vvEPA
          United States      Industrial Environmental Research  EPA 600 / 79 022b
          Environmental Protection  Laboratory         February 1979
          Agency         ,>arch Triangle Park NC 2771 1
EPA Utility FGD
Survey:
October-November 1978

Interagency
Energy/Environment
R&D Program Report

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                  RESEARCH REPORTING SERIES


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

     1. Environmental Health Effects Research

     2. Environmental Protection Technology

     3. Ecological Research

     4. Environmental Monitoring

     5. Socioeconomic Environmental Studies

     6. Scientific and Technical Assessment Reports (STAR)

     7. Interagency  Energy-Environment Research and Development

     8. "Special" Reports

    9. Miscellaneous Reports

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

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

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                                         EPA-600/7-79-022b

                                                February 1979
        EPA  Utility FGD  Survey:
         October-November  1978
                             by
                 M. Melia, M. Smith, T. Koger, and B. Laseke

                      PEDCo. Environmental, Inc.
                        11499 Chester Road
                       Cincinnati, Ohio 45246
                       Contract No. 68-02-2603
                           Task No. 24
                     Program Element No. EHE624


                        EPA Project Officers:
          N. Kaplan
        J. C. Herlihy
Industrial Environmental Research Laboratory
  Office of Energy, Minerals, and Industry
   Research Triangle Park. NC 27711
Division of Stationary Source Enforcement
      Office of Enforcement
     Washington, DC 20460
                          Prepared for
                U.S. ENVIRONMENTAL PROTECTION AGENCY
                   Office of Research and Development
                       Washington, DC 20460

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                             NOTICE


     This report,  (prepared by PEDCo Environmental, Inc., Cincinnati,
Ohio, tinder EPA Contract No. 68-02-2603, Task No. 24) is provided
as an information transfer document.  Data in this report are
supplied voluntarily by utility representatives; flue gas desulfuri-
zation  (FGD) system designers, vendors, and suppliers; regulatory
personnel; and others.  Neither EPA nor the designated contractor
warrants the accuracy or completeness of information contained in
this report.

     This report is the fifth of five supplementary issues to the
December 1977-January 1978 report.  Supplementary issues are
cumulative, so that it is necessary to retain only the latest
issue and the December 1977-January 1978 report  (EPA-600/7-78-
051a).

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

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                             CONTENTS
Notice
Tables
Executive Summary and Highlights

Section 1 Summary List of FGD Systems                         1

Section 2 Status of FGD Systems                               4

Section 3 Performance Description of Operational FGD Systems 23
          Alabama Electric
               Tombigbee 2
          Arizona Electric Power
               Apache 2
          Arizona Public Service
               Cholla 1
               Cholla 2
          Central Illinois Light
               Duck Creek 1
          Columbus and Southern Ohio Electric
               Conesville 5
               Conesville 6
          Duguesne Light
               Elrama 1 through 4
               Phillips 1 through 6
          Gulf Power
               Scholz 1 and 2
          Indianapolis Power and Light
               Petersburg 3
          Kansas City Power and Light
               Hawthorn 3
               Hawthorn 4
               La Cygne 1
          Kansas Power and Light
               Jeffrey 1
               Lawrence 4
               Lawrence 5
          Kentucky Utilities
               Green River 1, 2, and 3
23

24

25
26

27

29
31

32
34

36

37

38
39
40

41
42
43

44
                               iii

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                      CONTENTS (continued)
          Louisville Gas and Electric
               Cane Run 4
               Cane Run 5
               Mill Creek 3
               Paddy's Run 6
          Minnkota Power Cooperative
               Milton R. Young 2
          Montana Power
               Colstrip 1
               Colstrip 2
          Nevada Power
               Reid Gardner 1
               Reid Gardner 2
               Reid Gardner 3
          Northern Indiana Public Service
               Dean H. Mitchell 11
          Northern States Power
               Sherburne 1
               Sherburne 2
          Pennsylvania Power
               Bruce Mansfield 1
               Bruce Mansfield 2
          Philadelphia Electric
               Eddystone 1A
          Public Service Company of New Mexico
               San Juan 1
               San Juan 2
          Southern Carolina Public Service
               Winyah 2
          Southern Mississippi Electric
               R. D. Morrow 1
          Springfield City Utilities
               Southwest 1
          Tennessee Valley Authority
               Shawnee 10A
               Shawnee 10B
               Widows Creek 8
          Texas Utilities
               Martin Lake 1
               Martin Lake 2
               Monticello 3
          Utah Power and Light
               Huntington 1

Section 4 Summary of FGD Systems by Company

Section 5 Summary of FGD Systems by Vendor
46
47
48
49

50

51
52

53
55
57

59

61
63

65
67

69

70
71

72

73

74

76
77
80

82
83
84

85

86

87
                                iv

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                      CONTENTS (continued)
                                                          Paqe
Section 6


Section 7


Section 8


Section 9


Section 10

Section 11

Section 13

Appendix A
Appendix B
Appendix C
Summary of New and Retrofit FGD Systems by
Process                                         89

Summary of Operating FGD Systems by Process
and Generating Units                            90

Summary of Sludge Disposal Practices for
Operational FGD Systems                         92

Summary of FGD Systems by Process and
Regulatory Class                                94

Summary of FGD Systems Under Construction       96

Summary of Planned FGD Systems                  98

Total of FGD Megawatt Capacity by Year         101

FGD Systems Economics                          A-l
FGD Process Flow Diagrams                      B-l
Definitions                                    C-l
                                v

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                             TABLES


No.                                                         Page

  I  Number and Total Capacity of FGD Systems                vii

 II  Summary of Changes, October-November, 1978             viii

III  Performance of Operational Units, October-November,
     1978                                                     xi
                               vi

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                       EXECUTIVE SUMMARY
This report is prepared every other month by PEDCo Environmental,
Inc., under contract to the Industrial Environmental Research
Laboratory/Research Triangle Park and the Division of Stationary
Source Enforcement of the U.S. Environmental Protection Agency.

Table I summarizes the status of FGD systems in the United States
during October and November 1978.  Table II lists the units that
changed status in this period, and Table III shows the perform-
ance of operating units.

       TABLE I.  NUMBER AND TOTAL CAPACITY OF FGD SYSTEMS
Status
Operational
Under construction
Planned:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only FGD systems
TOTAL
No. of
units
46
43

20
3
5
27
144
Capacity,
MW
16,054
17,297

10,690
1,960
3,100
13,406
62,507
The total power generating capacity of the electric  utility
industry in the United States is now approximately 564 GW.a
Coal-fired units account for approximately 265 GW" or 47% of this
total.  As indicated in Table I, 46 power generating units (all
coal-fired) are now equipped with operating FGD systems.  These
units represent 16,054 MW, which is 3% of total utility power
generating capacity and just over 6% of utility coal-fired capac-
ity.  Projections indicate that the total power generating capac-
ity of the U.S. electric utility industry will be approximately
                               vii

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                                  TABLE II.   SUMMARY OF CHANGES,

                                       OCTOBER-NOVEMBER 1978
H-
H-
PGD status report
9/30/78
Arizona Public Service
Four Corners 1
Arizona Public Service
Four Corners 2
Arizona Public Service
Four Corners 3
Basin Electric Power
Laramie River 3
Northern States Power
Sherburne 3
Northern States Power
Sherburne 4
Potomac Electric Power
Dickerson 4
Springfield Water, Light &
Power
Dallman 3
Tampa Electric
Big Bend 4
Tennessee Valley Authority
Johnson vi lie
Tennessee Valley Authority
Paradise 1
Tennessee Valley Authority
Paradise 2
Utah Power & Light
' Emery 2
11/30/78
Operational
No.
46













16
MW
16,054













16,054
Under
construction
No.
38
+ 1
+1
+ 1




-i-l




•4-1
43
MW
16,128
175
175
229




190




400
17,297
Contract
awarded
No.
23



+1
-]
-1

-)




-I
20
MW
12,450



550
860
860

190




400
1.0,690
Letter of
intent
No.
1




+1
+1







3
MW
240




860
860







1,960
Requesting/
evaluat no bids
No.
4



-1






+ 1
+1

5
MW
2,350



550






650
650

3,100
Considering
only FGD
No.
27
-1
-1
-1



+ 1

+ 1
+1



27
MW
12,160
175
175
229



800

425
600



13,406
Total
No.
139






+ 1

+ 1
+1
+1
+1

144
MW
59,382






800

425
600
650
650

62,507

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         TABLE  III.
PERFORMANCE  OF OPERATIONAL UNITS,
OCTOBER-NOVEMBER 1978
Plant
Tonbigboe 2
Apache 2
Choi la 1
Cholla 2
Duck Creek 1
Conesville 5
Conesvillo 6
drama
Phillips
Scholz CT-121
Petersburg 3
Hawthorn 3
Hawthorn 4
La Cygne
Jeffrey 1
Lawrence 4
Lawrence 5
Green River I,/, 3
Cane Run 4
Cane Run 5
Mill Creek 3
Paddy's Run 6
Milton R. Young 2
Colstrip 1
Colstrip 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Mitchell 11
Sherburne 1
Shorburne 2
Mansfield 1
Mansfield 2
Eddystone 1A
San Juan 1
San Juan 2
Hinyah 2
R.D. Morrow 1
Southwest 1
Shawnee IDA
Shawnee 10B
Widows Creek S
Martin Lake 1
Martin Lake 2
Montlcello 3
Huntington 1
TOTAL
PGD systen
design
capacity
225
200
115
250
400
400
400
510
410
23
530
100
100
820
680
125
400
64
178
183
425
65
450
360
360
125
125
125
115
710
710
825
825
120
314
306
280
180
200
10
10
550
793
793
750
415
16,054
PGD unit
on line
during
period
225
200
115
250
400
400
400
510
410
23
530


820
680
125
400
64
178
183
425
450


125
125
125
115
710
710



314
306
280
180
200
10
10




415
0,413
Ho information
for this
period










100
100









360
360






825
825
120






550

793
793
750

5,576
Shut down
through-
out
period




















65























65
FGD nyfltcn
availability,
Oct.



16
77
68


99



97



30






100
96
100
44
92
94
















Nov.



e
operab
I
Oct.



26
64 i 42
26


99



94



24



46*


89
99
98
99
92
92







51








32










94

96
84



100
95




















-
iUty,
Nov.

reliability.

ut i 1 ization ,
I
O-t. 1 Nov. Oct.

34

9
52
6










100
97
94
35
53*


37
93
91










44








100

26
43
33










96






100
99

73


















100

9
52
6










74



54"


87
93
91
99









44










16
41
27










30

71
91



90
92
0
44


















Sov.

24

8
46
4










24
56
33
42
42"


83
36
62
98









43








a Values roportcri are annual averanco for opcr.itu.n .'.unr.a 1978.

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878 GW by 1988,a an increase of 56% over the present total.
(This value reflects the annual loss resulting from the retire-
ment of older units, which is considered to be 0.4% of the aver-
age generating capacity at the end of each year.)   Approximately
395 GW3""0 or 45% of the 1988 total will come from coal-fired
units.  Of the 144 FGD-equipped units (62,507 MW)  shown in Table
I, 141 (61,267 MW) are scheduled for operation by 1988.  There-
fore, approximately 7% of the projected total generating capacity
and 16% of the projected coal-fired capacity will be controlled
by FGD by the end of 1988.

               HIGHLIGHTS:  OCTOBER-NOVEMBER 1978

The following paragraphs highlight FGD system developments during
October and November 1978.

Arizona Public Service reported that Cholla 1 was in service
through October and November.  Module A logged 434 hours of
operation the first month and 720 hours the second, whereas
Module B logged 416 and 657 hours.  The boiler operated 434 hours
in October and 720 hours in November.  The reliability index
values for Modules A and B at Cholla 1 were 100% in both October
and November.  Also, the utility reported that construction has
begun at Four Corners 1, 2, and 3 to upgrade the existing par-
ticulate scrubbers for additional SO2 removal.

Basin Electric Power announced that a contract was awarded to
Babcock and Wilcox for the installation of a dry collection FGD
system on Laramie River 3, a new 550-MW unit designed to fire
subbituminous coal and scheduled to commence operation in April
1982.  The dry collection system will use lime slurry as the
scrubbing reagent.

Kansas City Power and Light reported average availabilities of 97
and 94% for the La Cygne 1 FGD system in October and November.
No major problems were reported.

Kansas Power and Light reported 100% availability for the FGD
systems at Lawrence 4 and 5 in both October and November.  The
only downtime reported was 1 week in October for the annual
inspection of the boiler turbine.

Louisville Gas and Electric reported that the Cane Run 4 boiler
was out of service during all of October and the first part of
November because of boiler tube repairs.  Operations resumed
during the second week of November.  Operability of the FGD
system was 97% for the remainder of the month.

Northern States Power reported that the FGD system availability
for Sherburne 1 was 92% in both October and November and that the

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FGD system availability for Sherburne 2 was 94% in October anu
92% in November.  A letter of intent is still in effect for the
FGD systems planned for Sherburne 3 and 4, which are scheduled to
start operation in May 1984 and 1987.  Each new unit will be
rated at 860 MW and equipped with a limestone slurry rod scrubber
and spray tower absorber.

Nevada Power reported high FGD system availabilities at Reid
Gardner:  100% in October and 89% in November for Reid Gardner 1,
96% in October and 98% in November for Reid Gardner 2, 100% in
October and 98% in November for Reid Gardner 3.

Northern Indiana Public Service reported that the demonstration
Wellman-Lord FGD system on D.H. Mitchell 11 was available 99% of
the time during November.

Potomac Electric Power is in the preliminary stages of planning
an FGD system for Dickerson 4, a new 800-MW coal-fired unit
scheduled to start operation in May 1985.

Springfield Water, Light & Power reported that foundation con-
struction work began on the limestone slurry FGD system at
Dallman 3, a 190-MW coal-fired unit.  Research Cottrell is sup-
plying this system, which will have a design SO2 removal effi-
ciency of 90%.

Tampa Electric announced plans to install an FGD system on Big
Bend 4, a new 425-MW unit scheduled to begin operation in early
1985.  An electrostatic precipitator will provide primary partic-
ulate control.  Although the FGD process has not yet been
selected, the design SO2 removal efficiency will be 90%.

The Tennessee Valley Authority plans to retrofit a magnesium
oxide FGD system at the Johnsonville steam plant.  This system,
which will accommodate flue gas from 600 MW of the plant's 1500
MW capacity, is scheduled to begin operation in 1982.  The
utility also announced plans to install FGD systems at Paradise 1
and 2 and is requesting/evaluating bids for two limestone slurry
FGD systems.  Each system will treat 100% of the flue gas from
one of the two boilers.  The Paradise 1 FGD system is scheduled
to begin operation in 1982.  No startup date was reported for the
Paradise 2 FGD system.

Utah Power and Light reported that construction is proceeding on
Emery 2, a new 400-MW coal-fired unit scheduled for startup in
June 1980.  Chemico will supply a lime slurry FGD system for
Emery 2.  FGD construction is reported to be approximately 35%
complete.
                               XI

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                REFERENCES  FOR EXECUTIVE  SUMMARY


a.    Sixth Biennial Survey  of  Power  Equipment Requirements  of  the
     U.S.  Electric Utility  Industry:   1977-1986.   Sponsored by
     the Power Equipment Division, National Electrical Manu-
     facturers Association.

b.    Temple,  Barker,  and Sloane,  Inc.   Policy Testing Model for
     Electric utilities, Exhibit  II-3.

c.    Twelth Annual Power Engineering Survey, Power Engineering,
     April 1978.
                              xxi

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    COMPANY NAME
                                                EPA UTILITY FGD SUKVEY: UCIOHtK 19/fl - NOVEfbtk  19/B
                                         SECTION 1
                               SUMMARY LIST OF FGO SYSTEMS
                                         UNIT NAME
                                                                  STAKl UP UAIt   STATUS
                                                           KtG
                                                          CLASS
   ALABAMA ELECTRIC COOP
   ALABAMA ELECTRIC COOP
   ALLEGHENY POWEK SYSTEM
   ALLEGHENY POWER SYSTEM
   ARIZONA ELECTRIC POWER COOP
   ARIZONA ELECTKIC POWER COOP
   ARIZONA PUBLIC SERVICE
   ARIZONA PUBLIC SERVICE
   ARIZONA PUBLIC SERVICE
   ARIZONA PUBLIC SERVICE
   ARIZONA PUBLIC SERVICE
   ARIZONA PUBLIC SERVICE
   ARIZONA PUBLIC SERVICE
   ARIZONA PUBLIC SERVICE
   ASSOCIATED ELECTRIC COOP
   BASIN ELECTRIC POWER COOP
   BASIN ELECTRIC POnER COOP
   BASIN ELECTRIC POWER COOP
   BASIN ELECTRIC POWER COOP
   BASIN ELECTRIC POWER COOP
   BIG RIVERS ELECTRIC
   BIG RIVERS ELECTRIC
   CENTRAL ILLINOIS LIGHT
   CENTRAL ILLINOIS LIGHT
   CENTRAL ILLINOIS PUBLIC SERV
   CENTRAL MAINE POWER
   CINCINNATI GAS ft ELECTRIC
   COLORADO UTE ELECTRIC ASSN.
   COLORADO UTE ELECTRIC ASSN.
   COLUMBUS ft SOUTHERN OHIO ELEC.
   COLUMBUS & SOUTHERN OHIO ELEC.
   COLUMBUS * SOUTHERN OHIO ELEC.
   COLUMBUS ft SOUTHERN OHIO ELEC.
   COMMONWEALTH EDISON
   COOPERATIVE POWER ASSOCIATION
   COOPERATIVE POWER ASSOCIATION
   DELMARVA POWER ft LIGHT
   DUOUESNE LIGHT
   DUOUESNE LIGHT
   EAST KENTUCKY POWER COOP
   GENERAL PUBLIC UTILITIES
   GENERAL PUBLIC UTILITIES
   GULF POWER
   HQ.03JER ENERGY
   HOOSIER ENERGY
   INDIANAPOLIS POWER & LIGH1
   INDIANAPOLIS POWER ft LIGHT
   KANSAS CITY POWER ft LIGHT
   KANSAS CITY POWER ft LIGHT
   KANSAS CITY POWER ft LIGHT
   KANSAS POWER ft LIGHT
   KANSAS POWER ft LIGHT
   KANSAS POWER ft LIGHT
   KANSAS POWER & LIGHT
   KENTUCKY UTILITIES
   LAKELAND UTILITIES
   LOUISVILLE GAS & ELECTRIC
   LOUISVILLE GAS & ELECTRIC
   LOUISVILLE GAS ft ELECTRIC
   LOUISVILLE GAS ft ELECTRIC
  TOMBIGBEE 2
  TOMBIGBEE 3
  PLEASANTS 1
  PLEASANTS 2
  APACHE 2
  APACHE 3
  CHULLA 1
  CHOLLA 2
  CHOLLA 4
  FOUR CORNERS 1
  FOUR CORNERS 2
  FOUR CORNERS 3
  FOUR CORNERS 4
  FOUR CORNERS 5
  THOMAS HILL 3
  ANTELOPE VALLEY 1
  ANTELOPE VALLEY 2
  LARAMIE RIVfcR 1
  LARAMIE RIVER 2
  LARAMIE KIVER 3
  GREEN 1
  GREEN 2
  DUCK CREEK 1
  DUCK CREEK 2
  NEWTON 1
  SEARS ISLAND 1
  EAST BEND 2
  CRAIG 1
  CRAIG 2
  CONESVILLE 5
  CUNESVILLE b
  POSTON 5
  POSTON 6
  POWERTON 51
  COAL CREEK 1
  COAL CREEK 2
  DELWAHE CITY 1, 2 & 3
  ELRAMA POWER STATION
  PHILLIPS POWER STATION
  SPURLOCK 2
  COHO 1
  SEWARD 7
  SCHOLZ 1 ft 2
  MEROMJ_
  MEROM 2
  PETERSBURG 3
  PETERSBURG o
  HAWTHORN 3
  HAWTHORN 4
  LA CYGNE 1
  JEFFREY 1
  JEFFREY 2
  LAWRENCE 4
  LAWRENCE 5
  GREEN RIVER 1,2 ft 3
  MCINTOSH 3
  CANE RUN 4
  CANE RUN 5
  CANE RUN 6
  HILL CREEK 1
 9-7(1
 b-/9
 3-79
 3-80
lo-M
 4-7H
 b-HO
 0-79
 0-79
 0-/9
 0-OtJ
 0-Bt!
 1-02
1 1-el
11-83
 u-ec
10-00
 4-0<2
12-79
12-80
 /-7a
 1-U«
11-79
ll-8b
 1-81
 3-79
 3-79
 I-//
 fa- 78
 0-83
 0-85
 3-/9
 2-/9
11-/9
 4-80
10-/b
 7-73
 3-80
 b-86
 b-85
 8-7«
 4-8.1
 1-82
10-77
10-63
11-/2
 8-72
 2-73
 8-78
 fa-80
12-b8
11-71
 9-75
10-81
 B-7b
12-77
12-78
 1-81
1.  OPERATIONAL UNITS
3.  UNITS UNDER CONSTRUCTION
3.  PLANNED - CONTRACT AWARDED
4.  PLANNED - LETTER OF INTENT SIGNED
5.  PLANNED - REQUESTING/EVALUATING BIDS
6.  CONSIDERING ONLY FGO SYSTEMS
7.  CONSIDERING FGD SYSTEMS AS WELL AS ALTtHNATIVE  MtTHODS
a
a
b
n
A
t)
rj
t)
U
b
A
A
A
A
A
A
A
H
B
«
a
ri
H
c
A
A
C
b
b
A
A
A
C
A
A
A
A
H
b
C
B
b
b
H
C
A
6
H
B
H
A.  BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
B.  BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FtDERAL NSPS
C.  BOILER SUBJECT TO STATE STANDARD THAT IS EUUAL TO OR LESS STRINGENT THAN NSPS
0.  OTHER
E.  REGULATORY CLASS UNKNOWN

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EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 1978
      COMPANY NAME
                                           SECTION 1
                                 SUMMARY LIST OF FGO SYSTEMS
                                           UNIT NAME
                                                                                             REb
                                                                    S1AK1 UP OATt   STATUS  CLASS
     LOUISVILLE GAS * ELECTRIC
     LOUISVILLE GAS & ELECTRIC
     LOUISVILLE GAS & ELECTRIC
     LOUISVILLE GAS & ELECTRIC
     MINNESOTA POWER & LIGHT
     MINNKOTA POWER COOPERATIVE
     MONTANA POWER
     MONTANA POWER
     MONTANA POWER
     MONTANA POWER
     NEVADA POWER
     NEVADA POWER
     NEVADA POWER
     NEVADA POWER
     NEVADA POWER
     NEVADA POWER
     NEVADA POWER
     NEVADA POWER
     NEVADA POWER
     NEVADA POWER
     NEW ENGLAND ELEC SYSTEM
     NIAGARA MOHAWK POWER COOP
     NORTHERN INDIANA PUB SERVICE
     NORTHERN INDIANA PUB SERVICE
     NORTHERN INDIANA PUB SERVICE
     NORTHERN STATES POWER
     NORTHERN STATES POWER
     NORTHERN STATES POWER
     NORTHERN STATES POWER
     OTTER TAIL POWER
     PACIFIC GAS AND ELECTRIC
     PACIFIC GAS AND ELECTRIC
     PACIFIC POWER & LIGHT
     PENNSYLVANIA POWER
     PENNSYLVANIA POWER
     PENNSYLVANIA POWER
     PHILADELPHIA ELECTRIC
     PHILADELPHIA ELECTRIC
     PHILADELPHIA ELECTRIC
     PHILADELPHIA ELECTRIC
     POTOMAC ELECTRIC POWER
     POWER AUTHORITY OF NEW YORK
     PUBLIC SERVICE OF INDIANA
     PUBLIC SERVICE OF NEW MEXICO
     PUBLIC SERVICE OF NEW MEXICO
     PUBLIC SERVICE OF NEW MEXICO
     PUBLIC SERVICE OF NEW MEXICO
     SALT RIVER PROJECT
     SALT RIVER PROJECT
     SALT RIVER PROJECT
     SAN MIGUEL ELECTRIC COOP
     SEMINOLE ELECTRIC
     SIKESTON BOARD OF MUNIC. UTIL.
     SOUTH CAROLINA PUBLIC SERVICE
     SOUTH CAROLINA PUBLIC SERVICE
     SOUTHERN ILLINOIS POWER COOP
     SOUTHERN ILLINOIS POWER COOP
     SOUTHERN INDIANA GAS & ELEC
     SOUTHERN MISSISSIPPI ELECTRIC
     SOUTHERN MISSISSIPPI ELECTRIC
  1.  OPERATIONAL UNITS
  8.  UNITS UNDER CONSTRUCTION
  3.  PLANNED - CONTRACT AWARDED
  MILL CREEK  2
  MILL CHEEK  3
  MILL CREEK  a
  PADDYS RUN  6
  CLAY BOSWELL 4
  MILTON R.  YOUNG  2
  COLSTR1P 1
  COLSTRIP i.
  COLSTRIP 3
  COLSTKIP 4
  HAKKY ALLEN 1
  HAKRY ALLEN 2
  HARRY ALLEN 3
  HAKKY ALLEN 4
  KEIO GARDNER 1
  RtID GARDNER 2
  REID GARDNER 3
  REID GAKDNEK 4
  WARNER VALLEY  1
  WARNEK VALLEY  2
  BRAYTON POINT  3
  CHARLES R.  HUNTLEY  6
  BAILLY 7
  BAILLY 6
  DfcAN H. MITCHELL 11
  SHERBURNE  1
  SHERBUKNE  2
  SHERBUHME  3
  SHERBURNE  4
  COYOTE 1
  FOSSIL 1
  FOSSIL 2
  JIM BRIDGER 4
  BRUCE MANSFIELD  1
  BKUCfc MANSFIELD  2
  BRUCE MANSFIELD  3
  CROMdY
  EDDYSTONE  1A
  EDOYSTONE  IB
  EDDYSTONE  2
  OICKERSON  4
  ARTHUR KILL PLANT
  GIBSON 5
  SAN JUAN 1
  SAN JUAN 2
  SAN JUAN 3
  SAN JUAN 4
  CORONADO 1
  CORONAOO 2
  CORONADO 3
  SAN MIGUEL  1
  SEMINOLE 1
  SIKESTON POWER STATION
  WINYAH 2
  WINYAH 3
  MARION 4
  MARION 5
  A. B. BROWN 1
  R. D. MORROW 1
  R. D. MORROW 2

4.  PLANNED - LETTER  OF INTENT SIGNED
5.  PLANNED - REQUESTING/EVALUATING BIDS
fa.  CONSIDERING ONLY  FGD SYSTEMS
7.  CONSIDERING FGD  SYSTEMS AS WELL AS ALTERNATIVE METHODS
*
i-Bd
8-78
7-81
4-73
5-80
9-77
11-75
B-7b
7-80
7-el
6-85
6-86
6-87
6-08
4-74
4-74
7-76
0-83
6-04
6-85
U- 0
0-80
U- 0
0- 0
11-76
3-76
4-77
5-84
0-87
5-81
0-85
0-86
9-79
4-76
7-77
4-80
6-80
9-75
6-80
6-80
5-85
11-84
0-82
4-78
8-78
6-79
1-82
2-79
1-80
0-87
6-BO
6-83
6-81
7-77
5-80
9-78
0-84
4-79
8-78
2-79
3
1
2
1
2
1
1
1
3
3
6
6
6
6
1
1
1
6
6
6
7
3
6
6
1
1
1
4
4
2
6
6
2
1
1
2
6
1
4
6
6
7
5
1
1
3
3
2
2
6
2
6
2
1
3
2
6
2
1
2
B
B
0
C
A
b
A
A
B
B
A
A
A





A
A
C
C
C
C
C
ri
B
b
B
A
B
B
B
d
B
B
t)
B
B
d
0
B
A
B
B
b
B
B
d
B










  A.  BOILER CONSTRUCTED SUBJECT  TO FEDERAL NSPS
  B.  BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
  C.  BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT  THAN NSPS
  D.  OTHER
  E.  REGULATORY CLASS UNKNOWN

-------
                                                EPA  UTILITY  FGD  SUKVEY:  OCTOBER  1978  - NOVtMbEK  1978
                                         SECTION 1
                               SUMMARY LIST OF FGO  SYSTEMS
    COMPANY NAME
   SOUTHWESTERN ELECTRIC POWER
   SPRINGFIELD CITY UTILITIES
   SPRINGFIELD MATER LIGHT & PWR
   ST.  JOE ZINC
   TAMPA ELECTRIC
   TENNESSEE VALLEY AUTHORITY
   TENNESSEE VALLEY AUTHORITY
   TENNESSEE VALLEY AUTHORITY
   TENNESSEE VALLEY AUTHORITY
   TENNESSEE VALLEY AUTHORITY
   TENNESSEE VALLEY AUTHORITY
   TENNESSEE VALLEY AUTHORITY
   TEXAS MUNICIPAL POWER AGENCY
   TEXAS POWER & LIGHT
   TEXAS POWER & LIGHT
   TEXAS POWER & LIGHT
   TEXAS UTILITIES
   TEXAS UTILITIES
   TEXAS UTILITIES
   TEXAS UTILITIES
   TEXAS UTILITIES
   TEXAS UTILITIES
   UTAH POWER & LIGHT
   UTAH POWER & LIGHT
   UTAH POWER & LIGHT
   VIRGINIA ELECTRIC * POWER
   WISCONSIN POWER & LIGHT
                                         UNIT  NAME
  HENRY  tt.  PERKEY  1
  SOUTHWEST 1
  OALLMAN  3
  &.  F.  WEATUN 1
  BIG bEND  4
  JUHNSONVILLE
  PARADISE  1
  PARADISE  2
  SHAWNEE  10A
  SHAWNEE  10B
  WIDOWS CREEK 7
  WIDOWS CREEK 8
  GIBBONS  CREEK 1
  SANDOW 4
  TWIN OAKS 1
  TWIN OAKS 2
  FOREST GROVE 1
  MARTIN LAKE  1
  MARTIN LAKE  2
  MARTIN LAKE  3
  MARTIN LAKE  4
  MONTICELLO 3
  EMERY  1
  EMERY  2
  HUNTINGTON 1
  MT. STORM
  COLUMBIA 2
STAHT UP DATE
2-84
4-77
7-80
12-78
0-85
0-82
0-82
0- 0
4-72
4-72
10-80
b-77
1-82
7-BO
8-83
9-84
0-81
8-77
5-78
12-78
8-50
5-78
1-79
6-80
5-78
0- 0
1-80
STATUS
3
1
2
2
6
6
5
5
1
1
2
1
3
3
b
6
5
1
1
2
3
1
2
2
1
7
3
REG
CLASS
A
A
A
H
A
c
c
c
c
c
c
c
A
A
A
A
A
A
A
A
A
A
A
A
A
C
A
1.  OPERATIONAL UNITS
a.  UNITS UNDER CONSTRUCTION
3.  PLANNED - CONTRACT AWARDED
4.  PLANNED - LETTER OF INTENT SIGNED
5.  PLANNED - REQUESTING/EVALUATING BIDS
6.  CONSIDERING ONLY FGO SYSTEMS
7.  CONSIDERING FGO SYSTEMS AS WELL AS ALTERNATIVE  METHODS
A.  BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
B.  BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
C.  BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
D.  OTHER
E.  REGULATORY CLASS UNKNOWN

-------
EPA UTILITY F60 SURVEY: OCTOBER  1978 - NOVEMBER 1978
 UNIT IDENTIFICATION
                                            SECTION 2
                                       STATUS OF FGD SYSTEMS
                                                               CURRENT STATUS
ALABAMA ELECTRIC COOP
TOMBIGBEE £
  225  MM - NEN
COAL; 1.15X SULFUR
PEABODY PROCESS SYSTEMS
LIMESTONE
STARTUP   9/78
REFER TO SECTION 3 OF THIS KEPOHT FOK ADDITIONAL INFOKMATItlN. PEABUUY
PROCESS SYSTEMS WAS AWARDED A CONTRACT FOR THE IiMS IALLA1 IUiM OF A LlUt-
STONE FGD SYSTEM ON THIS UNIT. A HIGH-EFFICIENCY ESK INSTALLED UPSIKhAM UF
THE FGO SYSTEM PROVIDES PRIMARY PARTICULATE CONIROL. THE  FGO SYSTEM CUR-
TAINS TWO SCRUBBING TRAINS, TREATING APPRUX1MAttLY 70X UF THE FLUE GAS FUK
REMOVAL OF S02. STACK GAS REHEAT IS NUT REOU1KED. THE UNIT IS CURRENTLY IN
THE SHAKEDOWN-DEBUGGING PHASE OF OPERATIONS.
ALABAMA ELECTRIC COOP
TOMBIGBEE 3
  225  MH - NEH
COAL; i.isx SULFUR
PEABUDY PROCESS SYSTEMS
LIMESTONE
STARTUP   6/79
PEABODY PROCESS SYSTEMS HAS BEEN AWARDED A CUNTKACT FUK THE INSTALLATION
OF A LIMESTONE FGO SYSTEM ON IHIS UNIT. A HIGH-bFUC 1 ENCY ESP "ILL
BE INSTALLED UPSTREAM UF THE FGO SYSTEM TO PROVIDE PKIMAKY
PARTICULATE CONTROL. THE FGO SYSTEM CONSISTS UF  FwO TWAINS, TOGETHER
TREATING APPROXIMATELY 70X OF THE FLUE GAS FOR REMOVAL UF SULFUK
DIOXIDE. STACK GAS REHEAT WILL NOT BE REUUIKED.  CUNSTRUU10N ON THE UNIT
TURBINE AND BOILER IS NOW SOX COMPLETE.
ALLEGHENY POWER SYSTEM
PLEASANTS 1
  625  MM - NEN
COAL; o.sx SULFUR
BABCOCK & WILCOX
LIME
STARTUP   3/79
THE THREE PRINCIPAL OPERATING UTILITY CUMPANIES OF THE ALLEGHENY PUwEK
SYSTEM ARE INSTALLING AN EMISSION CONTROL SYSTEM FOR THIS NEW CUAL-FIKEU
UNIT WHICH INCLUDES A HIGH EFFICIENCY ESP UPSTkEAM OF FUUK TRAY TUWEKS
FOR THE CONTROL OF PAHTICULATES AND SULFUK DIUXIOE. DESIGN RfcKOVAL
EFFICIENCIES FOR THIS EMISSION CONTROL SYSTEM ARE V9.5 AND 90 PERCENT
RESPECTIVELY. THE DRAVO CO. IS SUPPLYING THIOSORdIC LIME. THt CUNSULTING
ENGINEERING FIRM IS UNITED ENGINEERS AND CONSTRUCTORS. CURKENTLY, EREC-
TION OF THE SCRUBBING EUUIPMENT IS IN PROGRESS.
ALLEGHENY POWER SYSTEM
PLEASANTS 2
  625  MM - NEW
COAL; 4.5X SULFUR
BABCOCK S WILCOX
LIME
STARTUP   3/80
THE THREE PRINCIPAL OPERATING UTILITY CUMPANIES OF I HE ALLEGHENY POWER
SYSTEM ARE INSTALLING AN EMISSION CONTROL SYSTEM FOR  THIS NEW CUAL-F IKKI)
UNIT WHICH INCLUDES A HIGH EFFICIENCY ESP uPSTRtAM UF FUUR TKAY TUwEkS
FOR THE CONTROL OF PARTICIPATES AND SULFUR DIOXIDE. DESIGN REMOVAL
EFFICIENCIES FOR THIS EMISSION CONTROL SYSTEM ARE 99.b AND 90 PERCENT,
RESPECTIVELY. THE DRAVO CO. IS SUPPLYING TH10SOK8IC LIME. THE CONSULTING
ENGINEERING FIRM IS UNITED ENGINEERS AND CONSTRUCTORS. CURRENTLY, FOUNDA-
TION WORK ON THE SCRUBBER PLANT IS IN PROGRESS.
ARIZONA ELECTRIC POWER COOP
APACHE 2
  200  MM - NEN
COAL; 0.7X SULFUR, iox ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP   8/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE FGD
SYSTEM FOR THIS NEW 200 MW UNIT WAS SUPPLIED BY RESEARCH CUTTRELL. THE
DESIGN INCLUDES A 22 ACRE SLUDGE POND AND A 64 ACKE ASH PUND, BUTH [IF
WHICH ARE UNLINED AND TEN FEET DEEP. A KEHEAT SYSTEM IS NUT INCLUDED. THE
LINERS USED IN THE STACK AND THE DUCTS THAT LEAD TO THE STACK AKE A NE*
COLE BRAND CXL2000 WHICH HAS A VERY HIGH HEAT RESISTANCE. THIS UNIT BURNS
BITUMINOUS COAL WITH SULFUR AND ASH CUNTENTS OF .7X AND IOX RESPECTIVELY.
INITIAL OPERATION OF THIS UNIT BEGAN IN AUGUST, 1970.
ARIZONA ELECTRIC POWER COOP
APACHE 3
  200  MW • NEN
COAL; o.?x SULFUR, iox ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP   4/79
CONSTRUCTION OF UNIT 3 IS NOW ESSENTIALLY COMPLETE.  STRUCTURE
ERECTION OF THE SCRUBBER-ABSORBER TOWERS IS COMPLETE. EACH SCRUBBER CAN
HANDLE 400,000 ACFM o> 270 F AND RECIRCULATE 20,000 GPM OF SLURRY. HUILER
CONSTRUCTION HAS BEGUN. THERE ARE CURRENTLY 2 PONDS WITH A TOTAL OF 20-
YRS CAPACITY FOR THE DISPOSAL OF THE UNFIXATEO SLUDGE. 2 ADDITIONAL PONDS
ARE PLANNED PROVIDING AN ADDITIONAL 20 YRS OF DISPOSAL CAPABILITY. THERE
WILL BE NO REHEAT. BECAUSE OF THE HIGH COST OF THE UNIT 2 STACK UNEK,
UNIT 3 WILL USE A CEILCOTE LINING INSTEAD OF THE CXL2000 USED IN UNIT 2.
ARIZONA PUBLIC SERVICE
CHOLLA 1
  115  MW • RETROFIT
COAL; o.ssx SULFUR, iox ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP  10/73
REFER TO SECTION 3 OF THIS REPORT FUK ADDIIlUNAL INFUKMATIUN.
THIS LIMESTONE SCRUBBING SYSTEM WAS PLACED IN SERVICE IN OCTOBER 1973.
THE SCRUBBER PLANT CONSISTS OF TWO PARALLEL SCRUBBING TRAINS. PARTICU-
LATE CONTROL IS PROVIDED BY TWO FLOOOEO-DISC SCRUBBERS. S02 CONTROL  IS
PROVIDED BY ONE PACKED (MUNTERS PACKING) TOWER IA-SIOE). FLUE GAS CLEAN-
ING WASTES ARE DISCHARGED TO AN EXISTING FLY ASH POND. NO WATER IS Kt-
CYCLED BACK FROM THE DISPOSAL POND. IN-LINE STEAM KEHEATERS RAISE THt
GAS TEMPERATURE 40 F.
ARIZONA PUBLIC SERVICE
CHOLLA 2
  250  MW - NEW
COAL; o.ssx SULFUR, iox ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP   4/78
REFER '- SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE CONTRACT FOR THIS WET LIMESTONE SCRUBBING SYSTEM WAS AWARDED BY THE
UTILITY TO RESEARCH-COTTRELL. THE DESIGN INCLUDES MECHANICAL COLLECTORS
FOR PRIMARY PARTICULAR REMOVAL. THE FGU SYSTEM CONSISTS OF FOUR PARALLEL
FLOODEO-OISC AND PACKED TOWER ABSORBER TRAINS. THREE ARE REQUIRED FUR FULL
LOAD CAPACITY. INITIAL OPERATIONS BEGAN IN JUNE 1978. COMPLIANCE TESTING
WAS COMPLETED OUR1NS THE SECOND WEEK UF AUGUST 1978. THE UNIT  IS CURRENTLY
UNDERGOING SHAKEDOWN AND DEBUGGING OPERATIONS.

-------
                                                   EPA  UTILIIT  FGD  SOKVEY:  UCIUbtK l-»7rt -
                                                                                                    14/ri
                                             SECTION  e
                                        STATUS OF FGU SYSTEMS
 UNIT IDENTIFICATION
                                                                 CURRENT  SIATlJb
ARIZONA PUBLIC  SEKVICE
CHOLLA 4
  350  MW -  NEH
COAL; o.?x SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP   6/80
UNI! NO. 4  IS CURRENTLY  UNDER  CON!) 1KUC HUN. AKb HAb AMKDtD If^ Fu.ll Cuu-
TRACT TO RESEARCH COTTHELL.  THE  STATE REGULAIUF.Y AGENCY hAb NUT Yt I ut-
CIUEO THE EMISSIONS  REGULATIONS  WHICH WILL APHLY )u Iht J-LA^l. IHt U-t
BOILER WILL FIkE  THE  SAME  COAL AS CHOLLA ,xO. 1, *11H bliLFUK LUfjJt*! OF
0.44-1.0 PERCENT. THt  A-E  FIRM IS tBASCO. TMfc FbJ SYblFM IS A IHJUrtLt LUOf
LIMESTONE ABSORPTION  PROCESS ANO REVENUES OF iHh. LnuTRACT lu h-C A.U
REPORTED TO BE  $5 MM.  FOR  CONTROL OF PARTICULAlt AN tbP flli. HAMJLt H'UZ
OF THE FLUE GAS.
ARIZONA PUBLIC  SERVICE
FOUR CORNERS  1
  175  MM • RETROFIT
COAL; o.rx SULFUR,  23.ox ASH
CHEMICO/APS
LIME/ALKALINE FLYASH
STARTUP   0/79
APS IS UPGRADING  THE  OPERATIONAL PARTlCOLAIt bCRUrtHtKb AT THt FUUK
CORNERS 1, 2 ANO  3  FOR  ADDITIONAL Sod REMOVAL. LOHRtMLY, FACH il«II HAS e.
CHEMICO VENTURI SCRUBBER  MODULES FOK HAHTlCuLATt CONTROL. KUIK.HLY Jui. UF
THE FLUE GAS 802  CONTEM  IS  HEMOVtD AT THE PKEbt'Jl I IMF  lu THE VH.TuxlS
WITH THE HIGH  ALKALINE  FLYASH.  NEW MF.X1CO ARC UFFICAL5 IfiOlCAIED THAT
THE 5 FOUR CORNERS  UNITS  WILL BE REUUIREu To KthuVfc AT LtASI  b7.bi OF 1HF
STATION SOU  (ALL  5  UNITS  CONSlOERtO TOGETHER). Al)i> I I IDivAL ALKALINITY rtlLL
BE IMPARTED  TO  THE  SCROBBlNG SOLUTION Br ADOlNb
ARIZONA PUBLIC  SERVICE
FOUR CORNERS  2
  175  MH - RETROFIT
COAL; o.?x SULFUR,  23.ox ASH
CHEMICO/AP3
LIME/ALKALINE FLYASH
STARTUP   0/79
APS IS .JPUHADI^G  THE  OPERATIONAL PJftT ' CL'L ATE SChUrtdEwa «l Tilt FUu«
CORNERS UNIT  .'IOS.  1.  2  ANO 3 FOR ADO" IONAL SOd REMOVAL. tACH UNIT H«i> t
CHEMICO VENTURI SCRUBBER  MOOULES FOh HARFICULAlh CO^lKOL. RUUUHLY iOX ciF
THE FLOE GAS  S02  CONTENT  IS REMOVED AT  THE PRESENl IIME IN THE VEnTUKli,
WITH THE HIGH ALKALINE  FLYASH. NEW MEXICO APC OFFICALb 1NOICAIEI)  1HA1
THE 5 FOUR CORNERS UNITS  MILL BE REUOIREO Fj REMOVd Al LFAS1 67.b^ (IF I MR
STATION SOi  (ALL  5 UNITS,  CONSIDERED TOGETHtR). AUOIFONAL *LnALInllT .tlLL
BE IMPARTED  TO THE SCRUBBING SOLUHUN HY ADOINb
ARIZONA PUBLIC  SEKVICE
FOUR CORNERS  3
  229  MM - RETROFIT
COAL; o.7x SULFUR*  23.ox ASH
CHEMICO/APS
LIME/ALKALINE FLYASH
STARTUP   0/79
APS IS UPGRADING  THE  OPERAIlONAL PAHIICULAIE bCNUbrttKb Al  Int FUUK
CORNERS UNIT  NOS.  1,  2  ANO 3 FOR ADDITIONAL SU£ KtMOvAL. tAC" nr/ll HAb e
CHEMICO VENTURI SCRUBBER  MODOLES FOK PAKTICOLATE C.OMKOL. ROUbnLY iu* UK
THE FLUE GAS  S02  CONTENT  IS REMOVED Al 1 ME HrfESt.xT TI.-E In 1HE vbNluwIb
WITH THE HIGH ALKALINE  FLYASH. NEtt MEXICO APC UFFICALS INDICATED  THAT
THE S FOUR CORNERS UNITS  rtlLL BE HEOUIRED IO Rf^OVE Al LEAbl h/.bX OF fHF
STATION S02  (ALL  5 UNITS  CONSIDERED TOGETHER). AOUMIUNAL ALKALINITY nRL
BE IMPARTED  TO THE SCRUBBING SOLUTION BY ADDING LIME.
ARIZONA PUBLIC  SERVICE
FOUR CORNERS  4
  755  MN  - RETROFIT
COAL; 0.7% SULFURf  23.ox ASH
UNITED EN6INEERS
PROCESS NOT SELECTED
STARTUP    0/62
THE UllLIfV  IS  CURRENfLY  EVALUAllNG IHE !>AIA »Nl/ livf" J«f A I IU.M ACCUMuLAIEu
DURING  THE HORIZONTAL  PROTOTYPE SChUBH!
-------
EPA UTILITY FbO SURVEY: OCTOBER  1978 - NOVEMBER  1978
                                            SECTION 2
                                       STATUS OF FGO SYSTEMS
 UNIT IDENTIFICATION
                                                               CURRENT STATUS
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 2
  455  MW - NEW
LIGNITE; 0.681 SULFUK, 8X ASH
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP  11/83
TMfc UTILITY IS TENTATIVELY INVESTIGATING VARIOUS FGl) PROCESSES FOR THIS
SECOND LitNITE-HKEU UNI! SCHEDULED AT IHt NEW STATION LOCATED IN MEKCtK
COUNTY, NEAR BEULAH, NORTH DAKOTA. THIS NEW FACILITY WILL BE KNOWN AS
THE ANTELOPE VALLEY STATION AND WILL BE REuUIREU 1U COMPLY WITH STATE AIK
EMISSION STANDARDS VIA THfc BtS! AVAILABLE TECHNOLOGY. STAKT-UP IS NUrt
SCHEDULED FOR NOVEMBER 1963.
BASIN ELECTRIC POWER COOP
LARAM1E RIVER 1
  570  MW - NEW
COAL; o.ex SULFUR, TZ ASH
RESEARCH COTTRELL
LIMESTONE
STARTOP   4/80
RESEARCH-C01THELL IS CuRftENlLY FABKICAI1NG I HE OOAL-LuOK LIMES1UNE WE I
SCRUBBERS. ON-SITt CONSTRUCTION COMMENCED IN JANUARY 1978. SLUDGfc WILL BE
DEWATEREO TO B3X SOLIDS BEFORE LANDFILL. 1HE SCKUBBERS WILL BE MADE OK
SIAlULtSS STEtL AND WILL HANDLE c!.3 MM ACFM AT 286 F. L/G RATIO WILL  HE
60. B&W HAS BEEN AWARDED A CONTRACT FOR TWO tSP'S. IHb DESIGN DOES NO!
INCLODE STACK GAS HEHEAI. COOLING TOWEK SLOWDOWN WILL BE USED FUR MAKE-UP
IN THIS CLOSED LOOP SYSTEM. CONSTRUCTION IS NOW 201 COMPLETE.
BASIN ELECTRIC POWE* COOP
LARAMIE RIVER 2
  570  «« - NEW
COAL; o.ex SULFUR, 7t ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP  10/80
ftt&ESKCH-COTTRELL IS CURRENTLY FABRICATING 1 ME DUAL-LUOP LlnEaTONE w£1
SCRUBBERS. ON-SITE CONSTRUCTION CUMf-ENCEl) IN JANUARY 1978. SLUDGE WILL  BE
L.C«A i*EU TO 83X SOLIDS BEFORE LA.JOFILL. THE SCKUB8ERS WILL BE MADE OF
STAINLESS STEEL ANO WILL HANDLE 2.3 MM ACFM AT 286 F. L/G RATIO ttlLL HE
60. B&w HAS BEEN AWARDED A CONTKACT FOR ! WO ESP'S. THE UfcSIbN DOES NO!
INCLUDE STACK GAS RhHEAl. COOLING TOWtR SLOWDOWN WILL BE USED FUR MAKE-UP
IN THIS CLOSED LOOP SYSTEM. CONSTRUCTION IS NOW 20X COMPLETE.
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 3
  550  MW - NEW
COAL; 0.8X SULFUR, 7X ASH
BABCOCK S HILCOX
PROCESS NOT SELECTED
STARTUP   4/82
LARAMIE RIVER STATION WILL FIRE SUB-BITUMINUUS COAL WITH THE FOLLOWING
CHARACTERISTICS: 8100 BTU/LB, O.tt PERCENT SULFUR AND 7.0 PERCENT ASH. A
CONTRACT FOR A DRY TYPt FGD SYSTtM HAS BEEN AWARDED TO BABCOCK & WlLCUX.
BI6 RIVERS ELECIKIC
GREEN 1
  250  MH - NEw
COAL; 3.75X SULFUR
AMERICAN AIR FILTER
LIME
STARTUP  12/79
THE EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIREO UMI IS BEING SUP-
PLIED BY AMERICAN AIR FILTER. THE SYSTEM WILL CONSIST OF A COLO-SIDE ESP
AND TWO SPRAY TOWERS CONTROLLING PARTICULATE ANO S02 TO 99.6 PERCENT AND
90 PERCENT, RESPECT1VLEY. THE B&W BOILER WILL FIRt HIGH SULFUR  13.5  Tu
4.5 PERCENT) WESTERN KENTUCKY COAL. CONSTRUCTION IS NUh 66X
COMPLETE ON THE BOILER ANO 3
-------
                                                    EPA  UTILITY FbO SURVEY: OCTOBER  IS/fi  -  NUV b ^r>e R
                                              SECTION  e!
                                        STATUS  OF  FGD SYSTEMS
 UNIT IDENTIFICATION
                                                                 COKHEl.T STATUS
CENTRAL  ILLINOIS  PUBLIC SERV
NEWTON 1
  575  MW -  NEW
COAL; 4X SULFUR
BUELL/ENVIROTECH
DOUBLE ALKALI
STARTUP  11/79
A CONTRACT HAS  BEEN  AnAROED HY CIPSCO TU BUELL/E N V I HI) I fc;CH  FOR  Tue
INSTALLATION  OF  AN EMISSION CONTwnc SYSTEM ON UNtl 1. I HE  >• t Y  COM-
PONENTS UF THE  EMISSION CUNIRUL SYSTEM luLLUDt: A  H1GH-EFFICItNCY  EbP;
FOUR PRECOULERS,  FOOK  PULYSPHERE ABbLKljtRb,  THuEE  THICK t'.tKb,  T.-.o  EX-
PERIMENTAL REHEAT SYSTEMS,  AND THKEE HURI/U'ITAL EXTKACI ION  FILTERS  HIK
SLUDGE DEftATEKlfJb. MOKE THAN bO PERCEM ilF I  HE CuivS t ROC T I'JN  ftURK.
AT THE PLANT  HAS  MEEN  COMPLETED. THE FI,IJ bYbit* *ILL  HAVE  CEILCOTE-
LINED ABSORBER  MODULES.
CENTRAL MAINE  POWER
SEARS ISLAND  1
  600  MW - NEW
COAL; SOURCE  UNDETERMINED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP  11/86
BECAUSE OF  THE  DISCOVERY OF A GEllLOl, I C AL FAOLI 0"J  StARS  ISLAND,  THE
UTILITY HAS  CANCELLtO PLANS FOR A HbU-r-., NUCLEAR  Ki,,-,tR  PLANT.  A
600-Mrt COAL-FiKfcD  UNIT  IS NOW BE I hi, PLANNED  In ITS  PLACE.  CO'- ME RCI AL
OPERATION  IS  PROJECTED  FUK NOVEMBER l^db. COMPLIANCE  .'.ITH  SU£  NbPb  ,11L L
BE ACHIEVED  BY  INSTALLING AN FGD SYSTEM. L1.- E ANiJ  L I'-.ES TOi.. CUrtntNfLY,  CMPCO HAa
FILED AN APPLICATION rtllH THE SIATE PUBLIC OIILUIcb  COMMISSION.  AN  tu-
VIKUNMENTAL  PEKMIT  APPLICATION rtILL 'it FILED .'. 1 I n [ w  THE  Nt»l  UO  YtAi-'b.
CINCINNATI GAS  &  ELECTRIC
EAST BEND 2
  600  MW -  NEW
COAL
BABCOCK & WILCOX
LIME
STARTUP   1/81
A CONTRACT HAS  BEEN  CONO I TIONALL Y AWARDED TO r»AbCUCi\  AND  AlLCUX  F UK A
COMMERCIAL LIME  SCKOddI'MG  SYSTEM. IHE COAL bOOKCF.  IS  txPECTcD  TU Bt A
WESTERN KENTUCKY  COAL rtlTH A HIliM SULFUK CO^ftM.   THE  THKeE  LI.'-iE  SLUKHY
FGO MODULES  ftlLL  8E  PRECEDED BY Hit ESP FOK PAKTIUULATt  COnTKOL.  A  COHlKACT
HAS BEEN CONDITIONALLY AWARDED TO IUCS FOR THE SLODGt FIXATION.  THK A-t
FIRM  IS SARGENT  AND  LUNDY. UfJlT FOONJAT IO.J Clli.S T ROC I I Of. HAS  rt£(,UN  AND
FGO SYSTEM CONSTRUCT loh «1LL BEGIN IN tAHLY  IS/9.
CULUKADU UIE  ELECIRIC ASSN.
CRAIG 1
  450  MW - NEW
COAL; o.4sx SULFUR
PEABODV PROCESS  SYSTEMS
LIMESTONE
STARTUP   3/79
COLORADO UTE  ELECTRIC ASSN.
CRAIG 2
  450  MW - NEW
COAL; 0.45X SULFUR
PEABOOY PROCESS  SYSTEMS
LIMESTONE
STARTUP   3/79
COLUMBUS & SOUTHERN OHIO ELEC.
CONESVILLE 5
  400  MM - NEW
COAL; 4.7X SULFUR,  15.IX ASH
AIR CORRECTION DIVISION, UOP
LIME (MG-PROMOTED)
STARTUP   1/77
PEABOOY PROCESS  SYSIEMb HAb BEEN AWARDED A CimlxACI  lu  DEsIG'.  Ann
SOPPLY A LIMESTONE  SLURRY SPRAY TV.vtR AciSUROtH  SYSTEM FUR  502  KEMOVAL
FROM LUW-SULFUH  COAL-FIRED BOILER FLUE GAS FOK  U'.'lTb  1  AMU 
-------
EPA UTILITY F6D SURVEY: OCTOBER  1978 - NOVEMBER  1978
 UNIT
                                            SECTION 2
                                       STATUS UF FGD SYSTEMS

      IDENTIFICATION                                           CURRENT  STAlUS
COLUMBUS & SOUTHERN OHIO ELEC. THIS UNIT WILL BURN HIGH SULFUR  CuAL  I APPRO* IMA TEL Y  !, UNE OF  I .Ml
IDENTICAL BOILERS SUPPLYING STEAM TO AN HbO-MW 1UKrtlNt-Gt "*KATOK.  TnK
SLUDGE HILL BE STABILIZED AND HAOLED TO A LANDFILL. HtntA! WILL  Hfc
PROVIDED BY A STEAM COIL WHICH WILL HtAT THE AMBIENT AIK THAT IS HUHPtli
INTO THE SCRUBBER OUTLET BEFORE THE FLUE GAS ENTERS iHb SUCK.  THfe  SOrf
EMISSION S1ANDARD IS 1.8 LB. SOa/MM tjTO. CURRtMLY, EXCAVATION,  'UCKFlLL,
AND STRUCTURAL STEEL ERECTION IS IN PROGRESS.
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
  545  MH - NEW
LIGNITE! 0.63X SULFUR
COMBUSTION ENGINEERING
LIME
STARTUP   2/79
                               THIS UNIT  IS UNDER  THE COMBINED  OWNERSHIP  OK  COOP  POWER  AND ONIltD
                               A CONTRACT HAS BEEN AWARDED  TO COMBUSlIUN  ENGINEERING  FOR  THE INSIALLA-
                               TION OF LIME FGD SYSTEMS ON  OMTS  1  AND  i  Al  THIS  STAllUlv.  THE F(,0 SYSlfcM
                               FOR EACH BOILER WILL CONSIST  UF  FOUR SPRAY  HlwtR AdSORStk  MODOLfcS KOR S0i>
                               REMOVAL. ELECTROSTATIC PRECIPITATURS WILL  BE  INSTALLED UPSTREAK  UF EACH
                               ABSORBER TRAIN. CONSTHOCTION  bEGAN EARLY IN AUGOS!  1977.  THE DMT IS hi Off
                               85-90X COMPLETE. BAD WINTER  WEATHER  SLOWED  CONSTKUCUUN  SLIGHTLY.
COOPERATIVE POWER ASSOCIATION  THIS UNIT  IS UNDER  THE  COMBINED  OWNERSHIP  OF  COUP  POrtER AND UMTt.D HuwER
                               A CONTRACT HAS BEEN  AWARDED  TO  COMBOSIIUN  ENGINEERING  FUR THfc INMALLA-
                               OF LIME FGD SYSTEMS  UN  UNITS  1  AND  i.  AT  THIS  STATION.  TnE F-bD SYSTEM F-uK
                               EACH BOILER WILL CONSIST  OF FUUR  SPRAY  TOWER  AHSOhBER  MODULES FOR SUe
                               REMOVAL. ELECTROSTATIC  PRECIP1 T A TORS  WILL  tit  INSTALLl-.O UPSTKtAf Cit- EACH
                               ABSORBER TRAIN. CONSTRUCTION  BEGAN  IN AUGUSI  19/7  AND  THE UNIT is NOW <4t>*
                               COMPLETE. THERE HAVE BEEN MINOR DELAYS BUI  START-UP  IS STILL SCHEDULED FUR
                               NOVEMBER 1979.

                               DELMARVA'S DELAWARE  CITY  PLAN I  HAS  a  BOILERS,  i  OF wnlCH HAVE SIEAM CAPA-
                               CITIES OF 500K LBS/HK EACH.  THE BUILEKS  GENtRAU STEA* AS WELL AS ELKCTKI-
                               CAL POWER FOR GETTY  REFINING  «  MARKETING.  7-8i S COKE  WILL BE HORNEU IN
                               THE BOILERS (INSTEAD OF  THE LOW-S CRUDE  OIL NOW  HURNED)  wHtN THE COufHUL
                               SYSTEM GOES INTO OPERATION  IN APRIL 1980.  DELMARVA WILL  USE VENTIJRI SCRUB-
                               BERS FOR PARTICULATE REMOVAL  AND  WELLMAN LORD  FGD  SYSTEMS AT EACH rtUlLER
                               GAS EXIT FOR S02 CONTROL. DESIGN  PAkTICULATt  AND SOi REMOVAL EFFICIEN-
                               CIES ARE 90 AND 85-90 PERCENT RESPECTIVELY. CUNSlKUCTION IS IU COMPLETE.

                               REFER TO SECTION 3 OF THIS  REPORT FOR ADDITIONAL  INFORMATION.
                               THE FGD SYSTEM ON THIS  
-------
                                                   tPA UIILITr FGu  buwvkY:  uciuntK
                                                                                           NuvLi*rtLr
 UNIT IDENTIFICATION
                                             SECTION
                                        STATUS OF FtO
                                                      SYSTEMS
                                                                CUHKENF  blAlOb
GENERAL PUBLIC UTILITIES
COHO 1
  800  MW - NEW
COAL; 3.5X SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   5/88
STARTUP DATE MAS CHANGED  TO  b/88  FUK  BOTH HulLtK 4NU HE SULF UK 1L A T Illu
SYSTEM LIME AND LlMESTurtE  SCKUBdING  AK£  THE  Pnlr-.AKY SIxATtblES  rttl'H*
CONSIDERED FOrf COMPLIANCE  WITH  NEw  bounct PtuFUKMariut s> UIVDAKDS. riu
DECISION HAS BEEN MAOh  YET,  ALTHOUGH  A bLUMrtY TYPt sYSTtf IS MM
CONTEMPLATED.
GENERAL PUBLIC  UTILITIES
SEWARD 7
  800  MM - NEW
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   5/85
STARTUP DATE WAS  CHANGED  TO  b/85 I-ON bUtH BOlLtK AND OES'lLF UK 1/A T [ill,
SYSTEM LIME AND LIMESTONE  SCRUBBING AKE THE PKIMAKY blKAttGItS Mtl-il,
CONSIDERED FOR COMPLIANCt  WITH  Hit, SOUKCt PkHHlNMANCt SlAiiOAKUS. HO
DECISION HAS BEEN MADE  YET,  ALTHOUGH SLUrtkY [YHfc ft ILL NUT ot DSEU.
GULF POWER
SCHOLZ 1 ft 2
   23  MW - RETROFIT
COAL; ax SULFUR,  iix  ASH
CHIYODA INTERNATIONAL
THOROUGHBRED 121
STARTUP   8/78
REFER TO SECTION  3  OF  THIS  REPORT  FOH ADDITIONAL INF UKMAl 1 Dr.. UHlYUliA  h.-
TERNATIONAL SUPPLIED  THIS  23 MW PMlTOlYPE uull  AHlCH ritb»n oHtKATlin, IM
AUGUST 30,  1978.  THE  CT-121  SYSTEM INCLUDES A r,t*LY DEVELOPED JET
BUBBLING REACTOR  WHICH FEATURES A  LAKbE bAS-LlUUlD lulEKFACIAL AKEA AM)
PROVIDES PARTICOLATE  AS WELL AS su^ KEMOVAL. »-ibT ELIMINATION ib PKUVIOLU
BY A DOUBLE PASS  VERTICAL  CHEVKON. GYPSUM IS PKuOUCED AIM!) bUCKED in INK
EXISTING POND.  THE  STACKING  CAPABILITIES OF THt GYPSUM AKt UhIMG Tfcblti)
ALONG WITH  THE  GHUUNO  WATER  NEAK THE STAC^ SITE To CHECK FUK Lf.ECH I NI, .
HOOSIER ENERGY
MEROM 1
  490  MW •  NEW
COAL; 3.sx SULFUR
MITSUBISHI INTERNATIONAL
LIMESTONE
STARTUP   4/81
HOOSIER ENERGY
MEROM 2
  490  MW - NEW
COAL; 3.sx SULFUR
MITSUBISHI INTERNATIONAL
LIMESTONE
STARTUP   1/82
INDIANAPOLIS  POWER  S  LIGHT
PETERSBURG 3
  530  MW - NEW
COAL; 3.25X SULFUR, 9.5X ASH
AIR CORRECTION DIVISION, UOP
LIMESTONE
STARTUP  10/77
HOOSIER ENERGY  AWARDED  A  CONIKACI  lu MITSUBISHI In I t«i»A I IUNAL LUKP.
FOR TWO LIMESTONE  FGO  SYSTEMS FUK  MErtOM 1  AND •. CUAL-t-InKn
UNITS ARE PLANNED  FOR  LOCATION IN  SULLIVAN, INDIANA. IHt FLUh (,A.S b[KK«(-S
WILL BE CLEANED  OF PAKTICOLATES WITH ESP'S 194. <4i) AND OF SULHUK i)IuXti)E
WITH GRID-10WEH  ABSOHBEKS 190*) . SLUDliE wILL BE SlAolLlZtu Aijij sUCK
PILED.  THE GROUND  WAS  8KOKEN FOH CONSTKOCTION IN NUVE^HEK 1977, HUT nut
TO THE  BAD WlNf£R  WEATHER,  CONST HOC T IUM WAS OtLAYEO. CUNS TKUC T [Uu HAS
PROCEEDED ACCORDING TO  SCHEDOLE THROUGH THE bUMMEK.

HOOSIER ENERGY  AWARDED  A  CONTRACT  TO MITSUBISHI IivTtK-iAT IUNAL CUKP.
FOR TWO LIMESTONE  FGO  SYSTEMS FOR  MEKOM 1  AND £. 1 HE I-.E.M ^4U Mrt COAL-HIwtO
UNITS ARE PLANNED  FOR  LOCATION IN  SULLIVAN, INDIANA. Tut FLilt GAS 3 f K t A !•< s
WILL BE CLEANED  OF PARTICULATES WITH ESP'S [94.«XJ ANU Oh SULHIK UIn*lDt
WITH GRIO-TOwER  ABSORBtHS (90X). SLUDGE «1LL HE STAblLUtU A,IU STuCi\
PILED.  THE GROUND  WAS  BROKEN FOR CONSTKUCTIUN IN NOvEMHtK 1477, Hul nut
TO THE  BAD WINTER  rttATHER,  CONSTRUCTION  WAS DELAYED. InE bUILtK IS
ESSENTALLY COMPLETE. STAKTUP IS EXPECTED SHUKILY.

REFER TO SECTION 3 OF  THIS  REPORT  FOH ADDITIONAL INFUKN- A T ION. THt at I
LIMESTONE FGD SYSTEM INSTALLED ON  THIS ONIT WAS SUPPLIED BY THE AIx
CORRECTION DIVISION OF  UOP.  UNIT 3 FIHES BITUMINOUS  COAL HAVING A SuLhUK
CONTENT OF 3.0-3.5X, AN ASH  CONTENT OF 9-101 AND A ll.OUU HlU/LB MfcATIm.
VALUE.  TWO ESPS  PROVIDE PRIMARY PARTICOLATE CuMKUL  UHSTKEAM OF A rliUK-
MOOULE  TCA FGO  SYSTEM.  STABILIZED  SLUDGE IS DISPOSED ON AN Of-,-SlTE
THE DESIGN INCLUDES AN  INDIRECT STEAM TUBE KEHEAI SYSTEM.
GING OPERATIONS  ARE STILL PRUCEDING.
INDIANAPOLIS PUWER  ft  LIGHT
PETERSBURG 4
  530  MW - NEW
COAL; 3.5X SULFUR,  1UX  ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP  10/83
INDIANAPOLIS POWER  &  LIGHI  AWAKDEU A CONIKACT iu KESEAKCH CUIIKELL FUK
LIMESTONE FGD SYSTEM.  SOa  REMOVAL  EFFICIENCY rtlLL HE APPKOX IMA 1 tL Y
80 PERCENT. THIS NEW  UNIT  WILL  FIRE Hl&H-SULFUH SUribl I UM l.MUUS COAL «IlH
A HEATING VALUE OF  11,000  8TU/LB  AND ASH AND SuLFuR CUNTENTS OF lu
AND 3.5 PERCENT, RESPECTIVELY.  SLUDGt WILL bt DtwAIEHtD Ar40 MIXED
FLYASH TO PRODUCE A DRY  STABILIZED PROOOCI. EXCAVA T iu>v, FOUNDATION
WORK AND SOME STEEL WORK  IS NOW IN PROGRESS ON THE UNIT.
KANSAS CITY POWER  ft  LIGHT
HAWTHORN 3
  100  MW - RETROFIT
COAL; ax SULFUR, u.sx  ASH
COMBUSTION ENGINEERING
LIME
STARTUP  11/72
REFER TO SECTION  3  OF  THIS  REPORT  FUR ADOIHoNAL ImFUHMAI lOw.
THE SCRUBBER-ABSORBER  SYSTEM  ON THIS UNIT WAS CONVEKltO FKOM A LIMESTONE
FURNACE INJECTION AND  TAIL-END  SYSTEM TO A TAIL-END LIfE SLUHHY SYSTEM.
OPERATION IN THE  LIME  SCRUBBING MODE COMMENCED UN FEBKOAKY 7, 1977. Cun-
PLIANCE TEST RESULTS INDICATED  THE UNIT  MEETS THE KANSAS CITY 0.17 Lrt/
MM BTU PARTICULATE  REG.  FGD SYSTEM DESIGN INCLUDES A FINNtD-TUbE STtAM
REHEATER, AN ON-SITE UNLINED  SLUOliE DISPOSAL POND, AND A CrtEVKON HIST
ELIMINATOR SYSTEM.  THE Z FGO  MOOULES CAN BE BY-PASStO IN EMERGENCIES.

-------
EPA UTILITY FGO SURVEY: OCTOBER  1978 - NOVEMBER  1978
                                            SECT ION i.
                                       STATUS OF FGO SYSTEMS
 UNIT IDENTIFICATION
                                                               CURRENT STATUS
KANSAS CITY POWER & LIGHT
HAWTHORN 4
  100  MM - RETROFIT
COAL; 2X SULFUR, 12.51 ASH
COMBUSTION ENGINEERING
LIME
STARTUP   8/72
                               REFER TO StCTIUN 3 OF THIS REPORT FOR AODIT10NAL INFORMATION.
                               THE SCRUBBER-ABSORBER SYSTEM ON  THIS UNIT WAS CONVERTED FROM A LIMESTONE
                               FURNACE INJECTION AtvU TAIL-ENO SYSTEM TU A TAIL-ENO LIME SLURRY  SYSTtM.
                               OPERATION IN THE LIME SCRUBBING MOOt COMMENCtD UN JANUARY 1, 197/. COM-
                               PLIANtt TEST RESULTS INUlCATbO IHE UNIT MEETS THE KANSAS CITY O.I/ LB/
                               MM BTU PARTICULATt KtG. FGO SYSlbM OESIGN INCLUDES A HuNEll-TUBE  STEAM
                               kEHEATEW, AN ON-SITE UNLINED SLUObE DISPOSAL POND , ANO A CHEVRON MIST
                               ELIMINATOR SYSIEM. THE Z FbO MODULES CAN BE BY-PASStO  IN EMERbENC IE.S .
KANSAS CITY POWER A LIGHT
LA CYGNE 1
  820  MW - NEW
COAL; 5X SULFUR, 25X ASH
BABCOCK « wILCOX
LIMESTONE
STARTUP   2/73
                               REFER TU SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
                               THE EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED PuwER-GENERAT1NU  UNll
                               CONSISTS OF EIGHT SCRUBBER MODULES FOR FLY ASH AND 502 REMOVAL.  EACH
                               MODULE INCLUDES A VENTURI SCRUBBtw IN SERIES wITn A 2-STAGE IMPINGEMENT
                               PLATE ABSORBER. THE SCRUBBER PLANT IS AN INTEGRAL PART UF THE POrtER-
                               GENERATING COMPLEX, ALLOWING NO FLUE bAS BYPASS. INITIAL OPERATIONS
                               COMMENCED IN FEB. 1973. COMMERCIAL SERVICE IAS ATTAINED BY JUNE  19/3.
KANSAS POWER & LIGHT
JEFFREY 1
  680  MM - NEW
COAL; o.3x SULFUR, 7.sx ASH
COMBUSTION ENGINEERING
LIMESTONE
STARTUP   8/78
                               REFER TO SECTION 3 UF THIS REPORT FOR ADDITIONAL INFORMATION. COMBUSTION
                               ENGINEERING SUPPLIED THE LIMESTONE EMISSIUN CONTRUL SYSIEM FOR  IHIS  NEW
                               COAL FIREO UNIT. THE SYSTEM CONSISTS UF A CULD-SIDE ESP AND SPRAY  TUrttRS
                               FOR THE CONTROL OF S02 AND PARTICULATE EMISSIONS. 301 OF  THE FLUE  GAS  Ib
                               BYPASSED FOR REHEAT. NOX EMISSIONS ARE CONTROLLED UT AN AIR OVERFIRE SYS-
                               TEM AT THE TANGENTIALLY FIRED PULVERISED BURNERS. THE CLEANED GASES  ARE
                               VENTED TO A 600 FT STACK. SLUDGE IS MIXED rtlTH BOTTOM ASH AND DISPUSEO
                               OF IN THE EXISTING ON-SiTE BOTTOM ASH POND.
                               COMBUSTION ENGINEERING  IS SUPPLYING THE EMISSION CONTROL SYSTEM  FOR  THIS
                               NEw COAL FIRED UNIT. THE SYSTEM KILL CONSIST OF A COLD SIDE ESP  ALONG  wlTH
                               SPRAY TOWERS FOR THE CONTROL OF S02 AND PARTICULATE EMISSIONS. 30* UF  THE
                               FLUE GAS WILL BE BYPASSED FOR REHEAT. AN OVERFIRE AIR SYSTEM  AT  THE  TAN-
                               GENTIAL FIREO PULVERIZED BURNERS WILL CONTROL NOX EMISSIONS.  THE  CLEANED
                               GASES WILL BE VENTED TO A 600 FT STACK. SLUDGE nILL BE MIXED  WITH BUTTOM
                               ASH AND DISPOSED ON-SITE IN THE BOTTOM ASH POND. IHE SYSTEM STEEL WUKU IS
                               UP ANO CONSTRUCTION IS  APPROXIMATELY t>OX COMPLETE.

                               REFER 10 SECIIOU 3 OF IHIS REPORT FOR ADD1IIUNAL INFORMAIION.
                               THE NEW LIMESTONE FGO SYSTEM COMMENCED OPERATIONS IN EARLY JANUARY 19/7.
                               THE NEW SYSTEM REPLACED MARBLE-BED TOWERS WITH SPKAY TOWERS.  THERE HAVE
                               BEEN NO FORCED SCRUBBER OUTAGES REPORTED SINCE START-UP. CONTINOOUS  S02
                               MONITORS HAVE RECORDED  S02 REMOVAL EFFICIANCItS OF BETTER THAN 
-------
                                                   tPA UTILITY FGO SURVEY: UClObEK 197B - UUVEN'-BER 1S7B
                                             SECTION ^
                                        STATUS UF  FGO SYSTEMS
 UNIT IDENTIFICATION
                                                                CURRENT SIATUb'
LOUISVILLE GAS & ELECTRIC
CANE RUN 4
  178  MW - RETROFIT
COAL? 3.75X SULFUR,  15.5X  ASH
AMERICAN AIR FILTER
LIME (CARBIDE)
STARTUP   8/7b
     REFER 10 SECTION 3 OF THIS REPOK1 FUK  ADDITIONAL  INKUKVAT1UN.
     THE FGO SYSTEM RETROFITTED ON  THIS BUILEK  AAS  DESIGNED  AND  SUPPLIED  HY
     AMERICAN AIR ULTEK ANO HAS FIRST PLACED  IN  THt &Ab  PATH  UN AUGUbT  /,
     1976. THE SYSTEM CONSISTS UF TWO PARALLEL  MODULES  rtnlLH  INCLUDE  MOBILE
     BEO CONTACTORS ANO OPERATE WITH A CAKH10E  Llr/t  ADUlllVt.  FOLLUMM.  A
     NUMBER OF MAJOR SYSTEM MODIFICATIONS  CCHEVKUN-TYPE MIST  ELIMINATOR,  U1L
     FIREO REHEAT, PLASI1E DUCT LINER, HIGHER  L/G) ,  1Ht SYSTEM SUCCESSFULLY
     PASSED COMPLIANCE TESTING (85X SU MM FOR OPERATION, RESEARCH AND  OEVELUPMENT,  AND KEPOK1  nkJTING  FUR
     A ONE-YEAR PERIOD FOLLOWING  THE FIRST  THREE  MUNIHS  UF  UPtKAlIUf,  IMHEMHIS
     SUBSIDY WILL NOT BE APPLIED  FUR ANY  CAPITAL  EXPENDITURES).  CUNS1RUCT10'J  AT
     THIS UNIT IS PRESENTLY 98Z  CUMPLETE. UNIT  STARTUP  IS tXPFCTED  Tu «E  IN
     LATE DECEMBER 1978 OR EARLY  JANUARY  1V79.
     A COMPLIANCE SCHEDULE WAS SUBMITTED  TO  THE  JEFFERSON  COUNTY  AIR  POL-
     LOTION CONTROL DISTRICT WITH  
-------
EPA UTILITY FGD  SURVEY:  OCTOBER  197B  -  NOVEMBER  197H

                                             SECTION i
                                        STATUS  OF  FGU SYSTEMS

 UNIT  IDENTIFICATION                                            CURRENT  STATUS

MINNESOTA POWER  » LIGHT        MINNESOTA  P  & L HAb  AnAROEO  A CuNlKACI  10 PEABUUY pKUthSS SYSTEMS F UK A
CLAY BOSWELL 4                 L IME/ALKAL 1 Nt FLYASH SCRUBBING SYSTEM.   THK  CUNf IMINA 1 ION MLL tth VFNIllKl
  500  MW - NEW                SCRUBBERS  FOLLOWED BY SHRAY  IUWERS.  HUT  S10E tSP'S rtlLL rtt UStl) F UK
COAL?  o.ax SULFUR. 9X  ASH      PAHTKULATE  CONIRUL. STACK  GAS REHEAT  WILL BE ACcuMruiSHtu BY HYpAssiNb
PEABODY PROCESS  SYSTEMS        5*  OF  FLUE GAS  AROUND THE  SCRUBBER.  THE  UNIl WILL FlKt  SUo-HlT UM I NUUS>
LIME/ALKALINE FLYASH           COLSTR1P COAL W11H A SULFUR  CUNTtNl  OF  U.tlX. AND  AN AS>H CUNU.Nl UF 9.Ui
STARTUP   5/80                 (HEATING VALUE  -  8300 BTU/LB). MAKt-UH  WATER SOURCE rtlLL rth lut Hlvt* AMI
                               THE CLAY-LINED  POND. CONSTRUCTION OF  THt  FGO SYSTEM IS  ABOUT dOl CUMHLMh.

MINNKOTA POWER COOPERATIVE     REFER  TO SECTION  3 OF THIS  REPORT FOR  ADDITIONAL  I(MF OKMAT IHN.
MILTON R. YOUNG  Z              THIS LI ME/ ALKAL INE FLYAbH  SCRUBBING  SYSTtM rtAS OtSlGNtD AIMU buHPLltl) UY
  450  MW - NEW                AUL/COMBUSTION  EQUIPMENT  ASSOClATtS.  IT  CONSISTS  OF A CULO-SlOt tSP
LIGNITE* 0.7X SULFUR,  8. OX  ASH FOLLOWED BY  TWO SPRAY TOWERS, THfc DESIGN  INCLUDES A WASH TKAY AIMI) A
AOL/COMBUST ION EQUIP ASSOCIATE CHEVRON  MIST  ELIMINATOR.  JbX FLUE GAS  BYPASS PHUVlDES STACK GAS rfEHhAI.
LIME/ALKALINE FLYASH           THE UNJT FIRES  A  LOK-SULFUR  NORTH DAKOTA  LIGNITE  WITH AN AVEKAGt A.Sn
STARTUP   9/77                 CONTENT  OF fl  PERCENT, SULFUH CONTENT OF  0.7  PERCENT,  AMU HKAT CUNltuI
                               OF  6bOO  BTU/LB. THE  FLY  ASH  ALKALINITY  JS USED AS THE PRIMARY SU«J REAbKul.

MONTANA POWER                  REFER  TO SECTION  3 OF THIS  REPORT FOR  ADDITIONAL  IiMFUKMA T 1UN .
COLSTRIP 1                     THIS FGD EQUIPPED  UNIT WAS  DECLARED  COMMERCIAL IN NOVEMBER 197b. I Hh
  360  MW - NEW                SCRUBBING  SYSTEM  PROVIDES  PAKTICULA1E  AND 30e! CONTKUL wllh THRtL SCKUrt-
COALJ 0.6X SULFUR, 12X ASH     BER MODULES.  EACH  MODULE  CONSISTS OF A  DUwNFLUw VENlURl SCKUrtHLK CtultK-
ADL/COMBUSTION EQUIP ASSOCIATE EU  WITHIN  AN  UPFLOw  SPRAY  TOwER ABSORBER. EACH KODULt CAM ThtAT 4>J* OF
LIME/ALKALINE FLYASH           THE TOTAL  BOILER  FLUE GAS  AND THE MODULES CAM01  BE UYPASSF.O. THt UN-
STARTUP  11/75                 STABILIZED SLUDGE  IS DISPOSED IN AN  UN-SITE  LINED 01SPUSAL POND. iN-LliMh
                               STEAM  REHEAT  AND  CLOSED  WATEK LOOP CAPABILITY ARE INCLUDED IN 1 Hh SYSItH.

MONTANA POWER                  REFER  TO SECTION  3 OF THIS  REPORT FUR  ADDITIONAL  INFUK^AT Inm.
COLSTRIP Z                     THIS FGD EUUIPPED  UNIT WAS  DECLARED  CUMMERClAL IN AUGUST 197b. THE
  360  MW - NEW                SCRUBBING  SYSTEM  PRuVIDES  PARUCULATE  AND SOd CUNTRUL WITH THRtb SCRUh-
COAL?  o.ax SULFUR* 12X ASH     BER MODULES.  EACH  MODULE  CONSISTS OF A  DOWNFLUW VENTURI SCRUHBER C(NTER-
ADL/COMBUSTION EQUIP ASSOCIATE ED  WITHIN  AN  UHFLUW  SPRAY  TOMER ABSORBER. EACH MODULE CAN TRbAT <4Ui Ut-
LIME/ALKALINE FLYASH           THE TOTAL  BOILER  FLUE GAS  AND THE MODULES CANNOT  BE BYPASStU. THt UN-
STARTUP   B/76                 STABILIZED SLUDGE  IS DISPOSED IN AN  ON-SITE  LINED lUSt-USAL HUNI). [u-LIi-iK
                               STEAM  REHEAT  AND  CLOSED  WATER LOOP CAPABILITY ARE INCLUDED IN iHt
MONTANA POWER                  A CONTRACT  FOR  THE  INSTALLATION  OF  TWO  ADDITIONAL Llwt / ALiv AL I NE FLYASH
COLSTRIP 3                     SCRUBBING  SYSTEMS HAS  BEEN  AWARDED  TU  A.U.  LIT T LE/CUMeUST 1UN EUUlPMhNT
  700  MM - NEW                ASSOCIATES.  THESE SYSTEMS WILL BE  INSTALLED UN  UNITS * ANU n UF THt
COALI o.7x SULFUR              COLSIRIP POWER  STATION.  COLSTRIP ONUS  i  AND ^  ARE BOTH tuuipHtu WITH
ADL/COMBUSTION EQUIP ASSOCIATE OPERATIONAL  LIME/ALKALINE FLYASH SCRUBBING  SYSTEMS FOR THE REMOVAL OF
LIME/ALKALINE FLYASH           PARTICULATES AND SULFUR  DIOXIDE.
STARTUP   7/80


MONTANA POWER                  A CONTRACT  FOR  I HE  1NSJ I ALLA I IUN  OF  I WU  ADDI I IUNAL LIME / ALiv ALlNt FLYASH
COLSTRIP 4                     SCRUBBING  SYSTEMS HAS  BEEN  AWARDED  TO  A.O.  LITTLE/COMBUSTION EUU1PMEM
  700  MW - NEW                ASSOCIATES.  THESE SYSTEMS WILL BE  INSTALLED ON  UNITS 3 AND 1 OF THE
CO*L> 0.7X SULFUR              CULSTR1P POWER  STATION.  COLSTRIP ON1TS  1  AND i  ARE B01H EUUJHPtO MTH
AOL/COMBUSTION EQUIP ASSOCIATE OPERATIONAL  LIME/ALKALINE FLYASH SCRUBBING  SYSTEMS FUR THE KhMUVAL UF
LIME/ALKALINE FLYASH           PARTICULATES AND SULFUR  DIOXIDE.
STARTUP   7/81


NEVADA POWER                   CONSIDERING  HOT SIDE ESP IN CONJUNCTION WITH AM FGD SYSTtM. SPtClFICA-
MARRY ALLEN i                  T10NS  HAVE  NOT  YET  BEEN  PREPARED.
  SOO  MW - NEW
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   6/85


NEVADA POWER                   CONSIDERING  HOT SIDE ESP IN CONJUNCTION WITH AN FGO SYSTEM"~SPEC If ICA-
HARRY ALLEN Z                  TION8  HAVE  NOT  YET  BEEN  PREPARED.
  500  MM - NEW
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   6/86

-------
                                                  EPA UTILITY FGD SUKVEY: OCTOBER 1<»78 - NOVEMBER
 UNIT IDENTIFICATION
                                            SECTION a
                                       STATUS OF FGD SYSTEMS
                                                               CORRENT STATUS
NEVADA POWER
HARRY ALLEN 3
  500  MW - NEW
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   6/87
CONSIDERING HOT SIDE ESP IN CONJUNCTION WITH AM FGO SYSTEM. SPECIFICA
TIONS HAVE NOT YET BEEN PHEPAKED.
NEVADA POKER
HARRY ALLEN 4
  SOO  MM - NEW
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   6/88
CONSIDERING HOT SIDE ESP IN CONJUNCTION WITH AN FGO SYSTEM. SPECIFICA-
TIONS HAVE NOT YET BEEN PREPARED.
NEVADA POWER
REIO GARDNER 1
  125  MW - RETROFIT
COALf 0.5X SULFUR, 8X ASH
AOL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
STARTUP   4/74
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS SODIUM CARBONATE-BASED  CTRONA) SCRUBBING SYSTEM CONSISTS OF ONE
MODULE CONTAINING A THIN VARIABLE-THROAT VENTURI SCKUBbtR FOLLOWED BY A
SEPARATOR IN SERIES WITH A SINGLE-STAGE PERFOKATED-PLATE HASH TOrtEH.
PRIMARY PARTICULATE CONTROL  IS PROVIDED BY UPSIKEAM MECHANICAL COLLtCTUKS.
AN INDIRECT STEAM HOT AIR REHEAT SYSTEM HAlStS THE GAS FEMPERATORE iU F
PRIOR TO DISCHARGE TO THE MAIN STACK. THE FLUE GAS CLEANING WASTES ARE
ULTIMATELY DISPOSED IN AN ON-SITE CLAY-LINtO SOLAK EVAPORATION PUNU.
NEVADA POWER
REID GARDNER 2
  125  MW - RETROFIT
COAL; o.sx SULFUR, ax ASH
ADL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
STARTUP   4/74
REFER 10 SECTION 3 OF THIS REPORT FOH AODIIIONAL INFORMAIION.
THIS SODIUM CARBONATE-BASED  (TRONA) SCRUBBING SYSTEM CONSISTS OF ONE
MODULE CONTAINING A THIN VARIABLE-THKOAT VENTUHI SCKUbBEK FULLOwED bY A
SEPARATOR IN SERIES WITH A SINGLE-STAGE PERFOHATED-PLATE HASH TOrtEK.
PRIMARY PARTICULATE CONTROL  IS PROVIDED BY UPSTKEAM MECHANICAL COLLtCTUKS.
AN INDIRECT STEAM HOT AIR REHEAT SYSTEM RAISES THE GAS TEMPERATURE 30 F
PRIOR TO DISCHARGE TO THE MAIN STACK. THE FLUE GAS CLEANING WASTES ARE
ULTIMATELY DISPOSED IN AN ON-SITE CLAY-LINED SOLAK EVAPORATION POND.
NEVADA POWER
REID GARDNER 3
  125  MW - NEW
COAL> O.SX SULFUR, 8X ASH
AOL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
STARTUP   7/76
REFER TO SECTION 3 OF THIS REPOKI FUR ADDITIONAL INFOKMAIION.
THIS UNIT IS A NEW COAL-FIRED BOILtR THAT IS EQUIPPED WITH SOOIUM
CARBONATE-BASEO(TRONA)SCRUBBING  SYSTEM WHICH INCORPORATES A TnIN
VARIABLE-THROAT VENTURI SCRUBBER FOLLOWED BY A SEPAKAIOK IN SERIES «IlH
A SINGLE-STAGE PERFORATED-PLATE  NASH TObEK. MECHANICAL COLLEC10KS PROVIDE
PRIMARY PARTICULATE CONTROL. REHEAT IS PROVIDED BY AN INDIRECT STEAM HUT
AIR REHEAT SYSTEM. WASTE IS DISPOSED IN AN ON-SITE CLAY-LINED FOND.
NEVADA POWER
REID GARDNER 4
  250  HW - NEW
COAL? 0.75X SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   0/83
NEVADA POWER COMPANY HAS SCRAPPED THIER ORIGINAL PLANS TO MAKE UNIT 4 A
COPY OF UNIT 3. THE NEW PLANS CALL FOH A 250-Mfc UNIt TO bt IN OPERATION
BY 1983. THE UTILITY IS PREPARING SPECIFICATIONS AT THIS TIME. CONSTRUC-
TION IS SCHEDULED TO START IN 1980.
NEVADA POWER
WARNER VALLEY 1
  250  MW - NEW
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   6/84
SPECIFICATIONS ARE BEING PREPARED FOR A SCRUBBING SYSTEM. NEVADA POwER
HAS NOT YET ANNOUNCED PLANS FOR THIS UNIT'S EMISSION CONTROL STRATEGY.
NEVADA POWER
WARNER VALLEY 2
  250  MW - NEW
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   6/85
SPECIFICATIONS ARE BEING PREPARED FOH A SCRUBBING SYSTEM. NEVADA POwER
HAS NOT YET ANNOUNCED PLANS FOR THIS UNIT'S EMISSION CONTROL STRATEGY.
                                                  13

-------
EPA UTILITY FGO SURVEY: OCTOBER  1978 - NOVEMBER  1978
                                            SECTION 2
                                       STATUS OF FGD SYSTEMS
 UNIT IDENTIFICATION
                                    CURRENT STAIUS
NEN ENGLAND ELEC SYSTEM
BRAYTON POINT 3
  650  MW - RETROFIT
FUEL OIL; l.OX SULFUR, .11
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   OX 0
        ENGLAND ELECTRIC SYSTEM HAS REQUESTED PERMISSION TO BURN 1.5X SULFUR
    COAL AT THIS UNIT. THIS IS ALLOWABLE UNDER STATE STANDARDS BUT SOS EMIS-
    SIONS MOULD 8fc ABUVE ALLOWABLE FEDERAL LEVELS. A DECISION BY THE EPA IS
ASH STILL PENDING. MEANWHILE,  THE UTILITY IS INVESTIGATING VARIOUS ADVANCED
    REGENERABLE FGO SYSTEMS WHICH OFFER A BREAKTHROUGH IN OPERATING COSTS AND
    PRODUCE ELEMENTAL SULFUR AS AN END PRUOUCT. THE UTILITY IS CURRENTLY IN-
    VOLVED IN BENCH AND LABORATORY SCALE INVESTIGATIONS OF SULFUR KECUVERY.
    THIS UNIT IS CURRENTLY OPERATIONAL FIRING LOW SULFUR FUEL OIL.
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
  100  MW - RETROFIT
COAL; 3.sx SULFUR
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE
STARTUP   0/80
    A CONTRACT HAS AWARDED TO ATOMICS INTERNATIONAL FOR THE DESIGN AND IN-
    STALLATION OF AN AQUEOUS CARBONATE FGO SYSTEM. THIS DEMONSTRATION SYSIEM
    WILL PRODUCE END-PRODUCT SULFUR. FUNDS ARE dEING PROVIDED BY THE USEPA
    AND THE EMPIRE STATE ELECTRIC ENERGY RESEARCH CORP. THE DESIGN SU2 RE-
    MOVAL EFFICIENCY WILL BE 90 PERCENT. GROUND BREAKING FOR CONSTRUCIION WILL
    BE IN LATE FALL 1978.
NORTHERN INDIANA PUB SERVICE
BAILLY 7
  190  MW - RETROFIT
COAL; 3x SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   OX 0
    NORTHERN INDIANA PUBLIC SERVICE IS CURRENTLY CONSIDERING A LIME OR LIME-
    STONE SCRUBBING UNIT FUR BAILLY 7 AND 8. THEY AKE ALSU WAITING FUR
    PERFORMANCE RESULTS OF THE wELLMAN LORDXALLIED CHEMICAL UNIT IN SERVICE
    AT DEAN H. MITCHELL 11. LOW SULFUR COAL MAY BE EMPLOYED TO COMPLY WITH
    S02 EMISSION REGULATIONS. APPLICABLE INDIANA S02 REGULATIONS ARE STILL NOT
    FIRMLY ESTABLISHED.
NORTHERN INDIANA PUB SERVICE
BAILLY 8
  400  MW - RETROFIT
COAL; 31 SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   OX 0
    NORTHERN INDIANA PUBLIC SIRVICE IS CURRENTLY CONSIDERING A LIME UK LIME-
    STONE SCRUBBING UNIT FOR BAILLY 7 AND 8. THEY AKE ALSO WAITING FOR
    PERFORMANCE RESULTS OF THE WELLMAN LORDXALLIED CHEMICAL UNIT IN SERVICE
    AT DEAN H. MITCHELL 11. LOW SULFUR COAL MAY BE EMPLOYED Tu COMPLY WITH
    S02 EMISSION REGULATIONS. APPLICABLE INDIANA S02 REGULATIONS ARE STILL NUT
    FIRMLY ESTABLISHED.
NORTHERN INDIANA PUB SERVICE   REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL  INFORMATION.
DEAN H. MITCHELL 11
  115  MW - RETROFIT
COAL; 3.sx SULFUR, IDS ASH
DAVY POWERGAS
WELLMAN LORD
STARTUP  11X76
    THIS FGD SYSTEM IS AN INTEGRATION OF THE wELLMAN-LORD 802 RECOVERY PROCESS
    OFFERED BY DAVY POWERGAS AND THE S02 TO SULFUR REDUCTION PROCESS DE-
    VELOPED BY ALLIED CHEMICAL. DAVY POWERGAS IS THE DESIGN AND CONSTRUCTION
    FIRM AND ALLIED CHEMICAL IS SYSTEM OPERATOR AND PRODUCT MARKETER.
    PERFORMANCE TESTS WERE SUCCESSFULLY COMPLETED ON SEPTEMBER 14, 1977. A
    DEMONSTRATION YEAR COMMENCED ON SEPTEMBER 16, 1977.
NORTHERN STATES POWER
SHERBURNE 1
  710  MW - NEW
COAL; o.ex SULFUR, 9.sx SULFUR
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
STARTUP   3/76
    REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
    FULL COMMERCIAL OPERATION OF THE SYSTEM BEGAN ON MAY 1, 197b. THE SCRUB-
    BING SYSTEM FOR THIS UNIT CONSISTS OF 12 MODULES. EACH SCRUBBING MODULE
    INCORPORATES A VENTUHI-ROD SECTION AND A MARBLE BED ABSORBER FOR PAR-
    TICULATE AND SULFUR DIOXIDE REMOVAL. A FORCED OXIDATION SYSTEM CONVERTS
    ALL THE CALCIUM SULFITE TO SULFATE PRIOR TO DISCHARGE TO A CLAY-LINED
    SETTLING POND. STACK GAS REHEAT IS PROVIDED BY IN-LINE HOT WATER TUBES.
    THE COAL BURNED AT THIS UNIT CONTAINS ,6X SULFUR AND 9-1UX ASH.
NORTHERN STATES POWER
SHERBURNE 2
  710  MW - NEW
COAL; o.ex SULFUR, 9.sx ASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
STARTUP   4/77
    REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
    THE SHERBURNE NO. 2 AIR QUALITY CONTROL SYSTEM IS IDENTICAL IN DESIGN TO
    THE SYSTEM IN OPERATION ON THE NO. 1 UNIT AT THIS STATION. TWELVE 2-STAGE
    PARTICULATE SCRUBBER (VENTURI-ROD SCRUBBER) AND SULFUR DIOXIDE A8SURBER
    (MARBLE-BED ABSORBER) MODULES ARE PROVIDED FOR FLY ASH AND 302 CONTROL.
    ELEVEN MODULES ARE REQUIRED FOR FULL GENERATING CAPACITY OPERATIONS.
    THE CALCIUM SULFITE IS FORCIBLY OXIDIZED TO SULFATE PRIOR TO DISCHARGE TO
    THE DISPOSAL POND. IN-LINE HOT WATER TUBES PROVIDE STACK GAS REHEAT.
NORTHERN STATES POWER
SHERBURNE 3
  660  MW - NEW
COAL; o.ax SULFUR, 9.sx ASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
STARTUP   5/60
    TWO ADDITIONAL COAL-FIRED POWER-GENERATING UNITS ARE SCHEDULED TU BE IN-
    STALLED AT NSP'S SHERBURNE COUNTY GENERATING STATION IN BECKER MINNESOTA.
    A LETTER OF INTENT HAS BEEN SIGNED WITH C-E FOR A LIMESTONE SLURRY SPRAY
    TOWER FGO SYSTEM FOR THIS NEW 860 MW UNIT. THE 2-STAGE SCRUBBING SYSTEM
    WILL REMOVE PARTICULATE (99.5X) & S02 (BOX). THE BOILER CONTRACT HAS BEEN
    AWARDED TO BABCOCK AND WILCOX AND THE TURBINE WILL BE SUPPLIED BY GENERAL
    ELECTRIC. START-UP HAS BEEN DELAYED TO MAY 1984 AND CONSTRUCTION START-
    UP HAS BEEN SUSPENDED UNTIL APRIL 1980 DUE TO ENVIRONMENTAL PROBLEMS.
                                                   14

-------
                                                   tPA  UTILITY  FGD  SURVEY:  UCTOBEk  197a  -  NUVtl"bEk  1978
                                             SECTION  2
                                        STATUS  OF  FGD SYSTEMS
 UNIT IDENTIFICATION
                                                                CURRENT  STATUS
NOKTHEKN STATES PUNEK
SHERBURNE 4
  660  MM - NEW
COAL; o.ex SULFUR, 9.sx ASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
STARTUP   0/87
TWO AUDIUUNAL COAL-FlKEl) POWER-GENERATING UNIIS ARE SCHEDULED fu BE IN-
STALLED AT NSP'S SHERBURNE CUUNTY GENERATING STATION IN BECKER MINNESOTA.
A LETTER OF INTENT HAS BEEN SIGNED WITH C-E FUR A LIMESTONE SLURRY SPKAY
TOWER FGO SYSTEM FOR THIS NEW 66U MW UNIT. THE d-STAGE SCRUBBING SYSTEM
WILL REMOVE PARTICULATE (99.5X) & S02 (SOX). THE BOILER CONTRACT HAS cJEEN
AWARDED TO BABCOCK AND WILCUX AND THE TURBINE KILL BE SUPPLIED BY GENERAL
ELECTRIC. UNIT START-UP IS NOW TENTATIVELY SCHEDULED FOR 19»7 ALTHOUGH
ALTHOUGH CONSTRUCTION HAS BEEN SUSPENDED FnK T*0 YEARS.
OTTER TAIL POWER
COYOTE 1
  400  MM • NEW
LIGNITE; 0.9X SULFUR, 6.5X  ASH
WHEELABRATOR-FRYE/R.I.
NA-CO, SPRAY DRYING
STARTUP    5/81
THIS f>.tw COAL-FIRED STATION IS JOINTLY UWHLI) n 1 FIVE UTILITIES. OTTER
TAIL POWER IS THE MAJOR OWNER AND CONSTRUCTOR. MONTANA-DAKOTA UTILITIES
IS THE FACILITY OPERATOR. THIS PLANNED ONIT WILL F1KE LOW SOLFUR LIGNITE
FROM THE MERCER COUNTY AREA IN A B&w CYCLONE buILEH. THE CONTRACT FUR THIS
AQUEOUS CARBONATE/FABRIC FILTER S02 SCRUBbER-ABSORBER MAS AWARDED TO
WHEELABRATOR-FRYE AND ATOMICS INTERNATIONAL. THE DRY REMOVAL SYSTEM COM-
BINES AI'S AQUEOUS CARBONATE PROCESS IN A W-F FABRIC FILTER. UNIT CON-
STRUCTION IS NOW 20X COMPLETE AND FGO SYSTEM CONSTRUCTION HAS JUST BEGUN.
PACIFIC GAS AND ELECTRIC
FOSSIL 1
  BOO  HW - NEW
COAL} 0.6X SULFUR*  10X  ASH
VENDOR NOT SELECTED
LIMESTONE
STARTUP   0/85
PACIFIC GAS AND ELECTRIC
FOSSIL a
  600  MW - NEW
COAL} O.BX SULFUR,  10X  ASH
VENDOR NOT SELECTED
LIMESTONE
STARTUP   0/86
PACIFIC POWER ft LIGHT
JIM BRIDGER 4
  509  MW - NEW
COAL} 0.56X SULFUR, 9X  ASH
AIR CORRECTION DIVISION,  UOP
SODIUM CARBONATE
STARTUP   9/79
PENNSYLVANIA POWER
BRUCE MANSFIELD t
  825  MM - NEW
COAL} 4.7X SULFUR, 12r5X ASH
CHEMICO
LIME
STARTUP   4/76
PGSE ANNOUNCED PLANS TO BUILD TWO 800-MW COAL-FIRED POWER GENERATING
UNITS IN NORTHERN CALIFORNIA. THE FIRST UNIT WILL BURN COAL WITH A HEAT-
ING VALUE OF 12000 BTU/LB, 0.8X SULFUR AND  1UX ASH CONTENTS. THE SECOND
UNIT WILL BURN COAL OF EQUAL OR BETTER UUALITY. THE EMISSION CONTROL
SYSTEM WILL CONSIST OF AN ESP OR BAGHOUSE AND A LIMESTONE FGD SYSTEM.
SLUDGE WILL BE DISPOSED OF IN A LANDFILL. START-UP DATES ARE 1985 AND 198b
FOR NOS. 1 AND 2 RESPECTIVELY. CONSTRUCTION  IS NOT ENVISIONED TO BEGIN
BEFORE TWO TO THREE YEARS.

PGftE ANNOUNCED PLANS TO BUILD TWO 800-MW COAL-FIRED POWER GENERATING
UNITS IN NORTHERN CALIFORNIA. THE FIRST UNIT WILL BURN COAL WITH A HEAT-
ING VALUE OF 12000 BTU/LB, 0.8X SULFUR AND  10X ASH CONTENTS. THE SECOND
UNIT WILL BURN COAL OF EQUAL OR BETTER QUALITY. THE EMISSION CONTROL
SYSTEM WILL CONSIST OF AN ESP OR BAGHOUSE AND A LIMESTONE FGD SYSTEM.
SLUDGE WILL BE DISPOSED OF IN A LANDFILL. START-UP DATES ARE 1905 AND 1986
FOR NOS. 1 AND 2 RESPECTIVELY. CONSTRUCTION  IS NOT ENVISIONED TO BEGIN
BEFORE TWO TO THREE YEARS.

THE AIR CORRECTION DIVISION OF UOP WAS AWARDED A CONTRACT FOR AN FGD
SYSTEM AT THIS NEW-509 MW COAL-FIRED UNIT.  THE FGO SYSTEM WILL CONSIST OF
PARALLEL TRAY TOWER ABSORBER MODULES, EACH  TREATING ONE-THIHD OF THE
BOILER FLUE GAS AT FULL LOAD. AN ESP WILL PROVIDE PRIMARY PARTICULATE
CONTROL. AN ACID BRICK LINED WET STACK IS INCLUDED IN THE SYSTEM.  PPL'S
PILOT STUDY INSPECTION REVEALED SCALE FORMATION PROBLEMS. TESTS ARE BEING
CONDUCTED TO RESOLVE THIS PROBLEM. THE UTILITY EXPECTS TO CONDUCT A
SYSTEM CHECKOUT IN 7/79 WITH COMMERCIAL STARTUP AT THE END OF 1979.

REFER TO SECTION 3 OF THIS REPORT FOR ADDITONAL INFORMATION.
THIS EMISSION CONTROL SYSTEM WAS DESIGNED TO REMOVE FLYASH AND S02 FROM
3.35 MM ACFM OF FLUE GAS USING THIOSORBIC LIME AS A SCRUBBING ABSORBENT.
THE INITIAL SHAKEDOWN AND DEBUGGING PHASE OF OPERATION BEGAN FOR PART OF
THE SYSTEM IN DECEMBER 1975. PARTIAL COMMERCIAL OPERATION COMMENCED IN
APRIL 1976. THE UNIT WAS CERTIFIED FULL-LOAD COMMERCIAL IN JUNE 1976.
THE FGD SYSTEM HAS EXPERIENCED OPERATIONAL PROBLEMS SINCE IT HAS BEEN IN
SERVICE REQUIRING A NUMBER OF SYSTEM REPAIRS AND DESIGN MOD IF ICATINS.
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
  825  MW - NEW
COAL) 4.7X SULFUR, 12.SX ASH
CHEMICO
LIME
STARTUP   7/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS EMISSION CONTROL SYSTEM WAS DESIGNED TO REMOVE FLYASH AND 302 FROM
3.35 MM ACFM OF FLUE GAS USING THIOSORBIC LIME AS A SCRUBBING ABSORBENT.
SIX SCRUBBING TRAINS, EACH INCLUDING TWO VENTURI SCRUBBERS IN SERIES
ARRANGEMENT, ARE PROVIDED FOR FULL-LOAD OPERATION. THE INITIAL SHAKEDOWN
AND DEBUGGING PHASE OF OPERATION BEGAN FOR THREE TRAINS IN JULY, 1977.
FULL COMMERCIAL OPERATION FOR THE ENTIRE SYSTEM COMMENCED ON OCTOBER 1,
1977.
PENNSYLVANIA POWER
BRUCE MANSFIELD 3
  625  MW » NEW
COAL} 4.7X SULFUR
PULLMAN KELLOGG
LIME
STARTUP   4/80
A CONTRACT WAS AWARDED TO PULLMAN KELLOGG FUR THE FGD SYSTEM AT THIS UNIT.
THE EMISSION CONTROL SYSTEM FOR THIS UNIT WILL CONSIST OF ESP'S UP-STREAM
OF FIVE WEIR HORIZONTAL CROSSFLOW WET SCRUBBING MODULES. SLUDGE WILL BE
DISPOSED OF BY THE EXISTING SYSTEM AT THE BRUCE MANSFIELD PLANT. LINER IN
THE CHIMNEY WILL BE AN INCUNEL 625 MATERIAL. THE UNIT IS CURRENTLY UNDER
CONSTRUCTION WITH ESP'S 70-80 PERCENT CU-^LEIt AND THE FGO SYSTEM 30
PERCENT COMPLETE. UNIT START-UP WILL BE IN APRIL 1980.
                                                   15

-------
EPA UTILITY FGD SURVEY! OCTOBER  1976  -  NOVEMBER  1978
 UNIT  IDENTIFICATION
                                             SECTION  i
                                        STATUS OF FGD SYSTEMS
                                                               CURRENT STATUS
PHILADELPHIA ELECTRIC
CROMBY
   150  MW • RETROFIT
COAL; 2-4Z SULFUR
UNITED ENGINEERS
MAGNESIUM OXIDE
STARTUP   b/80
THE UTILITY PLANS TO RETROFIT ONE OF THE TWU BOILERS AT CROMUY WITH AN
FGO SYSTEM. HOWEVER* A FINAL DECISION HAS NUT BEEN MAUE. THE SYSTEM
BEING GIVEN PRIMARY CONSIDERATION IS MAGNESIUM OXIOE. CURRf-NTLY, THE
UTILITY IS RE-NEGOTIATING CONSENT ORDERS AND THE STAHT-UP DATE OF JUNE
I960 IS TENTATIVE.
PHILADELPHIA ELECTRIC
EOOYSTONE  1A
  120  MW  - RETROFIT
COAL; 2.5Z SULFUR, 101 ASH
UNITED ENGINEERS
MAGNESIUM  OXIDE
STARTUP    9/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFOKMATION.
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF THRtE PARALLEL
SCRUBBING TRAINS FOR THE CONTROL OF PARTICULATt AND SULFUR DIOXIDE.
THE C-SIDE SCRUBBING TRAIN INCLUDES AN Su2 ABSUKBER MUDULt IN SERIES
WITH A PARTICULATE SCRUBBER. APPROXIMATELY UNE-THIRO OF THE BUILEK FLUE
GAS IS SCRUBBED WITH MAGNESIUM OXIDE SLURKY FOR S02 REMOVAL. THE SPKNT
SLURRY IS REGENERATED AT THE ESSEX SULFURIC ACID PLANT IN NEWARK, N.J.
THE REGENERATED MAGOX IS RETURNED TO THE PLANT FOR 302 SCRUBBING SERVICE.
PHILADELPHIA ELECTRIC
EDOYSTONE IB
  240  MW - RETROFIT
COAL; 2.5X SULFUR, 101 ASH
UNITED ENGINEERS
MAGNESIUM OXIDE
STARTUP   6/80
THE INSTALLATION OF AN FGD SYSTEM ON THE BALANCE OF THE FLIlt GAS FKUM
THIS UNIT WILL FOLLOW PENDING THE OUTCOME OF THE PERFORMANCE OF THE EXPER-
IMENTAL SCRUBBING UNIT WHICH HAS BEEN INSTALLED AND CURRENTLY OPERATIONAL
ON THIS UNIT. CURRENTLY, 3 PARTICULATE SCRUBBERS ARE TREATING THE FULL
GAS LOAD FROM THIS UNIT. CONSENT ORDEKS ARE PRESENTLY BEING KE-NEGUTI AT ED
AND THE START-UP DATE OF JUNE 1980 IS TENTATIVE.
PHILADELPHIA ELECTRIC
EDDYSTONE 2
  336  MW - RETROFIT
COAL; 2.5Z SULFUR, 10Z ASH
UNITED ENGINEERS
MAGNESIUM OXIDE
STARTUP   b/80
THE UTILITY IS AWAITING PERFORMANCE RESULTS FROM THE EXPERIMENTAL FGO
SYSTEM INSTALLED ON UNIT 1 AT THIS STATION BEFORE PROCEEDING WITH THE
DESIGN OF AN FGD SYSTEM FOR THIS COAL-FIRED BOILER. THE SYSTEM BEING
GIVEN PRIMARY CONSIDERATION IS MAGNESIUM UXIDE, DESIGNED JOINTLY BY
UNITED ENGINEERS AND PHILADELPHIA ELECTRIC. CURRENTLY, THE UTILITY IS
RE-NEGOTIATING CONSENT ORDEKS AND THE START UP DATE OF JUNE 1980 IS
TENTATIVE.
POTOMAC ELECTRIC POWER
DICKERSON 4
  800  MW - NEW
COAL; 2X SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   5/85
THERE ARE NO FIRM PLANS FOR INSTALLATION OF AN FGD SYSTEM.  STARTUP DATE
OF THE BOILER IS PLANNED FOR 1985. THIS UNIT HILL BURN 2 PERCENT SULFUR
COAL WITH A HEATING VALUE OF 11,000 BTU/L8.
POWER AUTHORITY OF NEW YORK
ARTHUR KILL PLANT
  700  MW - NEW
COAL; 3z SULFUR - REFUSE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP  11/84
THE UTILITY IS CONSIDERING BOTH REGENERABLE AND LIMESTONE FGD PROCESSES.
FGD TECHNOLOGY IS. BEING CONSIDERED FOR A FOSSIL FUEL BURNING UNIT WHICH
WILL EMPLOY COAL AS THE PRIMARY FUEL AND OIL AS BACKUP. REFUSE WILL BE
PROVIDED AS A SUPPLEMENTAL FUEL SUPPLY. THE PREFERRED PLANT SITE IS THE
ARTHUR KILL FACILITY LOCATED ON STATEN ISLAND. THE PROJECT DESIGN ENGI-
NEERING FIRM IS SARGENT AND LUNDY. PUBLIC SERVICE COMMISSION HEARINGS
ARE IN PROGRESS.
PUBLIC SERVICE OF INDIANA
6IBSON 5
  650  MW • NEW
COAL; 3.3Z SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   0/62
PUBLIC SERVICE CO OF INDIANA ANNOUNCED PLANS FOR THE CONSTRUCTION OF THIS
NEW 6SO-MW COAL FIRED POWER GENERATIONG UNIT AT GIBSON STATION. BIDS
HAVE BEEN RECEIVED AND ARE BEING EVALUATED.  INITIAL STARTUP IS SCHEDULED
FOR 1982.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
  314  MM - NEW
COAL; 0.6X SULFUR* 20Z ASH
DAVY POWERGAS
MELLMAN LORD
STARTUP   4/78
REFER 10 SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS FGD
SYSTEM IS AN INTEGRATION OF THE WELLMAN LORD 802 RECOVERY PROCESS OF DAVY
POWERGAS AND ALLIED CHEMICAL'S S02 REDUCTION TO SULFUR PROCESS. A HOT
SIDE ELECTROSTATIC PRECIPITATOR PRECEEDS THE FGD SYSTEM. OF THE FOUR
ABSORBER TOWERS INSTALLED, THREE ARE NEEDED TO CARRY THE FULL LOAD. THE
COAL BURNED AT THIS UNIT HAS SULFUR AND ASH CONTENTS OF .8Z AND 20X RE-
SPECTIVELY. THE SYSTEM OPERATES ON A CLOSED WATER LOOP WITH RIVER WATER
BEING USED AS MAKE-UP FOR LOSSES DUE TO EVAPORATION.
                                                   16

-------
                                                   EPA  UTILITY  FGO  SURVEY:  UCTUdER  197H  -  NUVtl»dKH
                                             SECTION  2
                                        STATUS  OF  FGD SYSTEMS
 UNIT IDENTIFICATION
                                                                CURRENT  STATUS
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 2
  306  MW • RETROFIT
COAL) O.BX SULFUR, 20X ASH
DAVY POWERGAS
WELLMAN LORD
STARTUP   8/78
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
  468  MM - NEW
COAL; o.ax SULFUR, 2ox ASH
DAVY POWERGAS
WELLMAN LORD
STARTUP   6/79
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 4
  473  MW - NEW
COAL; o.ax SULFUR, aox  ASH
DAVY POWERGAS
NELLMAN LORD
STARTUP   1/82
REFER TO SECTION 3 (if THIS REPOHT FOR ADDITIONAL INFORMATION.  THIS FGI)
SYSTEM is AN INTEGRATION OF THE WELLMAN LORD so<2 RECOVERY PKDCESS OF DAVY
POWERGAS ANU ALLIED CHEMICAL'S S02 REDUCTION TO SULFUrf PROCESS. A HUT Slot
ELECTROSTATIC PRECIPITATOR PRECEEDS THE FliD SYSTEM. THE SYSTEM INCLUDES
FOU« ABSORBER TOWERS, THREE OF WHICH ARE NECESSARY TO CARRY THE HULL LDAU.
THE WATER LOOP IS CLOSED WITH RIVER WATER HEING USED TO MAKE UP F0« LUSStb
DUE TO EVAPORATION. THE COAL BURNED AT THIS UNIT HAS SULFUR AND ASH
CONTENTS OF .8X AND aOX RESPECTIVELY.

A CONTRACT HAS BEEN AWARDED TO DAVY POWERGAS TO SUPPLY FOUR AHSURBER
TOWERS FOR REMOVAL OF S02 AT THIS NEW UNIT. ONE MODULE IS EXPECTED TO HE
OPERATIONAL BY JUNE 1979 WHICH rtILL BRING THE UNIT INTO COMPLIANCE rtllH
FEDERAL NSPS. THE REMAINING THREE MODULES SHUULD BE OPERATIONAL BY JANUARY
1982 AT WHICH TIME THE UNIT WILL BE IN COMPLIANCE OF STATE STANDARDS.
POWER PLANT CONSTRUCTION IS BEHIND SCHEDULE BUT A8SURBER CONSTRUCTION IS
PROCEEDING AS PLANNED. IT IS POSSIBLE THAT  THE FINAL THREE ABSORBERS MAY
BE IN AS EARLY AS JANUARY 1961.

DAVY POWERGAS HAS BEEN AWARDED A CONTRACT TO SUPPLY THE S02 REMOVAL SYSTEM
FOR THIS UNIT. THE PLANS INCLUDE A rtELLMAN  LORD SO
-------
EPA UTILITY FGD SURVEY: OCTOBER  1976 - NOVEMBER
                                            SECTION i
                                       STATUS OF FGD SYSTEMS
 UNIT IDENTIFICATION
                                                               CURRENT STATUS
SIKESTON BOARD OF MUNIC. DTK.
SIKESTON POWER STATION
  235  MW - NEw
COAL; 2.ex SULFUR, ii.ai ASH
BABCOCK & WILCOX
LIMESTONE
STARTUP   6/81
B&W WAS AWARDED A CONTRACT FOR THE BOILER AND AIR QUALITY CONTROL SYSTEM.
THE AOCS MLL CONSIST OF 2 ESP'S FOLLOWED BY 3 FGD MODULES, EACH CAPAtiLE
OF HANDLING bOX OF THE BOILER LOAD; ONE WILL BE ON STAND-BY AT ALL TIMES.
THE UNIT WILL BURN A 2.8X SULFUR COAL. THE SIKESTON STATION WILL FEATURE
AN FRP-LINED STACK, 2 PONDS (ONE FOR FLY ASH, ONE FOR SCRUBBER SLUDGE/
BOTTOM-ASH DISPOSAL), AND « AXIAL FLOW FANS. NO STACK GAS REHEAT IS
PLANNED. MAXIMUM FLUE GAS CAPACITY IS 7
-------
                                                   tPA  UTILITY  FGO  SURVEY:  OCTOBER 197tt - NUVtl"bEk 197M
                                             SECTION  2
                                        STATUS  OF  FGO SYSTEMS
 UNIT IDENTIFICATION
                                                                COkKENT STATUb
SOUTHWESTERN ELECTRIC POWFR
HENRY W. PERKEY 1
  730  MW - NEW
LIGNITE; 0.8X SULFUR, 20X  ASH
AIR CORRECTION DIVISION, UOP
LIMESTONE
STARTUP   2/84
     A CONTRACT FUR THE EMISSION CONTROL SYSHM HAS MF.t.M AftARDEI) TO THE Alk
     CORRECTION DIVISION OF UOP. THE SYSTEC DESIGN INCLUDES  Two CULD-SII)t bSH'b
     FOR PARTICULATE REMOVAL UP-STKEAM FROf a SHkAY TUwEKS WHICH OTILUt LIHb-
     STONE SLURRY FOR S03 CONTROL. SLODGE DISPOSAL WILL BE HANULEO BY Au IUCS
     SYSTEM. START-UP IS EXPECTED BY FEBRUARY 19Bi|.
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
  200  MW - NEW
COAL; 3.5X SULFUR,  13X  ASH
AIR CORRECTION DIVISION,  UOP
LIMESTONE
STARTUP   4/77
SPRINGFIELD WATER LIGHT  S
DALLMAN 3
  190  MW - NEW
COAL; 3.7% SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP   7/80
     REFER TO SECTION S OF THIS REPORT FOK ADDITIONAL  INFORMATION.
     THE EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIKtD UNIT CONSISTS OF A
     FOUR-FIELD HIGH EFFICIENCY ESP  (99.6X DESIGN) AND Z TURBULENT CONTACT AB-
     SORBER MODULES C80X DESIGN) FOR THE CONTROL OF PAKTICULATES AMD bo2. BOlH
     THE ESP AND LIMESTONE FGD SYSTEM ARE SUPPLIED BY  UOP.  THE SCRUBBING
     WASTES ARE DEWATEHEU BY A ROTARY DRUM VACUUM FILTER AND 1HE FILTER CAKF.  IS
     HAULED AWAY TO A LANDFILL. INITIAL OPERATION OF THE FGD SYSTEM OCCURRED  IN
     APRIL 77. IN SEPT. 77, THE UNIT SUCCESSFULLY COMPLETED COMPLIANCE TtSIIuU.
PWR  A CONTRACT WAS AWARDED TO RESEARCH COTTRELL FOR  THE  INSTALLATION UF
     A LIMESTONE FGD SYSTEM. REQUIRED SULFUR DIOXIDE  REMOVAL EFFICIENCY
     IS 90 PERCENT. A SLUDGE DISPOSAL STRATEGY HAS NO!  BEEN FINALIZEO, BUI
     THE UTILITY IS CONSIDERING EITHER PONDING OR LANDFILL. CONSTRUCTION  OF
     THE FGD SYSTEM FOUNDATIONS HAVE BEGUN. ALL SYSTEMS ARE ON  SCHEDULE.  THt
     BOILER OPERATION WAS SCHEDULED TO COMMENCE IN JUNE 1978.
ST. JOE ZINC
6. F. WEATON  1
   60  MW - RETROFIT
COAL; 3x SULFUR
BUREAU OF MINES
CITRATE
STARTUP  12/78
     CONSTRUCTION CONTINUES ON  THE CITRATE  PROCESS  SCRUBBING  SYSTEM  «HICH
     WILL CONTROL 502 EMISSIONS FROM  A  bO-f.1  COAL-FIRED  POWER  GENFRATINb
     UNIT AT ST. JOE MINERALS.  THIS UNIT  PROVIDES POWER  FOR THE  LOCAL  UTILITY
     GRID. FGD SYSTEM START-UP  IS SCHEDULED FOR  DECEMBER 1978. THE kEGENKKABLE
     FbD SYSTEM WILL PRODUCE ELEMENTAL  SULFUR AS A  BY-PRODUCT. ALL MAJOk
     CONSTRUCTION IS COMPLETE.  WIRING AND PIPING WORK  IS NOW  BEING COMPLETED.
TAMPA ELECTRIC
BIG BEND 4
  435  MW - NEW
COAL; 0.4-4.3X SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   0/85
     TAMPA ELECTRIC HAS ANNOUNCED PLANS  TO  INSTALL  AN FGO  SYSTEM  AT  BIG  BEND  <»
     WHICH IS SCHEDULED TO BEGIN OPERATIONS EARLY  IN  1985.  THE  FGO PROCESS  HAS
     NOT YET BEEN SELECTED. PRIMARY PARTICULATE  CONTROL  WILL  BE PROVIDED  BY Atj
     ELECTROSTATIC PRECIPITATOR OPSTHEAM  UF THt  FGD SYSltM.  AN  INDIRECT  ISTEAM
     COIL) HOT AIR INJECTION REHEAT SYSTEM  WILL  BE  INCLUDED  AT  THE scwuBuEk
     OUTLET. DESIGN SULFUR DIOXIDE REMOVAL  EFFICIENCY WILL  BE 90  PEP-CtNT.
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE
  600  MW - RETROFIT
COAL
TVA/UNITED ENGINEERS
MAGNESIUM OXIDE
STARTUP   0/62
     TVA IS PLANNING TO RETROFIT A 600-MW MAGNESIUM OXIDE FGD SYSTEM AT
     THE JOHNSONVILLE STEAM PLANT, A  1500-MW COAL-FIRED  STATION. ENGINEERING
     ASSISTANCE WILL BE PROVIDED BY UNITED ENGINEERS.  THIS  PROJECT  IS BUDGETED
     AT $185 MILLION, INCLUDING THE COST OF A NEW 60U-FT. STACK.
TENNESSEE VALLEY AUTHORITY
PARADISE 1
  650  MW - RETROFIT
COAL
VENDOR NOT SELECTED
LIMESTONE
STARTUP   0/62
TENNESSEE VALLEY AUTHORITY
PARADISE Z
  650  MW - RETROFIT
COAL
VENDOR NOT SELECTED
LIMESTONE
STARTUP   O/ 0
     TVA IS REQUESTING/EVALUATING BID SPECIFICATIONS FOR  TwO LIMESTONE SLURRY
     FGD SYSTEMS WHICH WILL BE RETROFITTED ONTO  TwO 65U-MW HIGH SULFUR COAL-
     FIRED BOILERS AT THIS STATION. THE FGO SYSTEMS WILL  TREAT 100X OF THE FLUE
     GASES FROM BOTH UNITS. TVA HAS PROJECTED  THE TOTAL COST OF THE PAKAOISE
     FGD SYSTEMS TO BE APPROXIMATELY $820 MILLION ($170/KW).  BIO REQUEST WAS
     COMPLETED BY MID-NOVEMBER AND EVALUATION  IS NOW IN PROGRESS. BID EVALUA-
     TION IS EXPECTED TO BE COMPLETED BY JANUARY 1 AND A  CONTRACT SHOOLD 8E
     AWARDED SHORTLY THEREAFTER.

     TVA IS REQUESTING/EVALUATING BIO SPECIFICATIONS FOR  TnO LIMESTONE SLURRY
     FGD SYSTEMS WHICH WILL BE RETROFITTED ONTO  TWO 650-MW HIGH SULFUR CUAL-
     FIRED BOILERS AT THIS STATION. THE FGD SYSTEMS WILL  TREAT 1UOX OF THE FLUE
     GASES FROM BOTH UNITS. TVA HAS PROJECTED  THE TOTAL COST OF THE PARADISE
     FGD SYSTEMS TO BE APPROXIMATELY $220 MILLION ($17U/KW). 8ID REQUEST WAS
     COMPLETED BY MID-NOVEMBER AND EVALUATION  IS NOW IN PROGRESS. BIO EVALUA-
     TION is EXPECTED TO BE COMPLETED BY JANUARY i AND A  CONTRACT SHOULD BE
     AWARDED SHORTLY THEREAFTER.
                                                   19

-------
EPA UTILITY FGO SURVEY: OCTOBER  1<>78  -  NOVEMBER  1978
                                             SECTION  2
                                        STATUS  OF  FGO SYSTEMS
 UNIT IDENTIFICATION
                                                                CURRENT  StAIUS
TENNESSEE VALLEY  AUTHORITY
SHANNEE  10A
   10  MW - RETROFIT
COAL; 2.9X SULFUR,  15.8X  ASH
AIR CORRECTION DIVISION,  UOP
LIME/LIMESTONE
STARTUP   fl/72
REFER 10 THE BACKGROUND INFORMATION IN SbCUUN 3 OF THIS HEPURT.  IH1S
TURBULENT CONTACT ABSORBER (TCA) LIHE/LlMESTUNfc SCRUBBING SYSTfcM  HAS bEfcN
OPERATIONAL SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY  THE  tKA WITH
TVA AS THE CONSTRUCTOR AND FACILITY OPEKATUK. THt BtCHTtL CORP. OF SAN
FRANCISCO IS THE MAJOR CONTRACTOR, TEST OIRtCTOK, AND REPORT  WRITER.
TESTING CHEMICAL ADDITIVES FOR IMPROVING S02 REMOVAL EFFICIENCY
CONTINUED THROUGH OCTOBER AND NOVEMBER.  BOTH VtNTURl/SPRAY TUWfcK AND TCA
SYSTEMS WERE OPERATED ON LIMESTONE SLURRY WITH HIGH FLYASH LOADING.
TENNESSEE VALLEY AUTHORITY
SHAWNEE 108
   10  MW - RETROFIT
COAL) 2.9X SULFUR, 15.8X ASH
CHEMICO
LIME/LIMESTONE
STARTUP   4/72
REFER TO THE BACKGROUND INFORMATION IN SECTION 3 OF THIS KF.PORT.  THIS
VENTUR1/SPRAY TOWER LIME/LIMESTONE SCRUBBING SYSTEM HAS BttN OPERATIONAL
SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY THE EPA WITH TVA AS IHb
CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTEL COKP. OF SAN FRANCISCO  IS
THE MAJOR CONTRACTOR, TEST DIRECTOR, AND REPOKT WRITER. TESTING WITH
CHEMICAL ADDITIVES FOR IMPROVING 502 REMOVAL EFFICIENCY CUNTINUEO
THROUGH OCTOBER AND NOVEMBER. BOTH VENTURI/SPRAY TOWER AND TCA SYSTEMS
WERE OPERATED ON LIMESTONE SLURRY WITH HIGH FLYASH LOADING.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
  575  MW - RETROFIT
COAL» 3.7X SULFUR
COMBUSTION ENGINEERING
LIMESTONE
STARTUP  10/80
TENNESSEE VALLEY AUTHORITY ANNOUNCED THAT A CONTRACT HAS BEEN AWAHllH> Tu
COMBUSTION ENGINEERING FOR A LIMESTONE SLURRY bPHAY TOWER FGO SYSTEM. THt
FGO SYSTEM WILL TREAT HIGH SULFUR COAL FLUE GAS. THE SPRAY TUwEK AUSUKbEWS
WILL BE CONSTRUCTED OF 317L STAINLESS STEEL. THt NO. 7 UNIT FIRES CUAL
WITH THE SAME CHARACTERISTICS AS THE COAL FIRED IN UNIT 8.
INITIAL OPERATIONS ARE SCHEDULED FOR OCTOBER 19BO. THE FGO SYSTEM IS
CURRENTLY UNDER CONSTRUCTION.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 8
  550  MW - RETROFIT
COAL; 3.7x SULFUR, i7x ASH
TENNESSEE VALLEY AUTHORITY
LIMESTONE
STARTUP   5/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS bbO-Mw COAL-FIRED POwhR-GENERATING
UNIT CONSISTS OF EXISTING ELECTROSTATIC PRECIPITA10RS FOLLOWED BY FOUR
PARALLEL SCRUBBING TRAINS, EACH CAPABLE OF HANDLING 25 PERCENT OF THE
BOILER FLUE GAS FROM UNIT 8. EACH TRAIN INCLUDES A RECTANGULAR THROAT
VENTURI SCRUBBER AND A GRID-TOWER ABSORBER SUPPLIED BY PULYCON. THE GKID
TOWER CAN BE CONVERTED TO A MOBILE-BED TOWEK IF GREATER SU2 REMOVAL IS
REQUIRED.
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
  400  MW - NEW
LIGNITE; 1.06X SULFUR, 25X ASH
COMBUSTION ENGINEERING
LIMESTONE
STARTUP   1/82
COMBUSTION ENGINEERING WAS AWARDED A CONTRACT TU DESIGN ANO SUPPLY
A 400-HW LIGNITE-FIRED BOILER, ESP, AND FGD SYSTEM AT GIBBONS CREEK
STEAM ELECTRIC STATION UNIT NO. 1. THE BOILER WILL BURN l.ObX SULFUR
LIGNITE. FLUE GAS WILL BE CLEANED OF PARTICULATES BY A COLO-S10E ESP
(99.73X EFFICIENCY). SU2 WILL BE REMOVED BY 3 SPRAY TOWER MODULES UTILU-
ING A LIMESTONE SLURRY (72.5 TO 87.5X EFFICIENCY). A CONTRACT HAS BEEN
AWARDED TO IOCS FOR SLUDGE DISPOSAL. CONSTRUCTION IS TO BEGIN IN THE
SPRING OF 1979. COMMERCIAL START-UP IS SCHEDULED FOR JANUARY, 19«2.
TEXAS POWER & LIGHT
SANDOW 4
  545  MW - NEW
LIGNITE
COMBUSTION ENGINEERING
LIMESTONE
STARTUP   7/80
COMBUSTION ENGINEERING HAS BEEN CHOSEN AS THE BOILER AND FGO VENDOR FUR
THIS UNIT. BOILER CONSTRUCTION BEGAN ON SEPTEMBER 9, 19/7. PARTICULAR
REMOVAL EQUIPMENT WILL BE LOCATED ON THE COLD-SIDE UF THE AIR HEATER.
SOME PORTION OF FLUE GAS WILL BYPASS THE SCRUBBER FUR REHEAT. THE SPENT
SLURRY WILL BE PONDED AND WATER RECYCLED. FGD CONSTRUCTION IS SCHEDULED
TO BEGIN NOVEMBER 1978.
TEXAS POWER & LIGHT
TWIN OAKS t
  750  MW - NEW
LIGNITE
VENDOR NOT SELECTED
LIMESTONE
STARTUP   8/63
THIS UNIT WILL BE JOINTLY OWNED BY TP&L AND ALCOA. A FIRM DECISION HAS
NOT BEEN MADE WHETHER TU INSTALL FGD FACILITIES. THIS IS PRIMARILY
DUE TO THE FACT THAT SUCH A DECISION IS NOT YET REQUIRED IN THE
UTILITIES PLANNING TIMETABLE.
TEXAS POWER * LIGHT
TWIN OAKS 2
  750  MW - NEW
LIGNITE
VENDOR NOT SELECTED
LIMESTONE
STARTUP   9/84
THIS UNIT WILL HE JOINTLY OWNED BY TPfcL AND ALCUA. A FIRM DECISION HAS
NOT BEEN MADE WHETHER TO INSTALL FGD FACILITIES. THIS IS PRIMARILY
DUE TO THE FACT THAT SUCH A DECISION IS NOT YET REQUIRED IN THE
UTILITIES PLANNING TIMETABLE.

-------
                                                   EPA  UTILITY  FGO  SURVEY:  OCTOBER  1978  -  NOVtKBtk
 UNIT IDENTIFICATION
                                            SECTION  a
                                       STATUS  OF  FGO SYSTEMS
                                                                CURRENT  STATUS
TEXAS UTILITIES
FOREST GROVE 1
  750  MW - NEW
LIGNITE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   0/81
TEXAS UTILITIES IS PLANNING A NEK 7bO-Mrt UNIT Al TMt FUREM GROVt blTt.
TWO ESP'S WILL BE INSTALLED FOR PARTICULATE CUNTHOL. THE UTILITY IS
CURRENTLY REQUESTING BIOS FOR AN FGD SYSTEM. START-UP IS SCHEDULED FUR
LATE 1981. THE BOILER WILL BE SUPPLIED BY THE BABCOCK A wlLCOX COMHAMt.
THE DESIGN DOES NOT INCLUDE A STACK GAS REHEAT SYSTEM.
TEXAS UTILITIES
MARTIN LAKE 1
  793  MN - NEW
COAL) 0.9X SULFUR, 8X ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP   8/77
TEXAS UTILITIES
MARTIN LAKE 2
  793  MW - NEW
COAL; o.9x SULFUR, az ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP   5/78
TEXAS UTILITIES
MARTIN LAKE 3
  793  MM - NEW
COAL; o.9z SULFUR,  ax  ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP  12/78
TEXAS UTILITIES
MARTIN LAKE 4
  793  MM - NEM
COAL; o.9z SULFUR, sx ASH
RESEARCH COTTRELL
LIMESTONE
STARTUP   8/50
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS lit* 74.5
MW UNIT FIRES TEXAS LIGNITE CONTAINING U.9X SULFUK IAVG) AMD 8X ASH
(AVG). THE UNIT IS EQUIPPED WITH AN EMISSION CONTROL SYSTEM WHICH INCLUDES
COLD-SIDE ESP'S AND A LIMESTONE FGD SYSTEM bUTH SUPPLIED BY RESEAKCH-CUT-
TRELL. THE FGD SYSTEM CONSISTS OF b PACKED/SPRAY TO«tK ABSORBERS AHICH
TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REGAINING FLUE GAS I-S HYPASStU
FOR REHEAT. TOTAL 302 REMOVAL EFFICIENCY IS 7U.bX. THE FLUE GAS CLF.AMUG
WASTES ARE STABILIZED AND DISPOSED IN AN ON-SITE, LANDFILL.

REFER TO SECTION 3 OF THTS REPORT FOR ADDITIONAL INFUKMAT ION. IH1S NE« 79.5
MW UNIT FIRES TEXAS LIGNITE CONTAINING 0.9X SULFUK (.AVG) AND SX ASH tAVU).
THE UNIT IS EQUIPPED WITH AN EMISSION CONTROL SYSTEM CONSISTING UF COLD-
SIDE ESP'S AND A LIMESTONE FGO SYSTEM, BOTH SUPPLIED BY HESEAHCH-COTTHtLL.
THE FGD SYSTEM CONSISTS OF 6 PACKED/SPRAY TOWtR ABSORBERS THAT CHEAT 7bX
OF THE BOILER FLUE GAS. THE REMAINING GAS IS BYPASSED FUR REHEAl. TUTAL
DESIGN S02 REMOVAL EFFICIENCY IS 70.5X. THE FLUE GAS CLEANING rtASTES ARE
STABILIZED AND DISPOSED IN AN ON-SITE, LANDFILL.

THIS NEW 793-MW POWER GENERATING UNIT WILL FIRE TEXAS LIGNITE CONTAINING
0.9X SULFUR (AVG.) AND HZ ASH (AVG.). TU MEET FEDERAL NSPS, THk UNIT WILL
BE EQUIPPED WITH AN EMISSION CONTROL SYSTEM CONSISTING UF COLD-SIDt ESP'b
AND A LIMESTONE FGO SYSTEM, BOTH SUPPLIED BY RESEARCH-COTTRELL. THt FtiU
SYSTEM CONSISTS OF b PACKED/SPRAY TUWER ABSORBERS WHICH HILL TREAT 7bi UF
THE TOTAL BOILER FLUE GAS. THE REMAINING GAS WILL BE BYPASSED FDR REHEAT.
TOTAL DESIGN S02 REMOVAL EFFICIENCY IS 70.SX. THE FLUt GAS CLEANING rtASIES
WILL BE STABILIZED AND DISPOSED IN AN ON-SITE, LANDFILL.

THE CONTRACT FOR THIS FGD SYSTEM HAS BEEN AWARDED Fu RESEARCH-COTTRELL.
THE BOILER IS NOW BEING ERECTED. START-UP HAS BEEN DELAYED TO EITHER 19«b
OR 1986.
TEXAS UTILITIES
MONTICELLO 3
  750  MM - NEM
LIGNITE* 1.5Z SULFUR,  19X  ASH
CHEMICO
LIMESTONE
STARTUP   5/78
UTAH POWER ft LIGHT
EMERY 1
  400  MW - NEW
COAL; o.sx SULFUR, 9-i2z  ASH
CHEMICO
LIME
STARTUP   1/79
UTAH POWER « LIGHT
EMERY 2
  400  MM • NEW
COAL; o.sx SULFUR, 9-12X ASH
CHEMICO
LIME
STARTUP   6/80
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE
CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A HIGH EFFICIENCY ESP AMD A LIKE-
STONE FGD SYSTEM. THE ESP (POLLUTION CONTROL-WALTHER) PROVIDES PRIMARY
PARTICULATE CONTROL (99.56Z). THE FGD SYSTEM CONSISTS OF 1 LIMESTONt
SCRUBBING SPRAY TOWERS THAT PROVIDE PRIMARI S08 CONTROL (7UZ). (HE FGD
SYSTEM IS DESIGNED TO TREAT 3MM ACFM OF FLUE GAS RESULTING FROM COAL WITH
l.SZ SULFUR, 18.9Z ASH AND O.OOZ CL. THE FLUE GAS CLEANING WASTES ARE
DISPOSED IN AN ON-SITE, LINED POND.

A CONTRACT HAS BEEN AWARDED TO THE CHEMICO AIR POLLUTION DIVISION FOR
A PEBBLE LIME WET SCRUBBING SYSTEM ON THIS NEW UNIT. THE SCRUBBING
SYSTEM IS DESIGNED TO OPERATE IN AN OPEN WATER LOOP MODE WITH AN SOS
REMOVAL EFFICIENCY OF 80 PERCENT FOR LOW SULFUR UTAH COAL. PRIMARY
PARTICULATE CONTROL WILL BE PROVIDED BY AN ESP UPSTREAM OF THE SCRUBBERS.
THE SLUDGE MILL BE STABILIZED WITH FLYASH AND DISPOSED ON THE PLANT SITE.
THE A-E DESIGN FIRM FOR THIS PROJECT IS STEARNS-ROGER. CONSTRUCTION IS NU«
IN ITS FINAL STAGES. START-UP MAY BE PUSHED BACK TO FEBRUARY.

UTAH P»L AWARDED CHEMICO A CONTRACT TO SUPPLY A LIME FGD SYSTEM FOR
EMERY 2 DESIGNED TO OPERATE IN AN OPEN WATER LOOP MODE WITH AN 505 REMOVAL
EFFICIENCY OF 80 PERCENT (FIRING LOW SULFUR UTAH COAL). PRIMARY PARTIC-
ULATE CONTROL WILL BE PROVIDED BY AN ESP UP-STREAM OF THE SCRUBBERS. THE
SLUDGE WILL BE STABILIZED WITH FLYASH AND DISPOSED ON THE PLANT SITt.
INITIAL BOILER AND FGO SYSTEM START-UP IS SCHEDULED FOR JUNE 19«0. THIS
UNIT WILL BE IDENTICAL TO UNIT 1. CONSTRUCTION ON THIS UNIT IS NOW ABUUT
35X COMPLETE. THIS UNIT WILL BE IDENTICAL TU UNIT ONE.
                                                   21

-------
EPA UTILITY FGO SURVEY: OCTOBER 1976 - NOVEMBER  1978
                                            SECTION 2
                                       STATUS OF FGO SYSTEMS
 UNIT IDENTIFICATION
                                CURRENT STATUS
UTAH POWER ft LIGHT
HUNTINGTON 1
  415  MW - NEH
COAL; O.SX SULFUR, 101 ASH
CHEHICO
LIME
STARTUP   5/78
REFER TO SECTION 3 OF THIS RFPORT FOR ADDITIONAL INFORMATION. CHEMICO WAS
THE SUPPLIER OF A LIME SCRUBBING SYSTEM FOH THIS NEW UNIT. PRIMARY PAKTIC-
ULATE REMOVAL IS PROVIDED BY AN ESP INSTALLED UHSTKtAM OF THE WEI SCRUB-
BING SYSTEM. A DAMPER IS USED DURING OPERATION TO ALLOW BETWEEN 10 AND «JU
PERCENT OF THE FLUE GAS TO BY-PASS THE FGD SYSTEM. DESIGN REMOVAL EFFI-
CIENCIES FOR 302 AND PARTICULATE ARE 80 AND 99.5 PERCENT KESPECTIVELY .
SLUDGE IS DEWATERED (60X SOLIDS) AND TRUCKED TO AN UN-SITE LANDFILL.
INITIAL OPERATIONS AT THIS UNIT BEGAN ON MAY 10, 1978.
VIRGINIA ELECTRIC 8 POWER
MT. STORM
 1147  MW - RETROFIT
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP   O/ 0
THE UTILITY IS CURRENTLY WAITING FOR AN EPA DECISION REGARDING A WEST
VIRGINIA STATE EMISSION CONTROL PROPOSAL. PLANS FOR SULFUR DIOXIDE
CONTROL ARE TEMPORARILY AT A STANDSTILL PENDING THIS DECISION. IF THE
PRESENT PROPOSAL IS ACCEPTED AN FGD SYSTEM MAY NOT BE REQUIRED.
WISCONSIN POWER * LIGHT
COLUMBIA 2
  527  MW - NEW
COAL} O.BZ SULFUR
CHEMICO
LIME/ALKALINE FLYASH
STARTUP   1/80
A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR A LIME/FLYASH FGD SYS-
TEM. IT WILL CONSIST OF TWO SPRAY MODULES WITH A HOT-SIDE ESP FUR PAR-
TICULATE REMOVAL. A CLOSED LOOP WATER SYSTEM IS ANTICIPATED WITH FLYASH
STABILIZATION OF THE SLUDGE. A SLUDGE DISPOSAL POND LOCATED OFF-SITE IS
BEING CONSIDERED. THE FGD SYSTEM IS BEING DESIGNED TO TREAT bOX OF THE
FLUE GAS RESULTING FROM THE COMBUSTION OF LOW SULFUR COLSTRIP COAL. THE
REMAINING 40X WILL BE BYPASSED FOR REHEAT.
                                                  22

-------
                                                  EPA UTILITY FGD SURVEY:  OCTObEH  1978  -  NOVEMHEK  1S/B
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS

    UTILITY NAME          ALABAMA ELECTRIC COOP
    UNIT NAME             TOMBIGBEE Z
    UNIT LOCATION         JACKSON ALABAMA
    UNIT RATING            ZZ5 Mw
    FUEL CHARACTERISTICS  COAL; l.lbX SULFUR
    FGD VENDOR            PEABODY PROCESS SYSTEMS
    PROCESS               LIMESTONE
    NEW OR RETROFIT       NEW
    START UP DATE          9/78
    EFFICIENCY:
     PARTICIPATES (ACTUAL)
                  (DESIGN)   99.6 PERCENT
     S03          (ACTUAL)
                  (DESIGN)   60.0 PERCENT
    WATER MAKE UP         OPEN LOOP 1.10 GPM/MW
    SLUDGE DISPOSAL       UNSTABILIZED/SLUDGE POND

    OPERATING EXPERIENCE UPDATE:
                                                                                                i
AUGUST-SEPTEMBER 1978 - INITIAL OPERATION OF THIS UNIT BEGAN DURING THE AUGUST-SEPTEMBER REPUKT ,
PERIOD.  THE FGO SYSTEM IS CURRENTLY IN THE SHAKEDOWN AND DEBUGGING PHASE UF UPEKATIUN.  DUE TO/
-------
EPA UTILITY F60 SURVEY: OCTOBER 1<>78 - NOVEMBER 1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS


    UTILITY NAME          ARIZONA ELECTRIC POWER COOP

    UNIT NAME             APACHE 2

    UNIT LOCATION         COCHISE ARIZONA

    UNIT RATING            800 MW

    FUEL CHARACTERISTICS  COAL; 0.7X SULFUR, 10X ASH

    F60 VENDOR            RESEARCH COTTRELL

    PROCESS               LIMESTONE

    NEN OR RETROFIT       NEW

    START UP DATE          8/76

    EFFICIENCY!
     PARTICIPATES (ACTUAL)

                  (DESIGN)   99.4 PERCENT

     303          (ACTUAL)

                  (DESIGN)   8S.O PERCENT

    MATER MAKE UP         OPEN LOOP 9.2 GPM/MW

    SLUDGE DISPOSAL       UNSTABILIZtD/SLUDGE POND



    OPERATING EXPERIENCE UPDATE:


  AUGiT-SEPTEMBER 1978 - INITIAL OPERATION OF THE FGD SYSTEM AT THIS UNIT BEGAN IN AUGUST AND  II  IS
  CURlNTLY BEING TESTED.  NO INITIAL PROBLEMS HAVE BEEN REPORTED.  DUE TO THE RECENT OPERATING STATUS
  HOUR OF OPERATION ARE NOT YET AVAILABLE.

  PERI)             BOILER             FGD HOURS          OPEHABIL1TY  (X)          UTILIZATION (X)
               OPERATION (HR)         A       B             AH                AH

  OCT. |           303                N/A     N/A           N/A     N/A              N/A     N/A
    BOiER OUTPUT = 86,379 MW-H
  NOV. 7           468                121     213            25      44               17       30
          OUTPUT = 116,217 MW-H
         COMPLIANCE TEST WAS COMPLETED, BUT THE RESULTS ARE NOT YET AVAILABLE.  AN ACCEPTANCE TEST
        5 SCHEDULED FOR THE BEGINNING OF 1979.  THE ONLY PROBLEM REPORTED BY THE UTILITY WAS  THE
         (ABILITY OF THE LIMESTONE CRUSHER TO MEET DESIGN CAPACITY.

-------
                                               EPA UTILITY FGO SURVEY: OCTUBtk 1978 - NOVEMbtK 19/a
                  SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING
                          ARIZONA PUBLIC SERVICE

                          CHOLLA  1

                          JOSEPH  CITY  ARIZONA

                            115 MW
 FUEL CHARACTERISTICS  COAL; 0.55X SULFUR. 10X ASH

 F60 VENDOR            RESEARCH COTTRELL

 PROCESS               LIMESTONE

 NEW OR RETROFIT       RETROFIT

 START UP DATE         10/73
 EFFICIENCY:
  PARTICULATES (ACTUAL)

               (DESIGN)

  303          (ACTUAL)

               (DESIGN)

 WATER MAKE UP

 SLUDGE DISPOSAL
                             99.7 PERCENT

                             99.7 PERCENT

                             50-60 PERCENT

                             58.5 PERCENT

                          OPEN LOOP  1.04 GPM/MW

                          UNSTABILIZED/SLUDGE POND
    OPERATING EXPERIENCE UPDATE:

              RELIABILITY  (X)
MONTH      MODULE A    MODULE B
JAN. 78       97         91
FEB. 78       99         88
MAR.
APR.
MAY
JUNE
JULY
AUG.
SEP.
OCT.
NOV.
78
78
78
78
78
78
78
78
78
74
100
87
100
99
100
100
100
100
74
100
90
100
100
95
too
100
too
                                                             COMMENTS
                                 THE FLOODED DISC SCRUBBER TANK HEADER FOR SLURRY LIMESTONE
                                 REPAIRED AFTER BEING DAMAGED DURING THE OVERHAUL.  THE BUILER
                                 WAS OPERATED ONLY 135 HRS. DURING JANUARY AS THE OVERHAUL HAU
                                 EXTENDED INTO THIS MONTH.  THE A-SIDE ANU 8-SIDE SERVICE HOURS
                                 WERE 131 AND 183 HOURS RESPECTIVELY.

                                 SOME MINOR LEAK REPAIRS AFTER THE OVERHAUL/CLEANING TOUK PLACE
                                 DURING FEBRUARY.  SERVICE HOURS MERE: BOILER = 642, A-SIOE =
                                 636, B-SIDE = 564.

                                 ONE FORCED SHUTDOWN OCCURRED ON THE A-SIOE. SERVICE HOURS HERE:
                                 BOILER = 744, A-SIOE = 744, B-SIDE = 735.

                                 A MINOR LEAK REPAIR MAS NECESSARY AFTER AN OVERHAUL/CLEANING.
                                 SERVICE HOURS WERE: BOILER = 780, A-SIDE = 667, B-SIDE = 7£u.

                                 THERE WERE NO SIGNIFICANT PROBLEMS REPORTED.  ONLY GENERAL
                                 MAINTENANCE WAS PERFORMED ON THE SYSTEM.

                                 NO PROBLEMS WERE REPORTED.

                                 ONLY ROUTINE MAINTENANCE WAS REQUIRED.

                                 REPAIRS WERE NECESSARY TO PLUGGED B-SIDE REHEAT COILS.

                                 NO PROBLEMS WERE REPORTED.  SERVICE HOURS WERE: BOILER = 720,
                                 A-SIDE s 720,.B-SIDE = 704.

                                 ONLY ROUTINE MAINTENANCE WAS REQUIRED.  SERVICE HOURS WERE:
                                 BOILER * 434, A-SIDE > 434, B-SIDE * 416.

                                 NO PROBLEMS WERE REPORTED.  SERVICE HOURS WERE: BOILER - 720
                                 A-SIDE = 720, B-SIDE = 657.
                                               25

-------
EPA UTILITY FGO SURVEY: OCTOBER  1978 - NOVEMBER 1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS


    UTILITY NAME          ARIZONA PUBLIC SERVICE

    UNIT NAME             CHOLLA 2

    UNIT LOCATION         JOSEPH CITY ARIZONA

    UNIT RATING            250 MM

    FUEL CHARACTERISTICS  COAL; 0.55Z SULFUR, 10Z ASH

    FGD VENDOR            RESEARCH COTTRELL

    PROCESS               LIMESTONE

    NEW OR RETROFIT       NEW

    START UP DATE          6/70

    EFFICIENCY:
     PARTICULATES (ACTUAL)

                  (DESIGN)   99.7 PERCENT

     302          (ACTUAL)

                  (DESIGN)   75.0 PERCENT

    MATER MAKE UP         OPEN LOOP

    SLUDGE DISPOSAL       UNSTABILIZEO/SLUDGE POND



    OPERATING EXPERIENCE UPDATE:


APRIL-HAY 1978 - THE SCRUBBER ON UNIT 2 IS NOW WORKING MOST OF THE TIME AND IS THEREFORE CONSIDERED
TO BE OPERATIONAL. SOME PROBLEMS HAVE OCCURRED WITH VIBRATIONS THROUGH THE SYSTEM. THE EPA HAS
GRANTED THE UTILITY AN EXTENSION FOR COMPLIANCE.

JUNE-JULY 1978 - UNIT 2 IS STILL UNDERGOING SHAKEDOWN AND DEBUGGING OPERATIONS.  THE SLURRY RECYCLE
PIPING HAS EXPERIENCED CONTINUAL VIBRATION.  THE CONTRACTOR HAS BEEN INJECTING NITROGEN (GAS) INTO
THE LINES TO DAMPEN THE VIBRATIONS (AIR WAS NOT USED BECAUSE THE SULFITE WOULD BE OXIDIZED TO
SULFATE AND RESULT IN SCALE FORMATION IN THE SYSTEM).  A PROBLEM HAS ALSO OCCURRED WITH PEELING OF
THE CORROSION RESISTANT COATING IN THE OOWNCOMER AREA IN ONE OF THE ABSORBER MODULES.

AUGUST-SEPTEMBER 1970 - SHAKEDOWN/DEBUGGING OPERATIONS CONTINUE.  THE SLURKY RECYCLE PIPING IS STILL
EXPERIENCING RESONANT VIBRATIONS.

OCTOBER-NOVEMBER 1976 - THE SHAKEDOWN/DEBUGGING OPERATIONS CONTINUE.  SOME SCRUBBER COMPONENTS ARE
STILL MANNED BY BECHTEL STAFF ALTHOUGH APS IS OPERATING MOST OF THE SYSTEM.

-------
                                                  EPA UTILITY F60 SUHVEY: OCTOBER 1978 - NOVEMBtK 197B
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL F6D SYSTEMS
    UTILITY NAME


    UNIT NAME


    UNIT LOCATION


    UNIT RATING
                  CENTRAL ILLINOIS LIGHT


                  DUCK CREEK 1


                  CANTON ILLINOIS


                   400 MN
    FUEL CHARACTERISTICS  COAL; 3.3X SULFUR, 6.3X ASH
    FGO VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE

    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)


     302          (ACTUAL)


                  (DESIGN)


    WATER MAKE UP


    SLUDGE DISPOSAL
                  RILEY STOKER / ENVIRONEERING


                  LIMESTONE


                  NEW


                   7/78



                     99.8 PERCENT


                     99.8 PERCENT





                     85.0 PERCENT


                  CLOSED LOOP 1.5 GPM/MW


                  UNSTABILIZED/SLUDGE POND
    OPERATING EXPERIENCE UPDATE:
JUNE-JULY 1978 • ALL 4 MODULES BECAME OPERATIONAL ON JULY 24.  THE SYSTEM HAS OPERATED INTERMIT-
TENTLY THROUGHOUT THE PERIOD.  MODIFICATIONS WERE MADE TO THE SLURRY TRANSFER TANK, SINCE IT HAS
FOUND TO BE UNDER DESIGNED.  A PLUGGING PROBLEM OCCURRED IN THE FGD SYSTEM DUE TO COAL FINES BEING
MIXED IN WITH THE SLURRY.  THIS RESULTED FROM THE USE OF COMMON UNLOADING AND TRANSFER SYSTEMS FUR
THE COAL AND LIMESTONE.
PERIOD
   TOTAL
PERIOD (HR)
AUG. 78    744
AVAILABILITY = 45X
OPERABILITY = 46X
RELIABILITY = 46X
UTILIZATION = 42X
                          BOILER
                      OPERATION  (HR)


                           691
                           691
     SYSTEM
AVAILABILITY (HR)


      333
                                      333
 SYSTEM CALLED
TO OPERATE (HR)


     685
                                                                  685
HR. SYSTEM
 OPERATED


   315
                                                                          315
SEP. 78    720
AVAILABILITY = 46X
OPERABILITY s 46X
RELIABILITY = 46X
UTILIZATION = 44X
       PROBLEMS CONTINUED WITH THE COMMON COAL AN D LIMESTONE UNLOADING FACILITY THROUGH AUGUST AND
                   SCREEN BASKETS WERE USED TO KEEP COAL PARTICLES OUT OF THE LIMESTONE IN
                                          MORE PERMANENT SEPARATOR SYSTEMS ARE BEING STUDIED.
       DESIGN DEFICIENCIES IN THE SLURRY TRANSFER SYSTEM PREVENTED PROPER FLOW OF THE SLURRY TU THE
       SCRUBBER MODULE RECYCLE TANKS.  THE OLD SYSTEM MAS REMOVED AND A NEW PIPING SYSTEM MAS IN-
       STALLED.  NO PROBLEMS HAVE BEEN ENCOUNTERED WITH THE NEW SYSTEM.  PLUGGING OF THE RECYCLE
       PUMP SHUT-OFF VALVES OCCURRED AND THEY ARE BEING REPLACED WITH PINCH VALVES.  THE SCRUBBER
       WASTE WATER SUMP PUMPS HAVE ALSO BEEN PLUGGING AND NEW PUMPS ARE BEING INVESTIGATED.
       SEPTEMBER.
       ORDER TO PREVENT NOZZLE PLUGGING.
                                                  27

-------
EPA UTILITY F60 SURVEY: OCTOBER  1978 - NOVEMBER  1978

           TOTAL          BOILER             SYSTEM           SYSTEM CALLED    HR. SYSIEM
PERIOD  PERIOD (HR)   OPERATION  (HR)    AVAILABILITY  IHR)     TO OPERATE  (HR)    OPERATED

OCT. 78    7<1
-------
                                                   EPA  UTILITY  FGO  SUHVEY:  UCTOBEk  1978  -  MOVt^rtEK
                      SECTION  3
   PERFORMANCE  DESCRIPTION  FOR  OPERATIONAL  FGD  SYSTEMS
    UTILITY  NAME

    UNIT  NAME

    UNIT  LOCATION

    UNIT  RATING
                 COLUMBUS » SOUTHERN OHIO ELEC.

                 CONESVILLE 5

                 CONESV1LLE OHIO

                  400 MW
    FUEL  CHARACTERISTICS   COAL;  4.7X  SULFUR,  15.U  ASM
    FGD  VENDOR

    PROCESS

    NEW  OR RETROFIT

    START UP  DATE

    EFFICIENCY:
     PARTICULATES  (ACTUAL)
                   (DESIGN)

     802           (ACTUAL)

                   (DESIGN)

    WATER MAKE  UP

    SLUDGE DISPOSAL
                 AIR CORRECTION DIVISION, UOP

                 LIME  (M6-PROMOTED)

                 NEW

                  1/77




                    99.6 PERCENT



                    89.5 PERCENT

                 OPEN LOOP 1.25 GPM/Mh

                 STABILIZED/LANDFILL
    OPERATING EXPERIENCE  UPDATE:
PERIOD
   OPERATION TIME (HR)
BOILER    A-SIDE    B-SIDE
JAN. 78                00
ALL INDEX VALUES  =  0  PERCENT

FEB. 78
ALL INDEX VALUES  =  0  PERCENT

HAR. 78    379         72        60
AVAJUABUJTY  <*)  =     20        20
OPERABILITY (X) =      19        16
RELIABILITY (X) =      64        54
UTILIZATION (X) =10        8

APR. 78    716        418       425
AVAILABILITY  (X)  =     67        65
OPERABILITY (X) s      SB        59
RELIABILITY (X) =      61        63
UTILIZATION (X) =      58        59

MAY  78    720        327       365
AVAILABILITY  (X)  =     52        54
OPERABILITY (X) a      45        50
RELIABILITY (X) =      45        51
UTILIZATION (X) =      44        49

JUNE 76    720        269       217
AVAILABILITY  (X) =     48        30
OPERABILITY (X) *      37        30
RELIABILITY (X) *      37        30
UTILIZATION (X) s      37        30

JULY 78    727        478       240
AVAILABILITY  (X) «     66        43
OPERABILITY (X) s      66        33
RELIABILITY (X) *      66        33
UTILIZATION (X) s      64        32
                                                                      COMMENTS
                                   THE UNIT WAS SHUTDOWN FUK OVERHAUL THROUGH FEBRUARY ANI
                                   STARTED UP ON MARCH 16.

                                   IMPURITIES IN LIME HAVE CAUSED PLUGGING PROBLEMS.  PH
                                   CONTROLS AND SU2 ANALYSERS HAVE GIVEN SOME UPEKAT ION»L
                                   PROBLEMS.
                                   THE SYSTEM WAS DOWN DUE TO AN EXCESS OF FLUCCULAM
                                   IN THE THICKENER. THIS CAUSED A HIGH AMOUNT UF SOLIDS
                                   IN THE OVERFLOW THAT RESULTED IN PLUGGING PHUHLEMS IN
                                   THE ABSOKBER MODULES.
                                   THE SYSTEM WAS TAKEN OUT OF SEKVICE BECAUSE UF CONTINUED
                                   PROBLEMS WITH THE FLOCCULANT FEED SYSTEM.  THE THICKENtR
                                   WAS EMPTIED TO RESTORE PROPER FLUCCULANT BALANCE.
                                   FLOCCULANT WAS CLEANED OUT.
                                   AN FRP PIPING FAILURE IN THE MIST ELIMINATOR NASH
                                   SYSTEM OCCURRED IN JUNE.
                                   OUTAGE TIME WAS DUE TO PLUGGING IN THE MIST ELIMINATOR
                                   AND SCRUBBER BALL REGIONS.
                                                  29

-------
EPA UTILITY FGO  SURVEY:  OCTOBER  1978  -  NOVEMBER  1978

COLUMBUS ft SOUTHERN OHIO ELEC.
            OPERATION  TIME  (HR)
PERIOD   BOILER    A-SIDE    B-SIOE

»US. 76    667       134       137
AVAILABILITY  (X) =     18        18
OPERABILITY (X) s      20        21
RELIABILITY (X) s      20        21
UTILIZATION (X) s      18        18

SEP. 78    707       324       300
AVAILABILITY  (X) =     61        54
OPERABILITY (X) =      46        44
RELIABILITY (X) s      55        53
UTILIZATION (X) =      45        43

OCT. 78    713       268       335
AVAILABILITY  (X) =     72        82
OPERABILITY = (X)      37        47
RELIABILITY = (X)      38        47
UTILIZATION = (X)      36        45

NOV. 78    642       187      475
AVAILABILITY = (X)     43        64
OPERABILITY (X) r      29        74
RELIABILITY (X) s      29        75
UTILIZATION (X) =      26       66
                    CONESVILLE 5
                         COMMENTS
FORCED OUTAGE TIME WAS REQUIRED TO REMOVE SCALE
FROM THE MIST ELIMINATOR.  IT WAS ALSO NECESSAKT  TO HE-
PLACE SOME OF THE PING PONG BALLS IN THE MODULES.
DURING THE AUGUST-SEPTEMBER REPORT PERIOD PROBLEMS WERE
ENCOUNTERED WITH THE BYPASS DAMPERS.  UTHER PROBLEM
AREAS INCLUDED BROKEN SLUDGE LINES AND PLUGGING OF- THE
LIME SLURRY FEED LINES.
DURING THE OCTOBER-NOVEMBER KEPORT PERIOD PROBLEMS,Wl TH
THE DAMPER DRIVE WERE REPORTED.  ALSO MINIMAL kUbBER
LINER FAILURE WAS OBSERVED AT THE TOP OF THE SCKUBBEH
MODULE AND JUST AFTER THE PRESATURATUR.
                                                  30

-------
                                                   EPA UTILITY  FGU  SURVEY:  OCT08EK  1978  -  NUVEI"BEN  1978
                      SECTION  3
   PERFORMANCE  DESCRIPTION  FOR  OPERATIONAL F6D SYSTEMS
     UTILITY  NAME

     UNIT  NAME

     UNIT  LOCATION

     UNIT  RATING
                 COLUMBUS & SOUTHERN OHIU ELEC.

                 CONESVILLE 6

                 CONESVILLE OHIO

                  000 Mw
    FUEL  CHARACTERISTICS   COALj  4.67X SULFUR,  15.IX ASH
     FGO  VENDOR

     PROCESS

     NEW  OR RETROFIT

     START UP  DATE

     EFFICIENCY:
      PARTICULATES  (ACTUAL)
                   (DESIGN)

     302           (ACTUAL)

                   (DESIGN)

    HATER MAKE  UP

    SLUDGE DISPOSAL
                 AIR CORRECTION DIVISION, UOP

                 LIME  (MG-PROMOTED)

                 NEW

                  6/76




                    99.6 PERCENT



                    89.5 PERCENT

                 OPEN LOOP 1.25 GPM/MW

                 STABILIZED/LANDFILL
    OPERATING  EXPERIENCE  UPDATE:
PERIOD
    OPERATION TIME (HR)
BOILER    A-SIDE    B-SIDE
JUNE 78    524        173       175
AVAILABILITY  (X) =     56        44
OPERABILITY  (X) =      49        33
RELIABILITY  (X) =      51        34
UTILIZATION  (X) =      42        30

JULY 78    502        166        96
AVAILABILITY  U) =     83        70
OPERABILITY  (X) a      37        19
RELIABILITY  (X) =      63        33
UTILIZATION  (X) -      25        13

AUG. 76    642        318       390
AVAILABILITY  (X) =     47        62
OPERABILITY  (X) =      50        60
RELIABILITY  (X) =      66        61
UTILIZATION  (X) =      43        52

SEP. 78    706        356       388
AVAILABLITY  (X) c      55        69
OPERABILITY  (X) =      50        55
RELIABILITY  (X) r      S3        57
UTILIZATION  (X) =      49        54

OCT. 78    603        181       218
AVAILABILITY  (X) c     98        37
OPERABILITY  (X) »      29        35
RELIABILITY  (X) a      30        36
UTILIZATION  (X) *      24        29

NOV. 78    480         14        43
AVAILABILITY  (X) s     26        26
OPERABILITY  (X) =      3        9
RELIABILITY  (X) «      3        6
UTILIZATION  (X) *      2        8
                                                            COMMENTS

                                   CONTROL OF THE LOUVERED DAMPER OF THE BYPASS SYSTEM
                                   WAS LOST.  THE RESULT WAS A BACK PRESSURE BUILD UP
                                   THAT AUTOMATICALLY TRIPPED THE BOILEK OFF.  SCRUBBER
                                   CONTROLS WERE NOT OPERATING PROPERLY AND NEEDED ADJUST-
                                   MENT.

                                   THE LOUVERED DAMPER PROBLEM CONTINUED.  3CKUBBEH
                                   CONTROLS WERE ADJUSTED.  THE FRP TRANSFER LINE FROM
                                   THE THICKENER TO THE IUCS SYSTEM RUPTURED AS A RESULT
                                   OF A WATER HAMMER IN THE LINES AND HAD TU BE REPAIRED.
                                   THE LINE BECAME PLUGGED AT A "Y" VALVE DURING DUhN TIME.

                                   DURING AUGUST PROBLEMS WERE ENCOUNTERED WITH THE SLUDGE
                                   LINE AS WELL AS THE BY-PASS CONTROL DAMPERS.   THE
                                   UTILITY REPORTS THAT THESE ARE TYPICALLY HIGH MAIN-
                                   TENANCE AREAS.
                                   THE BY-PASS DAMPER CONTROL PROBLEMS CONTINUED THROUGH
                                   SEPTEMBER.  ANOTHER PROBLEM AREA WAS THE PLUGGING OF
                                   THE LIME SLURRY FEED LINES.
                                   PROBLEMS WITH DAMPER SEAL AND GUIDEBARS WERE ENCOUNT-
                                   ERED.  THE UTILITY PLANS TO REPLACE THEM DURING THE
                                   NEXT  BOILER OUTAGE.
                                   LIME TRANSFER UAGHOUSE SHAKER PROBLEMS WERE EXPERIENCED
                                   DURING NOVEMBER.  ALSO DURING NOVEMBER THE THICKENER
                                   RAKE MOTOR BURNED OUT AND HAD TO BE REWOUND CAUSING
                                   DOWNTIME.

-------
EPA UTIUITV F60 SURVEYS OCTOBER 1978 - NOVEMBER 197fl
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
              OUOUESNE LIGHT

              ELRAMA POWER STATION

              ELRAMA PENNSYLVANIA

               510 Mw
    FUEL CHARACTERISTICS  COAL; 22 SULFUR, 16.SZ ASH
    FGD VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE

    EFFICIENCY!
     PARTICIPATES (ACTUAL)
                  (DESIGN)

     302          (ACTUAL)

                  (DESIGN)

    HATER MAKE UP

    SLUDGE DISPOSAL
              CHEMICO

              LIME

              RETROFIT

              10/75


                 99.0 PERCENT

                 99.0 PERCENT

                 75+ PERCENT

                 63.0 PERCENT

              OPEN LOOP

              STABILIZED/LANDFILL
    OPERATING EXPERIENCE UPDATE!
PERIOD


JAN. 76
   OPERATING HOURS
BOILER     SCRUBBER-ABSORBER VESSELS
            101  201  301  401  501
            700  673   36  161
26
DURING THE PERIOD A NEW WURMfcR RECYCLE PUMP IN-
STALLED IN NOVEMBER EXPERIENCED JACK SHAFT BEARING
PROBLEMS RESULTING IN THE REMOVAL UF TWAIN 501
FROM SERVICE.  BOILEK NO. « WAS CONNECTED ADDING
AN ADDITIONAL 176 Mw LUAO TU THE SYSTtM.  THt
IUCS SLUDGE DISPOSAL FACILITY IS NUW IN SEKVICh.
A LOW LOAD DEMAND AND THE COAL STKIKE HAVE
HAMPERED SCRUBBER OPERATIONS.  THEKE IS SOME
OUTAGE TIME SCHEDULED FOR MARCH.
FEB. 78
MAR. 78
            204  277    0  107  121   THE SYSTEM WAS SHUTDUWN UN FEB. 11 DUE TU A COAL
              00000   SHORTAGE.  THE FOLLOWING REPAIKS WERE MADt DURING
                                      THE OUTAGE WHICH CONTINUED THROUGH MARCH:
                                        *  BOILER EXIT DAMPERS WERE LINED WITH 316 SS UN
                                           AREAS OF HIGH EROSION CAUSED BY FLYASH IM-
                                           PINGEMENT.
                                        *  EXPANSION JOINTS IN THE UPSTREAM DUCTWORK
                                           WERE SHIELDED BY METAL PLATES WHICH WERE
                                           WELDED AT ONE END.
                                        *  EXPANSION JOINTS IN THE DOWNSTREAM DUCTWORK
                                           WERE COMPLETELY REPLACED.
                                        *  THE DOWNSTREAM DUCTWORK WAS RELINED WITH
                                           CEILCOTE.
                                        *  MODULE 401 INTERNALS WEKE CLEANED AND SUME
                                           HOLES IN THE UPPER CONICAL REGION WERE RE-
                                           PAIRED.
                                      BOILERS 1, Z AND 4 ARE NOW COMPLETELY CONNECTED
                                      TO THE FGD SYSTEM.  BOILER 3 13 UNDERGOING
                                      AN EXTENSIVE OVERHAUL AND WILL BE CONNECTED TO
                                      THE SYSTEM IN LATE APRIL.
                                                   32

-------
                                                  EPA UTILITY FGO SURVEY: UCTOdeR 197B - NOVEMBER 1478

DUOUESNE LIGHT                                                   ELRAMA POKEn STATION

                                     OPERATING HOURS
                     BOILER                         SCRUBBER-ABSORBER
MONTH      1234    AVG        101   201    501   401   501   AVG

APR. 78   699   526    0    672   475
MAY  78   723   723    0    740   547
       DURING THE APRIL-MAY PERIOD BOILER NUM8EK 3 WAS STILL BEING OVERHAULED.  HGC SYSTtM CUNSfKilC-
       TION WAS COMPLETED AND PRELIMINARY TESTING VERIFIED  SYSTEM S02  REMOVAL EFFICIENCY.

JUNE 78   691   616    0    662   492
JULY 78   691   640   588   729   662
       MODULE 301 WAS PULLED OFF FOR A  MAJOR  CLEANING OVER  THE  PERIOD.  MIST F.LIKIN.10K PLUGGING hAS
       EXPERIENCED AS A RESULT OF LOW PH.   THE CHRONIC INABILITY TO CONTROL CHtMiSTRf IPH) IS
       DIRECTLY RELATED TO GRIT BUILD-UP  IN  THE LIME HANDLING AND SLURRY  PREPARATI UNSYS IEM.   THE
       UTILITY IS CURRENTLY STUDYING WAYS TO  TIGHTEN THE WATER  BALANCE  BY USING THlCENER  SUPERNA-
       TANT INTERMITTENTLY WITH CLEAR SERVICE HATER FOR  THE MIST ELIMINATORS.   A  CUMLlANCt TEST
       SHOULD TAKE PLACE DURING THE NEXT  REPORT PERIOD.

AUG. 78   735   601   686   691   678
SEP. 78   676   585   674   720   664
       DURING AUGUST MODULES 301 AND 501  WERE TAKEN DOWN FOR CLEANING.   THt RUBBER  LMNG  UN  THREE
       FAN HOUSINGS WAS REPAIRED.   IT WAS ALSO NECESSARY TO SHUT DUWN  THE LIME  MIXINGJASTN tN n*i»-w
       TO CLEAN OUT EXCESSIVE GRIT  AND  SOLIDS BUILD UP.
                                                   33

-------
EPA UTILITY F60 SURVEY:  OCTOBER 1978 - NUVEMBER 1978
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING  ,
                     DUOUESNE LIGHT

                     PHILLIPS POWER STATION

                     SOUTH HEIGHT PENNSYLVANIA1

                      •410-MW.
    FUEL CHARACTERISTICS  COAL; SI SULFUR, 16.SX ASH
    FGD VENDOR

    PROCESS

    NEW OR-RETROFIT
         -  '   '  •'/ '
    START UP DATE

    EFFICIENCY:/   .
     PARTICULATES (ACTUAL)
                  (DESIGN)

     S02          (ACTUAL)

                  (DESIGN)

    WATER MAKE; UP

    SLUDGE DISPOSAL
                     CHEMICO

                     LIME

                     RETROFIT

                      7/73


                        99.0 PERCENT

                        99.0 PERCENT

                        75+ PERCENT

                        83.0 PERCENT

                     OPEN LOOP

                     STABILIZED/LANDFILL
    OPERATING EXPERIENCE UPDATE:
MONTH

JAN.
FEB.
           1
                           BOILER
                       3     4
                                        OPERATING HOURS
                                              AVG       101
                                                        SCRUBBER-ABSORBER
                                                         201   301   401
                                                                                AVG
78                                                 627   574     0   484   421
78                                                 209   287    18   1.52   167
  AN OUTAGE OCCURRED BETWEEN JAN. 6 AND JAN. 8 WHEN THE STACK DRAIN LEAKS w£«E REPAIRED BY
  SANDBLASTING THE OUTER WALL AND REPLACING THE CARBON STEEL BANDS WITH STAINLESS STEEL BANDS.
  THE SYSTEM WAS SHUTDOWN ON FEB. 11 DUE TO THE COAL SHORTAGE.  THE OUTAGE CONTINUED THROUGH
  MARCH AND THE SYSTEM IS SCHEDULED TO BE ON LINE BY APRIL 15.  DURING THE OUTAGE 1HE FOLLOWING
  REPAIRS AND MODIFICATIONS WERE MADE:
          • THE BOILER EXIT DAMPERS WERE LINED WITH 316SS ON AREAS OF HIGH EKOSIUN CAUSED MY
           FLYASH IMPINGEMENT.
          •EXPANSION JOINTS ON THE INLET DUCTWORK WERE SHIELDED BY METAL PLATES WHICH MERE
           MELDED AT ONE END.
          •NUMEROUS HOLES IN THE WET GAS DUCT WORK WERE REPAIRED AND THE DUCTS WERE RELINEU
           WITH CEILCOTE.
          •THE THROAT DAMPERS WERE CLEANED ON ALL THE SCRUBBERS.
          •INTERNAL MIST ELIMINATORS WERE CLEANED.  THE EXTERNAL MIST ELIMINAlORS, WHICH
           ARE BADLY DETERIORATED, MAY BE REPLACED.
          •THE STACK BRICKLINING WAS INSPECTED AND SOME BRICKS WERE REPLACED AT THE TUP UF THE
           STACK.
  CONSTRUCTION WORK ON ADDITIONAL EQUIPMENT SUCH AS THE THICKENER AND SILOS IS ALMOST COMPLETE.
  IT WAS NOTED THAT THE CEILCOTE LINER COROLINE SOSAR HAS HELD UP WELL OVER THREE YEAHS ON
  THE CONICAL APEX OF MODULE 401.
MAR.! 78
APR. 78
MAY  78
     358    0    562   623   524    0    345
     725   389   714   667   690    0    531
  THE FGO SYSTEM CAME BACK ON LINE AFTER THE COAL STRIKE IN LATE MARCH.  IT IS NOT OPERATING
  AT FULL LOAD BECAUSE THE NO. 6 BOILER IS STILL OUT AND SHOULD BE BACK ON LINE IN MID-JULY.
  COMPLIANCE TESTS WILL TAKE PLACE IN JULY, AFTER BOILER 6 IS BACK ON LINE, TO SEE IF THE
  SYSTEM IS MEETING THE 83X S02 REMOVAL REQUIREMENT FOR 2* SULFUR COAL.  THERE WEKE NO HOURS
  REPORTED FOR THIS PERIOD BECAUSE OF PRELIMINARY TESTING BEING CONDUCTED IN PREPARATION FUR
  THE COMPLIANCE TESTS.  SO FAR, TESTS INDICATE THAT THE SYSTEM WILL COMPLY WITH THE REOUIKED
  STANDARDS.  THE AVAILABILITY FOR ALL FOUR TRAINS WAS BETWEEN 65 AND 75 PERCENT.
                                                  34

-------
                                                  EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEKbEK 197B

OUOUESNE LIGHT                                                   PHILLIPS POWER STATION

                                        OPERATING HOURS
                           BOILER                            SCRUBBER-ABSORBER
MONTH      183456    AVG       101   201   301   401   AVG

JUNE 76   632   581   616   720   516    0    S12
JULY 78   476   425   566   544   566    0    434
       THE INTERNAL MIST ELIMINATOR ON MODULE 201 WAS REMOVED AND CLEANED OVER IHE PERIOD.  THE
       FGD SYSTEM HAS ACCUMULATED APPROXIMATELY 24,000 HOURS OF OPERATION UN ALL FOUK MODULES SINCE
       START-UP.  WATER BALANCE PROBLEMS HAVE CONTRIBUTED  TO THE OCCURRANCE OF LOW PH,
       RESULTING IN MIST ELIMINATOR PLUGGING.  THE MIST ELIMINATOR PLUGGING IS
       ALSO RELATED TO LOW PH RESULTING FROM LIME HANDLING AND SLURKY PREPARATION SYSTEM FAILURE.
       GRIT BUILD UP HAS BEEN THE MAJOR SOURCE OF THE REAGENT HANDLING SYSTEM FAILURES.  THE
       UTILITY IS CURRENTLY STUDYING WAYS TO TIGHTEN THE WATER BALANCE BY USING THICKENER SUPERNA-
       TANT INTERMITTENTLY WITH CLEAR SERVICE WATER FOR THE MIST ELIMINATORS.  THE COMPLIANCE
       TEST SHOULD TAKE PLACE DURING THE NEXT REPORT PERIOD.

AUG. 76   636   663   500   627   591   623   607
SEP. 78   608   599   593   546   146   447   490
       DURING THE AUGUST-SEPTEMBER PERIOD MIST ELIMINATOR  CLEANING TOOK  PLACE IN ORDER TO CORRECT
       THE PLUGGING PROBLEM.  IN AUGUST THE INTERNAL MIST  ELIMINATOR ON  MODULE 201 WAS REPLACED.
       THE LIME MIXING BASIN HAD TO BE SHUTDOWN OVER A WEEKEND SO THAT EXCESSIVE GNIT
       AND SOLID PARTICLES THAT HAD BUILT UP COULD BE CLEANED OUT.  HIGH PRESSURE WATER CLEANING WAS
       PERFORMED ON MODULES 101 AND 401 AND THE RUBBER LINING ON MODULE  1U1 WAS REPAIRED.  A MAJOK
       PROBLEM AREA DURING THE PERIOD WAS CAUSED BY  INSUFFICIENT SUPPLIES OF DRY FLYASH TO MIX
       WITH THE SLUDGE.  AS A RESULT THE SLUDGE HAS BEEN LEAKING OUT OF  THE TRANSPORT TRUCKS WHILE
       IN TRANSIT TO THE FINAL DISPOSAL SITE.  APPARENTLY  NOT ENOUGH FLYASH IS BEING COLLECTED WITH
       THE PRESENT SYSTEM.
                                                   35

-------
EPA UTILITY FGD SURVEY* OCTOBER 1978 - NOVEMBER 1978
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS

    UTILITY NAME          GULF POWER
    UNIT NAME             SCHOLZ 1 & 2
    UNIT LOCATION         CHATTAHOOCHEE FLORIDA
    UNIT RATING             23 MW
    FUEL CHARACTERISTICS  COAL; 2X SULFUR, 11X ASH
    FGD VENDOR            CHIYODA INTERNATIONAL
    PROCESS               LIMESTONE
    NEW OR RETROFIT       RETROFIT
    START UP DATE          8/78
    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)   99.5 PERCENT
     S02          (ACTUAL)
                  (DESIGN)   90 PERCENT
    WATER MAKE UP         CLOSED LOOP
    SLUDGE DISPOSAL       GYPSUM/STACKED, EXISTING POND

    OPERATING EXPERIENCE UPDATE:

AUGUST-SEPTEMBER 1978 - OPERATION OF THIS PROTOTYPE UNIT BEGAN ON AUGUST 30.  THIS SYSTEM UTILIZES
THE NEW JET BUBBLING REACTOR DESIGN AND IS CAPABLE OF SCRUBBING 50 PERCENT OF I HE FLUE GAS FRUM
EITHER BOILER 1 OR 2.  NO INITIAL OPERATIONAL PROBLEMS HAVE BEEN REPORTED AND SYSTEM AVAILABILITY
HAS BEEN GREATER THAN 99 PERCENT.
OCTOBER-NOVEMBER 1978 - HOURS OF OPERATION ARE STILL UNAVAILABLE FUR THIS NEWLY  OPERATIONAL
PROTOTYPE SYSTEM.  NO MAJOR OPERATIONAL PROBLEMS HAVE BEEN ENCOUNTERED AND SYSTEM AVAILABILITY
REMAINS AT GREATER THAN 99 PERCENT.  TYPICAL SULFUR DIOXIDE REMOVAL EFFICIENCY IS REPORTED 1U BE
APPROXIMATELY 93 PERCENT.  A 130 HOUR SCHEDULED OUTAGE OCCURRED IN OCTOBER.
                                                  36

-------
                                                   EPA  UTILITY  F6D  SUkVEY:  UCTUHtK  197H - IjUVt-ftiEK  1 4 7 »
                     SECTION  3
   PERFORMANCE DESCRIPTION  FOR  OPERATIONAL  FGO  SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
INDIANAPOLIS POWER * LIGHT

PETERSBURG 3

PETERSBURG INDIANA

 530 MW
    FUEL CHARACTERISTICS   COAL?  3.25X  SULFUR,  9.5Z  ASH
    FGD VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE

    EFFICIENCY:
     PARTICULATES  (ACTUAL)
                   (DESIGN)

     S02           (ACTUAL)

                   (DESIGN)

    WATER MAKE UP

    SLUDGE DISPOSAL
AIR CORRECTION DIVISION, UOP

THOROUGHBRED 121

NEW

10/77




   99.3 PERCENT



   80.0 PERCENT

CLOSED LOOP; 1.66 GPM/Mrt

STABILIZED/SLUDGE POND
    OPERATING EXPERIENCE  UPDATE:


DECEMBER-JANUARY  1978 - OPERATION  OF  ALL  FOUR  MODULES  /»AS  INITIATED  IN  DECtMbtK  1977.   A  SUCCESSFUL
24-HOUR RUN WA3 COMPLETED ON DEC.  16  AND  17  WITH  MODULES  "B",  "C"  ANO  "0"  IN  UPfcKATIUN.   •»" MJDULh
HAD AN INOPERATIVE RECYCLE  TANK AGITATOR.  REPAIR OF  THE  AGITATOR  WAS  CUMPLE1EU  ON  DhC. di.
AND MODULE A WAS  PLACED IN  INITIAL OPERATION.   A  30-DAY RUN  SCHEDULED  TO HtGIN JA«.  11  MAS  POST-
PONED UNTIL MID-MARCH PENDING RESOLUTION  OF  PROBLEMS  ASSOCIATED  WITH THE FLY  ASH rttMUVAL  SYSTEM.
THE COLO HEATHER  NECESSITATED THE  ERECTION OF  TEMPORARY ENCLOSURES AROUNU  SEGMENTS  OF  THt FGO SYSTEM
UNTIL THE INSTALLATION OF HEAT TRACING  COULD BE COMPLETED.

FEBRUARY-MARCH 1976 - THE MODULES  DID NOT OPERATE DURING FEBRUARY  AS REPAIRS  *ERE MADE  Tu LINtS Am)
VALVES DAMAGED BY FREEZE-UPS DURING THE WINTER.   DURING MARCH  SOME SCHEDULED  ktPAlKS
HERE MADE WHICH INCLUDED  INSTRUMENTATION  WORK,  INSULATION  INSTALLATION  AMD REPAIR UF A  URUHHu KlNlUN
SEAR ON THE THICKENER.  SYSTEM START-UP IS STILL  BEING DELAYED BY  PHUBLtMS *ITH  IHfc  FLY ASM HANDLINU
SYSTEM AND IS NOW EXPECTED  TO BE IN MID-APRIL.

APRIL-MAY 1978 -  THE UNIT CAME BACK ON  LINE  IN  THE  MIDDLE  OF APRIL AFTER PROBLEMS ftlTH  Trtf  FLYASH
HANDLING SYSTEM HERE CORRECTED.  THE  SYSTEM  OPERATED  UNTIL THE MAIN POWER  TRANSFORMER  FAULHU,
CAUSING THE SYSTEM TO GO  DOWN.  THE OUTAGE LASTED UNTIL JUNE 16.   PROBLEMS HAVE  ALSO BEEN EXPtKl-
ENCED WITH ALL CONTROL VALVES AND  PIPING.  THE  VALVES  HAD  TO BE  SENT BACK  Tu  THE FACTORY  FOR MODI-
FICATIONS.

JUNE-JULY 1978 -  THE UNIT IS STILL PROCEEDING  WITH  SHAKEDOWN AND DEBUGGING OPERATION AS FINAL DtSIUN
MODIFICATIONS ARE BEING MADE.  PREPARATIONS  ARE BEING  COMPLETED  FOR THE COMPLIANCE  TEST WHICH HAS
NOT YET TAKEN PLACE.

AUGUST-SEPTEMBER  1978 - SHAKEDOWN/DEBUGGING  OPERATIONS CONTINUE.   THE COMPLIANCE TEST  IS  NUrt SET HUR
THE LAST HEEK IN OCTOBER.   THE UNIT HAS EXPERIENCED PROBLEMS WITH  CONTROLS, FIBERGLASS  HIPING AMU
VALVES.

OCTOBER-NOVEMBER  1978 - THE 302 COMPLIANCE TEST HAS BEEN RESCHELDULEO FUR DECEMHER DUE  TO THE
INVALIDITY OF THE TEST PREVIOUSLY  RUN (BYPASS DAMPER PROBLEMS).  HOWEVER THE  PREVIOUS  TtSTINU DtU
SHOH THAT THE UNIT HAS IN PARTICULATE AND NOX COMPLIANCE.  THE CRACKED PIPING PROBLEM  HAS 8tEN
SOLVED BY REPLACING SECTIONS WITH  RUBBER LINED STEEL PIPING, NEW FRP PIPING,  ANO PROVIDING
ADDITIONAL PIPE SUPPORTS.   PROBLEMS REPORTED RECENTLY  WERE FREEZE-UPS IN THE  LIME DELIVERY SYSTEM
AND AN INSTRUMENTATION POWER TRANSFORMER FAILURE  THAT CAUSED ABOUT 6 DAYS UuTAGE.
                                                  37

-------
EPA UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGI) SYSTEMS


    UTILITY NAME          KANSAS CITY POWER & LIGHT

    UNIT NAME             HAWTHORN 3

    UNIT LOCATION         KANSAS CITY  MISSOURI

    UNIT RATING            100 MM

    FUEL CHARACTERISTICS  COAL; 2X SULFUR, 12.5X ASH

    FGO VENDOR            COMBUSTION ENGINEERING

    PROCESS               LIME

    NEW OR RETROFIT       RETROFIT

    START UP DATE         11/78

    EFFICIENCY:
     PARTICULATES (ACTUAL)   99.0 PERCENT

                  (DESIGN)   99.0 PERCENT

     so2          (ACTUAL)

                  (DESIGN)   70.0 PERCENT

    HATER MAKE UP         OPEN LOOP 7.0 GPM/MW

    SLUDGE DISPOSAL       UNSTABILIZED/SLUOGE PONO



    OPERATING EXPERIENCE UPDATE:


                                                                FGD SYSTEM
MONTH     PERIOD HRS.      BOILER HRS.      FGD SYSTEM HRS.   UTILIZATION (X)

FEB. 78       672              167             167                   25
MAR. 78       744              406             406                   56
       DURING FEBRUARY THE UNIT WAS DOWN FOUK TIMES WITH ECONOMIZER AND WATER WALL LEAKS (OUTAGE
       TIME APROX. 504 HRS).  A TWO WEEK OUTAGE WAS SCHEDULED DURING MARCH FOR SEASONAL MAINTENANCE.
       WATER WALL LEAK REPAIR AS WELL AS ACID CLEANING OF THE BOILEK CAUSED ADDITIONAL OUTAGE TIME
       DURING THE LAST WEEK IN MARCH.

APR. 78       720              548             220                   76
MAY  78       744              403             403                   42
       AN AIR PREHEATER FIRE DISCOVERED ON MAY 12 CAUSED DAMAGES THAT FORCED MUOULE A TO BE OUwN THE
       REST OF THE MONTH.

JUNE 78
JULY 78
       NO INFORMATION WAS AVAILABLE FOR THE JUNE-JULY REPORT PERIOD DUE 10 A PLANT STRIKE.

AUG. 78
SEP. 78
       THE SCRUBBING SYSTEM IS OPERATING ALTHOUGH THE UTILITY IS STILL IN IHE MIDST UF A STRIKE.
       FGD PERFORMANCE FIGURES ARE NOT AVAILABLE.  THE UTILITY IS NOT RECORDING FGD SYSTEM OPEKAIIuU
       HOURS DURING THE STRIKE.
                                                  38

-------
                                                  EPA UTILITY FGD SUKVEY: UCTUbEK 1978 - NUVEMUfcK 1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL F60 SYSTEMS


    UTILITY NAME          KANSAS CITY POWER & LIGHT

    UNIT NAME             HAWTHORN 4

    UNIT LOCATION         KANSAS CITY  MISSOURI

    UNIT RATING            100 MW

    FUEL CHARACTERISTICS  COAL; 2X SULFUR, 13.5* ASH

    F60 VENDOR            COMBUSTION ENGINEERING

    PROCESS               LIME

    NEW OR RETROFIT       RETROFIT

    START UP DATE          8/72

    EFFICIENCY:
     PARTICULATES  (ACTUAL)   99.0 PERCENT

                   (DESIGN)   99.0 PERCENT

     S02           (ACTUAL)

                   (DESIGN)   70.0 PERCENT

    WATER MAKE UP         OPEN LOOP 7.0 GPM/MW

    SLUDGE DISPOSAL       UNSTABILI ZED/SLUDGE PUNO



    OPERATING EXPERIENCE UPDATE:


                                                                               FGU SYSTtM
MONTH         PERIOD MRS.     BOILER HRS.          FGD SYSTEM MRS.             UTILIZATION  (X)

FEB. 76          b72            198                       19B                          3D
MAR. 78          7
-------
EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 1978
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
                     KANSAS CITY POnER * LIGHT

                     LA CYGNE 1

                     LA CYGNE KANSAS

                      820 MH
    FUEL CHARACTERISTICS  COAL; 5X SULFUR, 551 ASH

    FGD VENDOR            BABCOCK & WILCOX

    PROCESS               LIMESTONE

    NEW OR RETROFIT       NEW

    START UP DATE
    EFFICIENCY!
     PARTICULATES (ACTUAL)

                  (DESIGN)

     802          (ACTUAL)

                  (DESIGN)

    WATER MAKE UP

    SLUDGE DISPOSAL
                        98.2 PERCENT

                        98.0 PERCENT

                        80.1 PERCENT

                        76.0 PERCENT

                     OPEN LOOP 1.4 GPM/MW

                     UNSTABILIZED/SLUDGE POND
    OPERATING EXPERIENCE UPDATE:
MONTH

FEB. 76
MAR. 78
      BOILER HOURS

           578
           741
     PERCENT AVAILABILITY-BY MODULE
       B      C      0      E      F
92
95
                                    93
                                    95
95
90
94
95
91
94
97
95
96
89
93
93
                                                         AVERAGE
                  94
       FGD OPERATIONS AT LA CYGNE WERE CONDUCTED DURING THE REPORT PERIOD WITH NU MAJOR PROBLEMS
       ENCOUNTERED.
APR. 70
           620
91
                                    92
                                             91
                                                    90
                                   92
                                                                       91
                                                                              91
                                                                                         91
MAY
  THE BOILER WAS DOWN A TOTAL OF 100 HOURS IN APRIL.  THIS TIME INCLUDED IHKEE UUTAGtS DUE TU
  BOILER LEAKS AND LACK OF LOAD REQUIREMENT. MODIFICATIONS TO THE FGD SYSTEM wEKE PERFORMED
  DURING THE OUTAGES WHICH INCLUDED CHANGING THE REHEAT TUBE BUNDLES.

78         593          89     92     92     93     92     91     93     86         91
  IN MAY THE BOILER «AS DOWN TWICE FOR A TOTAL OF 151 HOURS.  OUTAGES WERE AGAIN CAUSED BY
  BOILER LEAKS.  GENERAL MAINTENANCE AND REPAIRS ON THE FGD SYSTEM WERE CONTINUED.
JUNE 78
JULY 76
            15
           341
       97
                                           92     94     88     93     93     95         93
       THE UNIT WAS ONLY UP FOR 15 HOURS IN JUNE.  IN THE FIRST PART OF JUNE THERE WERE BOILER TUttt
       LEAKS.  FROM JUNE 8 TO JUNE 17 A BOILER OUTAGE WAS NECESSARY FUR GENERATOR REPAIR.  THE UNIT
       OPERATED THROUGHOUT JULY.

AU6. 78         577          92     93     95     96     93     94     95     95         94
SEP. 78         720          96     96     96     96     96     96     95     97         96
       THERE WERE TWO BOILER OUTAGES (NON-FGO-RELATED) IN AUGUST.  THE FGD SYSTEM REUUIRED ONLY ROU-
       TINE MAINTENANCE.  THE UTILITY IS EXPERIMENTING WITH A 3-STAGE MIST ELIMINATOR AND SOME DOU-
       BLE STAGE MIST ELIMINATORS.  BETTER MIST ELIMINATION AT THE SCRUBBER EXIT WUULD REDUCE THE
       FREQUENCY OF REHEATER CLEANING.  DURING THE JULY-SEPTEMBER PERIOD TwO I.D. FAN ROTORS WERE
       REPLACED.
OCT. 76
NOV. 76
           255
           720
96
92
                                    96
                                    95
98
94
97
93
97
94
98
93
97
94
96
96
       THE UTILITY REPORTED THAT NO UNUSUAL OPERATING PROBLEMS WERE ENCOUNTERED.
97
94
                                                  40

-------
                                                  EPA UTILITY FGD SURVEY: UC1UBEH 19/8 - MJVKMHtrf
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL F60 SYSTEMS
    UTILITY NAME          KANSAS POWER * LIGHT
    UNIT NAME             JEFFREY 1
    UNIT LOCATION         ST MARYS KANSAS
    UNIT RATING            680 MW
    FUEL CHARACTERISTICS  COAL; 0.3X SULFUR, 7.5Z ASH
    FGO VENDOR            COMBUSTION ENGINEERING
    PROCESS               LIMESTONE
    NEW OR RETROFIT       NEW
    START UP DATE          8/78
    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)   99.0 PERCENT
     302          (ACTUAL)
                  (DESIGN)   60.0 PERCENT
    HATER MAKE UP         CLOSED LOOP .59 GPM/MW
    SLUDGE DISPOSAL       UNSTAB1LIZED/SLUOGE POND

    OPERATING EXPERIENCE UPDATE:
AUGUST-SEPTEMBER 1978 - THE SYSTEM IS PRESENTLY IN THE SHAKEDOWN PHASE OF OPERATION.  EACH UF THE
SIX MODULES OPERATED DURING THIS PERIOD NO MAJOR PROBLEMS WERE REPORTED.  INTEGRATED OPERATION OF
THE SYSTEM IS EXPECTED TO BEGIN DURING THE FIRST HALF OF OCTOBER.
OCTOBER-NOVEMBER 1978 » INTEGRATED OPERATION FOR THIS UNIT STILL HAS NOT BEEN ACHIEVED.  A
CERTIFICATION TEST WHICH HAD BEEN SCHEDULED HAD TO BE CANCELLED DUE TO A BOILER OUTAGE.  HOWEVER
NOW THE COLO WEATHER HAS FORCED POSTPONEMENT OF THE TEST INDEFINITELY.  MEANWHILE INTERMITTENT FGU
OPERATIONS CONTINUE.
                                                  41

-------
EPA UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 1978

                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
    UTILITY NAME          KANSAS POWER R LIGHT
    UNIT NAME             LAWRENCE 0
    UNIT LOCATION         LAWRENCE KANSAS
    UNIT RATING            125 MW
    FUEL CHARACTERISTICS  COAL; 0.51 SULFUR, 10X ASH
    FGO VENDOR            COMBUSTION ENGINEERING
    PROCESS               LIMESTONE
    NEW OR RETROFIT       RETROFIT
    START UP DATE         12/68
    EFFICIENCY:
     PARTICULARS (ACTUAL)   99* PERCENT
                  (DESIGN)   98.9 PERCENT
     302          (ACTUAL)   90+ PERCENT
                  (DESIGN)   73.0 PERCENT
    MATER HAKE UP         OPEN LOOP
    SLUDGE DISPOSAL       UNSTABILIZED/SLUDGE POND

    OPERATING EXPERIENCE UPDATE:

FEB. 78   THE FGD SYSTEM OPERATED DURING THE REPORT PERIOD WITH NO MAJOR PROBLEMS.  THE THICKENER
MAR. 78   UNDERFLOW LINE IS STILL FROZEN AND TWO 3 INCH DIAMETER FIRE HOSES ARE BEING USED TO PUMP
          THE UNDERFLOW SOLIDS TU THE POND.
APR. 70   THE UTILITY REPORTED THAT THE FGO SYSTEM AND THE BOILER RAN WITHOUT ANY OUTAGES DURING
MAY 78    THIS PERIOD.
JUNE 78   THE BOILER AND FGO SYSTEM BOTH OPERATED THROUGHOUT THE PERIOD.  THE UTILITY
JULY 78   REPORTED THAT THE OPERATING HOURS EQUALED THE HOURS IN THE PERIOD.
AUG. 78   HOURS OF OPERATION WERE NOT AVAILABLE BUT THE UTILITY REPORTED THAT THE SYSTEM RAN WITH NO
SEP. 78   FORCED OUTAGES DURING THE PERIOD.  THE UNIT WAS DOWN THE LAST WEEK AND A HALF IN SEPTEMBER
          FOR A SCHEDULED FALL TURBINE/BOILER OUTAGE.  ROUTINE MAINTENANCE INCLUDED BOILER AND
          TURBINE CLEANING AND REPAIR.
OCT. 78   THE SYSTEM RAN CONTINUOUSLY THROUGHOUT THE PERIOD WITH THE EXCEPTION OF A UNE WEEK OUTAGE
NOV. 78   FOR A BOILER-TURBINE INSPECTION.  AN EPA SPONSORED CONTINUOUS MONITORING TEST BEGAN AT
          THIS UNIT AT THE BEGINNING OF DECEMBER AND WILL CONTINUE THROUGH THE END OF JANUARY.
          THE TEST INVOLVES 24 HOUR MONITORING OF S02, OPACITY AND NOX.

-------
                                                  EPA UTILITY FGD SURVEY: UCTUbEK 197tt - NOVEPBfcK 19/e


                     SECTION 3
   PERFOHMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS


    UTILITY NAME          KANSAS POWER & LIGHT

    UNIT NAME             LAWRENCE 5

    UNIT LOCATION         LAWRENCE KANSAS

    UNIT RATING            400 MW

    FUEL CHARACTERISTICS  COAL; 0.5X SULFUR,  10X ASH

    FGO VENDOR            COMBUSTION ENGINEERING

    PROCESS               LIMESTONE

    NEW OR RETROFIT       NEW

    START UP DATE         11/71

    EFFICIENCY:
     PARTICULATES  (ACTUAL)

                   (DESIGN)   96.9 PERCENT

     302           (ACTUAL)

                   (DESIGN)   52.0 PERCENT

    WATER MAKE UP         OPEN LOOP

    SLUDGE DISPOSAL       UNSTABILIZED/SLUDGE POND



    OPERATING EXPERIENCE UPDATE:


FEB. 78   THE ORIGINAL FGD SYSTEM WAS PULLED  OFF LINE ON MARCH 20 SO THAT THE NEW SCKUBBtR-ABSOKBER
MAR. 78   SYSTEM COULD BE TIED INTO THE GAS PATH.  THIS NEW SYSTEM CONSISTS OF TWO MODULES EACH WITH
          A ROD SECTION FOR PARTICULATE REMOVAL AND A SPRAY TOWER FOh S02 REMOVAL. THE CAPACITY IS
          210 MW EACH.  INITIAL OPERATION SHOULD BEGIN BY THE FIRST OF MAY.

APR. 78   THE NEW UNIT WENT IN SERVICE ON APRIL 11 AND HAS OPERATED MTH NU OUTAGES SINCE START-UP.
MAY  78

JUNE 78   THE BOILER OPERATED ALL BUT TWO DAYS OF THE JUNE-JULY PERIOD.  THE 1*0 DAYS OF OUTAGE
JULY 76   TIME IN JUNE WERE DUE TO A BOILER DRAIN LINE LEAK.  THE FGD SYSTEM OPEHATED THE ENTIRE
          TIME THE BOILER WAS ON-LINE,  NO PROBLEMS WERE REPORTED.

AUG. 78   THE SYSTEM RAN WITH NO FORCED OUTAGES DURING THE AUGUST-SEPTEMBEK PEK10D.  THE UNIT WAS
SEP. 78   TAKEN DOWN AT THE END OF SEPTEMBER  FOR A SCHEDULED TWO WEEK TURBINE/bUILtR OUTAGE.  KOU-
          TINE MAINTENANCE IS BEING PERFORMED ON THE BOILER AND TURBINE.

OCT. 78   THE SYSTEM RAN THROUGHOUT THE ENTIRE PERIOD WITH ONLY ONE OUTAGE.  THE OUTAGE "AS WEUU1HEO
NOV. 78   FOR AN ANNUAL BOILER-TURBINE INSPECTION AND LASTED FOR ONE WEEK IN OCTOBER.

-------
EP* UTILITY FGO SURVEY: OCTOBEH 1978 - NOVEMBER 1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS


    UTILITY NAME          KENTUCKY UTILITIES

    UNIT NAME             GREEN RIVER 1,2 « 3

    UNIT LOCATION         CENTRAL CITY KENTUCKY

    UNIT RATING             64 MM

    FUEL CHARACTERISTICS  COAL; 3.7X SULFUR, 11.OX ASH

    FGD VENDOR            AMERICAN AIR FILTER

    PROCESS               LIME

    NEW OR RETROFIT       RETROFIT

    START UP DATE          9/75

    EFFICIENCY:
     PARTICULATES (ACTUAL)   99.7 PERCENT

                  (DESIGN)   99.7 PERCENT

     SOS          (ACTUAL)   80-90 PERCENT

                  (DESIGN)   80.0 PERCENT

    WATER MAKE UP         CLOSED LOOP 1.20 GPM/Mh

    SLUDGE DISPOSAL       UNSTABILIZED/SLUDGE POND



    OPERATING EXPERIENCE UPDATE:

            TOTAL          BOILER            MODULE           MODULE CALLED    HK. MODULE
PERIOD  PERIOD (HR)   OPERATION (HR)    AVAILABILITY (HR)    TO OPERATE (HK)    OPERATED

JAN. 78     744             537                722                  537            170
AVAILABILITY = 23X
RELIABILITY = 32X
OPERABILITY = 32X
UTILIZATION = 23X
       DURING THE MONTHS OF DECEMBER AND JANUARY NUMEROUS FREEZE-UPS OCCUHED.  AS ONE COMPONEfU
       HAS THAWED ANOTHER MOULD FREEZE.  THE ABSORBER WAS AVAILABLE FOR FGD OPERATIONS BUT CUULU NOT
       BE UTILIZED BECAUSE THE SLURRY LINE TO THE POND FROZE.  THE UNIT WENT DUWN AFIEK ABUIJI 170
       HOURS OF OPERATION IN JANUARY.  BECAUSE OF EMERGENCY CONDITIONS THE UTILITY CHOSE TO CONCEN-
       TRATE THEIR MAINTENANCE CREWS ON POWER GENERATION RATHER THAN FGD OPERATION.  UNDER NOR-
       MAL CONDITIONS THE RELATIVELY MINOR FGD SYSTEM PROBLEMS WOULD HAVE BEEN SOLVED MOKE UUICKLY.
       IN LIGHT OF THIS THE SYSTEM COULD HAVE BEEN CONSIDERED AVAILABLE THKOUGHUUT MOST OF THE
       PERIOD CONCERNED.

FEB. 78     672             672                672                   0              0
AVAILABILITY z 100X
RELIABILITY = UNDEFINED
OPERABILITY = OX
UTILIZATION = OX
       DURING THE FREEZE UP NUMEROUS GASKETS WERE TORN THROUGHOUT THE SYSTEM.  THE SYSTEM WAS SHUT
       DOWN COMPLETELY FOR REPAIR WORK.

MAR. 76     744             669                744                   0              0
AVAILABILITY = 100X
RELIABILITY = UNDEFINED
OPERABILITY = OX
UTILIZATION » OX
       REPAIR WORK HILL CONTINUE UNTIL LATE APRIL 78 WHEN THE SCRUBBER-AttSUKBtK SYSTbK IS EXPECTED
       BACK ON LINE.

APR. 78     720             295                296                  295            296
AVAILABILITY = 41X
RELIABILITY s 99X
OPERABILITV s 99X
UTILIZATION = 41X
                                                   44

-------
                                                  EPA UTILITY hGU SURVEY: UCTUbtK 19/a - NOVbfbtK 19/H

KENTUCKY UTILITIES                                               GKEEN KIVbK l,<> t. 3

            TOTAL          BOILER            MODULE           MODULE CALLED    HK. MODULE
PERIOD  PERIOD (HR)   OPERATION (HO)    AVAILABILITY  (HK)    TO OPERATE  (HK)    UPb*ATtO

MAY  78     744             HIU                474                  tli            UJ a
AVAILABILITY = 64X
RELIABILITY = 100X
OPERABILITY = 100X
UTILIZATION = 64X
       THE SCREENS ON THE SUCTION SIDE OF THE PUMPS THAT PUMP THE SLURRY FKOM THE PKEP «UOM TO 1 Hfc
       NOZZLES EXPERIENCED PLUGGING PROBLEMS.  THE SCREENS GET PLUGGED rtlTH LAKlib GKIT IN THE SLUKKr
       AND ARE SUCKED OUT OF POSITION BY THE PUMPS.   THE UTILITY REPORTED THAT THIS TENDS IU Ht 4
       RE-OCCURRING PROBLEM.

JUNE 78     730             525                524                  b2t            iia
AVAILABILITY = 73%
RELIABILITY a 100X
OPERABILITY = 100X
UTILIZATION = 73X
       BOILER AND FGO SYSTEM OUTAGES DURING JUNE WERE FOR ROUTINE MA INTEilANCb.

JULY 78     744             103                 99                   99             44
AVAILABILITY = 13X
RELIABILITY = 100X
OPERABILITY = 96X
UTILIZATION s 13X
       BOILER AND FGD SYSTEM OUTAGES DURING JULY WERE FOR ROUTINE MAINTENANCE.

AUG. 78     744             207                454                  207            <>Ub
AVAILABILITY = 61X
RELIABILITY = 99X
OPERABILITY = 99X
UTILIZATION = 28X
       THE UNIT WAS DOWN FROM AUGUST 1 UNTIL AUGUST 12 AS A  RESULT UF BLEED PUMP PxObLEM3.  ROUTINE
       MAINTENANCE ALSO CONTINUED THROUGH THE MIDDLE  UF  THE  MONTH.

SEP. 78     720             303                546                  298   '        £9A
AVAILABILITY = 76X
RELIABILITY = 100X
OPERABILITY = 98X
UTILIZATION = 41X
       BECAUSE OF PLUGGING PROBLEMS THE FGD SYSTEM WAS OPERATED AT APPROXIMATELY ONE  THIKU UF TOTAL
       CAPACITY THROUGHOUT SEPTEMBER.

OCT. 78     744             236                222                  232            2
-------
EPA UTILITY F60 SURVEY: OCTOBER  1978 - NOVEMBER  1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS


    UTILITY NAME          LOUISVILLE GAS & ELECTRIC

    UNIT NAME             CANE RUN a

    UNIT LOCATION         LOUISVILLE KENTUCKY

    UNIT RATING            178 MW

    FUEL CHARACTERISTICS  COAL;  3.751 SULFUR, 15.5X ASH

    FGD VENDOR            AMERICAN AIR FILTER

    PROCESS               LIMb (CARBIDE)

    NEW OR RETROFIT       RETROFIT

    START UP DATE          8/76

    EFFICIENCY:
     PARTICULATES (ACTUAL)   99.0 PERCENT

                  (DESIGN)   99.0 PERCENT

     302          (ACTUAL)   86-89 PERCENT

                  (DESIGN)   85.0 PERCENT

    HATER MAKE UP         OPEN LOOP .56 GPM/MW

    SLUDGE DISPOSAL       STABILIZED/SLUDGE POND



    OPERATING EXPERIENCE UPDATE:


                                               PERFORMANCE FACTORS (X)
PERIOD   HOURS   BOILER (HR)   FGO SYSTEM (HR)   OPEHABILITY   UTILIZATION

FEB. 78   672         0           0                N/A            0
MAR. 78   744                    349                              34
       THE UNIT WAS DOWN THE ENTIRE MONTH OF FEBRUARY DUE TO THE COAL SHORTAGE ANO A LACK OF AVAIL-
       ABLE LIME RESULTING FROM  THE SEVERE WINTER WEATHER.  THE UNIT CAME BACK ON LINE MARCH 21
       AFTER WHICH TIME THE FGD  SYSTEM WAS ON LINE DURING 95X OF THE BOILER HOURS THROUGH THE END OF
       MARCH.

APR. 78   720        303         303               100            47
       DURING APRIL THE BOILER WAS DOWN FOR REPAIRS.  THE UTILITY REPORTED THAT THE AVAILABILITY
       ANO RELIABILITY WERE BOTH 100X.

MAY  78   744        352         115                35            13
       THE BOILER WAS DOWN AGAIN IN MAY FOR REPAIRS.  DURING THE BOILER OUTAGE A NUMtfER OF MODIFICA-
       TIONS WERE MADE TO THE DAMPERS IN THE FGD SYSTEM.  THE UTILITY REPORTED THAT THE FGD SYSTEM
       HAS BEEN RUNNING WELL SINCE THE MODIFICATIONS TOOK PLACE.  THE AVAILABILITY ANO RELIABILITY
       FOR MAY WERE 31 AND 35 PERCENT RESPECTIVELY.

JUNE 78   720        720         715                99            99
JULY 78   744        687         678                99            91
       NO FGD SYSTEM RELATED OUTAGES WERE REPORTED BY THE UTILITY FOR THE JUNE-JULY PERIOD.

AUG. 78   744        744         701                94            94
SEP. 78   720        138         138               100            19
       THERE WERE NO FGD FORCED  OUTAGES DURING THE AUGUST-SEPTEMBER REPORT PERIOD.  THE BOILER WAS
       DOWN DURING SEPTEMBER FOR TUBE REPAIRS.

OCT. 78   744        0             0               N/A             0
NOV. 78   720        432         420                97            58
       THE UNIT REMAINED OUT OF  SERVICE THROUGHOUT OCTOBER FOR BOILER TUBE REPAIRS.  RESUMPTION OF
         OPERATIONS COMMENCED DURING THE SECOND WEEK OF NOVEMBER.  NO PROBLEMS WERE REPORTED SINCE
       STARUP.
                                                   46

-------
                                                  EPA UTILITY FGD SUKVEr: OCTOHEK 19/B - NUVEKbfcK 197H
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTtMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
LOUISVILLE GAS & ELECTRIC

CANE RUN 5

LOUISVILLE KENTUCKY

 103 MW
    FUEL CHARACTERISTICS  COAL? 3.751 SULFUR,  15.5X ASH
    FGO VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE

    EFFICIENCY:
     PARTICULATES  (ACTUAL)
                   (DESIGN)

     302           (ACTUAL)

                   (DESIGN)

    WATER MAKE UP

    SLUDGE DISPOSAL
COMBUSTION ENGINEERING

LIME (CARBIDE)

RETROFIT

12/77




   99.0 PERCENT



   85.0 PERCENT

OPEN LOOP

STABILIZED/SLUDGE POND
    OPERATING EXPERIENCE UPDATE:


DECEMBER-JANUARY 1970 - OPERATION OF THE FGD SYSTEM AT CANE RUN 5 BEGAN ON DECEMbER 29.  INITIAL
OPERATIONS WERE NOT CONTINUOUS.  DURING OPERATION SOME OF THE CONTROLS WERE NOT WORKING PROPERLY
AND MODIFICATIONS WERE NECESSARY.

FEBRUARY-MARCH 1976 - THE PLANT REMAINED OFF LINE THROUGHOUT FEBRUARY AND THEN KE-STAHTEU UN CAWC
24.  THE BOILER OPERATED APPROXIMATELY 182 HOURS THROUGH THE END OF ^ARCH WITH THE F&D SYSTh'l"
OPERATING APPROXIMATELY 91 HOURS.  VARIOUS INITIAL START-UP PROBLEMS WERE STILL BEING ENCUUNUREO
CAUSING FGD SYSTEM OUTAGES.
PERIOD   HOURS   BOILER  (HR)  FGD SYSTEM  (HR)
                       PERFORMANCE FACTORS (X)
                      OPERABILITY   UTILIZATION
APR. 76   720       669            648              97            90
MAY  78   744       432            364              84            49
       FGD SYSTEM MODIFICATIONS WERE MADE DURING THIS PERIOD  IN PREPARATION FOK PERFORMANCE TESTS.
       TESTING TOOK PLACE BUT EPA TEST METHODS WERE NOT FOLLOWED ACCURATELY ANU THE PROCESS OF DATA
       ACQUISITION WAS HANDLED POORLY BY DATA CREWS.  THE UTILITY WAS CONFIDENT THAT HAD THE CHEWS
       TAKEN THE DATA PROPERLY THE UNIT WOULD HAVE PASSED THE TESTS.

JUNE 78   720       685            590              86            82
JULY 78   744       632            506              60            68
       THE SYSTEM EXPERIENCED REHEATER PROBLEMS OVER THE PERIOD.  THE REHEAT COIL (STEAM) INSTALLA-
       TION HAS BEEN A CHRONIC PROBLEM AREA.  THE BANK OF TUBES AROUND THE DUCT HAS WELDS AT EACH
       END, WHERE THE COR FORMS A "U". THESE WELDS HAVE BEEN FAILING EVER SINCE INITIAL OPERATIONS.
AUG. 78   744       540            464              86            62
SEP. 78   720       609            485              80            67
       PROBLEMS CONTINUED THROUGH AUGUST AND SEPTEMBER WITH THE REHEAT COIL nELDS.
       AFFECTED ONLY SCRUBBER MODULE "A".
                                                          THIS  PROBLEM
OCT. 78   720        530         510                96            71
NOV. 78   744        253         237                94            33
          REDUCED SERVICE TIME FOR THE FGD SYSTEM OCCURRED BECAUSE OF SYSTEM SHUTDOWN FOR REPAIRS
          TO THE STEAM REHEATER COILS.  THE OUTAGE LASTED APPROXIMATELY TWO WEEKS.
                                                  47

-------
EPA UTILITY F60 SURVEY: OCTOBER 1978 - NOVEMBER 197B


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTtMS


    UTILITY NAME          LOUISVILLE GAS & ELECTRIC

    UNIT NAME             MILL CREEK 3

    UNIT LOCATION         LOUISVILLE KENTUCKY

    UNIT RATING            425 MW

    FUEL CHARACTERISTICS  COAL; 3.751 SULFUR, 15.5X ASH

    FGD VENDOR            AMERICAN Alk FILTER

    PROCESS               LIME (CARBIDE)

    NEW OR RETROFIT       NEW

    START UP DATE          8/78

    EFFICIENCY:
     PARTICULATES (ACTUAL)

                  (DESIGN)   99 PERCENT

     S02          (ACTUAL)

                  (DESIGN)   85 PERCENT

    WATER MAKE UP         OPEN LOOP .35 GPM/MW

    SLUDGE DISPOSAL       STABILIZED/SLUDGE POND



    OPERATING EXPERIENCE UPDATE:


AUGUST 1978 - INITIAL OPERATIONS BEGAN AT THIS UNIT ON AUGUST 13.  UUt TU I Ht RECENT OPERATING
       STATUS OF THE SYSTEM HOURS OF OPERATION WERE NUT AVAILABLE FOK AUGUST.

                                                 PERFORMANCE FACTORS (X)
PERIOD   HOURS   BOILER (HR)   FGD SYSTEM (HR)   OPERABILITY   UTILIZATION

SEP. 76   720       714            576              81            80
       DURING THE MONTH PROBLEMS WERE ENCOUNTERED WITH FRP PIPING AND SOMfc OF 1Hb PUKPS.
       THE PUMP PROBLEMS WERE RELATED TO BEARING AND SHAFT FAILURES.

OCT. 78   744       710            607              84            ttl
NOV. 78   720       351            299              85            42
       THE UNIT WAS SHUT DOWN ON NOVEMBER 18 FOR A SCHEDULED INSPECTION UF TURhlNEr BOILER AND
       THE FGD SYSTEM.  THE UNIT IS NOT EXPECTED TO BE BACK ON LINE UNTILL FEBKUAKY 1, 1S79.
                                                  48

-------
                                                  EPA UTILITY FGU SUHVtY: OCTubtK IS/6   NoVtcnhK 14/a


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO bYSTEMS


    UTILITY NAME          LOUISVILLE GAS & ELECTKIC

    UNIT NAME             PADDYS RUN 6

    UNIT LOCATION         LOUISVILLE KENTUCKY

    UNIT RATING             65 MM

    FUEL CHARACTERISTICS  COAL; 3.75X SULFUR, 15.5X ASH

    FGD VENDOR            COMBUSTION ENGINEERING

    PROCESS               LIME (CARBIDE)

    NEW OR RETROFIT       RETROFIT

    START UP DATE          «/73

    EFFICIENCY:
     PARTICULATES  (ACTUAL)   99.0 PERCENT

                   (DESIGN)   99.0 PERCENT

     303           (ACTUAL)   80-99 PERCENT

                   (DESIGN)   ao.0 PERCENT

    MATER MAKE UP         OPEN LOOP 0.7 GPM/MW

    SLUDGE DISPOSAL       STABILIZED/LANDFILL



    OPERATING EXPERIENCE UPDATE:


SEPTEMBER 1977-MARCH 1978 - PADDY'S RUN DID NOT OPERATE DURING THIS PEKIUO DUt TO A LACK UF
REQUIREMENT.  THIS IS A PEAK LOAD UNIT THAT IS TO BE HEUREU SOON AFTEH  THE MILL CKttK 3 UNIT
BECOMES FULLY OPERATIONAL.

APRIL-MAY 1978 - PADDY'S RUN MAS ONLY ON LINE A FEW HOURS DUHING THIS PERIOD.  .JU UP£HAT10NAL
PROBLEMS WERE REPORTED BY THE UTILITY.

JUNE-JULY 1978 - THIS UNIT RAN INTERMITTENTLY FOR AHOUT EIGHI TU UN DAYS OVEK THE JUNt-JULT

AUGUST-SEPTEMBER 1978 - THIS UNIT WAS OPERATED FOR TWO WEEKS IN SEPTEMBER 50 THAT TESTInb UF A ne
FLOCCULANT COULD BE CARRIED OUT.  THE RESULTS OF THE TESTS WILL DETERMINE THt IrPE uF FLUCCULANT
THAT MILL BE USED  IN THE FUTURE AT THE OTHER LG&E UNITS.

OCTOBER-NOVEMBER 1978 - THE BOILER WAS NOT OPERATED DURING OCTOBER OK NOVEMRtK.
                                                  49

-------
EPA UTILITY FGO SURVEY: OCTOBER  !<»/« - NOVEMBER  1978
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL F&O SYSTEMS
    UTILITY NAME

    ONIT NAME

    UNIT LOCATION

    UNIT RATING
                        MINNKOIA POWER COOPERATIVE

                        MILTON R. YOUNG 2

                        CENTER NORTH DAKOTA

                         Q50 Mw
    FUEL CHARACTERISTICS  LIGNITE; 0.7X SOLFOR, «.OX ASH
    FGU VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE

    EFFICIENCY:
     PARTICULATES (ACTUAL)

                  (DESIGN)

     S02          (ACTUAL)

                  (DESIGN)

    HATER MAKE UP

    SLUDGE DISPOSAL
                        ADL/COMBUSTIUN EOUIP ASSOCIATE

                        LIME/ALKALINE FLYASH

                        NEW

                         9/77




                           99.6 PERCENT



                           75.0 PERCENT

                        OPEN LOOP 1.56 GPM/MW

                        UNSTABILIZtD/LANOF ILL
    OPERATING EXPERIENCE UPDATE:
FEBRUARY-MARCH 1978 - BOTH THE 8UILEKS AND FGO SYSTEM CAME HACK ON LINE FEB. 21 AFTER COMPLETION
OF THE TURBINE REPAIRS.  ONE FORCEO-DKAFT FAN (UPSTREAM OF FGO SYSTEM) HAD AN U1L LEAK AND A SHAFT
ALIGNMENT PROBLEM.  IT WAS TAKEN OFF THE LINE AND SHIPPED TO BUFFALO FORGE FUR REPAIRS.  THE
AFFECTED MODULE WAS DOWN FROM FEB. 23 THROUGH APRIL 10. WHEN THE REPAIRED UNIT WAS RE-INSTALLEU.
THE VACUUM FILTER ALSO MALFUNCTIONED. ALLOWING LARGER SIZE
PARTICLES TO ESCAPE THE FILTER.  THIS CAUSED THE RUBBER LINING DOWNSTREAM TO PEEL WHICH, IN
TURN,  CREATED A PLUGGING PROBLEM.  EIMCO ENGINEERS ARE PRESENTLY STUDYING THE PROBLEM
AND HOPE TO INCORPORATE MODIFICATIONS TO IMPROVE THE PERFORMANCE OF THE FILIERS.  THE COMPLIANCE
TEST HAS AGAIN BEEN RESCHEDULED WITH EPA FUR THE END OF MAY.

APRIL-MAY 1978 - COMPLIANCE TESTING TOOK PLACE DURING THE WEEK OF JUNE 5.  THE REPORT SHU1ILD BE
AVAILABLE TO THE UTILITY BY THE END OF JUNE.  THE UNIT WAS DOWN WITH DAMPER PROBLEMS  (OUWN
ON THE 24TH OF JUNE).  APPARENTLY THE CHAINS THAT PULL THE GUILLOTINE DAMPERS WERE UNDERDfcSIGNED  AND
HAVE BEEN REPLACED.

JUNE-JULY 1976 - NO INFORMATION *AS REPORTED BY THE UTILITY FOR THIS REPORT PERIOD.

AUGUST-SEPTEMBER 1978 - OFFICIAL RESULTS OF THE COMPLIANCE TEST PERFORMED UN JUNE 6 ARE STILL  NOT
AVAILABLE.  VARIOUS PROBLEMS WERE ENCOUNTERED WITH THIS SYSTEM DURING THE PERIOD.  THE THICKENER  HAS
BEEN A MAJOR PROBLEM AREA.  THE POLYETHYLENE LINER WAS ACCIOENTLY PIERCED DURING REPAIRS AND HAD  TU
BE PATCHED.  BECAUSE OF INTERMITTENT OPERATION, HOURS ARE NOT YET AVAILABLE.

OCTOBER-NOVEMBER 1978 - THE UTILITY REPORTED THAT OPERATION OF THE BOILER AND FGD SYSTEM CONTINUED
ON AN INTERMITTENT BASIS THROUGHOUT THE PERIOD.  THICKENER LINING PROBLEMS WERE ENCOUNTERED AND
EROSION IN THE SPRAY TOWERS WAS SEVERE ENOUGH TO CAUSE HOLES IN THE TOWERS.  ALSO F.D. FAN PROBLEMS
HAVE BEEN A MAJOR CONCERN.
THE UTILITY HAS REPORTED OPERATIONAL PARAMETERS FOR THE ENTIRE YEAR OF 1978.  THE REPORTED
PARAMETERS AREJ  BOILER HOURS = 6926  MW-H = 2,626,201
                         A-MODULE  B-MODULE
                           1790      2110         TOTAL SYSTEM AVAILABILITY = 46X
                           1940      2500         TOTAL SYSTEM OPERA8ILITY = 53X
                           4965      4426         TOTAL SYSTEM RELIABILITY = 54*
                           1634      1634         TOTAL SYSTEM UTILIZATION = 42X
FGO SYSTEM:
  OPERATION (HR)
  AVAILABLE (HR)
  FORCED OUTAGE (HR)
  SCHEDULED OUTAGE  (HR)
                                                   50

-------
                                                  EPA UTILITY FGU SURVtY: UCTUBEK 1S7B    NUVfcCHtk
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTtMS

    UTILITY NAME          MONTANA POWER
    UNIT NAME             COLSTRIP 1
    UNIT LOCATION         COLSTRIP MONTANA
    UNIT RATING            360 Mw
    FUEL CHARACTERISTICS  COAL; 0.8X SULFUK, 121 ASH
    FGO VENDOR            ADL/COMBUST1 ON EQUIP ASSOCIATE
    PROCESS               LIME/ALKALINE FLYASH
    NEW OR RETROFIT       NEW
    START UP DATE         11/75
    EFFICIENCY:
     PARTICULATES (ACTUAL)   99.5 PERCENT
                  (DESIGN)   99.5 PERCENT
     303          (ACTUAL)   75.0 PERCENT
                  (DESIGN)   60.0 PERCENT
    WATER MAKE UP         CLOSED LOOP
    SLUDGE DISPOSAL       STABILIZED/SLUDGE POND

    OPERATING EXPERIENCE UPDATE:

JAN. 78     TOTAL SYSTEM AVAILABILITY   96X
FEB. 78     TOTAL SYSTEM AVAILABILITY - 100X
MAR. 78     TOTAL SYSTEM AVALIABILITY - 92X
APR. 78     TOTAL SYSTEM AVAILABILITY = 100X
MAY  78     TOTAL SYSTEM AVAILABILITY = 66X*
       *THIS FIGURE IS BASED UPON 9.92 HOURS OF OPERATION ON TnU SCRUBbtKS WHILE UM1  1  WAS BEING
       BROUGHT BACK ON LINE AFTER COMPLETION OF ITS ANNUAL OVERHAUL.  THE I.D. FAN MUTUK WAS NUT
       AVAILABLE AT UNIT STARTUP ON THE 1A MODULE.
JUNE 78     TOTAL SYSTEM AVAILABILITY - 76X
JULY 78     TOTAL SYSTEM AVAILABILITY = 96X
                                                  51

-------
EPA UTILITY F60 SURVtY: OCTOBER  1978 - NOVEMBER  197B


                     SECTION  3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS


    UTILITY NAME          MONTANA POWER

    UNIT NAME             COLSTHIP ^

    UNIT LOCATION         COLSTRIP MONTANA

    UNIT RATING            360 MW

    FUEL CHARACTERISTICS  COAL?  0.8X SULFUR,  12X ASH

    FGO VENDOR            AOL/COMBUST ION EQUIP ASSOCIATE

    PROCESS               LIME/ALKALINE FLYASH

    NEW OR RETROFIT       NEW

    START UP DATE          8/76

    EFFICIENCY:
     PARTICULATES (ACTUAL)   99.5 PERCENT

                  (DESIGN)   99.5 PERCENT

     S08          (ACTUAL)   75.0 PERCENT

                  (DESIGN)   60.0 PERCENT

    WATER MAKE UP         CLOSED LOOP

    SLUDGE DISPOSAL       STABILIZED/SLUDGE POND



    OPERATING EXPERIENCE UPDATE:


JAN. 78     TOTAL SYSTEM AVAILABILITY   97X

FEB. 78     TOTAL SYSTEM AVAILABILITY - 95X

MAR. 76     TOTAL SYSTEM AVAILABILITY = 89X*
       •THIS FIGURE IS BASED UPON THE 17 DAYS OF OPERATION BEFORE THE UNIT WAS SHUT UOwN FOR A
       SCHEDULED ANNUAL OVERHAUL.

APR. 78     TOTAL SYSTEM AVAILABILITY = 87X*
       •THIS FIGURE IS BASED UPON 8 DAYS OF OPERATION IN APRIL AFTER A UNIT OVERHAUL.

MAY  78     TOTAL SYSTEM AVAILABILITY - 99X

JUNE 78     TOTAL SYSTEM AVAILABILITY   97X

JULY 78     TOTAL SYSTEM AVAILABILITY - 96X

-------
                                                  EPA UTILITY FGD 5UKVKY: UCIUritH 147H - MOVfcf'ttE* 14/H
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS


    UTILITY NAME          NEVADA POWER

    UNIT NAME             REID GARDNER  1

    UNIT LOCATION         MOAPA NEVADA

    UNIT RATIN6            125 MW

    FUEL CHARACTERISTICS  COAL; 0.5X SULFUR, 6X ASH

    FGD VENDOR            AOL/COMBUSTION EQUIP ASSOCIATE

    PROCESS               SODIUM CARBONATE

    NEW OR RETROFIT       RETROFIT

    START UP DATE          4/70

    EFFICIENCY:
     PARTICULATES  (ACTUAL)   99+ PERCENT

                   (DESIGN)   99.0 PERCENT

     302           (ACTUAL)   05-94 PERCENT

                   (DESIGN)   85.0 PERCENT

    WATER MAKE UP         OPEN LOOP 0.40 GPM/MM

    SLUDGE DISPOSAL       UNSTABILIZED/SOLAR EVAP PUND



    OPERATING EXPERIENCE UPDATE:


                                             HR.
                 BOILER       MODULE       CALLED
           TOTAL OPERATION   AVAILABLE     UPON TO   OPERATION
PERIOD     (HR.)   (HR.)       (HR.)       OPERATE      (HR.)

FEB. 78    672      369        654          309         292
AVAILABILITY = 97X
RELIABILITY = 94Z
OPERABILITY = 7SX
UTILIZATION = 43X
       THE SCRUBBER-ABSORBER SYSTEM WAS OFF-LINE FOR APPROXIMATELY IB HOUH5 UUKINti FtBHUAKY DDE Tu
       PLUGGED SENSING LINES AND A DUCT HI-LO PRESSURE  TRIP.  THE BOILER WENT OUT OF SEKVICfc ON
       ON FEBRUARY 17 FOR A THREE WEEK OUTAGE.

MAR. 78    744.      355        207          355         207
AVAILABILITY = 28X
RELIABILITY = 58X
OPERABILITY = S8X
UTILIZATION = 28X
       THE BOILER CAME BACK ON LINE MARCH 16 BUT PROBLEMS nITH THE GUILLOTINE SNITCHES UtLAYtD
       START-UP OF THE FGD SYSTEM UNTIL MARCH 22.  FGD  DOWNTIME WAS APPROXIMATELY 537 HOUKS.
       A PROBLEM WAS ALSO ENCOUNTERED WITH THE REHEAT STEAM REGULATOR DURING MAKCH.

APR. 78    720      560        720          541         541
AVAILABILITY = 100X
RELIABILITY = 100X
OPERABILITY z 97X
UTILIZATION = 75X
       THERE WERE NO FGD SYSTEM FORCED OUTAGES.  ALL DOWNTIME WAS BOILER RELATLD (179 HKS.).

MAY  78    744      630        721          605         582
AVAILABILITY s 97X
RELIABILITY = 96X
OPERABILITY a 92X
UTILIZATION = 78X
       THE UNIT WAS DOWN 132 HOURS FOR A PRODUCTION CONTROL OUTAGE, 7 HOURS FOK KEPAIKS 10 THE
       CONDENSER, AND 23 HOURS DUE TO HIGH TEMPERATURE  ON 1.0. FAN BEARING.  (OUTAGES HERE BOILEK
       RELATED.)



                                                  53

-------
EPA UTILITY FGD SURVEY! OCTOBEK 1978 - NOVEMBER 1978

NEVADA POWER                                                    REID GARDNER 1

                                             HR.
                 BOILER       MODULE       CALLED
           TOTAL OPERATION   AVAILABLE     UPON TO   OPERATION
PERIOD     (HR.)   (HR.)       (HR.)       OPERATE     (HR.)

JUNE 78    720      720        644          663        644
AVAILABILITY = 89X
RELIABILITY . 100X
OPERABILITY = 89*
UTILIZATION = 89X
       THERE WAS ONE SCHEDULED FGD OUTAGE TO REPAIR A LEAK ON THE VENTUHI WATfcK BOX.

JULY 78    744      744        744          736        736
AVAILABILITY = 100X
RELIABILITY = 100X
OPERABILITV - 99X
UTILIZATION = 99X
       A SCHEDULED FGD OUTAGE WAS REQUIRED TO RECTIFY A HIGH TRAY DIFFEKbNTlAL PRESSURE KHUHLtM.
       THE TRAY WAS CLEANED OUT DURING THE OUTAGE.

AUG. 78    744      706        696          707        661
AVAILABILITY = 94X
RELIABILITY = 93X
OPERABILITY = 94X
UTILIZATION = 89X
       THE SCRUBBER WAS FORCED OFF LINE ON AUGUST 5 BECAUSE UF A LOSS UF THE ASH PANtL CONTROL
       POWER.  THIS LEFT THE UNIT WITHOUT EMERGENCY SPRAY TO THE SCRUBBERS.  A SfcCUND FORCED OUTAGE
       OCCURRED ON AUGUST 20 WHEN THERE WAS A SCRUBBER VENTURI HIGH TEMP ALAKM.  THE EXACT CAUSE WAS
       NOT KNOWN BUT A BOILER TUBE LEAK WAS SUSPECTED.  THERE WAS ONE SCHEDULED OUTAGE DURING THt
       MONTH TO CLEAN THE TRAY.

SEP. 78    720      644        715          631        626
AVAILABILITY = 99X
RELIABILITY s 99X
OPERABILITY = 97X
UTILIZATION = 87X
       DURING THE MONTH A BOILER TRIP OCCURRED WHICH WAS CAUSED BY SCRUBBER HIGH DUCT PRESSURE.  AS
       A RESULT, THE UNIT WAS DOWN FOR 5.3 HOURS WHILE THE SCRUBBER PRESSURE SENSING LINES WERE
       CLEANED.  THERE WERE THREE OTHER BOILER-RELATED OUTAGES DURING THE MONTH TOTALING 89
       HOURS.  A BOILER TUBE LEAK AND BOILER BURNER WERE REPAIRED.

OCT. 78    744      667        744          667        667
AVAILABILITY = 100X
RELIABILITY - 100X
OPERABILITY - 100X
UTILIZATION = 90X
       THE BOILER MAS OFF LINE ABOUT 77 HOURS FOR REMOVAL OF AN ASH CLINKER.

NOV. 78    720      686        641          686        598
AVAILABILITY s B9.X
RELIABILITY = 87X
OPERABILITY = 87X
UTILIZATION = 83X
       THE FGD SYSTEM WAS DOWN FOR SCRUBBER OUTLET TEMPERATURE PROBE REPAIRS AND HIGH SOLIDS CONTENT
       IN THE SCRUBBER EFFLUENT.  FURTHER OUTAGE TIME RESULTED WHEN BOILER PROBLEMS CAUSED THE
       VENTURI OUTLET GAS TEMPERATURE TO BECOME TOO HIGH (TEMPERATURE ALARM HIGH TKIP).
                                                  54

-------
                                                  EPA UTILITY FGO SUHVtY: OCTUbEH 1978 - NUVtMBtK


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS


    UTILITY NAME          NEVADA POWER

    UNIT NAME             KEIO GARDNER 2

    UNIT LOCATION         MOAPA NEVADA

    UNIT RATING            125 MW

    FUEL CHARACTERISTICS  COAL; 0.5X SULFUR, 8X ASH

    FGD VENDOR            AOL/COMBUSTION EQUIP ASSOCIATE

    PROCESS               SODIUM CARBONATE

    NEW OR RETROFIT       RETROFIT

    START UP DATE          4/74

    EFFICIENCY:
     PARTICULATES  (ACTUAL)   99+ PERCENT

                   (DESIGN)   99.0 PERCENT

     302           (ACTUAL)   85-94 PERCENT

                   (DESIGN)   85.0 PERCENT

    WATER MAKE UP         OPEN LOOP 0.40 GPM/MW

    SLUDGE DISPOSAL       UNSTA8ILI ZED/SOLAR EVAP POND



    OPERATING EXPERIENCE UPDATE:

                                             HR.
                 BOILER       MODULE       CALLED
           TOTAL OPERATION   AVAILABLE     UPON TO   OPERATION
PERIOD     (HR.)    (HR.)       (HR.)       OPERATE      (HR.)

FEB. 78    672      636        625          632         585
AVAILABILITY = 93Z
RELIABILITY = 92X
OPERABILITY = 92X
UTILIZATION = 87X
       FGD DOWNTIME DURING FEBRUARY WAS APPROXIMATELY 48 HOURS DUE TU A PLUGGED SENSING LINE AND
       A DUCT HI-LO PRESSURE TRIP.  THE BOILER WAS OUT  OF SERVICE 34 HOURS.

MAR. 78    744      672        726          614         595
AVAILABILITY = 98X
RELIABILITY r 97X
OPERABILITY = 89X
UTILIZATION = SOX
       THERE WAS ONLY ONE FORCED FGD OUTAGE DURING MARCH WHICH LASTED APPROXIMATELY 18 HOURS.  A
       SCHEDULED BOILER OUTAGE AT THE BEGINNING OF THE  MONTH TO REMOVE ASH BUILDUP WAS CANCELLED.

APR. 78    720      320        720          317         317
AVAILABILITY = 100X
RELIABILITY - 100X
OPERABILITY = 98X
UTILIZATION = 44X
       THERE WAS ONE SCHEDULED BOILER OUTAGE WHICH LASTED ABOUT 403 HOURS.

MAY  76    744      726        743          726         724
AVAILABILITY = 100X
RELIABILITY = 100X
OPERABILITY = 100X
UTILIZATION = 97X
       THE BOILER WAS OFF FOR APPROXIMATELY 18 HOURS FOR REPAIRS ON THE MILL SPOKES.  THE 2A SEC.
       BREAKER TRIPPED AND CAUSED AN OUTAGE OF ABOUT ONE HOUR.
                                                  55

-------
EPA UTILITY F60 SURVEY: OCTOBER  1978 - NOVEMBER 1978

NEVADA POWER                                                    REID GAkDNtK d

                 BOILER       MODULE     HR. CALLED
           TOTAL OPERATION   AVAILABLE     UPON TO   OPERATION
PERIOD     (HR.)    (HR.)        (HR.)       OPERATE      (HR.)

JUNE If    720      720         718          663         661
AVAILABILITY =  100X
RELIABILITY = 100X
OPERABILITY = 92X
UTILIZATION = 92X
       THERE HERE TWO SCHEDULED  FGD OUTAGES TO UNPLUG THE TRAYS AND TO CHANGfc THt OIL UN THE  I.I).
       FAN.  A FORCED FGD OUTAGE OCCURRED WHEN HIGH DUCT PRESSURE CAUSED A B01LEK 1KIP.

JULY 78    744      676         596          701         553
AVAILABILTY = 80X
RELIABILITY = 79X
OPERABILITY - 82X
UTILIZATION = 74X
       THE BOILER WAS OUT OF SERVICE DUE TO A BOILER TUBE LEAK.  THERE WAS ALSU A bOlLEH TklP UUt TO
       A HIGH DUCT PRESSURE.  THIS WAS CAUSED BY A FAULTY POSITIONER ON THE I.U. FAN CUMTKULLtk.
       THE 1.0. FAN EXPANSION JOINT ON THE SCRUBBER WAS REPLACED.  ANOTHER FGD OUTAGE UCCUHRfcO "HtN
       A BOLT, WHICH FELL FROM  THE FAN, CAUSED VIBRATIONS.  A SbCONU 8UILER IMP DURING JULT  vsAS
       CAUSED BY AN UNDETERMINED SOURCE.  THE SUCTION LINE FROM THE VENTUR1 DISCHARGE LINF TO
       THE EFFLUENT PUMPS WAS CLEANED OUT, WHEN PLUGGING OCCURRED.

AUG. 78    744      733        603          643         601
AVAILABILITY = SIX
RELIABILITY = 93X
OPERABILITY = 82X
UTILIZATION = 81X
       TWO SCHEDULED OUTAGES DURING THE PERIOD WERE NECESSARY TO CLEAN THE SCRUbttEk TRAY.  A  THIHIJ
       SCHEDULED OUTAGE WAS NECESSARY TO CLEAN THE NOZZLES ON THE SCRUbBER SPRAY HACK.  THE STAIN-
       LESS STEEL PIPE TO THE TRAY SPRAY NOZZLES WAS ALSO REPLACED.  THEKE WERE THREE FllHCEO  UUTAGKS
       DURING THE MONTH.  ON AUGUST 1 THE SCRUBBER EXPERIENCED HIGH DUCT PRESSURE.  UN AUGUST 3 II
       WAS NECESSARY TO TAKE THE SCRUBBER OFF LINE TO REPACK THE VEN1URI PUMKS.  THE THIKO OUTAGE
       WAS CAUSED BY A LOSS OF THE ASH PANEL CONTROL POWER.  THIS LEFT THE SCRUBBER WITHOUT EMERGEN-
       CY SPRAY.

SEP. 78    720      693        720          675         675
AVAILABILITY = 100X
RELIABILITY = 100X
OPERABILITY = 97X
UTILIZATION = 94X
       A SCHEDULED SCRUBBER OUTAGE TOOK PLACE DURING THE MONTH IN ORDER TO CLEAN THE TRAY RECYCLE
       TANK AS WELL AS THE TRAY  AND SOME OF THE LINES.  THREE OTHER BOILER RELATED OUTAGES WERE
       CAUSED BY PROBLEMS WITH A 10-KW GENERATOR.  CONTROL POWER SURGES WEKE BEING CAUSED BY  OVtk-
       VOLTA6E MOTOR TRIPS.

OCT. 78    744      721        714          691         685
AVAILABILITY = 96X
RELIABILITY = ??X
OPERABILITY = 95X
UTILIZATION = 921
       DURING OCTOBER THE SCRUBBER INSTRUMENTS WERE WORKED ON DURING A SCHEDULED OUTAGE.  THE tfUILbR
       WAS FORCED OUT OF SERVICE FOR ABOUT 28 HOURS BECAUSE OF BOILER DRUM PROBLEMS.

NOV. 78    720      277        702          277         258
AVAILABILITY = 98X
RELIABILITY = 93X
OPERABILITY = 93X
UTILIZATION = 36X
       A FORCED FGD OUTAGE OCCURRED DUE TO HIGH DUCT PRESSURE.  WORK WAS ALSU DONE ON I.D. FAN
       CONTROLS.  THE UNIT WAS SHUT DOWN NOVEMBER 12 FOR SCHEDULED BOILER MAINTENANCE. THE UNIT
       REMAINED OUT OF SERVICE THE REMAINDER OF THE MONTH.
                                                  56

-------
                                                   EPA  UTILITY  FGD  SURVEY:  UCtUbEK  IVtti - MJVtKrthn 1476


                      SECTION  5
   PERFORMANCE  DESCRIPTION  FOR  OPERATIONAL  FUD  SYSTEMS


    UTILITY  NAME          NEVADA  POWER

    UNIT NAME             REID  GARDNER  3

    UNIT LOCATION         MOAPA NEVADA

    UNIT RATING            125  MM

    FUEL CHARACTERISTICS  COAL? 0.5X  SULFUR,  8X ASH

    F60 VENDOR            ADL/COMBUSTION  EQUIP  ASSOCIATE

    PROCESS               SODIUM  CARBONATE

    NEW OR RETROFIT       N£w

    START UP DATE           7/76

    EFFICIENCY:
     PARTICULATES  (ACTUAL)    99+  PERCENT

                   (DESIGN)    99.0 PERCENT

     902           (ACTUAL)    85-90 PERCENT

                   (DESIGN)    85.0 PERCENT

    WATER MAKE  UP         OPEN  LOOP 0.40  GPM/MH

    SLUDGE DISPOSAL       UNSTABILIZED/SOLAR  EVAP  POND



    OPERATING EXPERIENCE  UPDATE:


                                              HR.
                 BOILER       MODULE        CALLED
           TOTAL OPERATION    AVAILABLE      UPON TO  OPERATION
PERIOD     (HR.)    (HR.)        (HR.)        OPERATE     (HR.)

FEB. 78    672      619         642         618        588
AVAILABILITY =  96X
RELIABILITY  = 95X
OPERABILITY  = 95X
UTILIZATION  s 88X
       DURING FEBRUARY FAULTY WIRING  CAUSED A HIGH VENTUKI  TtMPEHATUKE RESULTING  IN AN INITIAL Ib
       HOUR  FGD SYSTEM OUTAGE.  THERE WAS A SECOND OUTAGE OF 13 HOURS TO CHECK  THE VENTURI
       TURE  INDICATOR.  A THIRD OUTAGE  WAS  CAUSED  BY PLUGGING OF THE MIX TANK rtHlCh MADE IT
       SIBLE TO MIX CHEMICALS.

MAR. 78    744      741         724         738        716
AVAILABILITY =  97X
RELIABILITY  a 97X
OPERABILITY  = 97X
UTILIZATION  = 96X
       THE MIX  TANK PROBLEM CONTINUED INTO  MARCH CAUSING THE ONLY  FGU DOWNTIME  FOK THE f-.UNTh
       (APROX.  20 HOURS).   A FURNACE HI-LO  PRESSURE TRIP CAUSED A  BOILER OUTAGE UF 6 HOURS.

APR. 78    720      704         699          650         629
AVAILABILITY =  97X
RELIABILITY  = 97X
OPERABILITY  a 89X
UTILIZATION  = 87X
       THE FGD  SYSTEM WAS DOWN  APPROXIMATELY 21 HOURS FOR REPAIRS  ON THE VENTURI EMERGENCY SPRAY
       SYSTEM.  THE BOILER WAS  DUWN APPROXIMATELY  70 HOURS DURING  APRIL.

MAY  78    744      646         724          514         494
AVAILABILITY = 97X
RELIABILITY  = 96X
OPERABILITY * 77X
UTILIZATION  « 66X
       THERE WAS A SCHEDULED OUTAGE OF 230 HOURS FOR BOILER MAINTENANCE, AND A FORCED OUTAGE UF
       20 HOURS DUE TO A FAULTY TEMPERATURE PROBE  AT THE VENTUKI DURING MAY.



                                                   57

-------
EP* UTILITY F6D SURVEY: OCTOBER  1978 - NOVEMBER  1978

NEVADA POWER                                                    REID GARDNER 3

                 BOILER       MODULE     HH. CALLED
           TOTAL OPERATION   AVAILABLE     UPON  TO   OPERATION
PERIOD     (HR.)   (HR.)        (HR.)       OPERATE      (HR.)

JUNE 78    720      715         730          715         686
AVAILABILITY =  100X
RELIABILITY = 961
OPERABILITY = 96X
UTILIZATION = 95X
       A SCHEDULED FGD OUTAGE OCCURRED WHEN THE  FIRE SPRAY SYSTEM WAS OUT UF SERVICE.   THERE hAS
       ALSO A BOILER TRIP (HI-LO FURNACE PRESSURE TRIP).

JULY 78    744      726        744          583         583
AVAILABILITY =  100X
RELIABILITY = 100X
OPERABILITY = 80X
UTILIZATION = 78X
       LOW VENTURI FLOW CAUSED ONE OF THREE SCHEDULED FGD OUTAGES.  THIS WAS CORRECTED WHEN THE
       NOZZLES ON THE RACE TRACK WERE CLEANED.   ANOTHER OUTAGE OCCURRED WHEN AN INSPECTION OF  THE
       VENTURI TANK AND RACE TRACK WAS REQUIRED.  THE TANK AND RACE TRACK NOZZLES WERE CLEANED AND
       THE RUBBER LINING ON THE VENTUKI SPOOL WAS REPLACED.  A THIRD OUTAGE WAS REUUIRED TO CLEAN
       THE VENTURI RACE TRACK.  A SCHEDULED OUTAGE. WHICH WAS NOT FGD SYSTEM RELATED. TO CLEAN THE
       TURBINE LUBE OIL COOLERS ALSO OCCURRED DURING JULY.

AUG. 78    744      736        730          736         721
AVAILABILITY = 98X
RELIABILITY - 98X
OPERABILITY = 98X
UTILIZATION = 97X
       THERE WAS ONE FORCED BOILER OUTAGE DURING THE MONTH CAUSED BY HIGH FURNACE PRESSURE.  THE
       SCRUBBER WAS FORCED OFF LINE ON AUGUST 28 DUE TO HIGH SCRUBBER FAN OUTLET PRESSURE.  THE
       SCRUBBER PRESSURE SENSING LINE WAS CLEANED.  ON  AUGUST 29 THE SCRUBBER tFFLUEM SUL10S  LEVEL
       WAS HIGH CAUSING AN OUTAGE OF APPROXIMATELY FIVE HOURS.  THE SYSTEM WAS FLUSHED TU CORRECT
       THE PROBLEM.

SEP. 78    720      236        720          228         228
AVAILABILTY = 100X
RELIABILITY = 100X
OPERA6IHTY = 97X
UTILIZATION = 32X
       THIS UNIT WENT DOWN ON SEPTEMBER 10 FOR A TURBINE OVERHAUL WHICH LASTEO THRUUGH THE END OF
       THE MONTH.  NO SCRUBBER OUTAGES WERE REPORTED FOR THE PERIOD SEPTEMBER 1-10.

OCT. 78    744        0        744            0          0
AVAILABILITY = 100Z
RELIABILITY = N/A
OPERABILITY = N/A
UTILIZATION = OX
       THE UNIT WAS DOWN THE ENTIRE MONTH OF OCTOBER FOR TURBINE OVERHAUL.

NOV. 78    720      489        707          489         447
AVAILABILITY = 98X
RELIABILITY = 91X
OPERABILITY = 9U
UTILIZATION = 62X
       THE UNIT MAS BROUGHT BACK ON LINE THE 10TH OF NOVEMBER.  THE FGD SYSTEM WAS DOWN ABOUT  12
       HOURS FOR REPAIRING VENTURI TEMPERATURE PROBES.

-------
                                                  EPA UTILITY FGU  SURVEY: OCTOBER 197B - NUVEKBfcK IT/tt
                     SECTION  3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FliO SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
                 NORTHERN INDIANA PUB SERVICE

                 DEAN H. MITCHELL 11

                 GARY INDIANA

                  1 15 MM
    FUEL CHARACTERISTICS  COAL;  3.5Z SULFUR,  10*  ASH
    FGD VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE
                 DAVY POWERGAS

                 WELLMAN LORD

                 RETROFIT

                 11/76
    EFFICIENCY:
     PARTICULATES  (ACTUAL)   99.5 PERCENT
                   (DESIGN)

     S02           (ACTUAL)

                   (DESIGN)

    MATER MAKE UP

    SLUDGE DISPOSAL
                    99.5 PERCENT

                    91.0 PERCENT

                    90.0 PERCENT

                 CLOSED LOOP

                 ELEMENTAL SULFUR PRODUCT
    OPERATING EXPERIENCE UPDATE:
MONTH
  HOURS
IN PERIOD
  HOURS
AVAILABLE
  HOURS
CALLED ON
TO OPERATE
  HUURS
UPERATED
                                                          AVAILABILITY  RELIABILITY  UTILIZATION
NOV. 77     720         531          596         128           7a           72           90
THE FGU UNIT OPERATED FOR  16 CONSECUTIVE DAYS, AVERAGING 901 S02 REMOVAL WITH 285 LONG TONS OF
SULFUR RECOVERED.  FGD OPERATION WAS INTERRUPTED BY A UNIT  11 BOILER TUBE LEAK AND RESUMPTION OF FGD
OPERATION WAS FURTHER DELAYED BY MAINTENANCE  IN THE EVAPORATOR SECTION.  MAINTENANCE WAS ALSO PER-
FORMED ON THE FLUE GAS ISOLATION DAMPER, FLUE GAS BOOSTER BLOWER, AND S02 REDUCTION SECTION.

DEC. 77     768         379          272          0            49            0 .           0
THE FGD SYSTEM WAS NOT OPERATED DURING THIS PERIOD DUE TO ABNORMAL BOILER OPERATING CONDI TUNS
RELATED TO HIGH SILICA LEVELS IN THE FEED WATER.  THE HIGH  SILICA LEVELS KSULTED FROM HIGH MAKE-UP
WATER REQUIREMENTS DUE IN  PART TO A HIGHER THAN NORMAL FGD  PLANT USAGE, AS WELL AS UNIT 11 COAL FEtn
PROBLEMS AND A PRECIPITATOR MALFUNCTION.  MAINTENANCE WAS PERFORMED ON THE FG BOOSTER BLOWER AND
THE ABSORBER SOLUTION REGENERATION SECTION.

JAN. 76     720         S76           0           0            80                         0
THE FGD SYSTEM REMAINED DOWN THROUGHOUT JANUARY AS HIGH SILICA LEVELS IN THE UNIT 11 BOILER FEED
WATER PERSISTED.  MAINTENANCE WAS PERFORMED ON THE UNIT 11  PRECIPITATOR, THE FG BOUSIER BLOWLR AND
THE FGO SYSTEM 302 COMPRESSOR.

FEB. 78     720         336           0           0            17                         0
THE FGD SYSTEM WAS NOT OPERATED DUE TO ABNORMAL BOILER OPERATING CONDITIONS RELATED TO HIGH SILICA
LEVELS IN THE BOILER FEED  WATER, COUPLED WITH UNIT 11 COAL  FEED PROBLEMS, STOP VALVE PROBLEMS, PRE-
CIPITATOR MALFUNCTION AND  A LEAKING BOILER TUBE AND WORK ON THE FLUE GAS ISOLATION DAMPER.  MAIN-
TENANCE WAS ALSO PERFORMED ON THE FG BOOSTER BLOWER, THE EVAPORATOR CIRCULATING PUMP AND THE S02
SUPERHEATER PIPING.

MAR. 78     720         618          281         215           90           77           30
THE FGD SYSTEM OPERATED FOR TEN DAYS.  OPERATION WAS INTERRUPTED BY SHUTDOWN OF THE UNIT 11 BUILER
FOR REPAIR OF COAL GRINDING MILLS AND PRECIPITATORS.  PROPER CONDITIONS COULD NOT BE RE-ESTABLISHEU
FOR RE-START OF FGD OPERATION BECAUSE OF COAL FEED AND GRINDING PROBLEMS CAUSED BY EXTREMELY POOR
QUALITY COAL.  MAINTENANCE WAS PERFORMED ON THE BOOSTER BLOWER AND OPERATING PROBLEMS WERE
ENCOUNTERED WITH THE FLUE  GAS ISOLATION DAMPER.
                                                  59

-------
EPA UTILITY F60 SURVEY: OCTOBER  1976 - NOVEMBER  1978

NORTHERN INDIANA PUBLIC SERVICE
MONTH
HOURS
IN PERIOD
  HOURS
AVAILABLE
    HOURS
CALLED ON
TO OPERATE
  HOURS
OPERATED
                                                       DEAN n. MITCHELL 11
AVAILABILITY  RbLIAHlLlM   UtlLUAtlUH
                                                                                          U
APR. 76     720          0           288          0             U            U
THE F6 BOOSTER BLOWEH WAS OUT OF SERVICE FOR THIS ENTIRE PERIOD FOR KEHLA01NU.   IHk FbD SYSTE* WAS
INOPERABLE.  A FAILURE OF THE FLUE GAS ISOLATION DAMPER ALSO OCCURRED.  A NEH SUPPLY OF HIGH SULHW
COAL WAS OBTAINED AND SUCCESSFULLY TESTED ON UMI 11 BOILER.  THIS COAL IS EXPECThl) TO ALLhVlAU
PAST DIFFICULTIES WITH THE COAL FEED AND GRINDING SYSTEM.  MAINltNANCE WAS ALSO  PERFORMED ON THE
BOILER ID FANS, COAL FEEDING AND GRINDING SYSTEM AND THE FGO AbSORHEK.

MAY  78     720         368          529         263           51           bU           4?
THE S02 RECOVERY PORTION OF THE FGD SYSTEM OPERATED FOR 26 DAYS.  THE COMPLETE FGD SYSTEM OPERATED
FOR 11 DAYS.  OPERATION WAS INTERRUPTED BY FAILURE OF THE FLUE GAS ISOLATION DAMPEK, PKUbLEMi * I IM
WET COAL WHICH REQUIRED THAT THE UNIT 11 BOILER OPERATE ON LOW SULFUR COAL FOK A SHUKT PERIOD AND
PLUGGING OF AN ENTRAINMENT SEPARATOR IN THE S02 REDUCTION UNIT.

JUNE 78     720          97          521           3           13            1            U
OPERATION OF THE FGD SYSTEM WAS LIMITED BY FAILURE OF THE BOOSTER BLOWER DRIVE TURHINF AMU
INABILITY OF THE ISOLATION DAMPER TO OPERATE.  THE FGO PROCESS FACILITIES, CONSISTING OF THE
ABSORBERr EVAPORATOR. S02 REDUCTION AND PURGE TREATMENT UNITS, WERE AVAILABLE FUK OPERATION FOk
ESSENTIALLY THE ENTIRE PERIOD.

JULY 78     720          43          113          17            6            4            2
OPERATION OF THE FGD SYSTEM WAS LIMITED BY IMBALANCE OF THE BOOSTER BLOWEK.  DUE 10 INAH1L1IY
OF THE ISOLATION DAMPER TO OPERATE, THIS CONDITION COULD NOT BE CORRECTED UNTIL  PilftKR OEKANOS
PERMITTED A SHUT DOWN OF UNIT 11 BOILER.  RECURRING FLUCTUATIONS IN THE PRESSORE OF I HE MAI';
STEAM SUPPLY TO THE FGD SYSTEM ALSO LIMITED OPERATION.  FLUE GAS BOOSTER BLOnEK  PROBLEMS INCLUDED
LOW OIL PRESSURE, LEAKING BEARING OIL SEALS AND DRIVE TURBINE GOVERNOR MALFUNCTION.  THE FGO
PROCESS FACILITIES WERE AVAILABLE FOR OPERATION FOR THE ENTIRE PER100.

AUG. 78     720         707         720          707           98           9B           9H
THE UNIT 11 BOILER OPERATED CONTINUOUSLY ON HIGH SULFUR COAL THROUGHOUT THE PERIOD.  THt FGO SYSTEM
ACHIEVED FULL OPERATION ON THE FIRST DAY OF THE PERIOD.  AFTER PROBLEMS WITH THE HOOSTtR hLO*v£R
WERE CORRECTED, IT REMAINED IN FULL OPERATION FUR THE BALANCE OF THE PERIOD rvITH THE F.XCEMIUN UF
ONE TWO-HOUR INTERRUPTION DUE TO AN ELECTRICAL MOTOR MALFUNCTION.

SEP. 78     720         319          321         319           44           99           44
THE UNIT 11 BOILER OPERATED ON HIGH SULFUR COAL UNTIL SEPTEMBER 12 WHEN IT wAb SHUT-DOWN FOR AN
ANNUAL OVERHAUL.  THE BOILER REMAINED DOWN THROUGH THE END OF THE PERIOD.  THE FGD SYSTEM CONTIN-
UED IN FULL OPERATION UNTIL SEPTEMBER 12, WITH THE EXCEPTION OF ONK TWO-HOUR INTERRUPTION DUE TO A
GOVERNOR MALFUNCTION ON THE S02 COMPRESSOR DRIVE TURBINE, AND WAS THEN SHUT-DOnN CONCURRENTLY WITH
THE UNIT 11 BOILER.

OCT. 78     840         369          504         369           44           li           44
THIS PERIOD COVERS SEPTEMBER 29 THROUGH NOVEMBER 2.  FOLLOWING THE ANNUAL TUKNARUIINU, THE UNIT U
BOILER RE-STARTED ON OCTOBER 6.  A NEh BASELINE TEST WAS RUN ON THE HOILER OCTOBER 7 THROUGH 12.
BALANCING OF THE FLUE GAS BOOSTER BLOWER WAS THEN COMPLETED AFTER WHICH THE FGD  SY6TEK MAS STARTED
ON OCTOBER 18.

NOV. 78     720         712          717         709           99           99           98
THE UNIT 11 BOILER OPERATED CONTINUOUSLY ON HIGH SULFUR COAL EXCEPT FOR ONE THKEE-HOUK OUTAGE FOR
REPAIR OF A STEAM CONTROL VALVE.  VARIATIONS IN THE PRESSURE OF THE STEAM SUPPLY TO FGD OCCURRED
DUE TO HIGH SILICA IN THE MAKE-UP WATER TO UNIT 11.  PROBLEMS nERE ALSO ENCOUNTERED nITH Thfc
SODIUM SULFATE PURGE DRYER WHICH NECESSITATED DISPOSING OF PART OF THE SULFATE PURGE TO THE BOTTOM
ASH POND FOR A PORTION OF THE PERIOD.
                                                  60

-------
                                                   EPA  UTILITY  FGD  SUkVEY:  UCTUnEK  \11H  -  hOVtf'HFW  1^


                      SECTION  3
   PERFORMANCE DESCRIPTION  FOR  OPERATIONAL  FGO  SYSTEMS


    UTILITY NAME          NORTHERN  STATES POWER

    UNIT NAME             SHER8URNE 1

    UNIT LOCATION         BECKER  MINNESOTA

    UNIT RATING             710  MW

    FUEL CHARACTERISTICS  COAL?  0.8X  SULFUR,  9.5X  SULFUR

    FGO VENDOR            COMBUSTION  ENGINEERING

    PROCESS               LIMESTONE/ALKALINE  FLYASH

    NEW OR RETROFIT       NEW

    START UP DATE           3/76

    EFFICIENCY:
     PARTICULATES  (ACTUAL)    99+  PERCENT

                   (DESIGN)    99.0 PERCENT

     S02           (ACTUAL)    50-55  PERCENT

                   (DESIGN)    50.0 PERCENT

    WATER MAKE UP         OPEN  LOOP 1.13 GPM/MW

    SLUDGE DISPOSAL       FORCIBLY  OX 101ZED/SLUOGE PONU



    OPERATING EXPERIENCE  UPDATE:


              BOILER  OPERATION  TIME AND MODULE  OPEKABILITY  (X)
       BOILER
PERIOD   KR. 101    102    103    104    105    106    107    108    109    110    111    112

FEB. 76  636   0    93    92     89     74    85     89    88     76     66     B«     b7
TOTAL SYSTEM AVAILABILITY = 92  PERCENT
MEGAWAMT-HOURS GENERATED  = 366,200
        MODULE 101  WAS DOWN IN  FEBRUARY FOR MODIFICATIONS  TO  THE SPRAT  TUWtk  AbSUWBEK.   4  HULK
        ENTRAINMENT SEPARATOR WAS INSTALLED ALONG  WITH  A KOCH  «ASH TRAY.   SPRAY  NOBLES ivtKE
        REPLACED.   THE 2  IN.  DIA. SS  RODS IN  THE PRIMARY CONTACTOR WERE KEPLACtO «ITH 6(5/B)lN.  U1A.
        CERAMIC COATED C.S. RODS.  THE CERAMIC  SLEEVES  ARE  9/16IN. THICK.   MODULES WHICH  AKF-  SHIinING
        AVAILABILITY  OF LESS  THAN 80  PERCENT, ARE  THOSE IN  WHICH THE  STRAINER  MOOIFICATlUUb  nE^t
        PERFORMED.

MAR. 78  676  71    83    64    89     90    83     62    89     97     71     79     90
TOTAL SYSTEM AVAILABILITY = 92  PERCENT
MEGAWATT-HOURS GENERATED  = 423,220
        STRAINER MODIFICATIONS  CONTINUED THROUGH MARCH  AFFECTING THE  AVAILABILITIES  UF  MODULES  101,
        103, 107 AND  110.

APR. 78  713  92    87    87    44     81    85     91    86     92     91     87     S2
TOTAL SYSTEM AVAILABILITY = 95  PERCENT
MEGAWATT-HOURS GENERATED  - 464,520
        THE REASON FOR LOW  AVAILABILITY ON  MODULE  104  AND  112  IN APHIL  RESULTED  FOKM THE  OUTAGE  TIME
        NECESSARY FOR THE INSTALLATION OF STEEL STRAINER SCREENS.

MAY  78  635  61    86    85    86     89    64     62    83     «2     71     87     79
TOTAL SYSTEM AVAILABILITY = 95 PERCENT
MEGAWATT-HOURS GENERATED  = 380,010
        THERE WERE NO MAJOR FGD RELATED OUTAGES DURING MAY.

JUNE 78  717  50    84    85    85     62    78     55    83     88     82     72     95
TOTAL SYSTEM AVAILABILITY = 93 PERCENT
MEGAWATT-HOURS GENERATED  = 414,670
                                                  61

-------
EPA UTILITY F6D SURVEY: OCTOBER  1978 - NOVEMBER  1978

NORTHERN STATES POWER                                                     SHEKbUKNE  1

              BOILER OPERATION TIME AND MODULE UPERABILITY  (X)
       BOILER
PERIOD   HR. 101   102   103   104   105   106    107   108    IU9   110    111    112

JULY 78  694  82    76    71     74    75    52    75    63    62    72    66    73
TOTAL SYSTEM AVAILABILITY = 95 PERCENT
MEGAHATT-HOURS GENERATED  = 394,510
        THE UTILITY IS IN THE PROCESS OF REMOVING THE ORIGINAL ZURN DUPLEX STRAINEHS AND REPLACING
        THEM WITH 316 STAINLESS  STEEL STRAINERS.  THE UCCURANCE OF PLUGGING PROBLEMS IN THE MIST
        ELIMINATOR AND REHEATER  HAS BEEN MORE FREOUENT THAN NORMAL.  THE  UULITY  IS  EVALUATING NEW
        RUBBER LINED PUMPS  (8000 GPM) AND STAINLESS STEEL MIST ELIMINATOR WASH  LANCF.S  ITO REPLACE
        ORIGINAL FIBERGLAS LANCES).  THE FGD SYSTEM HAS HEEN EXPERIENCING PRIMAKY CUMACTOK hALL AND
        MARBLE BED WEAR.  THE UTILITY IS PREPARING FOR THE STATE COMPLIANCE DEADLINE ON NOV.  1.
        CURRENTLY TESTING HAS BEEN PROCEEDING ON DIFFERENT MODULES IN AN  EFFORT To FINE HlNE  THfc
        SYSTEM.

AUG. 78  742  64    65    73     63    65    80    81    73    63    73    64    83
TOTAL SYSTEM AVAILABILITY = 91 PERCENT
MEGAWATT-HOURS GENERATED  = 416,930
        NO MAJOR FGD RELATED OUTAGES h£RE REPORTED BY THE UTILITY FOR THE MONTH OF AUGUST.

SEP. 78  357  89    62    77     77    58    82    68    68    80    80    55    75
TOTAL SYSTEM AVAILABILITY = 97 PERCENT
MEGAWATT-HOURS GENERATED  = 185,740
        THE BOILER WAS TAKEN DOWN ON SEPTEMBER 15 FOR A SCHEDULED ANNUAL  BUILER AND  lUKHlNE INSPEC-
        TION.  THIS IS EXPECTED  TO LAST THROUGH OCTOBER 16.  THE UTILITY  HAS ASKED THAI THE STATE
        COMPLIANCE DEADLINE BE MOVED UP FROM NOVEMBER 1.  THE DECISION IS CURRENTLY  PENDING.  THt
        RUBBER LINED PUMPS THAT  THE UTILITY WAS  INVESTIGATING AS POSSIBLE SOLUTIONS  TO THF MIST
        ELIMINATOR AND REHEATER  PLUGGING PROBLEMS HAVE BEEN ORDERED.  FOUR OF THt HUMPS HAVE  BEtM
        RECEIVED AND ONE IS INSTALLED.  THE OTHERS WILL BE INSTALLED AS THEY COME IN.  OIHFF.NfcNT
        MIST ELIMINATOR SPRAY PATTERNS ARE ALSO BEING TESTED.

OCT. 78  375  95    65    80     17    66    88    53    72    86    70    85    73
TOTAL SYSTEM AVAILABILITY = 92 PERCENT
MEGAWATT-HOURS GENERATED  = 195,700
        THE LOW OCTOBER HOUKS RESULTED FROM THE SCHEDULED ANNUAL BOILER ANU TURBINE  UVEKHAUL.  THE
        UNIT WAS BROUGHT BACK ON LINE IN THE MIDDLE OF OCTOBER.  THE NEW  SPRAY  PUMPS (MtlMTIUNEU  IN
        JULY) MERE INSTALLED ON  MODULES 104, 107, AND 110.

NOV. 78  714  42    51    88     81    71    78    77    63    85    61    84    70
TOTAL SYSTEM AVAILABILITY = 92 PERCENT
MEGAWATT-HOURS GENERATED  = 403,110
        IN NOVEMBER MODULE 101 (THE CONVERTED ROD SCRUBBER MODULE) WAS DOWN FOR PUMP WORK ANU
        INTERNAL HEADER CONVERSION.  THE UTILITY IS NOW IN THE PROCESS OF PREPARING  THE MODULE FOK
        FURTHER TESTING.
                                                  62

-------
                                                  fcPA UTILITY FGO SURVtY: UCIOBtK 1978 - NuVEKBEK 197S


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS


    UTILITY NAME          NORTHERN STATES POWER

    UNIT NAME             SHERBURNE 2

    UNIT LOCATION         BECKER MINNESOTA

    UNIT RATING            710 MM

    FUEL CHARACTERISTICS  COAL; 0.8X SULFUR, 9.5X ASH

    FGD VENDOR            COMBUSTION ENGINEERING

    PROCESS               LIMESTONE/ALKALINE FLYASH

    NEW OR RETROFIT       NEW

    START UP DATE          4/77

    EFFICIENCY:
     PARTICIPATES  (ACTUAL)   50-55 PERCENT

                   (DESIGN)   99.0 PERCENT

     802           (ACTUAL)   55.0 PERCENT

                   (DESIGN)   50.0 PERCENT

    WATER MAKE UP         OPEN LOOP 1.13 GPM/MW

    SLUDGE DISPOSAL       FORCIBLY OXIDIZED/SLUDGE POND



    OPERATING EXPERIENCE UPDATE:


              BOILER OPERATION TIME AND MODULE OPERA8ILITY  (X)
       BOILER
PERIOD   HR. 201   202   203   204   205   206   207   208   209   210   211   212

FEB. 78  620  83    85    55    91    89    76    71    89    85    81    97    60
TOTAL SYSTEM AVAILABILITY = 92 PERCENT
MEGAWATT-HOURS GENERATED  = 367,080
        MODULES 203 AND 212 HAVE LOW AVAILABILITY DUE TCKSTRAINEK MODIFICATIONS.

MAR. 78  744  82    92    90    83    78    85    91    62    83    78    88    89
TOTAL SYSTEM AVAILABILITY =  97 PERCENT
MEGAWATT-HOURS GENERATED  =  483,750
        IN SPITE OF STRAINER MODIFICATIONS ON MODULES 208 AND 210, THE SYSTEM GENERATED MAXIMUM
        MEGAWATT-HOURS AND TIED THE HIGHEST RECORDED AVAILABILITY OF 97 PERCENT.

APR. 78  719  70    82    90    84    91    83    84    86    78    90    67    85
TOTAL SYSTEM AVAILABILITY = 92 PERCENT
MEGAWATT-HOURS GENERATED  = 436,420
        DURING APRIL MODULE 201 WAS CONVERTED FUR USE WITH  THE NEW SPRAY TOWER WHICH WAS INSTALLED.

MAY  78  120  97    94    80    90    90    89    90    92    28    91    78    14
TOTAL SYSTEM AVAILABILITY = 91 PERCENT
MEGAWATT-HOURS GENERATED  = 70,070
        THERE WERE LINER FAILURES (CE1LCOTE) IN MOST OF THE MODULES DURING MAY.  THE LINERS »EKt
        REPAIRED BY THE CEILCOTE COMPANY AT THEIR OWN EXPENSE.  THE INLET SEAL STRIPS WEKb ALSO
        REPAIRED.  THE UNIT WENT DOWN ON MAY 6 FOR THE FIRST YEAR BOILER AND TURBINE INSPfcCTION AND
        WAS DOWN FOR THE REMAINDER OF THE PERIOD.

JUNE 78  572  77    46    41    67    62    62    72    78    60    62    76    75
TOTAL SYSTEM AVAILABILITY = 95 PERCENT
MEGAWATT-HOURS GENERATED  = 326,760
                                                  63

-------
EPA UTILITY FGD SURVEY: OC10BEK  1978  -  NOVEMBER  1978

NORTHERN STATES POWER                                            SHhRBUKNE  2

              BOILER OPERATIUN TIME AND MODULE OPERAB1L1TY  (k)
       BOILER
PERIOD   HR. 201   202   203   204    205   206    207    208    209   210    211    212

JULY 78  697  87    69    62     93    90    60     8b     67     61    81     73     71
TOTAL SYSTEM AVAILABILITY = 95 PERCENT
MEGAWATT-HOURS GENERATED  = 393,610
        THE UTILITY IS IN THE PROCESS OF REMOVING  THE ORIGINAL  ZURN DUPLEX S1KA1NEKS AND
        THEM WITH 316 STAINLESS  STEEL STRAINERS.   THE OCCURANCE  OF  PLUGGING PRUBLEMb IN IHE MbT
        ELIMINATOR AND REHEATER  HAS BtEN MORE FREMUtNT  THAN  NORMAL.  THE  UIILITY  Ib  EVALUATING NbW
        RUBBER LINED PUMPS  (8000 GPM) AND STAINLESS STEEL MIST  ELIMINATOR  KAbH  LANCEb (lU REPLACE
        ORIGINAL FIBERGLAS LANCES).   THF. FGD SYSTEM HAS  BEEN EXPERIENCING  PRIKANY CUNTACfOK rtALL AM)
        MARBLE BED WEAR.  THE UTILITY IS PREPARING FOR  THE STATE COMPLIANCE OtADLIIvE ON HllV. 1.
        CURRENTLY, TESTING HAS BEEN PROCEEDING ON  DIFFERENT  MODULES IN  AN  EFFORT  TU  UNE TUNE tHfc
        SYSTEM.

AUG. 76  695  88   100    48     79    81    72     64     67     54    76     60     71
TOTAL SYSTEM AVAILABILITY = 93 PERCENT
MEGAWATT-HOURS GENERATED  = 384,400

SEP. 78  720  72    82    70     61    74    64     62     72     75    78     82     66
TOTAL SYSTEM AVAILABILITY = 96 PERCENT
MEGAWATT-HOURS GENERATED  = 396,500
        NO FGD RELATED OUTAGES WERE REPORTED BY  THE UTILITY  FOR  THE AUGUST-SEKIEMHEK KEPUKT PI-KIUD.
        THE UTILITY HAS ASKED THAT THE  STATE COMPLIANCE  TEST BE  MOVED UP  FKUM NOVEMBER  1.  A DECI-
        SION IS STILL PENDING.   THE RUBBER LINED  PUMPS  THAT  THE  UTILITY WAb INVESIIGATING AS POS-
        SIBLE SOLUTIONS TO THE MIST ELIMINATOR AND REHEATER  PLUGGING PkUBLEMb HAVE  KEEN ORDF.KtO.
        FOUR OF THE PUMPS HAVE BEEN RECEIVED AND  ONE  IS  INSTALLED.   THE OTHEKS  rtILL  BE  INSTALLED Ab
        THEY ARE RECEIVED.  DIFFERENT MIST ELIMINATOR SPRAY  PATTERNS ARE  ALSO BEING  TESTED.

OCT. 78  688  90    79    59     73    69    64     78     76     72    69     Id     62
TOTAL SYSTEM AVAILABILITY = 94X
MEGAWATT-HOURS GENERATED = 378,990
        DURING OCTOBER MODULE 203 EXPERIENCED REHEATER  PROBLEMS  AND A PLUGGED STkAlNEk  CAUSING A
        0 TO 5 DAY OUTAGE.

NOV. 78  472  84    45    82     60    75    58     77     75     63    83     72     47
TOTAL SYSTEM AVAILABILITY = 92X
MEGAWATT-HOURS GENERATED  = 237,860
        THE LOW NOVEMBER BOILER  HOURS RESULTED FROM A TURBINE  INSPECTION.  NUkMAL OVERHAUL
        MAINTENANCE WAS PERFORMED ON  THE SPRAY PUMPS  OF  MODULES  202 AND 21«!.

-------
                                                  EPA UTILITY F6D SURVEY: OCTOBEK 197B - NUVECBEH 1976
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
                          PENNSYLVANIA POWER

                          BRUCE MANSFIELD 1

                          SHIPPINGPORT PENNSYLVANIA

                           825 MW
    FUEL CHARACTERISTICS  COAL; 4.7X SULFUR, 12,5X ASH
    FGD VENDOR
    PROCESS
    NEW OR RETROFIT
    START UP DATE
    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)

     S02          (ACTUAL)

                  (DESIGN)

    WATER MAKE UP

    SLUDGE DISPOSAL
                          CHEMICO

                          LIME

                          NEW

                           1/76


                             99.9 PERCENT

                             99.8 PERCENT

                             95.0 PERCENT

                             92.1 PERCENT

                          OPEN LOOP

                          STABILIZED/LANDFILL
    OPERATING EXPERIENCE UPDATE:
MONTH
               BOILER
   OPERATING HOURS
      FGD MODULES
BCD
NOV. 77     720           682
F60 AVAILABILITY FACTOR X  95
F60 OPERABILITY FACTOR X   95
F6D UTILIZATION FACTOR X   95
                                 713
                                  99
                                  99
                                  99
      657
       91
       91
       91
TOTAL FGD LOST GENERATION FACTOR = 52.SX
       REMOVAL OF THE OLD COATING AND PRIMING OF THE FLUE LINING IN FLUE IB IS PROCEEDING
       SLOWER THAN ANTICIPATED.  IT IS EXPECTED THAT TOTAL WORK ON THE FLUE WILL NOT BE COMPLETED
       UNTIL FEBRUARY OR MARCH.1978.
                                                             THE FLUE WILL BE RELINEO WITH
DEC. 77     626*          677    592    675      0       0
FGD AVAILABILITY FACTOR X 100     93     99      0       0
FGD OPERABILITY FACTOR X  100     94    100      0       0
FGD UTILIZATION FACTOR X   91     79     91      0       0
TOTAL FGD LOST GENERATION FACTOR = 61 X
       SANDBLASTING OF UNIT 1-B FLUE IS NEARING COMPLETION.
       CXL-2000.

JAN. 78     331»          433      0    432      0       00
F6D AVAILABILITY FACTOR X 100      0    100      0       00
FGD OPERABILITY FACTOR X  100      0    100      0       00
FGD UTILIZATION FACTOR     58      0     58      0       00
TOTAL F6D LOST GENERATION FACTOR = 60X
       THERE WERE PROBLEMS WITH IB FAN WHICH NECCESITATED EXTENSIVE REPAIRS.  LINING ABRASION AND
       DISBONDMENT IN FAN CAUSED CORROSION OF UNDERLYING SUPPORT METAL.  THE UNIT TRIPPED SEVEHAL
       TIMES DUE TO DIFFICULTIES IN BURNING WET STOCKPILE COAL.

FEB. 78     514*          534    410    551      0       00
FGD AVAILABILITY FACTOR X  79     61     82      0       0      0
FGD OPERABILITY FACTOR X  100     80    100      0       00
F6D UTILIZATION FACTOR X   79     61     82      0       0      0
TOTAL FGO LOST GENERATION FACTOR = 54X
       EXTENSIVE REPAIRS TO IB I.D. FAN AND THE EMERGENCY NEED FOR LOAD FROM THE PLANT DURING THE
       COAL STRIKE TEMPORARILY OVERLOADED 1A AND 1C TRAINS.  THE MIST ELIMINATOR MILL BE REPLACED
       1C TRAIN AS A RESULT OF THIS.  IB FLUE RELINING CONTINUES.
                                                  65

-------
EP* UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 1978

PENNSYLVANIA POWER
                                                                BRUCE MANSFIELD 1
MONTH
               BOILER
MAR. 78     689           324
F60 AVAILABILITY FACTOR X  43
FGD OPERABILITY FACTOR X   47
F60 UTILIZATION FACTOR X   43
                                  B

                                 678
                                  91
                                  98
                                  91
OPERATING HOURS
  FGD MODULES
   C      0
  670
   90
   97
   90
485
 65
 70
 65
376
 50
 54
 50
449
 60
 65
 60
                                                                             REPAIRS WERE DONE ON
TOTAL FGD LOST GENERATION FACTOR = 54X
       REPLACEMENT OF THE LINING IN IB CHIMNEY WITH CXL 2000 WAS COMPLETED.
       A, B, AND C FAN HOUSINGS.

APR. 78     720           530    632    357    630     697    678
FGD AVAILABILITY FACTOR X  74     88     49     87      97     94
FGD OPERABILITY FACTOR X   74     88     49     87      97     94
FGD UTILIZATION FACTOR X   74     88     49     67      97     94
TOTAL FGD LOST GENERATION FACTOR = 18X
       MISCELLANEOUS LEAK REPAIRS WERE DONE ON FAN HOUSINGS AND DUCTS.

MAY  70     457           442      0    443    389     394    395
FGD AVAILABILITY FACTOR X  98      0     98     91      92     92
FGD OPERABILITY FACTOR X   97      0     97     85      84     86
FGD UTILIZATION FACTOR X   59      0     59     52      52     53
TOTAL FGD LOST GENERATION FACTOR = 21X
       EXTENSIVE REPAIRS WERE MADE ON THE IB FAN.  ANNUAL BOILER INSPECTION OUTAGE BEGAN UN MAY 20.

JUNE 78       0             000000
FGD AVAILABILITY FACTOR X   0      0    100    100     100    100
FGD OPERABILITY FACTOR X    0      0      0      0       00
FGD UTILIZATION FACTOR X    0      0      0      0       00
TOTAL FGD LOST GENERATION FACTOR = OX
       UNIT OUTAGE TIME WAS FOR BOILER INSPECTION AND GENERATOR STATOR COOLER REPAIRS.

*NOTE: AN ATTEMPT is ALWAYS MADE TO BEGIN OPERATION OF THE BOILER AND FGD SYSTEM SIMULTANEOUSLY AT
       BRUCE MANSFIELD.  OCCASIONALLY PROBLEMS DELAY BOILER START-UP MAKING IT POSSIBLE FOR MONTHLY
       FGD MODULE HOURS TO EXCEED ACTUAL BOILER HOURS.
                                                  66

-------
                                                  EPA UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 197B
                     SECTION  3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
PENNSYLVANIA POWER

BRUCE MANSFIELD 2

SHIPPINGPORT PENNSYLVANIA

 825 MW
    FUEL CHARACTERISTICS  COAL; 4.7X SULFUR,  12.5X ASH

    FGD VENDOR            CHEMICO

    PROCESS               LIME

    NEW OR RETROFIT       NEW

    START UP DATE           7/77
    EFFICIENCY!
     PARTICULATES  (ACTUAL)

                   (DESIGN)

     S02           (ACTUAL)

                   (DESIGN)

    WATER MAKE UP

    SLUDGE DISPOSAL
   99.9 PERCENT

   99.8 PERCENT

   95.0 PERCENT

   92.1 PERCENT

OPEN LOOP

STABILIZED/LANDFILL
    OPERATING EXPERIENCE UPDATE:
MONTH
           BOILER
         OPERATING HOURS
           FGD MODULES
        BCD
NOV. 77     581*          598    584    533    331    304    246
FGD AVAILABILITY FACTOR X 100     96     86     47     55     47
FGD OPERABILITY FACTOR X  100    100     92     57     52     42
FGD UTILIZATION FACTOR X   63     81     74     46     42     34
TOTAL FGD LOST GENERATION FACTOR = 27X
       PROBLEMS ASSOCIATED WITH THE STATION POWER TRANSFORMERS CAUSED LIMITATION IN LOAD ON UNIT 2.
       THREE OF THE SIX STATION TRANSFORMERS FOR UNIT 2 MERE DESTROYED.

DEC. 77     607*          469    638    616    644     513    565
FGD AVAILABILITY FACTOR X  74     99     98    100      89     99
FGD OPERABILITY FACTOR X   77    100    100    100      85     93
FGD UTILIZATION FACTOR X   63     86     83     86      69     76
TOTAL FGD LOST GENERATION FACTOR = 7.4X
       COLD WEATHER CREATED SOME FREEZING PROBLEMS WITH PROCESS PIPING.

JAN. 76     391*          228    564    218    521     481    375
FGD AVAILABILITY FACTOR X  95    100     96     94      99     99
FGD OPERABILITY FACTOR X   58    100     56    100     100     96
FGD UTILIZATION FACTOR X   31     76     29     70      64     50
TOTAL FGD LOST GENERATION FACTOR = 4.3X
       UNIT TRIPPED SEVERAL TIMES DUE TO DIFFICULTIES IN BURNING WET STOCKPILE COAL.  BOILER
       CONTROL VALVE PROBLEMS ("W" VALVE) COMPOUNDED START-UP ATTEMPT DIFFICULTIES.  WHEN THE UNIT
       WAS ON LINE DURING THIS MONTH, THE WET COAL ALSO PREVENTED FULL LOAD OPERATION OF
       COAL MILLS.

FEB. 78     672           321    460    594    460     664    525
F60 AVAILABILITY FACTOR X  84     87     89     97      99     78
FGD OPERABILITY FACTOR X   46     68     88     71      99     78
FGD UTILIZATION FACTOR X   48     66     88     71      99     76
TOTAL FGO LOST GENERATION FACTOR = 16.6 X
       MANY PROBLEMS OCCURRED WITH I.D. FAN COOLERS DUE TO INCLEMENT WEATHER.
                                                  67

-------
EPA UTILITY F60 SURVEY: OCTOBER 1978 - NOVEMBER 1978

PENNSYLVANIA POWER
MONTH
           BOILER
MAR. 78     094*
FGD AVAILABILITY FACTOR X
FGD OPERABILITY FACTOR X
FGD UTILIZATION FACTOR X
502
100
100
 67
 B

409
 93
 91
 60
            OPERATING HOURS
              FGD MODULES
               C      0      E
96
13
10
13
509
 95
100
 68
474
 95
 96
 64
TOTAL F6D LOST GENERATION FACTOR = 28X
       A BOILER TUBE LEAK CAUSED AN OUTAGE FOR SEVERAL DAYS,
       WERE PERFORMED ON THE 2C FAN.

APR. 78     713           583    583    424    108    101
FGD AVAILABILITY FACTOR X 100    100     59     15     14
FGD OPERABILITY FACTOR X   82     83     59     15     14
FGO UTILIZATION FACTOR X   81     81     59     15     14
                                      BRUCE  MANSFIELD  2
487
 97
 99
 65

 EXTENSIVE I.U. FAN HOUSING REPAIRS
                                    96
                                    13
                                    13
                                    13
TOTAL FGD LOST GENERATION FACTOR = 38X
       2B CHIMNEY FLUE LINING REPAIRS BEGAN ON APRIL 5.  EXTENSIVE REPAIRS WERE DONE ON THE 
-------
                                                   EPA UTILITY FGO SURVEY: OCTOttEk  19/8 - NOVEM8EH  1978
                      SECTION  3
   PERFORMANCE DESCRIPTION  FOR  OPERATIONAL FGO  SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
                 PHILADELPHIA ELECTRIC

                 EOOYSTONE 1A

                 EDDYSTONE PENNSYLVANIA

                  120 MW
    FUEL CHARACTERISTICS   COAL;  2.5X  SULFUR,  10*  ASH
    FGD VENDOR

    PROCESS

    NEM OR RETROFIT

    START UP DATE

    EFFICIENCY!
     PARTICULATES  (ACTUAL)
                   (DESIGN)

     302           (ACTUAL)

                   (DESIGN)

    MATER MAKE UP

    SLUDGE DISPOSAL
                 UNITED ENGINEERS

                 MAGNESIUM OXIDE

                 RETROFIT

                  9/75


                    99.9 PERCENT

                    99.9 PERCENT

                    95-97 PERCENT

                    90.0 PERCENT

                 OPEN LOOP 1.1 GPM/MW

                 ACID PLANT REGENERATION
    OPERATING EXPERIENCE UPDATE:
FEB. 76
MAR. 78
APR. 78
MAY  78
JUNE 78
     78
MONTH

AUG. 78
SEP. 78
 THE  TURBINE OVERHAUL CONTINUED DURING THE REPORT  PERIOD.   DURING THE  SHUIDUWN PEHIOD  IT
 HAS  FOUND THAT SOME HIGH PRESSURE STEAM TUBES HERE CRACKED,  SU UNIT  MAINTENANCE:  HAS  TAKEN
 LONGER THAN EXPECTED.  SOME MINOR FGD SYSTEM MODIFICATIONS HAVE BEEN  INCOKPOHATEU  IN  THE
 COURSE OF THE SHUTDOWN PERIOD.  START UP IS EXPECTED IN MID-APRIL 78.

 THE  UNIT JUST CAME BACK ON LINE JUNE 1  AFTER AN EXTENSIVE  SYSTEM MODIFICATION UUTAGE
 WHICH BEGAN DECEMBER 22.  THE UNIT WAS  EXPECTED BACK ON LINE IN MJ.O-APKIL,  BUT THEKE  "AS
 A  PROBLEM WITH A SUPER PRESSURE STEAM TURBINE.

 DURING JUNE THE FGD SYSTEM ACHIEVED A 49X OPERABILITY.   OPERABILITY  FOR  JULY
.WAS  SIX, .PROBLEMS OCCURRED THE LAST WEEK OF JUNE WITH  THE MGS03 SLUKRY  CIRCULATION PUMP
 NHEN THE UTILITY DISCOVERED THE RUBBER  LINER WAS  TORN AWAY.   THEKE HAVE  BEEN  SOME  PROBLEMS
 WITH THE M60 SECTION WHERE THE MGO MIXES WITH THE SYSTEM LIQUOR.  FIKE BRICK  WAS REMOVED
 FROM THE FLUID BED REACTOR CHAMBER TO REPLACE THE ACID  8ARRIOR PLATES  WHICH w£KE FAILING.
 THE  FIRE BRICK WAS THEN REPLACED.  THE  SLOW PIECE BY PIECE PROCEDURE  WAS TIME CONSUMING
 AND  ACCOUNTED FOR MOST OF  THE REGENERABLE FACILITY DOWN TIME (MOST OF  JUNE  AND JULY).
 MAJOR PROBLEMS WERE SOLVED ON THE REGENERATIVE  FACILITY OVER THE PERIOD  RESULTING  IN
 IMPROVED AVAILABILITY OF THE  FACILITY.
  PERIOD
  HOURS
BOILER
HOURS
                               HOURS
FGD SYSTEM PARAMETERS
     OPERABILITY   UTILIZATION
   744       631         240            3BX            32X
 DURING  THE  MONTH  OF  AUGUST  SCRUBBER  CIRCULATING  PIPING  PROBLEMS  MERE  ENCOUNTERED.   A  HUT-
 TERFLY  CONTROL  VALVE WAS NOT  FULLY OPEN  AND  A  SECTION OF  PIPE  DOWNSTREAM  AT  A  9U DEGREE
 BEND ERODED AWAY.  TO CORRECT THE PROBLEM  THE  BUTTERFLY VALVE  WAS  TAKEN UUT  AND REPLACED
 WITH A  RESTRICTION ORIFICE.   THE CIRCULATION PUMPING RATE WAS  ALSO REDUCED.

   720       S16         402            78X            56X
 THE UTILITY REPORTED THAT NO  MAJOR PROBLEMS  WERE  ENCOUNTERED DURING THE MONTH  OF
 SEPTEMBER.   CERTAIN  MECHANICAL  PROBLEMS  WERE RESOLVED WHICH CAUSED AN IMPROVEMENT  IN  THE
 OPERABILITY FIGURE.
                                                  69

-------
EPA UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 1976
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
UTILITY NAME

UNIT NAME

UNIT LOCATION

UNIT RATING

FUEL CHARACTERISTICS  COAL; 0.8X SULFUR, 30X ASH
                          PUBLIC SERVICE OF NEW MEXICO

                          SAN JUAN 1

                          WATERFLOW NEW MEXICO

                               MW
    FGO VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE

    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)

     302          (ACTUAL)

                  (DESIGN)

    WATER MAKE UP

    SLUDGE DISPOSAL
                      DAVY POWtRGAS

                      wELLMAN LORD

                      NEW

                       0/78




                         99.a PERCENT



                         85.0 PERCENT

                      CLOSED LOOP 1.53 GPM/Mw

                      ELEMENTAL SULFUR PRODUCT
    OPERATING EXPERIENCE UPDATE:


FEBRUARY-MARCH 1978 - INITIAL 303 ABSORPTION AT SAN JUAN NO. 1 BEGAN ON APRIL 8, 1978.  FULL CUMMEK-
CIAL OPERATION IS EXPECTED BY LATE JUNE.  THE FGD SYSTEM IS CURRENTLY IN SERVICE WITH two OF Tut
UNIT'S FOUR ABSORBER CELLS OPERATING CONTINUOUSLY.  A THIRD CELL IS TO BE BROUGHT UN LINE LATbK.
THREE CELLS WILL BE REQUIRED FOR FULL LOAD WITH A FOURTH INCLUDED FOR SPARE FGl) CAPACITY.  THE CUR-
RENT MODE IS TO KEEP 2 CELLS IN SERVICE AT ALL TIMES AND 2 OUT OF SERVICE.  2/3 OF THE FLUb GAb
IS BEING TREATED WHILE 1/3 IS BEING BYPASSED.  THE UNIT IS IN COMPLIANCE AT PRESENT WITH KtSPECT TO
302 KITH ONLY 2 CELLS RUNNING BECAUSE THE BISULFITE CONCENTRATION HAS NOT YET BUILT UP IN IHE AH80K-
BENT LIOUOR.  WHEN THE SYSTEM REACHES EQUILIBRIUM WITH RESPECT TO BISULFITE (1BX BISULFITE) THE UNIT
WILL BE READY TO BEGIN REGENERATING OPERATIONS.  REGENERATION IS EXPECTED TO BEGIN BY APRIL 27.

APRIL-MAY 1978 - OVER THE PERIOD THE UTILITY ACCUMULATED 22 DAYS OF DATA DURING WHICH THE BOILER
WAS DOWN FOR 7 HOURS AND THE ABSORBERS WERE DOWN FOR 28 HOURS (UNSCHEDULED).  THE UNIT IS STILL NOT
STABILIZED SO USEFUL FIGURES FOR WATER REQUIREMENTS ARE UNAVAILABLE.  THE CHEMICAL PLANT REMAINS IN
ITS START UP STAGE.

JUNE-JULY 1978 - THE UNIT EXPERIENCED A VERY HIGH PRESSURE DROP ACROSS THE VENTURIS DURING THIS
PERIOD.  AS A RESULT, THE FANS WERE NOT ABLE TO MOVE 100X OF THE FLUE GAS THROUGH THE FGD SYSTEM.

AUGUST-SEPTEMBER 1978 - DURING THIS PERIOD THE HIGH PRESSURE DROP PROBLEM WAS CORRECTED BY MODIFYING
ADJUSTABLE PLUMB BOBS WITHIN THE MODULES TO BE FARTHER AWAY FROM THE VENTURIS.  THIS IMPROVED THE
GAS FLOW AND REDUCED THE PRESSURE DROP.  THE UTILITY ANTICIPATES THAT THEY WILL NOW BE ABLE TO SCRUB
100X OF THE FLUE GAS.  IN ORDER TO PERFORM THESE MODIFICATIONS AT LEAST TWO MODULES WERE DOWN AT ALL
TIMES THROUGHOUT THE PERIOD.  MIST ELIMINATOR REPAIRS WERE ALSO MADE WHILE THE MODULES WERE DOWN.
THERE WAS A TWO WEEK BOILER OUTAGE IN SEPTEMBER CAUSED BY A FIRE IN THE START-UP TRANSFORMER DUCT
BANK.  HOURS OF OPERATION FOR THIS NEWLY OPERATIONAL UNIT ARE NOT YET AVAILABLE.

OCTOBER-NOVEMBER 1978 - THE UTILITY REPORTED THAT THE UNIT IS STILL CONSIDERED  IN THE START-UP PHASE
AND NO HOURS OF OPERATION ARE AVAILABLE.  THE ONLY PROBLEM REPORTED WAS LINE FREEZING DUE TO HEAT
TRACING FAILURES.  SOME SULFUR PRODUCT HAS BEEN PRDUCED BUT THE REGENERATION FACILITY IS ALSO IN
THE START-UP PHASE AND NO OPERATIONAL DATA IS AVAILABLE.
                                                  70

-------
                                                  EPA UTILITY FGD 3UKVEY: UCTOBEK 1978 - NOVEMBEK 1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS


    UTILITY NAME          PUBLIC SERVICE OF NEW MEXICO

    UNIT NAME             SAN JUAN 2

    UNIT LOCATION         WATERFLOW NEW MEXICO

    UNIT RATING            306 MW

    FUEL CHARACTERISTICS  COAL; 0.8X SULFUR, SOX ASH

    FGD VENDOR            DAVY POWERGAS

    PROCESS               WELLMAN LORD

    NEW OR RETROFIT       RETROFIT

    START UP DATE          8/76

    EFFICIENCY:
     PARTICULATES (ACTUAL)

                  (DESIGN)   99.5 PERCENT

     302          (ACTUAL)

                  (DESIGN)   85.0 PERCENT

    WATER MAKE UP         CLOSED LOOP

    SLUDGE DISPOSAL       ELEMENTAL SULFUR PRODUCT



    OPERATING EXPERIENCE UPDATE:


AUGUST-SEPTEMBER 1978 - INITIAL OPERATIONS BEGAN AT THIS UNIT LATE IN AUGUST.  ALL THREE MODULES
RAN TOGETHER AT FULL CAPACITY FOR THE FIRST TIME IN SEPTEMBER.  A TWO WEEK BOILEK OUTAGE OCCUKKED IN
SEPTEMBER AS A RESULT OF A FIRE IN THE START-UP TRANSFORMER DUCT BANK.  PROBLEMS WERE ALSO ENCOUN-
TERED WITH THE BOOSTER FAN CONTROL DAMPER.  DUE TO THE RECENT OPERATING STATUS (If THIS SYSTEM
HOURS OF OPERATION ARE NOT YET AVAILABLE.

OCTOBER-NOVEMBER 1978 - THE UNIT IS STILL IN THE STARTUP-DEBUGGING STAGE AND NO OPERATIONAL HOURS
ARE AVAILABLE.  PROBLEMS ENCOUNTERED INCLUDED LINE FREEZING DUE TO HEAT TRACING FAILURES AND A
TEMPORARY HIGH FLYASH LOADING DUE TO AN ESP MALFUNCTION.
                                                  71

-------
EPA UTILITY FGD SURVEY: OCTOBEK 1978 - NOVEMBER 1<»78


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS


    UTILITY NAME          SOUTH CAROLINA PUBLIC SERVICE

    UNIT NAME             WINYAH 2

    UNIT LOCATION         GEORGETOWN SOUTH CAROLINA

    UNIT RATING            580 MW

    FUEL CHARACTERISTICS  COAL? l.OX SULFUR, 19X ASH

    FGO VENDOR            BABCOCK ft WILCOX

    PROCESS               LIMESTONE

    NEW OR RETROFIT       NEW

    START UP DATE          7/77

    EFFICIENCY:
     PARTICULATES (ACTUAL)   99.1 PERCENT

                  (DESIGN)   99. 
-------
                                                  EPA UTILITY FGD SURVEY: UCTOBEK 197B - fiUVfcMBEk 1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS


    UTILITY NAME          SOUTHERN MISSISSIPPI ELECTRIC

    UNIT NAME             R. D. MORROW 1

    UNIT LOCATION         HATTIESBURG MISSISSIPPI

    UNIT RATING            180 MW

    FUEL CHARACTERISTICS  COAL; IX SULFUR, 8X ASH

    FGD VENDOR            RILEY STOKER / ENVIRONEERING

    PROCESS               LIMESTONE

    NEW OR RETROFIT       NEW

    START UP DATE          8/78

    EFFICIENCY!
     PARTICULATES (ACTUAL)

                  (DESIGN)   99.6 PERCENT

     303          (ACTUAL)

                  (DESIGN)   85 PERCENT GUARANTEE

    WATER MAKE UP

    SLUDGE DISPOSAL       STABILIZED/LANDFILL



    OPERATING EXPERIENCE UPDATE:


AUGUST-SEPTEMBER 1978 - INITIAL OPERATIONS AT THIS UNIT BEGAN IN AUGUST  1978.  A FORCED bOILEK OUT-
AGE OCCURRED DURING THE PERIOD AS A RESULT OF BOILER TOBE LEAKS.  THE UNIT IS EXPECTtO BACK UM LI*t
BY THE FIRST OF NOVEMBER.  DUE TO THE RECENT OPERATING STATUS OF THIS SYSTEM HUUHS OF OPEHATIOiM AWE
NOT YET AVAILABLE.

OCTOBER-NOVEMBER 1978 - DURING OCTOBER OPERATION OF THE UNIT WAS INTERMITTENT DUE TO CONTINUING
BOILER TUBE PROBLEMS.  THE FGD SYSTEM WAS BYPASSED ENTIRELY  IN OCTOBER DUE TO SERIOUS CONTROL
VALVE PLUGGING.  THE UTILITY IS IN THE PROCESS OF FINDING A  SOLUTION TO  THE VALVE
PROBLEM.  THE BOILER WAS SHUT DOWN AGAIN THE FIRST OF NOVEMBER DUE TO BOILER TUBE PROBLEMS.
RESUMPTION OF OPERATION OF THE UNIT IS SCHEDULED FOR MARCH 1979.
                                                  73

-------
EPA UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 1978
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
                   SPRINGFIELD CITY UTILITIES

                   SOUTHWEST 1

                   SPRINGFIELD MISSOURI

                    aoo MW
    FUEL CHARACTERISTICS  COALJ 3.SX SULFUR, 13X ASH
    FGD VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE

    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)

     SOS          (ACTUAL)

                  (DESIGN)

    MATER MAKE UP

    SLUDGE DISPOSAL
                   AIR CORRECTION DIVISION, UOP

                   LIMESTONE

                   NEW

                    4/77


                      99.8 PERCENT

                      99.7 PERCENT

                      92.0 PERCENT

                      80.0 PERCENT



                   UNSTABILIZED/LANOFILL
    OPERATING EXPERIENCE UPDATE:
FEB. 78
MAR. 78
       THE ABSORBERS DID NOT OPERATE DUE TO AN EXPANSION JOINT FAILURE BETWEEN THE ID FAN AND
       THE ABSORBERS.  CURRENTLY, THE ABSORBERS ARE BEING BY-PASSED.  THE FGD SYSTEM IS EXPECTED TO
       BE BACK ON LINE BY THE END OF APRIL.
APR. 78
MAY  78
JUNE 78
THE UNIT EXPERIENCED AN FRP LINER FAILURE AS WELL AS A PUMP FAILUKE DURING THE PERIOD.
CURRENTLY ONLY ONE SCRUBBER-ABSORBER MODULE IS RUNNING.  THE EXPANSION JOINT FAILURE
MENTIONED PREVIOUSLY WAS DIRECTLY RELATED TO THE DAMPER FAILURE WHICH ALLOWED THE BOILER
TO CONTINUE PUMPING GAS TO THE SEALED OFF FGD SYSTEM.


THE A-MODULE RAN STEADILY FOR OVER 11 DAYS.  B-MOOULE WAS STILL DOWN WITH EXPANSION JOINT
PROBLEMS.  DURING THE MONTH THE MIST ELIMINATOR WASH SYSTEM WAS ALTERED FROM A SEPARATE
CLOSED LOOP FOR EACH MODULE TO A COMMON SYSTEM FOR BOTH MODULES.  THE NEW SYSTEM TAKES SUPER-
NATANT FROM THE TOP OF THE THICKENER FOR MIST ELIMINATOR SPRAY.  INSTRUMENTATION PROBLEMS
HERE ENCOUNTERED DURING THE MONTH.  PH PROBES WERE LOST, THE MAG-FLOW METER FOR LIMESTONE
SLURRY FAILED, AND THE AUTOMATIC GAS ANALYZERS DID NOT OPERATE PROPERLY.  SOME PIPES PLUGGED
DUE TO NEOPRENE PEELING FROM VALVES.  THE SLUDGE SYSTEM EXPERIENCED SOME FILTER BELT PROBLEMS
BUT THESE MERE REPAIRED.
                                                  74

-------
SPRINGFIELD CITY UTILITIES
                                                  EPA UTILITY FGD SURVEY: OCTOBER  1978 - NOVEMBER

                                                                                       SOUTHWEST  1
MONTH
        BOILER
                     OPERATING HOURS
                 A-SIOE   B-SIDE   TOTAL
  FORCED OUTAGE TIME
A-SIDE   B-SIDE   TOTAL
MEGA^ATT-HUUk
 PRODUCTION
                                                                1364
                                                                            101,1B8
JULY 78   744      124        0     124        620      704
AVAILABILITY = 8X
OPERABILITY = 8X
RELIABILITY - 8X
UTILIZATION = 8*
       DURING THE MONTH PROBLEMS WERE ENCOUNTERED WITH THE MODULE  A  TRANSFER PUMPS.   NK.E  DAYS  >-.EwE
       REQUIRED TO TKACE THE ELECTRICAL PROBLEM.  A  17 DAY OUTAGE  WAS CAUSED BY PROBLEMS  rtlTH  THE
       BALL MILL AIR SUPPLY WHICH RESULTED  IN THE UNAVAILABILITY OF  SLURHY.  B-MOOULE  WAS  STILL  DOWN
       WHILE THE UTILITY WAITED FOR THE REPLACEMENT  EXPANSION JOINT.  WORK AAS DUNE  DURING  THE  MONTH
       TO IMPROVE THE INSTRUMENTATION.  IT  HAS DISCOVERED THAT MANY  OF  THE PROBLEMS  rtEHE  DUE  Tu
       SCALE ACCUMULATION ON THE PROBES.

AUG. 78   744      439        0     439        305      744    1049         01,622
AVAILABILITY = 30X
OPERABILITY = 30X
RELIABILITY   30X
UTILIZATION = 30X
       THE B-MODULE REMAINED DOWN THROUGHOUT AUGUST  BECAUSE  THE REPLACEMENT EXPANSION  JOINT HAD  rj()T
       YET ARRIVED.  EXPANSION JOINT REPAIR WAS REUUIREO ON  THE A-MODULE.  PROBLEMS  nlTH  THE
       THICKENER AND PLUGGED LINES CAUSED  A-MODULE  OUTAGES  TOTALING  211  HOURS.
       ULED OUTAGES.
                                                                                 THERE
                                                                                            NO  SCHED-
SEP. 78   557      159         0      159         348       720     1118          68,569
AVAILABILITY - 11X
OPERABILITY = 14X
RELIABILITY = 14X
UTILIZATION = 11X
       CONTINUATION OF  THE  EXPANSION JOINT  PROBLEM  RESULTED  IN  THE B-MODULE  REMAINING  DU*N  THROUGH-
       OUT THE MONTH.   A-MODULE  DOWN TIME WAS  DUE  TO  PLUGGING OF  THE  THICKENER  SLURRY  MAKEUP  LINES
       AND FAILURE OF  THE BALLS  WITHIN  THE  MODULE.
       RUBBER BALLS.
                                                     THE  PING  PONG  BALLS  HERE  REPLACED  «ITH  SOLID
OCT. 78    26        0         00           0         00
       THE BOILER WAS DOWN  FOR  A  SCHEDULED  OUTAGE DURING  THE  MONTH.   CONSIDERABLE  CLEANING
       OF THE A-MODULE WAS  DONE AS  THE LOWER  THO  LEVELS OF  THE  MODULE HAD  BEGUN  TO PLUG  WHEN  THE
       BALLS FAILED  (SEE  SEPTEMBER  1978).   A  THOROUGH  CLEANING  OF  THE ENTIRE  FGD  SYSTEM  «AS  ALSO
       DONE.  A BEARING WAS REPLACED  ON  THE SLURRY  DRAW OFF PUMP.   THE OUTLET  DUCT WAS CLEANED  AND
       PLASITE INSTALLED.   REPAIR WAS MADE  TO  THE BYPASS  DUCT  TOGGLE  DUE  TU METAL  DETERIORATION.
       ALL DAMPERS WERE SERVICED, REPAIRED  AND  EXERCISED.   THE  RUBBER COATING  ON  HOLD  TANK  AGITATORS
       AND SLURRY STORAGE TANK  AGITATOR  WERE  REPAIRED.
                             161
                                     624
                                                 32
                                                         273
                                                                 605
                                                                             72,697
NOV. 78   716      463
AVAILABILITY = 51%
OPERABILITY = 44X
RELIABILITY e 44X
UTILIZATION = 43X
       THE BOILER OUTAGE LASTED  INTO  THE  FIRST  PART  OF  NOVEMBER.  AN  FGD  OUTAGE  WAS  CAUSED  BY  A  FAN
       BEARING FAILURE ON MODULE B.
                                                   75

-------
EPA UTILITY F60 SURVEY: OCTOBER 1978 - NOVEMBER 1978
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL F60 SYSTEMS
    UTILITY NAME          TENNESSEE VALLEY AUTHORITY
    UNIT NAME             SHANNEE IDA
    UNIT LOCATION         PADUCAH KENTUCKY
    UNIT RATING             10 MM
    FUEL CHARACTERISTICS  COAL; 2.9X SULFUR,  15.8X ASH
    F60 VENDOR            AIR CORRECTION DIVISION, UOP
    PROCESS               LIME/LIMESTONE
    NEW OR RETROFIT       RETROFIT
    START UP DATE          4/72
    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)    EXPERIMENTALLY CONTROLLED
     502          (ACTUAL)
                  (DESIGN)    EXPERIMENTALLY CONTROLLED
    HATER MAKE UP         EXPERIMENTALLY CONTROLLED
    SLUDGE DISPOSAL       EXPERIMENTALLY CONTROLLED

    OPERATING EXPERIENCE UPDATE:
       REFER TO OPERATING EXPERIENCE UPDATE FOR SHAWNEE NO. 10B.
                                                  76

-------
                                                  EPA UTILITY FGD SURVEY: OCTOBE*  1978 - NOVEMBER  197B
                      SECTION  3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10B
PADUCAH KENTUCKY
  10 MW
    FUEL CHARACTERISTICS  COAL;  2.9X SULFUR,  15.8X ASH
    F6D VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE

    EFFICIENCY!
     PARTICULATES  (ACTUAL)
                   (DESIGN)

     302           (ACTUAL)

                   (DESIGN)

    WATER MAKE UP

    SLUDGE DISPOSAL
CHEMICO

LIME/LIMESTONE

RETROFIT

 4/72




   EXPERIMENTALLY CONTROLLED



   EXPERIMENTALLY CONTROLLED

EXPERIMENTALLY CONTROLLED

EXPERIMENTALLY CONTROLLED
    OPERATING EXPERIENCE UPDATE:


FEB. 78   MAJOR SYSTEM DOWNTIMES DURING  THE PERIOD INCLUDED: JANUARY 26 THROUGH FEBRUARY a FUR THE
MAR. 78   VENTURI/SPRAY TOWER AND JANUARY 26  THROUGH FEBRUARY 2 FOR THE TCA SYSTEM DUE TO FREEZING
          WEATHER, AND MARCH 6 THROUGH MARCH  17 FOR BOTH SYSTEMS DUE TO BOILER OUTAGE.
          THE EFFECT OF THE SLURRY LEVEL IN THE AIR SPARGED OXIDATION TANK WAS INVESTIGATED IN THE
          TWO SCRUBBER LOOP VENTURI/SPRAY TOWER SYSTEM WHICH IS OPERATING ON LIME SLURRY WITH HIGH
          FLY ASH LOADING.  NEAR COMPLETE SULFITE OXIDATION (98 PERCENT) WAS ACHIEVED WITH 1
-------
EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 1978

TENNESSEE VALLEY AUTHORITY
SHAHNEE 10A AND 10B
          TOWER.  MGO HAS ADDED TO THE EFFLUENT HOLD TANK TO MAINTAIN AN EFFECTIVE MG + + ION CONCEN-
          TRATION OF 5000 PPM.  A SLURRY STREAM WAS TAKEN FROM THE SCRUBBER DOWNCOMEK ANO SENT  TO
          AN OXIDATION TANK INTO WHICH AIK WAS SPAKGED.  A RECYCLE STREAM OF ABOUT so GPM HAS SENT
          BACK FROM THE OXIDATION TANK TO THE EFFLUENT HOLD TANK TO CONTROL PH IN THE OXIDATION TANK
          ANO TO PROVIDE GYPSUM SEEDS IN THE SCRUBBER SLURRY.  FINAL SYSTEM BLEEU WAS WITHDRAWN FKUM
          THE OXIDATION TANK.  AT AN AVERAGE OXIDATION TANK PH OF 6, SULFITE OXIDATION AVERAGED 98
          PERCENT.  FILTER CAKE SOLIDS CONTENT WAS as PERCENT, SIMILAR TO THAT OBTAINED WITH TWO
          SCRUBBER LOOP OPERATIONS.  HOWEVERi THE SLURRY SOLIDS SETTLING RATE HAS ONLY ABOUT
          0.4 CM/MIN, COMPARED TO ABOUT 0.8 CM/MIN FOR THE TWO LOOP OPERATION.  SETTLING HATE FOR
          UNOXIOIZED SLURRY CONTAINING MAGNESIUM ION NORMALLY DID NOT EXCEED 0.1 CM/MIN WITH 50 TO
          60 PERCENT FILTER CAKE SOLIDS.
          TCA CONTINUED TO OPERATE WITH MGO ADDITION WITH BOTH LIME AND LIMEST.ONE SCRUBBING.  FLUE
          GAS WITH HIGH FLY ASH LOADING WAS USED.  THE INTENT OF THESE TESTS WAS TO CLARIFY SOME OF
          THE INCONSISTENT RESULTS OBTAINED DURING EARLIER RUNS MADE IN APRIL-NOVEMBER 1976, DURING
          WHICH SCRUBBER DOWNCOMER AIR LEAKAGE HAS SUSPECTED IN SOME OF THE TESTS.  IN GENERAL,
          TESTS RUNS MADE IN 1976 HAD HIGHER INLET S03 CONCENTRATION, MOSTLY GREATER THAN 3000  PPM,
          WHILE THE RECENT RUNS HAD ONLY ABOUT 3500 PPM.  AT THE HIGHER INLET 803 AND THE HIGHER
          RESULTANT SOa MAKE-PER-PASS, THE 1976 TESTS OPERATED EITHER UNSATURATED UR SUPERSATURATED
          WITH RESPECT TO GYPSUM, DEPENDING UN THE SULFITE OXIDATION LEVEL.  SEVERE GYPSUM SCALING
          OCCURRED WHEN THE OPERATION WAS UNDER GYPSUM-SATURATED MODE.  IN THE RECENT RUNS, OPERA-
          TION WAS MOSTLY UNDER GYPSUM-SATURATED MODE.  HOWEVER, BECAUSE OF THE LOHEK INLET SOS AND
          LOWER 803 MAKE-PER-PASi, THE GYPSUM SATURATION LEVELS WERE NOT HIGH ENOUGH TU CAUSE ANY
          SIGNIFICAN1 SCALING.

JUNE 78   FORCED OXIDATION ON THE BLEED STREAM FROM THE VENTURI/SPRAY TOWER SYSTEM CONTINUED THROUGH
JULY 78   MID-JUNE.  TWO TEST RUNS WERE MADE IN WHICH MGO WAS ADDED TO MAINTAIN AN EFFECTIVE MG++
          CONCENTRATION OF 5000 PPM IN THE SCRUBBER SLURRY ANO NO RECYCLE STREAM WAS SENT BACK  FROM
          THE OXIDATION TANK (8 FT DIAMETER AND 18 FT TANK LEVEL) TO THE EFFLUENT HOLD TANK.  AVER-
          AGE SULFITE OXIDATION HAS 96 PERCENT OR HIGHER AT AN AIR STOICHIOMETKIC RATIO OF l.h
          ATOMS OXYGEN/MOLE SO? ABSORBED.  THE OXIDATION TANK PH WAS 5.4 TU 5.6, ONLY O.a UNIT
          HIGHER THAN THE EFFLUENT HOLD TANK PH.  THE FILTER CAKE SOLIDS WAS 85 PERCENT AND THE
          THE SOLIDS SETTLING RATE WAS 0.4 TO 0.5 CM/MIN.
          BOTH SCRUBBER SYSTEMS WERE SHUT DOWN FOR TWO WEEKS FROM JUNE 19 DUE TO A BOILER OUTAGE
          SCHEDULED FOR RE-ROUTING THE FLUE GAS DUCT FROM THE 800-FT STACK TO THE NO. 11 SMALL
          STACK.
          FOLLOWING THE BOILER OUTAGE, BOTH SCRUBBER SYSTEMS STARTED ON NEW LIME AND LIMESTONE  TEST
          BLOCKS IN WHICH AOIPIC ACID, AN ORGANIC ACID PH BUFFER, WAS ADDED TO THE SCRUBBER SLURRY
          TO IMPROVE 803 REMOVAL EFFICIENCY.
          INITIAL TEST RUNS WERE CONDUCTED WITHOUT ADIPIC ACID ADDITION TO ESTABLISH THE BASE CASE
          soa REMOVAL IN BOTH LIME AND LINESTONE SCRUBBING FOR BOTH SCRUBBER SYSTEMS.  THE VENTUHI/
          SPRAY TOWER SYSTEM WAS OPERATED WITH TWO-SCRUBBER-LOOP CONFIGURATION WITH FORCED OXIDATION
          IN THE FIRST LOOPf WHILE THE TCA WAS OPERATED IN A ONE-SCRUBBER-LOOP SCHEME WITHOUT FORCED
          OXIDATION.
          PRELIMINARY RESULTS SHOWED THAT 96 TO 99 PERCENT S02 REMOVAL WAS CONSISTENTLY ACHIEVED IN
          THE VENTURI/SPRAY TOWER SYSTEM OPERATING WITH ABOUT 1600 PPM AND 1400 PPM ADIPIC ACID IN
          THE VENTURI AND SPRAY TOWER, RESPECTIVELY.  THESE S02 REMOVALS COMPARE VERY FAVORABLY WITH
          THE 66 PERCENT REMOVAL FOR THE BASE CASE LIME RUN WITHOUT ADIPIC ACID.  ON THE TCA SYSTEM,
          A LIME RUN WITH ABOUT 400 PPM ADIPIC ACID GAVE ABOUT 80 PERCENT S03 REMOVAL, COMPARED TO
          67 PERCENT FOR THE BASE CASE RUN.

AUG. 78   TESTING WITH ADIPIC ACID AS ADDITIVE FOR IMPROVING 502 REMOVAL EFFICIENCY CONTINUED
SEP. 78   THROUGH AUGUST AND SEPTEMBER.  BOTH VENTURI/SPRAY TOWER AND TCA SYSTEMS WERE OPERATED ON
          LIMESTONE SLURRY WITH HIGH FLYASH LOADING DURING THIS PERIOD.  THE TCA WAS OPERATED
          WITHOUT FORCED OXIDATION AND THE VENTURI/SPRAY TOWER WITH THO-SCRUBBER-LOOP FORCED OXIDA-
          TION.  AS IN THE LIME TESTS WITH ADIPIC ACID ADDITION CONDUCTED IN JULY, SIGNIFICANT
          IMPROVEMENT IN S02 REMOVAL EFFICIENCY WAS ALSO OBSERVED IN THE LIMESTONE TESTS.
          UNDER TYPICAL OPERATION, S03 REMOVAL HIGHER THAN 90 PERCENT COULD BE ACHIEVED BY THE
          VENTURI/SPRAY TOWER WITH ABOUT 3100 PPM AND 1500 PPM ADIPIC ACID IN THE VENTURI ANO SPRAY
          TOWER, RESPECTIVELY.  UNDER THE SAME OPERATING CONDITIONS BUT WITHOUT ADIPIC ACID, THE SOS
          REMOVAL WAS ONLY 57 PERCENT.  THE SULFITE OXIDATION EFFICIENCY AND WASTE SLUDGE DEWATERING
          PROPERTIES DID NOT APPEAR TO BE AFFECTED BY THE PRESENCE OF ADIPIC ACID.
          IN THE TCA, HIGHER THAN 90 PERCENT 303 REMOVALS WERE OBTAINED WITH 750 TO 1500 PPM ADIPIC
          ACID, COMPARED TO 71 PERCENT REMOVAL FOR A BASE CASE RUN WITHOUT ADIPIC ACID.
          IN BOTH SCRUBBER SYSTEMS, THE PH IN THE SCRUBBER SLURRY NEEDS TO BE HIGHER THAN ABOUT 5.0,
          THE UPPER PH BUFFER POINT OF ADIPIC ACID, FOR THIS PARTICULAR ADDITIVE TO BE FULLY
          EFFECTIVE.
          DETERIORATION OR DECOMPOSITION OF ADIPIC ACID APPARENTLY TAKES PLACE IN THE SCRUBBER.
          ACTUAL FEED RATES OF ADIPIC ACID WERE Z TO 3 TIMES HIGHER THAN COULD BE ACCOUNTED FOR IN
          THE SYSTEM DISCHARGE SLUDGE.
                                                  78

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                                                  EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 1978

TENNESSEE VALLEY AUTTHORITY                                     SHANMEE  IDA  AND  108

OCT. 76   A ONE MONTH LONG-TERM RELIABILITY RUN WAS CONDUCTED ON BOTH THE VENTURI/SPRAY FUrtEK AND
NOV. 78   THE TCA SYSTEMS USING LIMESTONE SLURRY WITH AOIPIC ACIO AS AN  ADDITIVE FOR ENHANCING SU«2
          REMOVAL EFFICIENCY.  STEADY-STATE 302 REMOVAL IN BOTH RUNS WAS CONSISTNTLY HIGH IN THE
          RANGE OF 96 TO 99 PERCENT UNDER TYPICAL OPERATING CONDITIONS.  THE VENTURI/SPRAY TOWER
          SYSTEM MAS OPERATED WITH TWO-SCRUBBER-LOOP FORCED OXIDATION.   AOIPIC ACID CONCENTRATIONS
          WERE 1500 PPM IN THE TCA AND THE SPRAY TOWER. AND 2400 PPM IN  THE VENTUHI.  BOTH SCRUBBER
          SYSTEMS OPERATED FREE OF SCALING AND PLUGGING.
          LONG-TERM TESTS BEGAN IN MID-NOVEMBER TO COMPARE CONVENTIONAL  LIME SCRUBBING WITH ADVANCED
          LIMESTONE SCRUBBING USING CHEMICAL ADDITIVES AND FORCED OXIDATION.  EACH TEST WILL LAST
          ONE MONTH OR LONGER.  THE VENTURI/SPRAY TOWER IS BEING OPERATED WITH TwO-SCRUBBER-LOUP
          FORCED OXIDATION AND WITH LIMESTONE SLURRY AND ADIPIC ACID ADDITION.  THE TCA SYSTEM IS
          BEING OPERATED WITH LIME SLURRY (NO ADDITIVE) AND WITHOUT FORCED OX1DAUON.  DUKING THESE
          TESTS CONTINUOUS SOS EMISSIONS MONITORING PROCEDURES WILL BE ASSESSED.
                                                   79

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EPA UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 1978
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
    UTILITY NAME

    UNIT NAME

    UNIT LOCATION

    UNIT RATING
                          TENNESSEE VALLEY AUTHORITY

                          WIDOWS CREEK 8

                          BRIDGEPORT ALABAMA

                           550 MW
    FUEL CHARACTERISTICS  COAL; 3.7X SULFUR, 17X ASH
    FGD VENDOR

    PROCESS

    NEW OR RETROFIT

    START UP DATE

    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)

     802          (ACTUAL)

                  (DESIGN)

    HATER MAKE UP

    SLUDGE DISPOSAL
                          TENNESSEE VALLEY AUTHORITY

                          LIMESTONE

                          RETROFIT

                           5/77


                             99.5* PERCENT

                             99.5 PERCENT

                             85-94 PERCENT

                             80.0 PERCENT



                          STABILIZED/SLUDGE POND
    OPERATING EXPERIENCE UPDATE:
MONTH   BOILER   A-SIDE
                           OPERATING HOUHS
                          B-SIDE   C-SIDE   D-SIDE
                  COMMENTS
                            401
                                     370
                                              314
THE OUTAGE TIME FOR 1RAINS A AND B WAS KEUUIR-
ED TO REPLACE THE RUBBER LINEkS IN THE UUrtN-
COMER AREA WITH STAINLESS STtEL.  THIS WILL BE
DONE TO THE REMAINING TWU TRAINS AS WELL.
FEB. 78   586      171
AVAILABILITY « 55X
OPERABILITY = 54Z
RELIABILITY = 61X *
UTILIZATION = 47X
  * THE UTILITY REPORTED THAT THEY COULD NOT ACCURATELY DETERMINE RELIABILITY BECAUSE OF THEIR
INABILITY TO CALCULATE UNIT LOAD DEMAND ON A DAILY BASIS.  GENERALLY, IT IS ASSUMMEO THAT SYSTEM
FORCED OUTAGE HOURS PLUS THE HOURS FGD SYSTEM OPERATED WILL GIVE ROUGHLY THE HUURS THE SYSTEM WAS
CALLED UPON TO OPERATE.  IN THIS WAY,  RELIABILITY CAN BE CALCULATED INDIRECTLY.  HOWEVER, IN THIS
CASE, TNO TRAINS AT A TIME HAVE BEEN DOWN ON A SCHEDULED OUTAGE FOR NECESSARY MODIFICATIONS.  PART
OF THIS OUTAGE TIME LIMITED BUILER OPERATION SO THAT THE UNIT COULD NOT RUN AT FULL LOAD WHEN THERE
HAS A DEMAND FOR FULL LOAD.  FOR THIS  CALCULATION IT WAS ASSUMMED THAT THERE WAS A DEMAND FOR FULL
LOAD DURING THE ENTIRE SCHEDULED OUTAGE SO THAT ALL OF THE TRAINS WOULD HAVE BEEN CALLED THE ENTIRE
SCHEDULED OUTAGE.  THE RESULT WAS A VERY CONSERVATIVE ESTIMATE OF RELIABILITY WHERE HOURS CALLED
• SYSTEM FORCED OUTAGE HOURS » SYSTEM  SCHEDULED OUTAGE + HOURS THE FGD SYSTEM OPERATED.
  NOTEI THIS IS A PEDCO ESTIMATE.
MAR. 76   644      585
AVAILABILITY a 60X
OPERABILITY * 66X
RELIABILITY s 59X *
UTILIZATION * 58X
                            344      199      583     TRAIN B WAS OUT OF SERVICE MARCH 1 - MARCH 13
                                                      TO INSTALL STAINLESS STEEL IN THE ABSORBER AND
                                                      VENTURI OOWNCOMER AREAS.  STAINLESS STEEL
                                                      COVERS WERE INSTALLED ARUUND 1*0 EXPANSION
                                                      JOINTS ON TRAIN C, IN ORDER TO PREVENT FLUE
                                                      GAS LEAKAGE FROM THE EXPANSION JOINTS.  A
                                                      STAINLESS STEEL PLATE WAS WELDED OVEK THE
                                                      ENTRY DOOR OPENINGS TO TRAIN C OUTLET AND
                                                      BYPASS GUILLOTINE DAMPERS FOK THE PURPOSE
                                                      OF ELIMINATING GAS LLAKAGE.  TRAIN c WAS OUT
                                                      OF SERVICE MARCH 14 - MAKCH 39 TU INSTALL
                                                      STAINLESS STEEL IN THE ABSORBER AND VENTUHI
                                                      DOWNCUMER AREAS.  SEVERAL LIFTER BARS ON THE
                                                      FEED AND DISCHARGE ENDS OF THE HALL MILL WEHE
                                                      FOUND TO BE BADLY wOKN.  THE UTILITY HAS HAD
                                                      WEAR PROBLEMS WITH THE SLURRY SUMP PUMP
                                                      LINERS AT THE BALL MILL.
                                                  80

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                                                   EPA  UTILITY  FGD  SURVEY:  OCTUbEk  1978  -  NUVt^BKK

TENNESSEE VALLEY AUTHORITY                                       wlOOwS CREEK  a

MONTH   BOILER   A-SIOE   B-SIDE   C-SIOE    0-SIDE                      COMMENTS

APR. 78   540      480      464       576       375      DURING  A BRIEF  INSPECTION UF THE  SCKUKBEK  IN
AVAILABILITY = 691                                     EARLY  APRIL,  SOLIDS  DEPOSITION hAS  NOTICED IN
OPERABILITY a 83X                                      THE  MIST ELIMINATOR  SECTION  OF ALL  TWAINS  HE-
RELIABILITY 3 67X *                                    CAUSE  OF PLUGGING THAT  HAD  OCCUKHEU IN  SEVERAL
UTILAZATION a 62X                                      OF  THE  MIST  ELIMINATOR  SPRAY NOZZLES.   TKAIU 0
                                                       rtAS  NOT  IN OPERATION FOR  17  DAYS.  DURING  THIS
                                                       PERIOD  THE MIST ELIMINATOR  HAS D ISSASShMBLED
                                                       BY  SECTIONS  AND CLEANED.   A  STAINLESS  STEEL
                                                       LINER  HAS INSTALLED  ON  THE  SLOPING  AREAS OF
                                                       THE  ABSORBER AND VENTURI.  STAlULKSS STEEL
                                                       PLATES  WERE  INSTALLED OVER  THE ENTRY DOOR
                                                       OPENINGS TO  TRAIN D  INLET,  OUTLET,  AND  BYPASS
                                                       GUILLOTINE DAMPERS TO REDUCE GAS  LEAKAGE FROM
                                                       THE  ENTRY DOOR  OPENINGS.   STAINLESS STEEL
                                                       COVERS  WERE  INSTALLED AROUND THE  FIVE  EXPAN-
                                                       SION JOINTS  ON  TRAIN D, TwU  tXPANSION  JUINTS
                                                       ON  TRAIN A,  AND ONE  EXPANSION JOINT ON  TKA1N
                                                       8,  TO  REDUCE GAS LEAKAGE  TO  1HE ATMUSPHEKE.
                                                       THERE  CONTINUES TO BE A WEAR PROBLEM «ITH  PUMP
                                                       LINERS  AT THE BALL MILL.   NO CAOSE  OR  SOLUTION
                                                       OF  THE  PROBLEM  HAS BEEN ASCERTAINED AS  YET.
                                                   81

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EPA UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS


    UTILITY NAME          TEXAS UTILITIES

    UNIT NAME             MARTIN LAKE 1

    UNIT LOCATION         TATUM TEXAS

    UNIT RATING            793 MW

    FUEL CHARACTERISTICS  COAL; 0.9X SULFUR, 8Z ASH

    FGD VENDOR            RESEARCH COTTRELL

    PROCESS               LIMESTONE

    NEW OR RETROFIT       NEW

    START UP DATE          8/77

    EFFICIENCY:
     PARTICULATES (ACTUAL)   99* PERCENT

                  (DESIGN)   99.a PERCENT

     302          (ACTUAL)   73.9 PERCENT

                  (DESIGN)   70.5 PERCENT

    WATER MAKE UP

    SLUDGE DISPOSAL       BLENDED/SLUDGE POND



    OPERATING EXPERIENCE UPDATE:


FEBRUARY-MARCH 1978 - CERTIFICATION WAS RECEIVED FROM THE EPA FOR THIS UNIT.  THE BOILEH AND
FGD SYSTEM OPERATED THROUGHOUT THE PERIOD.  THE UTILITY IS STILL HAVING SOME PROBLEMS
WITH THE SLURRY HANDLING SYSTEM, AND SOME FORCED OUTAGE TIME OCCURRED.

APRIL-MAY 1978 - THIS UNIT WAS TAKEN OFF LINE IN APRIL FOR AN ANNUAL TWO WEEK OUTAGE.  GENERATOR
PROBLEMS WERE ENCOUNTERED IN MAY CAUSING THE UNIT TO BE TAKEN OFF LINE THROUGH THE END OF THE MONTH.

JUNE-JULY 1978 - THE SYSTEM IS NOW RUNNING COMMERCIALLY.  THE UTILITY HAS ENCOUNTERED SOME PROBLEMS
SINCE INITIAL OPERATION.  THE DAMPERS FOR EACH ABSORBER MODULE WERE NOT FUNCTIONING PROPERLY.  IT
HAS BEEN IMPOSSIBLE TO ISOLATE INDIVIDUAL MODULES FOR REPAIRS (THE ENTIRE SYSTEM WOULD HAVE TO BE
SHUTDOWN IF REPAIRS WERE REQUIRED ON ONLY ONE MODULE).  THERE HAS ALSO BEEN A PROBLEM WITH THE PH
METERS.  THE METERS HAVE NOT OPERATED PROPERLY FOR SOME TIME NOW.

AUGUST-SEPTEMBER 1978 - ISOLATION DAMPER PROBLEMS ARE CONTINUING.  THE UNIT STILL REQUIRES EXCESSIVE
MAINTENANCE.  FLOW MEASUREMENT INSTRUMENTATION HAS BEEN FAILING.  OPACITY HAS BEEN HIGHER THAN EX-
PECTED (20-25X) RESULTING FROM ESP PROBLEMS.  FGD SYSTEM ACCEPTANCE TESTS WERE PERFORMED BY THE
UTILITY DURING AUGUST.  RESULTS ARE NOT YET AVAILABLE.

-------
                                                  EPA UTILITY FGO SURVEY:  OCTOUE* 1978  -  NOVEMBER  197B
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
    UTILITY NAME          TEXAS UTILITIES
    UNIT NAME             MARTIN LAKE 2
    UNIT LOCATION         TATUM TEXAS
    UNIT RATING            793 MW
    FUEL CHARACTERISTICS  COAL? 0.9X SULFUR, 8X ASH
    FGO VENDOR            RESEARCH COTTRELL
    PROCESS               LIMESTONE
    NEW OR RETROFIT       NEW
    START UP DATE          5/78
    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)   99.fl PERCENT
     SOZ          (ACTUAL)
                  (DESIGN)   70.5 PERCENT  (TOTAL)
    MATER MAKE UP
    SLUDGE DISPOSAL       STABILIZED/SLUDGE POND

    OPERATING EXPERIENCE UPDATE:
JUNE-JULY 1976 - THE FGD SYSTEM WAS TESTED FOR COMPLIANCE WITH ALL 6 MODULES IN THE GAS STREAM
DURING THE FIRST PART OF AUGUST.  RESULTS  ARE NOT YET AVAIABLE.
AUGUST-SEPTEMBER J978 - COMPLIANCE TEST RESULTS HAVE STILL NOT BEEN PUBLISHED.  MO KAJUR FGD-RELATE.D
PROBLEMS WERE REPORTED.
                                                  83

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EP* UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 1978
                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
    UTILITY NAME          TEXAS UTILITIES
    UNIT NAME             MONTICELLO 3
    UNIT LOCATION         MT. PLEASANT TEXAS
    UNIT RATING            750 MW
    FUEL CHARACTERISTICS  LIGNITE; 1.5X SULFUR, 19X ASM
    FGD VENDOR            CHEMICO
    PROCESS               LIMESTONE
    NEW OR RETROFIT       NEW
    START UP DATE          5/78
    EFFICIENCY:
     PARTICULATES (ACTUAL)
                  (DESIGN)   99.5 PERCENT
     303          (ACTUAL)
                  (DESIGN)   74.0 PERCENT
    WATER MAKE UP         CLOSED LOOP
    SLUDGE DISPOSAL       STABILIZED/SLUDGE POND

    OPERATING EXPERIENCE UPDATE:
APR. 78  THE TEXAS AIR CONTROL BOARD REPORTED THAT THE TEXAS UTILITIES 750 Mw MUNUCfcLLO UNIT 3
MAY  78  BEGAN FGD OPERATIONS DURING THE REPORT PERIOD.  AS OF YET THE UNIT HAS NOT RUN AT FULL LOAD
         BUT IS EXPECTED TO BY THE END OF AUGUST.
JUNE 78  THE UNIT IS NOT AT FULL LOAD YET.  ONE OF THE THREE FGD MODULES IS FULLY OPERATIONAL.
JULV 78  ANOTHER ONE IS PARTIALLY OPERATIONAL, WHILE THE THIRD IS NUT OPERATING AT ALL AS YET.
AUG. 78  THE COMPLIANCE TEST HAS NOT YET TAKEN PLACE.  THE FGD SYSTEM IS OPERATIONAL.  INSTRUMENTA-
SEP. 78  TION INDICATES THAT THE UNIT is IN COMPLIANCE.

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                                                  EPA UTILITY FGD SURVEY: UCTObEK 1978 - NOVEMBEK 1978


                     SECTION 3
   PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS


    UTILITY NAME          UTAH POWER & LIGHT

    UNIT NAME             HUNTINGTON 1

    UNIT LOCATION         PRICE UTAH

    UNIT RATING            415 MW

    FUEL CHARACTERISTICS  COAL; 0.5X SULFUR, 10X ASH

    F6D VENDOR            CHEHICO

    PROCESS               LIME

    NEW OR RETROFIT       NEW

    START UP DATE          5/78

    EFFICIENCYJ
     PARTICULATE3 (ACTUAL)

                  (DESIGN)   99.5 PERCENT

     SOZ          (ACTUAL)

                  (DESIGN)   aO.O PERCENT

    MATER MAKE UP         CLOSED LOOP  .72 GPM/MW

    SLUDGE DISPOSAL       STABILIZED/LANDFILL



    OPERATING EXPERIENCE UPDATE:


APRIL-MAY 1978 - INITIAL OPERATIONS BEGAN AT THIS UNIT ON HAY 10, 1978.  DUE TO THE RECENT OPERATING
STATUS OF THE SYSTEM HOURS OF OPERATION HERE NOT AVAILABLE FOR THE APRIL-MAY REPURT PEKIOD.

           PERIOD   BOILER           FGD SYSTEM PARAMETERS
MONTH      HOURS    HOURS      HOURS      OPERABILITY   UTILIZATION

JUNE 70     720      730        470           65X           65X
JULY 78     744      731        714           98X           96X
       NO MAJOR PROBLEMS WERE REPORTED BY THE UTILITY FOR THIS PERIOD.   10-201 OF THE FLUfc GAS WAS
       BYPASSED THROUGH THE USE OF AN  ADJUSTABLE DAMPER.

AUK. 78     744      544        544          100X           73X
SEP. 78     720      496        496          100X           69X
       THERE WERE NO FORCED FGD OUTAGES DURING THE AUGUST-SEPTEMBER PERIOD.  MINOH PROBLEMS »EKE EX-
       PERIENCED WITH INSTRUMENTATION.  A THREE WEEK BOILER OUTAGE OCCURRED AS A RESULT OF AN
       EXPLOSION.
                                                  85

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EPA UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 1978

                                        SECTION 4
                           SUMMARY OF FGD SYSTEMS BY COMPANY
          UTILITY
 ALABAMA ELECTRIC COOP
 ALLEGHENY POHER SYSTEM
 ARIZONA ELECTRIC POWER COOP
 ARIZONA PUBLIC SERVICE
 ASSOCIATED ELECTRIC COOP
 BASIN ELECTRIC POHER COOP
 BIG RIVERS ELECTRIC
 CENTRAL ILLINOIS LIGHT
 CENTRAL ILLINOIS PUBLIC SERV
 CENTRAL MAINE POWER
 CINCINNATI GAS « ELECTRIC
 COLORADO UTE ELECTRIC ASSN.
 COLUMBUS ft SOUTHERN OHIO ELEC.
 COMMONWEALTH EDISON
 COOPERATIVE POWER ASSOCIATION
 DELMARVA POWER ft LIGHT
 DUOUESNE LIGHT
 EAST KENTUCKY POWER COOP
 GENERAL PUBLIC UTILITIES
 GULF POWER
 HOOSIER ENERGY
 INDIANAPOLIS POWER ft LIGHT
 KANSAS CITY POHER ft LIGHT
 KANSAS POWER ft LIGHT
 KENTUCKY UTILITIES
 LAKELAND UTILITIES
 LOUISVILLE GAS ft ELECTRIC
 MINNESOTA POWER ft LIGHT
 MINNKOTA POWER COOPERATIVE
 MONTANA POHER
 NEVADA POHER
 NIAGARA MOHAWK POHER COOP
 NORTHERN INDIANA PUB SERVICE
 NORTHERN STATES POHER
 OTTER TAIL POWER
 PACIFIC GAS AND ELECTRIC
 PACIFIC POHER ft LIGHT
 PENNSYLVANIA POHER
 PHILADELPHIA ELECTRIC
 POTOMAC ELECTRIC POWER
 PUBLIC SERVICE OF INDIANA
 PUBLIC SERVICE OF NEW MEXICO
 SALT RIVER PROJECT
 SAN MIGUEL ELECTRIC COOP
 SEMINOLE ELECTRIC
 SIKESTON BOARD OF MUNIC. UTIL.
 SOUTH CAROLINA PUBLIC SERVICE
 SOUTHERN ILLINOIS POWER COOP
 SOUTHERN INDIANA GAS ft ELEC
 SOUTHERN MISSISSIPPI ELECTRIC
 SOUTHWESTERN ELECTRIC POWER
 SPRINGFIELD CITY UTILITIES
 SPRINGFIELD WATER LIGHT ft PWR
 ST. JOE ZINC
 TAMPA ELECTRIC
 TENNESSEE VALLEY AUTHORITY
 TEXAS MUNICIPAL POHER AGENCY
 TEXAS POWER ft LIGHT
 TEXAS UTILITIES
 UTAH POWER ft LIGHT
 WISCONSIN POHER ft LIGHT
TOTAL
NO MW
2
2
2
6
1
b
2
Z
1
1
1
2
4
1
2
1
2
1
2
1
2
2
3
4
1
1
8
1
1
4
10
\
3
4
1
2
1
3
4
1
1
4
3
1
1
1
2
2
1
2
1
1
1
1
1
7
1
3
b
3
1
450.
1250.
400.
2804.
670.
2600.
490.
800.
575.
600.
600.
900.
1550.
425.
1090.
180.
920.
500.
1600.
23.
980.
1060.
1020.
1885.
64.
350.
2283.
500.
450.
2120.
3125.
100.
705.
3140.
400.
1600.
509.
2475.
846.
BOO.
650.
1560.
1050.
400.
600.
235.
560.
484.
250.
360.
720.
200.
190.
60.
425.
3045.
400.
2045.
4672.
1215.
527.
	 ... 	 STATUS — — — — — •
OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
NO MW NO MW NO MW NO
1
0
1
2
0
0
0
1
0
0
0
0
2
0
0
0
2
0
0
1
0
1
3
3
1
0
4
0
1
2
3
0
1
2
0
0
0
2
1
0
0
2
0
0
0
0
1
0
0
1
0
1
0
0
0
3
0
0
3
1
0
225.
0.
200.
365.
0.
0.
0.
400.
0.
0.
0.
0.
800.
0.
0.
0.
920.
0.
0.
23.
0.
530.
1020.
1205.
64.
0.
851.
0.
450.
720.
375.
0.
115.
1420.
0.
0.
0.
1650.
120.
0.
0.
620.
0.
0.
0.
0.
280.
0.
0.
180.
0.
200.
0.
0.
0.
570.
0.
0.
2336.
415.
0.
1
2
1
4
0
2
2
0
1
0
0
2
0
1
2
1
0
0
0
0
2
1
0
1
0
0
3
1
0
0
0
0
0
0
1
0
1
1
0
0
0
0
2
1
0
1
0
1
1
1
0
0
1
1
0
1
0
0
1
2
0
225.
1250.
200.
929.
0.
1140.
490.
0.
575.
0.
0.
900.
0.
425.
1090.
180.
0.
0.
0.
0.
980.
530.
0.
680.
0.
0.
1102.
500.
0.
0.
0.
0.
0.
0.
400.
0.
509.
825.
0.
0.
0.
0.
700.
400.
0.
235.
0.
184.
250.
180.
0.
0.
190.
60.
0.
575.
0.
0.
793.
800.
0.
0
0
0
2
1
2
0
0
0
0
1
0
0
0
0
0
0
1
0
0
0
0
0
0
0
1
1
0
0
2
0
1
0
0
0
0
0
0
0
0
0
2
0
0
0
0
1
0
0
0
1
0
0
0
0
0
1
1
1
0
1
u.
o.
u.
1510.
67U.
1005.
0.
0.
0.
0.
600.
0.
0.
0.
0.
0.
0.
500.
0.
0.
0.
0.
0.
0.
0.
350.
330.
0.
0.
1400.
0.
100.
0.
0.
0.
0.
0.
0.
0.
0.
0.
940.
0.
0.
0.
0.
300.
0.
0.
0.
720.
0.
0.
0.
0.
0.
400.
545.
793.
0.
527.
0
0
0
0
0
1
0
1
0
1
0
0
2
0
0
0
0
u
2
0
0
0
0
0
0
u
0
0
0
0
7
0
2
2
U
2
0
0
3
1
1
0
1
0
1
0
0
1
0
0
0
0
0
0
1
3
0
2
1
0
0
PLANNED
MW
u.
0.
0.
0.
0.
455.
U.
4UU.
0.
600.
0.
0.
750.
0.
0.
0.
0.
0.
16UO.
0.
0.
0.
0.
0.
U.
0.
0.
0.
0.
0.
2750.
0.
590.
1720.
0.
1600.
0.
0.
726.
800.
650.
0.
350.
0.
600.
0.
0.
300.
U.
0.
0.
0.
0.
0.
425.
1900.
0.
1500.
750.
0.
0.
    TOTALS
144  62507.  46  16054.  43  17297.  20  10690.  35  18466.
     NOTE • PLANNED STATUS INCLUDES LETTER OF INTENT SIGNED,
            AND CONSIDERING ONLY FGD SYSTEMS
                            REQUESTING/EVALUTING BIDS,
                                                  66

-------
                         EPA UTILITY FGO SURVEY: OCTOBEH  1978  - NOVEMBfcK  1978
           SECTION 5
SUMMARY OF FGD SYSTEMS BY VENDOR
           TOTAL
	STATUS	
OPERATIONAL  CONSTRUCTION   CONTRACT
                           AWARDED
MANUFACTURER/PROCESS
AOL/COMBUSTION EQUIP ASSOCIATE
DOUBLE ALKALI
LIME
LIME/ALKALINE FLYASH
SODIUM CARBONATE
TOTAL -
AIR CORRECTION DIVISION, UOP
LIME (MG-PROMOTED)
LIME/LIMESTONE
LIMESTONE
SODIUM CARBONATE
TOTAL -
AMERICAN AIR FILTER
LIME
LIME (CARBIDE)
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE
TOTAL -
BABCOCK S MILCOX
LIME
LIMESTONE
NOT SELECTED
TOTAL •
BUELL/ENVIROTECH
DOUBLE ALKALI
TOTAL -
BUREAU OF MINES
CITRATE
TOTAL -
CHEMICO
LIME
LIME/ALKALINE FLYASH
LIME/LIMESTONE
LIMESTONE
TOTAL -
CHEMICO/APS
LIME/ALKALINE FLYASH
TOTAL -
CHIYOOA INTERNATIONAL
LIMESTONE
TOTAL -
COMBUSTION ENGINEERING
LIME
LIME (CARBIDE)
LIME/LIMESTONE
LIMESTONE
LIMESTONE/ALKALINE FLYASH
TOTAL -
DAVY POWERGAS
MELLMAN LORD
TOTAL •
NO.

1
1
5
3
10

2
i
4
1
8

4
2
6

1
1

3
7
1
11

1
1

1
1

7
1
1
1
10

3
3

1
1

4
2
2
7
2
17

6
6
MW

277.
500.
2570.
375.
3722.

800.
10.
1875.
509.
3194.

1049.
603.
1652.

100.
100.

1850.
2569.
550.
4969.

575.
575.

60.
60.

3785.
527.
10.
750,
5072.

579.
579.

23.
23.

1290.
248.
660.
3405.
1420.
7023.

1855.
1855.
NO.

0
0
3
3
6

2
1
2
0
5

1
2
3

0
0

0
2
0
2

0
0

0
0

5
0
1
1
7

0
0

1
1

2
2
0
3
2
9

3
3
MW

0.
0.
1170.
375.
1545.

800.
10.
730.
0.
1510.

64.
603.
667.

0.
0.

0.
1100.
0.
1100.

0.
0.

0.
0.

2985.
0.
10.
750.
3745.

0.
0.

23.
23.

200.
248.
0.
1205.
1420.
3073.

735.
735.
NO.

1
0
0
0
1

0
0
1
1
2

3
0
3

0
0

2
3
0
5

1
1

1
1

2
0
0
0
2

3
3

0
0

2
0
1
2
0
5

1
1
MW

277.
0.
0.
0.
277.

0.
0.
425.
509.
934.

985.
0.
985.

0.
0.

1250.
819.
0.
2069.

575.
575.

60.
60.

800.
0.
0.
0.
800.

579.
579.

0.
0.

1090.
0.
330.
1255.
0.
2675.

160.
180.
NO.

U
1
2
0
1

(1
0
1
0
1

U
0
0

1
1

1
2
1
4

0
0

0
0

0
1
0
0
1

0
0

0
0

0
0
1
2
0
3

2
2
MM

U.
500.
1400.
U.
1900.

0.
0.
12(1.
U.
720.

0.
U.
0.

100.
100.

600.
650.
550.
1800.

0.
0.

0.
0.

0.
527.
0.
0.
527.

0.
0.

0.
0.

0.
0.
330.
945.
0.
1275.

940.
940.
                         67

-------
EPA UTILITY F60 SURVEYS  OCTOBER 1978 - NOVEMBER 1978
                                    SECTION 5
                         SUMMARY OF FGD SYSTEMS BY VENDOR

TOTAL
MANUFACTURER/PROCESS
FMC CORPORATION
DOUBLE ALKALI
TOTAL -
MITSUBISHI INTERNATIONAL
LIMESTONE
TOTAL -
PEABODY PROCESS SYSTEMS
LIME/ALKALINE FLYASH
LIMESTONE
TOTAL -
PULLMAN KELLOGG
LIME
LIMESTONE
TOTAL -
RESEARCH COTTRELL
LIMESTONE
TOTAL -
RILEY STOKER / ENVIRONEERING
LIMESTONE
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
MAGNESIUM OXIDE
NOT SELECTED
TOTAL -
WESTERN PRECIP./NIRO ATOM.
LIME SPRAY DRYING
TOTAL -
WHBELABRATOR-FRYE/R.I.
NA,CO. SPRAY DRYING
TOTKL -
NO.

1
1

2
2

1
a
5

1
3
a

13
13

3
3

1
1

1
2
3

1
1

1
1
MW

250.
250.

980.
980.

500.
1350.
1850.

825.
1370.
2195.

6117.
6147.

760.
760.

550.
550.

120.
1510.
1630.

455.
455.

400.
400.
OPERATIONAL
NO.

0
0

0
0

0
1
1

0
0
0

5
5

2
2

1
1

1
0
1

0
0

0
0
MW

0.
0.

0.
0.

0.
225.
225.

0.
0.
0.

2151.
2151.

580.
580.

550.
550.

120.
0.
120.

0.
0.

0.
0.
CONSTRUCTION
NO.

1
1

2
2

1
3
4

1
2
3

7
7

1
1

0
0

0
0
0

0
0

1
1
MM

250.
250.

980.
980.

500.
1125.
1625.

825.
700.
1525.

3203.
3203.

180.
180.

0.
0.

0.
0.
0.

0.
0.

400.
400.
CONTRACT
AWAkDEO
NO.

U
0

0
0

0
U
0

U
1
1

1
1

0
0

0
0

0
2
2

1
1

0
0
Mn

0.
u.

0.
U.

0.
U.
U.

U.
670.
670.

793.
793.

0.
0.

0.
U.

0.
1510.
1510.

455.
455.

U.
0.
                                 109  44041.
46 16054.
43 17297.
20 10690.

-------
                 EPA UTILITY FGD  SUHVEY:  UCTUHEk  1970 - NOVfcfbtk 197H

                 SECTION  b
SUMMARY OF NEW AND RETROFIT FGO SYSTEMS  BY  PhUCfcSb
NEW OR OPERATIONAL CONSTRUCTION CONlkACT
PROCESS RETROFIT

LIME

LIME (CARBIDE)

LIME (M6-PROMOTED)

LIME/ALKALINE FLYASH

LIME/LIMESTONE

LIMESTONE

LIMESTONE/ALKALINE FLYASH

SUBTOTAL LIME/LIMESTONE

AQUEOUS CARBONATE

CITRATE

DOUBLE ALKALI

MAGNESIUM OXIDE

NOT SELECTED

PROCESS NOT SELECTED

SODIUM CARBONATE

WELLMAN LORD

LIME SPRAY DRYING

NA,CO, SPRAY DRYING
2 3
THOROUGHBRED 121

TOTALS

LIMB/LIMESTONE Z OF TOTAL MW


N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
NO.
3
5
1
3
2
0
3
0
0
2
10
3
2
0
25.
13.
0
0
0
0
0
0
0
1
0
0
0
0
1
2
1
2
0
0
0
0
0
1
MW
2065
1164
425
426
800
0
1170
0
0
20
6501
790
1420
0
12381.
2420.
0
0
0
0
0
0
0
120
0
0
0
0
125
250
314
421
0
0
0
0
0
23
27.12820.
19.
97
75
3234.


NO
10
0
0
0
0
0
1
3
0
1
19
2
0
0
30.
6.
0
0
0
1
2
1
0
0
0
0
0
0
1
0
0
1
0
0
1
0
0
0
34.
9.


. MM
4950
0
0
0
0
0
500
579
0
330
7687
1000
0
0
13137.
1909.
0
0
0
60
825
277
0
0
0
0
0
0
509
0
0
180
0
0
400
0
0
0
14871.
2426.
88
79
PLANNED
AftAKDEU
NO.
2
0
0
0
0
0
3
0
0
1
7
0
0
0
12.
1.
0
1
0
0
0
0
0
0
1
2
0
0
0
0
2
0
1
0
0
0
0
0
16.
4.
78
17
Mw
1100
U
0
0
0
U
1927
0
U
330
3776
U
U
0
6805.
330.
0
100
0
0
0
0
0
0
550
1510
0
0
0
0
940
0
455
0
0
0
0
0
8750.
1940.


NO
0
0
0
U
(1
0
0
0
0
0
6
2
2
U
8.
2.
0
0
0
0
0
0
0
4
18
2
1
0
0
0
0
0
0
0
0
0
0
0
27.
8.


. Mn
U
0
0
0
0
0
0
U
0
0
4050
1.500
1720
0
5770.
1300.
0
0
0
0
0
0
0
1326
9055
590
425
0
0
0
0
0
0
0
0
0
0
0
15250.
3216.
38
40
TU1AL NO.
UF
NU
15
5
1
3
2
0
7
i
0
<4
46
7
a
0
75.
22.
0
1
0
1
2
1
0
5
19
4
1
0
2
2
3
3
1
0
1
0
0
1
104.
40.


PLANTS
Mi'.
8115
1 1«4
42b
42b
BOO
0
3b<*/
57S
0
680
2201b
3090
3140
0
38093.
5959.
0
100
0
60
825
277
0
1446
9605
2100
425
0
634
250
1254
601
455
0
400
0
0
23
51691.
10816.
74
55

-------
EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 1978

                        SECTION 7
              SUMMARY OF OPERATING FGD SYSTEMS BY
              PROCESS AND GENERATING UNITS
     PROCESS/GENERATING UNITS
FGD/MH  STARTUP  EXPERIENCE(MO.)
           LIME

   BRUCE MANSFIELD 1
   BRUCE MANSFIELD 2
   ELRAMA POWER STATION
   GREEN RIVER 1,2 * 3
   HAWTHORN 3
   HAWTHORN a
   HUNTINGTON 1
   PHILLIPS POWER STATION
           LIME (CARBIDE)

   CANE RUN 4
   CANE RUN 5
   MILL CREEK 3
   PADDYS RUN 6
           LIME (MG-PROMOTED)
   CONESVILLE
   CONESVILLE
           LIME/ALKALINE FLYASH
   COLSTRIP 1
   COLSTRIP 2
   MILTON R. YOUNG
           LIME/LIMESTONE
   SHAWNEE 10A
   SHAWNEE 10B
           LIMESTONE

   APACHE 2
   CHOLLA 1
   CHOLLA 2
   DUCK CREEK 1
   JEFFREY 1
   LA CY6NE 1
   LAWRENCE 4
   LAWRENCE 5
   MARTIN LAKE 1
   MARTIN LAKE 2
   MONTICELLO 3
   PETERSBURG 3
   R. D. MORROW  1

   SOUTHWEST  1
   TOMBIGBEE  2
   WIDOWS CREEK  8
   WINYAH 2
           LIMESTONE/ALKALINE FLYASH

   SHERBURNE 1
825
625
510
64
100
100
415
410
3249.
178
183
425
65
851.
400
400
800.
360
360
450
1170.
10
10
20.
200
115
250
400
680
820
125
400
793
793
750
530
180
200
225
550
280
4-76
7-77
10-75
9-75
11-72
8-72
5-78
7-73

8-76
12-77
8-78
4-73

1-77
6-78

11-75
8-76
9-77

4-72
4-72

8-78
10-73
6-78
7-78
6-78
2-73
12-68
11-71
8-77
5-78
5-78
10-77
8-78
4-77
9-78
5-77
7-77
                                      7291
  710
3-76
                            33
                            18
                            39
                            40
                            74
                            77
                             8
                            66

                           355
                            29
                            13
                             5
                            69

                           116
                            24
                             7

                            31
                            38
                            29
                            16

                            83
                            61
                            61

                           162
                             5
                            63
                             7
                             6
                             5
                            71
                           121
                            86
                            17
                             8
                             8
                            15
                             5

                            21
                             4
                            20
                            18

                           480
                                                                  34
                                                  90

-------
                                                EPA  UTILITY  F60 SURVEY:  OCTOBER 1978 - NOVEMBER 197?
                     SECTION  7
           SUMMARY OF  OPERATING  FGD  SYSTEMS BY
           PROCESS AND GENERATING  UNITS
  PROCESS/GENERATING  UNITS          FGD/MM  STARTUP  EXPERIENCE(MO.)


SHERBURNE 2                           710     4-77              21

                                    1420.                       55

        MAGNESIUM  OXIDE

EDDYSTONE 1A                          120     9-75              40

                                     120.                       40

        SODIUM  CARBONATE

REID GARDNER  1                        125     4-74              57
REID GARDNER  2                        125     4-74              57
REID GARDNER  3                        125     7-76              30

                                     375.                      144

        WELLMAN LORD

DEAN H. MITCHELL 11                   115    11-76              26
SAN JUAN  1                            314     4-78                9
SAN JUAN  2                            306     8-78                6

                                     735.                       41
        THOROUGHBRED 121
SCHOLZ  1 & 2
                                        23

                                        23.
8-78
_5
 5.

-------
EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 1978

                                         SECTION 8
             SUMMARY OF SLUDGE DISPOSAL PRACTICES FOK OPERATIONAL FGD SYSTEMS
     PROCESS/GENERATING UNIT
— SLUDGE--
STABILIZED
          --SLUDGE —
        UNSTABILIZED
                                                                     --- POND—-
                                                                       LINED
  PUND- —
UNLINED
      LIME

BRUCE MANSFIELD  1
BRUCE MANSFIELD  2
ELRAMA POWER STATION
GREEN RIVER 1,2  S3
HAWTHORN 3
HAWTHORN 4
HUNTINGTON 1
PHILLIPS POWER STATION

      TOTAL

      LIME (CARBIDE)

CANE RUN 4
CANE RUN 5
MILL CREEK 3
PADDYS RUN 6

      TOTAL

      LIME CMC-PROMOTED)

CONESVILLE 5
CONESVILLE 6

      TOTAL

      LIME/ALKALINE FLYASH

COLSTRIP 1
COLSTRIP 2
MILTON R. YOUNG  2

      TOTAL

      LIMESTONE

APACHE 2
CHOLLA 1
CHOLLA 2
PUCK. CREEK 1
JEFFREY 1
LA CYGNE 1
LAWRENCE 4
LAWRENCE 5
MARTIN LAKE 1
MONTICELLO 3
PETERSBURG 3
R. 0. MORROW 1

TOMBIGBEE 2
WIDOWS CREEK 8
WINYAH 2

      TOTAL

      LIMESTONE/ALKALINE FLYASH

SHERBURNE 1
SHERBURNE 2

      TOTAL

      SODIUM CARBONATE

REID GARDNER 1
                                                825
                                                825
                                                510
 415
 410

2985.
       178
       183
       425
        65

       851.
       400
       400

       800.
                        64
                       100
                       100
                       264
                                                                  0.
       793
       750
       530
       180
                                               2253.
   0.
                                                                  0.
                       360
                       360
                       450

                      1170.
                 200
                 115
                 250
                 400
                 680
                 820
                 135
                 400
                       225
                       550
                       280

                      4045.
                       710
                       710

                      1420.
                                                                125 (SOLAR POND)
                                                                                360
                                                                                360.
                                       680
                                                                                793
                                                                                750
                                                                                225
                                                                               2448.
                                                                                710
                                                                                710

                                                                               1420.
                                                                                                510
                                                                                                 64
                                                                                                100
                                                                                                100
                                                                                                41b
                                                                                                1 1 0

                                                                                                1599.
                                                                                                 178
                                                                                                 1H3

                                                                                                 65

                                                                                                 426.
                                                                                                400
                                                                                                <>UO

                                                                                                BOO.
                                                                                                360
                                                                                                360.
                                                                                                200
                                                                                                115
                                                                                                250
                                                                                                400

                                                                                                820
                                                                                                1,25
                                                                                                400
                                                                                                530
                                                                                                180
                                                 550
                                                 280

                                                3850.
                                                                                                  U.
                                                  92

-------
                                               EPA  UTILITY FGD SUKVEY: OCTObEK  1978 - NOVtMBEK 197B
                                     SECTION  8
        SUMMARY  OF  SLUDGE DISPOSAL PRACTICES FOK OPERATIONAL FGD SYSTEMS
PROCESS/GENERATING  UNIT
— SLUDGE--
STABILIZED
  --SLUDGE—
UNSTABILIZEO
                                                                       	POND
                                                                         LINED
  KUNU	
UNLINEU
REID GARDNER  2
REID GARDNER  3

      TOTAL
         0.
          125 (SOLAR POND)
          125 (SOLAR POND)

          375.
        THOROUGHBRED  121

 SCHOLZ  1 & 2
                         23
                                         23
                           TOTAL
                                                               23.
                                                                               23.

-------
EPA UTILITY FGD SURVEYS OCTOBER 1976 - NOVEMBER 1976
                                                  SECTION 9
                             SUMMARY OF FGD SYSTEMS BY PROCESS AND REGULATORY CLASS
REGULATORY
PROCESS CLASS

LIME




LIME (CARBIDE)




LIME (MG-PROMOTED)




LIME/ALKALINE FLYASH




LIME/LIMESTONE




LIMESTONE




LIMESTONE/ALKALINE FLYASH




SUBTOTAL - LJME/LIMESTONE




AQUEOUS CARBONATE




CITRATE




LIME SPRAY DRYING

A
B
C
D
E
A
B
C
0
E
A
B
C
D
E
A
B
C
D
E
A
B
C
D
E
A
B
C
D
E
A
B
C
0
E
A
B
C
D
E
A
B
C
D
E
A
B
C
0
E
A
B
C
D
E
OPERATIONAL
NO.
1
6
1
0
0
0
3
1
0
0
0
2
0
0
0
2
1
0
0
0
0
0
2
0
0
9
6
2
0
0
0
2
0
0
0
12,
20.
6.
0.
0.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Mw
415
2770
64
0
0
0
766
65
0
0
0
800
0
0
0
720
450
0
0
0
0
0
20
0
0
4151
1770
1370
0
0
0
1420
0
0
0
5286«
7996.
1519.
0.
0.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
CONSTRUCTION
NO.
8
2
0
0
0
0
0
0
0
0
0
0
0
0
0
1
3
0
0
0
0
1
0
0
0
10
9
2
0
0
0
0
0
0
0
19.
15.
2.
0.
0.
0
0
0
0
0
0
1
0
0
0
0
1
0
0
0
M*
3630
1320
0
0
0
0
0
0
0
0
0
0
0
0
0
500
579
0
0
0
0
330
0
0
0
3717
3970
1000
0
0
0
0
0
0
0
7847.
6199.
1000.
0.
0.
0
0
0
0
0
0
60
0
0
0
0
455
0
0
0
CONTRACT
AWARDED
NO.
2
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
2
0
0
0
0
1
0
0
0
7
0
0
0
0
0
0
0
0
0
JO.
3.
0.
0.
o.
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
MM
1100
0
0
0
0
0
u
u
0
0
0
0
0
0
0
527
1400
0
0
0
0
330
0
0
0
3778
0
0
0
0
0
0
0
0
0
5405.
1730.
0.
0.
0.
0
0
100
0
0
0
0
0
0
0
0
0
0
0
0
PLANNED
NO.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
3
3
2
0
0
0
2
0
0
0
3.
5.
2.
0.
0.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
MW
0
0
0
0
u
u
0
0
u
0
0
0
u
0
0
u
0
u
0
0
u
u
u
u
0
2100
1950
1300
0
0
0
1720
0
U
0
2100.
3670.
1300.
0.
0.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
TOTAL NO.
PLANTS
NO.
11
8
1
0
0
U
3
1
U
0
U
2
0
0
U
4
6
U
0
0
0
2
2
0
0
29
16
6
U
0
0
4
0
0
0
44,
43.
10.
0.
0.
0
0
1
0
0
0
1
0
0
0
0
1
0
0
0
MW
5145
4090
64
0
0
0
766
65
0
U
,0
BOO
0
0
0
1747
2429
0
0
0
0
660
20
0
0
13746
7690
3670
0
0
0
3140
0
0
0
20638.
19595.
3819.
0.
0.
0
0
100
0
0
0
60
0
0
0
0
455
0
0
0

-------
                                                EPA UTILITY FGO  SURVEY: OCTOBER  1978 - NOVfcMBEK  1978
                                                 SECTION  9
                            SUMMARY  OF  FGO  SYSTEMS  BY  PROCESS  AND  REGULATORY CLASS
REGULATORY OPERATIONAL
CONSTRUCTION
PROCESS CLASS

DOUBLE ALKALI




MAGNESIUM OXIDE




NOT SELECTED




NA2C03 SPRAY DRYING




SODIUM CARBONATE




WELLMAN LORD




THOROUGHBRED 121




TOTALS



LIME/LIMESTONE Z OF TOTAL MW




A
B
C
0
E
A
B
C
0
E
A
B
C
D
E
A
B
C
D
E
A
B
C
D
E
A
B
C
D
E
A
B
C
D
E
A
B
C
D
E
A
B
C
D
E
NO
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
3
0
0
0
0
0
2
1
0
0
0
0
1
0
0
15
23
8
0
0




MW
0
0
0
0
0
0
120
0
0
0
0
0
0
0
0
0
0
0
0
0
375
0
0
0
0
0
620
115
0
0
0
0
23
0
0
. 5661.
. 8736.
. 1657.
0.
0.
93
92
92
0
0
NO.
2
1
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
1
0
0
0
0
0
1
0
0
0
0
0
0
0
22.
18.
3.
0.
0.




MM
825
277
0
0
0
0
0
0
0
0
0
0
0
0
0
AOO
0
0
0
0
0
509
0
0
0
0
0
180
0
0
0
0
0
0
0
9072.
7045.
1180.
0.
0.
86
88
85
0
0
CONTRACT
PLANNED
AWARDED
NO.
0
U
0
0
0
0
0
U
0
0
0
3
0
0
0
0
0
U
0
0
0
U
0
0
0
0
2
0
0
U
0
0
0
0
0
10.
9.
1.
0.
0.




Mh
U
U
0
0
0
U
0
U
0
U
0
2060
0
0
U
U
0
0
0
0
0
0
0
0
0
0
940
0
0
0
0
0
0
0
0
5405.
5185.
100.
0.
0.
100
33
0
0
0
NO.
0
0
0
0
0
0
3
1
0
0
15
3
2
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
18
11
5
1
0




Mrt
0
0
U
0
0
0
726
600
0
0
7475
1205
590
800
0
0
U
0
0
0
0
0
0
0
0
U
0
U
0
0
0
0
0
0
0
. 9575.
. 5601.
. 2490.
800.
0.
22
66
52
0
0
TOTAL NO.
PLANTS
NU.
2
1
U
0
0
0
a
i
0
0
15
6
2
1
0
1
0
0
0
U
3
1
0
U
0
0
4
2
0
0
0
0
1
0
0
65.
61.
17.
1.
0.




Mn
825
277
U
0
0
U
046
600
0
0
7475
3265
590
8uo
0
400
0
0
0
U
375
509
0
0
U
0
1560
295
0
0
0
0
23
0
0
29713.
26567.
5427.
800.
0.
69
74
70
0
0
A.  BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
B.  BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT  THAN THE FEDERAL NSPS
C.  BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
0.  OTHER
E.  REGULATORY CLASS UNKNOWN

-------
EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 1978
                                             SECTION 10
                             SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
        UTILITY COMPANY
         POWER STATION

 ALABAMA ELECTRIC COOP
 TOMBI6BEE 3

 ALLEGHENY POWER SYSTEM
 PLEASANTS 1

 ALLEGHENY POWER SYSTEM
 PLEASANTS 2

 ARIZONA ELECTRIC POWER COOP
 APACHE 3

 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 COOP
 LARAMIE RIVER 1

 BASIN ELECTRIC POWER COOP
 LARAMIE RIVER 2

 BIG RIVERS ELECTRIC
 GREEN 1

 BIG RIVERS ELECTRIC
 GREEN 2

 CENTRAL ILLINOIS PUBLIC SERV
 NEWTON 1

 COLORADO UTE ELECTRIC ASSN.
 CRAIG 1

 COLORADO UTE ELECTRIC ASSN.
 CRAIG ^

 COMMONWEALTH EOISON
 POWERTON Si

 COOPERATIVE POWER ASSOCIATION
 COAL CREEK 1

 COOPERATIVE POWER ASSOCIATION
 COAL CREEK 2

 OELMARVA POWER 4 LIGHT
 OELWARE CITY 1, 2 * 3

 H003IER ENERGY
 MEROM 1

 HOOSIER ENERGY
 MEROM 2

 INDIANAPOLIS POWER * LIGHT
 PETERSBURG 4

 KANSAS POWER > LIGHT
 JEFFREY 2
NEW OR
RETROFIT
N
N
N
N
N
R
R
R
N
N
N
N
N
N
N
R
N
N
R
N
N
N
N
SIZE OF FGD
UNIT (MW)
225
625
625
200
350
175
175
229
570
570
250
240
575
450
450
425
545
545
160
490
490
530
680
PROCESS/VENDOR
PEABOUY PROCESS SYSTEMS
LIMESTONE
8ABCOCK S WILCOX
LIME
BABCOCK & WILCOX
LIME
RESEARCH COTTHELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
CHEMICO/APS
LIME/ALKALINE FLYASH
CHEMICO/APS
LIME/ALKALINE FLYASH
CHEMICO/APS
LIME/ALKALINE FLYASH
RESEARCH COTTKELL
LIMESTONE
RESEARCH C01THELL
LIMESTONE
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
BUELL/ENVIROTECH
DOUBLE ALKALI
PEA6UDY PROCESS SYSTEMS
LIMESTONE
PEABOOY PROCESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIME
DAVY POWERGAS
WELLMAN LORD
MITSUBISHI INTERNATIONAL
LIMESTONE
MITSUBISHI INTERNATIONAL
LIMESTONE
RESEARCH COTTHELL
LIMESTONE
COMBUSTION ENGINEERING
START-UP
DATfc
6/79
i/79
4/80
4/79
6/BU
0/79
U/79
U/79
4/ttU
10/80
12/79
12/8U
11/79
3/79
3/79
3/79
2/79
11/79
4/00
4/81
1/82
10/83
6/80
                                                       LIMESTONE

-------
                                                 EPA UTILITY  F6D  SURVEY:  OCT06EK  1978  -  NUVfcr'BEK  197H
                                            SECTION 10
                            SUMMARY OF FGO SYSTEMS UNDER CONSTRUCTION
       UTILITY COMPANY
        POWER STATION

LOUISVILLE GAS ft ELECTRIC
CANE RUN 6

LOUISVILLE GAS & ELECTRIC
MILL CREEK 1

LOUISVILLE GAS ft ELECTRIC
MILL CREEK 4

MINNESOTA POWER ft LIGHT
CLAY BOSWELL 4

OTTER TAIL POWER
COYOTE 1

PACIFIC POWER & LIGHT
JIM BRIDGER a

PENNSYLVANIA POWER
BRUCE MANSFIELD 3

SALT RIVER PROJECT
CORONAOO 1

SALT RIVER PROJECT
CORONAOO 2

SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1

SIKESTON BOARD OF MUNIC. UTIL.
SIKESTON POWER STATION

SOUTHERN ILLINOIS POWER COOP
MARION 4

SOUTHERN INDIANA GAS ft ELEC
A. B. BROWN 1

SOUTHERN MISSISSIPPI ELECTRIC
R. 0. MORROW 2

SPRINGFIELD WATER LIGHT ft PWR
DALLMAN 3

9Tt. JOE_ZJNC
8. F. WEATON 1

TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7

TEXAS UTILITIES
MARTIN LAKE 3

UTAH POWER * LIGHT
EMERY 1

UTAH POWER ft LIGHT
EMERY 2
NEW OR
RETROFIT
R
R
N
N
N
N
N
N
N
N
N
N
N
N
N
R
R
N
N
N
SIZE OF FGD
UNIT (Mw)
277
330
495
500
400
509
825
350
350
400
235
184
250
180
190
60
575
793
400
400
PROCESS/VENDOR
AOL/COMBUSTION EQUIP ASSOCIA'
DOUBLE ALKALI
COMBUSTION ENGINEERING
LIME/LIMESTONE
AMERICAN AIM FILTER
LIME
PEABODY PROCESS SYSTEMS
LIME/ALKALINE FLYASM
WHEELABRATOR-FRYE/R.I.
NA2C03 SPRAY DRYING
AIR CORRECTION DIVISION, UOP
SODIUM CARBONATE
PULLMAN KELLOGG
LIME
PULLMAN KELLOGG
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BABCOCK ft WILCOX
LIMESTONE
BABCOCK ft WILCOX
LIMESTONE
BABCOCK ft WILCOX
LIMESTONE
FMC CORPORATION
DOUBLE ALKALI
RILEY STOKER / ENVIHONEERING
LIMESTONE
RESEARCH COTTKELL
LIMESTONE
BUREAU OF MINES
CITRATE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
CHEMICO
LIME
CHEMICO
LIME
STAKT-UP
   DATE

 12/7tt
  1/81


  7/81


  5/80


  5/81


  9/79



  4/80


  2/79



  1/80


  b/80


  6/81


  9/78


  4/79


  2/79


  7/8U


 11/16


 1U/8U



 12/78


  1/79


  6/80
                                                 97

-------
EP* UTILITY FGO SURVEY: OCTOBER 1978 - NOVEMBER 1978
                                             SECTION 11
                                  SUMMARY OF PLANNED FGO SYSTEMS
        UTILITY COMPANY
         POWER STATION
             CONTRACTS AWARDED
 ARIZONA PUBLIC SERVICE
 FOUR CORNERS 4

 ARIZONA PUBLIC SERVICE
 FOUR CORNERS 5
 ASSOCIATED ELECTRIC COOP
 THOMAS HILL 3

 BASIN ELECTRIC POWER COOP
 ANTELOPE VALLEY 1
 BASIN ELECTRIC POWER COOP
 LARAMIE RIVER 3

 CINCINNATI GAS & ELECTRIC
 EAST BEND 2
 EAST KENTUCKY POWER COOP
 SPURLOCK 2

 LAKELAND UTILITIES
 MCINTOSH 3

 LOUISVILLE GAS & ELECTRIC
 MILL CREEK 2
 MONTANA POWER
          3
 MONTANA POWER
 COLSTRIH 4

 NIAGARA MOHAWK POWER COOP
 CHARLES. R. HUNTLEY 6

 PUBLIC SERVICE OF NEW MEXICO
 SAN JUAN 3

 PUBLIC SERVICE OF NEW MEXICO
 SAN JUAN 4

 SOUTH CAROLINA PUBLIC SERVICE
 WINYAH 3

 SOUTHWESTERN ELECTRIC POWER
 HENRY W. PERKEY 1

 TEXAS MUNICIPAL POWER AGENCY
 GIBBONS CREEK 1

 TEXAS POWER & LIGHT
 SANDOW 4

 TEXAS UTILITIES
 MARTIN LAKE 4

 WISCONSIN POWER ft LIGHT
 COLUMBIA 2
NEW OR
RETROFIT
R
R
N
N
N
N
N
N
R
N
N
R
N
N
N
N
N
N
N
N
SIZE OF FGD
UNIT (MW)
755
755
670
455
550
600
500
350
330
700
700
100
466
472
300
720
400
545
793
527
VENDOR/PROCESS
UNITED ENGINEERS
NOT SELECTED
UNITED ENGINEERS
NOT SELECTED
PULLMAN KELLOGG
LIMESTONE
WESTERN PRECIP./NIRU ATOM.
LIME SPRAY DRYING
BABCOCK & WILCOX
NOT SELECTED
BABCOCK & WILCOX
LIME
ADL/COMBUSTION EQUIP ASSOCIATE
LIME
BABCOCK 8 WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIME/LIMESTONE
ADL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALINE FLYASH
ROCKWELL INTERNATIONAL
AUUEOUS CARBONATE
DAVY POWERGAS
WELLMAN LORD
DAVY POWERGAS
WELLMAN LORD
BABCOCK ft WILCOX
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
CHEMICO
START-UP
DATE
u/e
-------
                                                 EPA UTILITY FGO SURVEY: OCTOBEK 1978 - NOVEMUEK 1978
                                            SECTION 11
                                 SUMMARY OF PLANNED FGD SYSTEMS
       UTILITY COMPANY
        POWER STATION

PHILADELPHIA ELECTRIC
EDDYSTONE IB
                                 NEW OR
                                RETROFIT
SIZE OF FGD  VENDOR/PROCESS
 UNIT (MW)
                                             240
                                                      UNITED ENGINEERS
                                                      MAGNESIUM OXIDE
                               START-UP
                                  DATE

                                 6/80
            REQUESTING/EVALUATING BIDS

                                    N
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2

PUBLIC SERVICE OF INDIANA
GIBSON 5

TENNESSEE VALLEY AUTHORITY
PARADISE 1

TENNESSEE VALLEY AUTHORITY
PARADISE 2

TEXAS UTILITIES
FOREST GROVE 1
                                    N
   900


   650


   650


   650


   750
NOT SELECTED
NOT SELECTED

NOT SELECTED
NOT SELECTED

NOT SELECTED
LIMESTONE

NOT SELECTED
LIMESTONE

NOT SELECTED
NOT SELECTED
                                                                                       1/84
                                                                                       0/82
                                                                                       U/82
                                                                                       u/ 0
                                                                                       0/81
            CONSIDERING FGD SYSTEM

BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 2

CENTRAL MAINE POWER
SEARS ISLAND 1

COLUMBUS & SOUTHERN OHIO ELEC.
POSTON 5

COLUMBUS & SOUTHERN OHIO ELEC.
POSTON 6

GENERAL PUBLIC UTILITIES
COHO 1

GENERAL PUBLIC UTILITIES
SEWARD 7

NEVADA POWER
HARRY ALLEN 1

NEVADA POWER
HARRY ALLEN 2

NEVADA POWER
HARRY ALLEN 3

NEVADA POWER
HARRY ALLEN q

NEVADA POWER
REID GARDNER 4

NEVADA POWER
WARNER VALLEY 1

NEVADA POWER
WARNER VALLEY 2

NORTHERN INDIANA PUB SERVICE
BA1LLV 7

NORTHERN INDIANA PUB SERVICE
BAILLY 8

PACIFIC GAS AND ELECTRIC
FOSSIL 1
                                             455


                                             600


                                             375


                                             375


                                             600


                                             800


                                             500


                                             500


                                             500


                                             500


                                             250


                                             250


                                             250


                                             190


                                             400


                                             800
            NUT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NUT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            NOT SELECTED

            NOT SELECTED
            LIMESTONE
                                11/83


                                11/86


                                 0/83


                                 0/85


                                 5/88


                                 5/85


                                 6/85


                                 6/66


                                 6/87


                                 6/88


                                 0/83


                                 0/84


                                 6/65


                                 O/ 0


                                 O/ 0


                                 0/65

-------
EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 197B
        UTILITY COMPANY
         POWER STATION

 PACIFIC 6AS AND ELECTRIC
 FOSSIL 2

 PHILADELPHIA ELECTRIC
 CROM8Y

 PHILADELPHIA ELECTRIC
 EDDYSTONE 2

 POTOMAC ELECTRIC POWER
 DICKERSON 4

 SALT RIVER PROJECT
 CORONADO 3

 SEMINOLE ELECTRIC
 SEMINOLE 1

 SOUTHERN ILLINOIS POWER COOP
 MARION S

 TAMPA ELECTRIC
 BI6 BEND a

 TENNESSEE VALLEY AUTHORITY
 JOHNSONVILLE

 TEXAS POKER I LIGHT
 THIN OAKS 1

 TEXAS POWER ft LIGHT
 THIN OAKS 2
            SECTION 11
 SUMMARY OF PLANNED FGD SYSTEMS

 NEH OR   SIZE OF FGD  VENDOR/PROCESS
RETROFIT   UNIT (MM)

    N        800      NOT SELECTED
                      LIMESTONE

    R        ISO      UNITED ENGINEERS
                      MAGNESIUM OXIDE

    R        336      UNITED ENGINEERS
                      MAGNESIUM OXIDE

    N        800      NUT SELECTED
                      NOT SELECTED

    N        350      NOT SELECTED
                      LIMESTONE

    N        600      NUT SELECTED
                      LIMESTONE

    N        300      NUT SELECTED
                      NOT SELECTED

    N        425      VENDOR NOT SELECTED
                      PROCESS NOT SELECTED

    R        600      TVA/UNITED ENGINEERS
                      MAGNESIUM OXIDE

    N        750      NOT SELECTED
                      LIMESTONE

    N        750      NOT SELECTED
                      LIMESTONE
STAKT-UP
   DATE

  U/86
  6/80
  6/80
  5/85
  0/87
  6/83
  U/84
  0/85
  0/82
  8/83
  9/84
                                                 100

-------
                                EPA UTILITY FGD SURVEY: UCTUbfcK 1978 - NUVfcMBEK  197B




                           SECTION 13






               TOTAL FGD MEGAWATT CAPACITY BY YEAR *




                   YEAH    NO. UNITS MEGAWATTS
1950
1968
1971
1973
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
UNDEFINED
1
1
1
4
4
2
4
6
10
18
19
23
10
11
6
6
7
3
3
2
3
793
125
400
220
1410
250
1054
2313
4921
6675
7026
9853
4805
6322
2960
3200
3950
1900
1710
1300
1240
• TOTALS DISPLAYED DO NOT INCLUDE TERMINATED OR  INACTIVE  SYS1EMS.
                                101

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     APPENDIX A




FGD SYSTEMS ECONOMICS
         A-l

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                          INTRODUCTION

     The cost of flue gas desulfurization  (FGD) systems for the
control of sulfur dioxide emissions is an area of intense inter-
est and substantial controversy.  As a result, many computer
models have recently been developed to estimate capital and
annual costs.  As part of an effort by the U.S. Environmental
Protection Agency to provide meaningful economic data concerning
FGD systems, reported economic data have been incorporated into
the EPA Utility FGD Survey report.  This information has appeared
as a separate appendix of the report since October 1976.  Until
January 1978, this cost appendix consisted entirely of data
reported by the utilities with little or no interpretation pro-
vided by PEDCo Environmental, Inc.  Beginning with the May 1978
report, the format and content of the cost appendix were revised
to include reported and adjusted costs for the operational FGD
systems.
     The rationale for including adjusted as well as reported
costs stems primarily from the lack of comparability of the
reported costs.  Many of the reported cost figures, both capital
and operating, are largely site-sensitive values that cannot be
accurately compared because they refer to different FGD battery
limits and different years in which the expenditures were made.
As a result, an analysis of the cost data was made for the opera-
tional units since these systems offer the potential of having
complete and accurate economic data.  The adjustments were made
to provide comparable, accurate cost data for the sulfur dioxide
portion of the emission control system.  This, in effect, will
eliminate much of the confusion that exists concerning the re-
ported data, and it will provide a common basis for the reported
costs.

                               A-2

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                             APPROACH


     In March 1978,  each utility having at least one operational
FGD system was  given a cost form containing all  available  cost

information then  in  the PEDCo files.   The utility was asked  to

verify the date), and  fill in any missing information called for

on the form.  R. follow-up visit by the PEDCo Environmental staff

was arranged to assist in data acquisition and to insure com-

pleteness and reliability of information.   Results of the  cost

analysis were irorwarded to each participating utility for  final

review and comment.

     The cost data were treated solely to establish the accurate

costs for FGD systems,  on a common basis,  not to critique  the

design or reasonableness of the costs  reported by any utility.

Adjustments focused  primarily on the following items:

     0    All capital costs were adjusted to July 1,  1977, dol-
          larss.  using the Chemical Engineering Index.   All  capital
          costs,  represented in dollars/kilowatt ($/kW), were
          expressed  in terms of gross  megawatts  (MW).  Actual
          costs were reported by utilities in dollar values  for
          years 1970 to 1980.   These values are  represented  in
          terms of the year of greatest capital  expenditures.

     0    Gross unit capacity was used to express all FGD  capital
          expenditures  because the capital requirement of  an FGD
          system  is  dependent on actual boiler size before de-
          rating  for auxiliary and air quality control power
          requirements.

     0    Par-ticulate control costs  were deducted.   Since  the
          purpose of the study was to  estimate the incremental
          cos't  for sulfur dioxide control,  particulate control
          costs were deducted using  either data  contained  in the
          cost  breakdowns or as a percentage of  the total  direct
          cost  (capital  and annual).   The  percentage  reduction
          varied depending upon system design and operation.
                               A-3

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The capital costs associated with the modification  or
installation of equipment not part of tlie  FGD  system
but needed for its proper functioning, were  included
(e.g. - stack lining, modification to existing ductwork
or fans, etc.).

Indirect charges were adjusted to provido  adequate
funds for engineering, field expenses, logal expenses,
insurance, interest during construction, allowance  for
startup, taxes, and contingency.

All annual costs, represented in mills/kilowatt-hour
(mills/kWh), were expressed in terms of net  megawatts
(MW) .

Net unit capacity was used to express all  FGD  annual
expenditures because the annual cost requirement of an
FGD system is dependent on the actual amount of kilo-
watt-hours (kWh)  produced by the unit after  derating
for auxiliary and air quality control power  require-
ments.

All annual costs were adjusted to a common capacity
factor  (65 percent).

Replacement power costs were not included  since only a
few utilities reported such costs and thes e  were pre-
sented using a variety of methods.

Sludge disposal costs were adjusted to ref.'Lect the
costs of sulfur dioxide waste disposal only  (i.e.,
excluding fly ash disposal) and to provide for disposal
over the anticipated lifetime of the FGD system.  This
latter correction was necessary since seveiral  utilities
reported costs for sludge disposal capacity  that would
last only a fraction of the FGD system life.   The
adjustments were based on a land cost of $2000/acre
with a sludge depth of 50 ft in a clay-lin«d pond  (clay
is assumed to be available at the site).

A 30-year life was assumed for all process and economic
considerations for all new systems that were installed
for the life of the unit.  A 20-year life was  assumed
for all process and economic considerations  for retro-
                     A-4

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          fit systems that were installed for the remaining por-
          tion of the life of the unit.*
     0    Regeneration and by-product recovery facility costs
          were added for those regenerable systems not reporting
          such costs.
     To the extent possible, all cost adjustments were made using
the previous assumptions developed by PEDCo Environmental.  When
cost data were inadequate, adjustments were made using process
design data in conjunction with the previous cost assumptions.
In some cases, no adjustments were possible because of in-
sufficient data.
*  The use of a 30-year service life for new units coincides with
   the conclusion of the National Power Survey of the Federal
   Power Commission which recognized this value as reasonable for
   steam-electric plants.  A 20-year service life was assumed for
   all retrofit units even if the remaining life of the units is
   less than this value.  Thus, two different rates are used and
   should be noted when making comparisons between new and retro-
   fit systems.
                               A-5

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                  DESCRIPTION OF COST ELEMENTS

     Capital costs consist of direct costs/  indirect costs,  con-
tingency costs,  and other capital costs.   Direct costs include
the "bought-out" cost of the equipment,  the  cost of installation,
and site development.  Indirect costs include interest during
construction, contractor's fees and expenses, engineering,  legal
expenses, taxes, insurance, allowance for start-up and shake-
down, and spares.  Contingency costs include those costs result-
ing from malfunctions, equipment alterations, and similar un-
foreseen sources.  Other capital costs include the nondepreciable
items of land and working capital.
     Annual costs consist of direct costs, fixed costs, and over-
head costs.  Direct costs include the cost of raw materials,
utilities, operating labor and supervision,  and maintenance and
repairs.  Fixed  costs include those of depreciation, interim
replacement, insurance, taxes, and interest on borrowed capital.
Overhead costs include those of plant and payroll expenses.   The
various capital  and annual cost components are discussed and
defined in greater detail in the following paragraphs.
     The direct capital costs include the following elements:
     0    Equipment required for the FGD system.  Table A-l
          provides a summary of the major process equipment used
          in regenerable and nonregenerable systems.
     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, buildings,
          piping, and other equipment, painting and piling.
     0    Site development may include clearing and grading,
          construction of access roads and walkways, establish-
          ment of rail, barge, and/or truck facilities, and
          parking facilities.

                                A-6

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         TABLE A-l.  MAJOR FGD SYSTEM EQUIPMENT SUMMARY
    Category
             Description
Material handling-
raw materials
Feed preparation-
raw materials
Sulfur dioxide
absorption
Flue gas reheat
Gas handling
Sludge disposal
Utilities
By-product
handling
Equipment for the handling and transfer of
raw materials includes unloading facilities,
conveyors, storage areas and silos, vibrators,
atmospheric emission control associated with
these facilities, and related accessories.

Equipment for the preparation of raw material
to produce a feed slurry consists of feed
weighers, crushers, grinders, classifiers,
ball mills, mixing tanks, pumps, agitators,
and related accessories.

Equipment for treating the flue gas includes
absorbers, mist eliminators, hold tanks,
agitators, circulating pumps, pond water re-
turn pumps, and related accessories.

Equipment required includes air, steam, or
hot water heaters, condensate tanks, pumps,
soot blowers, fans, fuel storage facilities,
gas bypass equipment, and related accessories.

Equipment to handle the boiler flue gas in-
cludes booster fans, ductwork, flue gas by-
pass system, turning vanes, supports, plat-
forms, and related accessories.

Nonregenerable FGD systems require solids/
water separation equipment such as clarifiers,
vacuum filters, centrifuges, sludge fixation
equipment, and related accessories.

Equipment to supply power and water to the
FGD equipment consists of switch-gear, break-
ers, transformers, piping, and related
accessories.

Equipment for processing the by-product of
regenerable FGD systems may include a rotary
kiln, fluid bed dryer, conveyor, storage  silo,
vibrator, combustion equipment and oil stor-
age tanks, waste heat boilers, hammer mills,
evaporators, crystallizers, strippers, tanks,
agitators, pumps, compressors, sulfuric acid
absorber and cooling, mist eliminator, pumps,
acid coolers, tanks, etc.
 (continued)
                               A-7

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TABLE A-l.   (continued)
    Category
              Description
Regeneration
Purge treatment
Auxiliary
 Equipment for  regeneration  of  the  absorbing
 medium  of an FGD  system may consist  of  re-
 actor vessels, material handling system,
 storage,  weigh feeder, conveyor, rotary kiln,
 fluid bed calciner, dust  collector,  storage
 silo, vibrator, combustion  equipment and  oil
 storage tanks, waste heat boiler,  hammer
 mill, evaporators,  crystallizers,  strippers,
 tanks,  agitators, pumps,  compressors, sul-
 furic acid absorber and cooling, mist elimi-
 nator,  pumps,  acid  coolers,  tanks, etc.

 Equipment for the removal of purge material
 (e.g. sodium sulfate) includes refrigeration,
 pumps,  tanks, crystallizer,  centrifuge,
 dryer,  dust collector, conveyors,  storage,
 and related equipment.

 Equipment not directly related to  the
 FGD system, but which may require  design  or
 modification to accommodate  an FGD system
 may include such  items as existing fans,
 ducts,  or stack.   If new  fans,  ducts, or
 stacks are added to improve boiler perfor-
mance and accommodate the FGD system, the
 costs are prorated to the boiler and FGD
 system.
                              A-8

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 Indirect capi-tal costs include the following elements:

      Interest accrued on borrowed capital during construction,

 0     Contractor's fee and expenses, including costs for
      field lab*or payroll; field office supervision; person-
      nel;  construction offices; temporary roadways; railroad
      trackage;  maintenance and welding shops; parking lot;
      communicat .ions;  temporary piping and electrical and
      sanitary facilities; safety security (fire, material,
      medical,  etc.);  construction tools and rental equip-
      ment;  unlo.ading and storage of materials; travel ex-
      penses;  pe: emits; licenses; taxes; insurance; overhead;
      legal liabilities; field testing of equipment; start-
      up;  and  lat»or relations.

 °     Engineering  costs, including administrative, process,
      project,  an»d general; design and related functions for
      specifications;  bid analysis; special studies; cost
      analysis;  accounting; reports; consultant fees; pur-
      chasing;  procurement; travel expenses; living expenses;
      expediting;  inspection; safety; communications; model-
      ing;  pilot p'lant studies  (if required because of pro-
      cess  design  ior application novelty); royalty payments
      during construction; training of plant personnel; field
      engineering;  safety engineering; and consultant ser-
      vices .

 0     Legal  expenses,  including those for securing permits,
      rights-of-way , etc.

 0     Taxes, includi.ng sales, and excise taxes.

 0     Insurance cove ring liability for equipment in transit
      and at site; f.ire, casualty, injury, and death; damage
      to property; dtslay;  and noncompliance.

 0     Allowance for at art-up and shakedown includes the cost
      associated with  system start-up.

 °     Spare  parts  inciluding pumps, valves, controls, special
      piping and fitti.ngs, instruments, spray nozzles,  and
      similar items.

Other capital costs iinclude the following elements:

 0     Land required foi: the FGD process,  waste disposal,  re-
      generation facili ty, and storage.

 °    Working capital,  .including the total amount of money
      invested in raw nuiterials and supplies in stock,
      finished products  in stock,  and unfinished products

                           A-9

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          in the process of being manufactured;  accounts re-
          ceivable;  cash kept on hand for payment of operating
          expenses such as salaries,  wages,  anol raw materials
          purchases;  accounts payable;  and taxfss payable.

     Annual cost of  an FGD system includes the: following direct,

fixed and overhead charges:

0    Direct Charges

          Raw materials, including those requ ired by the FGD
          process for sulfur dioxide  control, absorbent regenera-
          tion,  sludge treatment, sludge fixation, flocculants,
          etc.

          Utilities,  including water  for slurries, cooling and
          cleaning;  electricity for pumps, f;ans, valves, lighting
          controls,  conveyors, and mixers; fuel for reheating of
          flue gases;  and stream for  process} ing.

          Operating  labor,  including  supervisory, skilled, and
          unskilled  labor required to operate, monitor, and
          control the FGD process.

          Maintenance and repairs, consisting of both manpower
          and materials to keep the unit operating efficiently.
          The function of maintenance is both preventive and
          corrective to keep outages  to a :rninimum.

          Byproduct  Sales;   credit from th.e  sale of byproducts
          regenerable FGD processes (e.g. sulfur, sulfuric acid)
          is a negative charge deducted fjrom the annual direct
          cost to obtain the net annual direct cost of the FGD
          system.

0    Fixed Charges

     •    Depreciation - the annual char«;je to recover direct and
          indirect costs of physical  assists  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 cos1;s of  protection from loss
          by a specified contingency, j:»eril, or unforeseen event.
          Required coverage could include losses due to fire,
          personal injury or death, property damage, explosion,
          lightning,  or other natural ;phenomena.
                               A-10

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          Taxes,  including franchise, excise, and property taxes
          levied by a city, county, state, or Federal government.

          Interest on borrowed funds.

0    Overhead

          Plant and administrative overhead is a business expense
          that is not charged directly to a particular part of a
          project, but is allocated to it.  Overhead costs in-
          clude administrative, safety, engineering, legal and
          medical services; payroll; employee benefits; recrea-
          tion; and public relations.

     Table A-2 provides a summary of the means used to determine

the missing cost elements if the costs were not reported or

insufficient information prevented their actual determination.

The assumptions and cost bases for determining the capital and

annual costs of FGD systems were developed by the PEDCo staff

based upon previous economic studies conducted for the U.S. EPA
(Flue Gas Desulfurization Process Cost Assessment, May 1975;

Simplified Procedures for Estimating Flue Gas Desulfurization

System Costs, June 1976, EPA-600/2-76-150; Particulate and Sulfur

Dioxide Emission Control Costs for Large Coal-Fired Boilers,

March 1978, EPA-600/7-78-032) .
                               A-ll

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                TABLE A-2.  COST ELEMENT FACTORS
     Category
               Value
Indirect capital costs:
  Interest during
    construction
  Field overhead
  Contractor's fee and
    expenses
  Engineering
  Taxes
  Spares
  Shakedown allowance
Other capital costs:
  Contingency

Direct annual costs:
  Raw materials:
    Fixation chemicals
    Lime
    Limestone
    Magnesium oxide
    Sodium carbonate
    Salt cake (credit)
    Sulfur (credit)
    Sulfuric acid  (credit)
  Utilities:
    Electricity
    Water
    Steam
  Operating labor:
    Direct labor
    Supervision
10% of total direct capital costs

10% of total direct capital costs
 5% of total direct capital costs

10% of total direct capital costs
 2% of total direct capital costs
 1% of total direct capital costs
 5% of total direct capital costs
20% of total direct and indirect
  capital costs
             $2/ton
             $40/ton
             $10/ton
             $150/ton
             $80/ton
             $50/ton
             $65/ton
             $25/ton

          25 mills/kWh
          $0.20/103 gal
          $0.80/106 Btu

$ 8.50/man-hour
15% of direct labor costs
  Contingency costs are used only when the cost data supplied are
  incomplete (such as equipment costs or direct costs only) and a
  contingency cost must be factored in to give an accurate estimate
  of the total capital cost.
(continued)
   A-12

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TABLE A-2.  (continued)
     Category
               Value
  Maintenance:
    Labor and materials
    Supplies
  Overhead:
    Plant
    Payroll

Fixed annual costs:
  Depreciation
  Interim replacement
  Taxes
  Insurance
  Capital costs
 4% of total direct capital costs
15% of labor and materials costs

50% of operation and maintenance costs
20% of operating labor costs
3.33% or 5% (new or retrofit)
0.7% or 0.35%
4%
0.3%
9%
   Some  system components  have  life  spans  less  than  the expected
   service  life of  the  system.   Interim  replacement  is an  allow-
   ance  factor used in  estimating  annual revenue  requirements  to
   provide  for the  replacement  of  these  short-lived  items.  An
   average  allowance of 0.35% of the total investment is normally
   provided and used for systems with an expected service  life of
   20  years or less.  A higher  allowance of 0.70% of the total
   investment is provided  and used for systems  with  an expected
   service  life of  30 years  or  more.
                               A-13

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                   DEFINITION OF COST ELEMENTS

     The costs displayed in Appendix A are accompanied by a
series of alphabetic characters summarizing data presented for
each FGD system.  These relate to the cost elements described
earlier in this section and identify what has been included and
excluded for reported and adjusted capital and annual costs.  The
                    •»
alphabetic characters, along with their titles, are briefly de-
scribed in Table A-3.
                              A-14

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                      TABLE  A-3.    DESCRIPTION OF  COST
Code
                 Title
          Description
B


C
B
H
 L


 N



 N


 O
      articulate control (required for FGD pro-
     cess) included in capital cost.
 articulate control (included in PGD
process) included in capital cost.
Total direct capital costs included.
     Partial direct capital costs included.
Total indirect capital costs included.
     Partial  indirect  costs  included.
     Chemical  fixation  of  sludge  included  in
     capital cost.
Dry  sludge  disposal included in capital
cost.
      Off-site landfill area included in
      capital cost.

      Sludge pond included in capital cost.
      Additional sludge disposal capacity
      added for life of system.
 Stack included in capital cost.

 Modifications to stack, ducts, and/or
 fans included in capital cost.

 Total regeneration facility cost included
 in capital cost.
 Partial regeneration facility cost in-
 cluded in capital cost.

 R & D costs included in capital cost.
Particulate precollection device (ESP,
fabric filter, venturi)  prior to PGD
system required for proper operation of
SO. control system.
Particulate collection equipment (venturi
scrubber) is included in the FGD system.
Complete cost of all FfiD equipment,  the
labor and materials required for equip-
ment installation, and interconnecting
the system is included in the total
capital cost.
One or a number of direct cost items, or
the cost associated with one or a number
of direct cost items, are excluded from
the total capital cost.
Complete cost of all the indirect cost
elements, including interest during  con-
struction, contractor's fees, engineer-
ing, legal expenses, taxes, insurance,
allowance for start-up, and spares,  is
included in total capital cost.
One or a number of indirect cost items,
or the cost associated with one or a
number of indirect cost items, are ex-
cluded from the total capital cost.
The cost of a chemical fixation process
which stabilizes the flue gas cleaning
wastes prior  to disposal is included in
the total capital  cost.

The cost of a secondary dewatering or
treatment method,  such as filtration, cen-
trifugation,  or forced oxidation, which
ultimately produces a dry sludge cake
for final disposal, is included in the
total capital cost.
The cost of an off-site area used as a
landfill for  flue  gas cleaning wastes is
included in the total capital cost.
The cost of an on-site disposal area for
ponding  of treated or untreated flue gas
cleaning wastes is included in the total
capital  cost.
The cost of additional SO, waste disposal
capacity required  for FGD system operation
over the anticipated service life of the
unit is  included in the total capital cost.
The cost of the stack is included in the
total capital cost.
Modifications to existing equipment  (stack,
fans, ducts,  etc.) which are required be-
cause of inclusion of an FGD system.
Complete cost of entire regeneration
facility included  in total capital cost.
Part of  the cost associated with the re-f
generation facility included in the  total
capital  cost.
Bench scale or pilot plant studies to de-
termine  process and design characteristics.
  (continued)
                                      A-15

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                           TABLE A-3.   (continued)
Code
                 Title
           Description
W


X
     Costs underwritten by system supplier in-
     cluded in capital cost.
     Excess reagent supply costs included in
     capital cost.

     Total direct annual costs included.
     Partial direct annual costs included.
     Total fixed annual costs included.
     Partial fixed annual costs included.
Overhead cost included in total annual
cost.
Particulate control costs included in
direct annual cost.
     Sludge disposal service  costs  (contract)
     included in direct annual  cost.

     Replacement energy costs included  in
     total annual costs.
Capital expenditures underwritten by the
system supplier for system repairs or
modifications for optimization of perfor-
mance or R S D programs.
Capital expenditures for reagent supply
exceeds the amount required for the period
of initial operation.
Complete cost of all raw materials,
utilities, operating labor and maintenance
and repairs is included in the total
annual cost.
One or a number of direct annual cost items,
or the cost associated with one or a number
of direct annual cost items, are excluded
from the total annual cost.

Complete cost of all fixed cost elements,
including depreciation, interim replace-
ment, insurance, taxes, and interest, is
included in the total annual cost.
One or a number of fixed annual cost items,
or the cost associated with one or a
number of fixed annual cost items, are ex-
cluded from the total annual cost.
Plant and payroll overhead costs are in-
cluded in the total annual cost.

The cost of operating particulate collection
equipment included in the FGD system is in-
cluded in the total annual cost.

The treatment and disposal of flue gas
cleaning wastes that are handled by an
outside firm.

The cost of additional power-generating
capacity required to compensate for power
used by the PGD system.
                                          A-16

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                    RESULTS OF COST ANALYSIS

     The results of the operational FGD system survey are
summarized in Tables A-4 and A-5.  Table A-4 summarizes the re-
ported and adjusted capital and annual costs for all the
operational FGD systems addressed in the survey.  Table A-5 pro-
duces a summary of a categorical analysis of the reported and ad-
justed 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-17

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      TABLE A-4.  REPORTED AND ADJUSTED CAPITAL AND ANNUAL
               COSTS FOR OPERATIONAL FGD SYSTEMS*

Cholla 1
Conesville 5
Elrama 1-4
Phillips 1-6
Petersburg 3
Hawthorn 3-4
La Cygne 1
Green River 1-3
Cane Run 4
Cane Run 5a
Paddys Run 6
M.R. Young 2a
Colstrip 1-2
Reid Gardner 1-2
Reid Garbder 3
D.H. Mitchell 11
Sherburne 1-2
B. Mansfield 1-2
Eddystone 1AC
Winyah 2
Southwest la
Widows Creek 8
Reported
Capital
SAW
52.0
55.6
113.5
107.0
99.5
29.3
53.7
70.3
66.6
62.4
52.9
86.0
77.1
42.9
113.6
156.9
47.9
120.7
156.8
47.5
77.3
98.2
Annual
mills/kWh
2.19
4.71
8.62
7.83
8.40
1.70
14.35
2.75

0.27
2.10
2.10
14.86
1.99
14.35

1.61
2.99
Adjusted
Capital
$/kW
56.0
70.8
127.2
140.6
100.6
87.3
68.0
77.6
80.6
67.5
76.5
93.1
77.3
60.9
107.9
145.5
71.9
102.9
233.3
66.5
117.7
113.2
Annual
mills/kWh
2.58
7.42
7.81
8.57
6.56
4.35
3.78
5.24
5.78
5.56
6.51
5.16
4.06
3.20
4.38
12.73
2.77
8.68

2.92
6.17
5.28
  Annual costs were not reported by the utility for this system
  because of the lack of meaningful data due to recent operating
  status.


  Annual costs were not reported by the utility for this system
  because of the lack of meaningful data due to peak load status
  of unit.


0 Annual cost data are being assembled by the utility.


* Newly operation units do not appear as cost data are currently
  being assembled.

                              A-18

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                 TABLE A-5.   CATEGORICAL RESULTS OF THE REPORTED AND ADJUSTED
                     CAPITAL AND ANNUAL COSTS FOR OPERATIONAL FGD SYSTEMS

All
New
Retrofit
erable
Regenerable
Limestone
Live
Alkaline/fly
ash/1 iaestani
Alkaline ny
ash/line
Sodiua
Magnesium
oxide
Reported Adjusted
Capital
Range, S/kH
29.3-156.9
47.5-120.7
29.3-156.9
29.3-120.7
L56.8-156.9
47.5-99.5
29.3-120.7
47.9
77.1-86.0
42.9-113.6
156.8
Avg..
SAW
78.0
78.8
77.2
71.7
156.8
71.4
75.3
47.9
81.6
78.3
156.8
0
35.7
27.8
42.9
28.7
0.1
23.7
34.6

6.3
50.0

Annual
Range
mills/la*
0.27-14.86
0.27-14.35
2.10-14.86
0.27-14.35
14.86
1.61-2.99
2.75-14.35
1.99
0.27
2.10

Avg..
mills/kWh
5.6
4.3
7.4
5.2
14.9
2.1
9.3

0.27
2.1

Capital
o
5.1
5.4
5.4
4.8

0.6
4.3




Range, SAW
56.0-233.3
66.5-117.7
56.0-233.3
56.0-140.6
145.5-233.3
56.0-117.7
67.5-140.6
71.5
77.3-93.1
60.9-107.9
233.3
Avg.,
SAW
94.2
86.8
101.0
86.5
189.4
87.0
92.8
71.5
85.2
84.4
233.3
o
36.9
17.8
48.2
22.3
62.1
26.7
23.5

11.2
33.2

Annual
Range
millsAHh
2.58-12.73
2.77-8.68
2.58-12.73
2.58-8.68
12.73
2.58-6.56
4.35-8.68
2.77
4.06-5.16
3.20-4.38

Avg..
5.5
5.2
5.8
5.2
12.73
4.5
6.6
2.77
4.6
3.8

o
2.4
2.1
2.7
1.9

1.7
1.7

0.8
0.8

M
VO

-------
EPA UTILITY F6D SURVEY: OCTOBER 1978 - NOVEMBER 1978

                           SECTION A-l  FGD SYSTEM ECONOMICS: OPERATIONAL SYSTEMS

                                     REPORTED AND ADJUSTED COSTS
UTILITY
STATION
UNIT(S)
FGO MW
          ELEMENTS
         INCLUDED IN
         CAPITAL AND
         ANNUAL COSTS
            TOTAL     ANNUAL - MILLS/KWH
CAPACITY   CAPITAL  ———	
 FACTOR     S/KH    TOTAL  DIRECT   FIXED
    Z      (YEAR)          (YEAR)
ALABAMA ELECTRIC COOP
TOMBIGBEE
2
   255   C,E,J
 *************** REPORTED ***************
             69.5
           (1978)
 *************** ADJUSTED ***************
ARIZONA ELECTRIC POWER COOP
APACHE
2
   200   B,C
 *************** REPORTED ***************
              5.3
           (1978)
 *************** ADJUSTED ***************
ARIZONA PUBLIC SERVICE
CHOLLA
1
   126   B,C,E,S,U,X


         C,E,K,S,U,H
 *************** REPORTED ***************
     85      52.0    2.19
           (1973)          (1976)
 *************** ADJUSTED ***************
     65      56.0     2.56    .48    2.10
           (1977)          (1977)
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
   400   C,E,JrM
 *************** REPORTED ***************
             93.3    3.31
           (1978)          (1976)
 *************** ADJUSTED ***************
COLUMBUS & SOUTHERN OHIO ELEC.
CONESVILLE
5
   411   B,C,J,M,T,X       *************** REPORTED ***************
         ,Y                    51      55.6    4.71    4.71
                                     (1975)          (1977)
         C,E,J,M,S,U       *************** ADJUSTED ***************
         ,W,Y                  65      70.8     7.42   5.06    2.36
                                     (1977)          M977)
                                  COST ELEMENTS
    CAPITAL!
         A - PARTICULATE CONTROL (REQUIRED FOR FGD PROCESS) INCLUDED IN CAPITAL COST
         B - PARTICULATE CONTROL (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
         C - TOTAL DIRECT CAPITAL COSTS INCLUDED
         D - PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E - TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F - PARTIAL INDIRECT CAPITAL COSTS INCLUDED
         G • CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H - DRY SLUDGE DISPOSAL INCLUDED IN CAPITAL COST
         I - OFF-SITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J - SLUDGE POND INCLUDED IN CAPITAL COST
         K - ADDITONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L - STACK INCLUDED IN CAPITAL COST
         M - MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
         N • TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P - R * D COSTS INCLUDED IN CAPITAL COST
         0 - COSTS UNDERWRITTEN BY SYSTEM SUPPLIER INCLUDED IN CAPITAL COST
         R • EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST

    ANNUAL!
         S • TOTAL DIRECT ANNUAL COSTS INCLUDED
         T - PARTIAL DIRECT ANNUAL COSTS INCLUDED
         U • TOTAL FIXED ANNUAL COSTS INCLUDED
         V - PARTIAL FIXED ANNUAL COSTS INCLUDED
         H - OVERHEAD COSTS INCLUDED IN TOTAL ANNUAL COSTS
         X • PARTICULATE CONTROL COSTS INCLUDED IN DIRECT ANNUAL COSTS
         Y • SLUDGE DISPOSAL SERVICE COSTS (CONTRACT) INCLUDED IN DIRECT ANNUAL COSTS
         Z • REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
                                                A -

-------
UTILITY
STATION
UNIT(S)
                       EPA UTILITY FGD SURVEY: OCTOBER 1978 - NOVEMBER 197H


SECTION A-l  FGD SYSTEM ECONOMICS: OPERATIONAL SYSTEMS


          REPORTED AND ADJUSTED COSTS


              ELEMENTS

             INCLUDED IN
             CAPITAL AND
    FGO MW   ANNUAL COSTS
COLUMBUS & SOUTHERN  OHIO  ELEC.     411    B,C,J,M,T.X
CONESVILLE                               , Y
6

                                         C,E,J,M,S,U
                                         ,W,Y
CAPACITY
FACTOR
Z
TOTAL
CAPITAL
S/KW
(YEAR)
ANNUAL - MILLS/KHH
TOTAL DIRECT
(YEAR)
FIXED
                               *************** REPORTED ***************

                                   51      55.6
                                         (1975)
                               *************** ADJUSTED ***************

                                   65      70.8
                                         (1977)
DUUUESNE LIGHT
ELRAMA POWER STATION
       510   B,D,F,I,J,M

             »T,V,X,Y


             C,E,I,J,M,S
             »U,Y
*************** REPORTED ***************

    64     113.5    6.62    2.83    5.79
          (1976)          (1977)
*************** ADJUSTED ***************

    65     127.3     7.81   3.36    4.U,W,Y
                               ***************  REPORTED  ***************

                                           99.5
                                         (1976)
                               ***************  ADJUSTED  ***************

                                   65      100.6     6.56   3.57     2.99
                                         (1977)          (1977)
KANSAS CITY POWER * LIGHT
HAWTHORN
3
       110   B,D,F,T,X
                                        ,u,w,x
*************** REPORTED ***************

    14      29.3    8.40
          (1972)          (1977)
*************** ADJUSTED ***************

    65      67.3     4.35   2.93     1.42
          (1977)          (1977)
                                  COST ELEMENTS
    CAPITAL:
         A - PARTICULATE CONTROL (REQUIRED FOR FGD PROCESS) INCLUDED IN CAPITAL COST
         B - PARTICULATE CONTROL (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
         C - TOTAL DIRECT CAPITAL COSTS INCLUDED
         0 - PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E - TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F - PARTIAL INDIRECT CAPITAL COSTS INCLUDED
         G - CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H - DRY SLUDGE DISPOSAL INCLUDED IN CAPITAL COST
         I - OFF-SITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J • SLUDGE POND INCLUDED IN CAPITAL COST
         K - ADDITONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L • STACK INCLUDED IN CAPITAL COST
         M - MODIFICATIONS TO STACK, DUCTS, AND/UR FANS INCLUDED IN CAPITAL COST
         N • TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P - R * D COSTS INCLUDED IN CAPITAL COST
         0 • COSTS UNDERWRITTEN BY  SYSTEM SUPPLIER INCLUDED IN CAPITAL COST
         R - EXCESS REAGENT SUPPLY  COSTS INCLUDED IN CAPITAL COST

    ANNUAL:
         S - TOTAL DIRECT ANNUAL COSTS INCLUDED
         T - PARTIAL DIRECT ANNUAL  COSTS INCLUDED
         U - TOTAL FIXED ANNUAL COSTS INCLUDED
         V - PARTIAL FIXED ANNUAL COSTS INCLUDED
         W - OVERHEAD COSTS INCLUDED IN TOTAL ANNUAL COSTS
         X - PARTICULATE CONTROL COSTS INCLUDED IN DIRECT ANNUAL COSTS
         V - SLUDGE DISPOSAL SERVICE COSTS (CONTRACT)  INCLUDED IN DIRECT ANNUAL COSTS
         Z • REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
                                                A -21

-------
EPA UTILITY FGO SURVEY! OCTOBER 1978 - NOVEMBER 1978


                           SECTION A-l  FGO SYSTEM ECONOMICS: OPERATIONAL SYSTEMS


                                     REPORTED AND ADJUSTED COSTS


                                                                               ANNUAL - MILLS/KWH
UTILITY
STATION
UNIT(S)
                FGD MM
                          ELEMENTS
                         INCLUDED IN
                         CAPITAL AND
                         ANNUAL COSTS
                                   TOTAL
                       CAPACITY   CAPITAL	
                        FACTOR     S/KK    TOTAL  DIRECT   FIXED
                           X      (YEAR)          IYEAR)
KANSAS CITY POKER & LIGHT
HAHTHORN
4
                   110   B,D,F,T,X
                                        B,C,E,J,K,S
                                        ,U,w,X
                        *************** REPORTED ***************
                            10      29.3    8.40
                                  (1972)          (1977)
                        *************** ADJUSTED ***************
                            65      87.3     4.35   2.93    1.42
                                  (1977)          (1977)
KANSAS CITY POWER & LIGHT
LA CYGNE
1
                   874   B,C,E,J,S
                                        C,£,J,K,S,U
                        *************** REPORTED ***************
                            30      53.7    1.70    1.70
                                  (1972)          (1977)
                        *************** ADJUSTED ***************
                            65      60.0     3.76   1.70    d.06
                                  (1977)          (1977)
KENTUCKY UTILITIES
GREEN RIVER
1,2 ft 3
                    64   B,C,E,J,S,U       *************** REPORTED ***************
                         ,H                    16      70.3   14.35    5.06    9.29
                                                     (1975)          (197H
                         c,E,J,s,u,w       *************** ADJUSTED ***************
                                               65      77.6     5.24   2.71    2.53
                                                     (1977)          (1977)
LOUISVILLE GAS
CANE RUN
4
& ELECTRIC
190   C.E,H,J,Q,T
                                        C,E,H,J,K,Q
                                        ,S,U,W
*************** REPORTED ***************
    55      66.6    2.75
          (1975)          (1977)
*************** ADJUSTED ***************
    65      80.6     5.78   3.62    2.16
          (1977)          (1977)
LOUISVILLE GAS
CANE RUN
5
& ELECTRIC
200   C,E,H,J
                                        »U,W
*************** REPORTED ***************
            62.4
          (1977)
*************** ADJUSTED ***************
    65      67.5     5.56   3.47    2.09
          (1977)          (1977)
                                  COST ELEMENTS
    CAPITAL:
         A - PARTICULATE CONTROL (REQUIRED FOR FGO PROCESS) INCLUDED IN CAPITAL COST
         B - PARTICULATE CONTROL (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
         C • TOTAL DIRECT CAPITAL COSTS INCLUDED
         0 - PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E - TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F - PARTIAL INDIRECT CAPITAL COSTS INCLUDED
         6 - CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H • DRV SLUDGE DISPOSAL INCLUDED IN CAPITAL COST
         I • OFF-SITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J - SLUDGE POND INCLUDED IN CAPITAL COST
         K - AODITONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L - STACK INCLUDED IN CAPITAL COST
         M - MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
         N • TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P - R & D COSTS INCLUDED IN CAPITAL COST
         0 - COSTS UNDERWRITTEN BY SYSTEM SUPPLIER INCLUDED IN CAPITAL CUST
         R - EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST

    ANNUALS
         S - TOTAL DIRECT ANNUAL COSTS INCLUDED
         T - PARTIAL DIRECT ANNUAL COSTS INCLUDED
         U - TOTAL FIXED ANNUAL COSTS INCLUDED
         V - PARTIAL FIXED ANNUAL COSTS INCLUDED
         M - OVERHEAD COSTS INCLUDED IN TOTAL ANNUAL COSTS
         X - PARTICULATE CONTROL COSTS INCLUDED IN DIRECT ANNUAL COSTS
         V - SLUDGE DISPOSAL SERVICE COSTS (CONTRACT) INCLUDED IN DIRECT ANNUAL COSTS
         Z - REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
                                                A -22

-------
UTILITY
STATION
UNIT(S)
                                                   EPA  UTILITY  FGO  SURVE":  OCTOBER  1978  - NOVtMHtK 1976


                            SECTION A-l   FGO  SYSTEM ECONOMICS:  OPERATIONAL  SYSTEMS


                                      REPORTED  AND  ADJUSTED  COSTS


                                                                                ANNUAL  - MILLS/KrtH
          ELEMENTS
         INCLUDED IN

         CAPITAL AND
FGO MW   ANNUAL COSTS
LOUISVILLE  GAS  &  ELECTRIC
PADDYS RUN
6
    70   C,E



         C,E,S,U,W
                                   TOTAL
                       CAPACITY   CAPITAL

                        FACTOR     S/KW    TOTAL  DIHtCT   FIXED
                           X      (YEAR)          CYEAK)
                        *************** REPORTED ***************
                                    52.9
                                  11973)
                        *************** ADJUSTED ***************
                            65      76.5     b.51    3.9d    2.59
                                  (1977)          (1977)
MINNKOTA POWER  COOPERATIVE
MILTON R. YOUNG
a
177   C,E,H,P



      C,E,H,M,P,S
                           *************** KEPORTED ***************

                                       86. 0
                                     (1976)
                           *************** ADJUSTED ***************

                               65      93.1     5.16   1.85    3.M

                                     (1977)          (1977)
MONTANA POWER
COLSTRIP
1
   330   B,C,E,J,P,T



         C,ErJ»K,P,S
                        *************** KEPORTED ***************
                            76      77.1      .27     .27
                                  (1975)           (1977)
                        *************** ADJUSTED ***************

                            65      77.3      4.06   1.51     ci.55
                                  (1977)           (1977)
MONTANA POWER
COLSTRIP
   330   B,C,E,J,P,T



         C,E,J,K,P,S
         »U,W
                        ***************  REPORTED  ***************
                            76       77.1      .27      .27
                                  (1975)           (1977)
                        ***************  ADJUSTED  ***************
                            65       77.3      4.06   1.51     2.55
                                  (1977)           (1977)
NEVADA POWER
REID GARDNER
1
   125   B,0,E,P,S,U
         fW,X


         B,C,E,J,P,S
         ,U,W,X
                        ***************  REPORTED  ***************
                            67       42.9    2.10     1.30      .t>0
                                  (1973)           (1977)
                        ***************  ADJUSTED  ***************

                            65       60.9     3.20    1.30     1.90
                                  (1977)           (1977)
                                  COST ELEMENTS
    CAPITAL:
         A - PARTICULATE CONTROL  (REQUIRED FOR FGD PROCESS) INCLUDED IN CAPITAL COST
         B - PARTICULATE CONTROL  (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
         C - TOTAL DIRECT CAPITAL COSTS INCLUDED
         D - PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E - TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F - PARTIAL INDIRECT CAPITAL COSTS INCLUDED
         G - CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H - DRY SLUDGE DISPOSAL  INCLUDED IN CAPITAL COST
         I - OFF-SITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J - SLUDGE POND INCLUDED IN CAPITAL COST
         K - ADDITONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L - STACK INCLUDED IN CAPITAL COST
         M - MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
         N - TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P - R * D COSTS INCLUDED IN CAPITAL COST
         0 • COSTS UNDERWRITTEN BY SYSTEM SUPPLIER INCLUDED IN CAPITAL COST
         R - EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST

    ANNUALS
         3 - TOTAL DIRECT ANNUAL COSTS INCLUDED
         T - PARTIAL DIRECT ANNUAL COSTS INCLUDED
         U • TOTAL FIXED ANNUAL COSTS INCLUDED
         V - PARTIAL FIXED ANNUAL COSTS INCLUDED
         M - OVERHEAD COSTS INCLUDED IN TOTAL ANNUAL COSTS
         x • PARTICULATE CONTROL COSTS INCLUDED IN DIRECT ANNUAL COSTS
         V - SLU06E DISPOSAL SERVICE COSTS (CONTRACT) INCLUDED IN DIRECT ANNUAL COSTS
         Z - REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
                                                A -83

-------
EPA UTILITY FGD SURVEY: OCTOBER 1976 - NOVEMBER 1978


                           SECTION A-l  FGO SYSTEM ECONOMICS: OPERATIONAL SYSTEMS


                                     REPORTED AND ADJUSTED COSTS
UTILITY
STATION
UNIT(S)
          ELEMENTS                    TOTAL     ANNUAL - MILLS/KWH
         INCLUDED IN      CAPACITY   CAPITAL	
         CAPITAL AND       FACTOR     S/KW    TOTAL  DIKECT   FIXED
FGD MM   ANNUAL COSTS         X      (YEAR)          IYEAR)
NEVADA POWER
REID GARDNER
2
   125   BfDfErPfS>U       *************** REPORTED ***************
         ,W,X                  67      42.9    2.10    1.30     .80
                                     (1973)          (1977)
         B*C«ErJ,P,S       *************** ADJUSTED ***************
         ,U,H,X                65      60.9     3.20   1.30    l.<*0
                                     (1977)          (1977)
NEVADA POWER
REID GARDNER
3
   12S   B,C,E,L,S,U
                                        B,C,E,S,U,W
*************** REPORTED ***************
    67     113.6    2.10    1.30     .00
          (1975)          (1977)
*************** ADJUSTED ***************
    65     107.9     4.30   1.30    3.00
          (1977)          (1977)
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
    92   B,CrE,L,N,S
         ,U,W,X,Z


         C,E,L,N,S,U
         »H,Z
*************** REPORTED ***************
    77     156.9   14.86    6.47    8.39
          (1976)          (1976)
*************** ADJUSTED ***************
    65     145.5    12.73   7.54    5.19
          (1977)          (1977)
NORTHERN STATES POWER
SHERBURNE
1
   720   B,C,J,S,U,X
         ,Z


         C,E,J,K,S,U
         rW
*************** REROUTED ***************

    73      47.9    1.99    1.06     .93
          (1972)          (1977)
*************** ADJUSTED ***************
    65      71.5     2.77    .75    2.02
          (1977)          (1977)
NORTHERN STATES POWER
SHERBURNE
2
   720   B,C,J,S,U,X
         ,Z


         C,E,J,K,S,U
         iW
*************** REPORTED ***************
    73      47.9    1.99    1.06     .93
          (1972)          (1977)
*************** ADJUSTED ***************
    65      71.5     2.77    .75    2.02
          (1977)          (1977)
                                  COST ELEMENTS
    CAPITAL:          .               .  .
         A - PARTICULATE CONTROL (REQUIRED FOR FGD PROCESS) INCLUDED IN CAPITAL COST
         B - PARTICULATE CONTROL (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
         C - TOTAL DIRECT CAPITAL COSTS INCLUDED
         0 - PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E - TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F - PARTIAL INDIRECT CAPITAL COSTS INCLUDED
         6 - CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H - DRY SLUDGE DISPOSAL INCLUDED IN CAPITAL COST
         I - OFF-SITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J - SLUDGE POND INCLUDED IN CAPITAL COST
         K - ADDITONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L - STACK INCLUDED IN CAPITAL COST
         M - MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
         N - TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P • R * 0 COSTS INCLUDED IN CAPITAL COST
         0 - COSTS UNDERWRITTEN BY SYSTEM SUPPLIER INCLUDED IN CAPITAL COST
         R - EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST

    ANNUALS
         8 • TOTAL DIRECT ANNUAL COSTS INCLUDED
         T - PARTIAL DIRECT ANNUAL COSTS INCLUDED
         U • TOTAL FIXED ANNUAL COSTS INCLUDED
         V - PARTIAL FIXED ANNUAL COSTS INCLUDED
         H - OVERHEAD COSTS INCLUDED IN TOTAL ANNUAL COSTS
         X » PARTICULATE CONTROL COSTS INCLUDED IN DIRECT ANNUAL COSTS
         V - SLUDGE DISPOSAL SERVICE COSTS (CONTRACT) INCLUDED IN DIRECT ANNUAL COSTS
         Z • REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
                                                A -24

-------
UTILITY
STATION
UNIT(S)
                       EPA UTILITY FGD SURVEY:  OCTOBER 1978 - NOVEMBER 1978


SECTION A-l  FGD SYSTEM ECONOMICS: OPERATIONAL  SYSTEMS


          REPORTED AND ADJUSTED COSTS


              ELEMENTS
             INCLUDED IN
             CAPITAL AND
    FGD MW   ANNUAL COSTS
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
       917
             B,C,E,G,I,L
             ,S,U,W,X
                                              p I ? M * S
                                         fU,W
CAPACITY
FACTOR
X
TOTAL
CAPITAL
S/KW
(YEAH)
ANNUAL - MILLS/KWH
TOTAL DIRECT
(YEAH)
FIXED
*************** REPORTED ***************
                                   40
                                                  11.34
                                                           4.08

                                                         (1977)
           120.7

          (1975)
*************** ADJUSTED *******

    65     102.1     8.68   5.51

          (1977)          (1977)
                                                                  10.26
                                                                                               3.17
PENNSYLVANIA POWER

BRUCE MANSFIELD
2
       917   B,C,E,G,I,L       ***************  REPORTED  ***************
             ,S,U,W,X               40      120.7   14.34     4.08    10.26
                                         (1975)          (1977)
             C,E,G,I,M,S       ***************  ADJUSTED  ***************

             'U'H                  65      102.1     8.68   5.51     3.17
                                         (1977)          (1977)
PHILADELPHIA ELECTRIC
EODYSTONE
1A
       105   D,F,N,P



             C,E,N,P
*************** REPORTED ***************

           156.8
          (1972)
*************** ADJUSTED ***************

           233.3
          (1977)
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
i
       357    A,C,E,N
                               ***************  REPORTED  ***************

                                          127.9
                                         (1977)
                               ***************  ADJUSTED  ***************
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
       357    A,C,E,N
                               ***************  REPORTED  ***************
                                          127.9
                                         (1977)
                               ***************  ADJUSTED  ***************
                                  COST ELEMENTS
    CAPITAL:
         A - PARTICULAR CONTROL  (REQUIRED FUR F6D PROCESS) INCLUDED IN CAPITAL COST
         B - PARTICULATE CONTROL  (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
         C - TOTAL DIRECT CAPITAL COSTS INCLUDED
         D - PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E • TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F • PARTIAL INDIRECT CAPITAL COSTS INCLUDED
         6 - CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H - DRY SLUDGE DISPOSAL  INCLUDED IN CAPITAL COST
         I - OFF-SITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J - SLUDGE POND INCLUDED IN CAPITAL COST
         K - AOOITONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L - STACK INCLUDED IN CAPITAL COST
         M - MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
         N - TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P - R S 0 COSTS INCLUDED IN CAPITAL COST
         Q - COSTS UNDERWRITTEN BY SYSTEM SUPPLIER INCLUDED IN CAPITAL COST
         R - EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST

    ANNUAL:
         S - TOTAL DIRECT ANNUAL COSTS INCLUDED
         T - PARTIAL DIRECT ANNUAL COSTS INCLUDED
         U - TOTAL FIXED ANNUAL COSTS INCLUDED
         V - PARTIAL FIXED ANNUAL COSTS INCLUDED
         N - OVERHEAD COSTS INCLUDED IN TOTAL ANNUAL COSTS
         X - PARTICULATE CONTROL COSTS INCLUDED IN DIRECT ANNUAL COSTS
         Y - SLUDGE DISPOSAL SERVICE COSTS (CONTRACT)  INCLUDED IN DIRECT ANNUAL COSTS
         2 - REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
                                                A -25

-------
EPA UTILITY FGD SURVEYS OCTOBER 1978 - NOVEMBER 1976
                           SECTION A-l  FGO SYSTEM ECONOMICS: OPERATIONAL SYSTEMS

                                     REPORTED AND ADJUSTED COSTS
                                                                               ANNUAL - MILLS/KWH
UTILITY
STATION
UNIT(S)
                               FGD MW
       ELEMENTS
      INCLUDED IN
      CAPITAL AND
      ANNUAL COSTS
                                                                     TOTAL
                                                         CAPACITY   CAPITAL	
                                                          FACTOR     S/KW    TOTAL  DIKECT   FIXED
                                                             X      (YEAR)          (YEAR)
SOUTH CAROLINA PUBLIC SERVICE
WINY AH
2
                                  140   C,F,J,M,S,V
                                        ,u,w
                        *************** KEPOKTtD ***************
                            ao      47.5    i.bi     .«8     .73
                                  (1976)          (1977)
                        *************** ADJUSTED ***************
                            65      66.5     2.92   1.04    l.dtt
                                  (1977)          (1977)
SOUTHERN MISSISSIPPI ELECTRIC
R. D. MORROW
1
                                  160
      CrE
*************** REROUTED ***************
            37.4
          (1975)
*************** ADJUSTED ***************
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
194   C,F,H,J,P


      C,E,H,J,K,P
                                                          *************** REPORTED ***************
                                                                      77.3
                                                                    (1974)
                                                          *************** ADJUSTED ***************
                                                              65     117.7     6.17   2.87    3.30
                                                                    (1977)          (1977)
TENNESSEE VALLEY AUTHORITY
NIOONS CREEK
6
                                  550   B,C,E,P,R,T
                                        ,U

                                        C,E,J,S,U,W
                        *************** REPORTED ***************
                            60      98.2    2.99
                                  (1976)          (1977)
                        *************** ADJUSTED ***************
                            65     113.2     5.28   1.44    3.84
                                  (1977)          (1977)
TEXAS UTILITIES
MONTICELLO
3
                                  750
                        *************** REPORTED ***************
                                    25.0
                                  (1978)
                        *************** ADJUSTED ***************
                                  COST ELEMENTS
    CAPITAL:
         A - PARTICULATE CONTROL (REQUIRED FOR FGD PROCESS) INCLUDED IN CAPITAL COST
         B • PARTICULATE CONTROL (INCLUDED IN FGO PROCESS) INCLUDED IN CAPITAL COST
         C - TOTAL DIRECT CAPITAL COSTS INCLUDED
         D - PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E - TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F • PARTIAL INDIRECT CAPITAL COSTS INCLUDED
         G • CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H - DRY SLUDGE DISPOSAL INCLUDED IN CAPITAL COST
         I - OFF-SITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J • SLUDGE POND INCLUDED IN CAPITAL COST
         K • ADDITONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L • STACK INCLUDED IN CAPITAL COST
         M - MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
         N • TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 • PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P - R » D COSTS INCLUDED IN CAPITAL COST
         0 • COSTS UNDERWRITTEN BY SYSTEM SUPPLIER INCLUDED IN CAPITAL COST
         R • EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST

    ANNUAL I
         8 - TOTAL DIRECT ANNUAL COSTS INCLUDED
         T - PARTIAL DIRECT ANNUAL COSTS INCLUDED
         U • TOTAL FIXED ANNUAL COSTS INCLUDED
         V - PARTIAL FIXED ANNUAL COSTS INCLUDED
         N - OVERHEAD C08T8 INCLUDED IN TOTAL ANNUAL COSTS
         X - PARTICULATE CONTROL C08T8 INCLUDED IN DIRECT ANNUAL COSTS
         Y - 8LUD6E DISPOSAL SERVICE COSTS (CONTRACT) INCLUDED IN DIRECT ANNUAL COSTS
         Z • REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
                                                A -26

-------
UTILITY
STATION
UNIT(S)
                         EPA UTILITY  FGO  SURVEY:  OCTOBER  1978  - NOVEMBER 197«

SECTION A-a  FGD SYSTEM ECONOMICS:  NONOPERATIONAL SYSTEMS

            REPORTED AND ADJUSTED COSTS


                                                      ANNUAL - MILLS/KWH

                                                                    FIXED
                                         ELEMENTS
                                         INCLUDED IN
                                         CAPITAL AND
                               FGD MW    ANNUAL COSTS
ALABAMA ELECTRIC  COOP
TOMBIGBEE
3
                                   ass   C.E.J
            TOTAL
CAPACITY   CAPITAL
 FACTOR     S/Kn    TOTAL
    X      (YEAR)          (YEAR)
                                                          *************** KEPURTED ***************
                                                                      69.5
                                                                     (197tt)
ARIZONA ELECTRIC POWER COOP
APACHE
3
                                   200   B,C
                                                          *************** KEPORTED ***************
                                                                       5.3
                                                                     (1978)
BASIN ELECTRIC POWER COOP
LARAHIE RIVER
1
                                  550   C,E
                                                          *************** REPORTED ***************
                                                                      68.a
                                                                    (1980)
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
2
                                   550
                                        C,E
                                                          *************** REPORTED ***************
                                                                      68.a
                                                                     (198U)
BIG RIVERS ELECTRIC
GREEN
i
                                   250   B,C
                                                          *************** REPORTED ***************
                                                                      43.3
                                                                     (1976)
BOSTON EDISON
MYSTIC
6
                                   155   B,C,E,N,0
                                                          *************** REPORTED ***************
                                                                      63.1    3.00
                                                                    (1972)          (1971)
CENTRAL ILLINOIS PUBLIC SERV
NENTON
i
                                  575   C,E,G
                                                          *************** REPORTED ***************
                                                                     189. 0
                                                                    (1979)
COLORADO UTE ELECTRIC ASSN.
CRAIG
1
                                  450   B,D,E
                                 ***************  REPORTED  ***************
                                            117.0
                                           (1979)
                                  COST ELEMENTS
    CAPITAL!    .                .
         A • PARTICULATE CONTROL (REQUIRED FOR FGD PROCESS) INCLUDED IN CAPITAL COST
         B - PARTICULATE CONTROL (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
         C - TOTAL DIRECT CAPITAL COSTS INCLUDED
         D - PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E - TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F - PARITAL INDIRECT CAPITAL COSTS INCLUDED
         6 • CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H • DRY SLUDGE DISPOSAL INCLUDED IN CAPITAL COST
         I • OFF-BITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J • SLUDGE POND INCLUDED IN CAPITAL COST
         K - AOOITONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L • STACK INCLUDED IN CAPITAL COST
         H • MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
         N - TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P • R t D COSTS INCLUDED IN CAPITAL COST
         0 - COSTS UNDERWRITTEN BY SYSTEM SUPPLIER INCLUDED IN CAPITAL COST
         R - EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST
    ANNUAL!
         S •
         T •
         U •
         V •
         N •
         X
             TOTAL DIRECT ANNUAL COSTS INCLUDED
             PARTIAL DIRECT ANNUAL COSTS INCLUDED
             TOTAL FIXED ANNUAL COSTS INCLUDED
             PARTIAL FIXED ANNUAL COSTS INCLUDED
             OVERHEAD COSTS INCLUDED IN TOTAL ANNUAL COSTS
             PARTICULATE CONTROL COSTS INCLUDED IN DIRECT  ANNUAL  COSTS
         V  . SLUDGE DISPOSAL SERVICE COSTS (CONTRACT)  INCLUDED IN DIRECT ANNUAL COSTS
         Z  - REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT  ANNUAL COSTS
                                                A -27

-------
EP» UTILITY F60 SURVEY: OCTOBER 1976 - NOVEMBER 1978

                         SECTION A-2  FGD SYSTEM ECONOMICS: NONOPERATIONAL SYSTEMS

                                     REPORTED AND ADJUSTED COSTS

                                                                               ANNUAL - MILLS/KWH
UTILITY
STATION

UNIT(S)
                           ELEMENTS

                          INCLUDED IN
                          CAPITAL AND
                 FGD MM   ANNUAL COSTS
                                   TOTAL
                       CAPACITY   CAPITAL  —	——	
                        FACTOR     S/KW    TCHAL  DIHECT   FIXED
                           X      (YEAR)          (YEAR)
COLORADO UTE ELECTRIC ASSN.
CRAIG
2
                                  450
                          A,C
                        *************** REPORTED ***************

                                   117.0
                                  (1979)
COMMONWEALTH EDISON

POWERTON

SI
                    425   C,E,H,J
                        *************** REPORTED ***************
                                   117.7
                                  (1979)
COMMONWEALTH EDISON

WILL COUNTY
1
                    167   B,C,E,G,J,X
                        *************** REPORTED ***************
                            49     113.0   13.06
                                  (1972)          (1975)
DETROIT EDISON
ST. CLAIR
6
                    163   B,C,E,J,M,X
                        *************** REPORTED ***************
                                    80.3    9.60
                                  (1976)          (1976)
ILLINOIS POWER
HOOD RIVER
4
                    110   A,CrE,M,N
                        *************** REPORTED ***************
                                    82.5
                                  (1972)
LOUISVILLE GAS
CANE RUN
6
 ft ELECTRIC
277   C»E»H,M,S,V       *************** REPORTED ***************
      ,W                            57.9    3.24    1.92    1.32
                                  (1977)          (1979)
PACIFIC POWER
JIM BRIDGER
4
& LIGHT
509   C,E,J
*************** REPORTED ***************
           120.0
          (1979)
POTOMAC ELECTRIC POWER
OICKERSON

3
                    190   A,C,E,M
                        *************** REPORTED
                                    68.0
                                  (1973)
                                                                                   ***************
                                  COST ELEMENTS
    CAPITAL:
         A - PARTICULATE CONTROL (REQUIRED FOR FGD PROCESS) INCLUDED IN CAPITAL COST
         B - PARTICULATE CONTROL (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
         C - TOTAL DIRECT CAPITAL COSTS INCLUDED
         D • PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E - TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F - PARITAL INDIRECT CAPITAL COSTS INCLUDED
         G - CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H • DRY SLUDGE DISPOSAL INCLUDED IN CAPITAL COST
         I - OFF-SITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J - SLUDGE POND INCLUDED IN CAPITAL COST
         K - AODITONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L - STACK INCLUDED IN CAPITAL COST
         M - MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
         N • TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P - R * D COSTS INCLUDED IN CAPITAL COST
         Q - COSTS UNDERWRITTEN BY SYSTEM SUPPLIER INCLUDED IN CAPITAL COST
         R - EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST

    ANNUAL:
         8 - TOTAL DIRECT ANNUAL COSTS INCLUDED
         T - PARTIAL DIRECT ANNUAL COSTS INCLUDED
         U • TOTAL FIXED ANNUAL COSTS INCLUDED
         V - PARTIAL FIXED ANNUAL COSTS INCLUDED
         W • OVERHEAD COSTS INCLUDED IN TOTAL ANNUAL COSTS
         X - PARTICULATE CONTROL COSTS INCLUDED IN DIRECT ANNUAL COSTS
         V - SLUDGE DISPOSAL SERVICE COSTS (CONTRACT) INCLUDED IN DIRECT ANNUAL COSTS
         Z - REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
                                                A -26

-------
                                                   EPA  UTILITY  FGD  SURVEY:  OCTOBER  1978  -  NOVEMBEK  197a

                          SECTION  A-2   F60  SYSTEM  ECONOMICS:  NONOPERATIONAL  SYSTEMS

                                      REPORTED  AND ADJUSTED COSTS
UTILITY
STATION
UNIT(S)
                                 ELEMENTS
                                INCLUDED IN
                                CAPITAL AND
                       FGD MN   ANNUAL COSTS
PUBLIC SERVICE  OF  COLORADO
VALMONT
                           50   B,C,E,J
            TOTAL     ANNUAL - MILLS/KWH
CAPACITY   CAPITAL	.	
 FACTOR     S/KW    TOTAL  DIRECT   FIXEU
    X      (YEAR)          (YEAR)
                                                  *************** REPORTED ***************
                                                              67.0
                                                            (1974)
SALT RIVER PROJECT
CORONADO
1
                          350   C,E
                                                  ***************  REPORTED ***************
                                                              96.0
                                                            C1978)
SALT RIVER PROJECT
CORONADO
2
                          350   C,E
                                                  ***************  REPORTED  ***************
                                                              98.0
                                                            (197B)
SOUTHERN INDIANA GAS ft ELEC
A. B. BROWN
1
                          250   C,E,G
                                                  ***************  REPORTED  ***************
                                                              43.2
                                                            (1979)
SOUTHERN MISSISSIPPI ELECTRIC
R. 0. MORROW
2
                          160   C,E
                                                  ***************  REPORTED  ***************
                                                              37.4
                                                            (1975)
WISCONSIN PONER I LIGHT
COLUMBIA
2
                          527
                                                  ***************  REPORTED  ***************
                                                              57.0
                                                            (1980)
                                  COST ELEMENTS
    CAPITAL*
         A - PARTICULATE CONTROL (REQUIRED FOR FGD PROCESS) INCLUDED IN CAPITAL COST
         B • PARTICULATE CONTROL (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
         C - TOTAL DIRECT CAPITAL COSTS INCLUDED
         0 - PARTIAL DIRECT CAPITAL COSTS INCLUDED
         E - TOTAL INDIRECT CAPITAL COSTS INCLUDED
         F - PARITAL INDIRECT CAPITAL COSTS INCLUDED
         6 - CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
         H - DRY SLUDGE DISPOSAL INCLUDED IN CAPITAL COST
         I - OFF-SITE LANDFILL AREA INCLUDED IN CAPITAL COST
         J - SLUDGE POND INCLUDED IN CAPITAL COST
         K - AD01TONAL SLUDGE DISPOSAL CAPACITY ADDED FOR LIFE OF SYSTEM
         L • STACK INCLUDED IN CAPITAL COST
         M - MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
         N - TOTAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
         P - R & D COSTS INCLUDED IN CAPITAL COST
         0 - COSTS UNDERWRITTEN BY  SYSTEM SUPPLIER INCLUDED IN CAPITAL COST
         R - EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST
    ANNUAL!
         3
         T
         U
         V
    TOTAL DIRECT ANNUAL COSTS INCLUDED
  - PARTIAL DIRECT ANNUAL COSTS INCLUDED
  - TOTAL FIXED ANNUAL COSTS INCLUDED
  • PARTIAL FIXED ANNUAL COSTS INCLUDED
W - OVERHEAD COSTS INCLUDED IN TOTAL ANNUAL COSTS
X • PARTICULATE CONTROL COSTS INCLUDED IN DIRECT ANNUAL COSTS
V - SLUDGE DISPOSAL SERVICE COSTS (CONTRACT) INCLUDED IN DIRECT ANNUAL COSTS
Z - REPLACEMENT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
                                                A  -29

-------
                      APPENDIX B
               FGD PROCESS FLOW DIAGRAMS
THIS APPENDIX COMPRISES BOTH ACTIVE AND INACTIVE UNITS
     ARRANGED ALPHABETICALLY ACCORDING TO UTILITY
                "SUPPLEMENTAL EDITION"
                   CHANGES/ADDITIONS
                         B-l

-------
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                  (Wit t)
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                                                                                                              SCMKI WttU
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                                                              Alabama  Electric,
                                            Simplified Process  Flow Diagram for Tomblgbee  2

-------
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                                       Simplified Process Flow Diagram

-------
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            Central  Illinois Light,
Simplified Process Flow Diagram of Duck Creek 1
    Power Plant  and Emission Control System

-------
CO
I
in
                                                                          TO STACK - aUE GASES


                                                                      HIST ELIMINATOR
         STORAGE
          SERVICE
          ttVTER
                            SLURRY
                           TRANSFER
                             TANK
*-4
SLURRY
STORAGE
TANK





^
                                     D

                               RECYCLE TANK
                                                      TO OTHER
                                                    RECYCLE TANK
SUMP
                                                                                            - OVERFIOM
                                                                                             TO ASH POND
                                                                                               FROM OTHER
                                                                                            - RECYCLE TANK
                                                                                                                                   TO IOCS
                                  Columbus and  Southern  Ohio Electric,  Conesville  5 and  6
                                     Simplified  Process  Flow  Diagram  for a  Riven Module

-------
CD
I
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                                   JET BUBBLING REACTOR
                             WATER
                                   —-"""-'^V   •...-—."  ff-.        ~^>"—
                                 - ..--^ **s,-.-.  ••' -//-   ---   y-
                                   ' -^	  s*1"' . -^X'/
                                         Gulf Power, Scholz 1  and 2
                                            Prototype FGD System,
                                       Simplified  Process Flow Diagram

-------
00

-J
                                                                                              ABSORBER
                                                                                             REJCIRCULATION
                                                                        ENTUR1
                                                                       SCRUBBER
  VENTURI
RECIRCULATION
PUMPS
                                                       RECIRCULATIO
                                                           TANKS
                                                                                       HYOROCLONE
                                                                                       CLASSIFIER
                                                                                                    LIMESTONE
                                                                                                    BUNKER
                                                           LIMESTONE
                                                             SLURRY   .
                                                            STORAGE^
                        BOILER
SETTLING POND
      WET BALL
        MILL
                                                Kansas City Power and  Light,
                                          LaCygne 1  FGD System:   General Diagram

-------
                                    FURNACE
                                                                DAMPERS
•3*

00
              TWO PRECIPITATORS
FOUR 1.0. FANS
                                                                              ONE
                                                                              STACK
                                                       WATER RETURN TO
                                                        REACTION TANKS
                                                                            BLEED PUMP

                                                                     RANSFER TANK
                                               FOUR,
                                             REACTION
                                               TANKS
                                                        SLUDGE DISPOSAL
                                                             POND
                                              Kansas Power and Light,
                        Schematic of Jeffrey Steam Generator and Emission Control  Equipment

-------
                                                      STACK
50
I
£>
        COAL  SUPPLY-
FEEDER
            PULVERIZER
                                                                       I.D. FAN
STACK GAS

  IR HEATER

    DEMISTER
TACK GAS REHEATER
                                                                                                        RECYCLE
                                                                                                        WATER
                                                              STACK'
                                                                GAS
                                                             SCRUBBER

                                                   Kansas  Power  and Light
                                   Original Operational FGD System at Lawrence No. 4.

-------
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EFF
                                                                                                                         REHEATER



                                                                                                                          	REHEATER BLOHER
                                                                                                             ABSORBEI
                                                                                                                             _NIST ELtmNATOR
                                                                                                                                 BLOMEK
                                                                                                                      STRAINER HASHER
                                                                                                                       (TYP.)
                                                                                                             TANK
                                                                   I
                                                                             MMBCf*!
                                                                             PUVS(Z)
                                                                                                                             STRAINER HASH
                                                                                                                             LINE (TYP.)
                                                                                                                                            ABSORBER
                                                                                                                                            SPRAY PUMP
                                                                                                            BLEED
                                                                                                                                    	|
                                                             Kansas Power and Light,
                                                    Lawrence  No.  4 Operational  FGD System
                                                        Simplified Process  Flow Diagram

-------
                                              STACK
OWL SUPPLY-
       FEEDER—ft*
     PULVERIZER
                                                                •I.D.  FAN
•STACK GAS REHEATER
                                                                                                 RECYCLE
                                                                                                 WATER
                                                       STACK'
                                                         GAS
                                                      SCRUBBER
                                      Kansas Power and Light
                                  Original  FGD System Installed at Lawrence No. 5:
                                   Simplified Process Flow Diagram.

-------
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                                                                                                                               n
   STACK I PONO RETURN
       1  (MAKE-UP)
	1    HATER
                                                                                                                                 HASH
                                                                                                                                 PUMP
                                                                                                                      'TO STRAINER  I
                                                                                                                      1  HASHERS"^

                                                                                                                      IHAKE-UP HATER
            lECIftC
            TANK
                 RECIRC4
                 PUMPS
                                                                                                                        EFFLUENT
                                                                                                                          BLEED
                                                                                                                                             	IHEIR
                                                                                                                                     THICKENER rOVERFLOM
                                                                                                                                    |^gl]	»-5ETTL

                                                                                                                                   THICKENER   POHI
                   SETTLING
                     PONO
                                                                                                                                UNOCRFLOH PUMPS
                                                                Kansas Power  and Light,
                                                       Lawrence  No.  5 Operational  FGD  System
                                                           Simplified Process Flow  Diagram

-------
09


CO
                                                            ELECTRICAL
                                                            GENERATING
                                                            UNIT NO. 1
  ELECTRICAL
  GENERATING
  UNIT NO. 2
                                                                    MECHANICAL
                                                                    COLLECTORS
                                                                                           EXISTING
                                                                                            STACK
                                                                                           K>fl      ™
                                                                                           BYPASS
SCRUBBER
BOOSTER
  FAN
                                                                                                             MAKEUP MATER


                                                                                                               MAKEUP MATER
                                                                                       RECYCLE      r^  MIX/HOLD TANK

                                                                                                  SPARE
                                                                          SPARE
                                                        Kentucky Utilities,
                                     Green  River FGD System:  General Process Diagram

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                                                        QUENCHER
                                                                    HIST
                                                                  ELIHINATOR
                                                                  (CHEVRON)

                                                                  CONTACTOR
                                                                  SCRUBBFR
                                                                   MODULE
           ELECTROSTATIC
           PRECIPITATOR
BOILER
 FLUE
 6AS
REACTION
  TANK
                                                                CONTACTOR
                                                                 SCRUBBER
                                                                  MODULE
                                                                           ABSORBER
                                                                            RECYCLE
                                              FAN
              MIST
            ELIHINATOR
             (CHEVRON)
                                                                                       I
              FLOCCUIANT
              ADDITION
                                                                                 THICKENER
T
,___Ly-l_
\ SETTLING / POND WATER RETURN
\ POND /
S.URGE '
TANK

                         Louisville  Gas and Electric, Cane Run 4
                       FGD System:   Simplified Process  Flow Diagram

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                                                                                                   REAGENT
                                                      •»TO STACK

                           ELECTROSTATIC
                           PRECIP1TATOR
DO
I
BOILER
 FLUE -
 GAS
                                                      -STEAM
                                                       REHEAT
                                                    SPRAY
                                                    TOWER
                                                                                          LIME SLURRY
                                                                                           FEED PUMP
\ \
REACTION
TANK



— 1 	
RECYCLE
PUMP
r*
i-
,


THK
/
                                   Louisville Gas and Electric,  Cane Run  5 FGD  System:
                                               Simplified Process  Flow Diagram

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CD
i
ot
                                                        EMERGENCY WATER
           PLENUM
            •  BLEED ^
                          MIST
                          ELIMINATORS
          -MXEAN FLUE GAS

     00-SEAL WATER  SUPPLY
JJNpERSPRAY	MAKEUP
                   WATER
                                                                                                   POND
                                                                                                   IETURN
                                                                                WASH TRAY POND
                                      FLY ASH POND
                                      Montana Power, Col strip F6D System:
                                         General Process Flow Diagram

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                                                                  TO CNIMCY
           MLVERIZCR
00
i
                                                                                                             EVAPORATION ram
                                                                                                                  ON MESA
                                      NUNMICM.
                                        OUST
                                      COLLECTOR
                                    (NULTICLONES]
                                                                                      REHEATER AIR FAN
                                                  •OILER
                                                  1.0. FAN
                               *—i—ri
TRAY RECYCLE PUMP

        SODA ASH
  THIN
VENTURI
THROAT
SCRUBBER
                                                     VENTURI RECYCLE
                                                         PUMP
                                         fURGC
                                       TO ASH POND
          SODA ASM
         SLURRY PUMP
                                             Nevada  Power, Reid Gardner 1,2, and 3
                                   General  Process  Flow Diagram  for  One  of the FGD Systems

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                   FLUE GAS
                     TO
                   SCRUBBER
                                     REHEATER
LIMESTONE —i
CO
i

00
                                       MIST
                                    ELIMINATOR
                                   OVERFLOW POTS
                                  AND MARBLE BED

                                   I.I
                                                              THICKENER
                                                              UNDERFLOW
                                                                PUMP
                                                                                                          ASH POND
                                                                                                         RETURN PUMP
                               Northern States Power,  Sherburne  1  and 2  FGD System:
                                           Simplified  Process Flow  Diagram

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                                                              TMMIII NOUU I
00
I
             Uttl.b*
             n
mxiwuu
    •mi
                                  Pennsylvania Power, Bruce  Mansfield FGD  System:
                                       Process Flow Diagram  for Unit 1 or  2

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r\>
o
  LIMESTONE
  FEED UN
(OK IN USE
  FOR WO
  •OILERS)
                                                                       MIST
                                                                         I  rwr
                                                                        (ONE IN USE
                                                                         ONE SPAKE)
                                                                                                     I
                                                                                                   VENTURI SOWER
                                                                                                    SCRUMERTN
                                                                                                    (ONE IN USE)
                                                                                        MSUP MATER
                                                                      HIST
                                                                    ELININA'
                                                                    TANK (ONE
                                                                    wIN USE)
,1
                                                                                                    I
                                                                                                    j
                                                1.0. FAN
                                              (WO IN UK)
               NEW mm
               (OK IN USE)
                                               NET CYCLONE
                                               CLASSIFIER
HETIALLNUL
(ONE IN USE)
          HILL SLURRY
             TANK   IMC
         (ORE IRUSE)lgii
                                                                          mi
                                                                       (ONE IN USE)
                                                                  I
                                                . MXER
                                                (ONE IN USE)
                                                                                                                                           FROM THICKENER
SLURRY STORA6E
g^m  TMNK
   (ONE IN USE)
                                                                             SLURRY
                                                                              PIMP
                                                                           (ONE IN USE
                                                                            ONE SPARE)
                                                                                   RECYCLE TANK
                                                                                   (ONE IN USE)
                                                                                                                       "*
                                THICKENER
                                 SUPPLY

                               (ONE IN USE)
                                                                                                                              PUNP
                                                                                                                           ONE IN USE
                                                                                                                           ONE SPARE)
                                                                                                 (TNO IN USE
                                                                                                  ONE SPARE)
                                                Southern  Mississippi  Electric  R.D.  Morrow 1,
                                                         Simplified  Process  Flow Diagram

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                                   SCRUBBER INLET
                                 TEST PORT LOCATION
                                                       •B" ABSORBER
                                                         NODULE
 TOP OF STACK
ELEVATION 1645*

   TEST PORT
ELEVATION 1516'
                 PRECIPITATOR
                  INLET TEST
                 PORT LOCATION
00

INS
                                                                               I—TOP OF OUTLET BREECHING
                                                                                  ELEVATION 1372'-2 3/8"
                                                                               L-TOP OF BYPASS BREECHING
                                                                                 ELEVATION 1307'- 8 1/2"
                                        SCRUBBER INLET
                                      TEST PORT LOCATION
                                               Springfield City  Utilities, Southwest  No.  1:
                                                           Simplified  Process Diagram

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                                             REHEATER
CO

ro
TNJ
                             "_"_ ITRAINS
                             *~~* IB,C, AND D
        ENTRAINMENT
         SEPARATOR
                     TO TRAINS
                     B.C. AND D
                                                                                 IjH
                                                                                 S7]
                                                                                 (T^
                    SLURRY PUMP
                    SEAL HATER
                     . HEADER
                    ' »J  •
              o
                 FROM B. C. AND D TRAIN
                VENTURI CIRCULATION TANKSI

                  TO SETTLING POND _
  VENTURI
CIRCULATION
 TANK AND
   PUMPS
  ABSORBER
CIRCULATION
  TANK AND
   PUMPS
                                                                                                      — RIVER HATER

                                                                                                      ^*  PUMPS  f


                                                                                                       FROM POND HATER
                                                                                                        RECYCLE PUMPS


                                                                                                 FROH LIMESTONE SLURRY
                                                                                                     I TRANSFER PUMPS
                                 EFFLUENT SLURRY
                               SURGE TANK AND PUMPS
TO TRAINS / *
B.C. AND DK

  LIMESTONE SLURRY
     FEED PUMPS
LIMESTONE SLURRY
  STORAGE TANK
                              Tennessee Valley Authority, Widows Creek 8 FGD  System:
                             Process Flow Diagram  for One of  the Four Scrubber Trains

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                                           FM OUTLET
                         FMNMIIEII
                        AIR PREHEATERS
ro
CO
                                                          PIMP SEAL
                                                          MATER TO
                                                          QUENCHER
                                                    euwppiM PUMPS
                                                    INF R US
                                                                                                            PUMP SEAL IMTER.
                                                                                                            •All Mill COOL INS
                                                                                                            AND HOSE STATIONS
         H.TA»
                                                                                                  MAKEUP HATER TO
                                                                                                  HMtSTONE AREA
                                                               SERVICE MUTER
                                                               (LAKE WATER)
  ASH POND
 RCTUM HATER
(RECTCLE MATER)
              |  SOLIDS  |
              \XTe^=^^OO
                                                                 Texas  Utilities,
                                 Simplified  Process Flow Diagram for  One of the  Two Identical
                                                           Martin  Lake  FGD Systems

-------
00
                                  PRECIPITATORS
           LIMESTONE STORAGE
             UL
                                     TO SPRAY TOHER 301
                                     TP SPRAY TOHER 301
                                     TO SPRAY TOHER 201
                              LIMESTONE
                               STORAGE
                                 UN
                                 LIMESTONE GRINDING
                                      SYSTEM
                                         TANK AGITATOR
                                                                    IYPASS

                                                                    TO SPRAY TOUER 301




                                                                    TO SPRAY TOHER 201
                             BYPASS

                 FROM SPRAY TOUER  301
                  FROM SPRAY TOUER 201
ID
TANS
301 -


301 •

d










ME* Ml
NEK 201
ma
I*

LURRY
TOR
MATCH
M
m

r

— •
=7
MM





I

N
ELIH




i

ST
NA

X
TOR
1



.LIMESTONE
.S SLURRY
*~I IMWM
^ 	 s.

iNf
" " *


^ *• ^ •
• •* •
" • ~* •*
• V W W
SWAT TOMER
n ""
J /
RHITTENT
PRAYS



j


SP
Arn
ASH

OVERFLOH
l"

RAY
UER
rATI
•i
I
i
NTST CLIHINATC
HASH HATER
TO SPRAY TO



~\

__ SEWICE HATE*
»
HER 201
FRO
4 SPRAY TOM
TO SPRAY TOUER 301 FROM SPRAY TOMER j

	 ^.TOHER DRAIN TO
DISPOSAL
R
1 SPRAY TOHER
RECYCLE PIMP
TOTAL PUMP SI
— INSTRtWCNT PI
SO, REHOVAL
r- SUMP PUH
J
EALS AND
URGE HATER
) ASH
PONO
AREA
PS
FROM ASH m
RETENTION 1
                                                                                                                                            TO ASH AREA
                                                      LIMESTONE
                                                       SLURRY
                                                        TANK
S02 REHOVAL AREA SUMP
                                                                   Texas  Utilities,
                                            Simplified  Process Flow Diagram  for Monticello  3

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APPENDIX C




DEFINITIONS
    01

-------
                           DEFINITIONS
Boiler Capacity Factor:
Boiler Utilization Parameter
Efficiency:
     Particulates
     SO.
     FGD Viability Indexes
 (KWh generation in year)/
maximum continuous generating
capacity in kW x 8760 hr/yr).

Hours boiler operated/hours in
period, expressed as a percen-
tage.
The actual percentage of
particulates removed by the
emission control system (mech-
anical collectors, ESP, or
fabric filter and FGD) from
the untreated flue gas.

The actual percentage of SO,
removed from the flue gas by
the FGD system.  Design removal
efficiency values are presented
for nonoperational systems for
which actual removal data are
not available.

Several parameters have been
developed to quantify the
viability of FGD system tech-
nology.  Various terms such as
"availability," "reliability,"
"operability," and "utilization
are used to accurately repre-
sent the operation of any FGD
system during a given period.
The above-mentioned parameters
are defined below and dis-
cussed briefly.  The objectives
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
purposes so that reasonably
consistent comparisons can be
made.
                               C-2

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                      DEFINITIONS
Availability Index
Reliability Index
PGD Operability Index
Hours the PGD system is avail-
able for operation  (whether
operated or not) divide*..- by
hours in period, expressed as
a percentage.  This parameter
tends to overestimate th>-
viability of the FGD system
because it does not pen. lize
for election not ro operate
the system when it could have
been operated.  Boiler down-
time nay tend to increase the
magnitude ot the parameter
because FGD failures generally
cannot occur during such
periods.

Hours the FGD system was
operated divided by the hour;
the FGD system was called upon
to operate, expressed ar i
percentage.  This parameter
has been developed in orcer
not to penalize the FCL
system for elected outaqes,
e.q., periods when th*..- FGD
system could have been run but
was not run because of ch<-'«ui-
cal shortages, lack of manpower,
short duration boiler operations,
etc.  The main problem in
using this formula is thr-
concise determination whether
or not the system was "called
upon to operate" during a
given time period.  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 outage when FGD system
is available).

Hours the FGD system was opera-
ted divided by boiler operating
hours in period, expressed as
a percentage.  This parameter
indicates the degree to which
the FGD system is actually
usedi relative to boiler
                          C-3

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     FGD Utilization Index
FGD Status:
     Category 1


     Category 2
     Category 3
operating time.  The parameter
does not reflect the extent of
exertion on the FGD system,
that is, the magnitude of the
parameter has little or no
correlation with FGD system
operating time.  Also, the
parameter is penalized when
options are exercised not to
use the FGD system in periods
when the system is operable.
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
outage when FGD system is
available).

Hours that the FGD system
operated 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 para-
meter can be strongly influ-
enced by conditions that are
external to the FGD system
(e.g., infrequent boiler
operation will lower the value
of the parameter although the
FGD system may be highly
dependable in its particular
application).

Operational - FGD system is in
service removing SO2.

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.
                               C-4

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     Category 4
     Category 5
     Category 6
     Category 7


     Category 8
FGD Vendor
Fuel Characteristics
New
Nonregenerable
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
intent or contract has been
issued.

Considering only FGD Systems -
an FGD system is proposed as a
means to meet an SO- regula-
tion.

Considering an FGD system as
well as alternative methods.

Nonoperational - FGD system
has been in service in the
past but has been shut down
permanently or for an extended
indefinite period of time.

A firm which fabricates and
supplies FGD systems, most
notably the flue gas treating
and ancillary equipment.

Type of fuel, average gross
heating value in Btu/lb.
average percent ash and average
percent sulfur content for
fuel as fired.

FGD unit and boiler were
designed at the same time or
space for addition of an FGD
unit was reserved when boiler
was constructed.

The S02 removed from the flue
gas is not recovered in a
usable or marketable form and
resulting sulfur-bearing waste
products must be disposed in
an environmentally acceptable
fashion.
                               C-5

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Operational Experience
Process
Regulatory Class
Regenerable
Retrofit
Sludge Disposal
                               C-6
Summary of FGD status and
description of current month's
progress.

Company name if process is
patented.  Generic name if
several companies have similar
processes.

A.   New boiler constructed
     subject to Federal New
     Source Performance Stan-
     dards.

B.   Existing boiler subject
     to State Standard that is
     more stringent than the
     Federal New Source Per-
     formance Standard (NSPS).

C.   Existing boiler subject
     to State Standard that is
     equal to or less strin-
     gent than NSPS.

D.   Other (unknown, undeter-
     mined) .

The SO2 removed from the flue
gas is recovered in a usable
or marketable form  (e.g.,
sulfur, sulfuric acid, gypsum,
ammonium sulfate, sodium
sulfate).

FGD unit must be added to an
existing boiler not specifi-
cally designed to accommodate
FGD unit.

Disposal method for nonregen-
erable systems producing
sludge including:  lined
or unlined ponds, stabilized
or unstabilized sludge, and
on- or off-site disposal,
disposal type  (minefill,
landfill, structural fill).
For the regenerable systems,
the form or method of sulfur
recovery is provided  (e.g. -
molten elemental sulfur,
sulfuric acid plant).

-------
Start-up Date
Total FGD System  Lost
Generation Factor
Unit Cost
Unit Location


Unit Name
Unit Rating
Date when initial SC>2 removal
began or is scheduled to
begin.

The total monthly lost genera-
tion hours due to FGD train
outages divided by the total
monthly expected generation if
the FGD trains would have been
available for operation,
expressed as a percentage.

Capital Cost in $/kW includ-
ing:  SC>2 absorption and
regeneration system, S02
recovery system, solids dis-
posal, site improvements,
land, roads, tracks, substa-
tion, engineering costs,
contractors fee and interest
on capital during construc-
tion.

Annualized Cost in mills/kWh
including fixed and variable
costs.  Fixed costs include:
interest on capital, deprecia-
tion, insurance, taxes, and
labor costs including over-
head.  Variable costs include:
raw materials, utilities, and
maintenance.

City and State listed in
mailing address.

Unit identification as it
appears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - or as indicated by
utility representative for
installations in planning
stages.

Operational - Maximum con-
tinuous gross generation
capacity in MW; Preopera-
tional - maximum continuous
design generation capacity in
MW.
                               r-i

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Utility Name                       Name of corporation as it
                                   appears in Electrical World -
                                   Directory of Electrical Util-
                                   ities,  McGraw-Hill - Current
                                   Edition - as space permits.

Water Make-Up                      Gallons per minute of make-up
                                   water required per MW of
                                   capacity.
                              C-8

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                                TECHNICAL REPORT DATA
                         (riease read Instructions on the reverse before completing)
1. REPORT NO.

EPA-600/7-79-022b
     2.
                                3. RECIPIENT'S ACCESSION NO.
4. TITLE AND SUBTITLE
EPA Utility FGD Survey: October-November 1978
                                5. REPORT DATE
                                 February 1979
                                                      6. PERFORMING ORGANIZATION CODE
7. AUTHOH(S)~  	'	

M.Melia, M.Smith, T.Koger, and B. Laseke
                                8. PERFORMING ORGANISATION REPORT NO.
9. PERFORMING ORGANIZATION NAME AND ADDRESS
PEDCo. Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio  45246
                                10. PROGRAM ELEMENT NO.
                                EHE624
                                11. CONTRACT/GRANT NO.

                                68-02-2603, Task 24
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 COV ERED
                                Periodic; 10-11/78	
                                14. SPONSORING AGENCY CODE
                                  EPA/600/13
is. SUPPLEMENTARY NOTES EPA project officers are N.Kaplan (IERL-RTP,MD-61.919/541^
2556) and J.C.Herlihy (DSSE,202/755-8137). EPA-600/7-78-051a thru -051d are pre-
vious reports in this series.	
IB. ABSTRACT The report jg ^ up(jated supplement to EPA-600/7-78-051a and should be
used in conjunction with it. It presents a survey of utility flue gas desulfurization
(FGD) systems in the U.S. , summarizing information contributed by the utility indus-
try, process suppliers, regulatory agencies, and consulting engineering firms.  Sys-
tems are tabulated alphabetically, by development status (operational, under cont-
struction, in planning stages, or terminated operations), by utility company, by pro-
cess supplier, by process, by waste disposal practice, and by regulatory class. It
presents data on system design, fuel sulfur content, operating history, and actual
performance.  It discusses problems and solutions associated with the boilers and
FGD systems. Process flow  diagrams and FGD system economic data are appended
to the report.
17.
                             KEY WORDS AND DOCUMENT ANALYSIS
                 DESCRIPTORS
                                          b.lDENTIFIERS/OPEN ENDED TERMS
                                            c.  COS AT I Field/Group
Pollution
Flue Gases
Desulfurization
Electric Utilities
Waste Disposal
Boilers
Maintenance
Pollution Control
Stationary Sources
Utility Boilers
13B
21B
07A,07D

15E
13A
18. DISTRIBUTION STATEMENT

 Unlimited
                    19. SECURITY CLASS (ThuRtp,
                    Unclassified   	
                               175
                    20. SECURITY CLASS (Thispage)
                    Unclassified
                                             22. PRICE
EPA Form 2220-1 (9-73)                          C - 9

 *U.S. GOVERNMENT PRICING OFFICE:! 979 -6«K> -01* U220 REGION NO. 4

-------