«*EPA
.
EPA Utility FGD
Survey:
February-March 1979
Interagency
Energy/Environment
R&D Program Report
-------
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.
-------
EPA-600/7-79-022d
July 1979
EPA Utility FGD Survey:
February-March 1979
by
M. Smith, M. Melia, and T. Koger
PEOCo. Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
Contract No. 68-02-2603
Task No. 48
Program Element No. EHE624
EPA Project Officers:
N. Kaplan J.C. Herlihy
Industrial Environmental Research Laboratory Division of Stationary Source Enforcement
Office of Energy, Minerals, and Industry Office of Enforcement
Research Triangle Park, NC 27711 Washington, DC 20460
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Research and Development
Washington, DC 20460
-------
NOTICE
This report, (prepared by PEDCo Environmental, Inc., Cincin-
nati, Ohio, under EPA Contract No. 68-02-2603, Task No. 48) is
provided as an information transfer document. Data in this
report are supplied voluntarily by utility representatives; flue
gas desulfurization (FGD) system designers, and suppliers; regu-
latory personnel; and others. Neither EPA nor the designated
contractor warrants the accuracy or completeness of information
contained in this report.
This report is the first of three supplementary issues to
the December 1978 - January 1979 report. Supplementary issues
are cumulative, so that it is necessary to retain only the latest
issue and the December 1978 - January 1979 report
(EPA-600/7-79-022C).
Initial distribution of the report (generally, one copy per
company) is limited to organizations and individuals indicating
a specific interest in the field 6f FGD technology. Additional
copies of this report and succeeding issues can be purchased from
National Technical Information Service, Springfield, Virginia
22151.
ii
-------
CONTENTS
Notice
Tables
Executive Summary and Highlights
Section 1 Summary List of FGD Systems
Section 2 Status of FGD Systems
Section 3 Design and Performance Data for Operational
FGD Systems
Alabama Electric
Tombigbee 2
Allegheny Power System
Pleasants 1
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 1-4
Phillips 1-6
Gulf Power
Scholz 1,2
Indianapolis Power and Light
Petersburg 3
Kansas City Power and Light
Hawthorn 3
Hawthorn 4
LaCygne 1
Kansas Power and Light
Jeffrey 1
Lawrence 4
Lawrence 5
Kentucky Utilities
Green River 1-3
1
6
34
34
35
37
38
40
41
43
45
46
47
48
49
51
52
53
55
56
57
58
iii
-------
CONTENTS (continued)
Louisville Gas and Electric
Cane Run 4 59
Cane Run 5 60
Cane Run 6 61
Mill Creek 3 63
Paddy's Run 6 64
Minnkota Power Cooperative
Milton R. Young 2 65
Montana Power
Colstrip 1 66
Colstrip 2 67
Nevada Power
Reid Gardner 1 68
Reid Gardner 2 69
Reid Gardner 3 70
Northern Indiana Public Service
Dean H. Mitchell 11 71
Northern States Power
Sherburne 1 72
Sherburne 2 74
Pennsylvania Power
Bruce Mansfield 1 76
Bruce Mansfield 2 77
Philadelphia Electric
Eddystone 1A 78
Public Service Company of New Mexico
San Juan 1 79
San Juan 2 80
Southern Carolina Public Service Authority
Winyah 2 81
Southern Indiana Gas and Electric
A.B. Brown 1 82
Southern Mississippi Electric
R.D. Morrow 1 84
Springfield City Utilities
Southwest 1 85
Tennessee Valley Authority
Shawnee 10A 87
Shawnee 10B 88
Widows Creek 8 90
Texas Utilities
Martin Lake 1 91
Martin Lake 2 92
Martin Lake 3 93
Monticello 3 95
Utah Power and Light
Hunter 1 95
Huntington 1 98
iv
-------
CONTENTS (continued)
Page
Section 4 Summary of FGD Systems by Company 99
Section 5 Summary of FGD Systems by System Supplier 101
Section 6 Summary of FGD Systems by Process 103
Section 7 Summary of Operating FGD Systems by Process
and Unit 104
Section 8 Summary of End-Product Disposal Practices
for Operational FGD Systems 106
Section 9 Summary of FGD Systems in Operation 108
Section 10 Summary of FGD Systems Under Construction 111
Section 11 Summary of Contract Awarded FGD Systems 113
Section 12 Summary of Planned FGD Systems 114
Section 13 Total FGD Units and Capacity (MW) Installed
by Year 117
Section 14 Design and Performance Data for Operational
Particulate Scrubbers 118
Appendix A FGD System Cost Data: Operational and
Nonoperational Systems
A-l Major FGD System Equipment Summary A-7
A-2 Cost Element Factors A-12
A-3 Description of Cost A-l5
A-4 Categorical Results of Reported and
Adjusted Capital and Annual Costs for
Operational FGD Systems A-18
A-5 Costs for Operational FGD Systems A-19
A-6 Costs for Nonoperational FGD Systems A-23
Appendix B FGD Process Flow Diagrams B-l
Appendix C Definitions C-l
Appendix D Glossary of Units D-l
-------
TABLES
No. Page
I Number and Total Capacity of FGD Systems vii
II Summary of Changes, February-March 1979 ix
III Performance of Operational Units, February-March 1979 x
vi
-------
EXECUTIVE SUMMARY
This report has been prepared every other month by PEDCo Environ-
mental, 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. After this issue, reports will be issued quarterly
(every three months.) This is the second issue generated by a
new computerized data base system, the structure of which is
illustrated in Figure 1.
Table 1 summarizes the status of FGD systems in the United States
at the end of March 1979. Table II lists the units that have
changed status during February - March 1979, and Table III shows
the performance of operating units during this period.
TABLE I. NUMBER AND TOTAL CAPACITY OF FGD SYSTEMS
Status
Operational
Under construction
Planned:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only FGD
systems
TOTAL
No. of
Units
51
42
20
2
13
34
162
Total
Controlled
Capacity, MW*
19,170
17,357
11,093
1,100
9,998
17,944
76,662
Equivalent
Scrubbed +
Capacity, MW
17,822
15,763
10,517
1,100
9,110
17,174
71,486
* Total Controlled Capacity (TCC) is the summation of the gross
unit capacities (MW) brought into compliance with FGD systems
regardless of the percent of the flue gas scrubbed by the FGD
system(s).
Equivalent Scrubbed Capacity (ESC) is the summation of the ef
fective scrubbed flue gas in equivalent MW based on the percent
of the flue gas scrubbed by the FGD system(s).
vii
-------
H-
H-
PHOT
PUKT
roo
tCMONICS
1 1 1
«K«S
CMTtiruU
FANS
roo
ENtKT
CWUM>TIM
VMUW
riittR
roo
D(Sir.H
I
"1ST
uimwoB
PKOCtSS
CHtNISTRT
cwn«ni
1 1
BCOCU
PUWS
•tcrcil
tuns
KEHtAHR
IHIcrtHts
"Sir
0f -PROPIT T
,.„,„,„
,,0™
r,iuor,f
oiiPnsn
Figure 1. Computerized data base structure diagram.
-------
TABLE II. SUMMARY OF CHANGES: FGD SUMMARY REPORT, FEBRUARY-MARCH 1979
FGD status report
11/31/79**
Allegheny Power Systen
Pleasants 1
Louisville Gas a Electric
Cane Run 6
Nuscatine Power & Water
Huscatlne 9
Northern Indiana Public Service
Schahfer 17
Northern Indiana Public Service
Schahfer 18
Public Service of New Mexico
San Juan 3
South Carolina Public Service
Winyah 3
South Carolina Public Service
Winyah 4
Southern Indiana Gas & Elec.
A.B. Brown 1
Texas Utilities
Martin Lake 3
Utah Power & Light
Hunter 1
TOTAL
Operational
No.
46
+1
+1
*1
+1
+1
51
MW*
15,795
519
288
265
595
360
17.822
Under
construction
No.
45
-1
-1
+1
+1
-1
-1
-1
42
MW*
16.976
519
288
534
280
265
595
360
15.763
Contract
awarded
No.
21
-1
-1
+1
20
MW*
11,051
534
280
280
10,517
Letter of
Intent
No.
2
2
MW*
1100
1100
Requesting/
eval. bids
No.
11
+1
+1
13
MW*
8268
421
421
9110
Considering
FGO
No.
33
+1
34
MW*
17.014
160
17.174
Total
No.
158
+1
+r
+1
+1
162
HW*
70.204
160
421
421
280
71.486
' Equivalent scrubbed capacity.
•• The totals as of 1/31/79 shown have been modified as a
result of corrections of MW ratings reported by utilities.
-------
TABLE III. PERFORMANCE OF OPERATIONAL UNITS
FEBRUARY 1979 - MARCH 1979
PUnt
Toablgbee 2
PlNSantS 1
Apache 2
Cholla 1
Cholla 2
Duck Crtck 1
Conesvllle 5
Conesvllle 6
Elraaa 1-4
Phillips
Scholz 1.2
Petersburg 3
HMthorn 3
Hawthorn 4
LaCygne 1
Jiff ray 1
Lawrence 4
Lawrence S
Grtcn Rivers 1-3
Cane Run 4
Cane Run 5
Cane Run 6
Mill Creek 3
Paddy's Run 6
Hilton R. Young 2
Colstrlp 1
Colstrlp 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Dean H. Mitchell 11
Stwrourvw 1
Sncfvunw 2
FGO systea
capacity.
179
519
195
119
350
416
411
411
510
410
23
532
90
90
874
540
125
420
64
188
190
288
442
72
405
360
360
125
125
125
115
740
740
Flue gas
S scrubbed
70
84
100
100
100
100
100
100
100
100
J
N/Ad
100
100
100
100
r 75
100
100
100
100
100
100
100
100
85
100
100
100
100
100
100
100
100
FGO capacity
on line
during
period.
NM*.I>
179
519
195
119
350
416
411
411
23
532
90
90
874
540
125
420
64
190
288
442
360
360
125
125
125
115
740
740
No Information
for this
period.
NU
510
410
405
Shut dot*
through-
out
period.
NU
188
72
FGO systea
availability.
«e
Feb.
95
0
0
94
100
71
86
97
41
7
89
93
Kir.
95
25
38
100
95
11
100
98
98
100
47
92
91
FGO systea
operabillty.
1C
Feb.
100
0
0
98
18
86
93
46
Mar.
98
25
33
100
100
72
53
97
97
98
FGO systea
reliability.
1C
Feb.
100
0
0
46
86
93
46
1
Nar.
98
25
34
100
100
67
97
97
100
44
FGD systea
utilization.
1C
Feb.
100
0
0
98
39«
0
50
17
86
88
41
1
Nar.
98
22
29
100
39«
11
58
52
78
90
68
43
(continued)
-------
TABLE III. (continued)
PUnt
trace Mansfield 1
Brace Mansfield 2
Eddys tone 1A
San J«in 1
S*n Juan 2
Mlnyah 2
A.B. Bnwn 1
P..O. Morrow 1
Southwest 1
Shavnee KM
Shnmee 10B
UldoMS Creek 8
Martin Uke 1
Martin Uke 2
Martin Uke 3
Montlcello 3
Hunter 1
Hunttngton 1
TOTAL
FGO system
capacity. •
MM*
917
917
120
361
350
140
265
124
194
10
10
550
595
595
595
BOO
360
366
17,822
Flue gas
1 scrubbed
100
100
N/A<1
100
100
SO
62
100
H/Ad
H/Ad
100
75
75
75
100
85
FGO capacity
on line
during
period.
W*.b
917
361
350
140
265
V24
194
10
10
550
595
595
595
800
14.474
No Information
for this
period,
MM
917
120
366
2728
Shut down
through-
out
period.
MM
360
620
FGO systea
availability.
J«
Feb.
97f
25
Mar.
97f
59
FGO systea
operablllty,
xc
Feb.
96f
16
Mar.
96f
27
FGO system
reliability,
1C
Feb.
96f
16
Mar.
96f
27
FGO systea
utilization,
tc
Feb.
93f
12
Mar.
93f
26
* equivalent scrubber capacity.
This category Includes the flue gas capacity being handled by the FGO system at least part of the tine during the report period.
c The percent figures listed are average values for all system scrubbing trains during the period.
Flue gas I scrubbed for prototype and demonstration units Is not applicable unless the system Is designed to bring a unit Into
compliance with S0? emission standards.
' This figure represents the average utilization from September 1978 through December 1978.
The figures represent averages for February through March.
-------
As indicated in Table I, 51 power generating units (all coal-
fired) are now equipped with operating FGD systems. These units
represent a total controlled capacity of 19,170 MW. Projections
indicate that the total power generating capacity of the U.S.
electric utility industry will be approximately 878 GW by 1988.
(This value reflects the annual loss resulting from the retire-
ment of older units, which is considered to be 0.4% of the
average generating capacity at the end of each year.) Approxi-
mately 395 GWa'b'c or 45% of the 1988 total will come from coal-
fired units. Of the 162 FGD-equipped units (76,662 MW) shown in
Table I, 160 (76,072 MW) are scheduled for operation by 1988.
Therefore, approximately 19% of the projected coal-fired capacity
will be controlled by FGD by the end of 1988.
HIGHLIGHTS: FEBRUARY - MARCH 1979
The following paragraphs highlight FGD system developments during
February and March 1979.
Pleasants 1 of Allegheny Power System began operations in March
1979. Performance figures for the four-module lime slurry FGD
system are not yet available as the unit is undergoing shake-
down/debugging operations. Allegheny Power did report that some
operational problems occurred during the period.
Arizona Public Service reported that the Cholla 1 FGD system
remained in service during most of the report period. The FGD
system's average reliability for February and March was 100 and
98%, respectively. The boiler was in service 672 hours in
February and 727 hours in March.
The Thoroughbred 121 prototype FGD system retrofitted on Gulf
Power's Scholz Units 1 and 2 achieved operabilities of 98 and
100% during February and March, respectively. The Thoroughbred
121 facility removes SC>2 and flyash from an effective 23 MW
capacity slip stream drawn from the two 47 MW (gross) Scholz
units. Chiyoda International, the system supplier, reported that
removal efficiencies for S02 have ranged from 93 to 95%.
Kansas City Power and Light reported that the LaCygne 1 FGD
system was in service during the report period, achieving average
system availabilities of 94 and 95% for the months of February
and March, respectively. Unit power production was limited by a
number of boiler-related outages during the period, resulting in
unit service times of 342 hours for February and 314 hours for
March.
Cane Run 6 of Louisville Gas and Electric (LG&E) began operations
in March 1979 with the boiler logging 475 hours and the FGD
system, 237 hours in April 1979. This first full scale utility
dual alkali FGD system uses a carbide lime slurry circulated
through two parallel scrubbing trains to remove SO2 from the flue
gas generated by the 288 MW (gross) steam generator.
xii
-------
Muscatine Power and Water announced plans to install an FGD
system at Muscatine Power Station. The plans call for a lime or
limestone slurry type FGD system to clean flue gas generated by
Muscatine 9, which is scheduled to begin operations in 1982.
Particulate matter will be controlled with an ESP and SO2 with
two 100% capacity FGD modules. The design will include a forced
oxidation system to produce a sludge product suitable for land-
fill after drying, and an indirect steam coil type flue gas
reheat system.
Nevada Power reported that the FGD systems for Reid Gardner 1, 2,
and 3 were in service during most of February and March. FGD
system availabilities for February were 86% for Reid Gardner 1 and
97% for Reid Gardner 2 (Unit 3 experienced FGD system related
outages that yielded low February availability). FGD system
availabilities for March were 98, 98, and 100% for Units 1, 2,
and 3, respectively.
Northern Indiana Public Service Company (NIPSCO) is requesting/
evaluating bids for the installation of FGD systems on Schahfer
17 and 18. The new Schahfer units will be rated at 421 MW (gross)
each. Particulate matter will be controlled with cold-side
ESP's. NIPSCO is considering a sodium based FGD system for S02
control; however, no specific process has been selected. Schahfer
17 and 18 are scheduled to begin operations in June 1983 and June
1985, respectively.
Northern States Power reported that the FGD system availability
for Sherburne 1 was 89% in both February and March and that the
FGD system availability for Sherburne 2 was 93% in February and
91% in March.
Public Service Company of New Mexico reported that construction
of San Juan 3 is nearing completion. The 534 MW unit is scheduled
to begin operations in June, 1979, with a Wellman Lord FGD system
controlling SC>2 emissions.
Winyah 2 of South Carolina Public Service achieved a combined FGD
system availability of 97% for both February and March. The
boiler operated 1362 hours during the two month period and the
FGD system operated 1313 hours.
South Carolina Public Service reported that a contract was
awarded for an FGD system planned for Winyah 4, a new 280 MW
(gross) coal-fired unit scheduled for start up in May, 1981. The
utility will equip the unit with an ESP for particulate matter
control and a two-spray tower limestone slurry FGD system for SC>2
control. Winyah 3 is now under construction and is expected to
begin operations in May, 1980.
xiii
-------
A.B. Brown 1 of Southern Indiana Gas and Electric began opera-
tions in March, 1979. The 265 MW (gross) unit uses a cold-side
ESP for particulate matter control and a two-scrubber train dual-
alkali FGD system for the control of SC^- The FGD system can
operate in a closed or open loop and uses cooling tower blowdown
for makeup water.
Martin Lake 3 of Texas Utilities became operational in March
1979. The 750 MW (gross) unit uses a limestone slurry FGD system
for SO2 control and ESP's for particulate matter control. A
performance test was completed during the week of May 7- Results
are not yet available.
Utah Power and Light reported that Hunter 1 (formerly called
Emery 1) began operations in May 1979. The emission control
system includes an ESP for particulate matter removal and a four-
tower lime slurry FGD system for SC>2 control of flue gas generated
by the 400 MW (gross) steam generator.
xiv
-------
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 I1-3.
c. Twelth Annual Power Engineering Survey, Power Engineering,
April 1978.
xv
-------
i.P* UTILITY FC-D SUfcVtY: FEBRUARY »»PCH 1979
SECTION 1
SU"KARY LIST OF FGD SYSTEMS
COMPANY NAMt/
UNIT NAPC
ALAbAMA ELECTRIC COOP
TOMB1GEEE
TOMPI6BEE
ALLEGHENY POWER SYSTEM
MITCHELL
PLEASANTS
PLEASANT!,
ARIZONA ELECTRIC PO*F R COOP
APACHE
APACHE
ARIZONA PUb LlC SERVICE
CHOLLA
CHOLLA
CHOLLA
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
ASSOCIATED ELECTRIC COCP
THOMAS HILL
PASIN ELECTRIC POWtR COOP
ANTELOPE VALLEY
ANTELOPE VALLEY
LARAMIE RIVER
LARAMIE RIVER
LARAMIE RIVFR
PIG RIVERS ELECTRIC
GREEN
GREEN
CENTRAL ILLINOIS LIGHT
DUCK CREEK
DUCK CREEK
CENTRAL ILLINOIS PUEL 1C S ERV
NEWTON
CENTRAL MAINE POWER
SEARS ISLAND
CINCINNATI oAS & ELECTRIC
EAST BEND
COLORADO UTE ELECTRIC ASSN.
CRAIG
CRAIG
COLUMBUS 8 SOUTHERN OHIO kLEC,
CONESVILLE
CONESVILLE
POSTON
POSTON
UNIT
2
i
3
1
2
i
1
1
2
4
1
2
I
4
c
7
1
2
1
2
3
1
2
1
2
1
1
2
1
2
i
5
6
5
6
NO. UNIT LOCATION
LEROY
LtROY
COURTNEY
6ELMONT
iELKONT
COCHISE
COCHISE
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARPIN6TON
FARCINGTON
FARKIN6TON
FARPINGTON
FARflNGTON
M08ERLY
BEULAH
BEULAH
WHEATLAND
WHEATLAND
WHEATLAND
SEBPEE
StBREE
CANTON
CANTON
NEWTON
PEN06SCOT F-AY
RABE-ITHASH
CRAIG
CRAIG
CONESVILLE
CONESVILLE
ATHENS
ATHENS
ALABAMA
ALAPAMA
PENNSYLVANIA
rtEST VIRGINIA
WEST VIRGINIA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
NED MEXICO
NEW MEXICO
NE» MEXICO
NEW MEXICO
NEk MEXICO
MISSOURI
NORTH DAKOTA
NORTH DAKOTA
WYOMING
WYOMING
HVOMING
KENTUCKY
KENTUCKY
ILLINOIS
ILLINOIS
ILLINOIS
MAINE
KENTUCKY
COLORADO
COLORADO
OHIO
OHIO
OHIO
OHIO
START-UP
DATE
9/75
6/79
8/e2
J/79
9/80
8/78
6/79
10/73
4/78
6/80
0/79
0/79
0/79
0/82
0/82
1/82
11/81
11/83
4/80
10/80
4/82
12/79
12/80
7/76
1/84
11/79
11/87
10/81
6/79
11/79
1/77
6/78
0/83
o/ts
STATUS
1
2
e
1
2
1
2
1
1
2
2
2
2
3
3
3
3
6
2
2
3
2
2
1
5
2
6
2
2
2
1
1
6
6
REG
CLASS
A
A
B
A
A
fi
e
B
9
P
B
P
B
B
B
A
a
B
A
A
A
A
A
A
A
A
A
A
8
B
B
B
B
B
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED -CONSIDERING F60 SYSTEMS; ALSO 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
-------
FPA UTILITY FbD SURVEY: FEBRUARY - MftCH 1979
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
C01PANY NAPt/
UNIT NAHL
COMMONWEALTH EDI SOU
POWERTO*
COOPERATIVE POKER ASSOCIATION
COAL CREEK
COAL CREtK
t> EL NARVA POaER fc L16HT
DELAWARE CITY
DUOUESNE LI6HT
ELRAMA
PHILLIPS
EAST KENTUCKY <>OWEfl COOP
SPURLOCK
GENERAL PUbLIC UTILITIES
COHO
SEWARD
6ULf POWER
SCHOLZ
HOOSIEB ENEfcGY
MEROP
MERO*
HOUSTON LIGHTING I POwER CO.
k.A. PARISH
INDIANAPOLIS POKER & LIGHT
PETERSBURG
PETERSBURG
KANSAS CITY POWER 1 LIGHT
HAWTHORN
HAWTHORN
LA CY6NE
KANSAS POfcEH t LIGHT
JEFFRE V
JEFFREY
LAWRENCE
LAWPENCE
KENTUCKY UTILITIES
GREEN RIVER
LAKELAND UTILITIES
MC1NTOSH
LOUISVILLE 6AS ( fcLECTRIC
CANE RUN
CANE RUN
CANE PUN
HILL CREEK
HILL CREEK
MILL CREEK
MILL CREEK
PADDY'S RUN
UNIT NO.
51
1
2
1-:
1-4
1-6
2
i
7
1.2
1
2
t
3
4
3
4
1
1
2
4
5
1-J
3
4
5
6
1
2
1
4
6
UNIT LOCATION
PEEK1N
UNDERWOOD
UNDERWOOD
DELAWARE CITY
ELRAPA
SOUTH HEIGHT
HAYSVILLE
ERIE
SfchARD
SNEADS
SULLIVAN
SULLIVAN
THOMPSONS
PETERSBURG
PETERSBURG
KANSAS CITY
KANSAS CITY
LA CYGNE
WAMEGO
hAMEGO
LAWRENCE
LAWRENCE
CENTRAL CITY
LAKELAND
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
ILLINOIS
NORTH DAKOTA
NORTH DAKOTA
DELAWARE
PENNSYLVANIA
PENNSYLVANIA
KENTUCKY
PENNSYLVANIA
PENNSYLVANIA
FLORIDA
INDIANA
INDIANA
TEXAS
INDIANA
INDIANA
MISSOURI
MISSOURI
KANSAS
KANSAS
KANSAS
KANSAS
KANSAS
KENTUCKY
FLORIDA
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
START-UP
DATE
10/79
5/79
1C/80
4/eo
10/75
7/73
1C/60
12/85
12/65
8/78
4/61
1/62
10/02
12/77
10/63
11/72
8/72
2/73
6/78
6/eo
1/76
11/71
9/75
10/81
8/76
12/77
3/79
4/81
4/82
8/78
7/81
4/73
STATUS
2
2
2
£
1
1
3
6
6
1
2
2
5
1
2
1
1
1
1
2
1
1
1
3
1
1
1
2
3
1
2
1
REG
CLASS
C
A
A
C
B
B
A
A
A
C
A
A
•
A
A
B
B
C
B
B
B
B
C
A
A
A
A
B
B
B
B
C
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
?. PLANNED - CONTRACT AWARDED
4.
5.
6.
7.
PLANNED - LETTER OF INTENT SIGNED
PLANNED - RESULTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY F60 SYSTEMS
PLANNED - CONSIDERING F6D SYSTEMS; ALSO ALTERNATIVE METHODS
A. BOILER CONSTRUCTED SUfcJECT TO FEDERAL NSPS
B. BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
C. BOILER SUfcJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
D. OTHER
E. REGULATORY CLASS UNKNOWN
-------
EPA UTKITY FGO SURVEY: FEBRUARY - MARCH 1979
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAMt/
UNIT NAKE
LOUISVILLE uAS & ELECTRIC
TRIMBLE COUNTY
TRI'ELE COUNTY
MIDDLE SOUTH UTILITIES
ARKANSAS COAL
ARKANSAS COAL
LOUISIANA COAL
LOUISIANA COAL
MISSISSIPPI COAL
MISSISSIPPI COAL
UNIT NO. UNIT LOCATION
1 BEDFORD
2 BEDFORD
5
6
1
2
1
2
KENTUCKY
KENTUCKY
ARKANSAS
ARKANSAS
LOUSIANA
LOUSIANA
MISSISSIPPI
MISSISSIPPI
START-UP
DATE
7/8*
0/84
1/86
1/88
0/86
0/88
0/oS
0/87
STATUS
6
6
5
5
5
5
5
5
RE 6
CL»SS
D
D
D
D
D
D
D
D
MINNESOTA POKER t LI6HT
CLAY PCS .ELL 4
HINNKOTA POWER COOPERATIVE
MILTON R. YOUNG 2
MONTANA PO.tR
COLSTRIP 1
COLSTR1P 2
COLSTRIP 2
COLSTRIP 4
MUSCATINF. POWER K WATER
HUSCATINE 9
NEVADA POWER
HARRY ALLEN 1
HARRY ALLEN 2
HARRY ALLEN 3
HARPY ALLEN 4
REID GARDNER 1
REID GARDNER 2
REID GARDNER 3
REID GARDNER 4
WARNER VALLEY 1
EARNER VALLEY 2
NEW EN6LAND ELECTRIC SYSTEM
fcRAYTON POINT 3
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
NORTHERN INDIANA PUG SERVICE
faAlLLY
6AILLY
DEAN H. MITCHELL
SCHAHFEE
SCHAHFER
NORTHERN STATES POWER
SHERBURNE 1
SHERBURNt 2
SHERBURNE. 3
OTTER TAIL POWER
COTOTE 1
COHASSET
CENTER
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
MINNESOTA
NORTH DAKOTA
MONTANA
MONTANA
MONTANA
MONTANA
IOWA
K.E . LAS VE6AS NEVADA
N.E. LAS VEGAS NEVADA
K.E. LAS VEGAS NEVADA
LAS VEGAS NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
UTAH
UTAH
.E.
N.E.
MOAPA
CO* PA
MOAPA
MOAPA
ST. GEORGE
ST. GEORGE
SOMERSET
BUFFALO
MASSACHUSETTS
NEW YORK
7
e
11
17
18
CHESTERTON
CHESTERTON
GARY
WHEATFIELD
WHEATFIELD
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
BECKER
BECKER
BECKER
BEULAH
MINNESOTA
MINNESOTA
MINNESOTA
NORTH DOKOTA
5/1:0
9/77
9/75
5/76
7/80
7/81
0/82
3/76
4/77
5/84
5/81
6/85
6/86
6/67
6/88
4/74
4/74
6/76
0/83
6/84
6/8$
O/ 0
0/82
O/ 0
O/ 0
7/76
6/83
6/85
6
6
6
6
1
1
1
6
6
6
7
3
6
6
1
5
5
A
A
A
A
A
A
A
A
A
A
C
c
C
c
c
A
A
1* OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REVESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY F6D SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. BOILER CONSTRUCTED SUfcJECT 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
-------
fp» UTILITY FGD SUPVET:
- MARCH 1979
PACIFIC POWtR K LIGHT
JIM BRIDGE*
SECTION 1
SUMMARY LIST OF F60 SYSTEMS
COMPANY NAPfc/
UNIT NAPe
PACIFIC GAS t ELECTRIC
FOSSIL
FOSSIL
UNIT NO. UNIT LOCATION
1 CALIFORNIA
2 CALIFORNIA
START-UP
DATE
0/85
0/66
REG
STATUS CLASS
6 B
6 6
ROCK SPRINGS .YOKING
9/79
PENNSYLVANIA POWfR
bRUCE MANSFIELD
6RUCE MANSFIELD
BRUCE MANSFIELD
PHILADELPHIA ELECTRIC
CROMEY
EDDVSTONE
EDDYSTONE
EDDYSTONE
POTOMAC ELECTRIC POWER
OICKERSON
POWER AUTHORITY OF NEW YORK
ARTHUR KILL
PUBLIC SERVICE OF INDIANA
GIBSON
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
SAN JUAN
SAN JUAN
SAN JUAN
SALT RIVER PROJECT
CORONADO
CORONADO
CORONADO
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL
SEHINOLE ELECTRIC
SEMINOLE
SIKESTON BOARD OF "UN 1C. UTIL.
SIKESTON
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
WINYAH
WINY AH
SOUTHERN CALIFORNIA EDISOh
AL AX IT OS
SOUTHERN ILLINOIS POWER COOP
MARION
MARION
1
2
3
1A
2
4
SHIPPIN6PORT
SH1PPINGPOPT
SHIPPINGPORT
PHOENIXVILIE
EDDYSTONE
EDDYSTONE
EDDYSTONE
DICKERSON
STATEN ISLAND
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
MARYLAND
NEW YORK
12/75
7/77
4/80
6/60
9/75
6/80
6/80
0/87
11/88
1
1
2
6
1
4
6
6
6
B
B
e
B
B
e
B
D
B
PRINCETON
INDIANA
0/82
1
t
3
4
1
i
3
WATERFLOW
WATERFLOW
WATERFLOW
WATERFLOW
ST. JOHNS
ST. JOHNS
ST. JOHNS
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
ARIZONA
ARIZONA
ARIZONA
4/78
8/78
6/79
1/82
8/79
1/80
0/87
1
1
2
3
2
2
6
B
B
B
B
B
B
B
SAN MIGUEL TEXAS 8/80
PALATKA FLORIDA 6/83
SIKtSTON MISSOURI 11/80
GEORGETOWN SOUTH CAROLINA 7/77 1 A
GEORGETOWN SOUTH CAROLINA 5/80 2 A
GEORGETOWN SOUTH CAROLINA 5/81 3 A
SEAL BEACH CALIFORNIA 1/82
MARION ILLINOIS 5/79 2 A
MARION ILLINOIS 0/84 6 A
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO 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 F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 1
SUMMARY LIST OF F6D SYSTEMS
COMPANY NAPfc/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP
DATE
RE6
STATUS CLASS
SOUTHERN INDIANA 6AS t ELEC
A.B. BROkN 1
SOUTHERN MISSISSIPPI ELECTRIC
R.O. MORROW 1
R.O. MORROW 2
SOUTHWESTERN ELECTPIC POKE*
HENRY W. PERKEY 1
SPRIN6FIELO CITY UTILITIES
SOUTHWEST 1
SPRINGFIELD WATER, LI6HT 1 PWR
DALLMAN 3
ST. JOE ZINC
6.F. WEATON 1
TAMPA ELECTRIC
bIG BEND 4
TENNESSEE VALLEY AUTHORITY
CUMBERLAND
JOHNSONVILLE 1-10
PARADISE 1
PARADISE 2
SHAWNEE 10A
SHAWNEE 10t)
WIDOWS CREEK 7
WIDOWS CREEK 8
TEXAS MUNICIPAL POWER AGENCY
6ZBBONS CREEK 1
TEXAS POWER t LI6HT
SANDOW 4
TWIN OAKS 1
TWIN OAKS 2
TEXAS UTILITIES
FOREST GROVE 1
MARTIN LAKE 1
MARTIN LAKE 2
MARTIN LAKE 3
MARTIN LAKE 4
MILL CREEK 1
MILL CREEK 2
MONTICELLO 3
UTAH POWER i LI6HT
HUNTER 1
HUNTER 2
HUNTIN6TON 1
WEST FRANKLIN INDIANA
HATTISBU»6
HATT1S9UR6
HALISVILLE
SPR1NEFIELD
SPRINGFIELD
MONACA
TAMPA
MISSISSIPPI
MISSISSIPPI
TEXAS
MISSOURI
ILLINOIS
PENNSYLVANIA
FLORIDA
CUMBERLAND CITYTENNESSEE
NEW JOHNSONVILLTENNESSEE
PARADISE KENTUCKY
PARADISE KENTUCKY
PADUCAH KENTUCKY
PADUCAH KENTUCKY
BRIDGEPORT ALABAMA
BRIDGEPORT ALABAMA
CARLOS
TEXAS
ROCKDALE
ATHENS
TATUM
TATUM
TATUN
TATUM
HENDERSON
HENDERSON
MT. PLEASANT
CASTLE DALE
CASTLE DALE
PRICE
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
UTAH
UTAH
UTAH
3/79
6/78
7/79
2/84
4/77
7/80
7/79
0/85
3
1
2
2
7/82
0/82
6/82
3/82
4/72
*/72
10/80
5/77
1/82
7/80
8/83
0/86
0/81
4/77
5/78
2/79
0/85
0/85
0/86
5/78
5/79
6/80
5/78
6
5
3
3
1
1
2
1
3
2
6
6
5
1
1
1
3
6
6
1
1
2
1
C
c
C
c
c
c
c
c
A
A
A
A
A
A
A
A
A
0
D
A
A
A
A
WISCONSIN POWER
COLUMBIA
t LIGHT
PORTAGE
WISCONSIN
1/82
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
BOILER SUbJECT TO STATE STANDARD THAT IS EOUAL TO OR LESS STRINGENT THAN NSPS
OTHER
REGULATORY CLASS UNKNOWN
-------
EPA UTILITY FGD SURVEY: FEBRUARY - PAfcCH 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
AfcSTRACT
ALABAMA ELECTRIC COOP
TOM61G8EE
2
HEW 255.0 tU (CROSS)
179.0 "w (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
PEAfcODV PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.12
STATUS 1 STARTUP 9/78
REfER TO SECTION ' OF THIS REPORT FOR ADDITIONAL INFORMATION.
PEABODY EN6INEER1N6 HAS AWARDED A CONTRACT FOR THE INSTALLATION OF A
LIMESTONE F6D SYSTE" ON THIS UNIT. A HI6H-EFFIC1ENCY ESP INSTALLED
UPSTREAM OF THE FGD SYSTEM PROVIDES PRIMARY PARTICULATE CONTROL. THE F6D
SYSTEP CONTAINS TWO SCRUBB1N6 TR/INS. TREATING APPROXIMATELY 701 OF THE
FLUE EAS FOR REMOVAL OF S02. STACK GAS REHEAT IS NOT REQUIRED. THE UNIT
is CURRENTLY IN THE SHAKEDOWN-DEBUGGING PHASE OF OPERATIONS.
ILABAMA ELECTRIC COOP
TOMBIGBEE
i
NEW 255.0 MW (GROSS)
179.0 "W
300.0 -w
COAL
XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••X
STATUS 6 STARTUP 8/82
ALLEGHENY POWER SYSTE" WILL INSTALL FLUE GAS DESULFURIZATION EQUIPMENT
ON UNIT 3 AT THE MITCHELL POWER STATION. THE UTILITY IS CURRENTLY
IN THE PROCESS OF EVALUATING VARIOUS FGD TECHNOLOGIES. THE FGD IN-
STALLATION IS SCHEDULED TO EEG1N OPERATIONS IN AUGUST 1982.
ALLEGHENY POWER SYSTEM
PLEAS ANTS
i
NEW 62S.O MU (GROSS)
519.0 MW (ESC>
COAL
4.50 XS BITUMINOUS
LIKE
BABCOCK t MILCOX
ENERGY CONSUMPTION: «**•!
STATUS 1 STARTUP 3/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE THREE PRINCIPAL OPERATING UTILITY COMPANIES OF THE ALLEGHENY POWER
SYSTEM ARE INSTALLING AN EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED
UNIT WHICH INCLUDES A HIGH-EFFICIENCY ESP UPSTREAM OF FOUR TRAY TOWERS
FOR THE CONTROL OF PARTICULATES AND SULFUR DIOXIDE. DESIGN REMOVAL
EFFICIENCIES FOR THIS EMISSION CONTROL SYSTEM ARE 90 AND 99.5 PERCENT,
RESPECTIVELY. THE DRAVO CO. IS SUPPLYING THIOSORBIC LIME. THE CONSULTING
A-E DESIGN FIRM FOR THIS PROJECT IS STEARNS-ROGER.
ERECTION OF THE SCRUBBING EQUIPMENT IS IN PROGRESS.
ALLEGHENY POWER SYSTEM
PLEAS ANTS
?
DEW 625.0 «W (GROSS)
519.0 MW (ESC)
COAL
4.50 XS BITUMINOUS
LIME
PABCOCK I WILCOX
ENERGY CONSUMPTION: ••••!
STATUS 2 STARTUP 9/EO
THE THREE PRINCIPAL OPERATING UTILITY COMPANIES OF THE ALLEGHENY POWER
SYSTEM ARE INSTALLING AN EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED
UNIT WHICH INCLUDES A HIGH-EFFICIENCY ESP UPSTREAM OF FOUR TRAY TOWERS
FOR THE CONTROL OF PARTICULATES AND SULFUR DIOXIDE. DESIGN REMOVAL
EFFICIENCIES FOR THIS EMISSION CONTR0L SYSTEM ARE 9fl AND 99.5 PERCENT.
RESPECTIVELY. THE DRAVO CO. IS SUPPLYING TH10SORBIC LIME. THE CONSULTING
ENGINEERING FIRM IS UNITED ENGINEERS AND CONSTRUCTORS. CURRENTLY.
FOUNDATION WORK ON THE SCRUBBER PLANT IS IN PROGRESS.
ARIZONA ELECTRIC POWER COOP
APACHE
2
NEW 195.0 «U (GROSS)
195.0 MW (ESC)
COAL
.70 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: *.n
STATUS 1 STARTUP 6/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE FGD
SYSTEM FOR THIS NEW 200 HW UNIT WAS SUPPLIED BY RESEARCH COTTRELL. THE
DESIGN INCLUDES A 22 ACRE SLUDGE POND AND A 64 ACRE ASH POND. BOTH OF
WHICH ARE UNLINED AND TEN FEET DEEP. A REHEAT SYSTEM IS NOT INCLUDED. THE
LINERS USED IN THE STACK AND THE DUCTS THAT LEAD TO THE STACK ARE A NEW
COLE BRAND CXL2000 WHICH HAS A VERY HIGH HEAT RESISTANCE. THIS UNIT BURNS
BITUMINOUS COAL WITH ASH CONTENTS OF .7% AND 10X RESPECTIVELY.
INITIAL OPERATION OF THIS UNIT BEGAN IN AUGUST, 1978.
-------
EPA UTILITY FED SURVEY: FEBRUARY - MARCH 1979
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZONA ELECTRIC POWER COOP
APACHE
1
HEW 195.0 MW (GROSS)
1VS.O HW (ESC)
COAL
.70 IS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 4.IX
STATUS 2 STARTUP 6/79
CONSTRUCTION Of UN iT 3 IS NO* ESSENTIALLY COMPLETE. STRUCTURE
ERECTION OF THE SCRUBBER-ABSORBER TOWERS IS COMPLETE' EACH SCRUBBER CAD
HANDLE 400.000 ACFM AT ;70F AND RECIRCULATE 20,000 6PM OF SLURRY.
THERE APE CURRENTLY TWO PONDS WITH A TOTAL OF 20-
VRS CAPACITY FOR DISPOSAL OF UNFITTED SLUDGE. TWO ADDITIONAL PONDS
ARE PLANNED PROVIDING AN ADDITIONAL 20 YRS OF DISPOSAL CAPABILITY. TH£R£
WILL BE NO REHEAT. BECAUSE OF THE HIGH COST OF THE UNIT 2 STACK LINER,
UNIT 3 WILL USE A CEILCOTE LINING INSTEAD OF THE CXL2000 USED IN UNIT 2.
ARIZONA PUBLIC SERVICE
CHOLLA
1
RETROFIT 119.Q "W
COAL
.50 XS SUBblTUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 4.2X
STATUS 1 STARTUP 10/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION
THIS LIMESTONE SCRUBBING SYSTEM WAS PLACED IN SERVICE IN OCTOBER 1973.
THIS SCRUBBER PLANT CONSISTS OF TWO PARALLEL SCRUBBING TRAINS.
PARTICULATE CONTROL IS PROVIDED BY TWO FLOODED DISC SCRUBBERS. S02
CONTROL is PROVIDED BY ONE PACKED (MUNTERS PACKING) TOWER .
FLUE GAS CLEANING WASTES ARE DISCHARGED TO AN EXISTING FLY *SH POND.
NO WATER IS RECYCLED PACK FROM THE DISPOSAL POND. IN-LINE STEAM
REHEATERS RAISE THE GAS TEMPERATURE 40 F.
ARIZONA PUBLIC SERVICE
CNOLLA
2
NEW 350.0 «w (GROSS)
350.0 «W (ESC)
COAL
.50 X$ SUBBITUMIhOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: • *••»
STATUS 1 STARTUP 4/78
REFER TO 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 PARTICULATE REMOVAL. THE F6D SYSTEM CONSISTS OF FOUR PARALLEL
FLOODED DISC AND PACKED TOWER ABSORBER TRAINS. THREE ARE REQUIRED FOR
FULL LOAD CAPACITY. INITIAL OPERATIONS BEGAN IN APRIL 1978. COMPLIANCE
TESTING WAS COMPLETED DURING THE SECOND WEEK OF AUGUST 1978. THE UNIT IS
CURRENTLY UNDERGOING SHAKEDOWN AND DEBUGGING OPERATIONS.
ARIZONA PUBLIC SERVICE
CHOLLA
4
«EH 350.0 MW (GROSS)
126.0 MM (ESc>
COAL
.50 ZS
LIMESTONE
RESEARCH COTTRELL
ENERGT CONSUMPTION: ••••*
STATUS 2 STARTUP 6/60
UNIT NO. 4 IS CURRENTLY UNDER CONSTRUCTION. APS HAS AWARDED THE F6D
CONTRACT TO RESEARCH COTTRELL. THE STATE REGULATORY AGENCY HAS NOT VET
DECIDED THE EMISSION REGULATIONS WHICH WILL APPLY TO THE PLANT. THE C-E
BOILER WILL FIRE THE SAME COAL AS CHOLLA N0.1. WITH SULFUR CONTENT OF
0.44-1.0 PERCENT* THE A-E FIRM IS EBASCO. THE FGD SYSTEM IS A DOUBLE LOOP
LIMESTONE ABSORPTION PROCESS AND REVENUES OF THE CONTRACT TO R-C ARE
REPORTED TO BE S5 MM. FOR CONTROL OF PARTICULATE, AN ESP WILL HANDLE
100Z OF THE FLUE GAS.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT 175.0 *W (GROSS)
175.0 PU (ESc)
COAL
.75 ZS
LIME/ALKALINE FLYASH
CHEMZCO
ENERGT CONSUMPTION: • ••*%
STATUS 2 STARTUP 0/79
APS IS UPGRADING THE OPERATIONAL PARTICULATE SCRUBBERS AT THE FOUR
CORNERS 1,2* AND 3 FOR ADDITIONAL S02 REMOVAL. CURRENTLY, EACH UNIT HAS 2
CHEMICO VENTURI SCRUBBER MODULES FOR.PARTICULATE CONTROL. ROUGHLY 301 OF
THE FLUE GAS S02 CONTENT IS REMOVED AT THE PRESENT TIME IN THE VENTURIS
KITH THE HIGH AKALINE FLYASH. NEW MEXICO APC OFFICIALS INDICATED THAT
THE 5 FOUR CORNERS UNITS WILL BE REQUIRED TO REMOVE AT LEAST 67.SX OF THE
STATION S02(ALL 5 UNITS CONSIDERED TOGETHER). ADDITIONAL ALKALINITY WILL
BE IMPARTED TO THE SCRUBBING SOLUTION BY ADDING LIME.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
RETROFIT 175.0 MW (GROSS)
175.0 MV (ESC)
COOL
.75 SS
LIME/ALKALINE FLYASH
CHEMICO
ENER6V CONSUMPTION: ••*•»
STATUS 2 STARTUP 0/79
APS IS UPGRADING THE OPERATIONAL PARTICULATE SCRUBBERS AT THE FOUR
CORNERS 1.2, AND 3 FOR ADDITIONAL S02 REMOVAL. CURRENTLY. EACH UNIT HAS 2
CHEMICO VENTURI SCRUBBER MODULES FOR PARTICULATE CONTROL. ROUGHLY 30Z OF
THE FLUE GAS S02 CONTENT IS REMOVED AT THE PRESENT TIME IN THE VENTURIS
WITH THE HIGH ALKALINE FLYASH. NEW MEXICO APC OFFICIALS INDICATED THAT
THE 5 FOUR CORNERS UNITS WILL BE REQUIRED TO REMOVE AT LEAST 67.SX OF THE
STATION $02(ALL 5 UNITS CONSIDERED TOGETHER). ADDITIONAL ALKALINITY WILL
BE IMPARTED TO THE SCRUBBING SOLUTION BY ADDING LIME.
-------
'PA UTILITY FuD SUPVET: FEfcRUAOY - MAfcCH 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION ABSTRACT ^
•RIZONA PUBLIC SERVICE APS IS UPGR*oING THE OPERATIONAL pARjICuLATE SCRUBBERS »T THE 'OUR
FOUR CORNEPS CORNERS 1.2. AND 3 FOR ADDITIONAL S02 REMOVAL. CURRENTLY, EACH UNIT HAs 2
CHEHCO VENTURI SCRUBBER MODULES FOR PARTICULATE CONTROL. ROUGHLY 30X OF
"ETROFIT 225.0 flu (GROSS) THE FLUE GAS S02 CONTENT IS REMOVED AT THE PRESENT TIME IN THE VENTURIS
220.0 "« CESC) KITH ThE HI6H AKALINE FLrASH. NEb MEXICO APC OFFICIALS INDICATED THAT
COAL THE 5 fOUR CORNERS UNITS WILL BE REQUIRED TO REMOVE AT LEAST 67.SZ OF THE
.75 IS STATION S021ALL 5 UNITS CONSIDERED TOGETHER). ADDITIONAL ALKALINITY MILL
L1*E/ALKAL1NE FLYASH BE IMPARTED TO THE SCRUBBING SOLUTION BT ADD1N6 LIME.
CHCMICO
rNfR6T CONSUMPTION: ••••I
STATUS 2 STARTUP 0/79
THE UTILITY IS CURRENTLY EVALUATING THE DATA AND INFORMATION ACCUMULATED
DURINE THE HORIZONTAL PROTOTYPE SCRUBBING PROGRAM IN ORDER TO ASCERTAIN
VARIOUS POSSIBLE STRATEGIES TO CONTROL THE EMISSIONS FROM THIS COAL FIRED
755-HW UNIT. ADS HILL BE REQUIRED TO REDUCE THE CURRENT LEVEL OF $02
EMISSIONS FROM THE ENTIRE PLANT BY INCREASING THE REMOVAL EFFICIENCY
TO AT LEAST 67.5*. A CONTRACT HAS BEEN AWARDED TO UNITED ENGINEERS FOR
THE ENGINEERING AND CONSTRUCTION OF AN FGD SYSTEM.
•RI20NA PUBLIC SERVICE
FOUR CORNERS
I
"ETROFlT 755.0 •« (GFOSS)
755.0 *M (ESc>
COAL
.75 XS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: ••«•!
STATUS 3 STARTUP 0/t2
ARIZONA PUBLIC SERVICE
FOUR CORNERS
c
RETROFIT 755.0 «y (GROSS)
755.0 »w CE$c>
COAL
.75 ZS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: ••••*
STATUS 3 STARTUP 0/t2
THE UTILITY IS CURRENTLY EVALUATING THE DATA AND INFORMATION ACCUMULATED
DURING THE HORIZONTAL PROTOTYPE SCRUBBING PROGRAM IN ORDER TO ASCERTAIN
VARIOUS POSSIBLE STRATEGIES TO CONTROL THE EMISSIONS FROM THIS COAL FIRED
75S-MU UNIT. APS WILL BE REQUIRED TO REDUCE THE CURRENT LEVEL OF $02
EMISSIONS FROM THE ENTIRE PLANT bV INCREASING THE REMOVAL EFFICIENCY
TO AT LEAST 67.SZ. A CONTRACT HAS BE AWARDED TO UNITED ENGINEERS FOR
THE ENGINEERING AND CONSTRUCTION OF AN FGD SYSTEM.
•SSOCIATED ELECTRIC COOP
THOMAS HILL
T
NEW 730.0 •* (GROSS)
670.0 "W (ESC)
COAL
4.89 ZS
LIMESTONE
CULLKAN KELLOGG
ENERGY CONSUMPTION: ***«z
STATUS 3 STARTUP 1/t2
ASSOCIATED ELECTRIC COOP AWARDED A CONTRACT TO PULLMAN KELLOGG FOR THE
ENGINEERING, PROCUREMENT AND CONSTRUCTION OF AN FGD SYSTEM ON THE UTILI-
TY'S THOMAS HILL UNIT NO. 3 POWER PLANT. S02 REMOVAL EQUIPMENT WILL OPER-
ATE IN CONJUNCTION WITH A HIGH EFFICIENCY ESP. THE SYSTEM. SCHEDULED FOR
START-UP IN 1962* WILL UTILIZE MAGNESIUM-PROMOTED LIMESTONE AS A REAGENT
IN THE FOUR MODULE WEIR FGD SYSTEM. REHEAT WILL PROBABLY NOT BE INCLUDED.
THE STACK WILL BE BRICK LINED. THE DRV FIXATED SLUDGE HILL BE
HAULED TO AN ACTIVE STRIP MINE. CONSTRUCTION OF THE BOILER HAS BEGUN.
?AS1N ELECTRIC POWER COOP
ANTELOPE VALLtV
1
MEW 440.0 KW (GROSS)
440.0 MM (ESC)
COAL
.6b ZS LIGNITE
LIME/SPRAY ORrING
JOY MFG. CO. MESTERN PRfcClPlTA
ENERGY CONSUMPTION: ••••*
STATUS 3 STARTUP 11/?1
THE UTILITY HAS SELECTED A LlME SCRUBBING PROCESS FOR THEIR PLANNED
FGD SYSTEM. THE UNIT WILL FIRE LIGNITE COAL WITH A SULFUR CONTENT
OF O.tfe PERCENT AND AN ASH CONTENT OF fi.O PERCENT (6600 BTU/LB). THE
WATER LOOP WILL BE OPEN WITH MAKE-UP COMING FROM COOLING TOWER SLOWDOWN.
THE SLUDGE hILL BE DISPOSED IN A NINE LANDFILL. A CONTRACT HAS BEEN
AWARDED TO WESTERN PRECIPITATION DIVlSON. JOY MFG. CO. FOR A DRV FGD
SYSTEM. THE SPRAY DRYER HAS BEEN SUBCONTRACTED TO NIRO ATOMITER.
5ASIN ELECTRIC POttEK COOP
ANTELOPE VALLEY
7
NEW 440.0 *u (GROSS)
440.0 MU (ESC)
COAL
.68 ZS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••X
STATUS 6 STARTUP 11/E3
THE UTILITY IS TENTATIVELY INVESTIGATING VARIOUS FGD PROCESSES FOR THIS
SECOND LIGNITE-FIRED UNIT SCHEDULED AT THE NEW STATION LOCATED IN MERCER
COUNTY, NEAR 6EULAH. NORTH DAKOTA. THIS NEW FACILITY HILL BE KNOWN AS
THE ANTELOPE VALLEY STATION AND WILL BE REQUIRED TO COMPLY WITH STATE
AIR EMISSIONS STANDARDS VIA THE BEST AVAILABLE TECHNOLOGY. START-UP IS
NOW SCHEDULED FOR NOVEMBER 1983.
-------
EPA UTILITY FGD SURVEY: FEBRUARY - MAPCH 1979
SECTION 2
STATUS OF F60 SYSTE-S
UMlT IDENTIFICATION
ABSTRACT
5ASIN ELECTRIC POWER COOP
LARA41E RIVED
1
1EW fGO.O '. (GROSS)
'OC.O I'M (ESC>
COAL
.to xs
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: ««««i
RESEAPCH-cOTTRtLL jS CURSEfcUY FABRICATING THE DUAL-LOOP LIMESTONE WET
SCRUeFERS. ON-S1TE CONSTRUCTION COKMENCED IN JANUARY 1978. SLU06E WILL BE
DEWATEREO TO tlX SOLIDS BEFORE LANDFILL. THE SCRUBBERS MILL BE 'ADE OF
STAINLESS STEEL AND WILL HANDLE t.3 MM ACFM AT Jb6 F. L/6 RATIO fcILL BE
tC. E'b HAS BEEN AWARDED A CONTRACT FOR TWO ESP'S. THE DESIGN DOES NOT
INCLUDE STACK 6*5 REHEAT. COOLlNfc TOWER SLOWDOWN WILL BE USED FOR MAKE-UP
IN THIS CLOSED LOOP SYSTEM. CONSTRUCTION IS NOW 201 COMPLETE.
STATUS 2
STARTUP 4/50
»A«1N ELECTRIC POWER COOP
LAPAM1E RIVER
tt£W 6CO.O "W (GROSS)
6CO.O HW (ESC)
COAL
.80 XS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: »*««X
STATUS 2 STARTUP 10/tO
fESEAPCH-COTTRELL IS CURRENTLY F»eRIC»TIN{ THE DUAL-L0OP LIMESTONE wET
SCRUfaEERS. ON-51TE CONSTRUCTION COMMENCED IN JANUARY 1978. SLUDGE WILL BE
DEWATEfcED TO 83X SOLIDS BEFORE LANDFILL. THE SCRUBBERS WILL BE MADE OF
STAINLESS STEEL AND WILL HANDLE ...3 MM ACFM AT 266 F. L/G RATIO WILL BE
£0. tin HAS BEEN AWARDED A CONTRACT FOR TWO ESP'S. THE DESIGN DOES NOT
INCLUDE STACK GAS REHEAT. C0°LIN6 TOWER BLO*Do«N WILL BE USED FOR MAKE-UP
WATEk IN THIS CLOSED LOOP SYSTEM. CONSTRUCTION IS NOW 201 COMPLETE.
PASIN ELECTRIC POWER COOP
LARAK1E RIVER
NJW 600.0 «w (GROSS)
600.0 »w (ESc >
COAL
.54 XS
LIME/SPRAY DRYING
BABCOCK I W1LCOX
ENERGY CONSUMPTION: *•*•*
STATUS 3 STARTUP 4/b2
LARAMIE RIVER STATION WILL FIRE SUEBlTUMiNOUS COAL WITH THE FOLLOWING
CHARACTERISTICS: 8100 8TU/LF, 0.6 PERCENT SULFUR AND 7.0 PERCENT ASH A
CONTRACT FOR A DRY TYPE FGD SYSTEM HAS BEEN AWARDED TO BABCOCK ( W1LCOJ.
?1G RIVERS ELECTRIC
GREEN
1
NEW 242.0 »W (GROSS)
242.0 "w (ESc>
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *•••*
STATUS 2 STARTUP 12/79
THE EMISSION CONTROL SYSTEM FOR THIS NfW COAL-FIRED UNIT IS BEING
SUPPLIED BY AMERICAN AIR FILTER. THE SYSTEM WILL CONSIST OF A COLD-SIDE
ESP AND TWO SPRAY TOWERS CONTROLLING PARTICULATE AND S02 TO 99.6 PERCENT
AND 9C PERCENT. RESPECTIVELY. THE B(W BOILER WILL FIRE HIGH SULFUR (3.5
TO 4.5 PERCENT) WESTERN KENTUCKY COAL. CONSTRUCTION IS NOW 66X COMPLETE
ON THE BOILER AND 50X COMPLETE ON THE FGD SYSTEM. THE DESIGN INCLUDES AN
INDIRECT HOT AIR REHEAT SYSTEM. 1UCS WILL CONSTRUCT A SLUoGf DISPOSAL
SYSTEM TO SERVICE BOTH GREEN 1 AND 2«
=•16 RIVERS ELECTRIC
GREEN
2
NEW 242.0 •* (GROSS)
242.0 «• CESC)
COAL
3.7S XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: •«•*!
STATUS 2 STARTUP 12/80
THE EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED UNIT IS BEING
SUPPLIED BY AMERICAN AIR FILTER. THE SYSTEM WILL CONSIST OF A COLD SIDE
ESP AND TWO SPRAY TOWERS CONTROLLING PARTICULATE AND S02 TO 99.6 PERCENT
AND 90 PERCENT. RESPECTIVELY. THE PSW BOILER WILL FIRE HIGH SULFUR (3.5
4.5 PERCENT) WESTERN KENTUCKY COAL. THE FGD SYSTEM WILL INCLUDE AN
INDIRECT HOT AIR REHEAT SYSTEM. IUCS WILL CONSTRUCT A SLUDGE DISPOSAL
SYSTEM TO SERVICE BOTH GREEN 1 AND 2. THE BOILER IS CURRENTLY el COMPLETE
AND CONSTRUCTION HAS JUST BEGUN ON THE FGD SYSTEM.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
HEW 416.0 4W (GROSS)
416.0 "W (ESC>
COAL
3.30 XS BITUMINOUS
LIMESTONE
RILEY STOKER/ENVIRONEERING
ENERGY CONSUMPTION: 2.9X
STATUS 1 STARTUP 7/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. RILEY
STOKER WAS THE SUPPLIER OF THE FOUR VENTURI-ABSORBER MODULES AT THIS
UNIT. SCRUBBER TANKS AND PUMPS ARE NEOPRENE LINED. A HIGH EFFICIENCY ESP
IS UPSTREAM OF THE FOUR VENTURI-ABSORBER SCRUBBER MODULES FOR PARTICULATE
CONTROL. THE CONCRETE STACK IS LINED WITH CEILCOTE FLAKELINE 151. NO RE-
HEAT SYSTEM IS INCLUDED. THE FIRST LIMESTONE SLURRY SCRUBBER MODULE WAS
PLACED IN SERVICE ON SEPTEMBER 9.1976. AND OPERATED INTERMITTENTLY UNTIL
APRIL 1. 1977. ALL FOUR MODULES BECOME OPERATIONAL ON JULY 24. 1978.
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION ABSTRACT
CENTRAL ILLINOIS LI6HT THE UTILITY HAS NOT YET SELECTED A s'STEN SUPPLIER. THE UTILITY KILL
DUCK CREEK USE ESP'S FOR PARTICUIATE CONTROL AND EITHfR LIMESTONE OR DOUBLE ALKALI
Z FOR SCa ABSORPTION. THE UTILITY IS NOW IN THE PROCESS OF EVALUATING
NEK 416.0 4W (GROSS) BIOS AND A STUDY IS UNDERWAY TO DETERMINE THE SLUD6E DISPOSAL STRATEGY
«16.0 • * THAT WILL BE EMPLOYED.
COAL
3.30 XS BITUMINOUS
LIKES TONE
VENDOR NOT SELECTED
ENEB6Y CONSUMPTION: 2.91
STATUS 5 STARTUP 1/64
CENTRAL ILLINOIS PUBLIC SERV
NEMTON
1
*EW 617.0 •* (CROSS)
617.0 «W (E$C>
COAL
4.00 ZS BITUMINOUS
DUAL ALKALI
PUELL/ENVIROTECH
ENERGY CONSUMPTION: ««««X
STATUS 2 STARTUP 11/79
A CONTRACT HAS BEEN AWARDED BY CIPSO TO BUELL/ENVIROTECH FOR THE
INSTALLATION OF AN EMISSION CONTROL SYSTEM ON UNIT 1. THE KEY COM-
PONENTS OF THE EMISSION CONTROL SYSTEM INCLUDE: A HIGH-EFFICIENCY ESP;
FOUP PRECOOLERS, FOUR POLYSPHERE ABSORBERS. THREE THICKENERS. TWO E X-
PERI«NTAL REHEAT SYSTEMS. AND THREE HORIZONTAL EXTRACTION FILTERS FOR
SLUDGE DEWATERING. MORE THAN SO PERCENT OF THE CONSTRUCTION WORK
AT THE PLANT HAS BEEN COMPLETED. THE FGD SYSTEM WILL HAVE CEILCOTE-
LINED ABSORBER MODULES.
CENTRAL MAINE POWER
TEARS ISLAND
1
HEW 600.0 «W (GROSS)
600.0 MW
-------
EPA UTILITY fc-c SURVEY: FEBRUARY - PARCH 1979
SECTION 2
STATUS OF FED SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COLUMBUS t SOUTHERN OHIO ELEC.
CONESVILLE
5
NEW 411.0 *w (GROSS)
411.0 MM (ESC)
COAL
4.67 SS BITUMINOUS
LIME
AIR CORRECTION DIVISION. UOP
ENERGY CONSUMPTION: 3.9:
STATUS 1 STARTUP 1/77
REFER TO SECTION J OF THIS REPORT FOR ADDITIONAL INFORMATION. THE
tOILER AKD ESP WERE COMPLETED AND PLACED IN SERVICE IN SEPTEMBER 19?6.
THE b-SIDE MODULE BECAME AVAILABLE F0« SERVICE IN JANUARY 1977.
COMMERCIAL OPERATIONS HERE ACHIEVED ON FEBRUARY 1?, 1<>77 . THE EMISSION
CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A COLD-SIDE ESP FOLLOWED BY
THO LIME TCA MODULES SUPPLIED &Y UOP. DRAVO is SUPPLING THE THIOSORPIC
LIME PEA6ENT. IUCS IS SUPPLYJNb > POZ-0-TEC SLUDbE STABILIZATION FACILITY
COLUMBUS I SOUTHERN OHIO ELEC.
CONESVILLE
6
NEW 411.0 MU (GROSS)
411.0 My (E$C>
COAL
4.67 SS BITUMINOUS
LIME
•iR CORRECTION DIVISION. UOF
ENERCT CONSUMPTION: 3.«
STATUS 1 STARTUP 6/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. CtSOE
SIGNED LONG TERM CONTRACTS WITH DRAVO FOR THE PURCHACE OF TH10SORplC LIME
AND WITH IUCS FOR A SIUD6E FIXATION SYSTEM. CONSTRUCTION COMMENCED IN
1977 AND WAS COMPLETED IN JANUARY 1978. SIMILAR TO UNIT 5. THIS MINE
MOUTH PLANT BURNS COAL WITH 17X ASH AND 4.5 TO 4.91 SULFUR CONTENTS. THE
DESIGN INCLUDES A" ESP UPSTR£AM OF THE F6D STSTEM FOR PARTICIPATE
CONTROL. THE FGD SYSTEM INCLUDES TWO LIME TCA MODULES FOR TH£ REMOVAL OF
S02.
COLUMBUS I
POSTON
5
MEW
SOUTHERN OHIO ELEC.
375.0 MM (GROSS)
375.0 MU (ESC)
COAL
2.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: • •«•*
STATUS 6 STARTUP 0/83
THIS UNIT WILL BURN HIGH SULFUR OHIO COAL (APPROXIMATELY 2.5 PERCENT
SULFUR CONTENT). THE DESIGN OF THE EMISSION CONTROL STRATEGY HAS NOT
YET BEEN FINALIZED. THE PROCESS WILL EITHER BE LIME. LIMESTONE. OR
DOUBLE ALKALI.
COLUMBUS (
POSTON
6
NEW
SOUTHERN OHIO ELEC,
375.0 MU (GROSS)
375.0 MU (FSC)
2.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****z
STATUS 6 STARTUP 0/&5
THIS UNIT HILL BURN HIGH SULFUR COAL
COAL
3.60 XS
LIMESTONE
AIR CORRECTION DIVISION* UOP
ENERGY CONSUMPTION: 5.6X
STATUS 2 STARTUP 10/79
THE AIR CORRECTION DIVISION OF UOP WAS AWARDED THE CONTRACT FOR A UET
LIMESTONE SYSTEM THAT WILL BE BACKFITTED ON TO BOILER NO. 51. ONE OF TWO
IDENTICAL BOILERS SUPPLING STEAM TO AN 850-MW TURBINE-GENERATOR. THE
SLUDGE WILL BE STABILIZED AND HAULED TO A LANDFILL. REHEAT WILL BE
PROVIDED BY A STEAM COIL WHICH UILL HEAT THE AMBIENT AIR THAT IS PUMPED
INTO THE SCRUBBER OUTLET BEFORE THE FLUE GAS ENTcRS THE STACK. THE S02
EMISSION STANDARD IS 1.S Lb. S02/MM BTU. CONSTRUCTION {S
ABOUT 60S COMPLETE.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
1
MEW 545.0 MW (GROSS)
327.0 MW (ESC)
COAL
.63 XS LIGNITE
LIME
COMBUSTION ENGINEERING
ENERBV CONSUMPTION: ••••!
STATUS 2 STARTUP 5/79
THIS UNIT IS UNDER THE COMBINED OWNERSHIP OF COOP PO*ER AND UNITED POWER.
A CONTRACT HAS BEEN AWARDED TO COMBUSTION ENGINEERING FOR THE INSTALLA-
TION OF LIME FGD SYSTEMS ON UNITS 1 AND 2 AT THIS STATION. THE FGD SYSTEM
FOR EACH BOILER WILL CONSIST OF FOUR SPRAY TOWER ABSORBER NODULES FOR S02
REMOVAL. ELECTROSTATIC PRECIPlTATORS WILL BE INSTALLED UPSTREAM OF EACH
ABSORBER TRAIN. CONSTRUCTION BEGAN EARLY IN AUGUST 1977. THE UNIT 1$ NOW
E5-90X COMPLETE. BAD WINTER HEATHER SLOWED CONSTRUCTION SLIGHTLY.
11
-------
EP* UTILITY Ft>D SURVEY: FEbRUA^V - MARCH 1979
SECTION 2
STATUS OF FSB SYSTEMS
UNIT 1DEHTIFICATION
ABSTRACT
COOPERATIVE POWER ASSOCIATION
COAL CREEK
*EV 545.0 •« (GROSS)
227.0 M* (ESc)
COAL
.6! IS LI6NITE
LIKE
COMBUSTION ENblNEcRlNfi
ENERGY CONSUMPTION: «•••!
STATUS 2 STARTUP 10/80
THIS UNIT IS UNDER THE COMBINED OWNERSHIP OF COOP POWER AND UNITED
A CONTRACT HAS BEEN AWARDED TO COMBUSTION ENGINEERING FOR THE INSTALLA-
TION OF LIKE FCD SYSTEMS ON UNITS 1 AND 2 AT THIS STATION. THE F6D STSTEM
FOR EACH BOILER WILL CONSIST OF FOUR SPRAY TOWER ABSORBER MODULES FOR SO 2
REMOVAL. ELECTROSTATIC PRECIPITATORS WILL BE INSTALLED UPSTREAM OF EACH -
APSOR6ER TRAIN. CONSTRUCTION BEGAN EARjJT IN AUGUST 1977 AND THE UNIT IS
NOW 4«» COMPLETE. THERE HAVE BEEN MINOR DELAYS BUT START-UP IS STILL
SCHEDULED FOR NOVEMBER 1979.
DELMARVA POWER fc LIbHT
DELAWARE CITY
1 -!
RETROFIT iec.0 «w (GROSS)
ieo.o <<
COKE
7.50 *S COrE
DAVY POWERGAS
ENERGY CONSUMPTION: ««*«x
STATUS 2 STARTUP 4/50
DELMARVA'S DELAWARE CITY PLANT HAS 4 BOILERS. 3 OF WHICH HAVE STEAM
CAPACITIES OF 500K LBS/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS
ELECTRICAL POWER FOR GETTY REFINING I MARKETING. 7-8X S COKE WILL BE
EURMD IN THE BOILERS (INSTEAD OF THE LOW-S CRUDE OIL NOW BURNED) WHEN
THE CONTROL SYSTEM GOES INTO OPERATION IN APRIL 198Q. DELNARVA HILL USE
VEkTbFI SCRUbBERS FOR PARTICULATE REMOVAL AND WELLMAN-LORD FGD SYSTEMS AT
EACH BOILER GAS EXIT FOR S02 CONTROL. DESIGN PARTICULATE AND S02 REMOVAL
EFFICIENCIES ARE 90 AND 85-90 PERCENT RESPECTIVELY. CONSTRUCTION IS 38*
COMPLETE.
DUfiUESNE LIGHT
ELDA1A
1-4
RETROFIT 510.0 •* (GROSS)
510.0 *W (ESc)
»•••• ss
LIME
CHEMIcO
ENERGY CONSUMPTION: 3.5*
STATUS 1 STARTUP 10/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE FGD SYSTEM ON THIS 4-ftOILER UNIT CONSISTS OF FIVE COMMON-HEADERED
SINGLE STAGE VENTURI SCRUBBER-ABSORBERS DOWNSTREAM FROM A MECHANICAL
COLLECTOR-ESP PARTICULATE REMOVAL SYSTEM. THE PLANT BURNS COAL WITH A
HEATING VALVE OF 11*000 BTU/LB AND SULFUR AND ASH CONTENTS OF 1.8 TO 2.2X
AND 211 RESPECTIVELY. DEWATE«ED SLUDGE FROM THE 1UCS PLANT IS HAULED TO
AN OFF-SITE LANDFILL. THE SYSTEM INCLUDES A DIRECT OIL-FIRED STACK GAS
REHEAT SYSTEM. DESIGNED REMOVAL EFFICIENCIES ARE 991 (PART) AND 832
(S02).
DU6UESNE LIGHT
PHILLIPS
1-6
RETROFIT 410.0 <• (GROSS)
410.0 *W (ESC)
COAL
2.00 SS
LIME
CHEMIcO
ENERGY CONSUMPTION: 2.4?
STATUS 1 STARTUP 7/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE FGD SYSTEM ON THIS 6-BOILER UNIT CONSISTS OF ONE 2-STAGE AND THREE
SINGLE STAGE VENTURI SCRUBBER.ABSORBERS DOWNSTREAM FROM A MECHANICAL
COLLECTOR-ESP PARTICULATE REMOVAL SYSTEM. THE PLANT BURNS COAL WITH A
HEATING VALVE OF 11.000 BTU/LB AND SULFUR AND ASH CONTENTS OF 1.8 TO 2.2S
AND 211 RESPECTIVELY. DEWATfRED SLUDGE FROM THE IUCS PLANT IS HAULED TO
AN OFF-SITE LANDFILL. THE SYSTEM INCLUDES A DIRECT OIL-FIRED STACK GAS
REHEAT SYSTEM. DESIGNED REMOVAL EFFICIENCIES ARE 99* (PART) AND e3X(S02).
EAST KENTUCKY POWER COOP
SPURLOCK
2
NEW SCO.O NW (GROSS)
500.0 «W (ESC)
COAL
3.50 SS
LIME
•DL/COMBUSTION E8UIP ASSOCIATE
ENERGY CONSUMPTION: ••••«
STATUS 3 STARTUP 10/80
A CONTRACT HAS BEEN AWARDED TO ADL'COMBUSTION EQUIPMENT ASSOCIATES FOR
A LIME SLURRY FGD SYSTEM ON THE NEW 500-MW UNIT SPURLOCK 2. PARTICULATE$
WILL BE CONTROLLED BY A 99.5* EFFICIENT ESP. COOLING TOWER SLOWDOWN WILL
BE USED AS THE MAKE-UP WATER SOURCE F.OR THE FGD SYSTEM. THE DESIGN S02
REMOVAL EFFICIENCY IS 90S. THE SYSTEM IS NOW IN THE DESIGN PHASE.
GENERAL PUBLIC UTILITIES
COHO
1
«|£W 800.0 »W (GROSS)
800.0 MM (ESO
COAL
3.50 SS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
FNER6Y CONSUMPTION: • •••S
STATUS 6 STARTUP 12/85
STARTUP DATE WAS CHANGED TO 5/88 FOR BOTH BOILER AND DESULFURIZATIOft
SYSTEM. LINE AND LIMESTONE SCRUBBING ARE THE PRIMARY STRATEGIES BEING
CONSIDERED FOR COMPLIANCE WITH NEW SOURCE PERFORMANCE STANDARDS. NO
DECISION HAS BEEN MADE YET. ALTHOUGH A SLURRY TYPE SYSTEM IS NOT
CONTEMPLATED.
12
-------
EPA UTILITY FPD SURVEY: FEBRUARY - "ARCH 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
GENERAL PUBLIC UTILITIES
SEVARD
T
<*EM °oo.o MW (GROSS)
EOO.O Mb (ESc>
COAL
••••• JS
"ROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: •••.!
STATUS 6 STARTUP 12/F5
STARTUP DATE WAS CHANGED TO 5/65 FOR BOTH BOILER AND DESULFURINATION
SYSTEM. LINE AND LIMESTONE SCRUBBING ARE THE PRIMARY STRATEGIES BEING
CONSIDERED FOR COMPLIANCE KITH THE NEW SOURCE PERFORMANCE STANDARDS.
NO DECISION HAS BEEN MADE YET. ALTHOUGH A SLURRY TYPE WILL NOT BE USED.
GULF POWER
SCHCL2
1.2
RETROFIT 23.o MW (GROSS)
23.0 »M (ESC)
COAL
2.50 IS BITUMINOUS
LIMESTONE/THOROUGHBRED 121
CHIYODA INTERNATIONAL
fNERGY CONSUMPTION: ••••»
STATUS 1 STARTUP 8/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. CHIYQDA
INTERNATIONAL SUPPLIED THIS 23 MW PROTOTYPE UNIT WHICH BEGAN OPERATION
ON AUGUST 30. 1978. THE CT.121 SYSTEM INCLUDES A NEWLY DEVELOPED JET
tUEBLING REACTOR WHICH FEATURES A LARGE GAS-LIQUID INTERFACIAL AREA AND
PROVIDES PARTICULATE AS WELL AS $02 REMOVAL. MIST ELIMINATION is PROVIDED
BY A DOUELE PASS VERTICAL CHEVRON. GYPSUM IS PRODUCED AND STACKED IN THE
EXISTING POND. THE STACKING CAPABILITIES OF THE GYPSUM ARE BEING TESTED.
ALONG WITH THE GROUND WATER NEAR THE STACK SITE TO CHECK FOR LEACHING.
HOOSIER ENERGY
MEROM
1
HEM *90.o MW (GROSS)
4*1.0 MW (ESC)
COAL
3.50 XS
LIMESTONE
MITSUBISHI INTERNATIONAL
ENERGY CONSUMPTION: ••••X
STATUS 2 STARTUP 4/61
HOOS1ER ENERGY AWARDED A CONTRACT TO MITSUBISHI INTERNATIONAL CORP. FOR
TWO LIMESTONE FGD SYSTEMS FOR MEROM 1 AND 2. THE NEW 490 NW COAL-FIRED
UNITS ARE PLANNED FOR LOCATION IN SULLIVAN, INDIANA. THE FLUE GAS STREAMS
kILL BE CLEANED OF PARTICIPATE WITH ESP'S (99.41) AND OF SULFUR DIOXIDE
WITH GRID-TOMER ABSORBERS («ox). SLUDGE WILL BE STABILIZED AND
STOCKPILED. THE GROUND WAS BROKEN FOR CONSTRUCTION IN NOVEMBER 1977.
BOILER STRUCTURAL STEEL IS NOW BEING ERECTED AND FGD FOOTINGS ARE IN PLACE
HOOSIER ENERGY
MEROM
2
V£M. 490.0 MU (GROSS)
441.0 My (ESc)
COAL
3.50 XS
LIMESTONE
MITSUBISHI INTERNATIONAL
ENERGY CONSUMPTION: • •••»
STATUS 2 STARTUP 1/f2
HOOSIER ENERGY AWARDED A CONTRACT TO MITSUBISHI INTERNATIONAL CORP. FOR
TWO LIMESTONE FGD SYSTEMS FOR HEROM 1 AND 2. THE NEW 490 MW COAL-F1RED
UNITS ARE PLANNED FOR LOCATION IN SULLIVAN, INDIANA. THE FLUE GAS STREAMS
WILL BE CLEANED OF PARTICULATE WITH ESP'S (99.41) AND OF SULFUR DIOXIDE
WITH BRIO-TOWER ABSORBERS ooX). SLUDGE WILL BE STABILIZED AND
STOCKPILED. THE GROUND MAS BROKEN FOR CONSTRUCTION IN NOVEMBER 1977. BUT
DUE TO THE BAD WINTER WEATHER, CONSTRUCTION WAS DELAYED' THE BORER IS
ESSENTIALLY COMPLETE. STARTUP IS EXPECTED SHORTLY.
HOUSTON LIGHTING I POWER CO.
W.A. PARISH
DEW 550.0 MM (GROSS)
512.0 MH (ESC)
COAL
.60 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***«x
STATUS 5 STARTUP 10/P2
HL&P WILL BE INSTALLING AN F6D SYSTEM ON THE UTILITY'S 600 MW W. A.-
PARISH 8 UNIT. PARTICUALTE MATTER WILL BE CONTROLLED BY BAGHOUSE UP-
STREAM OF THE LIMESTONE SLURRY FGD SYSTEM. THE FGD SYSTEM WILL BE
DESIGNED TO REMOVE SO? WITH AN EFFICIENCY OF GREATER THAN 83X. REHEAT
WILL BE PROVIDED BY BY-PASSING 7X OF THE PARTICULATE CLEANED
GAS. SLUDGE WILL BE DEWATERED. BLENDED WITH FLYASH AND DISPOSED IN AN
ON SITE LANDFILL. INITIAL STARTUP IS SCHEDULED FOR FALL. 1982.
INDIANAPOLIS POMER C LIGHT
PETERSBURG
B
NEW 532.0 MU (GROSS)
532.0 MW (ESC)
COAL
3.25 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 12/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE VET
LIMESTONE FGD SYSTEM INSTALLED ON THIS UNIT WAS SUPPLIED BY THE AIR
CORRECTION DIVISION OF UOP. UNIT 3 FIRES BITUMINOUS COAL HAVING A SULFUR
CONTENT OF 1.5-4.5X. AN ASH CONTENT OF 9-1 OX AND A 11,000 BTU/LB
VALUE. TWO E$PS PROVIDE PRIMARY PARTICULATE CONTROL UPSTREAM OF A FOUR-
MODULE TCA FGD SYSTEM. STABILIZED SLUDGE IS DISPOSED ON AN ON-SITE POND.
THE DESIGN INCLUDES AN INDIRECT STEAM TUBE REHEAT SYSTEM. SHAKE DOWN
AND DEBUGGING OPERATIONS ARE STILL PROCEEDING.
13
-------
EPA UTILITY FbD SURVEY: FEe»U»tY - MRCH 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
INDIANAPOLIS POWER * LIGHT
PETERSBURG
t
NEW 53o«0 <
COAL
.32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: • •••X
STATUS 1 STARTUP 8/76
REFER TO SECTION 3 Of THIS REPORT FoR ADDITIONAL INFORMATION. COMBUSTION
ENGINEERING SUPPLIED THE LIMESTONE EMISSION CONTROL SYSTEM FOR THIS NEW
COAL FIRED UNIT. THE UNIT CONSISTS OF. A COLD-SIDE ESP AND SPRAY TOWERS
FOR THE CONTROL OF S02 AND PARTICULATE EMISSIONS. 30X OF THE FLUE GAS IS
BYPASSED FOR REHEAT. NOX EMISSIONS ARE CONTROLLED BY AN AIR OVERFIRE
SYSTEM AT THE TAN6ENTIALLY FlRED PULVERIZED BUNKERS. THE CLEANED GASES
ARE VENTED TO A 600 FT STACK. SLUDGE IS MIXED WITH pOTTOM ASH AND
DISPOSED OF IN THE EXISTING ON-SITE BOTTOM ASH POND.
KANSAS POWER I LI6HT
JEFFREY
j
NEW 700.0 "W (GROSS)
490.0 MM (ESC)
COAL
.30 ZS
LIMESTONE
COMeUSTION ENGINEERING
ENERGY CONSUMPTION: • •••X
STATUS 2 STARTUP 6/60
COMBUSTION ENGINEERING IS SUPPLYING THE EMISSION CONTROL SYSTEM FOR THIS
NEW COAL FIRED UNIT. THE SYSTEM WILL CONSIST OF A COLD-SIDE ESP AND SPRAY
TOWERS FOR THE CONTROL OF PARTICIPATE AND S02 EMISSIONS. 30Z OF THE FLUE
GAS WILL BE BYPASSED FOR REHEAT. AN OVERFIRE AIR SYSTEM AT THE TANGENTIAL
FIRED PULVERIZED BURNERS WILL CONTROL NOX EMISSIONS. THE CLEANED GASES
MILL BE VENTED TO A 600 FT STACK. SLUDGE WILL BE MIXED WITH BOTTOM ASH
AND DISPOSED ON-SITE IN THE BOTTOM ASH POND. THE SYSTEM STEEL WORK IS UP
AND CONSTRUCTION IS APPROXIMATELY 60Z COMPLETE.
14
-------
EPA
F6D SURVEY: FEBRUARY - VARCH 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KANSAS POWER k LIGHT
LAURENCE
4
RETROFIT 125.0 *w (GROSS)
125.0 1W (ESc)
COAL
.55 XS
LIKES TONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: • •••!
STATUS 1 STARTUP 1/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE NEk LIMESTONE F6D SYSTEM COMMENCED OPERATIONS IN EARLY JANUARY 1977.
THE NEK SYSTEM REPLACED MARELE-8EO TOWERS WITH SPRAY TOWERS. THERE HAVE
BEEN NO FORCED SCRUPBER OUTA6ES REPORTED SINCE START-UP. CONTINUOUS SOi
MONITORS HAVE RECORDED S02 REMOVAL EFFICIENCIES OF BETTER THAN PSt.
THE UTILITY REPORTED PARTICULATE REMOVAL IS SUCH THAT KO VISIBLE PLUME
EXITS THE STAC*. THE PLANT IS F1RIN6 COAl RATED AT 10,000 &TU/L6 »lTH A
SULFUR CONTENT OF 0.51
KANSAS POWER 6 LIGHT
LAWRENCE
5
RETROFIT 420.0 *w (GROSS)
420.0 <•* (ESC)
COAL
.55 IS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: • •••X
STATUS 1 STARTUP 11/71
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE
ORIGINAL LIMESTONE INJECTION AND TAIL-END SCRUBBING SYSTEM WAS SHUT
DOWN ON MARCH 20 SO THAT THE NEW ROD-SCRUBBER AND SPRAY TOWER APSORBER
SYSTEM COULD BE TIED INTO THE UNIT. THE NEW SYSTEM, WHICH INCLUDES TWO
MODULES. EACH CAPABLE OF HANDLING APPROXIMATELY 50 PERCENT OF THE TOTAL
BOILER FLUE GAS FLOW. C»ME ON LINE APR]L 14. 1978. THE SYSTEM DESIGNER
AND SUPPLIER WAS COMBUSTION ENGINEERING. THE UNIT FIRES LOW SULfUR
WYOMING COAL WITH A HEAT CONTENT OF 1C.000 BTU/LB.
KENTUCKY UTILITIES
GREEN RIVER
1-1
RETROFIT 64.0 «w (GROSS)
64.0 *W (ESc>
COAL
4.00 tS BITUMINOUS
LIME
AMERICAN AlR FILTE"
ENERGY CONSUMPTION: 3.ix
STATUS 1 STARTUP 9/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE SCRUBBER PLANT INSTALLED AT THIS STATION CONSISTS OF ONE MODULE
DESIGNED TO REMOVE PARTICULATE (VARIABLE-THROAT VENTURI) AND SG2 (MOBILE
-BED CONTACTOR) FROM COAL-FIRED BOILER FLUE GAS. THE SCRUBBER WAS
DES16NED AND SUPPLIED BY AAF. SLUDGE IS DISPOSED IN AN ON-SITE UNLINED
POND. THE COAL BURNED HAS SULFUR AND ASH CONTENTS OF 4,Q AND 11T
RESPECTIVELY AND A MOISTURE CONTENT OF 6-10 PERCENT. INITIAL STARTUP
OCCURRED IN SEPTEMBER 1975. COMMERCIAL OPERATION BEGAN IN J»NU">Y 1976.
LAKELAND UTILITIES
•CINTOSH
3
MEW 364.0 MU (6ROSS>
3*4.0 MM (ESC>
COAL
2.56 ZS BITUMINOUS
LIMESTONE
9ABCOCK t WILCOX
ENERGY CONSUMPTION: ••••x
STATUS 3 STARTUP 10/81
THE CITY OF LAKELAND DEPARTMENT OF ELECT RjC AND WATER UTILITIES A.ARDEO
A CONTRACT TO E-tW FOR AN EMISSION CONTROL SYSTEM ON THE UTILITY'S NfW
350-MW POWER 6ENERA6ING UNIT, MCINTOSH J. THE UNIT WILL UTILIZE COLD
SIDE ESP'S FOR PARTICULATE REMOVAL AND TWO LIMESTONE SCRUBBER APSORBER
MODULES. START-UP IS SCHEDULED FOR OCTOBER 1961. THE COAL WILL CONTAIN
A90UT 2.5X SULFUR. THE UNIT DESjfcN INCLUDES A REHEAT AND AN IUCS SLUDGE
DISPOSAL SYSTEM. SITE EXCAVATION HAS BEGUN.
LOUISVILLE GAS ft ELECTRIC
CANE RUN
It
RETROFIT IBB.O «w (GROSS)
168.0 MW (ESC)
COAL
3.75 ZS BITUMINOUS
LINE
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.61
STATUS 1 STARTUP 8/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE FED SYSTEM RETROFITTED ON THIS BOILER WAS DESIGNED AND SUPPLIED BY
AMERICAN AIR FILTER AND WAS FIRST PLACED Ik THE GAS PATH ON AUGUST 7.
1976. THE SYSTEM CONSISTS OF TWO PARALLEL MODULES WHICH INCLUDE MOBILE
BED CONTACTORS AND OPERATE WITH A CARBIDE LIME ADDITIVE. FOLLOWING A
NUMBER OF MAJOR SYSTEM MODIFICATIONS (CHEVRON-TYPE MIST ELIMINATOR. OIL
FIRED REHEAT, PLASITE DUCT LINER. HIGHER L/G), THE SYSTEM SUCCESSFULLY
PASSED COMPLIANCE TESTING (P5X S02 REMOVAL) ON AUGUST 3 AND 4. 1977.
LOUISVILLE GAS i ELECTRIC
CANE RUN
5
RETROFIT 190.0 MU (GROSS)
190.0 MU (ESC)
COAL
3.75 ZS BITUMINOUS
LINE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 12/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE F6D SYSTEM FOR THIS UNIT WAS DESIGNED AND SUPPLIED BY COMBUSTION
ENGINEERING. IT CONSISTS OF TWO SPRAY TOWER ABSORBERS FOR FULL-LOAD S02
REMOVAL AND UTILIZES CARBIDE LIME AS THE ABSORBING REAGENT. IN-LINE STEAM
REHEAT. A COMMON REACTION TANK. AND A THICKENER FOR SOLIDS DEWATERING
ARE INCLUDED. AN EXISTING UPSTREAM ESP PROVIDES PRlPARY pARTKuLATE
CONTROL. THE FGD SYSTEM BEGAN INITIAL OPERATION IN DEC. 1977 BUT A COAL
STRIKE FORCED A PLANT SHUTDOWN. THE SYSTEM UAS RE-STARTED MARCH 24. 1978.
15
-------
rPA UTIL1TT f bc SURVEY:
- MftCH 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE CAS I ELECTRIC
CANE RUN
(GROSS)
»ETR0flT 2E8.0
COAL
3. 75 XS BITUMINOUS
DUAL ALKALI
•DL/COMBUSTION ESU1P ASSOCIATE
ENERGY CONSUMPTION: 1.01
STATUS 1 STARTUP 3/79
REFEK TO SECTION 3 Of THIS REPORT FOR ADDITIONAL INFORMATION.
A.6. LITTLE/COMBUSTION EOU1PNENT ASSOCIATES HAS SUPPLIED THE INSTALLATION
OF A DOUBLE ALKALI SYSTEM. THE FEDERAL EPA WILL SUBSIDIZE A MAXIMUM
J4.5 ff FOR OPERATION, RESEARCH AND DEVELOPMENT, AND REPORT WRITING FOR
A ONE-YEA* PERIOD FOLLOWING THE FIRST THREE MONTHS OF OPERATIONS (NOTE:
THIS SUBSIDY KILL NOT b£ APPLIED FOR AN* CAPITAL EXPENDITURES).
LOUISVILLE 6Ai I tLECTRK
•ILL CREEK
1
RETROFIT 3St.o ** (GROSS)
35E.O »• (ESC)
COAL
3.75 ZS
LIHE'LIMESTOkt
COMBUSTION ESG1NEEP11G
FNER&Y CONSUMPTION: 1.41
STATUS 2 STARTUP 4/'1
A COMPLIANCE SCHEDULE HAS SUBMITTED TO THE JEFFERSON COUNTY AIR POLLUTION
CONTROL DISTRICT WITH 4/&1 ESTABLISHED AS THE STARTUP DATE FOR AN F6D
STSTcM. OPERATING DATA AND INFORMATION FROM THE FULL-SCALE SCRUBBER PLANT
NOW IK SERVICE ON THE NO. 4 UNIT AT CANE RUN WILL BE OBTAINED BEFORE THE
UTJLiTY PROCEEDS WITH ADDITIONAL SYSTEM DESIGN WORK. A CONTRACT WAS
AWARDED TO COMEUSTION ENGINEERING FOR A LIME/LIMESTONE FGD SYSTEM.
LOUISVILLE 6Ai I ELECTRIC
•ILL CREEK
2
RETROFIT ?so.c MW (G*OSS>
350.0 «w (ESc>
CO*L
3.75 IS
LIME/LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4,2
STATUS 3 STARTUP 4/?2
A COMPLIANCE SCHEDULE WAS SUBMITTED TO THE JEFFERSON COUNTY AIR POLLUTION
CONTROL DISTRICT WITH 4/62 ESTABLISHED AS THE STARTUP DATE FOR «N F6D
SYSTEM. OPERATING DATA AND INFORMATION FROM THE FULL-SCALE SCRUBBER PLANT
NOW IN SERVICE ON THE NO. 4 UNIT AT CANE RUN HILL BE OBTAINED BEFORE THE
UTILITY PROCEEDS WITH ADDITIONAL SYSTEM DESIGN WORK. A CONTRACT WAS
AWAR&ED TO COMBUSTION ENGINEERING FOR A LIME/LIMESTONE FGD SYSTEM.
LOUISVILLE GAS I ELECTRIC
•ILL CREEK
T
NEW 442.0 In (GROSS)
442.0 "W (ESC)
COAL
3.75 ZS BITUMINOUS
LIME
AMERICAN AIR F1LTE?
ENERGY CONSUMPTION: 1.61
STATUS 1 &TABTUP 8/7E
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE SYSTEM
WAS DESIGNED AND SUPPLIED BY AAF AND UTILIZES CARBIDE LIME
AS THE ABSORBENT. FOUR MOBILE-BED ABSORBERS TREAT THE FLUE GAS RESULTING
FROM THE COMBUSTION OF HIGH-SULFUR COAL. THE SYSTEM OPERATES IN AN OPEN
WATER LOOP. THE SCRUBBING WASTE IS STABILIZED WITH FLYASH AND LIME.
THE UNIT BECAME OPERATIONAL ON AUGUST 13, 1978.
LOUISVILLE GAS t ELECTRIC
MILL CREEK
4
«£W 495.0 «b (GROSS)
495.0 MU (ESc)
COAL
3.75 ZS
LIME
AMERICAN AIR FILTER
FNERGV CONSUMPTION: «*•»*
STATUS 2 STARTUP 7/81
tECAliSE POWER DEMAND HAS NOT CONE UP AS RAPIDLY AS HAD BEEN EXPECTED,
UNIT START-UP HAS BEEN MOVED BACK TO JULY 1981. CONSTRUCTION OF THIS
NEW 495-HW COAL-FIRED UNIT IS ON SCHEDULE. CURRENTLY, FOUNDATION WORK
IS Ik PROGRESS. THIS AAF SYSTEM WILL INCLUDE MOBILE-BED ABSORBERS
TREATING HIGH SULFUR COAL FLUE GAS. THE SYSTEMS HATER LOOP HILL BE
CLOSED. THE SLUDGE WILL BE STABILIZED WITH LIME AND FLYASH. STEAM
REHEAT WILL PROVIDE GAS TEMPERATURE ELEVATION OF THE SCRUBBED GASES
PRIOR TO DISCHARGE TO THE MAIN STACK.
LOUISVILLE GAS t ELECTRIC
PADDY'S RUN
RETROFIT 72.0 «W (GROSS)
72.0 MW (ESC)
COAL
2.50 IS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.6Z
STATUS 1 STARTUP 4/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS SCRUBBING SYSTEM WAS DESIGNED BY COMBUSTION ENGINEERING AND PLACED
IN SERVICE IN APRIL 1973. THE FGD SYSTEM CONSISTS OF THO 2-STAGE MARBLE
EED ABSORBERS WHICH ARE DESIGNED TO USE CARBIDE LIME ADDITIVE AS THE
SCRUBBING REAGENT. PADDYS RUN NO. 6 IS A PEAK-LOAD UNIT THAT OPERATES
ONLY DURING DEMAND PERIODS. AN EXTENSIVE EPA SCRUBBER/SLUDGE EVALUATION
STUDY MAS COMPLETED IN AUGUST 1977. THIS UNIT HILL BE RETIRED HHEN MILL
CREEK 3 BECOMES FULLY OPERATIONAL.
16
-------
EP* UTILITY FCD SURVEY: FEB°UARY - MAPCM 1979
SECTION 2
STATUS OF fGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE EAS & ELECTRIC
TR1B3LE COUNTY
1
NEW 575.0 1» (CROSS)
575.0 •«
COAL
4.00 IS BITUMINOUS
OROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPT13N: •••«!
STATUS 6 STARTUP 7/5*
L6HF. »UL si INSTALLlKg FGD SYSTEMS ON TrfO OF THE UTILITY'S TUMBLE
COUNTY UNITS. THE 575-MW UMTS «1LL cURN COAL WITH AN AVERAGE <-T SULFUR
CONTENT (IF NO COAL »ASH IS INCLUDED). PARTICULATE 'ATTER WILL PE
CONTROLLED t- Y CSP'S AK'O SOi WILL BE CONTROLLED PT WET SCRUBBING (901
PEMOV»L EFFICIENCY). SLUDGE DISPOSAL STRATEGY is AS YET. UNDECIDED.
START-UP IS SCHEDULED FOR JULY 1*84 AND 1«86 RESPECTIVELY.
LOUISVILLE CAS 4 ELECTRIC
TRIMBLE COUNTY
•)
NEW 575.0
COAL
.50 XS
PROCESS SOT SELECTED
VENDOR NOT SELECTED
FNER6Y CONSUMPTION: ••••t
STATUS 5 STARTUP M-b
A CONTRACT HAS BEEN AWARDED FOR bOILERS AND TURBINES ON SIX NEM MIDDLE
SOUTH UTILITIES UNITS. THE UTILITY IS CURRENTLY REBUESTING/EVALUATING
tIDS FOR THE FGD INSTALLATIONS ALTHOUGH THE TYPE OF F6D SYSTEM HAS NOT
YET dEEN DETERMINED.
•IDOLE SOUTH UTILITIES
ARKANSAS COAL
4,
N£W 89C.O •* (GROSS)
890.0 ** (ESc>
COAL
.53 XS
PROCESS NOT S£LEcTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••*•*
STATUS 5 STARTUP t/'6
A CONTRACT HAS BEEN AWARDED FOR fc01LE«S AND TURBINES ON SIX NEW KIDDLE
SOUTH UTILITIES UNITS. THE UTILITY IS CURRENTLY REQUESTIN6/EVALUATIN6
BIOS FOR THE FtD INSTALLATIONS ALTHOUGH THE TYPE OF FGD SYSTEM HAS NOT
YET BEEN DETERMINED.
"IDDLE SOUTH UTILITIES
LOUISIANA COAL
1
NEW 890.0 »W (GROSS)
B9C.O «M (ESc>
COAL
.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
FNER6Y CONSUMPTION: ••••X
STATUS 5 STARTUP 0/f6
A CONTRACT HAS BEEN AWARDED FOR BOILERS AND TURBINES ON SIX NEu MIDDLE
SOUTH UTILITIES UNITS. THE UTILITY IS CURRENTLY RECUEST/£VALVAT1N6
tIDS FOR THE FGD INSTALLATIONS ALTHOUGH THE TYPE OF FGD SYSTEM HAS NOT
YET BEEN DETERMINED.
MDDLE SOUTH UTILITIES
LOUISIANA COAL
^
c
NEW S90.0 MH (6ROSS)
890.0 Ik (ESC)
COAL
.50 XS
"ROCESS NOT SELECTED
VENDOR NOT SELECTED
ENER6T CONSUMPTION: •••«*
STATUS 5 STARTUP 0/68
A CONTRACT HAS BEEN AWARDED FOR bOIL£RS AND TURBINES ON $1* NEh MIDDLE
SOUTH UTILITIES UNITS. THE UTILITY IS CURRENTLY REQUESTING/EVALUATING
EIDS FOR THE F6D INSTALLATIONS ALTHOUGH THE TYPE OF FGD SYSTEM HAS NOT
VET cEEN DETERMINED.
17
-------
EPA UTILITY FGD SURVEY: FEpRUA*Y - d»I.Ch 197*
SECTION i~
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
•IDDLE SOUTH UTILITIES
•ISSISSIPPI COAL
1
N£W 990.0 »W (GROSS)
890.C NW
COAL
.SO SS
PROCESS MOT SELECTED
VENDOR NOT SELECTED
ENER6Y CONSUMPTI5N: «••*»
STATUS 5 STARTUP 0/£5
A CONTS.CT HAS BEEN AWARDED FO» BOILERS AND TURBINES ON SIS NEW MIDDLE
SOUTH UTILITIES UNITS. THE UTILITY IS CURRENTLY R£«UESTING/EVALUATING
BIDS FOR THE F6D INSTALLATIONS ALTHOUGH THE TYPE OF FGD SYSTEM HAS NOT
YET BEEN DETERMINED.
•IDDLE SOUTH UTILITIES
•ISSISSIPPI COAL
?
N£W 890.0 •» (6ROSS>
890.0 •* CESc)
COAL
.50 XS
PROCESS WOT StLECTEp
VENDOR NOT SELECTED
FNERGY CONSUMPTION: •••»x
STATUS 5 STARTUP 0/67
A CONTRACT HAS BEEN AWARDED FOR BOILERS AND TURBINES ON SIX NEW MIDDLE
SOUTH UTILITIES UNITS. THE UTILITY IS CURRENTLY REQUEST ING/EVALUATIN6
BIDS FOR THE F6D INSTALLATIONS ALTHOUGH THE TYPE OF F6D SYSTEM HAS NOT
YET bEEN DETERMINED.
•INNESOTA POWtR t LIGHT
CLAY bOSWELL
*
«EW 500-0 "U (GROSS)
475.0 KH (ESC)
CO»L
.00 XS SUbtlTUNIhOUS
LIKE/ALKALINE FLYASH
PEABQDY PROCESS SYSTEMS
ENERGY CONSUMPTION: ««••:
STATUS 2. STARTUP 5II0
PINNtSOTA PtL HAS AWARDED A CONTRACT TO PEABODY PRQCESS SYSTEMS FOR A
LIME/ALKALINE FLYASH SCRUB6INO SYSTEM. THE CONFIGURATION WILL BF. VENTURI
SCRUbEERS FOLLOWED BY SPRAY TOhERS. HOT SIDE ESP'S HILL BE USED FOR
FARTICULATE CONTROL. STACK GAS RbHEAT wILL BE ACCOMPLISHED BY BYPASSING
5X OF FLUE GAS AROUND THE SCRUBBER. THE UNIT WILL FIRE SUBBITUMINOUS
COLSTFIP COAL kjTH A SULFUR CONTENT OF Q.fl, AND AN ASH CONTENT OF 9.0Z
(HEATING VALUE-6300 BTU/LB). MAKE-UP WATER SOURCE WJLL BE THE filVER AND
THE CLAY LINED POND. CONSTRUCTION OF THE FGD SYSTEM IS ABOUT 9CX
COMPLETE .
•INNKOTA POWER COOPERATIVE
•ILTON R. YOUNG
2
«EW 477.0 «w (GROSS)
405.0 «W (ESC)
COAL
.70 XS LIGNITE
LIME/ALKALINE FL»ASH
•Dt/COMBUSTjOh E3UIP
FNERSY CONSUMPTION; 1.91
STATUS 1 STARTUP 9/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS LIME/ALKALINE FLYASH SCRUBBING WAS DESIGNED AND SUPPLIED BY
ADL/CCMPUSTION EQUIPMENT ASSOCIATES. IT CONSISTS OF A COLD-SIDE ESP
FOLLOWED BY TWO SPRAY TOWERS. THE DESIGN INCLUDES A WASH TRAY AND A
CHEVkON FIST ELIMINATOR. 15* FLUE GAS BYPASS PROVIDES STACK 6AS REHEAT.
THE UNIT FIRES A LOW-SULFUR NORTH DO«OTA LIGNITE WITH AN AVERAGE ASH
CONTtNT OF £ PERCENT, SULFUR CONTENT OF 0.7 PERCENT. AND HEAT CONTENT OF
6500 ETU/LB. THE FLYASH ALKALINITY IS USED AS THE PRIMARY S02 REAGENT.
•ONTANA POWEK
COLSTRIP
1
NEW
360.0 «w (GROSS)
360.0 •w (F.Sc>
COAL
.77 XS SUEoITUMINOUS
LIME
•DL/COMBUSTION EBUIP ASSOCIATE
ENERGY CONSUMPTION: 1.31
STATUS 1 STARTUP 9/75
REFER TO SECTION I OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS FGD EQUIPPED UNIT WAS DECLARED COMMERCIAL IN NOVEMBER 1975. THE
SCRU19IN6 SYSTEM PROVIDES PARTICULATE AND S02 CONTROL WITH THREE SCRUBBER
MODULES. EACH MODULE CONSISTS OF A DOWNFLOW VENTURI SCRUBBER CENTERED
WITHIN AN UPFLOW SPRAY TOWER ABSORBER. EACH MODULE CAN TREAT «ox OF
THE TOTAL BOILER FLUE GAS AND THE MODULES CANNOT BE BYPASSED. THE UN-
STABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED DISPOSAL POND. IN-LINE
STEAM REHEAT AND CLOSED WATER LOOP CAPABILITY ARE INCLUDED IN THE SYSTEM.
MONTANA POWER
COLSTRIP
2
NEW 360.0 »W (GROSS)
360.0 •• (ESC)
COAL
.77 ZS SUBblTUMINOUS
LIME
AOL/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 5/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS F60 CGUIPPED UNIT WAS DECLARED COMMERCIAL IN AUGUST 1976. THE
SCRUBBING SYSTEM PROVIDES PARTICULATE AND S02 CONTROL WITH THREE SCRUBBER
MODULES. EACH MODULE CONSISTS OF A DOWNFLOW VENTURI SCRUBBER CENTERED
WITHIN AN UPfLOW SPRAY TOWER ABSORBER. EACH MODULE CAN TREAT 40t OF
THE TOTAL BOILER FLUE GAS AND THE MODULES CANNOT BE BYPASSED. THE UN-
STABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED DISPOSAL POND. IN-LINE
STEAM REHEAT AND CLOSED WATER LOOP CAPABILITY ARE INCLUDED IN THE SYSTEM.
18
-------
EP* UTILITY Ffo SURVEY: FEBRUARY - MARCH 1979
SECTION i
STATUS Of F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MONTANA POWER
COLSTRIP
5
HEW 700.Q "y (CROSS)
700.0 *W (ESC>
COAL
.70 XS
LIME/ALKALINE FLYASH
AOL/COMBUSTION E3UIP ASSOCIATE
ENERGY CONSUMPTION: ««««X
STATUS 3 STARTUP 7/80
A CONTRACT FOR THE INSTALLATION Of T«0 ADDITIONAL LI HE/ALKALINfc FLYASM
SCRUEBIN6 SYSTEMS HAS bEEN AWARDED TO A.D. LITTLE/COHPUSTlON EfcUIPHENT
ASSOCIATES. THESE SYSTEMS ULL BE INSTALLED ON UNITt ? AND * OF THE
COLSTRIP POWER STATION. COLSTdP UNITS 1 AND 2 ARE FOTH E0UIPPEO WITH
OPERATIONAL LlhE/ALrAL1NE FLY»SH SCRUBBING SYSTEMS FOR THE REMOVAL OF
PARTICULATES AND SULFUR DIOXIDE.
•ONTANA POWER
COLSTRIP
t
NEW 700.0 «w (GROSS)
700.0 IN (ESc)
COAL
.70 XS
LIME/ALKALINE FLYASH
AOL/COMBUSTION ESUIP ASSOCIATE
ENERGY CONSUMPTION: ••••X
STATUS 3 STARTUP 7/81
A CONTRACT FOR THE INSTALLATION OF Two ADDITIONAL L I ME/«L
-------
?PA UTILITY FfaD SURVEY: FEbH-'APY - HARCh 1979
SECTION Z
STATUS OF F6D SYSTEMS
UN]T IDENTIFICATION
ABSTRACT
NEVADA POWER
"ARSY ALLEN
t
NEW 500.0 «W (GROSS )
5CO.O «H (ESC)
CO»L
••••• xs
PROCESS NOT StLECTEo
VENDOR NOT SELECTED
fNERSY CONSUMPTION: *..«X
STATUS 6 STARTUP 6/«8
CONSIDERING HOT SIDE ESP IN CONJUNCTION WITH AN F6D SYSTEM. SPECIFICA-
TIONS NAVE NCT YET BEEN PREPARED.
NEVADA POKER
BEID 6ARDSER
1
RETROFIT 125.0 *tt (CROSS)
125.0 •• (ESC)
COAL
• SO XS
'ODIUM CARBONATE
•DL/COMbUSTlON E8UIP ASSOCIATE
FNERGY CONSUMPTION: ««««x
STATUS 1 STARTUP 4/74
REFER TO SECTION 3 Of THIS REPORT FOR ADDITIONAL INFORMATION. THIS SODIUM
CARBONATE-BASED (TRONA) SCRUBBING SYSTEM CONSISTS OF ONE MODULE CONTAIN-
ING A THIN VARIABLE THROAT VENTURI SCRUBBER FOLLOWED BY A SEPARATOR
IN SERIES WITH A SINGLE-STAGE PERFORATED-PLATE BASH TOWER. PRIMARY
PART1CULATE CONTROL IS PROVIDED foV UPSTREAM MECHANICAL COLLECTORS.
AN INDIRECT STEAM HOT AIR REHEAT SYSTEM RAISES THE GAS TEMPERATURE 30F
FRIOfc TO DISCHARGE TO THE MAIN STACK* THE FLUE GAS CLEANING HASTES ARE
ULTIMATELY DISPOSED IN AN ON-S1TE CLAY-LINED SOLAR EVAPORATION POND.
NEVADA POWER
BEID GARDNER
?
RETROFIT 125.0 *w (GROSS)
125.0 «x (ESC>
COAL
.50 XS
SODIUM CARBONATE
•OL/COMBUSTION tsuiP ASSOCIATE
FNER6Y CONSUMPTION: ****X
STATUS 1 STARTUP 4/74
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS SODIUM
CARBONATE-BASED (TRONA) SCRUBBING SYSTEM CONSISTS OF ONE MODULE CONTAIN-
ING A TWIN VARIABLE THROAT VENTURI SCRUBBER FOLLOWED BY A SEPARATOR
IN SERIES WITH A SINGLE-STAGE PERFORATED-PLATE HASH TOWER. PRIMARY
PARTICULATE CONTROL is PROVIDED BY UPSTREAM MECHANICAL COLLECTORS.
AN INDIRECT STEAM HOT AIR *E*EAT SYSTEM RAISES THE GAS TEMPERATURE 30F
PRIOR TO DISCHARGE TO THE MAIN STACK. THE FLUE GAS CLEANING HASTES ARE
ULTIMATELY DISPOSED IN AN ON-SITE CLAY-LINED SOLAR EVAPORATION POND.
(GROSS)
(ESC)
NEVADA POWER
REID GARDNER
*
NEW 125.0 *W
125.0 »W
COAL
.50 XS
SODIUM CARBONATE
•DL/COMBUSTION EJUIP ASSOCIATE
ENERGY CONSUMPTION: •»••!
STATUS 1 STARTUP 6/76
REFER TO SECTION 5 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS UNIT IS A NEW COAL-FIRED BOILER THAT IS EQUIPPED WITH SODIUM
CARBONATE-BASED (TRONA) SCRUBBING SYSTEM WHICH INCORPORATES A TWIN
VARIABLE-THROAT VENTURI SCRUBBER FOLLOWED BY A SEPARATOR IN SERIES WITH
A SINGLE-STAGE PERFORATED-PLATE WASH TOWER. MECHANICAL COLLECTORS PROVIDE
PRIMARY PARTICULATE CONTOL. REHEAT IS PROVIDED BY A INDIRECT STEAM HOT
AIR REHEAT SYSTEM. WASTE IS DISPOSED IN AN ON-SITE CLAY-LINED POND.
NEVADA POWER
PEID GARDNER
t
NEW 250.0 KM (CROSS)
250.0 *w (ESc)
COAL
.75 ZS
PROCESS NOT SkLECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «***X
STATUS 6 STARTUP 0/?3
NEVADA POWER COMPANV HAS SNAPPED THEIR ORIGINAL PLANS TO MAKE UNIT 4 A
COPY OF UNIT J. THE NEW PLANS CALL FOR A 250-MW UNIT TO BE fN OPERATION
FT 19(3. THE UTILITY IS PREPARING SPECIFICATIONS AT THIS TIME.
CONSTRUCTION IS SCHEDULED TO START IN 1980.
NEVADA POWER
kARNER VALLEY
1
NEW 250.C »W (GROSS)
250.0 «h (ESC)
COAL
••••• XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••*•»
STATUS 6 STARTUP 6/B4
SPECIFICATIONS ARE BEING PREPARED FOR A SCRUBBING SYSTEM. NEVADA POWER
HAS NOT YET ANNOUNCED PLANS FOR THIS UNIT'S EMISSION CONTROL STRATEGY.
20
-------
EPA UTILITY FGD SURVEY: FEBRUARY - *APCH 1979
SECTION Z
STATUS OF FCO SYSTEMS
UNIT IDENTIFICATION
AtSTRACT
NEVADA POWER
WARNER VALLEY
?
NEW 250.0 *b (CROSS)
250.0 MW (ESC)
COAL
•**•• IS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENER6Y CONSUMPTION: ••••*
STATUS 6 STARTUP 6/f5
SPECIFICATIONS »Rfc PE]N£ PREPARED FOR A SCRUBBING SYSTEM. NEVADA POUER
HAS SOT VET ANNOUNCED PLANS FOR THIS UNIT'S EMISSION CONTROL STRATEGY.
NEW ENGLAND ELECTRIC SYSTEf
9RAYTON POINT
RETROFIT
6SC.O «w (GROSS)
450.0 tw
1.UO XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: •«••!
STATUS 7 STARTUP O/ 0
KEW ENGLAND ELECTRIC SYSTEM H»S REOUsSTED PERMISSION TO BURN 1.5X SULFUR
COAL AT THIS UNIT. THIS IS ALLOWABLE UNDER STATE STANDARDS BUT S02
EMISSIONS WOULD BE ABOVE ALLOWABLE FEDERAL LEVELS. A DECISION BY THE EPA
IS STILL PENDING. MEANWHILE, THE UTILITY IS INVESTIGATING VARIOUS ADVANCE
FEGENEKABLE f6D SYSTEMS ^HICH OFFER A BREAKTHROUGH IN OPERATING COSTS
AND PRODUCE ELEMENTAL SULFUR AS AN END PRODUCT. THE UTILITY IS CURRENTLY
INVOLVED IN 6ENCH AND LABORATORY SCALE INVESTIGATIONS OF SULFUR RECOVERY.
THIS UNIT IS CURRENTLY OPERATIONAL FIRING LOW SULFUR FUEL OIL.
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY
66
RETROFIT 100.0 «b (GROSS)
1CO.O »* (ESc>
COAL
1.80 XS
AQUEOUS CARBONATE
ROCKWELL INTERNATIONAL
ENERGY CONSUMPTION: ••••X
STATUS 3 STARTUP 0/b2
A CONTRACT WAS AWARDED TO ATOMICS INTERNATIONAL FOR THE DESIGN AND
INSTALLATION OF AN AQUeOUS CARBONATE F6D SYSTEM.. THIS DEMONSTRATION
SYSTEM WILL PRODUCE END-PRODUCT SULFUR. FUNDS ARE BEING PROVIDED BY THE
U.S. EPA AND THE EMPIRE STATE ELECTRIC ENERGY RESEARCH CORP. THE DESIGN
soz REMOVAL EFFICIENCY WILL BE 90 PERCENT. ROCKWELL INTERNATIONAL is
PRESENTLY IN THE DESIGN PHASE.
NORTHERN INDIANA PUB SERVICE
3AILLV
7
RETROFIT 190.0 *w (GROSS)
190.0 *w <£Sc>
COAL
3.00 tS
PROCESS NOT SbLECTED
VENDOR N9T.SELECTED
ENERGY CONSUMPTION: ****x
STATUS 6 STARTUP 01 0
NORTHERN INDIANA PUBLIC SERVICE IS CURRENTLY CONSIDERING A LIME OR LIME-
STONE SCRUBBING UNIT FOR BAILLY 7 AND 8. THEY ARE ALSO WAITING FOR
PERFORMANCE RESULTS OF THE WELLMAN LORD/ALLIED CHEMICAL UNIT IN SERVICE
AT DEAN H. MITCHELL 11. LOW SULFUR COAL NAY BE EMPLOYED TO COMPLY WITH
SOZ EMISSION RE6UALTIONS. APPLICABLE INDIANA S02 REGULATIONS ARE STILL
NOT FIRMLY ESTABLISHED*
NORTHERN INDIANA PUB SERVICE
9AILLY
f
RETROFIT 400.0 «w (GROSS)
400.0 <*W (ESC)
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••I
STATUS 6 STARTUP O/ 0
NORTHERN INDIANA PUBLIC SERVICE IS CURRENTLY CONSIDERING A LIME OR LINE-
STONE SCRUBBING UNIT FOR BAILLY 7 AND 8. THEY ARE ALSO WAITjNG FOR
PERFORMANCE RESULTS OF THE WELLMAN LORD/ALLIED CHEMICAL UNIT IN SERVICE
AT DEAN H. MITCHELL 11. LOW SULFUR COAL MAY BE EMPLOYED TO COMPLY WITH
SOZ EMISSION REGULATIONS. APPLICABLE INDIANA S02 REGULATIONS ARE STILL
NOT FIRMLY ESTABLISHED.
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
RETROFIT ns.o ** (GROSS)
115.0 "W (ESc>
COAL
3.50 ZS
WELLMAN LORD
DAVY POWERGAS
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 7/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION
THIS F6D SYSTEM IS AN INTEGRATION OF THE WELLMAN-LORD SOZ RECOVERY
PROCESS OFFERED BY DAVY POWERGAS AND THE SOZ TO SULFUR REDUCTION PROCESS
DEVELOPED 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.
21
-------
EPA UTILITY FbO SURVEY: FEE*UA*Y -
1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT 1DENT1FICATION
AbSTRACT
NORTHERN INDIANA PUB SERVICE:
SCHAHFER
17
HEW 421.0 % (GROSS)
4Z1.0 *k tESC>
COAL
3.20 ZS BITUMINOUS
PROCESS MOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: • ••«!
STATUS 5 STARTUP 6/?3
MPSCO IS RrQUESTiN6/EVA|.UATlN6 BID$ FOR FGD SYSTEMS ON SCHAHFER 17
AND 16. ALTHOUGH THE S02 CONTROL STRATEGY HAS NOT BEEN SELECTED THE
UTILITY IS CONSIDERING A SOCIUH bASED SYSTEM. PART1CULATE HATTER
kILL BE CONTROLLED BY AN ESP. THE SYSTEM DESIGN WILL INCLUDE A
REHEAT SYSTEM.
NORTHERN INDIANA PUB SERVICE
SCHAHFER
18
NEW 421.0 *w (GROSS)
421.0 NW (ESC)
COAL
3.20 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERSY CONSUMPTION: • •••»
STATUS 5 STARTUP 6/65
MPSCO IS REQUESTING/EVALUATING blD$ FOR FGD SYSTEMS ON SCHAHFER 17
AND If. ALTHOUGH THE S02 CONTROL STRATEGY HAS NOT PEEN SELECTED THE
UTILITY IS CONSIDERING A SODIUM bASED SYSTEM. PARTICULATE MATTER
kILL BE CONTROLLED BY AN ESP. THE SYSTEM DESIGN WILL INCLUDE A
REHEAT SYSTEM.
NORTHERN STATtS »OWER
SHERBURNE
1
NEW 7*0.0 W (GROSS)
860.0 Mw (ESC)
COAL
.00 ZS
LIMESTONE
COMBUSTION EN6INEERING
ENERGY CONSUMPTION: «•••!
STATUS 4 STARTUP 5/P4
TWO ADDITIONAL COAL-FIRED POWER-GENERATING UNITS ARE SCHEDULED TO BE IN-
STALLED AT NSP'S SHERPURNE COUNTY GENERATING STATION IN BECKER MINNESOTA.
A LETTER OF INTENT HAS BEEN SIGNED WITH C-E FOR A LIMESTONE SLURRY SPRAT
TOWER SYSTEM FOR THIS NEW 86Q-MW UNIT. THE 2-STA6E SCRUBBING SYSTEM WILL
REMOVE PARTKULATES « so2 (8oz>. THE BOILER CONTRACT HAS BEEN
AWARDED TO BA8COCK * W1LCOX AN0 TH£ TURBINE WILL BE SUPPLIED By GENERAL
ELECTRIC. START-UP HAS BEEN DELAYED TO MAY 1984 AND CONSTRUCTION START-UP
HAS BEEN DELATED UNTIL APRIL 1980 DUE TO ENVIRONMENTAL PROBLEMS.
OTTER TAIL PO«ER
COYOTE
1
NEW 44C.O MW (GROSS)
440.0 "W (ESC)
COAL
.87 ZS LIGNITE
AQUEOUS CARBONATE/SPRAY DRYING
WHEELABRATOR-FRYE/R.I.
ENERGY CONSUMPTION: ****Z
STATUS 2 STARTUP 5/81
THIS NEW COAL-FIRED STATION IS JOINTLY OWNED BY FIVE UTILITIES. OTTER
TAIL POWER IS THE MAJOR OWNER AND CONSTRUCTOR. MONTANA-DAKOTA UTILISES
IS THE FACILITY OPERATOR. THIS PLANNED UNIT WILL FIRE LOU SULFUR LIGNITE
FROM THE MERCER COUNTY AREA IN A BCW CYCLONE BOILER. THE CONTRACT FOR
THIS AOUEOUS CARBONATE/FABR1C FILTER $02 SCRUBBER-ABSORBER WAS AWARDED TO
WHEELABRATOR-FRYE AND ATOMICS INTERNATIONAL. THE DRY REMOVAL SYSTEM
COMBINES AI-S AOUEOUS CARBONATE PROCESS IN A W-F FABRIC FILTER. UNIT
CONSTRUCTION IS NOW 301 COMPLETE AND F6D SYSTEM CONSTRUCTION HAS JUST
BEGUN.
22
-------
EPA UTU1TT FGE SURVEY: FEBRUARY - PARCH 1979
SECTION i
STATUS OF FED SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PACIFIC EAS t, ELECTRIC
FOSSIL
1
NEW 800.0 *W (CROSS)
BOO.O MM (ESc)
COAL
.80 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «*««X
STATUS 6 STARTUP 0/85
PGtE ANNOUNCED PLANS TO BUUO Two 800-HW COAL-FIRED PO*ER GENERATING
UNITS IN NORTHERN CALIFORNIA. THE FIRST UNIT WILL BURN COAL hITx A
HEATING VALUE OF 12000 BTU/Lb. 0.8X SULFUR AND 101 ASH CONTENTS. THE
SECOND UNIT WILL BURN COAL OF AN EQUAL OR BETTER QUALITY. THE EMISSION
CONTROL SYSTEM WILL CONSIST OF A BAGHOUSE AND A LIMESTONE F6D STSTE".
SLUDGE WILL BE DISPOSED OF IN A LANDFILL* START-UP DATES ARE 1«?S AND
1986 FOR NOS. 1 AND 2 RESPECTIVELY. CONSTRUCTION IS NOT ENVISIONED TO
BEGIN BEFORE T«0 OR THREE YEARS.
PACIFIC 6AS & ELECTRIC
FOSSIL
I
NEW 800.0 M (GROSS)
800.0 MW (ESC)
COAL
.80 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «**«X
STATUS 6 STARTUP 0/e«
P6&E ANNOUNCED PLANS TO BUILD TWO 800-MW COAL-FIRED PO»ER GENERATING
UNITS IN NORTHERN CALIFORNIA. THE FIRST UNIT WILL BURN COAL »ITH A
HEATING VALUE OF 12000 BTU/Lb, 0.8X SULFUR AND 1Qt ASH CONTENTS. THE
SECOND UNIT WILL BURN COAL OF AN EQUAL OR BETTER QUALITY. THE EMISSION
CONTROL SYSTEM WILL CONSIST OF A BAGHOUSE AND A LIMESTONE FGD SYSTEM.
SLUDGE WILL BE DISPOSED OF IN A LANDFILL. START-UP DATES ARE 19P5 AND
1986 FOR NOS. 1 AND 2 RESPECTIVELY. CONSTRUCTION IS NOT ENVISIONED TO
EEGIK BEFORE TWO OR THREE YEARS.
PACIFIC POWER ( LIGHT
JIM 9R1D6ER
4
NEW 550.0
COAL
3.00 XS BITUMINOUS
LIKE
CHEMICO
ENERGY CONSUMPTION: 6.ox
STATUS 1 STARTUP 12/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS EMISSION CONTROL SYSTEM WAS DESIGNED TO REMOVE FLYASH AND S02 FROM
3.35 MM ACFM OF FLUE6AS 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 W*S 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 MODIFICATIONS.
PENNSYLVANIA POWER
9RUCE MANSFIELD
2
NEW 917.0 MW (GROSS)
917.0 MW (ESC)
COAL
3.00 XS BITUMINOUS
LINE
CHEMICO
ENERGY CONSUMPTION: 6.ox
STATUS 1 STARTUP 7/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS EMISSION CONTROL SYSTEM WAS DESIGNED TO REMOVE FLYASH AND S02 FROr
3.35 MM ACFM OF FLUE GAS USING THIOSORBIC LIME AS A SCRUBBING APSORBENT.
SIX SCRUBBING TRAINS. EACH INCLUDING ThO VENTURI SCRUBBERS IN SERIES
ARRANGEMENT, ARE PROVIDED FOR FULL-LOAD OPERATION. THE INITIAL JHAKEOObN
AND DEBUGGING PHASE OF OPERATION BEGAN Kfl THREE TRAINS IN JULY. 1977.
FULL COMMERCIAL OPERATION FOR THE ENTIRE SYSTEM COMMENCED ON OCTOBER 1.
1977.
PENNSYLVANIA POWER
BRUCE MANSFIELD
3
NEW 917.0 *W (GROSS)
917.0 MW (ESC)
COAL
3.00 XS
LIME
PULLMAN KELLOGG
ENERGY CONSUMPTION: • •••x
STATUS 2 STARTUP 4/80
A CONTRACT WAS AWARDED TO PULLMAN KELLOGG FOR THE FGD SYSTEM AT THIS
UNIT. THE EMISSION CONTROL SYSTEM FOR THIS UNIT kILL CONSIST OF ESP'S
UP-STREAM OF FIVE WEIR HORIZONTAL CRQSSFLOW WET SCRUBBING MODULES.
EACH MODULE CONSISTS OF SIX STAGES. ONE BEING A SPARE. SLUDGE WILL BE
DISPOSED OF BY THE EXISTING SYSTEM AT THE BRUCE MANSFIELD PLANT. LINER
IN THE STACK WILL BE AN INCONEL 625 MATERIAL. THE UNIT IS CURRENTLY
UNDER CONSTRUCTION WITH ESP'S 70-80 PERCENT COMPLETE AND THE FGD
SYSTEM 30 PERCENT COMPLETE. UNIT START-UP WILL BE IN APRIL 1980.
23
-------
FP» UTILITY FuD EUFVEYz FEFRUA*Y - MARCH 1979
SECTION 2
STATUS OF FED SYSTEMS
UNIT
FICATION
ABSTRACT
°HIL». DELPHI A ELECTRIC
CftOUST
DETRQFIT 150.0 «„ (GROSS)
15C.O «W «£Sc)
COAL
3.00 XS
•A6NESIU1 OHOE
UNITED E*6INEfcRS
FNERSY CONSIPPT10N: ««««X
STATUS 6 STARTUP 6/'G
THE UTILITY PLANS TO RETROFIT ONE OF THE TyO BOILERS AT CROMBV WITH AN
FGO SYSTEM. HOWEVER. A FINAL DECISION H«S NOT BEEN MADE. THE SYSTEM
BEING GIVEN PRIMARY CONSIDERATION IS MAGNESIUM OXIDE. CURRENTLY, THE
UTILITY IS RE-NEGOTIATING CONSENT ORDERS AND THE START-UP DATE OF JUNE
1980 IS TENTATIVE*
OHILADELPHIA ELECTRIC
rDDYSTONE
1 A
"ETRpFlT 120.0 lu
120.0 '» (ESC>
COAL
2.60 XS
•AGNESIU* OXIDE
UNITED ENGINEERS
?NFRGV CONSUMPTION: • •••X
STATUS 1 STARTUP 9/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF THREE PARALLEL
SCRUfcEING TRAINS FOR THE CONTROL OF PART1CULATE AND SULFUR DIOXIDE.
THE C-SIDE SCRUBBING TRAIN INCLUDES AN SO? ABSORBER MODULE IN SERIES
^iTH A PARTICULATE SCRUBBER. APPROXIMATELY ONE-THIRD OF THE BOILER FLUE
GAS IS SCRUBBED WITH MAGNESIUM OXIDE SLURRY FOR SO2 REMOVAL* THE SPENT
SLURRY IS REGENERATED AT THE ESStX SULFURIC ACID PLANT IN NEWARK, N.J.
THE REGENERATED MA60X IS RETURNED TO THE PLANT FOR S02 SCRUBBING SERVICE,
PHILADELPHIA ELECTFIC
?DDVSTONE
IB
OETROFIT
(GROSS)
(ESC)
243.0
2*0.0
COAL
2.6D XS
IAGNES.IU* O*IDE
UNITED ENGINEERS
ENERSY CONSUMPTION: • •••X
STATUS 4 STARTUP 6/fO
THE INSTALLATION OF AN F6D SYSTEM ON THE BALANCE OF THE FLUE GAS FROM
THIS UNIT MILL FOLLOW PENDING THE OUTCOME OF THE PERFORMANCE OF THE
EXPERIMENTAL 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 0"BER$ ARE PRESENTLY BEING
RE-NEGOTIATED AND THE START-UP DATE OF JUNE. 1980 is TENTATIVE*
PHILADELPHIA ELECTRIC
EDDYS TONE
2
"ETRoFlT 334.0 IK (GROSS)
734.0 "W- (ESC>
COAL
2.53 XS
-•AGNESIU1 OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: ••*•*
STATUS 6 STARTUP 6/60
THE UTILITY IS AWAITING PERFORMANCE RESULTS FROM THE EXPERIMENTAL F60
SYSTEM INSTALLED ON UNIT 1 AT THIS STATION BEFORE PRECEEDING WITH THE
DESIGN OF AN FGD SYSTEM FOR THIS COAL-FIRED BOILER. THE SYSTEM BEING
GIVEN PRIMARY CONSIDERATION IS MAGNESIUM OXIDE, DESIGNED JOINTLY BY
UNITED ENGINEERS AND PHILADELPHIA ELECTRIC. CURRENTLY, THE UTILITY is
RE-NEtOTlATING CONSENT ORDERS AND THE START UP DATE OF JUNE 1980 IS
TENTATIVE.
POT01AC ELECTRIC PO.ER
DICKERSOU
4
HEW 800.0 «W (GROSS)
800.0 «w (ESC)
COAL
2.00 XS
"ROCESS HOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «*«»x
STATUS 6 STARTUP 0/87
THERE ARE NO FIRM PLANS FOR INSTALLATION Of AN FGD SYSTEM. STARTUP DATE
OF THE BOILER IS PLANNED FOR 1985. THIS UNIT WILL BUR" Z> SULFUR COAL
WITH A HEATING VALUE OF 11QOO BTU/LB.
»OWE« AUTHORITY OF NEW YORK
ARTHUR KILL
NEW 700.0 *W (GROSS)
700.0 "W (ESC)
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••X
STATUS 6 STARTUP 11/88
THE UTILITY XS CONSIDERING BOTH RE6ENERABLE 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. TH£ PREFERRED PlANT SITE IS THE
ARTHUR KILL FACILITY LOCATED ON STATEN ISLAND. THE PROJECT DESIGN
ENGINEERING FIRM IS SARGENT AND LUNDY. PUBLIC SERVICE COMMISSION HEARINGS
ARE IN PROGRESS.
24
-------
-fM UTIL1TT FCO SURVEY: FEBRUARY - "APCH 1979
SECTION i
STATUS OF f60 SYSTE»S
UNIT IDENTIFICATION
ABSTRACT
°UPLIC SERVICE OF INDIANA
GIBSON
N£W 650.0 ow (GROSS >
650.0 OH (ESc )
COAL
3.30 ZS
OROCESS NOT SELECTED
VENDOR NOT SELECTED
FNERSY CONSUMPT13N: <*«*X
STATUS 5 STARTUP 0/t2
PUBLIC SERVICE CO Of INDIAN* ANNOUNCED PLANS FOR THE CONSTRUCTION Of THIS
NEW 6!0-I"W COAL FIRED POWER GENEkATING UNIT AT GlgSON STATION* P1DS HAVE
BEEN RECIEVED AND APE BEING EVALUATED. INITIAL START-UP IS SCHEDULED FOR
1962.
PUBLIC SERVICE OF Nt* MEXICO
SAN JUAN
1
RETROFIT 361.0 "W (GROSS)
361.0 Oh (ESC)
COAL
.80 *S
KELLMAN LORD
DAVY POWERGAS
ENERST CONSUMPTION; k.nX
STATUS 1 STARTUP 4/78
fEFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS FGD
SYSTEF IS AN INTEGRATION OF THE WELLMAN LORD S02 RECOVERY PROCESS OF
CAVY 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 CAR» THE FULL LOAD. THE
COAL EURNED AT THIS UNIT HAS SULFUR AND ASH CONTENTS OF -8X AND 201
PESPtCTIVFLY. THE SYSTEP OPERATES ON A CLOSED WATER LOOP WITH
RIVER «ATER bEING USED AS M»KE-UP FOR LOSSES DUE TO EVAPORATION.
BUBLIC SERVICE OF NEW MEXICO
SAN JUAN
•>
RETROFIT 350.0 *W (GROSS)
35C.O Ok (ESC)
COAL
.80 ZS
*ELL«»N LORD
DAW POWER 6 AS
FNERSY CONSUMPTION: * . 6J
STATUS 1 STARTUP 8/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS FGD
SYSTEM IS AN INTEGRATION OF THE wELLMAN LORD S02 RECOVERY PROCESS OF 0AVY
POWER6AS/ALLIEC CHEMICAL'S S02 REDUCTION TO SULFUR PROCESS. A HOT SIDE
ELECTROSTATIC PRECIPITATOR PRECEEDS THE FGD SYSTE". THE SYSTEM INCLUDES
FOUR ABSORBS* TOWERS, THREE OF WHICH ARE NECESSARY TO CARRY THE FULL
LOAD. THE WATER LOOP IS CLOSED WITH RIVER WATER BEING USED TO MAKE UP FOR
LOSSES DUE TO EVAPORATION. THE COAL BURNED AT THIS UNIT HAS SULFUR AND
ASH CONTENTS OF 0.81 AND 20* RESPECTIVELY.
PUPLIC SERVICE OF NEW MEIICO
SAN JUAN
NEW
534.0 oW (GROSS)
534.0 OW (ESC)
COAL
.60 XS
WELLNAN LORD
DAVY POWERGAS
ENERGY CONSUMPTION: ..««:
STATUS 2 STARTUP 6/79
A CONTRACT HAS BEEN AWARDED TO DAVY POWERGAS TO SUPPLY FOUR ABSORBER
TOWER: FOR REMOVAL OF S02 AT THIS NEW UNIT. ONE MODULE is EXPECTED TO
DE OPERATIONAL BY JUNE 1979 WHICH WILL BRING THE UNIT INTO COMPLIANCE
WITH FEDERAL NSPS. THE REMAINING THREE MODULES SHOULD BE OPERATIONAL
EY JANUARY 1982 AT WHICH TIME THE UNIT HILL BE IN COMPLIANCE OF STATE
STANDARDS. POWER PLANT CONSTRUCTION IS BEHIND SCHEDULE BUT ABSORBER
CONSTRUCTION IS PROCEEDING AS PLANNED. IT IS POSSIBLE THAT THE FINAL
THREE ABSORBERS MAY BE IN AS EARLY AS JANUARY 1981.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
4
NEW 534. 0 Mw (GROSS)
534.0 "W (ESC)
COAL
.BO XS
WELLOAN LORD
DAVY POWERGAS
ENERGY CONSUMPTION
DAVY POWERGAS HAS BEEN AWARDED A CONTRACT TO SUPPLY THE S02 REMOVAL
SYSTEM FOR THIS UNIT. THE PLANS INCLUDE A WELLMAN LORD S02 RECOVERY
PROCESS AS WELL AS AN UPSTREAM ELECTROSTATIC PRECIPITATOR FOR PRIMARY
PARTICULATE REMOVAL. FGD OPERATIONS ARE EXPECTED TO BEGIN AT THIS PLANT
IN JANUARY 1982.
STATUS 3
««««X
STARTUP 1 1t 2
SALT RIVER PROJECT
CORONADO
1
NEW 350.0 ow (GROSS)
260.0 MW (ESC)
COAL
1.00 XS SUEolTUMINOUS
LIMESTONE
PULLMAN KELLOGG
ENERSY CONSUMPTION: ***»Z
STATUS 2 STARTUP 8/79
THIS NEW UNIT WILL PURN LOW SULFUR WESTERN COAL* A MAXIMUM OF 20» OF THE
FLUE GAS WILL BE SCRUBBED TO MEET SULFUR DIOXIDE EMISSION REGULATIONS.
PULLHAN/KELLOGG WILL PROVIDE 2 WEIR HORIZONTAL SPRAY TOWERS UTILIZING
LIMESTONE SLURRY FOR S02 CONTROL. THE SYSTEM WILL UTILIZE RUBBER-LINED
SLURRY RECYCLE PUMPS, EACH RATED AT 9SQO SPM. RI6IFLAKE-LINED SCRUBBER
MODULES. VERTICAL HEIL MIST ELIMINATORS AND A MINIMUM OF 20 PERCENT OF
THE FLUE GAS WILL BE PYPASSED FOR REHEAT. THE SLUDGE WILL BE PONDED.
STRUCTURAL WORK IS <>OX COMPLETE.
25
-------
Epk UTILITY FGD SURVEY: FE6RUART - M»RCn 1979
SECTION :
STATUS Of FGD SYSTEMS
UNIT IDENTI FICATION
ABSTRACT
SALT RIVER PROJECT
CORON ADO
?
*EW 350.o •« (GROSS)
260.0 Nw (£SC>
COAL
1.00 ZS SUEoITUKINOUS
LIMESTONE
PULLMAN KELL066
ENERGY CONSUMPTION: • •••!
STATUS 2 STARTUP I/PC
THIS NEW UNIT KILL PURN LOW SULFUR WESTERN COAL. A MAXIMUM OF bOX OF THE
FLUE 60S WILL EE SCRUBBED TO MEET SULFUR DIOXIDE EMjSSlON REGULATIONS'
PULLMAN/KELL066 WILL PROVIDE 2 WEIR HORIZONTAL SPRAY TOWERS UTILIZING
LIMESTONE SLURRY FOR $02 CONTROL. THE SYSTEM WILL UTILIZE RUBBER-LINED
SLURRY RECYCLE PUMPS, EACH RATED AT 9800 6PM, RI61 FLAKE-LINED SCRUBBER
MODULES, VERTICAL HEIL MIST ELIMINATORS AND A MINIMUM OF 20 PERCENT OF
THE FLUE 6AS WILL BE BYPASSED FOR REHEAT. THE SLUDGE WILL BE PONDED.
STRUCTURAL WORK IS 60* COMPLETE.
SALT RIVER PROJECT
CORONADO
t
HEW 750.0 1W (GROSS)
280.0 •* (ESC)
COAL
1.00 SS
LIMESTONE
VENDOR NOT SELECTED
ENEREY CONSUMPTION: •«*•!
STATUS 6 STARTUP 0/E7
THIS NEW UNIT HILL BURN SULDUR WESTERN COAL. EIGHTY PERCENT OF THE
GAS fcILL BE SCRUBBED TO MEET SULFUR DIOXIDE EMISSION REGULATIONS.
UTILITY IS CURRENTLY CONSIDERING THE INSTALLATION OF TWO HORIZONTAL
SPRAT TOwERS EMPLOYING A LIMESTONE SCRU6BIN6 SOLUTION TO REMOVE S02 .
FROM THE FLUE GAS. SCHEDULED COMMERCIAL OPERATION DATE is l«er. PLANS
FOR AN EMISSION CONTROL SYSTE" HAVE NOT BEEN FINALIZED. SLUD6E WILL
FROBA9LY BE PONDED.
SAN NI6UEL ELECTRIC COOP
SAN NIGUEL
1
NEW 400.0 m> (CROSS)
400.0 NW (ESC>
COAL
1.70 ZS LIGNITE
LIMESTONE
•tABCOCK t WiLCOX
ENERGY CONSUMPTION: •«••!
STATUS 2 STARTUP 8/EO
THE tdSSION CONTROL EQUIPMENT FOR THE COAL-FIRED RADIANT B01LEP WILL
CONSIST OF AN ESP UPSTREAM OF FOUR LIMESTONE SCRU8BIN6 MODULES. THE
SCRUBBER FLUE 6AS CAPACITY IS NOMINALLY DESI6NED AT 1.579 MILLION ACFM
(302 F). DESIGN S02 REMOVAL EFFICIENCY IS 86 PERCENT FOR 4*00 PPM S02
lNLET. L'6 RATIOS ARE iQ AND 45 FOR QUENCHER AND ABSORBER. RESPECTIVELY.
RESEARCH COTTRELL HAS BEE" AWARDED THE SLUDGE DISPOSAL CONTRACT. F6D
SVSTL* FOUNDATION AND STRUCTURAL STEEL WORK IS COMPLETE. INITIAL START-
UP IS SCHEDULED FOR LATE SUMMER 1?EO.
SEMINOLE ELECTRIC
SEMINOLE
1
NEW 62Q-0 «.W (GROSS)
620.0 1W (ESC)
COAL
2.75 ZS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••t
STATUS 6 STARTUP 6/83
SEMINOLE ELECTRIC HAS ANNOUNCED PLANS TO CONSTRUCT ONE AND POSSIBLY TWO
NEW tOO MW COAL-FIRED UNITS. THE UTILITY INTENDS TO UTILIZE ESPS FOR PAR-
TICULATE REMOVAL AND * LIMESTONE FGD SYSTEM FOR $02 CONTROL OF EMISSIONS
FROM THE BURNING OF 2.75Z SULFUR, 8.5X ASH COAL (11000 8TU/LB HEATING
VALUE). THE UTILITY EXPECTS TO INITIATE REQUESTS FOR BIDS FOR THE F6D
SYSTEM IN MAY 1979.
SIRESTON BOARD OF MUN1C. UT1L.
SIKESTON
1
HEW 235.0 "W (EROSS)
235.0 MW (ESC)
COAL
2.60 SS
LIMESTONE
9ABCOCK I WILCOI
ENERGY CONSUMPTION: ••••X
STATUS 2 STARTUP 11/fO
BKW WAS AWARDED A CONTRACT FOR THE BfllLEfi AIR QUALITY CONTROL SYSTEM.
THE AQCS WILL CONSIST OF 2 ESP'S FOLLOWED BY 3 F6t> MODULES, EACH CAPABLE
OF HANDLING 50Z OF THE BOILER LOAD; ONE WILL BE ON STAND-BY AT ALL TIMES.
THE UNIT WILL BURN A 2.81 SULFUR COAL. THE SIKESTON STATION WILL FEATURE
AN FfcF-LlNED STACK, 2 PONDS (ONE FOR FLY ASH, ONE FOR SCRUBBER SLUD6E-
tOTTCM ASH DISPOSAL), AND * AXiAL FLOW FANS. NO STACK 6AS REHEAT IS
PLANNED. MAXIMUM FLUE 6AS CAPACITY IS 748,390 ACFM AT 286 F. BOILER
STRUCTURAL STEEL ERECTION IS NOW ABOUT J3I COMPLETE
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
?
NEW 280.0 «W (GROSS)
140.0 MW (ESC)
COAL
1.00 ZS BITUMINOUS
LIMESTONE
PABCOCK I WILCOX
ENER6Y CONSUMPTION: .71
STATUS 1 STARTUP 7/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A 100Z CAPACITY E$P
FOLLOWED BY A 50Z CAPACITY LIMESTONE F6D SYSTEM. ONE F6D MODULE, CONSIST-
ING OF A VENTURI SCRUBBER AND TRAY TOWER ABSORBER. REMOVES 701 OF THE
INLET $02. REHEAT IS SUPPLIED BY FLUE GAS BYPASS. THE SCRUBBING WASTES
ARE DISCHAR6ED TO AN ON-SITE. UNLINED DIKED POND. THE NO. 2 UNIT
COMMENCED INITIAL OPERATION IN JULY 1977.
26
-------
EPA UTILITY FGD SURVEY: FEBRUARY - PARCH 1979
SECTION ^
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTH CAROLINA PUBLIC SERVICE
WlNYAH
3
NEW 280.0 *M (GROSS)
280.0 4U (ESC)
COAL
1.70 IS
LIMESTONE
9ABCOCK I UILCOX
ENERGY CONSUMPTION: «•*•»
STATUS 2 STARTUP 5/60
A CONTRACT HAS BEEN AWARDED TO BABCoCr I W1LCO« FOR THE INSTALLATION
OF THE FGD SYSTEM ON THIS UNIT. PARTICULATE REMOVAL WILL 9E PROVIDED
tY RESEARCH COTTRELL ESP'S. THE 60ILER IS A COAL-FIPED DRT-FOTTOM UNIT
WHICH (ILL fcURN COAL WITH A 1.71 SULFUR CONTENT AND A HEAT VALUE OF
11,500 BTU/LB. THE GENERATING EQUIPMENT IS BEING SUPPLIED BY 01LEY
STOKER. 1002 OF THE FLUE t«s WILL BE SCRUBBED. ALL F&D FOOTINGS
HAVE BEEN POURED AND TANK FABRICATION IS COMPLETE. DOCTOR* IS IN
PROGRESS .
SOUTH CAROLINA PUBLIC SERVICE
WlNVAH
«
NEW 26Q.0
-------
EPA UTILITY F6D SU'VEY: FEfkUART - MARCH 1979
SECTION 2
STATUS Of f6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTHERN MISSISSIPPI ELECTRIC
°.D. MORROW
1
«IEW 200.0 in (GROSS)
12*.0 "W (E$c>
COAL
1.30 XS
LIMESTONE
BILfcT STOrER/ENVlRONEERING
ENERGY CONSUMPTION: 5.5*
STATUS 1 STARTUP 8/78
REFER TO SECTION J OF THIS REpORT FOR ADDITIONAL INFORMATION.
PART1CULATES WILL BE CONTROLLED BY A H16H-EFF1Clt"CY ESP UPSTREAM
OF THE FGO SYSTEM. DESIGN S02 AND PARTICULATE REMOVAL EFFICIENCIES ARE
i5 AND 99.6*. RESPECTIVELY. A MATER SPRAY MAS BEEN ADDED IN THE
FY-PASS DUCT TO PROTECT THE LINER FROM TEMPERATURE EXCURSION. SLUDGE HILL
fcE STABILIZED fclTH FLY»SH A». MORROW
?
NEW 20C.O «• (GROSS)
124.0 "W (ESC)
COAL
1.20 tS
LIMESTONE
R1LEY STOKER/ENV1RONE£R 1Kb
FNER6Y CONSUMPTION: S.5Z
STATUS 2 STARTUP 7/79
A CONTRACT WAS AWARDED BY S»E TO RIL£Y STOKER/ENV1RONEERIN6 FOR THIS
F6D SYSTEM. PARTKULATES WILL BE CONTROLLED BY A HIGH-EFFICIENCY ESP
UPSTREAM OF THE F6D SYSTEM. DESIGN SULFUR DIOXIDE AND PARTICULATE
EFFICIENCIES ARE 85 AND 99.6 PERCENT. RESPECTIVELY. A HATER SPRAY HAS
fcEEN ADDED IN THE BY-PASS DUCT TO PROTECT THE LINER FROM TEMPERATURE
EXCURSION. SLUDGE WILL BE STABILIZED WITH FLVftSH AND DISPOSED ON THE
PLANT SITE. CONSTRUCTION OF THE MET LIMESTONE SCRUBBING SYSTEM IS NOH
IN ITS FINAL STAGES. THE BOILER is NOW IN OPERATION.
SOUTHWESTERN tLECTRIC POKER
HENRY H. PERKtY
1
SEW 720.0 *W (GROSS)
720.0 "« (ESC)
COAL
.80 tS LIGNITE
LIMESTONE
MR CORRECTION DIVISION* UO F
ENERGY CONSUMPTION: ••>••!
STATUS 3 STARTUP 2/E4
A CONTRACT FOR THE EMISSION CONTROL SYSTEM HAS BEEN AWARDED TO THE AIR
CORRECTION DIVISION OF UOP. THE SYSTEM DESIGN INCLUDES THO COLD-SIDE
ESP'S FOR PARTICULATE REMOVAL UP-STREAM FROM 4 SPRAY TOHERS WHICH
UTILIZE LIMESTONE SLURRY FOR $02 CONTROL. SLUDGE DISPOSAL HILL BE HANDLED
BY AN IUCS SVSTEM. START-UP IS EXpECjED BY FEBRUARY 196*.
SPRIDGFIELD CITY UTILITIES
SOUTHWEST
1
WEH 194.0 «W (GROSS)
194.0 »W CESC)
COAL
3.SO XS BITUMINOUS
LIMESTONE
»1« CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: *.6i
STATUS 1 STARTJP */77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED UNIT CONSISTS OF A
FOUR-FIELD HIGH EFFICIENCY ESP (99.62 DESIGN) AND 2 TURBULENT CONTACT
ABSORBER MODULES (801 DESIGN) FOR THE CONTROL OF PARTICULATES AND S02.
BOTH THE ESP AND LIMESTONE F6D SYSTEM ARE SUPPLIED BY UOP. THE SCRUBBING
WASTES ARE DEWATERED BY A ROTARY DRUM VACUUM FILTER AND THE FILTER CAKE
IS HAULED AWAY TO A LANDFILL. INITIAL OPERATION OF THE FGD SYSTEM
OCCURRED IN APRIL 77. IN SEPT. 77, THE UNIT SUCCESSFULLY COMPLETED
COMPLIANCE JESTING.
SPRINGFIELD WATER* LIGHT &
DALLMAN
v
N£W 205.0 *w (GROSS)
205.0 KW (ESc)
COAL
3.30 XS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: »•••!
STATUS 2 STARTUP 7/60
PWR A CONTRACT WAS AWARDED TO RESEARCH CflTTRELL FOR THE INSTALLATION OF A
LIMESTONE FGD SYSTEM. REQUIRED SULFUR DIOXIDE REMOVAL EFFICIENCY IS 90
PERCENT. A SLUDGE DISPOSAL STRATEGY HAS NOT BEEN FINALIZED. BUT THE
UTILITY IS CONSIDERING EITHER PONDING OR LANDFILL. CONSTRUCTION OF THE
FGD SYSTEM FOUNDATIONS HAVE BEGUN. ALL SYSTEMS ARE ON SCHEDULE. THE
BOllfcF OPERATION WAS SeHEDUtED TO COMMENCE IN J||NE 1978.
ST. JOE ZINC
E.F. WEATON
1
RETROFIT 60.0 MW (GROSS)
60.0 MH (ESC)
COAL
3.00 XS
CITRATE
BUREAU OF MINES
ENERGY CONSUMPTION: •••*»
STATUS 2 STARTUP 7/79
CONSTRUCTION CONTINUES ON THE CITRATE PROCESS SCRUBBING SYSTEM HHICH HILL
CONTROL $02 EMISSIONS FROM A 60-MW COAL-FIRED POWER GENERATING UNIT AT
ST. JOE ZINC. THIS UNIT PROVIDES POHER FOR THE LOCAL UTILITY GRID.
FGO SYSTEM START-UP IS SCHEDULED FOR DECEMBER 1978. THE RE6ENERABLE FGD
SYSTEM HILL PRODUCE ELEMENTAL SULFUR AS A BY-PRODUCT. ALL MAJOR CONSTRUC-
TION IS COMPLETE. HIRING AND PIPING WORK IS NOH BEING COMPLETED.
28
-------
EPA UTILITY FGD SURVET: FEBRUARY - MARCH 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TAMP* ELECTRIC
316 3END
i
NEW 450.0 *W (GROSS)
450.0 "!W (ESc)
COAL
2.50 *S
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION; **••:
STATUS 6 STARTUP 0/f5
TAMPA ELECTRIC HAS ANNOUNCED PLANS TO INSTALL AN F60 SYSTEM AT BIS BEND
4 WHICH IS SCHEDULED TO BEGIN OPERATIONS EARLY IN 1985. THE F6D PROCESS
HAS NOT VET BEEN SELECTED. PRIHART PARTICIPATE CONTROL WILL BE PROVIDED
BY AN ELECTROSTATIC PRIC1PITATOR UPSTREAM OF THE FGD SYSTEM. AN INPIRECT
(STEAM COIL> HOT AIR INJECTION REHEAT SYSTEM WILL BE INCLUDED AT THE
SCRUbBER OUTLET. DESIGN SULFUR DIOXIDE REMOVAL EFFICIENCY WILL PE
9Q PERCENT
TENNESSEE VALLEY AUTHORITY
CUMBERLAND
RETROFIT 1300.0 NW (GROSS)
600.0 «W (ESC)
COAL
• •••• XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••X
STATUS 6 STARTUP 7/82
TVA INSTALLING A HEAVY-MEDIA COAL-CLEANING SYSTEM AND HAS AGREED TO
INSTALL A 600-MW FGD SYSTEM AT THE CUMBERLAND PLANT TO BRING IT INTO
COMPLIANCE WITH STATE AND FEDERAL S02 EMISSION LIMITS. THE TYPE OF
FGD SVSTEP CHOSEN WILL BE DETERMINED BY PROTOTYPE LEVEL EVALUATION OF
SEVERAL ADVANCED SCRUBBER CONCEPTS.
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE
1-10
RETROFIT i«so*o NW (GROSS)
600.0 "W (ESC)
COAL
*••** xs
•A6NES1U* OXIDE
TVA/UNITED ENGINEERS
ENERGY CONSUMPTION: **«*X
STATUS 5 STARTUP 0/82
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
6UD6tTTED AT S185 MILLION, INCLUDING THE COST OF A NEW 600-FT. STACK.
TENNESSEE VALLEY AUTHORITY
PARADISE
1
RETROFIT 704.o «w (GROSS)
704.0 NW (ESC)
COAL
••*** XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **««X
STATUS 3 STARTUP 6/82
TVA is REQUESTING/EVALUATING BID SPECIFICATIONS FOB TWO LIMESTONE SLURRY
FGD SYSTEMS WHICH HILL BE RETROFITTED ONTO TWO 650-MW HIGH SULFUR cOAL-
FIRED BOILERS AT THIS STATION. THE FGD SYSTEMS WILL TREAT 1001 OF THE
FLUE GASES FROM BOTH UNITS. TVA HAS PROJECTED THE TOTAL COST OF THE
PARADISE FGD SYSTEMS TO BE APPROXIMATELY S220 MILLION (S170/KW). BID
REQUEST WAS COMPLETED B* MID-NOVEMBER AND EVALUATION IS NOW IN PROCESS.
BID EVALUATION IS EXPECTED TO BE COMPLETED BY JANUARY 1 ANfl A CONTRACT
SHOULD BE AWARDED SHORTLY THEREAFTER.
TENNESSEE VALLEY AUTHORITY
PARADISE
2
RETROFIT 70*.o *M (GROSS)
704.0 NW (ESC)
COAL
4.20 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••X
STATUS 3 STARTUP 3/82
TVA IS REQUESTING/EVALUATING BID SPECIFICATIONS FOR TWO LIMESTONE SLURRY
FGD SYSTEMS WHICH WILL BE RETROFITTED ONTO TWO 650-MW HIGH SULFUR COAL-
FIRED BOILERS AT THIS STATION. THE FGD SYSTEMS WILL TREAT 1001 OF THE
FLUE GASES FROM BOTH UNITS. TVA HAS PROJECTED THE TOTAL COST OF THE
PARADISE FGD SYSTEMS TO BE APPROXIMATELY S220 MILLION (S170/KW). BID
REQUEST WAS COMPLETED BT MID-NOVEMBER AND EVALUATION IS NOW IN PROCESS.
BID EVALUATION IS EXPECTED TO BE COMPLETED BY JANUARY 1 AND A CONTRACT
SHOULD BE AWARDED SHORTLY THEREAFTER.
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10A
RETROFIT 10.0 "W (GROSS)
10.0 NW (ESC)
COAL
2.90 XS BITUMINOUS
LIME/LIMESTONE
RID CORRECTION DIVISION. UOP
ENERGY CONSUMPTION: ••••X
STATUS 1 STARTUP 4/72
REFER TO THE BACKGROUND INFORMATION IN SECTION 3 OF THIS REPORT. THIS
TURBULENT CONTACT ABSORBER (TCA) LIME/LIMESTONE SCRUBBING SYSTEM HAS BEEN
OPERATIONAL SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY THE EPA WITH
TV* AS THE CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTEL CORP. OF SAN
FRANCISCO is THE MAJOR CONTRACTOR. TEST DIRECTOR. AND REPORT WRITER.
TESTING CHEMICAL ADDITIVES FOR IMPROVING S02 REMOVAL EFFICIENCY
CONTINUED THROUGH OCTOBER AND NOVEMBER. BOTH VENTURI/SPRAY TOWER AND TCA
SYSTEMS WERE OPERATED ON LIMESTONE SLURRY WITH FLYASH LOADING.
29
-------
?PA UTILITY FGD SURVEY: FEfHUARY - MARCH 1979
SECTION 2
STATUS Of F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TENNESSEE VALLEY AUTHORITY
SHAUNEE
10P
RETROFIT
10.0 «W tGROSS)
• w CE$C>
10.0
COAL
2.9Q SS BITUMINOUS
LIME/LIMESTONE
CHEM1CO
ENERGY CONSUMPTION: •«*•!
STATUS 1 STARTUP 4/72
REFER TO SECTION J OF THIS REpo"T FOR ADDITIONAL INFORMATION. THIS
VENTUFI/SPRAY TOWER LIRE/LIMESTONE SCRUBBING SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY THE EPA KITH TWA AS THE
CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTEL CORP. OF SAN FRANCISCO IS
THE N«JO( CONTRACTOR* TEST DIRECTOR* AND REPORT WRITER. TESTING WITH
CHEMICAL ADDITIVES FOR IMPROVING S02 REMOVAL EFFICIENCY CONTINUED
THROU6H 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
RETROFIT 575.0 «* (GROSS)
575.0 *W
COAL
4.30 IS
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION: *•••!
STATUS 1 STARTUP 5/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS 516 MW COAL-FIRED POWER GENERATING
UNIT CONSISTS OF EXISTING ELECTROSTATIC PR EC IP1TATORS FOLLOWED PY FOUR
PARALLEL SCRUBBING TRAINS. EACH CAPABLE OF HANDLING 25 PERCENT OF THE
EOILEK FLUE GAS FROM UNIT 8. EACH TRAIN INCLUDES A RECTANGULAR THROAT
VENTUP1 SCRUBBER A*D * 6«10-TOWEfi ABSORBER SUPPLIED By POLfCON. THE GRID
TOWER CAN BE CONVERTED TO A MOBILE-BED TOWER IF GREATER S02 REMOVAL IS
REQUIRED.
TEXAS MUNICIPAL »OVER AGENCY
GIBBONS CREEK
1
NEW (00.0 'W (GROSS)
400.0 4W (ESC)
COAL
1.06 SS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: • ««•!
STATUS 3 STARTUP 1/P2
COMBUSTION ENGINEERING WAS AWARDED A CONTRACT TO DESIGN AND SUPPLY A
400-MW LIGNITE-FIRED BOILER. ESP, AND F6D SYSTEM AT GIBBONS CREEK STEAM
ELECTRIC STATION UNIT NO. 1. THE BOILER WILL BURN 1.061 SULFUR LIGNITE.
FLUE GAS WILL BE CLEANED OF PARTICULATES BY A COLD-SIDE ESP (99.73S
EFFICIENCY). S02 WILL BE REMOVED BY 3 SPRAY TOWER MODULES UTILIZING A
LIMESTONE SLURRY (72.5 TO 87.5* EFFICIENCY). A CONTRACT HAS BEEN AWARDED
TO IUCS FOR SLUDGE DISPOSAL. CONSTRUCTION IS TO BEGIN IN THE SPRING OF
1979. COMMERICAL START-UP IS SCHEDULED FOR JANUARY, 1982.
TEXAS POWER t LIGHT
SANDOW
I
HEW 545.0 «W (GROSS)
382.0 Nw (ESC>
COAL
1.60 SS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ••••X
STATUS 2 STARTUP 7/80
COMBUSTION ENGINEERING HAS BEEN CHOSEN AS THE BOILER AND FGD VENDOR FOR
THIS UNIT. BOILER CONSTRUCTION BEGAN ON SEPTEMBER 9, 1977. PARTlCULATE
REMOVAL EQUIPMENT HILL BE LOCATED ON THE COLD-SIDE OF THE AIR HEATER.
SOME PORTION OF THE FLUE GAS WILL BYPASS THE SCRUBBER FOR REHEAT. THE
SPENT SLURRY WILL BE PONDED AND WATER RECYCLED.
THE UNIT IS NOW APPROXIMATELY 35S COMPLETE.
TEXAS POWER t LIGHT
THIN OAKS
1
•EH 750.0 "W (GROSS)
750.0 MW
-------
EPA UTILITY FGD SURVEY: FEBRUARY - MARCH 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS POKER ( L16HT
TMIN OAKS
2
NEt» 750.0 *W (GROSS)
750.0 MW (E$C)
COAL
»•••• XS LIGNITE
LIMESTONE
VENOOR NOT SELECTED
ENER6T CONSUMPTION: • •••X
STATUS 6 STARTUP 0/86
THIS UNIT WILL BE JOINTLY OWNED BY TPtL AND ALCOA. * FIRM DECISION HAS
NOT BEEN HADE WHETHER TO INSTALL FGD FACILITIES. T«lS IS PRIMARILY DUE
TO THE FACT THAT SUCH A DECISION IS NOT YET REQUIRED IN THE UTILITIES
PLANNING TIMETABLE
TEXAS UTILITIES
FOREST GROVE
1
HEM 750.0 *u (GROSS)
750.0 MM (ESC)
COAL
• ••*• XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••X
STATUS 5 STARTUP 0/81
TEXAS UTILITIES IS PLANNING A NEk 7SO-MW UNIT AT THE FOREST GROVE SITE.
TWO ESP'S WILL BE INSTALLED FOR PARTICULATE CONTROL. THE UTILITY IS
CURRENTLY REQUESTING BIDS FOR AN FGD SYSTEM. START-UP IS SCHEDULED FOR
LATE 1981. THE BOILER WILL BE SUPPLIED BY BA6COCK ( hILCOX COMPANY.
THE DESIGN DOES NOT INCLUDE A STACK GAS REHEAT SYSTEM.
TEXAS UTILITIES
MARTIN LAKE
1
NEW 793.0 *W (GROSS)
595.0 MW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1.31
STATUS 1 STARTUP 4/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS NEW
793 HW UNIT FIRES TEXAS LIGNITE CONTAINING 0.9X SULFUR (AVG) AMD 81 ASH
(AVG). THE UNIT IS EQUIPPED WITH AN EMISSION CONTROL SYSTEM WHICH
INCLUDES COLD-SIDE ESP'S AND A LIMESTONE F6D SYSTEM BOTH SUPPLIED BY
RESEARCH-COTTRELL. THE FGD SYSTEM CONSISTS OF 6 PACrED/SPRAY TOWER
ABSORBERS WHICH TREAT 751 OF THE TOTAL BOILER FLUE GAS. THE REMAINING
FLUE GAS IS BYPASSED FOR REHEAT. TOTAL SO? REMOVAL EFFICIENCY IS 70.SZ.
THE FLUE GAS CLEANING WASTES ARE STABILIZED AND DISPOSED IN AN ON-SITE.
LANDFILL -
TEXAS UTILITIES
MARTIN LAKE
Z
NEU 793.0 MM (CROSS)
595.0 *W (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1.3s
STATUS 1' STARTUP 5/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS NEu
793 MW UNIT FIRES TEXAS LIGNITE CONTAINING 0.9X SULFUR (AVG) AND 8X ASH
(AVG). THE UNIT IS EQUIPPED WITH AN EMISSION CONTROL SYSTEM CONSISTING
OF CJLD-SIDE ESP'S AND A LIMESTONE FGD SYSTEM. BOTH SUPPLIED BY
RESEARCH-COTTRELL. THE FGD SYSTEM CONSISTS OF 6 PACKED/SPRAY TOWER
ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. TH£ REMAINING
FLUE GAS IS BY-PASSED FOR REHEAT. TOTAL DESIGN S02 REMOVAL EFFICIENCY IS
70.51. THE FLUE GAS CLEANING WASTES ARE STABILIZED AND DISPOSED IN AN
ON-SITf LANDFILL.
TEXAS UTILITIES
•ARTIN LAKE
5
NEK 793.0 MM (GROSS)
595.0 NW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1.3Z
STATUS 1 STARTUP 2/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS NEW 793-MW POWER GENERATING UNIT WILL FIRE TEXAS LIGNITE CONTAINING
0.9x SULFUR (AVG.) AND BX ASH (AVG.). TO MEET FEDERAL NSPS. THE
BE EQUIPPED WITH AN EMISSION CONTROL SYSTEM CONSISTING OF COLD-SIDE ESP'S
AND A LIMESTONE FGO SYSTEM. BOTH SUPPLIED BY RESEARCH-COTTRELL. THE FGD
SYSTEM CONSISTS OF 6 PACKED/SPRAY TOWER ABSORBERS WHICH WILL TREAT 75X OF
THE TOTAL BOILER FLUE GAS. THE REMAINING GAS WILL BE BYPASSED FOR REHEAT.
TOTAL DESIGN S02 REMOVAL EFFICIENCY IS 70.51 THE FLUE GAS CLEANING
WASTES WILL BE STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
TEXAS UTILITIES
MARTIN LAKE
I
NEH 750.0 M (GROSS)
750.0 My (ESC)
COAL
.90 IS LIGNITE
LIMES TOME
RESEARCH COTTRELL
ENERGY CONSUMPTION: ••••X
STATUS 3 STARTUP 0/85
THE CONTRACT FOR THIS FGD SYSTEM HAS BEEN AWARDED TO RESEARCH-COTTRELL.
THE BOILER IS NOW BEING ERECTED. START-UP HAS BEEN DELAYED TO EITHER
1985 OR 1986.
31
-------
fPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS UTILITIES
•ILL CREEK
1
«EW 750.0 MW (6ROSS)
750.0 *W (ESc>
COAL
..**. « LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: • •••»
STATUS 6 STARTUP 0/85
TEXAS UTILITIES IS PLANNING TMfl NEW 750-N|» UNITS FOR THE UTILITY'S
HILL CREEK SITE. THE UTILITY KILL INCORPORATE FGD SYSTEMS ON EACH UNIT
SO THAT SOZ EMISSIONS WILL BE CONTROLLED TO APPROXIMATELY US/MM BTU.
PARTUULATE MATTER WILL BE CONTROLLED BY ESP'S. START-UP FOB UNITS
1 ANDc ARE PROJECTED TO BE 1985 AND 1986 RESPECTIVELY.
TEXAS UTILITIES
MILL CREEK
?
NEW 750.0 1W (GROSS)
750.0 *H (ESC>
COAL
• •••• tS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
FNERGY CONSUMPTION: ••••*
STATUS 6 STARTUP 0/f6
TEXAS UTILITIES IS PLANNING TWO NEW 750-NW UNITS F0* THE UTILITY'S
PILL CREEK SITE. THE UTILITY WILL INCORPORATE FGD SYSTEMS ON EACH UNIT
SO THAT $02 EMISSIONS WILL BE CONTROLLED TO APPROXIMATELY 1 LB/MM BTU.
PARTICULATE MATTER WILL BE CONTROLLED BY ESP'S. START-UP FOR UNITS
1 AND 2 ARE PROJECTED TO BE 191)5 AND 1986 RESPECTIVELY.
TEXAS UTILITIES
•ONTICELLO
t
1EW 800.0 <.
THE FGD SYSTEM IS DESIGNED TO TREAT 3 MM ACFM OF FLUE GAS RESULTING FROM
COAL WITH 1.5S SULFUR. 18.91 ASH AND 0.04« CL. THE FLUE GAS CLEANING
WASTES ARE DISPOSED IN AN ON-S1TE LINED POND.
UTAH POWER t LIGHT
HUNTER
i
HEW 400.0 4W (GROSS)
360.0 «w (ESC)
COAL
.55 XS
LIME
CHEMICO
ENERGY CONSUMPTION: •***X
STATUS 1 STARTUP 5/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
A CONTRACT HAS BEEN AWARDED TO THE CHEMICO AIR POLLUTION DIVISION FOR A
PEBBLE LIME WET SCRUBBING SYSTEM FOR THIS NEW UNIT. THE SCRUBBING SYSTEM.
IS DESIGNED TO OPERATE IN AN OPEN HATER LOOP MODE WITH AN $02 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
WILL BE STABILIZED WITH FLVASH AND DISPOSED OF ON THE PLANT SITE. TNE
A-E DESIGN FIRM FOR THIS PROJECT IS STEARNS-ROGER. CONSTRUCTION IS NOW
UTAH POWER i LIGHT
HUNTER
?
NEW 400.0
-------
EPA UTILITY F6U SURVEY: FEBRUARY - PAPCH 1979
SECTION 2
STATUS OF FfD SYSTEMS
UNIT IDENTIFICATION ABSTRACT
• 1SC3NSH POtltR ". LIGHT A CONTRACT HAS BEEN AWARDED TO CHEMICO FOP A LIME/FLYASH F6D SYSTEM. IT
COlU4bIA WILL CONSIST OF TWO SPRAY MODULES «1TH A HOT-SIDE ESP FOR pAgTlCULATE
? REMOVAL. A CLOSED LOOP WATER SYSTE* IS ANTICIPATED WITH FLYASH STA6ILI-
"ETROflT 527.0 «• (CROSS) ZATIOM OF THE SLUD6E. A SLUDbE DISPOSAL POND LOCATED OFF-SITE I* BEIH6
316.0 " CONSlttRED. THE F6D S^STE" IS 6EIN6 DESIGNED TO TREAT 601 OF THE FLUE
COAL CAS RESULTING FRO* THF CO»BUSTION OF LOU SULFUR COLSTRIP COAL. THE
.SO XS REMAINING 40X KILL ft STPASSED FOR REHEAT.
LIME/ALKALINE FLYASH
CHEMICO
FNERSY CONSUMPTION: ••••!
STATUS 3 STARTUP 1/t 2
-------
EPA UTILITY FbD SUFVEY: FEBfcUAFY - Ml. CM 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UH1T GtNERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY b/FGD - Mk
EQUIVALENT SCRUBBED CAPACITY - KM
•* FUEL DATA
FUEL TYPfc
FUEL GRADE
AVERAGE NEAT CONTENT - KJ/KG
AVERAGE ASh CONTENT - 2
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - *
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIbN REPOVAL EFFICIENCY - I
PARTICULATt DESIGN REMOVAL EFFICIENCY
•• MATER LOOP
TYPE
FRESH HAlE-UP WATER - LITER/S
•• DISPOSAL
TYPE
ALABAMA ELECTRIC COOP
TOMBI6BEE
2
LEROY
ALABAMA
255.0
235.0
179.0
( 11500 BTU/LB)
COAL
B1TU«INOUS
26749.
H.OO
7.00
1.15
MET SCRUBBING
LIMESTONE
PEAbODY PROCESS SYSTEMS
NEW
1.1
9/7E
• •/••
85.00
99.30
OPEN
17.6
LINED POND
( 280 GP*>
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TV RELIABILITY UTILIZATION
X REMOVAL
S02 PART,
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
•• PROBLEMS/SOLUTIONS/COMMENTS
672
744
720
START DATE 2/79 END DATE 4/79
THE UTILITY HAS REPORTED THAT NO UNUSUAL PROBLEMS HAVE OCCURRED.
34
-------
EPA UTILITY FED SURVEY: FEBRUARY - KABCM 1979
SECTION 3
DESIGN AND PERFORMANCE DATA f00 OPERATIONAL FGO SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - KE/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MU
CROSS UNIT GENERATING CAPACITY - «b
NET UNIT GENERATING CAPACITY w/FGD - Pb
NET UNIT GENERATING CAPACITY bO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU
•• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM 60ILER FLUE GAS FLCU - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - X
STACK TOP DIAMETER - M
ALLEGHENY "OWER SYSTfM
PLEASANTS
1
3ELMONT
*EST VIRGINIA
A
21.
516.
£25.0
625.0
519.0
••*••*
******
iASE
* * /**
1152.85
132.2
366.
( .050 L?/MMBTU)
I 1.200 LP/PM8TU)
(2443000 *CFM)
< 270 F)
(1:00 FT)
(•*••• FT)
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - *
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUP CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - '.
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - HU
• • ESP
NUMBER
SUPPLIER
COAL
BITUMINOUS
******
* ••••*••
10-20
4.50
2-4.5
******
(«••**. BTU/LB)
11.000-13,300
(•** TPH)
AI» CORRECTION DIVISION, UOP
•• FGD SYSTEM
SALEABLE PR9DUCT/THPOUAbAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEy/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
S02 DESIGN REMOVAL EFFICIENCY - x
COMMERCIAL DATE
INITIAL START-UP
*• AbSORBER
NUMBER
TYPE
INITIAL START UP
NUMBER OF STAGES
BOILER LOAD/APSORBER - X
GAS TEMPtRATURE - C
IHRObAfcAY PRODUCT
yET SCRUBBING
LIME
MG/2-6X
BABCOCK t WILCOX
UNITED ENGINEERS AND CONTRACTORS
FULL-SCALE
NEW
99.55
90.00
3/79
3/79
SPRAY TONER
3/79
1
83.5
132.2
•• REHEATER
TYPE BYPASS
TEMPERATURE BOOST - C 11>1
( 270 F)
20 F)
35
-------
EPA UTILITY FGD SURVEY: FEBRUARY - MARCH TWy
POhtR SYSTEM (CONT.)
•« HATE* LOOP
TYPE OPEN
---------------- .. ------------------ . ----- PERFORMANCE DATA—— — ---- — ------ .—._.———- ---- - —
BEtlOD MODULE AVAILABILITY OPEPAPIL1TY RELIABILITY UTILIZATION S REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTE* 74*
4/79 SYSTEM 720
•• PK04LE*S/SOLUTIONS/CO»rENTS
START DATE 3/79 END DATE
THE UNIT STARTED ON PARCH 7 1979. NO HOURS ARE YET AVAILABLE BECAUSE OF
THE RECENT OFERATIN6 STATUS.
START DATE 3/79 END DATE 4/79
A MODULE HAS BEEN REKOVED FFON SERVICE DUE TO A UELD FAILURE ON THE AB-
SORBER DOHNCOXER.
•36. .
-------
EPA UTILITY F6D SURVEY: FEBRUARY - PARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - *U
EQUIVALENT SCRUBBED CAPACITY - XW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• • F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEb/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICIPATE DESIGN REMOVAL EFFICIENCY
*• HATER LOOP
TYPE
FRESH MAKE-UP WATER - L1TER/S
•* DISPOSAL
TYPE
- X
ARIZONA ELECTRIC POWER COOP
APACHE
2
COCHISE
ARIZONA
195.0
175.0
195.0
COAL
BITUMINOUS
(•...*• BTU/LB)
10.00
••*•*
.70
MET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
4.1
8/78
1/79
85.00
99.50
OPEN
115.9
SLUDGE POND
( 1840 GP*>
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART,
PER BOILER
HOURS HOURS
FGD
HOURS
CAP.
FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
672
744
720
** PROBLE4S/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/7°
COMPLIANCE TESTS WERE RUN ON THIS UNIT LAST NOVEMBER AND THE UNIT MAS
DECLARED COMMERCIAL IN FEBRUARY. THE FGD SYSTEM OPERATES ONLY ABOUT 50
PERCENT OF THE BOILER HOURS BECAUSE THE UNIT OPERATES AT SUCH A LOW
RATING 50 PERCENT OF THE TI"E THAT THE FGD SYSTEM IS NOT NEEDED.
START DATE 2/79 END DATE 3/79
A BOILER EXPLOSION AT THE BURNER FACE CAUSED THE UNIT TO BE DOWN FROM THE
LAST WEEK IN FEBRUARY THROUGH THE MIDDLE OF MARCH.
37
-------
EPA UTILITY FGD SURVEY: FEPflUARV - H»RCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAPE
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - fd
NET UNIT GENERATING CAPACITY W/FGD - Mw
EQUIVALENT SCRUBBED CAPACITY - MK
«• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE COUTEkT - Z
• • FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICIPATE DESIGN REMOVAL EFFICIENCY
•• MATER LOOP
TYPE
FRESH MAKE-UP bATER - LITER/S
•* DISPOSAL
TYPE
- Z
ARIZONA PUBLIC SERVICE
CHOLLA
1
JOSEPH CITY
ARIZONA
119.0
11?.0
119.0
COAL
sue&iTUMI NOUS
2360Q.
13.50
1J.OO
.50
.02
MET SCRUebING
LIMESTONE
RESEARCH COTTRELL
RETROFIT
4.2
10/7!
12/73
58.50
99.70
( 10150 BTU/LB)
OPEN
7.6
UNLINED POND
( 120 GPM)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABIL1TI RELIABILITY UTILIZATION
Z REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
12/78 A
B
SYSTEM
1/79
A
B
SYSTEM
£8.2
£5.6
£6.9
99.2
100.0
99.6
68.1
68.3
88.2
99.1
100.0
99.6
88.2
85.6
JS6..9
99.2
100.0
99.6
PHOELE4S/SOLUT10NS/COMMENTS
7.4* 744
744 744
647 ._
741
START DATE 12/78 END DATE 1/79
THE UTILITY HAS REPORTED THAT THE F6D SYSTEM EXPERIENCED CONTROL PROB-
LEMS.
2/79 A
B
SYSTEM
3/79
A
B
SYSTEM
100.0
100.0
100.0
95.3
100.0
57.7
100.0
100.0
100.0
95.0
100.0
97.5
100.0
100.0
100.0
95.3
100.0
97.7
672 672
744 744
672
727
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 3/79 END DATE 3/79
THE UTILITY HAS EXPERIENCED PLUGGED REHEAT TUBES. THE OLD TUBES. IN UN-
SECTIONALIZED BUNDLES* WERE REPLACED UITH NEW TUBES OF SPLIT COIL CON-
38
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
ARIZONA PUBLIC SERVICE (CONT.)
-PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABUJTY RELIABILITY UTILIZATION t REMOVAL PER BOILER FCD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
STRUCTION AND MADE OF 316L SS. THE NEb TYPE OF TUBES ALONG WITH BETTER
HAINTENANCt PROCEEDURES HAS ADDED TO THE REHEAT TUBE LIFE AND AVAILABILI-
TY .
4/79 A 100.0 100-0 100.0
8 100.0 100.0 103.0
SYSTEM 100.Q 100.0 100.0 720 720 72Q
-------
EPA UTILITY FC.C SURVEY! FEBRUARY - MRCH 1979
SECTION 3
DESIGN AND PERFORMANCE OATH FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPt
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTEST - X
*• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICIPATE DESIGN REMOVAL EFFICIENCY
•* HATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
•* DISPOSAL
TYPE
- X
ARIZONA PUBLIC SERVICE
CHOLLA
2
JOSEPH CITY
ARIZONA
350.0
?50.0
350.0
COAL
SUPBITUMINOUS
33609.
13.50
15.00
.50
.02
MET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
*•*<•*•
4/78
• */»*
75.00
99.70
( 10150 BTU/LB)
OPEN
7.6
SLUDGE POND
( 120 GPM>
_ .. -PERFORMANCE DATA - — — —
MODULE AVAILABILITY OPERABILUV RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP*
S02 PART. HOURS HOURS HOURS FACTOR
12/78 SYSTEM
1/79 SYSTEM
2/79 SYSTEM
3/79 SYSTEM
*/79 SYSTEM
•• PRObLEMS/SOLUTIONS/COMMENTS
744
672
744
720
START DATE 12/78 END DATE 4/79
OPERATION PARAMATERS ARE STILL UNAVAILABLE FOR THIS UNIT.
40
-------
£PA UTILITY FGD SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAKE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - Mb
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - t
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEK/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO2 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
** MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
CENTRAL ILLINOIS U6HT
DUCK CREEK
1
CANTON
ILLINOIS
4U.O
37".0
416.0
( 10500 BTU/LB)
COAL
BITUMINOUS
24423.
9.12
* * *** •• *
J.30
.03
WET SCRUBBING
LIMESTONE
RILEV STOKER/ENVIRONEER1N6
NEW
7/76*
8/7E
85.00
X 99.80
CLOSED
37.8
LINED POND
6Do 6P«)
.- ._«. . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79
A
B
C
D
SYSTEM
23.0
26.Q
21.0
10.0
20.0
25.0
28.0
23.JJ
11.0
21.0
25.0
28.0
23. 0
11.0
21.0
23.0
26.0
21..0
10.0
20.0
744 706 151 66.0
PROBLE»S/SOLUTIONS/COMMENTS
START DATE 12/76 END DATE 12/78
ISOLATION DAMPER FAILURES AND SLURRY RECYCLE DISCHARGE VALVE FAILURES
OCCURRED DURING DECEMBER.
START DATE 12/78 END DATE 12/78
LIMESTONE MILL PROBLEMS AND PLUGGED LIMESTONE FEEDER HAMPERED SCRUBBER
OPERATIONS DURING DECEMBER.
START DATE 12/78 END DATE 12/78
FROZE" INSTRUMENT CONTROL LINES HERE A PROBLEM.
1/79
A
B
C
D
SYSTEM
.0
.0
.0
.0
.0
• 0
.0
.0
.0
.0
>0
.0
.0
.0
.0
.0
.0
.0
744
738
41
-------
EPA UTILITY FbD SURVEY: FEBRUARY - MARCH 1979
CENTRAL ILLINOIS LI6HT (CONT.)
... . .. .—.. .....PERFORMANCE DATA — -- __.— --—- ........ -.._—-—
PERIOD MODULE AVAILABILITY OPERABlLl" RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
• • PROeLE'S/SOLUTIONS/COMMENTS
START DATE 1/79 END DATE 1/79
FROZEN INSTRUMENT CONTROL LINES, RECYCLE TANK SUCTION LINES. MAIN MODULE
DRAIN LINFS A*D MIST ELjMlNATOR DRAIN LINES MERE MAJOR PROBLEM AREAS
DURING JANUARY.
START DATE 1/79 END DATE 1/79
SLURRY RECYCLE VALVE PLU66A6E AND SLURRY TRANSFER PUMP FAILURE CONTRIBUTED
TO EGO SYSTEM OUTA6E.
2/79
A
e
c
D
SYSTEM
.0
.0
.0
.0
.0
.0
.c
.0
.0
.0
.0
• 0
.0
.0
.0
.0
.0
.0
.0
.0
672 533
0 80.5
•• PROBLE^S/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 2/79
RECYCLE PUMP SUCTION VALVE FAILURES AND A SLURRY TRANSFER PUMP FAILURE
CONTRIBUTED TO THE LOW OPERATION PARAMETERS OF THE F6D SYSTEM.
START DATE 2/79 [ND DATE 2/79
FROZEN MIST ELIMINATOR DRAINS. ABSORfcEft DRAINS AND INSTRUMENT LINES WERE
A MAJOR PROBLEM DURING FEBRUARY.
3/79
A
B
C
•
SYSTEM
33.7
6.7
.0
10.1
31.1
6.7
.0
9.4
31.1
6.7
.0
9.4
31.1
6.7
.0
9.t
7*4
74*
70
*• PROSLE1S/SOLUTIONS/COMMENTS
START DATE 3/79
END DATE 3/79
FREEZING PROBLEMS CONTINUED TO HAMPER FGD OPERATIONS DURING MARCH*
START DATE 3/79 END DATE 3/79
BROKEN MIST ELIMINATOR SPAY LINES AN0 PLU«CED MIST ELIMINATOR NOZ2LES
WERE PROBLEM AREAS DURING MARCH.
START DATE 3/79 END DATE 3/79
RECYCLE PUMP FAILURES AND WASTE HATER PUMP FAILURES WERE EXPERIENCED DUR
IN6 MARCH.
START DATE 3/79
END DATE 3/79
PLUGGED SLURRY NOZZLES AND GENERAL INSTRUMENTATION PROBLEMS WERE REPORTED
BY THE UTILITY.
42
-------
EPA UTILITY F6D SUKVEY: FEBRUARY - HARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NU*BEfc
CITY
STATE
GROSS UNIT GENERATING CAPACITY - »h
NET UNIT GENERATING CAPACITY H/FGD - **•
EQUIVALENT SCRUBBED CAPACITY - Mb
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE NEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - i
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - %
*• F60 SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEta/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO 2 DESlbN REMOVAL EFFICIENCY - X
PART1CULATE DESIGN REMOVAL EFFICIENCY
•* WATER
TYPE
FRESH PAKE -UP
** TREATMENT
TYPE
** DISPOSAL
TYPE
MATER - LITER/S
COLUMBUS I SOUTHERN OHIO
CONESVILLE
5
CONESVjLLE
OHIO
*11.0
375.0
411.0
< 108SC BTU/LB)
COAL
31TU«1NOUS
25237.
15.10
7.50
4.67
•**•*«•*
MET SCRUBBING
LIME
AIR CORRECTION DIVISION, UOP
NEW
3.9
1/77
2/77
89.50
X 99.60
OPCN
31.5
( 500 6P«>
PROPRIETARY (POZ-0-TEC)
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
A
B
SYSTEM
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
672 0
•• PROoLEMS/SOLUTIONS/COMMENTS
START DATE 2/79
3/79
4/79
A
B
SYSTEM
A
B
SYSTEM
50.0
.0
25.0
17.0
•0
8.5
END DATE 2/79
THE LPb OPERATING HOURS FOR FEBRUARY WERE CAUSED BY SEVERE WINTER HEATHER.
START DATE O/ 0
END DATE O/ 0
THE LOb OPERATING HOURS FOR FEBRUARY WERE CAUSED BY SEVERE WINTER WEATHER.
49.0
.0
24.5
58.0
.0
29.0
50.0
• 0
25.0
73.0
.0
36.5
43.0
.0
21.5
12.0
.0
6.0
744
720
652
149
160
43
43
-------
EPA UTILITY FED SURVEY: FEBRUARY - MARCH 1979
COLUMBUS I SOUTHERN OHIO ELIC.
-------
EPA UTHIT* FGD SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL F6D StSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - M*
NET UNIT GENERATING CAPACITY W/F6D - My
EQUIVALENT SCRUBBED CAPACITY - MM
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START>UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICIPATE DESIGN REMOVAL EFFICIENCY
*• MATER LOOP
TYPE
FRESH MAKE-UP MATE* - LITER/S
•• TREATMENT
TYPE
•« DISPOSAL
TYPE
- X
COLUMBUS k SOUTHERN OHIO ELEC.
CONESVILLE
6
CONESVlLLE
OHIO
411.0
375.0
411. C
( 10850 8TU/LP)
COAL
BITUMINOUS
25237.
15.10
7.50
4.67
•*»•»**•
MET SCRUBBING
L1«E
AIP CORRECTION DIVISION, UOP
NEW
3.9
6/7?
6/78
89.50
99.60
OPEN
31.5
( 500 GPU)
PROPRIETARY
-------
EPA UTILITY F6D SURVEY: FEBRUARY - M»RcH 1979
SECTION 3
OESI6N AND PERFORMANCE DATA F0» OPERATIONAL F60 SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT EENERATINC CAPACITY U/F60 - My
EQUIVALENT SCRUBBED CAPACITY - MM
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• WATER LOOP
TYPE
FRESH MAKE-JP bATER - LITER/S
•* TREATMENT
TYPE
** DISPOSAL
TYPE
- X
OUOUESNE LIGHT
ELRAMA
1-*
£LRA«A
PENNSYLVANIA
510.0
475.0
510.0
COAL
••*•»•
26*00.
21.00
•*«••*•*
2.20
•*•*•*•»
«ET SCRUBBING
LIME
CHEHICO
RETROFIT
3.5
10/75
10/75
83.00
99.00
OPEN
*••**•*
POZ-0-TEC
LANDFILL
( 11350 BTU/LB)
(**.**
-------
EPA UTILITY F60 SUfcVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/f60 - Mb
EQUIVALENT SCRUBBED CAPACITY - Mb
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEb/RETROfIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
•* bATER LOOP
TYPE
FRESH KAKE-UP bATER - LITER/S
•• TREATMENT
TYPE
- Z
DUOUESNE LIGHT
PHILLIPS
1-6
SOUTH HEIGHT
PENNSYLVANIA
410.0
377.0
410.0
COAL
******
26400.
18.20
•*•**••*
2.00
********
*ET SCRUBBING
( 11350 BTU/LB)
CHEMICO
RETROFIT
2.4
7/73
• • /•*
83.00
99.00
OPEN
*******
POZ-O-TEC
(•«*** 6PM)
•* DISPOSAL
TYPE
LANDFILL
-------
EPA UTILITY FGD SUPVEY: FEERUART - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GPOSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/F6D - My
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPt
FUEL CFADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - I
•« FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• HATER LOOP
TYPE
FRESH MAKE-UP WATER > LITER/S
•• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
( 12500 BTU/LB)
GULF POWER
SCHOL2
1*2
SNEADS
FLORIDA
23.0
23.0
21.0
COAL
BITUMINOUS
29075.
11.00
5.00
2.50
MET SCRUBBING
LIMESTONE/THOROUGHBRED 121
CHIVODA INTERNATIONAL
RETROFIT
* **•«*«
8/78
** /*•
90.00
X 99.50
CLOSED
•*•••*•
(*•**• 6P»)
GYPSUM
STACKED IN POND
PERFORMANCE DATA
MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
2/79
3/79
4/79
SYSTEM
SYSTEM 1QO«0
SYSTEM 100.0
98
100
100
.3
.0
.0
100
100
.0
.0
98
100
100
.4
.0
.0
672
744
720
672
744
720
661
744
720
*• PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/79
ONE PUMP FAILURE CAUSING A 5 MINUTE OUTAGE HAS REPORTED BY THE UTILITY.
START DATE 4/79 END DATE 4/79
HIGH PARTICULATE LOADING TESTS WERE DONE IN APRIL. THE ESP HAS TOTALL*
SHUT DOWN. THE S02 REMOVAL HAS NOT AFFECTED BUT THE GYPSUM PRODUCT WAS
TEMPORARILY AFFECTED. HIGH CHLORIDE TESTS WERE ALSO PERFORMED BY ADDING
CALCIUM CHLORIDE TO THE SYSTEM. A RESULTANT CONCENTRATION OF 6000 PPM
CHLORIDE WAS FOUND IN THE UNDERFLOW- NO SIGNIFICANT SCALING WAS ENCOUNT-
ERED.
48
-------
EPA UTiUTT FGD SURVEY: FEBRUARY - PARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT MAKE
UNIT NUftBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - Mk
NET UNIT GENERATING CAPACITY M/F6D - Pb
EQUIVALENT SCRUBBED CAPACITY - MM
• * FUEL DATA
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - 2
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
•• FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEM/RETROF1T
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESI6N REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•* MATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
•* DISPOSAL
TYPE
- Z
INDIANAPOLIS POWER I LIGHT
PETERSBURG
3
PETERSBURG
INDIANA
532.0
515.0
532.0
< 10750 BTU/LB)
COAL
3ITUPJNOUS
25004.
•*•**• ••
••***•**
3.25
••**«***
MET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEW
2.4
12/77
12/77
85.00
99.30
CLOSED
55.6
UNLINED POND
( 882 6PM)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
•• PROfiLE'S/SOLUTIONS/COMMENTS
672
START DATE 2/79 END DATE 2/79
THE UTILIZATION FIGURES GIVEN BELOM ARE FOR THE PERIOD SEPTEMBER-DECEMBER 1
1/79 A 31.2
B 30.0
C 45.0
D 43.0
SYSTEM 39.0 744 715
• • PR06LENS/SOLUTIONS/COMMENTS
START DATE 1/79 END DATE 3/79
THE FGD SYSTEM MAS DOMN FROM JANUARY 1 TO MARCH 15 DUE TO SEVERE MiNTER
MEATNER.
4/79 SYSTEM
722
*• PROBLE1S/SOLUTIONS/COMMENTS
START DATE 4/79 END DATE 5/79
DUE TO THE FORMER SHELL LINING PEELING AWAY. THE STEEL
SHELL MAS SAND BLASTED AND RIGIFLAKE 4650 APPLYED BY TROMEL.
49
-------
EP» UTILITY ffaO SURVEY: FEBRUARY - r»RCH 1979
INDIANAPOLIS PO-ER i. LIGHT (COMT.)
- — _. . PERFORMANCE PAT A — -----
"ERI3D MODULE AVAILABILITY OPERABlLlTY RELIABILITY UTILIZATION Z REMOVAL PER BOILER F60 CAP.
S02 pART. HOURS HOURS HOURS FACTOR
START DATE 4/79 [No DATE 5/7"
ALL MIST ELIMINATORS HERE CLEANED DUE TO SEVERE SCALING PROBLEMS*
START DATE 4/79 END DATE 5/7"
EXTENSIVE REPAIRS MERE HADE TO THE INLET DAMPERS* THE OUTLET DUCTS HERE
LIKED WITH RESIST1FLAKE 1150, AND MAJOR REPAIRS WERE HADE TO BONNETS
BECAUSE OF ACID CORROSION.
START D*TE 4/79 END DATE 5/79
THE SYSTEM HAS BEEN 00«N SINCE MID-MARCH FOR INSPECTION AND MAINTENANCE.
SO
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS U1IT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F60 - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE CONTENT - 2
AVERAGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - Z
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS 1VPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
•* WATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
** TREATMENT
TYPE
•» DISPOSAL
TYPE
KANSAS CITY POWER I LIGHT
HAWTHORN
3
KANSAS CITY
MISSOURI
90.0
85.0
90.0
( 9800 BTU/LB)
COAL
BITUMINOUS
22795.
11.00
********
.60
********
WET SCRUBblNG
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
11/72
**/**
70.00
99.00
CLOSED
**•**•*
(*****
SOME STABILIZATION FROM FLYASH
UNLINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION z REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79' SYSTEM
*• PROBLEMS/SOLUTIONS/CONNENTS
START DATE
672
744
1/79 END DATE 3/79
OPERATING INFORMATION IS STILL NOT AVAILABLE FOR UNIT 3
4/79 SYSTEM 18.0
•* PROBLEMS/SOLUTIONS/COMMENTS
START DATE
720 130
130 9.0
4/79 END DATE 4/79
THE BOILER HAS DOWN IN APRIL FOR 543 HOURS FOR TURBINE OVERHAUL.
5/79
SYSTEM 55.0
*• PROBLE'S/SOLUTIONS/COMMENTS
START DATE
744 409
409 29.Q
S/79 END DATE 5/79
IN MAY THE OUTAGE TIME MAS DUE TO BOILER TUBE LEAKS.
51
-------
EPA UTILITY F60 SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UHIT 6ENERATIN6 CAPACITY - Mh
NFT UNIT GENERATING CAPACITY W/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - »U
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
- X
KANSAS CITY POU£R t LIGHT
HAWTHORN
4
KANSAS CITY
MISSOURI
90.0
85.0
90.0
COAL
BITUMINOUS
22795.
11.00
••*•**•*
.60
••••*•••
MET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
a/72
*•/««
70.00
99.00
9800 BTU/LB>
CLOSED
*•••**•
(***** 6PM)
SOME STABILIZATION FROM FLYASH
UNLINED POND
-PERFORMANCE DATA- ~ — ——
MODULE AVAILABILITY OPERA6ILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
3/79
SYSTEM
SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
672
744
START DATE 1/79 END DATE 3/79
OPERATING INFORMATION FOR UNIT 4 IS STILL NOT AVAILABLE.
4/79
SYSTEM 57.0
•• PROBLEMS/SOLUTIONS/COMMENTS
START DATE
720 410
410 3Q.O
4/79 END DATE 4/79
AN EXCITER FAILURE ON THE GENERATOR CAUSED THE APRIL OUTAGE TIME.
5/79 SYSTEM 94.0
*• PROBLEMS/SOLUTIONS/COMMENTS
START DATE
744 699
699 49.0
5/79 END DATE 5/79
MAY OUTAGE TIME WAS FOR SCRUBBER CLEANING AND GENERAL MAINTENANCE*
52
-------
EPA UTILITY F66 SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY b/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - *1U
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - 1
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT • X
• • FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• MATER LOOP
TYPE
FRESH MAKE-UP MATER - L1TER/S
*• DISPOSAL
TYPE
KANSAS CITY POWER t LIGHT
LA CY6NE
1
LA CV&NE
KANSAS
87*.0
•ZO.O
874.0
- X
COAL
SUBblTUMiNOUS
21913.
24.36
8.60
5.39
.03
WET SCRUBBING
LIMESTONE
3ABCOCK t MILCOX
NEW
2.7
2/73
6/73
BO.00
99.50
( 9421 BTU/LB)
OPEN
72.3
UNLINED POND
( 1148 GPN)
....... -PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP*
S02 PART. HOURS HOURS HOURS FACTOR
2/79 A
B
c
D
E
F
G
H
SYSTEM
3/79 A
B
C
D
E
F
6
H
S»STEM
4/79 *
B
C
D
E
F
95.0
94.6
92.6
93.5
95.1
94.3
94.1
93.8
94.1 672 342
96.1
96.0
93.2
95.6
96. 5
94. B
95.7
93.4
95.2 744 314
95.5
95.7
94.4
91.4
95.5
96.2
-------
EPA UTILITY FbO SURVEY: FEBRUARY - MARCH 1979
KANSAS CITY POMC4 S LIGHT (CONT.)
PERFORMANCE DATA — ———
»ER10o MODULE AVAILABILITY OPERA&ILJTY RELIABILITY UTILIZATION t REMOVAL PER BOILER F6D CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
6 95-9
H 95.7
SYSTEM 95.0 720 638
*. PRObLE'S/SOLUTIONS/CCMNENTS
STA3T DATE Z/79 END DATE 3/79
NO HAJOB FtO SYSTEM PROBLEMS WERE REPORTED BY THE UTILITY FOR FEBRUARY OR
MAfiCH.
START 0»TE 2/7V END DATE 3/79
THE UTILITY HAS REPORTED THAT MANY TUBE LEAKS AND CYCLONE LEAKS MERE
EXPERIENCED .ITH THE BOILER.
-------
EPA UTILITY F6D SURVEY: FEBRUARY - "A»CH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Hh
NET UNIT GENERATING CAPACITY W/F6D - MM
EQUIVALENT SCRUBBED CAPACITY - MW
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - i.
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• F6D STSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP CATE
502 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• VATER LOOP
TTPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TTPE
*• DISPOSAL
TTPE
- X
KANSAS POKES K LIGHT
4EFFPEY
1
( 8125 BTU/LB)
KANSAS
720.0
680.0
5*0.0
CO«L
•*•«*•
18899.
5.80
30.00
.32
.01
WET SCRUBBING
LIMESTONE
COMBUSTION EN6INEERIN6
NEW
»*•**••
8/7S
8/78
80.00
99.00
CLOSED
35.1
( 557 6PM)
NON-PROPRIETARY
UNLINED POND
PERFORMANCE DATA
»ERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 STSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
•* PRObLEMS/SOLUTIONS/COMMENTS
672
7**
720
7**
0
0
.0
.0
START DATE 4/79 END DATE 5/79
THE BOILER WAS SHUT DOWN FOR WARRANTY INSPECTION ON APRIL i AND REMAINED
OUT OF SERVICE DURINg MAY.
55
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MftRcH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FCD SYSTEMS
COMPANY NAME
PLAIT N»NE
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/FGD - Mb
EQUIVALENT SCRUBBED CAPACITY - HW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
•• FSD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-OP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* TREATMENT
TYPE
•« DISPOSAL
TYPE
- Z
KANSAS POWER t LIGHT
LAWRFNCE
4
LAURENCE
KANSAS
125.0
115.0
125.0
( 10000 BTU/LB)
COAL
******
23260.
9.80
••«*••*•
.55
.03
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
*******
1/76
**/**
73.00
98.90
CLOSED
*****•*
(*•**• 6PM)
NONPROPRIETARY; FORCED OXIDATION WITH AIR
UNL1NED POND
..... — PERFORMANCE DATA—-
PERIOD NODULE AVAILABILITY OPERABILITv RELIABILITY UTILIZATION
Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM
4/79 SYSTEM
•• PROBLEMS/SOLUTIONS/COMMENTS
START DATE
7*4
720
2/79 END DATE 4/79
UNIT 4 EXPERIENCED A MOTOR FAILURE ON AN I.D. FAN DURING THE FEBRUARY-
MARCH PERIOD.
56
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F60 SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Hk
NET UNIT GENERATING CAPACITY U/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - «W
•• FUEL DATA
FUEL TYPt
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
•• FtD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO2 DESIGN REMOVAL EFFICIENCY - I
PART1CULATE DESIGN REMOVAL EFFICIENCY
• • MATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•• TREATMENT
TYPE
** DISPOSAL
TYpE
LIGHT
- X
( 10000 BTU/LB)
KANSAS POWER I
LAWRENCE
5
LAWRENCE
KANSAS
420.0
400.0
420.0
COAL
**•••«
23260.
9.80
********
.55
.03
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
*****••
11/71
• • /*•
52.00
98.90
CLOSED
*******
(*•*** 6PM)
NONPROPRIETARY; FORCED OXIDATION WITH AIR
UNLINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGo CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
3/79
4/79
5/79
SYSTEM
SYSTEM
SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
672
744
720
744
START DATE 5/79 END DATE 5/79
THE UNIT HAS BROUGHT DOWN TO 1/2 CAPACITY FOR A SCHEDULED 3 MEEK
OUTAGE TO REBUILD AN AIR PREHEATER FAN MOTOR.
57
-------
rP» UTILITY fbD SURVEY: FEBRUARY - M*RcH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT 6ENERAT1N6 CAPACITY W/F60 - MW
EQUIVALENT SCRU3BED CAPACITY - MM
•* FUEL DATA
FUEL TYPE
FUEL ERAOE
AVERAGE HEAT CONTENT - KJ/RG
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• FCD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
*• WATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
•• DISPOSAL
TYPE
- X
KENTUCKY UTILITIES
GREEN RIVER
1-3
CENTRAL CITY
KENTUCKY
64.0
60.0
64.0
( 11000 8TU/LB)
COAL
BITUMINOUS
25586.
13.40
12.10
4.00
••***•*•
VET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
2.1
9/75
6/76
80.00
99.50
CLOSED
4.7 ( 75 6PM)
LINED POND
-PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM .0
•• PRO&LE«S/$OLUTIONS./C0MHENTS
4/79
5/79
.0
.0
672
START DATE 1/79 END DATE 2/79
THE PROBLEMS IN JANUARY AND FEBRUARY HERE A RESULT OF FREEZING HEATHER.
3/79 SYSTEM 11.2 100.0
*• PROdLE4S/SOLUTIONS/COMMENTS
100.0
11.2
744
83
83
START DATE 3/79 END DATE 4/79
THE LOW OPERATIONAL HOURS FOR MARCH AND APRIL DUE TO RECYCLE PUMP PROP-
LEWS.
SYSTEM
18.2
.0
100.0
100.0
.0
18.2
.0
S'STEM
*• PRObLEMS/SOLUTIONS/COPNENTS
720 131
744 0
.0
START DATE 5/79 END DATE 5/79
THE BOILER HAS TAKEN DOWN IN MAY FOR REPAIRS THAT is PROJECTED TO LAST
THROUGH THt END Of SEPTEMBER.
-------
EPA UTILITY F6D SURVEY: FEBRUARY - HARCM 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - «.
NET UNIT GENERATING CAPACITY W/F6D • Mb
EQUIVALENT SCRUBBED CAPACITY - Mw
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - T
AVERAGE CHLORIDE CONTENT - I
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• DISPOSAL
TYPE
LOUISVILLE b*S k. ELECTRIC
CANE RUN
4
LOUISVILLE
KENTUCKY
18?.0
175.0
188.0
COAL
SlTUMlNOUS
26749.
17.10
9.00
1.75
.04
WET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
1.6
8/76
9/77
85.00
99.00
( 11500 BTU/LB)
OPEN
6.3
LINED POND
( 100 6PM)
„„.. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
502 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
100.0
100.0
100.0
672
7*4
720
0
0
0
PROBLE*S/SOLUTIONS/CO*MENTS
START DATE 2/79 END DATE 4/79
THE UNIT DID NOT OPERATE DURING THESE MONTHS BECAUSE THE BOILER WAS STILL
DOWN WITH TUBE LEAKS.
59
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MH
EQUIVALENT SCRUBBED CAPACITY - MU
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - S
PARTICULATE DESIGN REMOVAL EFFICIENCY
*• HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
*• DISPOSAL
TYPE
C ELECTRIC
- X
LOUISVILLE GAS
CANE RUN
S
LOUISVILLE
KENTUCKY
190.0
180.0
190.0
COAL
31TUMINOUS
26749.
17.10
9.00
3.75
.04
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
1.6
12/77
5/79
85.00
99.00
11500 BTU/LB>
OPEN
******•
LINED POND
(*•*** CPU)
PERFORMANCE DATA — --
PERIOD MODULE AVAILABILITY OPERABIL1TT RELIABILITY UTILIZATION
t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 70.6
•• PROBLEM.S/S0LOT20NS/COMMENTS
50.1
672 477
337
START DATE 2/79 END DATE 2/79
DURING FEBRUARY FREEZING CAUSED PROBLEMS UITH LIME DELIVERY.
3/79 SYSTEM 71.8
4/79 SYSTEM 99.2
•• PR06LMS/SOLUTIONS/COMMENTS
57.5
49.6
744 596
720 360
428
357
START DATE 2/79 END DATE 4/79
SOME PROBLEMS HERE EXPERIENCED WITH DAMPERS AND THERE HERE PUMP FAILURES.
60
-------
EPA UTILITY F60 SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - Mu
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/FGD - Mu
NET UNIT GENERATING CAPACITY UO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANEE HEAT CONTENT - BTU/LB
AVERAGE A$H CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANEE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - N T/H
FUEL FIRING RATE - MW
*• ESP
NUMBER
•• F6D SYSTEM
SALEABLE PRODUCT/THROW AWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
S02 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
CONTRACT AWARDED
•• ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
BOILER LOAD/ABSORBER - X
GAS TEMPERATURE - C
L/C RATIO - L/CU.M
SUPERFICAL GAS VELOCITY - H/SEC
S02 INLET CONCENTRATION - PPM
502 OUTLET CONTRATION . PPM
•• FANS
NUMBER
TYPE
LOUISVILLE GAS » ELECTRIC
CANE RUN
LOUISVILLE
KENTUCKY
A
SO.
516.
992.0
288.0
269.0
272.0
288.0
( .116 LB/MMBTU)
t 1.200 LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
0/69
( 974000 ACFM)
< 300 F)
459.63
148.9
»*.***
•••*«*•
COAL
BITUMINOUS
26749.
17.10
15. 5-24.5
9.00
6.0-10.75
3.75
3.5-4.0
.04
3.03-0.06
(•••*• FT)
( 11500 BTU/LB)
10.400-11.900
(««* TPH)
THROWAHAY PRODUCT
MET SCRUBBING
DUAL ALKALI
ADI/COMBUSTION EQUIP ASSOCIATE
FULL-SCALE DEMONSTRATION
RETROFIT
95.00
3/79
10/76
12/78
COMBUST10N EQUIPMENT ASSOCIATES
2
60.0
80.0 ( 176 F)
1.3 ( 10.0 6AL/1000ACF)
2.7 < 9.0 FT/S)
3471
200
2
BOOSTER
61
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MUCH 1979
LOUISVILLE 6»S t, ELECTRIC (CONT.)
FILTER
NUMBER
TTPE
•• PUMPS
SERVICE
REACTOR PUM»
TANKS
SERVICE
PRIMRV REACTION TANK
SECONDARY REACTION TANK
FEED FORWARD TANK
FILTRATE SU1P
• • THICKENER
NUMBER
CONSTRUCTION MATF.Rj*L
DIAMETER - «
OUTLET SOLIDS - X
•• HATER LOOP
TTPE
•• DISPOSAL
NATURE
TTPE
LOCATION
ROTARY-DRU" KITH MATER WA$H
NU"BER
1
CONCRETE
3P.1
25.0
OPEN
FINAL
LINED POND
ON SITE
(125 FT)
PERFORMANCE DATA
PERIOD MODULE AVAILA8U1TY OPERABILITT RELIABILITY UTILIZATION t REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79 STSTE" 43.3
•• PRObLEMS/SOLUTIONS/CONMENTS
37.5
62 475
237
START DATE 4/79 END DATE 4/79
THIS UNIT STARTED OPERATING ON APRIL 4, 1979.
SCHEDULED FOR THE KEEK OF JUNE J.
COMPLIANCE TESTING is
62
-------
EPA UTILITY F6C SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBE*
CITY
STATE
GROSS UNIT GtNERATING CAPACITY - »b
NET UNIT GENERATING CAPACITY M/F6D - »V
EQUIVALENT SCRUBBED CAPACITY - PW
•* FUEL DATA
FUEL TYPt
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - i
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - t
AVERAGE CHLORIDE CONTENT - X
•• FGD STSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEM/RETROFIT
ENERGY CONSUMPTION 2
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICIPATE DESIGN REMOVAL EFFICIENCY
*• WATER LOOP
TYPE
FRESH MAKE-UP hATER - LITER/S
** TREATMENT
TYPE
*« DISPOSAL
TYPE
- t
LOUISVILLE GAS I ELECTRIC
MILL CREEK
3
LOUISVILLE
KENTUCKY
442.0
420.0
442.0
COAL
BITUMINOUS
26749.
11.50
*«*••*»*
3.75
*•••***•
MET SCRUBBING
HME
AMERICAN AIR FILTER
NEW
1.6
8/76
3/70
85.00
99.00
< 11500 BTU/LB)
OPEN
9.4
( 150 GPM)
FLYASH AND LlME STABILIZED
SLUDGE POND
-_.— -—_. ......—. .-PERFORMANCE DATA
>»E»lOO MODULE AVAILABILITY OPERA9ILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 1t.O
3/79 SYSTEM 53.1
• • PR06LEMS/SOLUTIONS/COMMENTS
17.4
52.4
672
744
651
735
117
390
START DATE 3/79 END DATE 3/79
COMPLIANCE TESTING HAS PERFORMED DURING MARCH AND THE UNIT HAS DECLARED
COMMERCIAL.
4/79
SYSTEM 63.6
«* PRObLE'S/SOLUTloNS/COMMENTS
44.4
720
503
320
START DATE 2/79 END DATE 4/79
THE ONLY PROBLEMS REPORTED HERE DAMPERS AND PUMP FAILURES.
63
-------
EPA UTILITY F6D SUPVET: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6(1 OSS UHIT 6ENERATIN6 CAPACITY - Mu
NET UNIT GENERATING CAPACITY M/F6D - MU
EQUIVALENT SCRUBBED CAPACITY > NU
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICIPATE DESIGN REMOVAL EFFICIENCY
** HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
LOUISVILLE GAS
PADDY'S RUN
6
LOUISVILLE
KENTUCKY
7?.0
67.0
72.0
COAL
•*•»»•
26749.
11.50
C ELECTRIC
( 11500 BTU/LB)
?.50
•««••«*•
UET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.8
4/73
*•/•*
90.00
X 99.10
CLOSED
3.1 C SO 6PM)
FIXATION HJTH LINE
UNLINED POND
PERFORMANCE DATA— —~— —
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION x REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
100.0
100.0
100.0
672
744
720
0
0
0
0
0
0
.0
.0
.0
*• PRObLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/79
THE UNIT HAS NOT OPERATED DURING THESE MONTHS BECAUSE OF LACK OF DEMAND.
64
-------
EPA UTILITY FGD SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUKBER
CITY
STATE
GROSS UWIT GENERATING CAPACITY Mb
NET UNIT GENERATING CAPACITY U/FGD - *•
EQUIVALENT SCRUBBED CAPACITY - »U
• * FUEL DATA
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - X
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
«• HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•* DISPOSAL
TYPE
POWER COOPERATIVE
MILTON R. YOUNG
Z
CENTER
NORTH DAKOTA
477.0
408.0
405.0
( 6500 BTU/LB)
COAL
LIGNITE
15119.
38.00
.70
••**.•••
«ET SCRUBBING
LIKE/ALKALINE FLYASH
ADL/COMBUSTlON EQUIP ASSOCIATE
NEW
1.9
9/77
6/78
85.00
Z 99.60
OPEN
44.1
HINEFILL
( 700 6PM)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITy RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
• • PROBLENS/SOLUTIONS/COHMENTS
672
744
START DATE 2/79 END DATE 3/79
NO INFORMATION WAS REPORTED BY THE UTILITY FOR THIS REPORT PERIOD.
65
-------
EPA UTILITY FGO SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAfE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY M/FGD - Mb
EQUIVALENT SCRUBBED CAPACITY - MM
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEM/RETROFIT
ENERGY CONSUMPTION - X
INlTjAt START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PART1CULATE DESIGN REMOVAL EFFICIENCY
•• rfATER LOOP
TYPE
FRESH PIAKE-JP b*TER - LITER/S
•• DISPOSAL
TYPE
- X
MONTANA POWER
COLSTRIP
1
COLSTRIP
MONTANA
360.0
332.0
360.0
COAL
SUBBITUMINOUS
20569.
8.60
23.90
.77
< 88*3 BTU/LB)
MET SCRUBBING
LIME
ADL/COMBUSTION EQUIP ASSOCIATE
NEW
3.3
9/75
11/75
60.00
99.50
CLOSED
(**••*
SLUDGE POND
PERFORMANCE D*T*
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/78 SYSTEM 96.7
1/79 SYJJEM 97..6
2/79 SYSTEM 90.3
744
2A4
672
66
-------
EPA UTILITY F60 SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITT
STATE
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY H/F60 - MV
EQUIVALENT SCRUBBED CAPACITY - MM
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
*• F&D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEK/RETROFIT
ENERGY CONSUMPTION Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - S
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• HATER LOOP
TYPE
FRESH MAKE-UP HATER - L1TER/S
•* DISPOSAL
TTPE
- z
< 8843 BTU/LB)
MONTANA POWER
COLSTRIP
2
COLSTRIP
MONTANA
260.0
332.0
360.0
COAL
SUBBITUHINOUS
20569.
8.60
23.90
.77
••»*••••
SCRUBBING
LIME
AOL/COMBUSTION EQUIP. ASSOCIATE
NEW
3.3
5/76
10/7f
60.00
90.50
CLOSED
•**•••*
SLUDGE POND
(****« 6PM)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION z REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/78 SYSTEM 91.2
1/79 .SYSTEM 94.3
2/79 SYSTEM 98.3
744
744
672
67
-------
EPA UTILITY FbO SURVEY: FEBRUARY - «»»C« T979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
OX IT NUMBER
CITY
STATE
CROSS UNIT GENERATINC CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - IV
EQUIVALENT SCRUBBED CAPACITY - »N
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• • FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
*• MATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
•* DISPOSAL
TYPE
NEVADA POMER
REID GARDNER
1
NOAPA
NEVADA
125.0
110.0
125.0
COAL
*****•
28950.
6.CO
******•*
.50
********
WET SCRUBBING
SODIUM CARBONATE
ADL/COMBUSTION EQUIP
RETROFIT
*******
4/74
• • /*•
90.00
97.00
( 12450 BTU/LB)
OPEN
1.6
EVAP POND
( 25 GPM>
-PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM 97.9 96.5
V PROBLEMS/SOLUTIONS/COMMENTS
96.5
78.?
744 603 582
START DATE 3/79 END DATE 3/79
THE FGD SYSTEM MAS OFF TO UNPLUG VENTUDI NOZZLES AND TO CLEAN SENSING
LINES. THE DOWNTIME HAS ABOUT 15 HOURS.
START DATE 3/79 END DATE 3/79
THE FGD SYSTEM HAS OFF FOR ABOUT 146 HOURS FOR REPAIR OF BOILER TUBE
LEAKS.
4/79 SYSTEM 100.0 98.7
*• PROBLEMS/SOLUTIONS/COMMENTS
98.6
25.7
720 188 185
START DATE 4/79 END DATE 4/79
THE BOILER AND FGD SYSTEM HERE OFF FOR APPROXIMATELY 533 HOURS FOR SCHED-
ULED MAINTENANCE.
66
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NU«BER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY M/FGD - Mb
EQUIVALENT SCRUBBED CAPACITY - MM
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERA6E SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - X
*• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• MATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
•* DISPOSAL
TYPE
( 12400 BTU/LB)
NEVADA POWER
REID GARDNER
2
10APA
NEVADA
125.0
110.0
125.0
COAL
******
28842.
8.00
•***•••*
.50
********
MET SCRUBBING
SODIUM CARBONATE
ADL/COMBUST10N EQUIP ASSOCIATE
RETROFIT
*****•*
4/74
**/•*
90.00
X 97.00
OPEN
1.6
EVAP POND
( 25 6P»>
__ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM 88.8 95.9
• • P.R.06LEKS/SOLU1IONS/COMMENTS
START DATE
96.0
88.8
744 688
640
3/79 END DATE 3/79
THE BOILER AND SCRUBBER WERE OFF FOR ABOUT TWO D«YS FOR REPAIR OF BOILER
TUBE LEAKS.
START DATE
3/79 END DATE 3/79
THE BOILER TRIPPED DUE TO HIGH FURNACE PRESSURE.
DOkN SENSING LINES HERE CLEANED ON THE SCRUBBER.
4/79 SYSTEM
•• PROBLEMS/SOLUTIONS/COMMENTS
START DATE
WHILE THE BOILER WAS
720 666
START DATE
4/78 END DATE 4/78
A HIGH PRESSURE ALARM ON THE SCRUBBER DUCT TRIPPED THE ScRUBBE* OFF Ll"E.
THE SCRUBBER PRESSURE SENSING LINES WERE CLEANED. THIS OCCURRED TWICE
DURING THE MONTH OF APRIL.
4/78 END DATE 4/78
A CONTROL PDMER FAILURE OCCURRED CAUSING A SCRUBBER TRIP WHEN THE 10 KW
GENERATOR WAS PUT BACK IN SERVICE.
69
-------
EPA UTILITY FbD SURVEY: FEERUjRY - KARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT N*ME
UNIT NUMBER
CITY
STATE
GROSS UV1T GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - "b
** FUEL DATA
FUEL TYPE
FUEL GRACE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - ^
AVERAGE MOISTURE CONTENT - «
AVERAGE SULFUR CONTENT - J
AVERAGE CHLORIDE CONTENT - X
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - S
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 OESlfcN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• I»AT£R LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
•• DISPOSAL
TYPE
( 12450 BTU/LB)
NEVADA POWER
REID GARDNER
3
MOAPA
NEVADA
125.0
110.0
125.0
COAL
•*•«*•
28959.
8.00
•••*•••*
.50
*****»*•
MET SCRUBBING
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
NEW
••«*•«•
6/76
7/76
85.00
I 99.00
OPEN
1.6
EVAP POND
C 25 GPM)
PERFORMANCE DATA ~ ~
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM 100.0 97.9
•• PR00LE1S/SOLUTIONS/COMMENTS
100.0
67.7
744 246 241
START DATE 3/79 END DATf 3/79
THE BOILER AND FGD SYSTEM HERE OFF FOR ABOUT 2 DAYS TO REPAIR AND BALANCE
A BOILER I.D. FAN.
START DATE 3/79 END DATE 3/79
THE BOILER AND FGD SYSTEM WERE OFF FOR ABOUT 19 DAY FOR SCHEDULED MAIN-
TENANCE.
4/79 SYSTEM 100.0 100.0
•* PROBLEMS/SOLUTIONS/COMMENTS
100.0
100.0
720 719 719
START DATE 4/79 END DATE 4/79
NO OUTAGES WERE REPORTED FOR APRIL.
70
-------
EPA UTILITY F6D SURVEY: FEBRUARY - "APCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F60 SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - PW
NET UNIT 6ENERATIN6 CAPACITY W/FGD - HU
EQUIVALENT SCRUBBED CAPACITY - NW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - 2
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
*• WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
NORTHERN INDIANA PUB SERVICE
DEAN H. "ITCHELL
11
GARY
INDIANA
115.0
115.0
115.0
COAL
******
25566.
********
11.00
3.50
******* *
MET SCRUBBING
WELLMAN LORD
DAVY POWER6AS
RETROFIT
•*«•**•
7/76
6/77
90.00
98.50
CLOSED
******•
( 11000 BTU/LB)
(•***« 6PD)
ELEMENTAL SULFUR
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA61L1TY RELIABILITY UTILIZATION
Z REMOVAL PER BOILER
502 PART. HOURS HOURS HOURS
CAP.
FACTOR
2/79 SYSTEM
7.0
1.0
1.0
720
•* PROBLEMS/SOLUT10NS/COMHENTS
START DATE 2/79 END DATE 2/79
THE BOILER OPERATED ON LOW SULFUR COAL FEBRUARY 1-12 AND HI6H SULFUR COAL
FEbRUARY 13-MRCH 2. THE FGD SYSTEM REMAINED DOWN THROUGH FEBRUARY 22
FOR COMPLETION OF SULFUR CONDENSER REPAIRS FOLLOWED BY REPAIR OF EXPANSION
JOINT LEAKS.
START DATE 2/79 END DATE 2/79
A POWER INTERUPTION ON FEBRUARV 24 RESULTED IN LOSS OF SEAL WATER TO THE
EVAPORATOR PUMP AND PACKING FAILURE. THE FGD SYSTEM REMAINED DOWN THROUGH
MARCH 2.
3/79 SYSTEM 47.0
*• PROBLENS/SOLUTIONS/COMMENTS
44.0
43.0
720
308
START DATE 3/79 END DATE 3/79
THE BOILER OPERATED ON HIGH SULFUR COAL.
START DATE 3/79 END DATE 3/79
THE FGD SYSTEM HAS SHUT DOWN DUE TO HIGH LEAKAGE IN THE EVAPORATOR CIRC-
ULATING PUMP PACKING GLAND. THE PUMP SHAFT SLEEVE HAS REPLACED AND THE
PUMP REALIGNED. THE SYSTEM HAS DOWN FOR ABOUT 16 DAYS.
71
-------
EPA UTILITY F60 SURVEY: FEBRUARY - PARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITt
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/F6D - MM
EQUIVALENT SCRUBBED CAPACITY - »U
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• F60 SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
soz DESIGN REMOVAL EFFICIENCY - i
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• HATER LOOP
TYPE
FRESH MAKE-JP HATER - LITER/S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
NORTHERN STATES POWER
SHER6URNE
1
BECKER
MINNESOTA
740.0
700.0
740.0
( 8500 BTU/LB)
COAL
SUBBITUMINOUS
19771.
9.00
25.00
.80
***** **•
•ET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
2.7
3/76
5/76
50.00
X 99.00
OPEN
*******
(•*••* 6PM)
FORCIBLY OXIDIZED
LINED POND
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPESAB1L1TY RELIABILITY UTILIZATION
3/79
131
102
103
104
105
106
107
108
109
61.0
88.0
45.0
86.0
94.0
71.0
91.0
73.0
91.0
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
101
102
103
104
105
106
107
108
109
110
111
112
SYSTEM 89.0
78.0
73.0
70.0
76.0
50.0
91.0
92.0
92.0
75.0
77.0
66.0
93.0
78.0
73.0
70.0
76.0
50.0
91.0
92.0
92.0
75.0
77.0
66.0
93.0
672 672 67.9
60.1
86.8
44.4
84.8
92.7
70.0
89.8
72.0
89.8
72
-------
[PA UTU1TY FGD SURVEY: FEBRUARY - "ABCH 1979
NORTHERN STATES POWER (CONT.)
... PERFORMANCE OAT A
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTO?
110
111
112
SYSTEM 92.0
eo.c
89.0
eo.o
7-.. 9
<)7.e
78.9
744 7?* 59.*
• * PROBLE'S/SOLUTIONS/COPMENTS
START DATE 2/79 END DATE 3/79
THE ONLY HOJOR PROBLEM REPORTED 6* THE UTILITY WAS BOILER RELATED -
SPECIFICALLY PROBLEMS WITH WET COAL.
START DATE 3/79 END DATE 3/79
CURRENTLY THE UTILITY IS INCREASING THE RECYCLE PUMP CAPACITY BY INSTAL-
LING 600 GPU UORTHINGTO* RECYCLE PUMPS. DURIN6 THIS PERIOD THEY H«vE
BEEN INSTALLED ON NODULES 101.103.10*.105.107. AND 110.
73
-------
PA UTILITY F&D SURVFY! FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITf
STATE
6ROSS UNIT GENERATING CAPACITY - »b
NET UNIT GENERATING CAPACITY W/FGD - Mti
EQUIVALENT SCRUBBED CAPACITY - Mb
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVEHA6E ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - t
•• F&D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITJAL START-UP DATE
COMMERCIAL START-UP DftTE
SO2 DESIGN REMOVAL EFFICIENCY - t
PARTICIPATE DESIGN REMOVAL EFFICIENCY
«* HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
NORTHERN STATES POWER
SHERBURNE
2
BECKER
MINNESOTA
740.0
700.0
740.0
( 8500 BTU/LB)
COAL
SUBB1TUHINOUS
19771.
9.00
25.00
.80
*•«*•***
WET SCRUBBING
LIMESTONE/ALKALINE FLVASH
COMBUSTION ENGINEERING
NEW
?.r
4/77
4/77
50.00
Z 99.00
OPEN
**•****
(***** 6PM)
FORCIBLY OXIDIZED
LINED POND
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
2/79
201
202
204
205
236
237
208
209
210
211
212
SYSTEM
93.0
3/79 231
202
203
204
205
206
207
208
209
210
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
86.0
84.0
89.0
59.0
76.0
72.0
6S.O
80.0
75.0
92.0
65.0
es.o
69.0
78.0
47.0
71.0
76.0
90.0
78.0
50.0
85.0
672 671
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
STATES POWER (CONT.)
... _—PERFOR1ANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION S REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
Z11 J7.C
212 86.0
SYSTlt 91.Q 7** 74*
• • PROfcLElS/SOLUTIONS/COMMENTS
START DATE 2/7° END DATE 3/79
THt ONLY RtAL PROBLEMS ENCOUNTERED DUR1N6 THIS PERIOD MERE PROBLEMS WITH
WET COAL.
START DATE 2/79 END DATE 3/79
THE RECYCLE PUMPS ARE BEING REPLACED WITH LAR6ER 8000 6PM WORTHIN6TON
PUfPS. DURING THIS PERIOD THE PUMPS WERE INSTALLED ON MODULES 20* AND
206.
-------
EP» UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - *V
EOU1VALFNT SCRUBBED CAPACITY - flW
•* FUEL DATA
FUEL TYPE
FUEL 6RADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
•* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
502 DESIGN REMOVAL EFFICIENCY - t
PARTICIPATE DESIGN REMOVAL EFFICIENCY
•• HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* TREATMENT
TYPE
•• DISPOSAL
TYPE
- Z
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
SHIPPlNfePORT
PENNSYLVANIA
917.0
825.0
917.0
COAL
BITUMINOUS
26749.
12.90
7.00
3.00
******••
MET SCRUBBING
LINE
CHENICO
NEW
6.0
12/75
6/76
92.10
99.00
OPEN
*******
CALCILOX
LANDFILL
I 11500 BTU/LB)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD
502 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 672
3/79 SYSTEM 744
4/79 SYSTEM 720
5/79 SYSTEM 744
•• PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 5/79
UNIT 1 IS CURRENTLY DOWN FOR BOILER OUTAGE.
START DATE 2/79 END DATE 5/79
SIX OF THE THELVE FAN HOUSINGS HAVE BEEN CHANGED FROM CARBON STEEL TO
INCOLLOY 825.
76
-------
EPA UTILITY FED SURVEY: FEBRUARY - PARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - «H
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - nW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LlTER/S
*• TREATMENT
TYPE
•• DISPOSAL
TTPE
PENNSYLVANIA
BRUCE MANSFIELD
2
SHIPPlNfiPORT
PENNSYLVANIA
"17.0
825.0
917.0
COAL
BITUMINOUS
26740.
12.90
'.00
7.00
*•*•••••
MET SCRUBBING
LI»E
( 11500 BTU/LB)
NEW
6.0
7/77
10/77
92.10
90.80
OPEN
••«••*«
CALCTLOX
LANDFILL
(•••«• 6PM)
... . . . . PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
*• PRO&LEHS/SOLUTIONS/COMMENTS
672
744
720
START DATE 1/79 END DATE 4/70
NO INFORMATION WAS REPORTED FOR THIS PERIOD BY THE UTILITY.
77
-------
EPA UTILITY F60 SURVEY: FEBRUARY - MUCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT CtNERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - »
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
*• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICIPATE DESIGN REMOVAL EFFICIENCY
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• BYPRODUCT
JVPRODUCT NATURE
DISPOSITION
PHILADELPHIA El-ECTRjC
EDDVSTONE
1A
EDDYSTONE
PENNSYLVANIA
120.0
120.0
120.0
COAL
•**••*
3163*.
9.40
5.90
2.60
••••*•••
MET SCRUBBING
MAGNESIUM OXIDE
UNITED ENGINEERS
RETROFIT
••*•«•*
9/75
9/75
90.00
99.00
( 13600 BTU/LB)
OPEN
8.3
SULFURIC ACID
( 132 6PM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITT RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
•• PROBLE4S/SOLUTIONS/COMNENTS
START DATE
672
744
2/79 END DATE 3/79
NO INFORMATION WAS REPORTED FOR THIS REPORT PERIOD.
78
-------
EPA UTILITY FED SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - Mb
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - X
•* FbD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
*• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
- X
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
1
NEW MEXICO
361.0
314.0
361.0
COAL
••*•••
16941.
22.45
14.82
.CO
•**•••••
MET SCRUBBING
UELLMAN LORD
DAVY POUERGAS
RETROFIT
«.4
4/7?
• « /•«
85.00
99.50
CLOSED
30.2
( 6100 BTU/LB)
( 480 6P«>
ELEMENTAL SULFUR
MARKETED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
•• PROCLE'S/SOLUTIONS/COMMENTS
672
744
720
720
START DATE 1/79 END DATE 5/79
HOURS ARE NOT VET AVAILABLE BECAUSE THE UTILITY IS CONCENTRATING EFFORTS
ON OPERATION OF THIS NEH UNIT. THE UTILITY REPORTED THAT THE SCRUBBING
MODULES THEMSELVES ARE OPERATING FINE. ALSO THE CHEMICAL PLANT IS READY
AND THERE IS NO SYSTEM PLUGGING WHATSOEVER.
START DATE 1/79 END DATE 5/79
THE MfJOR PROBLEM ENCOUNTERED WAS GYRATING FANS.
79
-------
FPA UTILITY FbD SURVEY: FEfRU«RY - MARCH 1979
SECTION 3
DESIGN ASD PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NU'EEk
CITY
STATE
6ROSS UNIT btKERATIKG CAPACITY - "k
NET UNIT GENERATING CAPACITY W/F6D - ••
EQUIVALENT SCRUBBED CAPACITY - MM
•• FUEL DATA
FUEL TYPfc
FUEL ERADE
AVERAGE HEAT CONTENT - KJ/KB
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE COS TENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTE" SUPPLIER
NEM/RE TROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULAR DESIGN REMOVAL EFFICIENCY
•« WATER LOOP
TYPE
FRESH K'HE-JP HATER - LITER/S
•• 3VPRODUCT
BYPRODUCT NATURE
DISPOSITION
- I
PUBLIC SERVICE OF NEW HE* 1 Co
SAN JUAN
2
NEW MEXICO
350.0
306.0
350.0
COAL
*****•
20934.
22. 45
14.82
.80
* *«***«•
MET SCRUBBING
BELLMAN LO"D
DAVY POWERGAS
RETROFIT
4.6
8/78
* •/*•
85.00
99.50
CLOSED
*******
( 9000 BTU/LB)
(•**•* 6PM)
ELEMENTAL SULFUR
MARKETED
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 STSTE"
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
*• PRObLE«S/SOLUTIONS/COMMENTS
672
744
720
720
START DATE 1/79 END DATE 5/79
HOURS ARE NOT YET AVAILABLE BECAUSE THE UTILITY IS CONCENTRATING EFFORTS
ON OPERATION OF THIS NEW UNIT. THE UTILITY REPORTED THAT THE SCRUBBING
MODULES THEMSELVES ARE OPERATING FINE. ALSO THE CHEMICAL PLANT IS READY
AND THERE IS NO SYSTEM PLUGGING WHATSOEVER.
STA»T DATE 1/79 END DATE 5/79
THE MAJOR PROBLEM ENCOUNTERED HAS GYRATING FANS.
BO
-------
tPA UTILITY F6D SURVEY: FEBRUARY PAPCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITf
STATE
GROSS UNIT GENERATING CAPACITY . Mb
NET UNIT GENERATING CAPACITY K/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - Mh
•• FUEL DATA
FUEL TYPE.
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 2
AVERAGE CHLORIDE CONTENT - Z
•• F60 SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• DISPOSAL
TYPE
- X
SOUTH CAROLINA PUBLIC SERVICE
MINYAH
2
GEORGETOWN
SOUTH CAROLINA
258. 0
1*0.0
COAL
9ITUMINOUS
( 11500 8TU/LB)
1J.50
•«•**
1.00
*****
•ET SCRUBBING
LIMESTONE
3ABCOCK I WILCOX
NEW
.7
7/77
* * /••
69.00
99.40
OPEN
6.3
UNLINED POND
( 100 6P»>
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPEPABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 672
3/79 SYSTEM 96.6 9C..4 Oft-* 92-7 7*4 1361 1313
*• PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 3/79
AN OUTAGE W»S REQUIRED TO RENEW QUENCHER PUMP BELTS AND FOR REPAIRS TO
QUENCHER SUCTION VALVE.
START DATE 2/79 END DATE 3/79
OUTAGES WERE REQUIRED TO REPAIR A HOLE IN THE FEED SLURRY LINE* TO INSPECT
THfc MODULE FOR PLUGGAGE, AND BECAUSE OF A BOOSTER FAN TRIP.
START DATE 2/79 ENo DATE 3/79
THE OPERATING VALUES SHOWN ARE THE FIGURES OF FEBRUARY AND MARCH COMBINED.
81
-------
EPA UTILITY FbD SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NE/J
$02 EMISSION LIMITATION - N6/J
NfT PLANT GENERATING CAPACITY - NW
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/F6D - MW
NET UNIT GENERATING CAPACITY bO/F6D - *V
EQUIVALENT SCRUBBED CAPACITY - MW
*• 90ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANEE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - Z
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT X
RANGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - t
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MW
•• ESP
NUMBER
TYPE
SUPPLIER
•• F6P SYS.TE* . . . . .
SALEABLE PRDOUCT/THRObAWAV PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
502 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
CONSTRUCTION INITIATION
CONTRACT AWARDED
STARTED REBUESTING SIPS
•• ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
BOILER LOAD/ABSORBER - Z
GAS FLOH - CU.M/S
SOUTHERN INDIANA GAS k ELEC
A.B. BROWN
1
WEST FRANKLIN
INDIANA
( .100 LB/MMBTU)
( 1.200 LB/MMBTU)
43.
516.
250.0
265.0
250.0
255.0
265.0
BABCOCK l VILCOX
PULVERIZED COAL. DRV BOTTOM
BASE
0/7«
372.82 < 790036 ACFM)
U5.3 ( 290 F)
152. I 498 FT)
•**•**• (**••• FT)
COAL
•••**•
30261.
8.80
•*«•*•
11.40
••*«*•
4.50
•••••*
•**•*•«•
******
*******
*****
( 13010 BTU/LB)
******
(*•* TPM)
COLD SIDE
BUELl-ENVlRoTECH
THROWAWAV PRODUCT
WET SCRUBBING
DUAL ALKALI
FMC CORPORATION
MID VALLEY DIVISION OF BROWN ROOT
MID VALLEY
FULL-SCALE
NEW
- Z 99.50
85.00
3/79
10/77
12/76
4/76
DISC CONTACTOR
1/79
FMC CORPORATION
3
62 HIGH X 32 DIA.
CARBON STEEL
CEILCOTE
60.0
237.84 C 504000 ACFft)
82
-------
EPA UTILITY FGD SURVEY: FEBRUARY - MA»CH 1979
SOUTHERN INDIANA GAS & EL EC CCCNT.)
GAS TEMPERATURE - C 145.0 ( 293 F)
S02 INLET CONCENTRATION - PPM 2810
S02 OUTLET CONTRATION - PPM 520
S02 DESIGN REMOVAL EFFICIENCY - X 85.0
•• FANS
NUMBER 2
TtPE BOOSTER
*• VACUUM FILTER
NUMBER 3
TYPE ROTARY ORU"
•• "1ST ELIMINATOR
NUMBER 2
TYPE CHEVRON
MASH SYSTEM WASH ONCE/SHIFT
•• PUMPS
SERVICE NUMBER
(((CIRCULATION 1
RECIRCULAT10N [SPARED 1
•* TANKS
SERVICE NUMBER
REACTOR • •••
SURGE TANK • •*•
** THICKENER
NUMBER 1
DIA«ETER - M 30.5 1100 FT)
•• MATER LOOP
TYPE UNDECIDED
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESI6N AMD PERFORMANCE DATA FOR OPERATIONAL F60 SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6»OSS UNIT GENERATING OPACITY - Mb
NET UNIT GENERATING CAPACITY V/F60 - Nw
EOU1VALENT SCRUBBED CAPACITY - Mb
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFU? CONTENT - *
AVERAGE CHLORIDE CONTENT - Z
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• *ATE» LOOP
TYPE
FRESH MAKE-UP bATER - LITER/S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
- Z
SOUTHERN MISSISSIPPI ELECTRIC
R.D. MORROW
1
HATTISBUR6
MISSISSIPPI
200.0
180.0
124.0
( 12000 BTU/LB)
COAL
•••**•
27912.
8.00
6.50
1.30
•*•*••••
WET SCRUBBING
LIMESTONE
RILEV STOKER/ENVIRONEERING
NEW
5.5
8/7P
• • /••
85.00
99.60
CLOSED
•*•••*•
(***** 6PM)
FLYASM STABILIZED
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
•• PROBLEMS/SOLUTIONS/COMMENTS
672
744
720
631
START DATE 4/79 END DATE 4/79
THt BOILER RETURNED TO SERVICE ON APRIL 1 AFTER COMPLETION OF REPAIRS
TO THE BOILER TUBES.
START DATE 4/79 END DATE 4/79
NO FGD SYSTEM RELATED PROBLEMS MERE REPORTED BY THE UTILITY FOR APRIL*
-------
EPA UTILITY FGD SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Pki
NET UNIT GENERATING CAPACITY W/FGD - HW
EQUIVALENT SCRUBBED CAPACITY - PW
•• FUEL OAT*
FUEL TYPt
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - Z
•• F60 SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/ftETROMT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN PEN OVAL EFFICIENCY
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
*• DISPOSAL
TYPE
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
SPRINGFIELD
MISSOURI
194.0
173.0
194.0
( 12500 BTU/LB)
COAL
BITUMINOUS
29075.
13.00
»****•*«
3.50
.30
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION* UOP
NEW
«.«
4/77
• */••
80.00
Z 99.70
CLOSED
19.8
NONPROPRIETARY
LANDFILL
( 315 6PM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 S-1 25.0
$-2 24.0 32.0 32.0 24.0
SYSTEM 24. 5 16.0 16.0 12.1
. - - -
672 508 81 71.4
*• PAOBLEMS/SOLUTIONS/COXMENTS
START DATE
START DATE
START DATE
START DATE
3/79
S-1
S-2
SYSTEM
62.0
55.0
58. 5
2/79 END DATE 2/79
THE S-1 NODULE EXPERIENCED PLUGGING PROBLEMS IN THE FIRST ANp SECOND
STAGE DURING FEBRUARY. ALSO DUE TO GAS LEAKAGE INTO THE MODULE CLEANING
HAS DELAYED.
2/79 END DATE 2/79
EXPANSION JOINT PROBLEMS AND BROKEN LINES WERE REPORTED.
2/79 END DATE 2/79
A LACK OF SCRUBBING MEDIUM DURING THE LATTER PART 0? FEBRUARY MAS REPORTED
BY THE UTILITY.
2/79 END DATE 2/79
THE S-2 MODULE PROBLEMS INCLUDED FROZEN VALVES AND LINES.
39.5
14.0
26.8
39.5
14.0
26.8
38.7
13.7
26.2
744 730
195 52.«
85
-------
EPA UTILITY F6D SURVEY: FEBRUARY - M«RfH 1979
SPRINGFIELD CITY UTILITIES (CONT.)
PERFORMANCE BAT A
>ERIOD NODULE AVAILABILITY OPE(J»BJL1T| RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
•• PROBLE4S/SOLUT10NS/CONNENTS
START DATE 3/79 END DATE 3/79
THE MAJORITY OF NODULE S-1 DOWNTIME HAS DUE TO • BROKEN SUPERNATE LINE AND
HAkEUP CROSS TIE.
START DATE 3/79 END DATE 3/79
THE UTILITY REPORTED THAT THE MODULE WAS UNABLE TO RUN FOR A TINE DUE TO
A DESI6N PROBLEM WITH A 500 HP MOTOR.
4/79 S-2 51.6 26.5 45.0 27.0
S-1 42.6 30.9 30.9 1*.5
SYSTEM 47.1 37.9 50.* 22.1* 720 432 164
• • PROBLEMS/SOLUTIONS/COMMENTS
START DATE 4/79 END DATE 4/7*
MODULE S-1 EXPERIENCED AN EXPANSION JOINT FAILURE ON THE 1.0. FAN DIS-
CHARGE.
START DATE 4/79 END DATE 4/79
L0» DENSITY AT THE SLURRY HOLD TANK HAS A NAJOR PROBLEM.
START DATE 4/79 END DATE 4/79
SOME PLUGGING OF THE FIRST STAGE OF THE S-2 NODULE WAS REPORTED BY THE
UTILITY.
86
-------
EPA UTILITY F£D SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN ANO PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NU«BER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - HW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
•* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SOZ DESIGN REMOVAL EFFICIENCY - Z
PARTICIPATE DESIGN REMOVAL EFFICIENCY
TENNESSEE VALLEY AUTHORITY
SHAUNEE
10A
PADUCAH
KENTUCKY
10.0
10.0
10.0
(**••** BTU/LB>
COAL
BITUMINOUS
•*•*«•
**•*•*••
• *******
2.90
********
UET SCRUBBING
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
RETROFIT
*******
4/72
• * /*•
»•*••**•
***** **•
______._-______.-___---.-_--._-__--_.---__p£ofOR1ANCE DATA-—--•
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
x REMOVAL
S02 PART,
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
0/79 SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
START DATE 0/72 END DATE 0/79
REFER TO PERFORMANCE UPDATE INFORMATION FOR SHAUNEE IOB,
87
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 3
OE$J6N AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mh
NET UNIT GENERATING CAPACITY W/F6D - MM
EQUIVALENT SCRUBBED CAPACITY - MU
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEV/RETROFU
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICIPATE DESIGN REMOVAL EFFICIENCY
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10P
PADUCAH
KENTUCKY
10.0
10.0
10.0
- Z
COAL
BITUMINOUS
•••**•
*****•**
2.90
••*•*»*•
MET SCRUBBING
LIME/LIMESTONE
CHEMICO
RETROFIT
*******
4/72
**/*•
••**••*•
•***••*•
(****** BTU/LB>
—PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
Z REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTE"
672
744
•• PROdLE'S/SOLUTlONS/COMMENTS
START DATE 2/79 END DATE 3/79
ONE TEST RUN WAS CONDUCTED ON EACH OF THE TVO SCRUBBER SYSTEMS IN
EABLY FEBRUARY TO PROVIDE SAMPLES FOR LEVEL 1 BIOASSY TESTING BY LITTON
BIONETICS CORPORATION UNDER CONTRACT WITH EPA. ACTUAL SAMPLING OF SCUR-
RIES AND CONOENSATES FROM THE SCRUBBER AND OXIDATION TANK OFF-GASES WAS
PERFORMED BY BATTELLE COLUMBUS LAPROATORV. FOR THIS PURPOSE. THE TCA WAS
OPERATED WITH LINESTONE/FLYASH SLURRY AS A BASE CASE. AND THE VENTURI/
SPSAY TOWER HAS OPERATED WITH LIMESTONE/FLVASH SLURRY AND WITH AD1PIC
ACID ADDITIVE AND TWO-SCRUBBER-LOOP FORCED OXIDATION.
A SERIES OF TESTS WAS CONDUCTED ON THE VENTURI/SPRAY TOWER SYSTEM FORM
MID-FEBRUARY THROUGH THE END OF MARCH TO SIMULATE THE PLANNED TVA WIDOWS
CREEK UNIT E FULL-SCALE. TWO-SCRUBBER-LOOP FORCED-OXIDATION SCHEME.
SPECIAL WIDOWS CREEK LIMESTONE (STONEMAN) AND COAL (PITTSBURGH MIDWAY)
WERE USED AT SHAWNEE DURING THESE TESTS. NEAR COMPLETE SULFITE OXIDATION
WAS ACHIEVED AT OXIDATION TANK PH UP TO 6.0 AND AN AIR STOICHIOMETRY AS
LOU AS 1.5 ATOMS OXYGEN/ MOLE soa ABSORBED. EXPECTED SLURRY CARRY-OVER
FROM THE FIRST TO THE SECOND SCRUBBER LOOP AT WIDOWS CREEK WAS SIMULATED
BY AN ARTIFICIAL BACKMIX STREAM OF UP TO 65 «PM.
A NEW LIME/ADIPIC ACID TEST BLOCK WITH AND WITHOUT FORCED OCIDATION
BEGAN IN EARLY FEBRUARY ON THE SINGLE-LOOP TCA SYSTEM USING FLUE GAS WITH
HIGH FLYASH LOADINGS. AT TCA INLET PH OF 7.0. 2400 TO 2900 PPM INLET $02.
L/G OF 50 GAL/ MCF. AND 15 INCHES TOTAL STATIC BED HEIGHT OF 1-7/8 INCH
NITRILE FOAM SPHERES. S02 REMOVALS WERE 83, 93, AND 97 PERCENT WITH ZERO,
60o« AND 1203 PPM ADIPIC ACID, RESPECTIVELY* JiTHOUT FORCED OXIDATION.
502 REMOVAL REMAINED HIGH AT 91 PERCENT WITH 1200 PPM ADIPIC ACID WHEN L/C
WA$ REDUCED FROM 50 TO 37 GAL/HCF. WHEN OXIDATION WAS FORCED WITH ABOUT
l.fc AIR STOfCHlONETRY, NEAR COMPLETE SULFITE OXIDATION WAS ACHIEVED AT
OXIDATION TANK PH (TCA INLET PH) UP TO ABOUT S.5, AND 1200 PPM ADIPIC
-------
EPA UTILITY FGO SURVEY: FEBRUARY - MARCH 1979
TENNESSEE VALLEY AUTHORITY
-------
EPA UTILITY FuD SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F«0 SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/fSD • MW
EQUIVALENT SCRUBBED CAPACITY - "M
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 2
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• DISPOSAL
TYPE
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
BRIDGEPORT
ALABAMA
550.0
516.0
550.0
( 10000 BTU/LB)
COAL
•*•**•
23260.
25.00
10.00
4.30
.**»•**•
HET SCRUBBING
LIMESTONE
TENNESSEE VALLEY AUTHORITY
RETROFIT
•••••**
5/77
1/78
BO.00
X 99.50
POND
"ERIOD NODULE AVAILABILITY OPERABIL1TY
PERFORMANCE DATA
RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTE"
3/79 SYSTEM
672
744
•• PROBLEMS/SOLUTIONS/COMMENTS
STAUT DATE
START DATE
2779 END DATE 3/79
CONSTRUCTION OF THE FORCED OXIDATION TEST WAS COMPLETED AND THE TESTING
HAS BEGUN ALTHOUGH NO RESULTS ARE YET AVAILABLE (THIS TESTING IS BEING
DONE ON ONE OF THE FOUR NODULES).
END DATE 3/79
THE UNIT OUTAGE WHICH BEGAN IN OCTOBER AND WAS SCHEDULED TO END IN FEB-
RUARY CONTINUED THROUGH MARCH BECAUSE AFTER A FEW START-UPS THERE
WERE BOILER AND TURBINE FAILURES.
-------
EPA UTILITY FGO SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESJ&N AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - *b
NET UNIT GENERATING CAPACITY U/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - MM
•• FUEL DATA
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 2
AVERAGE CHLORIDE CONTENT - X
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO2 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• HATER LOOP
TYPE
FRESH MAKE-UP »ATER - LITER/S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
TEXAS UTILITIES
HARTIN LAKE
1
TATUM
TEXAS
793.0
750.0
595.0
COAL
LIGNITE
17166.
8.00
32.00
.90
**•••**«
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
1.3
4/77
8/77
••*•»•••
99.40
( 7380 BTU/LB)
CLOSED
34.6
( 550 6PM)
FLYASH STABILIZED
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA9ILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
START DATE
672
744
720
2/79 END DATE 4/79
UNIT 1 IS NO* IN FULL OPERATION ALTHOUGH A SLUDGE DISPOSAS PROBLEM STILL
EXISTS.
START DATE 2/79 END DATE 4/79
THE UTILITY HAS CHANGED THE LOUVER DAMPERS WITH GUILLOTINE DAMPERS WHICH
SEE" TO WORK BETTER. HOWEVER* THEV STILL HAVE PROBLEMS WITH THE GUIL-
LOTINE DAMPERS FAILING TO SEAL WHEN THEY BECOME SCALED
START DATE 2/79 E"D DATE 4/79
THERE MAS BEEN REPORTS OF TOWER LEAKS* FROM LlNER FAILURE BUT IT DOESN'T
SEEM TO BE SERIOUS.
91
-------
EPA UTILITY ftoO SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - 1W
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEV/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIbN RErOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
•« HATER LOOP
TTPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
** DISPOSAL
TTPE
TEXAS UTILITIES
MARTIN LAKE
2
TATUM
TEXAS
793.0
750.0
595.0
COAL
LIGNITE
17166.
8.00
33.00
.90
•••**••*
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
1.3
5/78
t 7380 BTU/LB>
- Z
99.40
CLOSED
3*.6
( 550 6PM)
FLYASH STABLIZATION
LANDFILL
PERFORMANCE DATA — — —
PERIOD NODULE AVAILABILITY OPERABIL1TV RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM " 672
3/79 SYSTEM 744
4/79 SYSTEM 720
•• PR06LE4S/SOLUTIONS/COMNENTS
START DATE 2/79 END DATE 4/79
THERE HAS BEEN REPORTS OF TOWER LEAKS* FROM LINER FAILURE BUT IT SOESN'T
SEEM TO BE SERIOUS.
START DATE 2/79 END DATE 4/79
UNIT 1 IS NOtf IN FULL OPERATION ALTHOUGH A SLUDGE DISPOSAL PROBLEM STILL
EXISTS.
START DATE 2/79 END DATE 4/79
THE UTILTIV HAS CHANGED THE LOUVER DAMPERS WITH GUILLOTINE DAMPERS WHICH
SEEM TO WORK BETTER. HOWEVER. THEY STILL HAVE PROBLEMS WITH THE 6UIL-
LOTINE DAMPERS FAILING TO SEAL WHEN THEY BECOME SCALED.
92
-------
UTxLiTY F60 SURVEY: FEBRUARY ~ MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL F6D SYSTEMS
COUPAMY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - N6/J
SOZ EMISSION LIMITATION - K6/J
NET PLANT GENERATING CAPACITY - Mw
GROSS UNIT GfcNERATlNG CAPACITY - MM
NET UNIT GENERATING CAPACITY U/F6D - "H
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
•• 30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOM - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - N
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
RANGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - Z
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MH
•• ESP
NUMBER
TTPE
SUPPLIER
•* F6D SYSTEM
SALEABLE PRODUCT/THROWAUAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEU/RETROFIT
PARTICIPATE DESIGN REMOVAL EFFICIENCY
COMMERCIAL DATE
INITIAL START-UP
*• ABSORBER
NUMBER
TYPE
INITIAL START UP
NUMBER OF STAGES
BOILER LOAD/ABSORBER - Z
•• CENTRIFUGE
NUMBER
OUTLET SOLIDS - Z
•« MIST ELIMINATOR
NUMBER
TYPE
NUMBER OF STAGES
TE*AS UTILITIES
MARTIN LAKE
3
TATUM
TEXAS
A
47.
516.
3000.0
793.0
750.0
760.0
595.0
COMBUSTION ENGINEERING
******
3ASE
• */••
( .100 L9/MMBTU)
( 1.200 LB/MMBTU)
••••****
*******
******
* **** **
COAL
LIGNITE
17166.
8.00
5.6-13.2
33.00
29.0-37.9
.90
0.5-1.5
********
******
453.5
**•••
(*••*••• »CFM)
<••*• F>
(••*• FT)
(•••** FT)
( 7360 BTU/LB)
6972-789*
(500 TPM)
COLD SIDE
RESEARCH-COTTRELL
THROUAUAY PRODUCT
MET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
FULL-SCALE
NEW
- Z 99.40
12/78
2/79
PACKED/SPRAY TOMER
12/78
3
12.5
69.Q
6
CHEVRON
2
93
-------
EPA UT1LITT fGD SURVEY: FEBRUARY - HA»CH 1979
TEXAS UTILITIES «CONT.>
PUMPS
SERVICE
FEED
ABSORBER FEED PUMPS
TANKS
SERVICE
ABSORBER FEED TANKS
REHEATER
TYPE
THICKENER
NUMBER
TTPE
DIAMETER - *
OUTLET SOLIDS - S
TREATMENT
TYPE
SUPPLIER
DISPOSAL
NATURE
TTPE
LOCATION
TRANSPORTATION
NUMBER
• •*•
• •*•
NUMBER
3
BTPASS
GRAVITY
42.7
35.0
1140 FT)
FLYASH STABILIZATION
NONPROPRIETARY
FINAL
LANDFILL
ON-SITE
RAIL
. .—. -PERFORMANCE DATA — ._„_.— .
PERIOD MODULE AVAILABILITY OPERABUITT RELIABILITY UTILIZATION s REMOVAL
S02 PART.
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
3/79 SYSTEM
4/79 SYSTEM
744
720
• • PROBLEMS/SOLUTIONS/COMMENTS
START DATE 3/79 END DATE 4/79
MARTIN LAKE UNIT 3 BECAME OPERATIONAL DURIN6 MARCH. NO OPERATION DE-
TAILS ARE VET AVAILABLE.
-------
EPA UTILITY FGD SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - PU
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 1
AVERAGE CHLORIDE CONTENT - I
• * FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
•• HATER LOOP
TYPE
FRESH MAKE-UP taATER - LITER'S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
TEXAS UTILITIES
MONTICELLO
3
*T. PLEASANT
TEXAS
800.0
750.0
800.0
COAL
LIGNITE
•*»••*
ie.9o
1.50
.04
MET SCRUBBING
LIMESTONE
CHEMICO
NEW
*••**••
5/7?
10/78
74.00
99.50
CLOSED
34.4
(*•***• BTU/LB)
( 546 6P«)
FLYASH STABILIZED
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION i REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
Z/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
•• PRObLEHS/SOLUTIONS/COMMENTS
672
744
720
START DATE 2/79 END DATE 4/79
THE UNIT IS CURRENTLY OOUN FOR A SCHEDULED OVERHAUL. THE TOWfRS HAVE
BEEN INSPECTED AND NO SCALING MAS FOUND.
START DATE 2/79 END DATE 4/7"
SOCE MINOR FECYCLE PU*P LINER PROBLEMS HAVE BEEN REPORTED.
95
-------
FPA UTILITY FbD SURVEY: FEBRUARY - MARCH 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOi EMISSION LIMITATION - S6/J
NET PLAUT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - MW
NET UNIT GENERATING CAPACITY UO/F6D - MU
EQUIVALENT SCRUBBED CAPACITY - MU
•• BOILED DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAt FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - *
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANGE HEAT CONTENT - 6TU/16
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTJRE CONTENT - 2
AVERAGE SULFUR CONTENT - I
RANGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - 1 T/H
FUEL FIRING RATE - MU
UTAH POKER t LIGHT
HUNTER
1
CASTLE DALE
UTAH
A
•••••* <•••••• LB/MHBTU)
•****• <•••••• LB/MMETU)
•***•**
400.0
400.0
360.0
•••*•*
•*•••*
BASE
• •/•*
••**•*••
COAL
29075.
10.00
9-12
6.50
••••*•
.55
*•«
« *
•••••
(«•«**•• ACFM)
(**** f)
(•••• FT)
(••«** FT>
( 12500 BTU/LB)
12,200 - 12.700
(•*• TPH)
•• ESP
NUMBER
•• F6D SYSTEM
SALEABLE PRODUCT/THROWAUAY PRODUCT
.GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
soz DESI&N REMOVAL EFFICIENCY - t
COMMERCIAL DATE
INITIAL START-UP
•• ABSORBER
INITIAL START UP
SUPPLIER
•• REHEATER
TYPE
•• MATER LOOP
TfPE
•• TREATMENT
TYPE
•• DISPOSAL
ftATURE
TYPE
THROVAMAY PRODUCT
UET SCRUBBING.
LIME
CHE"ICO
STEARNS I ROGER
FULL-SCALE
NEK
- X 99.50
80.00
3/79
5/79
12/78
CHEMICO
BYPASS
OPEN
FLVASH STABILIZATION
FINAL
POND
96
-------
EPA UTILITY FED SURVEY: FEBRUARY - MARCH 1979
UTAH POKER I LI6HT (CONT.)
LOCATION ON-SITE
PERFORMANCE OAT A
PERIOD MODULE AVAILABILITY OPEPABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/79 STSTE" 74*
• * PROoLfcMS/SOLUT10NS/COri»ENTS
START DATE 5/79 END DATE 5/79
THE UNIT STARTED OPERATIONS ON «AY 21, 1979.
97
-------
EP« UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 3
OESJ6N AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mto
NET UNIT GENERATING CAPACITY W/FGO - Mh
EQUIVALENT SCRUBBED CAPACITY - MW
• • FUEL DATA
FUEL TVPt
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - 1
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PAftTKULATE DESIGN REMOVAL EFFICIENCY
•• MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
*• DISPOSAL
TYPE
UTAH POWER ft LIGHT
HUNTIN6TON
1
PRICE
UTAH
430.0
400.0
366.0
COAL
•*••••
29075.
10.00
6.50
.55
••***•••
WET SCRUBBING
LIME
CHENICO
NEW
••**«••
5/78
*•/*•
80.00
99.50
CLOSED
1P.9
( 12500 BTU/LB)
( 300 6PM)
NONPROPRIETARV FLVASH STABILIZED
LANDFILL
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPEPABIL1TY RELIABILITY UTILIZATION
Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
• • PRObLEMS/SOLUTIOMS/COMMfNTS
START DATE
672
7*4
2/79 END DATE 3/79
NO INFORMATION HAS REPORTED BY THE UTILITY FOR THIS REPORT PERIOD.
98
-------
EPA UTILITY F6C. SURVEY: FEBRUARY - NAPCH 1979
SECTION 4
SUMMARY OF F6D SYSTEMS BY COMPANY
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT PLANNED
AWARDED
COMPANY NAME
ALABAMA ELECTRIC COOP
ALLEGHENY POWER SYSTEM
ARIZONA ELECTRIC POWER COOP
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC COOP
BASIN ELECTRIC POWER COOF
BIG RIVERS ELECTRIC
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC iERV
CENTRAL MAINE POWER
CINCINNATI 6 AS * ELECTRIC
COLORADO UTE ELECTRIC ASSN.
COLUMBUS t, SOUTHERN OHIO ELEC.
COMMONWEALTH EDISON
COOPERATIVE POWER ASSOCIATION
DELMARVA POWER | LIGHT
DU6UESNE LIGHT
EAST KENTUCKY POWER COOP
GENERAL PUBLIC UTILITIES
GULF POWER
HOOSIER ENERGY
HOUSTON LIGHTING K P04ER CO.
INDIANAPOLIS POWER 8 LIGHT
KANSAS CITY POWER I LIGHT
KANSAS POWER t LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LOUISVILLE GAS I ELECTRIC
MIDDLE SOUTH UTILITIES
MINNESOTA POWER I UlfcHT
MINNKOTA POWER COOPERATIVE
MONTANA POWER
HUSCATINE POWER I WATER
NEVADA POWER
NIAGARA MOHAWK POWER COOP
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
OTTER TAIL POrfER
PACIFIC GAS i, ELECTRIC
PACIFIC PO«ER t LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
POTOMAC ELECTRIC POWER
POWER AUTHORITY OF NEW YORK
PUBLIC SERVICE OF INDIANA
PUBLIC SERVICE OF NEW MEXICO
SALT RIVER PROJECT
SAN MIGUEL ELECTRIC COOP
SEMlNOLe ELECTRfC
SIKESTON POARD OF MUNIC. UT1L.
SOUTH CAROLINA PUBLIC SERVICE
SOUTHERN CALIFORNIA EDISON
SOUTHERN ILLINOIS POwER COOP
SOUTHERN INDIANA GAS 1 ELEC
SOUTHERN MISSISSIPPI ELECTRIC
SOUTHWESTERN ELECTRIC POWER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER. LIGHT i PWR
ST. JOE ZINC
TANPA ELECTRIC
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER t LIGHT
TEXAS UTILITIES
UTAH POWER I LIGHT
NO.
t
J
2
t
1
r
./
2
2
1
1
1
2
4
1
t
1
2
1
2
1
2
1
2
i
t
1
1
10
t
1
1
t
1
10
1
c
T
1
i
1
7
l>
1
1
1
t
3
1
1
1
T
1
2
1
&
1
1
1
1
1
e
1
s
E
t
• w
ise.
1338.
390.
2684.
670.
2660.
464.
832.
617.
toe.
650.
894.
1572.
ISO.
654.
UO.
920.
500.
1600.
23.
882.
512.
1062.
1054.
1575.
64.
364.
3533.
5340.
475.
405.
2120.
1tO.
3125.
100.
1547.
2340.
440.
1600.
550.
2751.
844.
800.
700.
650.
1779.
840.
400.
620*
235.
700.
175.
484.
265.
248.
720.
194.
205.
60.
450.
3753.
400.
1882.
5585.
1086.
NO.
1
1
1
2
0
0
0
1
0
0
0
0
2
0
0
0
2
0
0
1
0
0
1
3
3
1
0
5
0
0
1
2
0
3
0
1
2
0
0
0
2
1
0
0
0
2
0
0
0
0
1
0
0
1
1
0
1
0
0
0
3
0
0
4
2
MW
179.
519.
195.
469.
0.
0.
0.
416.
0.
0.
0.
0.
022.
0.
C.
0.
920.
0.
0.
23.
0.
0.
532.
1054.
1085.
64.
0.
1180.
0.
0.
405.
720.
0.
375.
0.
115.
1480.
0.
C.
C.
1834.
120.
0.
0.
0.
711.
0.
0.
0.
0.
140.
0.
0.
2«5.
124.
0.
194.
0.
0.
0.
570.
0.
0.
258S.
726.
NO.
1
1
1
4
0
2
2
0
1
0
1
2
0
1
2
1
0
0
0
0
2
0
1
0
1
0
0
2
0
1
0
0
0
0
0
0
0
1
0
1
1
0
0
0
0
1
2
1
0
1
1
0
1
0
1
0
0
1
1
0
1
0
1
0
1
HW
179.
519.
195.
705.
C.
1200.
484.
0.
617.
0.
650.
894.
0.
450.
654.
160.
0.
0.
0.
0.
882.
0.
530.
0.
490.
0.
0.
853.
0.
475.
0.
C.
0.
0.
c.
0.
0.
440.
c.
550.
917.
0.
0-
0.
0.
534.
560.
400.
0.
235.
280.
0.
184.
0.
124.
0.
0.
205.
60.
0.
575.
0.
382.
0.
360.
NO.
0
0
0
2
1
2
0
0
0
0
0
0
0
0
0
0
c
1
0
0
0
0
0
0
0
0
1
1
0
0
0
2
0
0
1
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
1
1
0
0
0
1
0
0
0
0
2
1
0
1
0
Hrf
0.
0.
0.
1510.
670.
1040.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
500.
0.
0.
0.
0.
0.
0.
0.
0.
364.
350.
0.
0.
0.
1400.
0.
0.
100.
0.
0.
0.
0.
0.
0.
0.
0.
c.
0.
534.
0.
0.
0.
0.
280.
175.
0.
0.
0.
720.
0.
0.
0.
0.
1408.
400.
0.
750.
0.
NO.
0
1
0
0
0
1
0
1
0
1
0
0
2
0
0
0
0
0
2
0
0
1
3
0
0
0
0
2
6
0
0
0
1
7
0
4
1
0
2
0
0
3
1
1
1
0
1
0
1
0
0
0
1
D
0
0
0
0
0
1
2
0
2
3
0
*.
r.
300.
C.
c.
r.
*4C.
C.
416.
0.
tuo.
c.
0.
7SO.
C.
r.
c.
0.
c.
16CC.
c.
0.
512.
0-
0.
0.
C.
p.
1150.
5340.
C.
r.
c.
160.
275C.
C.
1432.
f t C-
0.
ieoo.
0.
0.
72*.
800.
700.
65C.
p.
2fcC.
0.
62o*
0.
0-
O
ICC.
o.
C'
c.
0.
0.
0.
450.
1200.
0.
15QO.
2250.
0.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT sib
AND CONSIDERING ONLY F6D SYSTEMS
NED, REQUESTING/EVALUT1NG BIDS,
99
-------
EPA UTILITY fbD SURVEY: FEEfcUARY - KARCM 1979
SECTION 4
SUHFARV OF 160 SYSTEMS BY COMPANY
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT PLANNED
AWARDED
COMPANY NAME NO. "U NO. NW NO. Mfc NO* MW NO. MM
MISCONSIK POMER . LI6HT 1 ?16. 0 0. 0 0* 1 316. 0 0.
TOTALS 162 71486. SI 178Z2. 42 1S763. 20 10517. 49 27384.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIC N£D. RE8UESTINS/EVALUTIN6 BIOS.
AND CONSIDERING ONLY FED SYSTEMS
100
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 5
SUP-MARY OF FGD SYSTEMS BY SYSTEM SUPPLIER
TOTAL
SYSTtM SUPPLIER/PROCESS
AOL/COMBUSTION EBU1P ASSOCIATE
DUAL ALKALI
LIME
LIKE /ALKALINE FLYASH
SODIUM CARBONATE
TOTAL -
AIR CORRECTION DIVISION. UOP
LICE
LIMESTONE
LIME /LIMESTONE
SODIUM CARBONATE
TOTAL -
AMERICAN AIR FILTEF
LIME
LIMESTONE
TOTAL -
BABCOCK B VILCOX
LIME
LIMESTONE
LIME/SPRAY DRYING
TOTAL -
BUELL/ENVIRGTECH
DUAL ALKALI
TOTAL -
BUREAU OF MINES
CITRATE
TOTAL -
CHE M CO
LIME
LIMESTONE
LIME/ALKALINE FLYASH
LIME/LI1ESTONE
TOTAL -
CHIYODA INTERNATIONAL
UMESTONE/THOROU6HERED 121
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME /LIMESTONE
TOTAL -
DAVY POWER6AS
UELLMAN LORD
TOTAL -
FMC CORPORATION
DUAL ALKALI
TOTAL -
JOY MFG. CO. WESTERN PRECIP1TA
LlME/SpRAY DRYING
TOTAL -
NO.
1
3
3
3
10
2
4
1
1
b
6
1
7
3
7
1
11
1
1
1
1
7
1
4
1
13
1
1
6
7
2
2
17
6
6
1
1
1
1
MM
288.
1220.
1805.
375.
36SB.
£22.
1896.
10.
550.
3278.
1673.
280.
1953.
1688.
2477.
600.
4765.
617.
617.
60.
60.
3840.
800.
895.
10.
5545.
23.
23.
1096.
2932.
1480.
708.
6216.
2074.
207*.
265.
265.
440.
440.
OPERATIONAL
NO.
1
2
1
i
7
2
2
1
0
5
3
C
3
1
2
0
3
0
0
0
0
6
1
0
1
8
1
1
4
3
2
0
9
3
3
1
1
0
0
Mh
2fc8.
720.
405.
375.
1788.
822.
726.
10.
0.
1558.
694.
0.
694.
51«.
1014.
0.
1533.
0.
0.
0.
0.
3460.
600.
0.
10.
4290.
23.
23.
442.
1065.
1480.
0.
3007.
826.
826.
265.
265.
0.
0*
CONSTRUCTION
NO*
0
0
0
0
0
0
1
0
1
2
3
0
3
2
4
0
6
1
1
1
1
1
0
3
0
4
0
0
2
3
0
1
6
z
2
0
0
0
0
MW
0.
0.
0.
0.
0.
0.
450.
0.
S5C.
1000.
979.
0.
979.
1169.
1099.
0.
2268.
617.
617.
60.
60.
360.
0.
579.
0.
939.
0.
0.
654.
1447.
0.
358.
2459.
714.
714.
0.
0.
0.
0.
CONTRACT
AWARDED
NO.
0
1
2
0
•»
0
1
0
0
1
0
1
1
0
1
1
2
0
0
0
0
0
0
1
0
1
0
0
0
1
0
1
2
1
1
0
0
1
1
MW
0.
SOD-
1*00.
0.
1900.
0.
720.
0.
0.
720.
0.
280.
280.
0.
364.
600.
964.
0.
0.
0.
0.
0.
0.
316.
0.
316.
0.
0.
0«
400.
0.
350.
7SQ.
534.
534.
0>
0.
440.
440.
101
-------
?PA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 5
SUMMARY OF F6D SYSTEMS BY SYSTEM SUPPLIER
TOTAL
SYSTEM SJPPLIER/PROCESS
•ITSUelSHI INTERNATIONAL
LIPESTOVE
TOTAL -
PEAEODY PROCESS SYSTEMS
LIMESTONE
LIM- /ALKALINE FLYASH
TOTAL -
PULLMAN KEiLOec
LIPE
LIMESTONE
TOTAL -
RESEARCH COTTRELL
LIMESTONE
TOTAL -
RILEV STOKER/ENVIRONEERING
LIMESTONE
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE
TOTAL -
SO. CALIFORNIA ED IS ON/STEAfthS-
LIME
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
LIME
MACNESIUM OXIDE
TOTAL -
VENDOR NOT SELECTED
LIMESTONE
TOTAL -
WHEELABRATOR-FRVt/R.I.
AQUEOUS CARBONATE/SPRAY DRYIN6
TOTAL -
NO.
2
i
It
1
5
1
3
*
13
13
3
3
1
1
1
1
1
1
2
1
3
2
2
1
1
MM
682.
£82.
1252.
*75.
1727.
917.
1230.
2147.
5*55.
5455.
664.
664.
100.
100.
175.
175.
550.
550.
1510.
120.
1630.
1408.
1408.
440.
440.
OPERATIONAL
NO.
0
0
1
0
1
0
0
0
6
6
2
2
0
0
0
0
1
1
0
1
1
0
0
0
0
Mtt
0.
0.
179.
0.
179.
0.
0.
0.
2449.
2449.
5*0.
540.
0.
0.
0.
0.
550.
550.
0.
120.
120.
0.
0.
0.
0.
ST
CONST
NO-
2
2
3
1
4
1
2
3
6
6
1
1
0
0
0
0
0
0
0
0
0
0
0
1
1
RUCTION
NU
882.
882.
1073.
475.
1548.
917.
560.
1477.
2256.
2256.
124.
12*.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
440.
440.
CONTRACT
AWARDED
NO.
0
0
0
0
0
0
1
1
1
1
0
0
1
1
1
1
0
0
2
0
2
2
2
0
0
MU
0.
0.
0.
0.
0.
o.
670.
670.
750*
750.
0.
0.
100.
100.
175.
175.
0.
0.
1510.
0.
1510*
1408.
1408.
o.
0.
TOTAL -
113 4*102.
51 17822.
42 15763.
20 10517.
102
-------
EPA UTILITY FGD SURVEY: FEBRUARY - MARCH 1979
SECTION 6
SUMARY OF F6D SYSTEMS BY PROCESS
TOTAL
OPERATIONAL
STATUS
CONSTRUCTION CONTRACT
AWARDED
PLANNED
PROCESS
AQUEOUS CARBONATE
CITRATE
LIMESTONE/THOROUGHtRtD 121
MAGNESIUM OXIDE
WELLMAN LORD
SUBTOTAL - SALEABLE PRODUCT
ABUEOUS CARBONATE/SPRAY DRYING
DUAL ALKALI
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLYASH
II ME /LIMESTONE
LIME/SPRAY DRY1N6
PROCESS NOT SELECTED
SODlUfl CARBONATE
SUBTOTAL - THROUAUAY PRODUCT
TOTALS
SALEABLE X OF TOTAL HU
NO.
1
1
1
5
6
14
1
T
31
57
t
E
5
2
3S
4
14E
162
MW
100.
60.
23.
1444.
2074.
3701.
(40.
1170.
12941.
25614.
1480.
3175.
1328.
1040.
19672.
925.
67785.
71486.
5
NO.
0
0
1
1
3
5
0
2
18
18
2
1
2
0
0
3
46
51
HU
0.
0.
23.
120.
826.
969.
0.
553.
6677.
7343.
1480.
405.
20.
0.
0.
375.
16653.
17822.
5
NO.
0
1
0
0
2
3
1
1
9
22
0
4
1
0
0
1
39
42
MM
0.
60.
0.
0.
714.
774.
440.
617.
4079.
7891.
0.
1054.
358.
0.
0.
550.
14989.
15763.
5
NO-
1
0
0
0
1
2
0
0
4
8
0
3
1
2
0
0
18
20
MH
100.
0.
0.
0.
534.
634.
0.
0.
2185.
4592.
0.
1716.
350.
1040.
0.
0.
9883.
10517.
6
NO.
0
0
0
4
0
4
0
0
0
9
0
0
1
0
35
0
45
49
RW
0.
0.
0.
1324.
C.
1324.
0.
0.
0.
57e«.
0.
o.
toe.
0.
19672.
0.
26060.
27384.
C
103
-------
EPA UTILITY F60 SURVEY: FEBRUARY - HAKCH 1979
SECTION 7
SUMMARY OF OPERATIONAL FBO SYSTEMS BY PROCESS AND UNIT
PROCESS'
UNIT NAME
DUAL ALKALI
«.B. BROWN
CANE RUN
LIME
BRUCE MANSF IELD
9RUCE MANSFIELD
CANE RUN
CANE RUN
COLSTRIP
COLSTRIP
CONESVILLE
CONESVILLE
ELPAHA
SREEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTIN6TON
MILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANT;
LIMESTONE
APACHE
CHOLLA
CHOLLA
DUCK CREEK
JEFFREY
LA CV6NE
LAWRENCE
LAWRENCE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MONTICELLO
PETERSBURG
R.D. MORROW
SOUTHWEST
TOMBI6BEE
WIDOWS CREEK
UINVAH
LIMESTONE/ALKALINE FLY*
SMERBURNE
SHERBURNE
LIME STONE /THOROUGHBRED
SCHOLZ
LIME/ALKALINE FLYASH
MILTON R. YOUNG
LIME/LIMESTONE
SHAWNEE
SHAWNEE
UNIT NO*
1
6
1
2
4
5
1
2
5
6
1-4
1-3
3
4
1
1
3
6
1-6
1
2
1
2
1
1
1
4
5
1
2
3
3
3
1
1
2
8
2
ISH
1
2
121
1.2
2
10A
106
CAPACITY
MW
265.
288.
553.
917.
917.
18fc.
190.
360.
360.
411.
411.
510.
64.
90.
90.
360.
366.
442.
72.
410.
519.
6677.
195.
119.
350.
416.
540.
874.
125.
420.
595.
595.
595.
800.
532.
124.
194.
179.
55Q.
140.
7343.
740.
740.
1480.
23.
23.
405.
405.
10.
10.
INITIAL
STARTUP
3/79
3/79
12/75
7/77
8/76
12/77
9/75
5/76
1/77
6/78
10/75
9/75
11/72
8/72
5/79
5/78
8/78
4/73
7/73
3/79
8/78
10/73
4/78
7/76
8/78
2/73
1/76
11/71
4/77
5/78
2/79
5/78
12/77
8/78
4/77
9/78
5/77
7/77
3/76
4/77
•>-' if. >- •
8/78
9/77
4/72
4/72
COMMERCIAL
STARTUP
O/ 0
O/ 0
6/76
10/77
9/77
5/79
11/75
10/76
2/77
6/78
10/75
6/76
O/ 0
O/ 0
3/79
O/ 0
3/79
O/ 0
O/ 0
3/79
1/79
12/73
O/ 0
8/78
8/78
6/73
O/ 0
O/ 0
8/77
O/ 0
12/78
10/78
12/77
QJ. 0
O/ 0
O/ 0
1/78
O/ 0
5/76
4/77
'.i' «?*(,;•,
O/ 0
6/78
O/ 0
O/ 0
104
-------
£P» UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 7
SUMMARY or OPERATIONAL FCD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
UNIT NO.
CAPACITY
MM
INITIAL
STARTUP
COMMERCIAL
STARTUP
MAGNESIUM OXIIE
EODVSTONE
SODIUM CARBONATE
REID GARDNER
REID GARDNER
REID GARDNER
1A
20.
120.
120.
125.
125.
125.
9/75
4/7*
4/74
6/76
9/75
01 0
O/ 0
7/76
375.
UELLPAN LORD
DEAN H. MTCHELL
SAN JUAN
SAN JUAN
11
1
2
115.
361.
350.
626.
7/76
4/7J
8/78
6/77
O/ 0
O/ 0
TOTAL
17822.
105
-------
EPA UTILITY F 6D SURVEY: FEBRUARY - f*RCM 1979
SECTION 8
SU«M»RV Of ENb-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL F60 SYSTEMS
PROCESS/
UNIT NAME
THROWAUAV
UNIT NO STAbILI2ED UNSTAGIL1ZED
TYPE
-BYPRODUCT
DISPOSITION
DUAL ALKALI
• .B
CANE RUN
LIME
?RUCE MANSFIELD
=»RUCE MANSFIELD
CANE RUN
CANE RUN
COLSTRIP
COLSTRIP
CONESVILLE
CONESVILLE
f L"AMA
5REEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTIN6TON
•ILL CREEK
BADDY'S RUN
PHILLIPS
"LEASANTS
LIMESTONE
APACHE
CHOLLA
CHOLLA
DUCK CREEK
JEFFREY
LA CV6NE
LAURENCE
LAURENCE
•ARTIN LAKE
4ARTIN LAKE
MARTIN LAKE
•ONTI CELLO
BETERSBUR6
».D. MORROW
SOUTHWEST
TOMfclGBEE
WIDOWS CREEK
WINYAH
LIMESTONE/ALKALINE
SHER9URHE
SHER9URNE
1
i
4
5
1
L
5
6
1-*
i-:
3
4
1
1
3
6
1-6
1
2
1
2
1
1
1
4
5
1
^
3
3
3
1
1
2
6
2
FLTASH
1
2
Ll'tSTONE/THOROUSHBRED 121
SCHOL2 1.2
LIME/ALKALINE FLYASH
•1LTON R. YOUNG i
LIME/LIMESTONE
SHAkNEE
SHAMNEE
«A6NEsIu
-------
EPA UTILITY FED SURVEY: FEBRUARY • PARCH 1979
SECTION e
SU*HARV OF EtiD-P'ODUCT DISPOSAL PRACTICES FOR OPERATIONAL f60 SYSTEMS
PROCESS/
UNIT NAHE
... THROWAUAY
UNIT NO STfttlLIZED UNSTABIL12ED
TYPE
-EiYpRODuCT-
OlSPOSITjON
SODIUM CARBONATE
REID 6ARDNFR 1
REID GARDNER Z
REID 6ARDNER i
WELLXAN LORD
DEAN H. MITCHELL 11
SAN JUAN 1
SAN JUAN i
tVAP POND
(VAP POND
EWAP POND
ASH POND
ASH POND
LLEMENTAL SULFUR
ELEMENTAL SULFUR
ELEMENTAL SULFUR
•ARKETED
•ARKETED
107
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME DMT NO.
ILAB«HA ELECTRIC COOP
TONBI6BEE i
ALLE6HENV POWER SYSTEM
PLEASANTS 1
ARIZONA ELECTRIC POtaER COOP
APACHE i
ARIZONA PUBLIC SERVICE
CHOLLA 1
ARIZONA PUBLIC SERVICE
CHOLLA 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
COLUMBUS I SOUTHERN OHIO ELEC.
CONESVILLE 5
COLUMBUS fc SOUTHERN OHIO ELEC.
CONESVILLE 6
DUOUESNE LI6HT
ELRA'A 1-4
DUBUESNE LIGHT
PHILLIPS 1-6
6ULF POWER
SCHOLZ 1.2
INDIANAPOLIS POWER t LIGHT
PETERSBURG 3
KANSAS CITY POWER t LIGHT
HAWTHORN 3
KANSAS CITY POWER I LIGHT
HAWTHORN 4
KANSAS CUT POKER i LIGHT
LA CTGNE 1
KANSAS POWER ft LIGHT
JEFFREY 1
KANSAS POWER t LIGHT
LAWRENCE 4
KANSAS POWER t LIGHT
LAWRENCE 5
KENTUCKY UTILITIES
GREEH RIVER 1-3
LOUISVILLE GAS t ELECTRIC
CANE RUN 4
LOUISVILLE GAS t ELECTRIC
CANE RUN 5
LOUISVILLE GAS t ELECTRIC
CANE RUN e
LOUISVILLE GAS t ELECTRIC
KILL CREEK 3
LOUISVILLE GAS t ELECTRIC
NEW OR
RETROFIT
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NED
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
CAPACITY
MW
179.0
519.0
195.0
119.0
550.0
416.0
411.0
411.0
510.0
410.0
23.0
532.0
90.0
90.0
874.0
540.0
125.0
420.0
64.0
188.0
190.0
288.0
442.0
72.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
PEABOBV PROCESS SYSTEMS
LIME
PABCOCK t WILCOX
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RILEY STOKER/ENVIRONEERIN6
LIME
AIR CORRECTION DIVISION* UOP
LIME
AIR CORRECTION DIVISION* UOP
LIKE
CHEMICO
LIME
CHEHICO
LIMESTONE/THOROUGHBRED 121
CHlVODA INTERNATIONAL
LIMESTONE
AIR CORRECTION DIVISION* UOP
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK ( WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
DUAL ALKALI
ADl/COMBUSTlON EQ|jIP ASSOCIATE
LIME
AMERICAN AIR FILTER
LIME
START-UP
DATE
9/78
3/79
8/78
10/73
4 778
7/76
1/77
6/78
10/75
7/73
8/78
12/77
11/72
8/72
2/73
8/78
1/76
11/71
9/75
8/76
12/77
3/79
8/78
4/73
COMBUSTION ENGINEERING
108
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION "
SUMMARY OF F6D SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
•1NNKOTA POKER COOPERATIVE
"HTON R> YOUNG i
MONTANA POWER
COLSTRIP 1
MONTANA POWER
COLSTRIP 2
NEVADA POkER
REID GARDNER 1
NEVADA POWER
REID GARDNER i
NEVADA PO.ER
REID GARDNER 3
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
NORTHERN STATES POWER
SHERBUPNE 1
NORTHERN STATES POWER
SHERBURNE 2
PENNSYLVANIA POWER
3RUCE MANSFIELD 1
PENNSYLVANIA POWER
9RUCE MANSFIELD 2
PHILADELPHIA ELECTRIC
EDDVSTONE 1A
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN i
SOUTH CAROLINA PUBLIC SERVICE
WINVAH i
SOUTHERN INDIANA 6AS t ELEC
A .8. BROWN 1
SOUTHERN MISSISSIPPI ELECTRIC
R.D. MORROW 1
SPRjNtriEtD CITY UTILITIES
SOUTHWEST 1
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10*
TENNESSEE VALLEY AUTHORITY
SHAWNEE 106
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK t
TEXAS UTILITIES
MARTIN LAKE 1
TEXAS UTILITIES
MARTIN LAKE 2
TEXAS UTILITIES
MARTIN LAKE 3
NEW OR 1
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
CAPACITY
MW
405.0
360.0
360.0
125. C
125.0
125.0
115.0
740.0
740.0
917.0
917.0
120.0
361.0
350.0
140.0
265.0
124.0
194.0
10.0
10.0
550.0
595.0
S9S.O
595.0
PROCESS/
SYSTEM SUPPLIER
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
LICE
ADL/COMbUSTION E8UIP ASSOCIATE
LI»-E
ADL/COMBUSTION EOUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMEiUSTlON EaUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMbUSTION EOUIP ASSOCIATE
SODIUM CARBONATE
AOL/COMBUSTION EOUIP ASSOCIATE
•ELLMAN LORD
DAVY POMER6AS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME
CHEMICO
LIME
CHEMICO
MAGNESIUM OXIDE
UNITED ENGINEERS
WELLMAN LORD
DAVY POWER6AS
WELLMAN LORD
DAVY POWERGAS
LIMESTONE
BABCOCK t WILCOX
DUAL ALKALI
FHC CORPORATION
LIMESTONE
RlLEV SToKER/ENVlRONEERING
LIMESTONE
AIR CORRECTION DIVISION. UOP
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
CHEMICO
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
START-UP
DATE
9/77
9/75
5/76
4/74
4/74
6/76
7/76
3/76
4/77
12/75
7/77
9/75
4/78
8/78
7-777
3/79
8/78
4/77
4/72
4/72
5/77
4/77
5/78
2/79
109
-------
5PA UTILITY FGO SUPWt»: FEBRUARY - MRCH 1979
SECTION 9
SUMMARY OF F6D SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME
TEXAS UTILITIES
40NTICELLO
UTAH POWER & LI6HT
HUNTER
UTAH POkER fc LI6HT
HUNTIN6TON
UMT NO.
3
1
1
MEU OR
RETROFIT
NEb
NEW
NEU
CAPACITY
HU
BOO.O
360.0
366.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
CHEKICO
LIME
CHEMICO
LIME
CHEMICO
START-UP
DATE
5/78
5/79
5/78
110
-------
EP» UTILITY FCO SURVEY: FEBRUARY - KARCM 1979
SECTION 10
SUMMMV OF F6D SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAP.E UNIT hO.
ALABAMA ELECTRIC COOP
TOMBIGBEE 3
ALLEGHENY POWER SYSTEM
PLEASANT* i
ARIZONA ELECTRIC POWER COOP
APACHE 3
ARIZONA PUBLIC SERVICE
C HOLLA 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
3ASIN ELECTRIC POWER COOP
LARA'lE RIVER 2
BIG RIVERS ELECTRIC
GREEN 1
9IG RIVERS ELECTRIC
GREEN i
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
CINCINNATI GAS I ELECTRIC
EAST BEND 2
COLORADO UTE ELECTR iC ASSN.
CRAIG 1
COLORADO UTE ELECTRIC ASSN.
CRAIG Z
COMMONWEALTH EDISON
POUERTON 51
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
COOPERATIVE POWER ASSOCIATION
COAL CREEK 2
DELMARVA POWER I LIGHT
DELAWARE CITY 1-3
HOOSIER ENERGY
HERO* 1
HOOSIER ENERGY
HERON i
INDIANAPOLIS POWER fc LIGHT
PETERSBURG *
KANSAS POWER 1 LIGHT
^tfFREY 2
LOUISVILLE GAS t ELECTRIC
NEW OR I
RETROFIT
NEk
NEW
>t.
NEW
RETROFIT
IETROFIT
RETROFIT
NEW
KEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
IAPACITY
MM
179.0
519.0
195. r
126.0
175.0
175.0
229.0
600.0
600. C
242.0
242.0
617.0
650. C
447.0
447.0
450.0
327.0
327.0
180.0
441.0
441.0
530.0
490.0
358.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
PEA60DY PROCESS SYSTEMS
Lift
EABCOCK t MILCOX
LIMESTONE
RESEARCH COTTRELL
LI»ESTONE
RESEARCH COTTRELL
LIME/ALKALINE FLYASH
CHEMICO
LIME/ALKALINE FLVASH
CHEMICO
L1ME/ALKALIME FLYASH
CHEMICO
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
DUAL ALKALI
BUELL/ENVIROTECH
L1»E
BABCOCK t W1LCOX
LIMESTONE
PEAbODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION. UOP
LIME
COMgUSTjON ENGINEERING
L1"E
COMBUSTION ENGINEERING
WELLMAN LORD
DAVY POhERGAS
LIMESTONE
MITSUBISHI INTERNATIONAL
LIMESTONE
MITSUBISHI INTERNATIONAL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
COMBUSTION ENGINEERING
LIME/LIMESTONE
START-UP
DATE
6/79
9/60
6/79
6/60
0/79
0/79
0/79
4/80
10/60
12/79
12/60
11/79
10/81
6/79
11/79
10/79
5/79
10/8Q
4/60
4/61
1/82
10/83
6/80
4/81
COMBUSTION ENGINEERING
111
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 10
SUMMARY Or F6D SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
LOUlSVILLt 6»S t ELECTRIC
*ILL CREEK »
MINNESOTA POWER I LIGHT
CLAY BOSnELL 4
OTTER TAIL POWER
COYOTE 1
PACIFIC POWER ( LIGHT
JIM 9RIDSER 4
PENNSYLVANIA POWER
BRUCE MANSFIELD 3
PUBLIC SERVICE OF Nt. MEXICO
SAN JUftN 3
SALT RIVER PROJECT
COR OX ADO 1
SALT RIVER PROJECT
CORONADO I
SAN MIGUEL ELECTRIC COOP
SAN "16UEL 1
SIKESTON BOARD OF "UN 1C. UTIL.
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
WINVAH 3
SOUTHERN ILLINOIS POWER COOP
MARION *
SOUTHERN MISSISSIPPI ELECTRIC
R.D. MORROW i
SPRINGFIELD WATER. LIGHT t PWR
OALLMAN 3
ST. JOE ZlNC
G.F. WEATON 1
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TEXAS POWER t LIGHT
SANDOW 4
UT*H POWER * LIGHT
HUNTER 2
NEW OR
RETROFIT
MEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
CAPACITY
MW
495.0
475.0
440.0
550.0
917.0
534.0
280. 0
280.0
400.0
235.0
280.0
184.0
124.0
205. 0
60.0
575.0
382.0
360.0
PROCESS/
SYSTEM SUPPLIER
LIME
AMERICAN AIR FILTER
LIME/ALKALINE FLYASH
PEABODV PROCESS SYSTEMS
AQUEOUS CARBONATE/SPRAY DRYING
WHEELABRATOR-FRYE/R.I.
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
LIME
PULLMAN KELLOGG
WELLMAN LORD
DAVY POhERGAS
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
EABCOCK t WiLCOX
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
RILEV STOKER/ENVIRONEERING
LIMESTONE
RESEARCH COTTRELL
CITRATE
BUREAU OF MINES
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
CHEHICO
START-UP
DATE
7/81
5/80
5/81
9/79
4/80
6/79
8/79
1/80
8/80
11/80
5/80
5/79
7/79
7/80
7/79
10/80
7/80
6/80
112
-------
(PA UTILITY FED SURVEY: FEBRUARY - MARCH 1979
SECTION 11
SUMMARY OF CONTRACT AWARDED F6D SYSTEMS
COMPANY NAME/
UNIT NAPE UMT NO.
ARIZONA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS '*
ASSOCIATED ELECTRIC COOP
THOF1AS HILL I
SAS1N ELECTRIC POWER COOP
ANTELOPE VALLEY 1
BASIN ELECTRIC POhER COOP
LARAME RIVER J
EAST KENTUCKY POKER COOP
SPURLOCK i
LAKELAND UTILITIES
MCINTOSH J
LOUISVILLE GAS t ELECTRIC
•ILL CREEK i
MONTANA POWER
COLSTRIP 3
MONTANA POWER
COLSTRIP 4
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN *
SOUTH CAROLINA PUBLIC SERVICE
HlNIAH *
SOUTHERN CALIFORNIA EDISON
ALAMITOS 6
SOUTHWESTERN ELECTRIC POWER
HENRY W. PERKEV 1
TENNESSEE VALLEY AUTHORITY
PARADISE 1
TENNESSEE VALLEY AUTHORITY
PARADISE 2
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
TEXAS UTILITIES
MARTIN LAKE *
WISCONSIN POKER t LIGHT
MEb OR 1
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
CAPACITY
nw
755.0
755.0
670.0
440.0
6QO.O
500.0
364.0
350.0
700.0
700.0
100.0
534.0
280.0
175.0
720.0
704.0
704.0
400.0
750. 0
316.0
PROCESS/
SYSTEM SUPPLIER
LIME
UNITED ENGINEERS
LIME
UNITED ENGINEERS
LIMESTONE
PULLMAN KELLOGG
LIME/SPRAY DRYING
JOY MFG. co. WESTERN PRECIPITA
LIME/SPRAY DRYING
BABCOCK t WILCOX
LIME
ADL/COMbUSTION EQUIP ASSOCIATE
LIMESTONE
9A6COCK ( WILCOX
LIKE/LIMESTONE
COMBUSTION ENGINEERING
LIME/ALKALINE FLVASH
ADL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALINE FLVASH
ADt/COMfcUSTlON EQUIP ASSOCIATE
AQUEOUS CARBONATE
ROCKWELL INTERNATIONAL
KELLMAN LORD
DAVY POWER6AS
LIMESTONE
AMERICAN AIR FILTER
LIME
SO. CALIFORNIA ED I SON/STE ARNS-
LIMESTOME
AIR CORRECTION DIVISION. UOP
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH COTTRELL
LIME/ALKALINE FLYASH
START-UP
DATE
0/82
0/82
1/82
11/81
4/82
10/80
10/81
4/82
7/80
7/81
0/E2
1/82
5/81
1/82
2/84
6/82
3/82
1/82
0/85
1/82
CHEMICO
113
-------
EPA UTILITY F6D SUPVEY: FEBRUARY MRCH 1979
SECTION 12
SUMMARY OF PLANNED F6D SYSTEMS
NAME/
UNIT
NO-
NEW OR
RETROFIT
CAPACITY PROCESS/
NW SYSTEM SUPPLIER
START-UP
DATE
LiTTER OF INTENT SI6NED
NEW
NORTHERN STATES POWER
SHERBURNE
PHILADELPHIA ELECTPIC
EDDYSTONE
RETROFIT
860.0
240.0
REQUESTING/EVALUATING BIDS
CENTRAL ILLINOIS LI6HT
DUCK CREEK i
HOUSTON LI6HT1N6 i POWEfc CO.
ri.A. PARISH I
MIDDLE SOuTH UTILITIES
ARKANSAS COAL 5
MIDDLE SOUTH UTILITIES
ARKANSAS COAL t
MIDDLE SOUTH UTILITIES
LOUISIANA COAL 1
MIDDLE SOUTH UTILITIES
LOUISIANA COAL i
MIDDLE SOUTH UTILITIES
MISSISSIPPI COAL 1
DIDDLE SOuTM UTILITIES
MISSISSIPPI COAL i
NORTHERN INDIANA PUb SERVICE
SCHAHFER 17
NORTHERN INDIANA PUB SERVICE
SCHAHFER 18
PUBLIC SERVICE OF INDIANA
6IBSON 5
TENNESSEE VALLEY AUTHORITY
JOHNSONV1LLE 1-1C
TEXAS UTILITIES
FOREST 6ROVE 1
CONSIDERING F66 SYSTEMS
ALLEGHENY PO*ER SYSTEM
MITCHELL 3
3AS1N ELECTRIC POWER COOP
ANTELOPE VALLEY 2
CENTRAL MAINE POWER
SEARS ISLAND 1
COLUMBUS t SOUTHERN OHIO ELEC. NEW
POSTON 5
COLUMBUS & SOUTHERN OHIO ELEC. NEW
POSTON t
GENERAL PUBLIC UTILITIES
COHO i
SENERAL PUBLIC UTILITIES
SEWARD 7
NEW
NEW
NEW
NEW
SEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
IS
RETROFIT
NEK
NEW
NEW
NEW
NEW
NEW
416.0
512.0
990.0
890.0
890. 0
890.0
890.0
890.0
421.0
421.0
650.0
600-0
750.0
300.0
440.0
600.0
375.0
375.Q
800.0
BOO.O
LIMESTONE
COMBUSTION ENGINEERING
"A6NESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
MAGNESIUM OXIDE
TVA/UNlTED ENGINEERS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME/LIMESTONE
VENDOR MOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
5/84
6/80
1/8*
10/82
1/86
1/88
0/86
0/88
0/8S
0/87
6/83
6/85
0/82
0/82
0/81
8/82
11/83
11/87
0/83
0/85
12/85
12/85
114
-------
EPA UTILITY F60 SURVEY: FEBRUARY - NAPCM 1979
SECTION 12
SUK'ARV OF PLANNED F6D SYSTEMS
COUPON* NAME/
OMIT NAME OMT NO.
LOUlSVILLt 6»S 1 ELECTRIC
TRIABLE COUNTY 1
LOUISVILLE GAS t ELECTRIC
TRINBLE COUNTY i
NUSCATINE POWER g WATER
•USCATINE v
NEVADA POnER
HARRY ALLEN 1
NEVADA POWER
HARRY ALLEN i
NEVADA POkER
HARRY ALLEN 3
NEVADA POWER
HARRY ALLEN 4
NEVADA POWER
REID GARDNER 4
NEVADA POWER
WARNER VALLEY 1
NEVADA POMER
WARNER VALLEY t
NORTHERN INDIANA PU6 SERVICE
3AILLY 7
NORTHERN INDIANA PUB SERVICE
3AILLY 8
PACIFIC 6AS t ELECTRIC
FOSSIL 1
PACIFIC 6AS 1 ELECTRIC
FOSSIL i
PHILADELPHIA ELECTRIC
CROMBY
PHILADELPHIA ELECTRIC
EDOYSTONE i
POT01AC ELECTRIC Po^ER
DICKERSON *
POME* AUTHORITY OF NEW YORK
ARTHUR KILL
SALT RIVER PROJECT
C OR ON AD o *
SEM1NOLE ELECTRIC
SEHINOLE 1
SOUTHERN ILLINOIS POWER COOP
MARION 5
TAMPA ELECTRIC
BI6 BEND 4
TENNESSEE VALLEY AUTHORITY
CUMBERLAND
TEXAS POWER I LIGHT
kEw OR 1
RETROFIT
NEW
KEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
CAPACITY
HW
575.0
57S.O
160.0
500.0
500.0
500.0
500. C
250.0
250.0
250.0
190.0
400.0
BOO.C
bOO.O
150.0
234.0
BOO.O
700.0
280-0
620.0
300.0
450.0
600.0
750.0
PROCESS/
SYSTEM SUPPLIER
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
MAGNESIUM OXIDE
UNITED ENGINEERS
•AGNESIUM OXIDE
UNITED ENGINEERS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR MOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
START-UP
DATE
7/8*
0/84
0/S2
6/85
6/86
6/87
6/se
0/83
6/B4
e/es
01 0
O/ 0
0/85
0/86
6t£0
6/80
0/87
11/88
0/87
6/83
0/84
0/85
7/82
?/B3
THIN OAKS
VENDOR NOT SELECTED
115
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MRCH 1*79
SECTION 12
SUMMARY OF PLANNED F6D SYSTEMS
COMPANY NAME/ NEW OR CAPACITY PROCESS/ START-UP
UNIT N»ME UklT M0« RETROFIT MW SYSTEM SUPPLIER DATE
TEXAS POWER t LIGHT NEW 750.0 LIMESTONE 0/86
TUN OAKS 2 ' VENDOR NOT SELECTED
TEXAS UTILITIES NEW 7SO.O PROCESS NOT SELECTED 0/85
HILL CREEK 1 VENDOR NOT SELECTED
TEXAS UTILITIES NEW 750.0 PROCESS NOT SELECTED 0/86
MILL CREEK 2 VENDOR NOT SELECTED
116
-------
IP* UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 13
TOTAL f6D UNITS ANO CAPACITY INSTALLED BY YEAR
YEAR
1968
1*71
1972
1973
197*
1«75
1976
1977
1978
1979
1980
1981
1982
1983
198*
1985
1966
1987
UNDEFINED
NE b
NO.
1
»
8
7
3
6
g
10
13
22
23
10
19
7
7
11
6
6
20
ON LINE
MM
0.
420.
200.
1*7$.
250.
1971.
2069.
«67*.
'736.
7242.
9117.
«918.
9326.
3386.
3696.
6786.
4580.
3070.
1240.
TERI
NO.
0
0
0
1
0
0
1
0
0
0
0
0
0
0
1
0
0
0
UNATED
MW
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
250.
0.
0.
0.
TOTAL
NO.
1
*
12
16
21
27
34
44
57
79
102
112
131
138
144
155
161
167
ON LINE
MW
0.
420.
620.
2095.
2345.
4316.
6385.
11059.
15795.
23037.
32154.
37072.
46398.
49784.
53230.
60016.
64596.
67666.
117
-------
FPA UTILITY FGD SURVEY: FEERUAPY - MUCH 1979
SECTION 1*
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLANT N*HE
UNIT NUMBER
CITT
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - (-G/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - Mfc
NET UNIT GENtRAUNG CAPACITY U/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGO - KW
EQUIVALENT SCRUBBED CAPACITY - CW
COMMONWEALTH
WILL COUNTY
1
ROMEOVjLLE
ILLINOIS
*•••• •
0.
77*.
1147 .0
167.0
137.0
.0
.0
EDISON
( .000 LB/HMBTU)
( 1.800 LB/MMBTU)
•• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM faOILER FLUt 6AS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
• • FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANGE HEAT CONTENT - 6TU/LB
AVERAGE ASH CONTENT - t
RANGE ASH CONTENT - S
AVERAGE MOISTURE CONTENT - Z
RANEE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - t
RANGE SULFUR CONTENT - S
AVERAGE CHLORIDE CONTENT - S
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - "W
•• ESP
NUMBER
TYPE
SUPPLIER
PARTICIPATE DESIGN REMOVAL EFFICIENCY
FLUE GAS TEMPERATURE - C
•• PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
TYPE OF N02ZLES
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LIQUID REC1RCULAT10N RATE - LITER/S
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL CAS VELOCITY - M/S
PARTICULATE INLET LOAD - 6/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
9ABCOCK i WILCOI
wET BOTTOM. CYCLONE
CYCLIC
0/55
363.36 ( 770000 ACFH)
179.* < 355 F>
107. < 350 FT)
3.8 < 12.* FT)
COAL
••••*•
22260.
7.*0
3-16
( 9570 BTU/LB)
9,100 - 10,500
1.50
0.3 - 4.5
•*••••••
77.1
167
t 85 TPH)
COLD SIDE
WESTERN PRECIPITATION fjov MANUFACTURING)
79.0
179.4 t 355 F)
ADJUSTABLE THRflAT VENTUftl
3ABCOCK I VUCOk
CARBON STEEL
PLASITE AND KAOCRETE
STAINLESS STEEL
181.7
179.4
365.4
2.4
2.2
36.6
.4
98.0
( 385000 ACFM)
i 355 F)
( 5800 6PM>
t18.0 GAL/1000ACF)
C 9 JN-H20)
( 120.0 FT/S)
( .16 6R/SCF)
118
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 1*
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
RE6ULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - K6/J
SOZ EMISSION LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - RU
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY WO/FGD - MV
EQUIVALENT SCRUBBED CAPACITY - PW
DETROIT EDISON
ST. CLAIR
6
BELLE RIVER
MICHI6AM
C
»*••• •
1376.
1775.0
325.0
.0
.0
{•••••• LB/NHBTU)
( 3.200 LB/MMBTU)
•• BOILER DATA
SUPPLIER
TTPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOU - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - H
• • FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - *
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MY
COMBUSTION ENGINEERING
TuO-STAGE SUPERHEATER
BASE
0/61
•*..«... (••*•••• ACFH)
132.2 ( 270 F)
•••••• (***• FT)
••••••« (••••* FT)
COAL
SUBBI TUMI NOUS
4.00
• * **•*
22 - 24
••••••*•
0.3 - 0.4
»•»••***
•••••*
120.6
*•**•
(•...*. BTU/LB)
9.SOO - 9.600
(133 TPH>
• • ESP
•• MECHANICAL COLLECTOR
•• PARTICULATE SCRUBBER
NUMBER
TYPE
2
VENTURI
119
-------
EPA UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 14
DESIGN AND PERFORNAfcCE DAT* FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
RE6ULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - ht/J
S02 EMISSION LIMITATION . ht/J
NET PLANT GENERATING CAPACITY - HN
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - My
NET UNIT GENERATING CAPACITY UO/F6D - OW
EQUIVALENT SCRUBBED CAPACITY - MW
•• 90ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAIIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANtt MEAT CONTENT - BTU/LB
AVERAGE A$H CONTENT - X
RANGE ASH CONTENT - X
AVERAGE.H01STURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - HW
•• PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD - G/CU.M
SOZ INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
SOZ DESIGN REMOVAL EFFICIENCY - S
MINNESOTA POKER ( LIGHT
AURORA
1
AURORA
MINNESOTA
**•••»
0.
*•••••
116.0
••*••••
53.0
.0
.0
COMBUSTION ENGINEERING
PULVERIZED COAL
( .000 LB/MRBTU)
{••••«• LB/MMBTU)
0/51
•••*•**•
••«••••
••••••
••**•**
COAL
SUBBITUMINOUS
20469.
•**•*•••
••*•*•
26.70
••••••
1.37
•••*••
(*••**•* ACFM)
(*••• F)
(**•• FT)
(•*•** FT)
( 8800 BTU/LB)
••***•
(«•• TPH)
ELBAIR SPRAI-INPINGEMENT
KREBS ENGINEERING
316 ELC STAINLESS STEEL
FLAKE-POLYESTER
100.0
137. 291160 ACFM)
171. 340 F)
1. 8.3 GAL/1000ACF)
3 IN-H20)
2. 7.0 FT/S)
4.7 2.06 6R/SCF)
.1 .040 GR/SCF)
800.000
500.000
37.0
-------
IPX UTILITY F6D SURVEY: FEBRUARY - MARCH 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
$02 EMISSION LIMITATION - kfi/J
NET PLANT GENERATING CAPACITY - MW
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY k/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGt - RW
EQUIVALENT SCRUBBED CAPACITY - MW
•• BOILER DATA
SUPPLIER
TTPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - N
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT KJ/KG
RANGE HEAT CONTENT - BTU/L6
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE M01STJRE CONTENT - t
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MW
•• PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
BOILE* LOAD/SCRUBBER - x
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
L/C RATIO - LITFR/CU.H
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - 6/CU.M
PARTICULATE OUTLET LOAD - 6/CU.P
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - t
MINNESOTA POWER t LIGHT
AURORA
2
AURORA
MINNESOTA
116.0
58.0
.0
.0
COMBUSTION ENGINEERING
PULVERIZED COAL
( .000 L9/MMBTU)
(•••••• LB/MMBTU)
0/5J
••••*••
COAL
SUB8ITUMINOUS
20469.
(••••••• ACFM)
«•••• F)
(•*•• fT)
(*••*• FT)
< 8800 BTU/LB)
*•«•••
26.70
*•*•••
1.37
TPH>
1
ELBAIR SPRAY-IMPINGEMENT
KRESS ENGINEERING
516 ELC STAINLESS STEEL
FLAKE-POLYESTER
100.0
137. 291160 ACFH)
171. 3*0 F>
1. 8.3 6AL/1000ACF)
3 IN-H20J
2. 7.0 FT/SJ
4.7 2.06 GR/SCF)
.1 .040 GR/SCF)
800.000
500.000
37.0
121
-------
EPA UTILITT FfiD SURVEY: FEBRUARY - MRCM 1979
SECTION 1*
DESIGN ADD PERFORMANCE 0*T» FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
P»RT1CULAT€ £MISSION LIMITATION - K6/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - HU
&ROSS UNIT GENERATING CAPACITY - Pb
NET UNIT GENERATING CAPACITY W/F6D - MH
NET UNIT GENERATING CAPACITY bO/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - MB
MONTANA-DAKOTA UTILITIES CO.
LEWIS t CLARK
••*•••
••*•••
0.
••••*•
••••*•*
.0
.0
( .000
(•••••* LB/MMBTU)
•• 90ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM oOILER FLUE 6A S FLOW - CU.P./S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - "
STACK TOP DIAMETER - P
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE MEAT CONTENT - KJ/KG
RANGE HEAT CONTENT - B1U/LB
AVERAGE ASH CONTENT - I
RANGE ASH CONTEXT - X
AVERAGE MOISTURE CONTENT - t
RANGE M01STJRE CONTENT - X
AVERAGE SULFUR CONTENT - S
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
kANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - 4 T/H
FUEL FIRING RATE - *u
•* "ECHANICAL COLLECTOR
NUMBER
•• PARTICULATE SCRUBBER
TTPE
SUPPLIER
L/6 RATIO - LlTER/CU.n
PRESSURE DROP - KPA
• •/•*
•*•••••*
COAL
LIGNITE
«••«••*
9.00
• * **• •
(*••••*• ACFM)
(•••* F)
C«.«« FT>
(••••• FT)
(•••••• BTU/L8)
•*••**
*•*••••*
••*•••
••••* ••
* • *«*
(•*» TPM)
VENTURI-FLOODtD DISC
RESEARCH COTTERELL
1.7 (13.0 6AL/1000ACF)
7.2 ( 13 IN-H20)
122
-------
CPA UTILITY Fft SURVEY: FEBRUARY - PARCH 1979
SECTION 14
DESIGN AID PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLANT HARE
UNIT NUMBER
C1TT
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - hG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - Mk
6ROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY k/FGD - M.
NET UNIT GENERATING CAPACITY WO/F6D - "IW
EQUIVALENT SCRUBBED CAPACITY - OH
•* BOILER DATA
SUPPLIER
TTPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
NAKIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP OIACETER - P<
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANGE HEAT CONTENT - BTU/L6
AVERAGE ASH CONTENT - 1
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - 1
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDF CONTENT - X
FUEL FIRING RATE - M T/h
FUEL FIRING RATE - MM
PACIFIC POWER I LIGHT
DAVE JOHNSTON
4
6LENPOCK
•YOKING
33C.O
.0
.0
COMBUSTION ENGINEERING
PULVERIZED COAL
( .000 L9/HHBTU)
(••»••• LB/MMBTU)
••*••••
COAL
SUBBITUNINOUS
172P2.
(*•••**• «CFH)
<•«•• F)
( £50 FT)
(•**•• FT)
( 7430 BTU/LB)
**»•••
12.00
2t.OO
• ••«
.50
(«•• TPH)
•• ESP
•• PARTICULATE SCRUBBER
NUMBER
TTPE
SUPPLIER
LINING MATERIAL
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LIQUID REC1RCULATION RATE - LITER/S
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
PARTICULATE INLET LOAD - G/CU.K
PARTICULATE DESIGN REMOVAL EFFICIENCY
SO2 INLET CONCENTRATION - PPP
502 DESIGN REMOVAL EFFICIENCY - t
- Z
3
VENTUR]
CHEMICO
POLYESTER-LINED
327.5
135.0
409.5
1.3
2.5
9.2
99.7
459.000
40.0
STEEL
694000 ACFM)
275 F)
6500 GP">
9.4 GAL/1000ACF)
10 IN-H20)
4.00 GR/SCF)
123
-------
EPA UTILITY F6D SURVEY: FEBtuARV - AARCH 1979
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITT
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION • hG/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT 6ENERAT1NG CAPACITY - "k
NET UNIT GENERATING CAPACITY U/F&D - <"•
NET UNIT GENERATING CAPACITY UO/FGC - MW
EQUIVALENT SCRUBBED CAPACITY - MM
POTOMAC ELECTRIC POU(R
CHALK POINT
4
******
HA*YLNAD
•••**.
0.
1892.0
630.0
630.0
.0
.0
•• BOILER DATA
SUPPLIER ••••••
TYPE •*••••
SERVICE LOAD 3ASE
COMMERCIAL SERVICE DATE •*/••
MAXIMUM BOILER FLUE GAS FLOW - CU.B/S ••*••*•«
FLUE GAS TEMPERATURE - C .......
STACK HEIGHT - M *•*••*
STACK TOP DIAMETER - M *•«•**•
•• FUEL DATA
FUEL TYPE OIL
FUEL GRADE ******
AVERAGE HEAT CONTENT - KJ/KG *••*•••
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X ••••••••
RANGE ASH CONTENT - Z •••«*•
AVERAGE MOISTURE CONTENT - X ••••••*•
RAN6E MOISTURE CONTENT - X ••••*.
AVERAGE SULFUR CONTENT - X *.*.**••
RANGE SULFUR CONTENT - X •••*««
AVERAGE CHLORIDE CONTENT - X •••«***•
RANGE CHLORIDE CONTENT - X ••••*•
FUEL FIRING RATE - M T/H •••••••
FUEL FIRING RATE - MU *•«••
( .000 LB/HHBTU>
(•**.*• LB/MMBTU>
(*•••••• ACFM)
(*••« F)
<*•*• FT)
(•**.* FTI
(*•«*•• BTU/LB)
*••*••
(••• TPM)
-------
EPA UTILITY FED SURVEY: FEBRUARY - MARCH 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL (-ARTICULATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CIT»
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSIOK LIMITATION - NG/J
502 EMISSION LIMITATION - NC/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY Ph
NET UNIT GENERATING CAPACITY W/F6B - MW
NET UNIT GENERATING CAPACITY WO/F6D - MU
EOUIVALENT SCRUBBED CAPACITY - My
*• 30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM S01LER FLUE CAS FLOW - CU.M/S
FLUE GAS TEMPERATURE . C
STACK HEIGHT - M
STACK TOP DIAMETER - *
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANGE HEAT CONTENT - ETU/LE
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
MANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T /H
FUEL FIRING RATE - Mb
• • ESP
NUMBER
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
POTO»AC ELECTRIC POWER
DICKERSON
3
DlCKFRSON
MARYLAND
( .000 LB/MMBTU)
( 1.600 LB/MMBTU)
0.
66?.
5*«.0
190.0
183.0
.0
.0
COMBUSTION ENGINEERING
PULVERIZED COAL* DRY BOTTOM
BASE
0/6Z
Z7E.42 < S90000 ACFM)
126.1 < 259 F)
122. ( tOO FT)
....... (*.... FT)
COAL
•••«•«
27214.
14.00
......
*.*•••
2.00
( 11700 BTU/LB)
«««*•«
......*.
••**••
67.1
.....
( 74 TPN>
- X
RESEARCH-COTTRELL
94.0
*• PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
BOILER LOAO/SCRUBBEB - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - c
L/6 RATIO • LITER/CU.M
PRESSURE DROP - KPA
ADJUSTABLE VEbTURI
CHEM1CO
50.0
139.2 ( 295000 ACFH)
126.1 ( 259 F)
2.7 (20.0 GAL/1000ACF)
2.7 < 11 IN-H20)
125
-------
EPA UTILITY F&D SURVEY: FE6uu*»f - MUCH 1979
SECTION 14
DESIGN AND PERFORMAfcCE DAT* FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE tNISSION LIMITATION - K6/J
$02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
(ROSS UNIT GENERATING CAPACITY - N»
NET UNIT GENERATING CAPACITY W/F6D - Mb
NET UNIT GENERATING CAPACITY VO/F6D - »W
EQUIVALENT SCRUBBED CAPACITY - AH
•• 90ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAIIHUP BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - •
STACK TOP DIAPETER M
•• FUEL DATA
FUEL TYPE
FUEL GRAPE
AVERAGE HEAT CONTENT - KJ/KG
RANGE HEAT CONTENT - BTU/L6
AVERAGE ASH CONTENT - *
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - « T/H
FUEL FIR1N6 RATE - M*
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANGE NEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - NH
• • ESP
NUMBER
•• MECHANICAL COLLECTOR
NUMBER
•• PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
L/G RATIO - LITER/CU.M
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - 6/CU.M
PARTICULATE OUTLET LOAD - G/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
PUBLIC SERVICE OF COLORADO
ARAPAHOE
t
( .000 LB/HHBTU)
(••*••• LB/MMBTU)
COLORADO
0.
••••*••
112.0
.0
.0
•*••*•
PULVERIZED COAL
•••*••
0/55
*•••••••
• *• ****
•••••*
(*••••«* ACFH)
(«••• f)
(••.* FT)
(•*•*• FT)
COAL
SUBBITUMINOUS
23725.
•*•*•
13.70
( 10200 BTU/LB)
•••*•*
.95
•*•••*
.01
••*•••
COAL
******
23493.
12.50
••**••
11.20
••**••
.65
******
.01
******
• ••*•
(*•* TPH>
( 10100 BTU/LB)
TPH>
1
TCA
UOP
3
CARBON STEEL
RUBBER
STAINLESS STEEL
7.5
3.*
1.8
• 0
93.0
500.000
(56.0 6AL/1000ACF)
( 11.0 FT/S)
C .80 6R/SCF)
( .020 GR/SCF)
126
-------
EP» UTILITY F6D SURVEY; FEBRUARY - 1ARCH 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE
S02 OUTLtT CONCENTRATION - PPf 750.000
S02 DES16N REMOVAL EFFICIENCY - t 30.0
-------
?PA UTILITY FGD SURVEY: FEBRUARY - PARCH 1979
SECTION 1*
DEtlGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - MG/J
S02 EMISSION LIMITATION - hfe/J
NET PLANT GENERATING CAPACITY - My
CROSS UNIT GENERATING CAPACITY - Hk
NET UNIT GENERATING CAPACITY K/F6D - MM
NET UNIT GENERATING CAPACITY bO/FGD - NU
EQUIVALENT SCRUBBED CAPACITY - MM
•• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOta - CU.M/S
FLUE GAS TEMPERATURE . C
STACK HEIGHT - M
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - I
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL F1RING RATE - "W
PUBLIC SERVICE OF COLORAD<>
CHEROKEE
1
DENVER
COLORADO
0.
( .000 L9/NMBTU)
(••«*•• L9/MM9TU)
710.0
115.0
100.0
.0
.0
3ABCOCK t VILCOX
PULVERIZED COAL
0/57
COAL
aiTUKINOUS
234.93.
12.50
(••••••• ACFM)
(•••• F)
(•.** FT)
(•*.•* FT)
( 10100 BTU/LB)
•**••*
11.JO
• * • ** *
.65
•••*•»
.01
(•*• TPH)
»• ESP
NUMBER
»• MECHANICAL COLLECTOR
NUMBER
•• PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LIMING MATERIAL
INTERNAL MATERIAL
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - c
L/G RATIO - LITER/CU.P
PRESSURE DROP - KPA
SUPERFICIAL 6»S VELOCITY - */S
PARTICULATE INLET LOAD - 6/CU.f
PARTICULATE OUTLET LOAD G/CU.P
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
$02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - t
- X
1
TCA
UOP
3
CARBON STEEL
RUBBER
STAINLESS STEEL
67.0
164.4
146.1
7.5
7.2
3.4
1.8
.0
97.0
500.000
420.000
16.0
( 3484QO *CFM)
( 295 F)
(56.0 6AL/1000ACF)
( 13 IN-H20)
( 11.0 FT/S)
( .80 6R/SCF)
( .020 6R/SCF)
128
-------
IP* UTILITY FCO SUfcVEY: FEBRUARY - »»PCH 1979
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITT
STATE
RE6JLATORT CLASSIFICATION
PARTICULATE EMISSION LIMITATION - Kg/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MW
CROSS UHjT GENERATING CAPACITY "w
NET UNIT GENERATING CAPACITY W/FGo - "•
NET UNIT GENtRATING CAPACITY WO/F6D - nu
EQUIVALENT SCRUBBED CAPACITY - *K
•• BOILER DATA
SUPPLIER
TVPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.K/S
fLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER M
•• FUEL DATA
FUEL TYPE
fUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANGE HEAT CONTENT - BTU/IE
AVERAGE ASH CONTENT - Z
RANGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - My
•• ESP
NUMBER
•• MECHANICAL COLLECTOR
NUMBER
•• PARTICULATE SCRUBfER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.H/S
FLUE GAS TE"»PE«ATURE - c
L/C RATIO - L1TER/CU.P
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY K/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD - 6/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
SOJ OUTLET CONCENTRATION - PP"
SO2 DESIGN REMOVAL EFFICIENCY - t
PUBLIC SERVICE OF COLORADO
CHEROKEE
3
DENVER
COLORADO
0.
710.0
170.C
1SO.O
.0
.0
3ABCOCK t. WILCOX
PULVERIZED COAL
******
0/62
•••*•*•• (•
.000 LB/HMBTU)
>*••• L9/MMBTU)
• CFM)
COAL
BITUMINOUS
23493.
(•••• F)
(•••• FT)
(••••* FT)
( 10100 BTU/LB)
12. 50
11.10
.65
.01
(••• TPH)
- Z
2
TC»
UOP
3
CARBON STEEL
RUBBER
STAINLESS STEEL
20.0
57.6
137.8
7.5
3.2
?.*
.9
.0
95.0
500.000
420.000
16.0
122000 ACFM)
280 F)
56.0 GAL/1000ACF)
13 JN-H20)
11.0 FT/S)
.40 Gft/SCF)
.020 6R/SCF)
129
-------
EP« UTILITY fit SUtVEY: FEERUAfT - MRCH 1979
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAPE
PLAIT NONE
UNIT NU'BER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION L1»ITATICN - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MM
60OSS UNIT GENERATING CAPACITY - Hh
NET UNIT GENERATING CAPACITY W/FGt - MM
NET UNIT GENERATING CAPACITY VO/F6D - MW
E8UIVALENT SCRUBBED CAPACITY - »M
PUBLIC SERVICE Of COLORADO
CHEROKEE
4
DENVER
COLORADO
••*•*«
0.
•••••*
71C.O
375.0
750.0
.0
.0
( .000 LB/BMBTU)
(*••••• LB/HMBTU)
- X
- X
*• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
HA XI HUP faOKER FLUE GAS FLOW - CU.H/S
FLUE EAS TEMPERATURE - C
STACK HEIGHT - "
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ /KG
RANGE HEAT CONTENT - BTU/LE
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT
RANGE CHLORIDE CONTENT - 1
FUEL FIRING RATE - N T /H
FUEL FIRING RATE - «w
• • ESP
NUM9ER
•• MECHANICAL COLLECTOR
NUMBER
•• PARTICULATE SCRUBBED
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
L/6 RATIO - LITER/CU.n
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY »/S
PARTICULATE INLET LOAD - G/CU.P
PARTICULATE OUTLET LOAD 6/CU.P
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
COMBUSTION ENGINEERING
PULVERIZED COAL
•••*••
0/68
717.29 (1520000 ACFM)
135.0 ( 275 F)
»•»•«• (•*•* FT)
•**••*• <*••»» FT)
COAL
BITUMINOUS
23493.
12.50
*••••*
11.30
••••••
.65
• **** *
.01
••**•*
•*••**•
( 10100 BTU/LB)
••»•**
(••* TPH)
TCA
UOP
3
CARBON STEEL
RUBBER
STAINLESS STEEL
7.5
3.2
3.4
1.6
.0
97.0
500.000
420.000
16.0
(56.0 GAL/1000ACF)
< 13 IN-H20)
( 11.0 FT/S)
( .70 SR/SCF)
( .020 CR/SCF)
130
-------
EPA UTILlTf FGD SURVEY: FEBRUARY - MARCH 1979
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBgERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
RE6ULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - HW
&ROSS UNIT GENERATING CAPACITY - Mta
NET UNIT GENERATING CAPACITY ta/FGD - »*
NCT UNIT GENERATING CAPACITY hO/FGD - MK
EQUIVALENT SCRUBBED CAPACITY - PW
•• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIHUP BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIA"ETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANGE HEAT CONTENT - bTU/LG
AVERAGE ASH CONTENT - *
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
RANGE MOISTURE CONTENT - T
AVERAGE SULFUR CONTENT - *
RANGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - t
RANGE CHLORIDE CONTENT - 1
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - "k
PUBLIC SERVICE
VALMQNT
5
VALMONT
COLORADO
0.
277.8
166.0
166.0
.0
.0
OF COLORADO
( .000 L9/MMBTU)
PULVERIZED COAL
BASE
0/6*
<••••••*
(•••• F)
(•... FT)
(*••*• FT)
• CFM)
COAL
BTU/LB)
S.2C
.60
(... TPH)
•• ESP
TYPE
•• MECHANICAL COLLECTOR
COLD SIDE
1S1
-------
APPENDIX A
FGD SYSTEM COST DATA: OPERATIONAL AND NONOPERATIONAL SYSTEMS
A-l
-------
INTRODUCTION
The cost of flue gas desulfurization (FGD) systems for the
control of sulfur dioxide emissions is an area of intense inter-
est and substantial controversy. As a result, many computer
models have recently been developed to estimate capital and
annual costs. As part of an effort by the U.S. Environmental
Protection Agency to provide meaningful economic ,ida,ta 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
-------
APPROACH
In March 1978, each utility having at least one operational
FGD system was given a cost form containing all available cost
information then in the PEDCo files. The utility was asked to
verify the data and fill in any missing information called for
on the form. A follow-up visit by the PEDCo Environmental staff
was arranged to assist in data acquisition and to insure com-
pleteness and reliability of information. Results of the cost
analysis were forwarded to each participating utility for final
review and comment.
The cost data were treated solely to establish the accurate
costs for FGD systems, on a common basis, not to critique the
design or reasonableness of the costs reported by any utility.
Adjustments focused primarily on the following items:
0 All capital costs were adjusted to July 1, 1977, dol-
lars using the Chemical Engineering Index. All capital
costs, represented in dollars/kilowatt (S/kW), were
expressed in terms of gross megawatts (MW). Actual
costs were reported by utilities in dollar values for
years 1970 to 1980. These values are represented in
terms of the year of greatest capital expenditures.
0 Gross unit capacity was used to express all FGD capital
expenditures because the capital requirement of an FGD
system is dependent on actual boiler size before de-
rating for auxiliary and air quality control power
requirements.
0 Particulate control costs were deducted. Since the
purpose of the study was to estimate the incremental
cost for sulfur dioxide control, particulate control
costs were deducted using either data contained in the
cost breakdowns or as a percentage of the total direct
cost (capital and annual). The percentage reduction
varied depending upon system design and operation.
A-3
-------
The capital costs associated with the modification or
installation of equipment not part of the FGD system
but needed for its proper functioning, were included
(e.g. - stack lining, modification to existing ductwork
or fans, etc.).
Indirect charges were adjusted to provide adequate
funds for engineering, field expenses, legal expenses,
insurance, interest during construction, allowance for
startup, taxes, and contingency.
All annual costs, represented in mills/kilowatt-hour
(mills/kWh), were expressed in terms of net megawatts
(MW).
Net unit capacity was used to express all FGD annual
expenditures because the annual cost requirement of an
FGD system is dependent on the actual amount of kilo-
watt-hours (kWh) produced by the unit after derating
for auxiliary and air quality control power require-
ments .
All annual costs were adjusted to a common capacity
factor (65%).
Replacement power costs were not included since only a
few utilities reported such costs and these were pre-
sented using a variety of methods.
Sludge disposal costs were adjusted to reflect the
costs of sulfur dioxide waste disposal only (i.e.,
excluding fly ash disposal) and to provide for disposal
over the anticipated lifetime of the FGD system. This
latter correction was necessary since several utilities
reported costs for sludge disposal capacity that would
last only a fraction of the FGD system life. The
adjustments were based on a land cost of $2000/acre
with a sludge depth of 50 ft in a clay-lined pond (clay
is assumed to be available at the site).
A 30-year life was assumed for all process and economic
considerations for all new systems that were installed
for the life of the unit. A 20-year life was assumed
for all process and economic considerations for retro-
A-4
-------
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
-------
DESCRIPTION OF COST ELEMENTS
Capital costs consist of direct costs, indirect costs, con-
tingency costs, and other capital costs. Direct costs include
the "bought-out" cost of the equipment, the cost of installation,
and site development. Indirect costs include interest during
construction, contractor's fees and expenses, engineering, legal
expenses, taxes, insurance, allowance for start-up and shake-
down, and spares. Contingency costs include those costs result-
ing from malfunctions, equipment alterations, and similar un-
foreseen sources. Other capital costs include the nondepreciable
items of land and working capital.
Annual costs consist of direct costs, fixed costs, and over-
head costs. Direct costs include the cost of raw materials,
utilities, operating labor and supervision, and maintenance and
repairs. Fixed costs include those of depreciation, interim
replacement, insurance, taxes, and interest on borrowed capital.
Overhead costs include those of plant and payroll expenses. The
various capital and annual cost components are discussed and
defined in greater detail in the following paragraphs.
The direct capital costs include the following elements:
0 Equipment required for the FGD system. Table A-l
provides a summary of the major process equipment used
in regenerable and nonregenerable systems.
° Installation of equipment, including foundations; steel
work for support, buildings, piping and ducting for
effluents, slurries, sludge, and make-up water, control
panels, instrumentation, insulation of ducting, buildings,
piping, and other equipment, painting and piling.
0 Site development may include clearing and grading,
construction of access roads and walkways, establish-
ment of rail, barge, and/or truck facilities, and
parking facilities.
A-6
-------
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
-------
TAfiLE A-l. (continued)
Category
Description
Regeneration
Purge treatment
Auxiliary
Equipment for regeneration of the absorbing
medium of an FGD system may consist of re-
actor vessels, material handling system,
storage, weigh feeder, conveyor, rotary kiln,
fluid bed calciner, dust collector, storage
silo, vibrator, combustion equipment and oil
storage tanks, waste heat boiler, hammer
mill, evaporators, crystallizers, strippers,
tanks, agitators, pumps, compressors, sul-
furic acid absorber and cooling, mist elimi-
nator, pumps, acid coolers, tanks, etc.
Equipment for the removal of purge material
(e.g. sodium sulfate) includes refrigeration,
pumps, tanks, crystallizer, centrifuge,
dryer, dust collector, conveyors, storage,
and related equipment.
Equipment not directly related to the
FGD system, but which may require design or
modification to accommodate an FGD system
may include such items as existing fans,
ducts, or stack. If new fans, ducts, or
stacks are added to improve boiler perfor-
mance and accommodate the FGD systen, the
costs are prorated to the boiler and FGD
system.
A-8
-------
Indirect capital costs include the following elements:
0 Interest accrued on borrowed capital during construction.
0 Contractor's fee and expenses, including costs for
field labor payroll; field office supervision; person-
nel; construction offices; temporary roadways; railroad
trackage; maintenance and welding shops; parking lot;
communications; temporary piping and electrical and
sanitary facilities; safety security (fire, material,
medical, etc.); construction tools and rental equip-
ment; unloading and storage of materials; travel ex-
penses; permits; licenses; taxes; insurance; overhead;
legal liabilities; field testing of equipment; start-
up; and labor relations.
0 Engineering costs, including administrative, process,
project, and general; design and related functions for
specifications; bid analysis; special studies; cost
analysis; accounting; reports; consultant fees; pur-
chasing; procurement; travel expenses; living expenses;
expediting; inspection; safety; communications; model-
ing; pilot plant studies (if required because of pro-
cess design or application novelty); royalty payments
during construction; training of plant personnel; field
engineering; safety engineering; and consultant ser-
vices.
0 Legal expenses, including those for securing permits,
rights-of-way, etc.
0 Taxes, including sales, and excise taxes.
0 Insurance covering liability for equipment in transit
and at site; fire, casualty, injury, and death; damage
to property; delay; and noncompliance.
0 Allowance for start-up and shakedown includes the cost
associated with system start-up.
0 Spare parts including pumps, valves, controls, special
piping and fittings, instruments, spray nozzles, and
similar items.
Other capital costs include the following elements:
0 Land required for the FGD process, waste disposal, re-
generation facility, and storage.
o Working capital, including the total amount of money
invested in raw materials and supplies in stock,
finished products in stock, and unfinished products
A-9
-------
in the process of being manufactured; accounts re-
ceivable; cash kept on hand for payment of operating
expenses such as salaries, wages, and raw materials
purchases; accounts payable; and taxes payable.
Annual cost of an FGD system includes the following direct,
fixed and overhead charges:
0 Direct Charges
Raw materials, including those required by the FGD
process for sulfur dioxide control, absorbent regenera-
tion, sludge treatment, sludge fixation, flocculants,
etc.
Utilities, including water for slurries, cooling and
cleaning; electricity for pumps, fans, valves, lighting
controls, conveyors, and mixers; fuel for reheating of
flue gases; and stream for processing.
Operating labor, including supervisory, skilled, and
unskilled labor required to operate, monitor, and
control the FGD process.
Maintenance and repairs, consisting of both manpower
and materials to keep the unit operating efficiently.
The function of maintenance is both preventive and
corrective to keep outages to a minimum.
Byproduct Sales; credit from the sale of byproducts
regenerable FGD processes (e.g. sulfur, sulfuric acid)
is a negative charge deducted from the annual direct
cost to obtain the net annual direct cost of the FGD
system.
0 Fixed Charges
• Depreciation - the annual charge to recover direct and
indirect costs of physical assets over the life of the
asset.
Interim, replacement - costs expended for temporary or
provisional replacement of equipment that has failed or
malfunctioned prematurely.
Insurance, including the costs of protection from loss
by a specified contingency, peril, or unforeseen event.
Required coverage could include losses due to fire,
personal injury or death, property damage, explosion,
lightning, or other natural phenomena.
A-10
-------
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
-------
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
-------
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
-------
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
-------
TABLE A-3. DESCRIPTION OF COST
Code
Title
Description
B
C
articulate control (required for FGD pro-
ess) included in capital cost.
articulate control (included in FGD
irocess) included in capital cost.
otal direct capital costs included.
artial direct capital costs included.
Total indirect capital costs included.
L
M
N
O
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 f, D costs included in capital cost.
Particulate precollection device (ESP,
fabric filter, venturi) prior to FGD
system required for proper operation of
SO- control system.
Particulate collection equipment (venturi
scrubber) is included in the FGD system.
Complete cost of all FGD equipment, the
labor and materials required for equip-
ment installation, and interconnecting
the system is included in the total
capital cost.
One or a number of direct cost items, or
the cost associated with one or a number
of direct cost items, are excluded from
the total capital cost.
Complete cost of all the indirect cost
elements, including interest during con-
struction, contractor's fees, engineer-
ing, legal expenses, taxes, insurance,
allowance for start-up, and spares, is
included in total capital cost.
One or a number of indirect cost items,
or the cost associated with one or a
number of indirect cost items, are ex-
cluded from the total capital cost.
The cost of a chemical fixation process
which stabilizes the flue gas cleaning
wastes prior to disposal is included in
the total capital cost.
The 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 PGD 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-*
generation facility included in the total
capital cost.
Bench scale or pilot plant studies to de-
termine process and design characteristics.
(continued)
A-15
-------
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 t D programs.
Capital expenditures for reagent supply
exceeds the amount required for the period
of initial operation.
Complete cost of all raw materials,
utilities, operating labor and maintenance
and repairs is included in the total
annual cost.
One or a number of direct annual cost items,
or the cost associated with one or a number
of direct annual cost items, are excluded
from the total annual cost.
Complete cost of all fixed cost elements,
including depreciation, interim replace-
ment, insurance, taxes, and interest, is
included in the total annual cost.
One or a number of fixed annual cost items,
or the cost associated with one or a
number of fixed annual cost items, are ex-
cluded from the total annual cost.
Plant and payroll overhead costs are in-
cluded in the total annual cost.
The cost of operating particulate collection
equipment included in the FGD system is in-
cluded in the total annual cost.
The treatment and disposal of flue gas
cleaning wastes that are handled by an
outside firm.
The cost of additional power-generating
capacity required to compensate for power
used by the FGD system.
A-16
-------
RESULTS OF COST ANALYSIS
The results of the operational FGD system survey are summarized
in Table A-4 and Section A-l. Table A-4 produces a summary of a
categorical analysis of the reported and adjusted capital and
annual costs for the operational FGD systems addressed in the
survey. Included in this categorical analysis are the ranges,
means, and standard deviation for all the various types and
categories of FGD systems examined. Section A-l summarizes the
reported and adjusted capital and annual costs for all the oper-
ational FGD systems addressed in the survey (Section A-2 summarizes
available cost data for nonoperational FGD systems).
In an attempt to further clarify and allow additional compar-
ison of costs between different FGD units, the adjusted fixed
annual costs were standardized. This was done by taking the
adjusted Total Direct and Indirect Capital Costs for each unit
and applying the identical rate for costs of depreciation, interim
replacement, taxes, insurance and capital. These new sums were
totaled, then added to the adjusted Variable Cost to determine
the Total Standardized Annual Costs. In this manner costs can be
compared based upon the assumption that Utilities can incur Fixed
Annual Costs at the same rate.
A-17
-------
TABLE A-4. CATEGORICAL RESULTS OP THE REPORTED AND ADJUSTED
CAPITAL AND ANNUAL COSTS FOR OPERATIONAL PGD SYSTEMS
CATEGORY
ALL
NEU
RETROFIT
TNROUAHAY PRODUCT
SALEADLE PRODUCT
LINESTONE
LINE
LINE/ALKALINE FLYASH
SODIUM CARDONATE
UELLNAN LORD
LIMESTONE/ALKALINE FLYASH
NA8NESIUN OXIDE
_____f»A»f TA|
RANGE
5.3-156.9
5.3-120.6
29.2-156.9
5.3-120.6
93.3-156.9
5.3- 99.5
29.2-120.6
85.9- 85.9
42.9-113.6
127.9-156.9
47.9- 47.9
156.7-156.7
, I/KM-
AV6
77.0
71.4
83.7
67.1
132.5
61.4
74.1
85.9
66.5
137.6
47.9
156.7
-REPORTED
DEV
36.9
30.0
42.7 2
29.2
23.5 3
27.6 1
29.7
ANNUAL, NILL8/KUH—
RANGE AV6 DEV
.3- 14.9
.3- 14.3
.1- 14.9
.3- 14.3
.3- 14.9
.6- 3.3
.3- 14.3
.0 «•••»- .0
33.3 2
13.7 14
.0 2
.0 •»•
.1- 2.1
.9- 14.9
.0- 2.0
••- .0
6.3
4.6
8.3
5.9
9.1
2.2
9.0
.0
2.1
14.9
2.0
.0
5.1
5.0
4.4
4.9
5.8
.8
4.5
.0
.0
.0
.0
.0
CAPITAL
RANGE
60.9-233.2
66.4-117.6
60.9-233.2
60.9-140.6
134.8-233.2
66.4-117.6
67.5-140.6
93.0- 93.0
60.9-107.9
134.8-134.8
71.5- 71.5
233.2-233.2
, «/KU-
AV6
94.2
85.5
103.6
87.0
184.0
93.1
88.9
93.0
76.6
134.8
71.5
233.2
--ADJU
DEV
35.2
16.9
43.8
21.2
49.2
21.9
21.1
.0
22.2
.0
.0
.0
DTCA _______
RANGE
2.7- 12.4
2.8- 8.7
2.7- 12.4
2.7- 8.7
12.4- 12.4
2.9- 6.6
2.7- 8.7
5.2- 5.2
3.2- 4.4
12.4- 12.4
2.8- 2.8
•*•*•- .0
ILL8/KMH—
AV6 DEV
5.5 2.4
5.2 2.0
5.8 2.6
5.2 1.9
12.4 .0
3.0 1.4
6.0 2.0
5.2 .0
3.6 .6
12.4 .0
2.8 .0
.0 .0
00
-------
PA UTH:TY FFD SURVEY: FEBRUARY - OARCH 1979
SECTION A-1
COST? FOP OPERATIONAL FliD SYSTEMS
UNIT DESCRIPTION
COST
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
ALABAMA ELECTt>IC CPO<=
TOMbl&flEE
7
179.Li Mrf (NET)
CAF-ACJTY FACTOR, r •*« 45
TOTAL CAHTAL. !/ )
COST FLfFNTS
44 65
35.9(1977) **•*..(
2.1(197°) *••«**(
C .E .H.J.L,? .
U.U.Y.Z
0)
0)
65
0)
C)
CENTRAL ILL I\OIS L7G4T
DUCK CREEK
1
41e.O M.1 (NF T)
CAPACITY FACTOR. ?
TOTAL CAPITAL, J/KW(YEAP>
TOT«L 'KNUAL, MILLS/KWH(YE A *)
COST ELEMENTS
• * *
93.3(197' )
C.E.J,"
0)
0)
C)
0)
COLU«6US & SCuTHFRN OHIO ELLC. CAPACITY FACTOR. 2 *fc 65 65
CONESVILLE TOT»L CAPITAL. t/KH(YfAP) 55.5(1975) 70.7(1977) 70.7(1977)
* TOTAL ANNUAL, PILLStK»n(YEAF) 5.c(197°) 7.4(1977) 7.4(1977)
411.0 MJ (NET) COST ELEMENTS S,C,J,*,3,U, C,E,J.P.S,U, C.E,J,f,S,U.
w,X,Y W.Y W.Y
4t 65 65
55.5(197?) 70.7(1977) «**•*•(
COLUIfcUS 8 SOUTHERN OHIO ELK. CAPACITY FACTOR, i
CONESVILLE TOT'L CAPITAL. 5/K*(YFAR)
f TOTAL ANNUAL, M ILLS /ICVh (YE A e ) 5.c(197?) *••*••( 0)
411.C H. (NET) COST ELEMENTS B .C . J .» ,S .1' , C.E.J.K.S.U.
W,X,Y W.Y
C)
( 0)
rUBUESNE LI6HT
1-4
510.0 HW (KLT)
CAPACITY FACTOP, Z
TOTAL CAPITAL. !/
CAPACITY FACTOR, X ••* " 65
TOTAL CAPITAL. S/KW(YEAR) 29.2(1972) 87.2(1977) 87.2(1977)
TOTAL ANNUAL. MILLS/KWH(YEAP) 8.4(1977) 4.1(1977) 4.4(1977)
COST ELEMENTS B.D,F,T,X B.C.E.J.K.S, 3,C,E
-------
FPA UTILITY F60 SURVEY: FEEfcUAfY - MARCH
SECTION A-1
COST5 FOR OPERATIONAL FGD 'YSTEMS
COST
UNIT DESCRIPTION COST DESCRIPTION REPORTED ADJUSTED STANDARDIZED
ADJUSTED
ifANSAS CITY POUfcR E LIGHT CAPACITY FACTOR, X 42 t5 65
LA CY&Nt TOT«L CAPITAL. I/KwmAR) 53.6(1972) 68.0(1977) 66,G(1977)
1 TOT'L ANNUAL, r. ILLS /KU HI Y« AP) 1.3(197") 3.5(19'7) 3.(1977)
t TOTAL ANNUAL, »-I LLS /KWH (YE A f ) «««.«*(1977) 5.8(1977) 6.2(1977)
1P6.C HW (NET) COST ELEMENTS C,E,H,J,0,T C.E.H.J.K.Q, C.t.H.J.K.C,
S.U.h S.U.V
LOUISVILLE 6*S & ELECTRIC CAPACITY FACTOR, I •** 65 65
CANE RUN TOTAL CAPITAL. $/KW«YFAR) 62.4(1977) 67.5(1977) 67.5(1977)
5 TOTAL ANNUAL. WILLS/KWH(YEAP) ««***•( 0) 5.6(1977) 5.6(1977)
190.0 Hri (N£T) COST ELEMENTS C.E.H.J C,E,H,J.K,S, C.E.H.J.K.S.
U.« U.W
LOUISVILLE CAS i ELECTRIC CAPACITY FACTOR. X •*« 65 65
CANE RUN TOTAL CAPITAL, J/dW(YEAP) 57.9(1977) ......( Q) **•**«( P)
i TOTAL ANNUAL, KILLS/KWH(YEAP) 3.2(197°) •****»( 0) •*****( P)
2St.O HW (NET) COST ELEMENTS C,E,H,X,S,V,
W
LOUISVILLE 6AS i. ELECTRIC CAPACITY FACTOR, Z «* 65 65
PADDY'S RUN TOTAL CAPITAL. I/KU(YEAP) 52.6(197') 76.4(1977) 76.4(1977)
* TOTAL ANNUAL, PILLS/KWHCYE A") *«***«( 0) 6.5(1977) 6.4(1977)
72.0 If (NET) COST ELEMENTS C ,E C.E.S.U.U C.E.S.U.h
MNNKOTA POWER COOPERATIVE CAPACITY FACTOR. ! «»* 65 65
•ILTON R. YOUN6 TOTAL CAPITAL, S/KW(YEAR> 05.9(1976) 93.0(1977) 93.0(1977)
? TOTAL ANNUAL, K1LLS/KWH{YEAP) ••***«( 0) 5.2(1977) 5.2(1977)
405.0 MM (NET) COST ELEMENTS C,E.H,P C.E,H,H,P.S, C.E.H.K.P.S.
U.W U.W
"ONTANA POWER CAPACITY FACTOR. » 76 65 «5
COL STRIP TOTAL CAPITAL, S/KW(YFAR> 77.1(1975) 77.2(1977) 77.2(1977)
1 TOTAL ANNUAL. KILLS/KUH(YFAP) «.**«*(1977) 4.1(1977) 4.0(1977)
360.0 Mi (NET) COST ELEMENTS B,C,E,J,P,T C.E,J,K,P,S, C,F,J,K,P,S,
U.W U.W
MONTANA POWER CAPACITY FACTOR, t 76 65 65
COLSTRIP TOTAL CAPITAL, S/KW(YEAR) 77.1(1975) 77.2(1977) 77.2(1977)
? TOTAL ANNUAL. PILLS/KWMYEAR) .3(1977) 4.1(1977) 4.1(1977)
360.0 HW (NET) COST ELEMENTS B.C.E.J.P.T C.E.J.K.P.S. C,E,J,K,P.S,
U.W U.W
NEVADA POWER CAPACITY FACTOR, X 67 65 65
REID GARDNER TOTAL CAPITAL, S/KU(YEAR) 42.9(1973) 60.9(1977) 60.9(1977)
1 TOTAL ANNUAL, 'ILLS/KWH(YEAC) 2.1(1977) 3.2(1977) 3.4(1977)
125.0 MM (NET) COST ELEMENTS B,D.E,P,S,U, B.D.E.P.S.U. B,D,E.P,S,U.
W.X N.X W,X
*•**•* INDICATES COST FIGURES NOT VET AVAILABLE
A - 20
-------
EPA UTILITY FID SURVEY: FEBRUARY - •AOCH 1979
SECTION A-1
COSTS FOR OPERATIONAL F6D SYSTEMS
UMIT DESCRIPTION COST DESCRIPTION REPORTED ADJUSTED STANDARDIZED
ADJUSTED
SEVADA POWER CAPACITY FACTOR^X 67 ..... 65 .......... 65
PEID GARDNER TOTAL CAPITAL. t/KW(YEAR) 42.«(1 3.3(1977)
740.0 Htf (NET) COST ELEMENTS a ,C . J , S ,U ,» , C.E.J.K.S.U, C,E.J,K.S,U,
Z W rf
NORTHERN STATES POWER CAPACITY FACTOR, I 72 65 65
SHER3URNE TOTAL CAPITAL. J/*W(YfAR) 47.9(1972) 71.5(1977) 71.5(1977)
2 TOTAL ANNUAL, MILLS/KWHC YE AP ) 2.0(1977) 2.6(1977) 3.5(1977)
740.0 Hri (NET) COST ELFftENTS 9,C,J,S,U,X, C.E.J.K.S.U, C,E,J.K,S,U.
z w w
PENNSYLVANIA POkER CAPACITY FACTOR. X 40 65 65
9RUCE MANSFIELD TOTAL CAPITAL, S/KWCYEAR) 120.6(1975) 102.1(1977) 1C2. 1(1977)
1 TOTAL ANNUAL, (• ILLS/KWH ( YE AP) 14.3(1977) 3.7(1977) 10.t(1977)
917.0 flf (NET) COST ELEMENTS B.C.E.G.I.L, C. E.G. I. M.S. C , E ,6 , I ,K . S ,
S.U.U.X U.W U.W
PENNSYLVANIA POWER CAPACITY FACTOR, t 40 45 ts
3RUCE HAMSF1ELD TOTA L CA PI TAL, S/
-------
CPA UTILITY FGD SUPVEY: FEtfcUAPY - MARCH 1
-------
EPA UTILITY FGD SURVEY: FEBRUARY - MARCH 1979
SECTION A-2
COSTS FOR NON-OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
ALA6AHA ELECTRIC COOP
TOM6IGBEE
T
179.0 Mrf (NET)
ARIZONA ELECTKIC POWER COOP
«PA:HE
T
195.0 KU (NET)
3ASIN ELECTRIC POWER COOP
LARA1IE DIVER
1
600.0 Hrf (NET)
COST DESCRIPTION
CAPACITY FACTOR. X
TOTAL CAPITAL, S/KW(YrAR)
TOTAL ANNUAL, MILLS /KWH (YF A" )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, S/Kw(YFAR)
TOTAL ANNUAL, MILLS /KWH ( YE AR)
COST ELEMENTS
CAPACITY FACTOR
TOTAL CAPITAL,
TOTAL ANNUAL, f
COST ELEMENTS
, X
S/KU(YFAR)
ILLS/KWH(YEAP)
REPORTED
C.E.J
44
31.6(7700) •
2.1(197") •
C.E ,H.J ,L,S .
U,W,Y,Z
»*»
66.2(1980) 1
C.E
ADJUSTED STANDARDIZED
ADJUSTED
65 65
65 65
65 £5
3AS1N ELECTRIC P3xER COOP
LARA^IE RIVER
CAPACITY FACTOR, X
TOTAL CAPITAL. S/
.0 MW (NET)
TOTAL ANNUAL, n I LL 5 /KWH t YF AB ) *••»••» rj } •****•(
COST ELEMENTS C ,E
CAPACITY FACTOR. X «* • 45
COST ELEMENTS B.C
CAPACITY FACTOR. X ••* 65
TOTAL CAPITAL, 1/KW(YEAR) 63.4(1972) *•**»•(
TOTAL ANNUAL, f ILLS /KWH ( YE AP ) 3.0(1974) •«**«•(
COST ELEMENTS 8,C,E,N,0
65
65
0) ****** ( C)
CENTRAL ILLINOIS PUBLIC SERV CAPACITY FACTOR. X •*• 65 65
NEWTON TOTAL CAPITAL, S/KW(YEAR) 189.0(1979) •«*«•«{ 0) •••*«•( C)
"'" TOTAL ANNUAL, MILLS/KWH(YEAP) «***•*( D) •*«***( 0) ••*•«*( 0)
617.0 N* (NET) COST ELEMENTS C.E,6
COLORADO UTE ELECTRIC ASSN.
CRA1B
1
4*7.0 HU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, I/KU(YFAR)
TOTAL ANNUAL. MILLS/KWH(YEAP)
COST ELEMENTS
*** 65
117.0(197°) ••**«•( 0)
.«....( 3) ......( 0)
B,D,E
65
C)
0)
COLORADO UTE ELECTRIC ASSN.
CRAIS
2
447.0 NW (NET)
CAPACITY FACTOR, X «** 65 65
TOTAL CAPITAL, S/KHCYEAR) 117.0(1975) «••*•*( 0> *•*•*•( 0)
TOTAL ANNUAL, HILLS/KMH(YEAR) •«*•**( 0) *••*••( 0> •«**.*( 0)
COST ELEMENTS *tC
COMMONWEALTH EDISON
"OWERTON
51
450.0 HU (NET)
CAPACITY FACTOR, X *** 6* *5
TOTAL CAPITAL, S/KW(YEAR) 117.7C1979) **«*•*( 0) •*•«•*( 0)
TOTAL ANNUAL. MILLS/KVHCYEAP) •*•*••! 0) •**•*•( 0) .*.**«( 0)
COST ELEMENTS C.E.H.J
****** INDICATES COST FI6URES NOT VET AVAILABLE
A- 23
-------
EPA UTILITY FbO SURVEY: FEfrfcUAFY - MARCH 1979
SECTION A-2
CCSTS FOR NON-OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
COMMONWEALTH EDISON
WILL COUMTY
1
.0 Hri (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL. S/KUCYEAR)
TOTAL ANNUAL, MILLS/KVH(YEAP)
COST ELEMENTS
49 65
113.0(1972) •***•*( 0>
13.111975) **•**•< 0)
6,C,E,G,J,«
65
******( 0)
******C 0)
DETROIT EDISON
ST. CLAIR
6
.0 MM (NET)
CAPACITY FACTOR. X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAP)
COST ELEMENTS
*** 65
80.3(1976) ******(
9.6(1976) ******(
B,C,E,J,N,X
65
0) «*****( 0)
0) »****«( 0)
ILLINOIS POWER COMPANY
WOOD RIVER
I,
.0 MW (NET)
CAPACITY FACTOR, I *** 65
TOTAL CAPITAL, S/KW(YEAR) 82.5(197?) •***•*(
TOTAL ANNUAL, fILLS/KWH(YEAP) ****•*( 0) «*«*«*(
COST ELEMENTS A.C,E.M,N
0)
0)
65
**•***( 0)
*****•( C)
PACIFIC POWER £ LIGHT
II* 9RID&ER
«
550.0 Mrf (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL. S/KU(YEAR)
TOTAL ANNUAL, MILLS/KWM(YEAP)
COST ELEMENTS
*•* 65
120.0(1979) •*****(
******( 0) ******(
C.E.J
65
0) ******(
0) »****•(
0)
0)
»OTO
-------
APPENDIX B
FGD PROCESS FLOW DIAGRAMS
THIS APPENDIX COMPRISES OPERATING FGD SYSTEMS
ARRANGED ALPHABETICALLY ACCORDING TO UTILITY
B-l
-------
SCRUBBED
GAS
to
MATER
SOLIDS
Louisville Gas and Electric, Cane Run 6
Dual Alkali FGD System: Simplified Process Flow Diagram
-------
LIME SILO
U)
FLUE GAS
BY-PASS
FLUE GAS FROM
ELECTROSTATIC
PRECIPITATOR
WATER
SOLID TO
ON-SITE
LANDFILL
Southern Mississippi Electric, A.B. Brown 1
Dual Alkali FGD System: Simplified Process Flow Diagram
-------
touts inn D«wr>
TOWi flUTin
I OW»t»
—
IOCATI
rur
»(HT
a
4
H
ON
J«(
>T[
U
—
Of
•
a
•
T
rn
--.
• runif
trains
» ( CHimfr J
TO OTHt«\ n
MnOUIf. ( •<"•
/ .&-
,A-
W
fl'«SM
conTinunus
«[CI»CUH'IWI
inor
~&~~
MT CTClOKtS
IMTd TO
lINfStOMt »t*
tmim
(ICCTCIC M»Tf»)
I socios I
\O^™^^^B
Texas Utilities,
Simplified Process Flow Diagram for One of the Three Identical
Martin Lake FGD Systems
-------
APPENDIX C
DEFINITIONS
C-l
-------
DEFINITIONS
Boiler Capacity Factor:
Boiler Utilization Parameters:
Byproduct
Disposal
Efficiency:
Particulate Matter
SO.
FGD Viability Indexes
(kWh generation in year)/maxi-
mum continuous generating
capacity in kw x 8760 hr/yr).
Hours boiler operated/hours in
period, expressed as a percen-
tage.
The nature (e.g. elemental
sulfur, sulfuric acid) and
disposition (e.g. stockpile on
site, marketed) of the end
product produced by systems
that generate a saleable
product.
Disposal method for throwaway
product systems producing
sludge including: stabilized
or unstabilized sludge, inter-
im and final disposal sites
and disposal type (minefill,
landfill, etc.) as well as
disposal location.
The actual percentage of
particulate matter removed by
the emission control system
(mechanical collectors, ESP,
or fabric filter and FGD) from
the untreated flue gas.
The actual percentage of S0_
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 avail-
able.
Several parameters have been
developed to quantify the
viability of FGD system tech-
nology. Various terms such as
"availability," "reliability,"
"operability," and "utiliza-
tion" are used to accurately
02
-------
Availability Index
Reliability Index
represent the operation of any
FGD system during a _given
period. The above-mentioned
parameters are defined below
and discussed briefly. The
objectives of this discussion
are to make the reader aware
that several different defini-
tions are being used and to
select appropriate parameters
that can be used for reporting
purposes so that reasonably
consistent comparisons can be
made.
Hours the FGD system is avail-
able for operation (whether
operated or not) divided by
hours in period, expressed as
a percentage. This parameter
tends to overestimate the
viability of the FGD system
because it does not penalize
for election not to operate
the system when it could have
been operated. Boiler down-
time may tend to increase the
magnitude of the parameter
because FGD failures generally
cannot occur during such
periods.
Hours the FGD system was
operated divided by the hours
the FGD system was called upon
to operate, expressed as a
percentage. This parameter
has been developed in order
not to penalize the FGD system
for elected outages, e.g.,
periods when the FGD system
could have been run but was
not run because of chemical
shortages, lack of manpower,
short duration boiler opera-
tions, etc. The main problem
in using this formula is the
concise determination whether
or not the system was "called
upon to operate" during a
given time period. In addi-
tion/ an undefined value can
C-3
-------
FGD Operability Index
FGD Utilization Index
End Product
Saleable
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
operated divided by boiler
operating hours in period,
expressed as a percentage.
This parameter indicates the
degree to which the FGD system
is actually used, relative to
boiler operating time. The
parameter is penalized when
options are exercised not to
use the FGD system in periods
when the system is operable.
In 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 para-
meter is a relative stress
factor forM£hQ,FGD system. It
is not a complete measure of
FGD system viability because
the parameter can be strongly
influenced by conditions that
are external to the FGD system
(e.g., infrequent boiler
operation will lower the value
of the parameter although the
FGD system may be highly
dependable in its particular
application).
The SO- removed from the flue
gas is recovered in a usable
or marketable form (e.g.,
sulfur, sulfuric acid, gypsum,
ammonium sulfate, sodium
sulfate).
C-4
-------
Energy Consumption, %
Throwaway 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.
The percentage of gross unit
electrical generating capacity
consumed by the FGD system, as
defined by the following
equation:
[Net MW w/o FGD - Net MW w/FGD]/
Gross unit rating]
Equivalent Scrubbed Capacity (ESC) The effective scrubbed flue
gas in equivalent MW based on
the percent of flue gas scrubbed
by the FGD system.
FGD Status:
Category 1
Category 2
Category 3
Category 4
Category 5
Category 6
Operational - FGD system is in
service removing SO-.
Under Construction - ground
has been broken for installation
of FGD system, but FGD system
has not become operational.
Planned, Contract Awarded -
contract has been signed for
purchase of FGD system but
ground has not been broken for
installation.
Planned, Letter of Intent
Signed - letter of intent has
been signed, but legal con-
tract for purchase has not
been awarded.
Planned, Requesting/Evaluating
Bids - bid requests have been
released but no letter of
intent or contract has been
issued.
Considering only FGD Systems -
an FGD system is proposed as a
means to meet an S02 regulation.
C-5
-------
Category 7
Category 8
FGD Vendor
Fuel Characteristics
General Process Type
New
Process Additives
Process Type
Considering an FGD system as
well as alternative methods.
Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended
indefinite period of time.
A firm that fabricates and
supplies flue gas desulfuriza-
tion systems.
Type of fuel, average gross
heating value in Btu/lb.
average percent ash and
average percent sulfur content
for fuel as fired.
2
The manner in which the SO
from the flue gas is collected,
e.g. wet scrubbing, spray
drying, dry adsorption.
FGD unit and boiler were
designed at the same time or
space for addition of an FGD
unit was reserved when boiler
was constructed.
A chemical compound or element
which is added to the process
or normally found with the
main process reagent in small
quantities (e.g. Mg, adipic
acid) to prolhote improved
process operation (e.g. scale
reduction, increased S02
removal efficiency).
Company name if process is
patented. Generic name if
several companies have similar
processes (e.g., Lime, Limestone,
Wellman Lord, Thoroughbred
121).
C-6
-------
Regulatory Class
Retrofit
Start-up Date
Total Controlled Capacity [TCC]
Total FGD System Lost
Generation Factor
Unit Location
A. New boiler constructed
subject to Federal New
Source Performance Stan-
dards (NSPS), 8/17/71.
B. Existing boiler subject
to State Standard that is
more stringent than the
NSPS, 8/17/71.
C. Existing boiler subject
to State Standard that is
equal to or less stringent
than NSPS, 8/17/71.
D. Other (unknown, undeter-
mined) .
FGD unit will be/was added to
an existing boiler not specifi-
cally designed to accommodate
FGD unit.
Date when initial S02 removal
began or is scheduled to
begin.
The gross rating (MW) of a
unit brought into compliance
with FGD, regardless of the
percent of flue gas treated at
the facility. In the case of
prototype and demonstration
FGD systems, this figure will
be identical to the Equivalent
Scrubbed Capacity rather than
the gross unit rating if the
system is not meant to bring
the facility into compliance
with SC>2 emission standards.
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.
City and State listed in
mailing address.
C-7
-------
Unit Name
Unit Rating
Gross
Net w/FGD
Net w/o FGD
Utility Name
Water Make-Up
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; Preoperational
- maximum continuous design
generation capacity in MW.
Gross unit rating less the
energy required to operate
ancillary station equipment,
inclusive of emission control
systems.
Gross unit rating less the
energy required to operate
ancillary station equipment/
exclusive of emission control
systems. "-•:••*
Name of corporation as it
appears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - as space permits.
Gallons per minute of make-up
water required per MW of
capacity.
C-8
-------
APPENDIX D
TABLE OF UNIT NOTATION
D-l
-------
TABLE OF UNIT NOTATION
D
10
Classification
Area
Concentration
Flow
Heat Content
Length
L/C Ratio
Haas/Height
Pressure
Temperature
Volume
L'nqli&h Unit
Ac r c-
Square foot
Grains pet standard
cubic foot
Parts per million
Pounds per million
Btu
Actual cubic feet
per minute
Gallons per minute
Pounds per minute
Ton per day
Ton per hour
Btu per pound
Foot
Inch
Mile
Gallons per
thousand actual
cubic feet
Pound
Ton
Inches of water
Degree Fahrenheit
Cubic feet
Acre-feet
Symbol
acre
ft*
tjr/scf
PP«> 6
lb/10 Btu
f t3/rain
(actual)
gal/min
Ib/min
t/day
t/h
Btu/lb
ft
in
mi
gal/1000
ftJ
(actual)
Ib
t
in. HjO
•P
ft3
Acre- ft
Survey Report
Notat ion
ACRE
SQ. FT
GR/SCF
PPM
LB/MMBTU
ACFM
GPM
LB/MIN
TPD
TPH
BTU/LB
FT
IN
HI
GAL/1000ACF
LB
T
IN. H20
F
CU.F
ACRE-FT
ASTM/SI Unit
Square meter
Square meter
Grams per cubic meter
Parts per million
Nanograms per joule
Cubic meters per
second
Liters per second
Kilogram per second
Metric ton per day
Metric ton per hour
Kilojoule per
kilogram
Meter
Centimeter
Kilometer
Liters per cubic
me tar
Kilogram
Megagram
Kilopascal
Degree Celsius
Cubic meter
Cubic meter
Symbol
"2
M2
g/.3
ppm
ng/J
.V.
liter/s
kg/s
M t/d
M t/h
kJ/kg
m
cm
km
liter/m3
k9
Hg
kPa
•C
•I
Survey Report
Notation
SQ.M
SO.M
G/CU.M
PPM
NG/J
CU.M/S
LITER/S
KG/S
M T/D
N T/H
KJ/KG
M
CM
KM
LITER/CD. M
KG
MG
KPA
C
CU.M
CU.M
-------
TECHNICAL REPORT DATA
ff lease read Inunctions on the reverse before completing)
EPA-600/7-79-022d
3. RECIPIENT'S ACCESSION NO.
PLE AND SUBTITLE
EPA Utility FGD Survey: February-March 1979
5 REPORT DATE
July 1979
6. PERFORMING ORGANIZATION CODE
'. AUTHOR(S)
M.Smith, M.Melia, andT.Koger
8 PERFORMING ORGANIZATION REPORT NO.
PN 3470-1-C
9.
:ORMING OROANIZATION 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 48
12. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
Periodic; 2-3/79
14. SPONSORING AGENCY CODE
EPA/600/13
15.SUPPLEMENTARY NOTES EPA project officers are N. Kaplan (IERL-RTP, MD-61, 919/541-
2556) and J.C.Herlihy (DSSE, 202/755-9137). EPA-600/7-78-051a thru -d and EPA-
600/7-79-002a thru -c are previous reports in this series.
16. ABSTRACT
report is the second in a series of four generated by a new computer-
ized data base system. Because the three succeeding issues are supplements, the
first should be retained for reference throughout the year. The report differs from
the previous series in that the scope of design data for operating FGD systems is
vastly expanded, section formats are revised, and a new section includes operating
particulate scrubbers. The report surveys utility FGD systems in the U.S. It sum-
marizes information contributed by the utility industry, process suppliers, regula-
tory agencies, and consulting engineering firms. Systems are tabulated alphabetically
by development status (operating, under construction, or in planning stages), utility
company, process supplier, process, waste disposal practice, and regulatory class.
It presents data on system design, fuel sulfur content, operating history, and actual
performance. It includes unit by unit dependability parameters and discusses pro-
blems and solutions associated with the boilers and FGD systems. Process flow dia-
grams and FGD system economic data are appended. Current data shows 51 units
operating FGD systems, 42 systems under construction, and 69 planned units with
gross generating capacities of approximately 19,170, 17,377, and 40,115, respect-
ively. Total controlled capacity for 1988 is expected to be 76,OOP-plus MW.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.IDENTIFIERS/OPEN ENDED TERMS
c. COSATI Field/Group
Pollution
Flue Gases
Desulfurization
Electric Utilities
Waste Disposal
Boilers
Maintenance
Pollution Control
Stationary Sources
Utility Boilers
13 B
21B
07A,07D
15E
13A.
18. DISTRIBUTION STATEMENT
Release to Public
19. SECURITY CLASS (TMl Report)
Unclassified
185
20. SECURITY CLASS (Thispage)
Unclassified
22. PRICE
•PA Form 2220-1 (t-7J)
*U.S.GOVERNMEhfTPRINTlNGOmCE: 1979. 640-
D~3
39 10 REGION NO. 4
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