***»**«*»*
*»******!»*
**********
*****»( Q)
65
**»****»4*
********"»»
**********
*»****( Q)
*-«**»*****
**********
**********
******( Q)
65
****<•****»
**********
**********
**«**•*( Q )
»«»»****«*
***********
**********
*****«( o)
65
**********
**********
**********
******( 0 )
**********
**********
**********
***»*-4( g )
******   INDICATES COST FIGURES NOT YET AVAILABLE

                   A-  27

-------
EFA UTILITY FGD S'JPVEY:  CCTC3ER - DECEMBER 1981
                                          SECTICN A-l
                               COSTS FOR OPERATIONAL FGD SYSTEMS

UNIT DESCRIPTION

NEVADA FOWE3
REID GARDNER 1
RETROFIT liSm (GROSS)
STARTUP 3/74 IZSK'J (ESC)
COAL
.53 XS BITUMIUQUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: **»»X
NEVADA POWER
REID GARDNER 2
RETROFIT 125MV4 (GROSS)
STARTUP 4/74 125MW (ESC)
COAL
.50 7.S BITUMINOUS
SODIUM CARBONATE
THYSSEH/CEA
ENERGY CONSUMPTION: **»*X
NEVADA POWER
REIO GARDNER 3
NEW 125MW (GROSS)
STARTUP 6/76 125MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
Tm SSEN/CEA
ENERGY CONSUMPTION: ****•/.
NCRTHERN INDIANA F'J3 SERVICE
DEAN H. MITCHELL 11
RETROFIT 116MU (GROSS)
STARTUP 7/76 115MW (ESC)
COAL
3.50 XS
UELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 12. ix
NCRTHERN STATES POWER
SHERtJRNE 1
NEW 740MW (GROSS)
STARTUP 3/76 74CMU (ESC)
COAL
.30 XS SUB3ITUMIKOUS
LIMESTONE/ALKALINE FLYASH •
COMBUSTION ENSINEERINS
ENERGY CONSUMPTION: 2.7X
NCRTHERN STATES POWER
SKERBURNE Z
NEW 740MW (GROSS)
STARTUP 3/77 740MW (ESC)
COAL
.80 XS SUSBITUMIMOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.7X

COST DESCRIPTION

CAPACITY FACTOR, X
DIRECT CAPITAL. »
INDIRECT CAPITAL, *
OTHER CAPITAL. *
TOTAL CAPITAL, $/KU( YEAR )
DIRECT ANNUAL. $
OVERHEAD COST, *
FIXED CHARGES. 4
TOTAL ANNUAL. MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, $
OTHER CAPITAL, »
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, *
OVEPHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL. *
INDIRECT CAPITAL, *
OTHER CAPITAL, «
TOTAL CAPITAL, «/KH(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWW YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, *
OTHER CAPITAL. S
TOTAL CAPITAL, $/KH(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, «/KU(YEAR)
DIRECT ANNUAL. *
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHI YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL. $
OVERHEAD COST, *
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHt YEAR )

REPORTED

56
2681660.
2681715.
**********
42.9(19731
251514.
**********
«***M*M«V*
.5(1978)
56
2681660.
2681715.
**********
42.9(1973)
251514.
**********
***** *****
.5(1978)
59
**********
a*********
**********
100.8(1975)
131824.
**********
****»**«*«
.2(1978)
23
11951830.
6240210.
***K*»***«
157.4(1976)
665890.
«**K»N**4*
***«*«**»«
13.0(1978)
61
34982020.
r*
87.1(1931)
1487650.
03550.
2031250.
5.8(1981)
65
**««****»*
***********
***«»»**»»
87.1(1981)
1487650 .
9S550.
C031C50.
5.8(1931)
65
**********
**********
**********
150.9(1981)
1317125.
50530.
3269508.
7.4(1981)
65
**********
»*>•*****»»
**********
254.6(1981)
1793207.
697816.
8638236.
20.8(1981)
65
72507042.
22207992.
**********
102.6(1981)
6219212.
**********
12798<»82.
5.4(1981)
65
72507042.
22207992.
**********
102.6(1981)
8219212.
**********
12798982.
5.4(1981)

STAf.2A-2:ZS3
A3 JUSTED
£5
«*»V*.4»**t»
»»*<«>» -4 -.•»•**
»*•*••»****•«
*•*•****( 0)
***»»•**»**
«*»****«**
**********
***•**»( 0)
65
**********
**********
*****.«*»**
****#«( Q)
**********
********-*
«****•«****
*«****( Q)
65
**********
**********
**********
******( Q)
**********
**********
**********
******( 0)
65
**********
***********
**********
*»*»**( Q)
***********
**********
**********
******( 0)
65
**********
**********
**********
**•«***( Q)
**********
**********
**********
*****»( 0 )
65
**********
**********
**********
******( Q)
**********
**********
**********
******( 0 )
                        ******   INDICATES COST FIGURES NOT YET AVAILABLE

                                           A-  28

-------
                     EPA UTILITY F6D SUBVEY:  OCTOBER - OECEKSER 1961
                  SECTION A-l
       COSTS FOR OPERATIONAL FGD SYSTEMS

UNIT DESCRIPTION
PACIFIC POWER 1 LIGHT
Jin EHICGER 4
NEW 550MVI (GROSS)
5TAPTTIP 9V7Q 55QPU fF^n
COAL
56 XS SUBBITUHINOUS
SODIUM CARBONATE
AIR CORRECTIOtl DIVISION, UOP
ENERGY CONSUMPTION: .27.
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
NSU 917MH ( GROSS 1
STARTUP 12/75 917MH (ESC)
COAL
3.00 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 6. OX
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
NEW 917HW (GROSS)
STARTUP 7/77 917KW (ESC)
COAL
3.00 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 6. OX
PENNSYLVANIA POWER
ERUCE MANSFIELD 3
NEW 917MU (GROSS)
STARTUP 6/60 917MW (ESC)
COAL
3.00 XS
LIME
M.W. KELLOGG
ENERGY CONSUMPTION: «**«x
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN I
RETROFIT 361MU (GROSS)
STARTUP 4/78 361MW (ESC)
COAL
.SO XS SUB3ITUMINOUS
UELLMAN LORD
DAVY (1CKEE
ENERGY CONSUMPTION: 4.4X
PUBLIC SERVICE OF HEW MEXICO
SAN JUAN 2
RETROFIT 350MU (GROSS)
STARTUP 8/78 35QMW (ESC)
COAL
.SO XS SUBBITUMINOUS
UELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 4.6X

COST DESCRIPTION
CAPACITY FACTOR i X
DIPECT CAPITAL, $
INDIRECT CAPITAL, *
TOTAL CAPITAL. $/XW«»tt»4X»
K»
-------
EPA UTILITY FC-D SURVEY: CCTGSER - DECEMBER 1981
                                          SECTION A-l
                               COSTS FOR OPERATIONAL FGD SYSTEMS

UNIT DESCRIPTION

PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
NEW 534MW (G90SS)
STARTUP 12/79 534MW ( ESC J
COAL
.so ;:s SUSBITUMINOUS
HELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 3.6X
SALT RIVER PROJECT
CCRONAOO 1
MEW 350MH (GROSS)
STARTUP 11/79 280MU (ESC)
COAL
.50 XS SUSBITUMINOUS
LIMESTONE
M.U. KELLOGG
ENERGY CONSUMPTION: *.3x
SALT RIVER PROJECT
CO-OMADO 2
NEU 350MW (GROSS)
STARTUP 7/80 280MW (ESC)
COAL
.50 XS SUBBITUMINOUS
LIMESTONE
M.U. KELLOGG
ENERGY CONSUMPTION: 4.3X
SOUTH CAROLINA PUBLIC SERVICE
UINYAH 2
NEW 280MM (GROSS)
STARTUP 7/77 140MH (ESC)
COAL
1.10 XS BITUMINOUS
LIMESTONE
BABCOCK t UILCOX
ENERGY CONSUMPTION: 1.1X
SOUTH CAROLINA PUBLIC SERVICE
UINYAH 3
NEU 280MH (GROSS)
STARTUP 5/80 280MH (ESC)
COAL
1.10 XS
LIMESTONE
BABCCCK & UILCOX
ENERGY CONSUMPTION: 2.1X
SOUTH MISSISSIPPI ELEC PUR
R.O. MORROU, SB. 1
NEU 200KW (GROSS)
STARTUP 8/78 124MW (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
ENVXRONEERINS. RILEY STOKER
ENERGY CONSUMPTION: 5.5X

COST DESCRIPTION

CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, */KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, $
FIXED CHARGES. •
TOTAL ANNUAL, MILLS/KMH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, *
INDIRECT CAPITAL, *
OTHER CAPITAL. *
TOTAL CAPITAL, «/KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, 4
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, *
INDIRECT CAPITAL, *
OTHER CAPITAL, 9
TOTAL CAPITAL. */KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, $
TOTAL ANNUAL. MILLS/KMH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, *
OTHER CAPITAL, 9
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, *
FIXED CHARGES, *
TOTAL ANNUAL. MILLS/KWW YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL. *
INDIRECT CAPITAL, f
OTHER CAPITAL. *
TOTAL CAPITAL, 9/KW(YEAH)
DIRECT ANNUAL, *
OVERHEAD COST, 9
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KUH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, *
INDIRECT CAPITAL, 9
OTHER CAPITAL. *
TOTAL CAPITAL, »/KU(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, «
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KUHIYEAH )

REPORTED

***
98790000.
**********
»"•**»* *•**•»
185.0(1978)
**********
**********
**********
»«»»»*( Q)
50
1889QOOO.
13725500.
**********
7« 4(1979)
1738000.
***«****«*
*»«**»*»*»
.8(1980)
50
18899000.
13725500.
««***»**»*
79.4(1979)
1738000.
**********
**********
.8(1980)
60
6026098.
520000.
100000.
23.7(1976)
527000.
**MI>H«****
**********
.3(1978)
***
10742500.
•ON*******
**********
38.4(1979)
yt********
**********
**********
******( Q )
***
10250000.
646000.
**********
53.7(1975)
**********
**********
**********
»»»*»«»( 1978)

ADJUSTED

65
*****»*»**

65
**********
**********
**********
******( Q)
**********
**********
**********
»•*»*>*( 0 )
65
**********
**********
**********
«»#**»( 0 )
*»*•«»*****
**Xrf*»*N*«
**********
***•***( Q )
65
**********
**********
**********
******( Q)
**********
**********
**********
***«*«( 0 )
65
**********
**********
**********
******l 0 )
***««»»***
**********
**********
**#***( 0 )
65
*»«***«*«*
**********
**********
******l Q )
**********
**********
**********
******( 0 )
                        *»***«   INDICATES COST FIGURES NOT YET AVAILABLE

                                           A-  30

-------
                     EPA UTILITY FGO SURVEY:  OCTC3ER - DEC  :ES 1931
                  SECTION A-l
       COSTS FOR OPERATIONAL FGD SYSTEMS

U1IT DESCRIPTION
SCUTH MISSISSIPPI ELEC FWH
R.D. MCRKO'J, SR. 2
STARTUP 6/79 124KW (ESC)
CCAL
1.30 XS BITUMINOUS
LIMESTONE
ENVIHONEERING, RILEY STOKER
ENERGY CONSUMPTION: 5.5X
SOUTHERN ILLINOIS POKER
MARION 4
NEU 173MW (GROSS)
STARTUP 5/79 173MW (ESC)
COAL/REFUS
3.75 XS BITUMINOUS
LIMESTONE
B« nrnrv • UTI CflY
*OUUUf\ a Wl LIUA
ENEPGY CONSUMPTION: 2.3X
SOUTHERN INDIANA GAS ft ELEC
A.B. BROWN 1
NEU 265MW (GROSS)
STARTUP 3/79 265MW (ESC)
COAL
3.35 XS BITUMINOUS
DUAL ALKALI
FHC
ENERGY CONSUMPTION: .ex
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
HZU 194MM (GROSS)
STARTUP 4/77 194MU (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 4.6X
SPRINGFIELD MATER, LIGHT t PUR
DALLMAN 3
NEU 20SMU (GROSS)
CTAPTtlD 1 ?yAO 1 A^MU 1 F*)<*.**( oi
65
**********
**********
**********
*#****( Q)
**•*•*•******
**********
******( 0)
65
*K>4»K»**)t
**********
**********
**»***( Q)
**********
**********
ttK********
*»****{ 0)
65
**********
**********
**********
******( Q)
**********
**********
**********
******( Q)
65
**********
**********
******( Q)
y**U4«.«*lt*
(*t«»
**********
******( 0,
65
**********
**********
**********
******( Q)
tt*********
**********
**********
******( 0)
******   INDICATES COST FIGURES NOT YET AVAILABLE

                   A-  31

-------
EPA UTILITY FGO SURVEY:  OCTOBER - DECEMBER 1981
                                          SECTION A-l
                               COSTS FOR OPERATIONAL FGO SYSTEMS

UNIT DESCRIPTION

TENNESSEE VALLEY AUTHORITY
WIDCWS CREEK 8
RETROFIT 550MW (GROSS)
STARTUP 5/77 SSOMH (ESC)
COAL
3.70 XS BITUMINOUS
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION: 4.7X
TEXAS UTILITIES
MONTICELLO 3
NEU flOOMM (GROSS)
STARTUP 5/78 800MVI (ESC)
COAL
1.50 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ****•/.
UTAH POKER & LIGHT
HUNTER 1
NEW 400MW (GROSS)
STARTUP 5/79 360MU (ESC)
COAL
.55 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: «»*«X
UTAH POWER I LIGHT
HUNTER 2
NEW 400MW (GROSS)
STARTUP 6/80 360MM (ESC)
COAL
.55 XS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: »»»*•/.
UTAH POWER I LIGHT
HUNTINGTON 1
NEW 430MW (GROSS)
STARTUP 5/78 366MW (ESC)
COAL
.55 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 1.6X

COST DESCRIPTION

CAPACITY FACTOR f X
DIRECT CAPITAL. 9
INDIRECT CAPITAL. 9
OTHER CAPITAL. $
TOTAL CAPITAL. $/KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, $
FIXED CHARGES. »
TOTAL ANNUAL, MILLS/KWH( YEAH )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, S/KUCYEAR)
DIRECT ANNUAL. «
OVERHEAD COST, $
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KUH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, $
OTHER CAPITAL, *
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, 9
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, »
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL. niLLS/KUH( YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, $
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWHf YEAR )

REPORTED

41
**********
**********
**********
87.1(1976)
**********
*****«»***
*»*****»»*
7.8(1978)
*»*
**********
**«»*»****
*»**«»«•«»
25.0(1978)
*» *3»*k«**lt
**********
**********
*»****( Q )
***
H**«»*»»*»
«W**»*4**»
**********
56.7(1978)
**»**»****
**«**»*«*»
M*M*tt«W»*«
»*»***( 1978)
96
**»******»
»»*»•»****»
»»»M**KWK*
60.2(1979)
**********
*»*******«
**********
.3(1930)
80
**********
**********
**********
63.0(1977)
2946400.
**********
**********
1.3(1978)

ADJUSTED

65
**tt**W*«*»
a*********
**********
153.K1931)
5159337.
»»«*******
16219666.
7.3(1981)
65
**********
**********
**********
**»***( Q)
*<«*«««»«»«
****)C«ft4«**K*
**********
-»»»*t*( Q)
**********
**********
**********
******( 0 )
65
**********
**********
**********
******( Q)
**********
**********
**********
******( Q )
65
**********
**********
**********
******( 0 )
*
**********
wowvvwt**
»»«**>»( 0 )
65
«***««***»
*»lt*
-------
                     EPA UTILITY F60 SURVEY: OCTOBER - OECErSEH
                  SECTION A-2
       COSTS FOR NON-OPERATIONAL FGD SYSTEMS

UNIT DESCRIPTION

BASIN ELECTRIC POWER
ANTELOPE VALLEY 1
MEM 440MU (GROSS)
STARTUP 10/03 440MW (ESC)
COAL
.68 XS LIGNITE
LIME/SPRAY DRYING
JOY MFG/NIKO ATCMIZER
ENERGY CONSUMPTION: ****•/.
BASIH ELECTRIC PCUER
ANTELOPE VALLEY 2
MEW 440tfJ < GROSS)
STAPTUP 10/85 440MW (ESC)
COAL
.63 XS LIGNITE
LIME/SFPAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: »*»»X
BASIN ELECTRIC POKER
LARAMIE RIVER 3
HEM S70HW (GROSS)
STARTUP 11/82 570HW (ESC)
COAL
.54 XS SUBBITUMINDUS
LIME/SPRAY DRYING
BAB COCK S UILCOX
ENERGY CONSUMPTION: »*»»x
BOSTON EDISON
MYSTIC 6
RETROFIT 150MH (GROSS)
STARTUP 4/72 150MW (ESC)
OIL
Z.OO XS NO. 6
MAGNESIUM OXIDE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: *«**X
COMMONWEALTH EDISON
MILL COUNTY 1A
RETROFIT 167MH (GROSS)
STARTUP 2/72 167MM (ESC)
COAL
1.50 XS
LIMESTONE
BABCGCK & MILCOX
ENERGY CONSUMPTION: 4.2X
DETROIT EDISON
ST. CLAIR 6A
RETROFIT 325MU (GROSS)
STARTUP 6/75 163MI4 (ESC)
COAL
.35 XS SUBBITUMINOUS
LIMESTONE
PEABCOY PROCESS SYSTEMS
ENERGY CONSUMPTION: 2.8X

COST DESCRIPTION

CAPACITY FACTOR • X
DIRECT CAPITAL i $
Tj-nTapfT TAPTTAI fi
XfiUAKCWI l.ArllMk, '
OTHER CAPITAL, 4
TOTAL CAPITAL, S/KW(YEAH)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHC YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, «
INDIRECT CAPITAL, 4
OTHER CAPITAL, $
TOTAL CAPITAL, 9/KkHYEAP)
DIRECT ANNUAL, *
OVERHEAD COST, $
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/XWHI YEAR 1
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, 9
TOTAL CAPITAL, S/KWCYEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES. 9
TOTAL ANNUAL. MILLS/KWW YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL. »
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KU(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWH( YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL. 4
INDIRECT CAPITAL. 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KU(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL. MILLS/KWHl YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL. 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL. 4
OVERHEAD COST, 4
FIXED CHARGES. 4
TOTAL ANNUAL, MILLS/KWHC YEAR)

REPORTED

75
**********
tt iMf 3Hf K IMMf It
**»««**»**
75.2(1991)
«»**«*****
*******»«»
»*****»»*»
.8(1961)
»HM
47960000.
«»»«»»«»*«
*»**tt**»*M
109.01 0)
1797596.
**********
** ********
.8(7800)
75
*****tH»***
**********
**»*»»****
83.0(1981)
»******«<(*
»********»
»**»**»***
.6(1981)
»**
««*««*«***
*»**«*****
*«M«M**)IH»
63.4(1972)
• IftifHWKKN*
»*»»*****»
»NN**N»IIII*
3.0(1974)
49
»»**»*****
»»******«*
»*M*K-4*II*»
113.0(1972)
**M **)>****
«***»*****
**********
13.1(1975)
***
**********
**********
«*»***i,***
80.3(1976)
**********
***»***»*»
**********
9.6(19761

ADJUSTED

65
**********
3f jtft 4(46 K H^Jf>******)>*
******* ***
***«**( Q )
65
**********
**********
**********
******( Q)
**********
**********
««»(«<(•(*»**
******( o )
65
**********
**********
**********
******( 0)
**********
**********
**********
*****»( Q)
65
**********
**********
**********
******( Q )
a*********
**********
**********
*****»( Q)
65
**********
**********
**********
******( o ]
**********
**********
**********
******( Q )

STiJOiFSISED
ASJ'JSTID
63
»*» ».*»>«•»»
)><•*- .-*<»*
••»*- -»C 0)
*»«*>*„***
*t*-»^*i.i**
**•»*»**-*•**
*.HV>H4>( 0 )
o5
**•»***•**•»*
*»»*,-«)(.*,*
****4,4«*«
*»****( 0|
**•»**•«»***
********-•*
**rf*
-------
EPA UTILITY FGD SURVEY:  OCTOBER - DECEMBER 1981
                                          SECTION A-2
                               COSTS FOR  NON-OPERATIONAL FGO SYSTEMS

UNIT DESCRIPTION

HCOSIER ENERGY
MEROM 1
NEU 490MU (GROSS)
STARTUP 5/82 441MU (ESC)
COAL
3.50 XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****•/.
ILLINOIS POWER COMPANY
U'COD RIVER 4
RETROFIT 110MM (GROSS)
STARTUP 9/72 110MM (ESC)
COAL
3.10 XS
CATALYTIC OXIDATION
MONSANTO ENVIRO CHEM SYSTEMS
ENERGY CONSUMPTION: ****•/.
LAKELAND UTILITIES
MCINTOSH 3
NEU 364KH (GROSS)
STARTUP 1/82 364MH (ESC)
COAL
2.56 XS BITUMINOUS
LIMESTONE
BABCOCK & UILCOX
ENERGY CONSUMPTION: »***•/.
MONTANA POUER
COLSTRIP 3
NEU 700MW (GROSS)
STARTUP 10/83 700MU (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: ****•/.
MONTANA PCUER
COLSTRIP 4
NEU 700MM (GROSS)
STARTUP 0/84 700MM (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: iHHWX
PHILADELPHIA ELECTRIC
EDOYSTONE 1A
RETROFIT 120MU (GROSS)
STARTUP 9/75 120MH (ESC)
COAL
2.60 XS BITUMINOUS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: ****X

COST DESCRIPTION

CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KUIYEAR)
DIRECT ANNUAL. 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KUW YEAR J
CAPACITY FACTOR. X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL. 9/KU(YEAR)
DIPECT ANNUAL. 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL. MILLS/KWH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL. 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL. MILLS/KKW YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KW(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES. 9
TOTAL ANNUAL. MILLS/KWH( YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWH(YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL. 9
OTHER CAPITAL. 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWHt YEAR )

REPORTED

***
24500000.
***«»**»»*
**********
50.01 0)
**********
**********
**********
******( 0 )
***
**********
**********
**********
82.5(1972)
**********
**********
**********
******( Q )
**»
11775400.
**********
**********
32. 4( 0)
****«**««*
**********
**********
******( o )
***
76643000.
**»*»«*««»
»*****«*«»
109.51 0)
**********
**********
**********
»*****( 0 )
*»«
70686000.
**********
**********
101.01 0)
**********
**********
**********
******( 0 )
65
*««****»»*
**»*«»»*»»
*«*****«*«
285.7(1973)
*«»**K*K»»
*»**«K*«tt»
**********
6.4(1979)

ADJUSTED

65
**********
**********
**********
******( Q)
**********
**********
**********
«*****( 0 )
65
***** *****
**********
**********
******! Q)
**********
**********
**********
******( 0 1
65
**********
**********
**********
****»*{ Q )
******»»**
**********
**********
*»»*»*( Q )
65
*»****»»««
**********
**********
******( o )
**********
**********
**********
******( Q )
65
**********
**********
**********
»»»*»*( Q)
«««*»K*4H>*
*«**«*****
**********
******l 0 )
65
«««>«Itlt***«
**********
**********
******( o )
***»**»»**
**********
**********
******( 0 )

STA.'Oi=3I2ED
ADJUSTED
o5
**********
**********
itM^voyvk^^
******•( 0 }
**********
***-***•***•*
**********
**+**»( 0 )
65
**#******#
**********
**********
*.***•<*( Q )
**********
**********
**********
******{ Q )
65
»«*****»**
**********
**********
**,****( 0 )
KM K* *«*»**
**********
**********
******( 0 )
65
****>«****»
**********
**********
******{ Q)
*•»»<»"»»»«»»
**********
**********
******( Q)
65
**********
**********
**********
******( Q)
M<(*<(K)f4)fl(M
**********
**********
******( Q)
65
**********
**********
**********
******( Q )
**********
**********
**********
******( o )
                        »•««•»    INDICATES COST FIGURES NOT YET AVAILABLE

                                           A-  34

-------
                     EPA UTILITY  FGD SURVEY: OC70SER  - DECEMBER 1931
                  SECTION  A-2
       COSTS FOR NON-OPERATIONAL  FGD SYSTEMS

UNIT DESCRIPTION

PUBLIC SERVICE OF COLORADO
VALMCNT 5 A
RETROFIT 166MW (GROSS)
STARTUP 10/74 166HVJ (ESC)
COAL
.70 XS SU33ITUMINCUS
LIMESTONE/ALKALINE FLYASH
UOP/PUBLIC SERVICE OF COLORADO
ENERGY CONSUMPTION: 3.6X
SOUTH CAROLINA PUBLIC SERVICE
CROSS 1
NEW 500MU (GROSS)
STARTUP 5/88 500MW (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: **»*X
SOUTH CAROLINA PUBLIC SERVICE
CROSS 2
NEW 500MW (GROSS)
STARTUP 11/83 500MH (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABOOY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****•/.
TENNESSEE VALLEY AUTHORITY
PARADISE 1
RETROFIT 704MW (GROSS)
STARTUP 0/83 704MW (ESC)
COAL
4.20 XS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ***»•/.
TENNESSEE VALLEY AUTHORITY
PARADISE Z
RETROFIT 704MU (GROSS)
STARTUP 0/83 704MU (ESC)
COAL
4.20 XS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: «»M*X

COST DESCRIPTION

CAPACITY FACTOR, X
DIPECT CAPITAL. S
INDIRECT CAPITAL, *
OTHER CAPITAL i $
TOTAL CAPITAL. S/KW( YEAR )
DIPECT ANNUAL, «
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, *
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, »/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWW YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL. *
OTHER CAPITAL, *
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST. $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHC YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL. $
INDIRECT CAPITAL, $
OTHER CAPITAL, *
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL. *
INDIRECT CAPITAL, 9
OTHER CAPITAL, *
TOTAL CAPITAL, */KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, *
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHt YEAR )

REPORTED ADJUSTED STA(OAR3:ZZ3
ADJUSTED
*»» 65 65
********** *****«*<"«* **.«.«*»*»<,«
********** ********** **********
37.0(1974) .«»*)«***( 0) <***',*{ 0)
********** *•«»•«****»* *»•••***•»***
********** ********** »**»**«***
********** ********** **********
******( 0) *»****( 0) ******( 0)
»*» 65 65
*«*****«*« ********** **!.*******
*»*»**#*** ****»**>«** XV********
********** ********** **********
40. 0( 0) »**»*»( 0) ««**•«•<( 0)
*»****x*** ********** **********
********** ********** »•*****»•***
********** ********** **********
******( Q) ******( Q) *****»( 0)
»** 65 65
*******»*» ********** **********
********** ********** **********
KM******** ********** **********
40. 0( 0) JHHHI1HK 0) »»<•**»( 0)
»»**»***»* ********** **********
*******),** ********** **********
********** ********** **********
***T«**( 0) ******( 0) ******( 0)
*** 65 65
52500000. ********** **********
********** ********** **********
********** ********** **********
74. 6( 0) »***»*( 0) «*****( 0)
******»»** ********** **********
********** ********** ***********
********** ********** **********
*«****( 0) ******( 0) ******( 0)
*** 65 65
52500000. ****»**»»» **********
********** ********** **********
********** ********** ***********
74. 61 0) ***«»*( 0) ****•*•*( 0)
********** ********** **>»*******
********** ********** **********
********** ********** **********
******( 0) ******( 0) **»***( Q)
******   INDICATES COST FIGURES NOT YET AVAILABLE

                   A-  35

-------
APPENDIX B




DEFINITIONS
   B-l

-------
                           DEFINITIONS
Boiler Commercial Service Date
Byproduct Nature
Commercial Service Date
  (FGD System)
Company Name
Disposal
Efficiency:
     Total Unit Design Particle
     Removal Efficiency
     Total Unit S02 Design
     Removal Efficiency
                               B-2
Date when boiler and auxiliary
equipment (including FGD sys-
tem for new boilers) has met
initial supplier guarantees
and begins to contribute elec-
trical power to the power
grid.

The nature (e.g. elemental
sulfur, sulfuric acid) and
disposition (e.g. stockpile on
site, marketed) of the end
product by systems that gen-
erate a saleable product.
Date when the FGD system suc-
cessfully completes compliance
testing and the utility is
satisfied that the system
meets supplier contractual
guarantees.

Name of corporation as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - as space permits.

Disposal method for throwaway
product systems producing
sludge including:  interim and
final disposal sites and
disposal type (minefill,
landfill, etc.)  as well as
disposal location and site
capacity.
The actual percentage of par-
ticulate matter removed by the
emission control system (me-
chanical collectors, ESP,  or
fabric filter and FGD)  from
the untreated flue gas.
The actual percentage of SO2
removed from the flue gas by
the FGD system.

-------
FGD Viability Indexes
     Availability Index
     Reliability Index
Several parameters have been
developed to quantify the vi-
ability of FGD system technol-
ogy.  Various terms such as
"availability," "reliability,"
"operability," and "utiliza-
tion" are used to accurately
represent the operation of any
FGD system during a given per-
iod.  The above-mentioned pa-
rameters are defined below and
discussed briefly.  The objec-
tives of this discussion are
to make the reader aware that
several different definitions
are being used and to select
appropriate parameters that
can be used for reporting pur-
poses so that reasonably con-
sistent comparisons can be
made.

Hours the FGD system is avail-
able for operation (whether
operated or not) divided by
hours in period, expressed as
a percentage.  This parameter
tends to overestimate the vi-
ability of the FGD system be-
cause it does not penalize for
election not to operate the
system when it could have been
operated.  Boiler downtime may
tend to increase the magnitude
of the parameter because FGD
failures generally cannot oc-
cur during such periods.

Hours the FGD system was oper-
ated divided by the hours the
FGD system was called upon to
operate, expressed as a per-
centage.  This parameter has
been developed in order not to
penalize the FGD system for
elected outages, e.g., periods
when the FGD system could have
been run but was not run be-
cause of chemical shortages,
lack of manpower, short dura-
tion boiler operations, etc.
The main problem in using this
                              B-3

-------
     FGD Operability Index
     FGD Utilization Index
End Product
     Sludge
formula is the concise deGermi-
nation whether or not the sys-
tem was "called upon to oper-
ate" during a given time per-
iod.  In addition, an undefined
value can result when the FGD
system is not called upon to
operate for a given period
(e.g., turbine or boiler out-
age when FGD system is avail-
able) .

Hours the FGD system was oper-
ated divided by boiler operat-
ing hours in period, expressed
as a percentage.  This param-
eter indicates the degree to
which the FGD system is actu-
ally used, relative to boiler
operating time.  The parameter
is penalized when options are
exercised not to use the FGD
system in periods when the
system is operable.  In addi-
tion, an undefined value can
result when the FGD system is
not called upon to operate 'for
a given period (e.g., turbine
or boiler outage when FGD sys-
tem is available) .

Hours that the FGD system op-
erated divided by total hours
in period.  This parameter is
a relative stress factor for
the FGD system.  It is not a
complete measure of FGD system
viability because the parameter
can be strongly influenced by
conditions that are external
to the FGD system  (e.g., in-
frequent boiler operation will
lower the value of the parame-
ter although the FGD system
may be highly dependable in
its particular application).
The SO2 removed from the flue
gas is not recovered in a us-
able or marketable form and
resulting sulfur-bearing waste
                               B-4

-------
     Recoverable Byproduct
Energy Consumption, %
Equivalent Scrubbed Capacity
  (ESC)
FGD Status:
     Category 1
     Category 2
     Category 3
     Cateogry 4
     Category 5
products must be disposed in
an environmentally acceptable
fashion.

The S02 removed from the flue
gas is recovered in a usable
or marketable form (e.g., sul-
fur, sulfuric acid, gypsum,
ammonium sulfate, sodium sul-
fate).

The percentage of gross unit
electrical generating capacity
consumed by the FGD system, as
defined by the following equa-
tion:

[Net MW w/o FGD - Net MW w/FGD]/
[Gross unit rating]
The effective scrubbed flue
gas in equivalent MW based on
the percent of flue gas scrubbed
by the FGD system.
Operational - FGD system is in
service removing SC-2.

Under construction - ground
has been broken for installa-
tion of FGD system, but FGD
system has not become opera-
tional.

Planned, Contract Awarded -
contract has been signed for
purchase of FGD system but
ground has not been broken for
installation.

Planned, Letter of Intent
Signed - letter of intent has
been signed, but legal con-
tract for purchase has not
been awarded.

Planned, Requesting/Evaluating
Bids - bid requests have been
released but no letter of in-
tent or contract has been is-
sued.
                              B-5

-------
     Category 6



     Category 1


     Category 8
Fuel Firing Rate - TPH
Initial Start-Up (FGD System)
New
Plant Name
Process Additives
Process Type
Considering only FGD Systems -
an FGD system is proposed as a
means to meet an SO2 regulation.

Considering an FGD system as
well as alternative methods.

Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended in-
definite period of time.

Boiler fuel firing rate in
terms of tons per hour at max-
imum continuous load.

Date when flue gas first
passes through any component
of the FGD system (or is
scheduled to do so).

FGD unit and boiler were de-
signed at the same time or
space for addition of an FGD
unit was reserved when boiler
was constructed.

Unit identification as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - or as indicated by
utility representative for in-
stallations in planning stages.

A chemical compound or element
which is added to the process
or normally found with the
main process reagent in small
quantities (e.g., Mg, adipic
acid) to promote improved
process operation (e.g., scale
reduction, increased 502
removal efficiency).

Company name if process is
patented.  Generic name if
several companies have similar
processes  (e.g., Lime, Lime-
stone, Wellman Lord, Thorough-
bred 121) .
                               B-6

-------
Regulatory Class
Retrofit
SO2 Removal Mode
Spare Capacity Index - %
Spare Component Index
System Supplier
Total Controlled Capacity
  (TCC)
A.   Unit(s) subject to Federal
     New Source Performance
     Standards (NSPS) promul-
     gated in June 1979.

B.   Unit(s) subject to Federal
     New Source Performance
     Standards (NSPS) promul-
     gated in December 1971.

C.   Unit(s) subject to stan-
     dard (s) more stringent
     than NSPS (6/79).

D.   Unit(s) subject to stan-
     dard (s) more stringent
     than NSPS (12/71), but
     not more stringent than
     NSPS (6/79)

E.   Unit(s) subject to stan-
     dard (s) equal to or less
     stringent than NSPS
     (12/71).

FGD unit will be/was added to
an existing boiler not specif-
ically designed to accommodate
FGD unit.

The manner in which the SO2
from the flue gas is collected,
e.g., wet scrubbing, spray
drying, dry adsorption.

The summation of the individ-
ual component capacities (%)
minus 100%.

The equipment spare capacity
index (%) divided by the indi-
vidual component capacity (%).

A firm that fabricates and
supplies flue gas desulfuriza-
tion systems.
The gross rating  (MW) of a
unit brought into compliance
with FGD, regardless of the
                              B-7

-------
                                   percent of  flue gas treated at
                                   the facility.   In the case of
                                   prototype and  demonstration
                                   FGD systems, this figure will
                                   be identical to the Equivalent
                                   Scrubbed Capacity rather than
                                   the gross unit rating if the
                                   system is not  meant to bring
                                   the facility into compliance
                                   with SC>2 emission standards.

Unit Rating
     Gross                         Operational -  Maximum contin-
                                   uous gross  generation capacity
                                   in MW; Preoperational - maxi-
                                   mum continuous design genera-
                                   tion capacity  in MW.

     Net w/FGD                     Gross unit  rating less the en-
                                   ergy required  to operate
                                   ancillary station equipment,
                                   inclusive of emission control
                                   systems.

     Net w/o FGD                   Gross unit  rating less the en-
                                   ergy required  to operate
                                   ancillary station equipment,
                                   exclusive of emission control
                                   systems.
                               B-8

-------
      APPENDIX C




TABLE OF UNIT NOTATION
         C-l

-------
                                TABLE OF UNIT NOTATION
Classification
Area
Concentration
Flow
Heat Content
Length
L/C Ratio
Haas/Weight
Pressure
Temperature
Volume
English Unit
Acre
Square foot
Grains per standard
cubic foot
Parts per million
Pounds per million
Btu
Actual cubic feet
per minute
Gallons per minute
Pounds per minute
Ton per day
Ton per hour
Btu per pound
Foot
Inch
Mile
Gallons per
thousand actual
cubic feet
Pound
Ton
Inches of water
Degree Fahrenheit
Cubic feet
Acre-feet
Symbol
acre
ft2
gr/scf
Pl» fi
lb/10 Btu
ftj/min
(actual)
gal/min
Ib/min
t/day
t/h
Btu/lb
ft
in
mi
gal/1000
(actual)
Ib
t
in. 11^0
•F
ft1
Acrc-ft'
Survey Report
Notation
ACRE
SO -FT
GR/SCF
PPM
LB/NMBTU
ACFM
GPH
LB/MIN
TPD
TPH
BTU/LB
FT
IN
MI
GAL/1000ACF
1.B
T
IN. HjO
F
CU.F
ACRE- FT
ASTM/SI Unit
Square meter
Square meter
Grams per cubic meter
Parts per million
Nanograms per Joule
Cubic meters per
second
Liters per second
Kilogram per second
Metric ton per day
Metric ton per hour
Joules per
gram
Meter
Centimeter
Kilometer
Liters per cubic
meter
Kilogram
Meqagran
Kllopascal
Degree Celsius
Cubic meter
Cubic meter
Symbol
"2
M*
ppm
ng/J
liter/s
kg/s
M t/d
H t/h
J/g
m
cm
km
liter/m1
kg
Mg
kPa
•C
»J
Survey Report
Notation
SO.M
SQ.M
G/CU.H
PPM
NG/J
CU.M/S
LITER/S
KG/S
M T/D
M T/H
J/G
M
CM
KM
LITER/CU.M
KG
HG
KPA
C
CU.M
CU.M
o
K)

-------
        APPENDIX D
FGD PROCESS FLOW DIAGRAMS
           D-l

-------
o

NJ
                                                                                                          UWSTOM StUMT
                                                                                                            ID Mil 1
                                                       Alabama  Electric,
                                        Simplified Process  Flow Diagram for Tombigbee 2 and  3

-------
V
Ul
                              SINCLC LOUVER
                                 DAMPER
                                            DOUBLE LOUVER
                                               DAMPER
                                                                      STACK
                              1.0. FAN
       . TO DISPOSAL POND
DOUBLE-BLADCO
GUIUOTINE
DAMPER



r — ]
*\

\
	 -|
LIQUID
     TO PROCESS
     SEAL HATER
    (SERVICE MATER)
    TOTAL PROCESS
    MAKE-UP WATER
   (COOLING TOWER
      ILOUOOUN)
                                                                                                                                     DISTRIBUTOR
                                                                                                                                                LIMESTONE
                                                                                                                                               STORAGE UN
                                                                                                                                                    MILL
TO UNIT NO. 3
FROM UNIT NO. 3
                                                                -» TO UNIT NO. 3
                                              Arizona  Electric  Power  Coop,  Apache 2 and  3
                                                             Process  Flow Diagram

-------

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                                    Arizona  Public Service, Cholla 1:
                                      Simplified Process Flow Diagram

-------
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                    Arizona Public Service, ChoHa  2:
                     Simplified Process Flow Diagram
                                     D-5

-------
o
at
                                             Central  Illinois Light,
                                 Simplified Process Flow  Diagram of Duck Creek  1
                                     Power Plant and  Emission Control System

-------
o
-J
            1 BOOSTER FAN
            2 CHLORIDE/FLVASH PRECOOLER
            3 FlYASH THICKENER
            4 ABSORBER
            S NEUTRAL 17ER
            6 REACTOR-CLARIFIER
            7 CAUSTICIZCRS
            8 THICKENER
            9 HORIZONTAL BELT FILTER
           10 REHEAT FACILITY (EXPERIMENTAL)
                                                                         «||SODA ASH||
                                                                           (MAKEUP)
                                           Central  Illinois  Public Service,  Newton  1:
                                Simplified Process  Flow Diagram Showing One of Four  Absorbers

-------
      HfKEUP M»TE«

      (POND MUTER)
                                                                       TO STACK - FlOt 6ASE5



                                                                    HIST ELIMINATOR
0
 I
03
  TO OTHER

RECYCLE TftNK
                                                                                          • OVERFLOW
                                                                                           TO ASH POND

                                                                                            FROM OTHER
                                                                                          - RECYCLE TANK
                                                                                                                              •• TO IUCS
                                 Columbus  and Southern Ohio Electric, Conesville 5  and  6:
                                   Simplified Process  Flow Diagram  for a  Given  Module

-------
                                 To Stock
D
Reaction Tank
  In-Tank
                     From
                  Precipitator
                                                                            Flyash Silo
                                                                                         Lime Silo
                                                               Flyash Wet'G
                                                                  Tank
                                                                        Lime
                                                                 Feed Pumps
                                                                                  Lime
                                                                                Feed Tank
  Strainer
                         To Disposal
                                 Cooperative Power Association, Coal Creek 1 and 2:
                                          Simplified Process Flow Diagram

-------
 I
I-1
o
                      Flue gas
                    from boilers
        Mnkeup from
          overflow
Sproy
waler gos
                                          Adjustable
                                          .  throat
                                            dampers
                                                                                          Fuel  Combus I ion
                                                                                           oil    oir
                                               Damper
                                         ">»— operator
                                               housing
                                                 eliminator
                                                            To thickener
pumps
Bleed to
thickener •*—
nd clorifier
To thickener

XX Recycle
pump
(rough K

Service woler


Lime slurry feed line

.'..

Lime
sloroge
silo
\=2

rolor
<;
r-— c
i
j. s
Dy£oss_^_

-------
D
                                             1ST STAGE
                                             ADJUSTABLE VENTURI
                                             FOR FLY ASH/S02
                CaS03/S04
                FLY ASM SLURRY
                           TO
                      STABILIZATION
                       FACILITIES
                                                               S02  ABSORBER SCRUBBER
                           RECYCL :  RETURN  SYSTEM
              n^
'THICKENER     ,|  -
                                    Duquesne Light, F. R. Phillips FGD System:
                                                 General Diagram.

-------
                                                                                         fBOM DISPOSAL POHD
D
 I
H
to
SURGE
TANK
(EXISTING
K-103 1 V-103
EPRI SfST.
                  FLANGED
                CONNECTION TO \—;
                CIHHVS DUCT
                                                                                                                           FILTER CAKE
                                                                                                                           MASH MATER
                                 SODA ASH
                                  TANK I
                                 AGITATO*
                                                                                                   REACTOR NO. 4
                                                                                                   AND AGITATOR
                                                                                                            RfACIOR NO. 4
                                                                                                            ADO AGIIMOR
                                                         Gulf Power,  Scholz 1:
                                     Simplified  Process  Flow  Diagram  of the Demonstration
                                              Soda  Ash/Limestone Dual Alkali  Process

-------
                        AIR
                       HEATER
    MOBILE  PACKING
PRE-SATURATION SPRAY
           FLUE GAS IN
       TO STORAGE AREA
                                           CLEAN  GAS  OUT TO  STACK
                                                      MIST  ELIMINATOR
                                                            WASH
                                   WASTE
                                 LURRY TANK
                                                 PUMP
             Indianapolis Power and Light,  Petersburg  3:
      Simplified Process Flow Diagram for One  of  Four  Absorbers
                                D-13

-------
                                                      STACK
                                                                     I.D. FAN
a
H
              COAL
              SUPPLY
               FEEDER
           PULVERIZER
AIR HEATER
    DEMISTER
                                                            RECYCLE
                                                            PUMP

                               Kansas City Power and Light, Hawthorn Units 3 and 4:
                         Simplified Process Flow Diagram of the Lime Scrubbing Process
                                                    LIME
                                                    PREPARATION
                                                    TANK
                                                  CLARIF1ER
                                                 MAKE UP
                                                 WATER

                                            TO ASH DISPOSAL
                                            POND

-------
o

H1
Ul
                                                                                     STEAM COI
                                                                                     REHEATE
                                                                                             ABSORBER
                                                                                             RE£IRCULATION
                                                                                               PUMPS
                                                               POND
                                                              RETURN
                                                               PUMPS
 AIR
HEATERS        TO
         RECIRCULATI
             TANKS
                                                                        ENTURI
                                                                       SCRUBBER
  VENTURI
RECIRCULATION
PUMPS
                                                                                       HYDROCLONE
                                                                                       CLASSIFIER
                                                                                                    LIMESTONE
                                                                                                    BUNKER
                                                           LIMESTONE
                                                            SLURRY   _
                                                            STORAGE^
                       BOILER
                                                                                                               160 ACRE
                                                                                                             SETTLING POND
                                              WET BALL
                                                MILL
                                                Kansas  City  Power and  Light,
                                          LaCygne 1  FGD System:   General Diagram

-------
                                 FURNACE
                                                             DAMPERS
D

(-••
en
TWO PRECIPITATORS


           FOUR  I.D. FANS
                                                                            ONE
                                                                           STACK
WATER RETURN TO
 REACTION  TANKS
                                                                          BLEED PUMP

                                                     SPRAY' PUMP TTRANSFER TANK
                                 FOUR,
                               REACTION
                                 TANKS
                                                                               SLUDGE DISPOSAL
                                                                                    POND
                                            Kansas Power and Light,
                      Schematic of Jeffrey Steam Generator and Emission Control Equipment

-------
u»u> tot
                                 to 01KM
                               SOUMO NOQULC
                                                                                                  UNDERFLOW PUMPS
                                            Kansas  Power and Light,
                                       Lawrence 4  Operational  FGD  System:
                                        Simplified  Process Flow  Diagram

-------
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                               T«W 60 SOI IDS
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                                                               I	
                                                          Kansas Power,and Light,
                                                     Lawrence 5 Operational  FGD System:
                                                      Simplified Process Flow Diagram

-------
a
M
vo
                                                         (LECTRICAL
                                                         GENERATING
                                                         UNIT NO. I
ELECTRICAL
GENERATING
UNIT NO. 2
                                                                              SPARE
                                                                      SPARE
                                                     Kentucky Utilities,
                                   Green River FGD System:  General  Process Diagram

-------
                                                                   QUENCHER
                                                                               HIST
                                                                            ELIMINATOR
                                                                            (CHEVRON)
                         ELECTROSTATIC
                         PRECIPITATOR
               BOILER
                FLUE
                GAS
O

to
O
                                       Louisville Gas  and Electric, Cane Run  4
                                     FGD  System:   Simplified Process  Flow  Diagram

-------
                                   IN LINE REHEATER (STEAM)
to
H
              I.D. BOOSTER FANS


                TO STACK-
                                                   'MIST ELIMINATOR

                                                     ,9. HIST ELIMINATOR WASH
BULK ENTRAINHEHT
  StPARATOR
                                                                                         FROM LIME
                                                                                                   MAKEUP
                                                                                                    WATER
                        SPRAY PUMPS
                         IN-TANK STRAINER
                                                              TO DISPOSAL-
                                                                                          PUMPS
                                                                                UNDERFLOW PUMPS
                                                     M.E.WASM
                                            RECYCLE     RUMP
                                             TANK
                                           Louisville  Gas  and Electric, Cane Run 5
                                        FGD System:   Simplified  Process  Flow Diagram

-------
                                    COMBUSTION AH
> EXISTING < NO. 2 OIL
I CMIMIEY -"I

-1 	 1 	 ' - OIL FIRED
REHCATER 1
fi"Si_ I
^3-
FAN
" /•
II FROM ABSORBER A-201 . _ /
EXISTING!! BY CEA ("IVER WATER)
II * P* EMERGENCY WATER
JL JL FROM REMEATER SUPPLY
BOOSTER TO ABSORBER — 	 {
FAN A-201 I

* ,*\ T* w C^. A-J
>1* Si/ BOOSTER
.X. TT FA"
EXISTING
, PRECIPITATOR !
I1 -•
EXISTING | FROM ABSORBER A-201 PRIMARY REACTOR
"1 OF TRAIN 2
|l 	 1 SECONDARY -
FROM ABSOR8CR A-101 OF Y*1*
r

1 	 1 REACTOR
BT O™8" 	 tjOF TRAIN 1
7X1 SECONDARY
— J1^!
OF TRAIN
_^J ^/ .
I
ORBER
01


u
REACTOR
TRANSFER
PUMP 	
1
C
•
-4
"JHil'
^- 	 -f*

j_
; ABSORBER
A-101
MIST ELIMINATOR
FROM THICKENER HOLD TANK

"•
M9*
RECYaE PUMP '
TYPICAL FOR (2)
RECYCLE PUMPS


,OVERaOW
1 * r-W
THICKENER *"
\
L--H
UN
WASH
AKE —
^
i
DERFLOW
PUMPS

M
2 '
•NsSjtt-P HOL
TTER \\hfr '*"
FILTERS El
1 ,
1
SODA ASH
sour ION
3
KAKE-UP
i .
' jH

SODA ASH
SILO
RIVER WATER
-L (START UP) ^ v.j ^
WEIGH FEEDER
i
rr
SODA ASH
SOLUTION
TANK^?
^ V OVFRFLOW
TO THICKENER
RIVER WATER
" 1.
HOLD TANK Tf| mvmlFR
TRANSFER
PUMPS
RCACTANT WACTOH TRANSFER S
FEED PUMK PUNT
         Louisville  Gas  and  Electric,  Cane Run 6
Dual Alkali FGO System:   Simplified Process Flow Diagram
                            D-22

-------
to
u>
               I.D. BOOSTER FANSv


                TO STACK*


                             BYPASS
                                        IN LINE REHEATER (STEAM)
                                                        •MIST ELIMINATOR

                                                         P MIST ELIMINATOR WASH
                                                        -cJd	—	
                              IN-TANK STRAINER
                                                                  TO DISPOSAL"
THICKNER
                               M.E.UASH

              PUMPS   "YAM"    PUMP
    UNDERFLOW PUMPS
                                                    Louisville  Gas and  Electric,
                                                   Mill Creek 1  and 2 FGD System:
                                                   Simplified Process Flow Diagram

-------
V
K)
             CAS INLET
                                              Louisville Gas and Electric,
                                                Paddys Run 6 FGD System:
                                             Simplified Process Flow Diagram

-------
                          .STACK
TREATED-GAS
   DUCT
SPRAY TOWER
 ABSORBER
                                                              "WET" VENTURI
                                                                SCRUBBER
             Minnesota Power and Light, Clay Boswell 4:
                           General Diagram
                                  D-25

-------
                                       RFI**T  BY -PASS
0

to
CT\
                                                     FILTER CAKC
                                  Minnkota  Power Cooperative,  Milton R. Young  2:
                             Simplified  Process Flow Diagram  for One of Two Absorbers

-------
a
M
                  S02 BOOSTER FANS
                  FLUE GAS}

                         "QUENCHER
            TO STACK
                LIME FEED
                 SYSTEM
-OCLONE
j, |
?!








LJ






fp


1
j

-j
»


                                        RECYCLE  TANK
WASH TRAY


-ABSORBER TRAY



     RECYCLE
      LIQUOR


        THICKENER
                   *-  TO EMERGENCY
                        DUMP POND
                                                                                    TO DISPOSAL SITE
                                      Monongahela Power, Pleasants 1  and 2:
                      Simplified Process Flow Diagram for One of Four Modules for Either Unit

-------
o
i
        FLUE
        GAS
                                                        EMERGENCY WATER
PLENUM



   BLEED
                          MIST
                          ELIMINATORS
    3	»-CLEAN FLUE GAS
    00-SEAL WATER SUPPLY
UNDERSPRAY      _MAKEIIP
                  WATER
                                                                                                    ;POND
                                                                                                    ETURN
                                                                                WASH  TRAY  POND
                                       FLY  ASH  POND
                                   Montana  Power,  Col strip  1  and  2:
                                 Process  diagram nf  a  given FGD module.

-------
                                                           TO CMINNCT
I
                                  HfCHANlCAl
                                    DUST
                                  COUECTM
                                (MUUIClOhlS)
          PWVERIM*
                                     Nevada  Power, Reid Gardner  1,2 and  3:
                                     Process  diagram of a given  FGD system.

-------
                                             DISCHARGE
                                             TO STACK
                                                                                             CONDENSER
                                                    TRAY TOWER
                                                     ABSORBER
            Na2C03
                                                                        MAKE-UP
                             PRESCRUBBER
                           (VARIABLE-THROAT
                                  VENTURI)
                FLUE GAS FROM
                   UNIT 111
OJ
o
       FLY ASH PURGE TO POND
                                                                                                 EVAPORATOR/
                                                                                                 ^CRYSTALLIZER
   TREATED
PURGE STREAM
                                   STORAGE
                                       BIN
                                           Y
                                           DRIED
                                          SULFATE
                                          PRODUCT
                                                               CENTRIFUGE
                                                     SODIUM  SULFATE
                                                         CAKE
                                                                                 TO S02
                                                                                REDUCTION
                                                                                   PLANT
                CRYSTALLIZER
                                  COMPRESSOR
                                            Northern Indiana Public Service,
                                        D.  H.  Mitchell  11 WeiIman. Lord/Allied System:
                                                General  Process Diagram.

-------
                                                 •Hti MtTIt
                                                                                                IIISTM

                                                                                    nuciiin   	'••• '**
                                                                            «*,.<«» \/\ A /
                                                                            iu inn  iu» V/  \/ V/
                                                                                 •MMiJt   M 	 W COUCCTI
                                                                                                      DISfOSM

                                                                                                      IT tWC>
                                                       Simplified Process Flow  Diagram
Spray  Dryer Cutaway View



     Northern States Power,  Riverside 6,7:   FGD System  Flow Diagrams

-------
U)
to
                   FLUE GAS
                      TO
                   SCRUBBER
                                     REHEATER
                                                                                                    LIMESTONE —i
                                       MIST
                                     ELIMINATOR
                                    OVERFLOW POTS
                                   AND MARBLE BED
                                                                                                          ASH POND
                                                                                                        RETURN PUMP
                               Northern  States Power, Sherburne  1  and  2  FGD System:
                                            Simplified Process Flow  Diagram

-------
OJ
u>
                                                            _"... , i~~              «n*»
                                                           _PZ    	  ,» .LI, "T""
                                                           —i—H J{—rsn=r  K™ 1	K7 | I
                                                           -   ED  ""'g
                                Pennsylvania Power,  Bruce Mansfield FGD System:
                                     Process Flow  Diagram for Unit 1 or 2

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FLUE GAS FROM
  UPPER ESP
FLUE GAS FROM
  LOWER ESP
                           X
 STACK INLET
 DAMPERS (2)
(1  EACH SIDE)
                                                                      HOT REHEAT GAS
                              EXHAUST PLENUM

                              EXHAUST
                              ISOLATION
                              DAMPERS
                            (4 PER UNIT)
       INLET
      PLENUM

           INLET  ISOLATION
        DAMPERS (4 PER UNIT)
              BOOSTER FAN FLOW
              CONTROL DAMPERS
                (4 PER UNIT)
                        STACK
               ABSORBERS
              (4  PER  UNIT)
                                                           VENTURIS
                                                           (4 PER UNIT)
BOOSTER FANS
(4 PER UNIT)
                          Public Service of New Mexico, San Juan 1, 2, and 3*
                                   FGD System Flue Gas Flow Path
                         *San Juan 3  is identical except that only one scrubbing
                          train is operational.

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                        JRP FLUE
           SCRUBBER-
            OUTLET
           DUCTWORK
            MIST
         ELIMINATOR
              REACTION
              MIX TANK
                                           FLUE GAS FROM
                                          . ELECTROSTATIC
                                         [ PRECIPITATORS
            INDUCED-
          DRAFT FANS
        BOOSTER FANS

PRESATURATOR
OJ
ui
                                                              TO SEAL-HATER SYSTEM

                                                              TO FLUSH CONNECTIONS
                                                       TO ALKALI-PREPARATION SYSTEM
                                        MIST-
                                      ELIMINATOR
                                        WASH
                                       /TANK A
                                                                                                    .FORTH-STAGE
                                                                                                  / SPRAY PUMP
 ABSORBER-A
   (BOOSTER
      FAN

TO
ABSORBER-B
BOOSTER FAN
                                                                                 TO STACK
     FROM ABSORBER B

           MAKEUP
            HATCH

TO ABSORBER B
     TO ABSORBER B
                                                                                LIMESTONE-SLURRY
                                                                                     MAKEUP

                                                                                     FROM ABSORBER B

                                                                                     FLOCCULENT
                                                                                     ADDITION
                                                                                          TO
                                                                                          ABSORBER 8
                                                                       .F-m     TO SLUDGE
                                                                              STORAGE TANKS
                              Salt  River Project,  Coronado 1  and  2 FGD  System:
                                       Simplified  Process  Flow  Diagram


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a
        RECYCLE
        WATER
        TANK
                                                                                               Y^V FjROM ESP

                                                                                                \J ID BOOST!
                                                                                                             TO POND
QUENCHEII
  PUMP
                                                           ABSORBER    QUENCHER
                                                            TANK         TANK
                           RECYCLE WATER
                               PUMP
                 South Carolina  Public Service Authority,  Winyah 2:  Simplified  Process Flow Diagram

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         BOILER
                                       EXISTING
                    ELEC P8ECIP.
                    W/W
                AIR
               HEATER
                                   \
                                         FA FAN
LJ
•J
  LIMESTONE
  FEED BIN
(ONE IN USE
  FOR TWO
  BOILERS)
                                       STACK
                                     (EXISTING)
            HEIGH FEEDER
            (ONE IN USE)
                                                     HIST ELIMINATOR
                                                       I  PUMP
                                                     (ONE IN USE
                                                       ONE SPARE)
                                                                            MIXER—v
                                                                         (ONE IN USE)
              MET BALL MILL
              (ONE  IN USE)
                         MILL SLURRY
  VENTURI SOR8ER
    SCRUBBERTN
   (ONE IN USE)
                                                                                                                                            FROM THICKENER
                                                                                                                                                TO THICKENER
                                            TANK
                                                     PU*P
                                                   (
                                        (ONE IN USE)         } (ONE IN USE)
                                                                                     RECTUE TANK
                                                                                     (ONE IN USE)
                                                                          ONE SPARE)
  RECYCLE
   PUMP
(TWO IN USE
 ONE SPARE)
                                                                                                                                 THICKENER
                                                                                                                                   SUPPLY
                                                                                                                                    TANK
                                                                                                                                (ONE IN USE)
                                                                                                                                  PUMP
                                                                                                                               ONE IN USE
                                                                                                                               ONE SPARE)
                                                  South Mississippi  Electric, R.D.  Morrow  1 and  2:
                                                       Simplified Process Flow Diagram

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                                LIMESTONE SLURRY
                                STORAGE TANK
                                               TO OTHER ABSORBER
   LIMESTONE
   SILO
      LIMESTONE
      FEEOE
                                                      ABSORBER MODULE
                                 LIMESTONE
                                 TRANSFER
                                 PUMP
                                                             CYCLONE
                                                             SEWRATOR  S
                           MILL PRODUCT PUMP
                                                                  QUENCHER
                                                                  REC1RCULATING
                                                                  PUMP
MILL PRODUCT TANK
                                                                      BOTTOM ASH
                                                                      OE WATERING
                                                                      BIN
                                                              ASH CONVEYOR

                                                             I PLUG MILL
                SLUDGE
            TRANSFER PUMP
                                          SLUDGE
                                          CONVEYOR
                                    CENTRATE SUMP
Southern Illinois Power Coop,  Marion  4:   Simplified  Process  Flow Diagram

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V
U)
                    FROM
                     ESP
                BY-
                PASS
STACK
                    *
                            >X
                        SODA ASH
                        STORAGE
         BOOSTER
                             S
              LIME
             STORAGE
                              Na2C03
                                        /    USE  /SLAKER Ca(OH)2
                                        /•r^BIN/
                                                   WATER
                                         LIME REACTOR
 5SULFUR DIOXIDE ABSORPTION
Na2S03 + S02 * H20	»2 NaHS03 | SURGE
£aS03/CaS04
                                                                                        FILTER
                                                                                         CAKE
                                                      SODIUM REGENERATION

                              2 NaHS03 + Ca(OH)2—" CaS03  *  1/2 H20 + Na2S03 + 1-1/2 H20
                               Southern  Indiana Gas and Electric, A.B.  Brown  1:
                            Dual  Alkali  FGD  System Simplified Process Flow Diagram

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                                 SCRUBBER INLET
                                TEST PORT LOCATION
V
o
               PRECIPITATOR
                INLET TEST
              PORT LOUT ION
                                                     "B" ABSORBER
                                                       NODULE
 TOP OF STACK
ELEVATION 1645'

   TEST PORT
ELEVATION 1516'
                                                                              -TOP OF OUTLET BREECHING
                                                                                ELEVATION  IJ72'-2 1/8"
                                                                              -TOP OF BYPASS BREECH INS
                                                                               ELEVATION 1307'- 8 1/2*
                                      SCRUBBER  INLET
                                    TEST PORT LOCATION
                                                  mm CM
                                                  imiuwn
                                                   faun m
                                             Springfield City  Utilities, Southwest 1:
                                                         Simplified  Process Diagram

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                                        H2S GENERATION
                                           METHANE/
                                        CARBON MONOXIDE.
        BOILER
                         PREHEATER
     LIME
  NEUTRALIZER
PRECONDITIONING AND
  S02 ABSORPTION
                            CRYSTALLIZER
              SULFUR
              SLURRY   SULFUR
        SULFUR        PRODUCT
       FLOTATION
SULFUR  PRECIPITATION
    AND RECOVERY
                 St. Joe Z1nc, G.F. Weaton 1:
     Citrate  FGD System Simplified Process Flow Diagram
                                D-41

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o

to
             I  AIR
             JFUEL OIL>— ^REHEATER--,
  TCA
SCRUBBER1
      | FLUE GAS
      |LIMESTONE
                            • • • •
                           l-V-5
                           T
                                       HAKEUP UATERj    ''
       SAMPLE POINTS

       OGAS COMPOSITION
       SPARTICIPATE COMPOSITION & LOADING
       ©SLURRY OR SOLIDS COMPOSITION
                                          ®
                         	GAS STREAM
                         	LIQUOR STREAM
                                                                   BLEED
                                                                                              i	
                                                                                                    STAC
                                                                                         r—QIAKEUP WATERJ
PROCESS
 WATER
 HOLD
 TANK
                                                                                    DISCHARGE
                                                                               SETTLING POND
                                             Tennessee Valley Authority,
                                          Shawnee IDA Prototype Test Unit:
                                              General Process Diagram.

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                                FLUE GAS
D

u>
                                                                                  CLARIFIED LIQUOR
                                                                                       WATER
                                                                                              D
                        SPRAY TOWER EFFLUENT
                             HOLD TANK







!
c
3

C
! t
i
DESUPERSATURATION
TANK
                           Tennessee Valley Authority, Shawnee  10B Prototype Test Unit:
                         Modified Venturi/Spray Tower System for 2-Stage Oxidation Testing.
                                                                                                               BLEED TO
                                                                                                             DEWATERING
                                                                                                            _,  SYSTEM^

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        I    AIR   >	-^

        I FUEL OIL >—»| REHEATEJT[—--.
                                                                PROCESS
                                                                 WATER
                                                                HOLD TANK
                    SCRUBBER
                    EFFLUENT
                     HOLD
                     TANK
SAMPLE POINTS
OGAS COMPOSITION
®PARTICULATE COMPOSITION & LOADING
©SLURRY OR SOLIDS COMPOSITION
	GAS STREAM
	LIQUOR STREAM
                                              SETTLING POND
                   Tennessee Valley Authority,  ShawneelOB Prototype Unit:
                                    General  Process  Diagram.

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O

ui
                    TO ASH
                                              REHEATER

                                             STEAM
                 7
                                           ENTRAPMENT
                                            SEPARATOR
                    DISPOSAL POND
                   TO STACK PLENUM
                                             N


X,

f 1





r

                                                                         TO TRAINS
                                                                         B.C. AND D
                                                                 £
                   FROM ESP
FAN
.. FROM B. C. AND 0 TRAIN.

 VENTURI CIRCULATION"
               CM
                    TO SETTLING POND
                                                  SLURRY  PUMP
                                                  SEAL HATER
                                                  , HEADER
                                                  /••I m
                                                                                                         RIVER HATER
                                                                                                            PUHPS
                                                                                                       FROM POND HATER
                                                                  RECYCLE PUHPS
                                                                                                  FROM LIMESTONE SLURRY
                                                                                                      I TRANSFER PUMPS
                                                      VENTURI
                                                    CIRCULATION
                                                     TANK AND
                                                       PUMPS
                                ABSORBER
                              CIRCULATION
                                TANK AND
                                 PUMPS
                                                                  TO TRAINS / |.
                                                                  B.C. AND D] „
LIMESTONE SLURRY
  STORAGE TANK
                                  EFFLUENT  SLURRY
                                SURGE  TANK AND PUMPS
                                               LIMESTONE SLURRY
                                                  FEED PUMPS
                               Tennessee Valley Authority, Widows Creek 8  FGD System:
                              Process Flow Diagram  for One of  the Four Scrubber  Trains

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                 fAlt OUTICT OAWEIK
                                      - TWCI IKCT 0*Mf t«
 FKM »OILt«
Alt PttHUTEtS
                                                                           PUHP SEAL UATU.
                                                                           MIL Hill COMIW
                                                                           AND HOSE STATrats
                                                                   SWf UP UATED TO
                                                                   HHtSIWIE AREA
                                               ASM ran
                                              RETURN HATER
                                             (KCTCLE HATE*)
                                     Texas Utilities,
        Simplified  Process  Flow Diagram for  One  of  the  Three Identical
                                Martin  Lake  FGD Systems

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                                        10 SPRAY TOUCR 101

                                        TO SPRA« TOUCH 201
O
                 FROM
           LIMESTONE STORAGE
TO SPRAY TOUCR 101
TO SPRAY TOUCR 201

TO SPRAY TOUCR 101
TO SPRAY TOUCR 201
                                LIMESTONE
                                 STORACt
                                   BIN
TO SPRA( TOHER 101
TO SPRAT TOWER 201
        rllKVIl

  	r
                                                   SERVICE HATER
                                 |   LINCSIONE CRINOIN6
                                 I	SYSTEM
                                          LIMESTONE SLURRY
                                           TANK AGITATOR
                                                                         etPASS

                                                                         TO SPRAY IOUER 101
                                                                         '0 SPRAf IOUER 201
                                                                         ElIM
                                                                           M ST
                                                                               BYPASS ,

                                                                  FROM SPRAY TOUIR  101 \




                                                                   FROM SPRAT TOUER 201 ]


                                                                               BYPASS :

                                                                             NATOR
                                                                             1
                                                                                              IN
                                                                                                 raws
                                                                                    •niiiniuin
                                                                                     SPRAY TOUCR
                                       N
                                                                                         101
                                                                                                 RHITTEMT
                                                                                                                                                        f
-------
                                      REHEATEK FAN
D


*-
CO
                           FROM

                       ELECTROSTATIC

                       PRECIPITATORS
SUPERHEATED
   STEAM

 FROM OTHER
  ABSO

   m
BOOSTER FAN



      LIME
                                        TO OTHER

                                        ABSORBERS

I


a
1 MIST 1
LIMlNATOf
;:::v.:::.:::.:.:.;.::v:v.

ABSORBER
ABSORBER
AGITATORS
hj
F


f>
                                                                       MIST
                                                                    ELIMINATOR
HATER
    FROM OTHER
    ABSORBERS
                                              MAKEUP

                                              WATER
                 VIBRATING

                   HOPPER
       Utah Power &  Light,  FGD  System  Simplified  Process Flow Diagram for Hunter 1,  2 or  Huntington  1

-------