United States Office of Air Quality EPA-340/1-85-014a
Environmental Protection Planning and Standards October 1984
Agency Washington, D.C. 20460
Stationary Source Compliance Series
Utility FGD Survey
October 1983-
September 1984
Volume 1:
Categorical
Summaries of
FGD Systems Property0f
EPA Lfcrr..--,
RTPNC 27, 11
EPA LIBRARY SERVICES RTP NC
TECHNICAL DOCUMENT COLLECTION
-------
EPA-340/1-85-014a
Utility FGD Survey
October 1983 - September 1984
Volume 1: Categorical Summaries of
FGD Systems
M. T. Melia, R. S. McKibben,
and B. W. Pelsor
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
EPA Contract No. 68-02-3963
Work Assignment No. 46
EPA Project Manager: John Busik
EPA Work Assignment Manager: Sonya M. Stelmack
U.S. ENVIRONMENTAL PROTECTION AGENCY
Stationary Source Compliance Division
Office of Air Quality Planning and Standards
Washington, D.C. 20460
October 1984
-------
ACKNOWLEDGMENT
The EPA-SSCD Project Officer and authors of this report
appreciate the assistance provided by Norman Kaplan, the Project
Officer for the U.S. Environmental Protection Agency (Industrial
Environmental Research Laboratory, Research Triangle Park, North
Carolina) for the Flue Gas Desulfurization Information System
(FGDIS), in updating and maintaining the data base and his sug-
gestions on the content and format of the survey report (and
project summary) and on other project activities.
DISCLAIMER
This report was prepared for the U.S. Environmental Protec-
tion Agency by PEI Associates, Inc., Cincinnati, Ohio, under Con-
tract No. 68-02-3963, Work Assignment No. 46. The contents of
this report are reproduced herein as received from PEI Associates,
Inc. The opinions, findings, and conclusions expressed are those
of the authors and not necessarily those of the U.S. Environmental
Protection Agency. Mention of trade names or commercial products
is not intended to constitute endorsement or recommendation for
use. Copies of this report are available from the National
Technical Information Services, 5285 Port Royal Road, Springfield,
Virginia 22161.
11
-------
NOTICE
The data in this information transfer document are supplied
voluntarily by utility representatives, flue gas desulfurization
(FGD) system suppliers and designers, regulatory agencies, and
others. The accuracy or completeness of the information con-
tained herein is not warranted by the Stationary Source Control
Division of EPA or the designated contractor. Portions of the
work upon which this publication is based were performed pursuant
to Contract Nos. RP982-32 (Electric Power Research Institute) and
68-02-3173 (Environmental Protection Agency).
A project summary will be distributed to organizations and
individuals indicating a specific interest in the field of FGD
technology. Interested parties can be added to the Project
Summary mailing list by contacting Carolyn Fowler at the Indus-
trial Environmental Research Laboratory (919/541-2915) or the
secretary of the Emission and Effluent Technology Branch of the
EPA (919/541-2578) . Copies of preceding issues of this report
through December 1981 can be purchased from the National Tech-
nical Information Service, Springfield, Virginia 22161, (703)
487-4650. Succeeding issues of this report can be purchased from
the Electric Power Research Institute Research Reports Center,
P.O. Box 50490, Palo Alto, California 94303, (415) 965-4081.
This report summarizes the FGD system design and performance
data contained in a computerized data base known as the Flue Gas
Desulfurization Information System (FGDIS). Access to the FGDIS
is available through the National Technical Information Service
(NTIS) for a nonprofit user's fee. Users also have access to
additional design and performance data stored within the data
base that cannot conveniently be printed in this report. Direct
access to the data base affords analyses of the data (e.g.,
averages, maxima, minima, and standard deviations of various
parameters), the use of simple mathematical functions, the capa-
bility of virtually unlimited data cross-referencing, and data
tabulation to fit the user's individual information needs. An
FGDIS users manual is available from NTIS (NTIS No. PB 83 146
209) .
Requests for further information concerning the FGDIS and
periodic FGDIS training seminars should be directed to Michael
Melia or Skip Jones, PEI Associates, Inc. (513/782-4700). In-
formation concerning access to the FGDIS can be obtained from
Walter Finch, NTIS, 5285 Port Royal Road, Springfield, Virginia
22161 (703/487-4808).
iii
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USE OF THIS REPORT
This report is the first fully compiled edition since the
July 1982-March 1983 issue released in April 1984, which contains
more complete design and performance data since the FGS system
startup dates. This report supersedes all previous issues.
Volume 1 includes several categorical summaries of key data and
the appendix sections. Volume 2, Parts 1 and 2 contain all
available design and performance data for operational FGD systems
(Section 13).
The Executive Summary contains the number and capacity of
FGD systems as of the end of December 1984, future (December 1993)
projections of controlled and uncontrolled generating capacity,
and unit-by-unit summaries of status changes (e.g., contract
awarded, under construction, or operational) and performance and
status highlights for the period.
Appendix sections incl-ude definitions, a table of unit
notation and simplified process flow diagrams, as well as data
on terminated FGD systems, particle scrubbers and Japanese FGD
systems.
IV
-------
ABSTRACT
The Utility FGD Survey report, which is generated by a
computerized data base system, represents a survey of operational
and planned domestic utility flue gas desulfurization (FGD)
systems. The three volume set summarizes information contributed
by the utility industry, system and equipment suppliers, system
designers, research organizations, and regulatory agencies. The
data cover system design, fuel characteristics, operating
history, and actual system performance. Also included is a
unit-by-unit discussion of problems and solutions associated with
the boilers, scrubbers, and FGD systems.
The development status (operational, under construction, or
in the planning stages), system supplier, process, waste disposal
practice, and regulatory class are tabulated alphabetically by
utility company. Simplified process flow diagrams of FGD systems,
definitions, and a glossary of terms are attached to the report.
Current data for domestic FGD systems show 124 systems in opera-
tion, 25 systems under construction, and 68 systems planned. The
current FGD-controlled capacity in the United States is 47,255 MW.
v
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CONTENTS
Acknowledgment
Notice
Use of This Report
Abstract
Tables and Figures
Executive Summary
Highlights
Section 1
Section 2
Section 3
Section 4
Section 5
Section 6
Section 7
Section 8
Section 9
Section 10
Section 11
Section 12
Appendix A
Appendix B
Appendix C
(Continued)
Summary List of FGD Systems
Status of FGD Systems
Summary of FGD Systems by Company
Summary of FGD Systems by System Supplier
Summary of FGD Systems by Process
Summary of Operational FGD Systems by
Process and Unit
Summary of End-Product Disposal
Practices for Operational FGD Systems
Summary of FGD Systems in Operation
Summary of FGD Systems Under Construction
Summary of Contract-Awarded FGD Systems
Summary of Planned FGD Systems
Total FGD Units and Capacity (MW)
Installed, by Year
Definitions
Table of Unit Notation
FGD Process Flow Diagram
VI
Page
11
iii
iv
v
viii
ix
xx
1-1
2-1
3-1
4-1
5-1
6-1
7-1
8-1
9-1
10-1
11-1
12-1
A-l
B-l
C-l
-------
APPENDIX (continued)
Appendix D Design and Performance Data for Operational
Particle Scrubber
Commonwealth Edison
Will County 1 D~l
Minnesota Power & Light
Clay Boswell 3 D-27
Syl Laskin 1 D-30
Syl Laskin 2 D-34
Montana-Dakota Utilities
Lewis & Clark 1 D-38
Pacific Power & Light
Dave Johnston 4 D-42
Potomac Electric Power
Dickerson 1 D-45
Dickerson 2 D-48
Dickerson 3 D-51
Public Service of Colorado
Arapahoe 4 D-58
Cherokee 1 D-62
Cherokee 4 D-65
Valmont 5 D-68
Southwestern Public Service
Harrington 1 D-75
Appendix E Design and Performance Data for Operational
Foreign FGD Systems E-l
Appendix F Design and Performance Data for Terminated
FGD Systems F-l
vn
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TABLES
Number Page
1 Number and Total Capacity of FGD Systems ix
2 Summary of Status Changes, October 1983 -
September 1984 xi
3 Power Generation Sources: Present and Future xiii
4 Power Production by Source xiii
5 FGD-Controlled Generating Capacity: Present
and Future xvi
6 Summary of FGD Systems by Process xvii
7 Categorical Results of the Reported and Adjusted
Capital and Annual Costs for Operational FGD
Systems xviii
FIGURES
Number
1
2
Computerized Data Base Structure Diagram
History of Utility Projections for Operational,
Under Construction, and Planned FGD Capacity
December 1970 through September 1984
Actual and Projected Coal-Fired Generating
Capacity and FGD Capacity, 1984
Page
x
xiv
XV
Vlll
-------
EXECUTIVE SUMMARY
This report is prepared by PEI Associates, Inc., under
contract to the Stationary Source Control Division of the U.S.
Environmental Protection Agency in conjunction with the Indus-
trial Environmental Research Laboratory/Research Triangle Park of
the U.S. Environmental Protection Agency. It is generated by a
computerized data base system, the structure of which is il-
lustrated in Figure 1.
Table 1 summarizes the status of flue gas desulfurization
(FGD) systems in the United States as of the end of September
1984. Table 2 lists the units on which the status has changed
during the October 1983-September 1984 period. The units includ-
ed in the figures presented in Table 1 are identified in Table 3.
TABLE 1. NUMBER AND TOTAL CAPACITY OF FGD SYSTEMS
Status
Operational
Under construction
Planned:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only FGD
systems for S02 control
TOTAL
No. of
units
124
25
15
3
4
46
217
Total
controlled
capacity, MW
50,870
14,656
9,248
2,500
1,926
27,512
106,712
Equivalent
scrubbed
capacity, MW
47,255
14,335
9,190
2,500
1,926
26,869
102,075
Summation of the gross unit capacities (MW) brought into compliance by the
use of FGD systems, regardless of the percentage of the flue gas scrubbed
by the FGD system(s).
Summation of the effective scrubbed flue gas capacities in equivalent MW,
based on the percentage of flue gas scrubbed by the FGD system(s).
IX
-------
FLUE GAS DESULFUR1ZATION INFORMATION SVS1EM
X
Figure 1. Computerized data base structure diagram.
-------
TABLE 2. SUMMARY OF FGD SYSTEM STATUS CHANGES, OCTOBER 1983-SEPTEMBER 1984
FGD status report
September 30. 1983
Arizona Public Service
Choi la 5
Big Rivers Electric
D.B. Wilson 1
Boston Edison
New Boston 1
New Boston 2
Central Illinois light
Duck Creek 2
Cincinnati Gas & Electric
Zinroer 1
Colorado Ute Electric
Craig 3
Deseret Generating I Transmission
Bonanza 1
General Public Utilities
Coal 1
Jersey Central Power ft Light
N/D 1
Los Angeles Dept. of Hater ft Power
Intel-mountain 2
Lower Colorado River Authority
Fayette Power Project 3
Fayette Power Project 4
Middle South Utilities
Arkansas Lignite 5
Arkansas Lignite 6
Unassigned 1
Unassigned Z
Montana Power
Colstrip 3
Operational
No.
116
+ 1
+ 1
*1
+ 1
MWa .
43,206°
440
447
410
778
Under
construction
No.
?6
-1
-1
-1
+ 1
+1
-1
HW »
14,609°
440
447
410
820
451
778
Contract
awarded
No.
21
-1
-1
MM8
12,635
820
451
letter
of intent
No.
7
-1
-1
-1
-1
«w8
6,060
890
890
890
890
Requesting/
eval. bids
No.
3
+1
+ 1
-1
MW\
l,840b
388
388
690
Considering
FGD
No.
41
»1
-]
+ 1
+ 1
-1
+ 1
rw «
23,549b
126
450
1,386
690
625
451
Total
No.
214
+1
+ 1
+ 1
-1
+ 1
-1
+ 1
-1
-1
-1
-1
MW*
101 ,899°
126
388
388
450
1,386
625
451
890
890
890
890
-------
TABLE 2 (continued)
x
(-••
K-
FGD status report
September 30, 1983
New York State Electricity i Gas
Somerset
Orlando Utilities Commission
C. H. Stanton 1
Pacific Power & Light
Jim Bridger 2
Wyodak 1
Platte River Power Authority
Rawhide 1
Public Service Company of Colorado
Pawnee 2
San Antonio Public Service
N/D 3
N/D 1
Seminole Electric
Seminole 2
South Carolina Public Service
Cross 2
Southern Indiana Gas * Electric
A.B. Brown 2
Southwestern Electric Power
Oolet Hills 1
Southwestern Public Service
South Plains 1
West Texas Utilities
Oklaunlon 1
Total
Operational
No.
1!6
+ 1
+ 1
+ 1
+ 1
124
MWS .
43.2066
625
279
620
450
47,255
Under
construction
No.
26
-1
+ 1
+ 1
-1
-1
-1
+1
+ 1
+ 1
25
MW8 .
14,609
625
465
550
279
620
450
265
720
504
14,335
Contract
awarded
No.
21
-1
-1
+ 1
-1
-1
-1
15
MWa
1?,635
465
550
330
265
720
504
9,190
Letter
of intent
No.
7
3
MW3
6,060
2,500
Requesting/
eval. bids
No.
3
4
MWa .
1 ,840b
1,926
Considering
FGO
No.
41
-1
+ 1
+1
+ 1
+ 1
46
MWa ,
23, Wb
330
500
500
500
572
26,869
Total
No.
214
+ 1
+ 1
+ 1
+ 1
217
MWa .
101,899°
500
500
500
572
102,075
8 Equivalent scrubbed capacity.
b This value was modified slightly to reflect a MW correction.
-------
Figure 2 presents a historic breakdown of utility status
reports for operational, under-construction, and planned FGD
capacity. The operating FGD capacity has grown significantly
each year since 1972. Since 1977 the capacity under construction
has been fairly stable. The planned capacity reported by the
utilities has increased each year in the past until 1980, when it
reached its peak, and has dropped sharply since that time.
Figure 3 presents a comparison of actual coal-fired generat-
ing capacity and FGD capacity from 1975 through 1984 and projec-
tions thereafter through 1992. Although the retirement of older
units is taken into account in these plots, such retirements
affect only the overall coal-fired capacity rate because FGD-
controlled capacity represents primarily new power generating
capacity. This accounts for the slightly greater slope of the
lower line, which depicts FGD-controlled capacity.
Current projections estimate the total power-generating ca-
pacity of the U.S. electric utility industry will be 791 GW by
the end of 1992.6 (This value reflects the loss resulting from
the retirement of older units, which is considered to be approx-
imately 3.24 GW by the end of 1992.7) Approximately 345 GW, or
44 percent of the 1992 total, is estimated to be produced by
coal-fired units. Table 3 presents a distribution of present
(December 1983) and future (December 1992) power generation
sources.
TABLE 3. POWER GENERATION SOURCES: PRESENT AND FUTURE
,6,7
Coal
December 1983 43%
December 1992 44%
Nuclear
11%
16%
Oil
20%
17%
Hydro
12%
11%
Gas
13%
11%
Other
1%
1%
Total generating
capacity, GW
671
791
It is interesting to note that the breakdown for the actual
power produced by these sources during the past year (Table 4)
differs appreciably, especially for coal- and oil-fired sources,
from the power generating capacity shown in Table 3. This is due
to the effect of the changing economy on the operation of various
types of powerplants.
TABLE 4. POWER PRODUCTION BY SOURCE8
Coal
January-December 1983 55%
Nuclear
13%
Oil
6%
Hydro
14%
Gas
12%
Other
0
Total energy
generated, GWh
2,308,746
Xlll
-------
no
100
90
i 80
o
0
170
t—
-------
450
400 -
350 -
300 -
250 -
i 200
150
100 «
50
i i i i i i i
COAL-FIRED CAPACITY
FGD-CONTROLLED CAPACITY
ACTUAL CAPACITY
PROJECTED CAPACITY
;:*;&&^
75 76
77 78 79 80 81 82 83 84 85 86 87
YEAR*
89 90 91 92
YEAR-END TOTALS
Figure 3. Actual and projected coal-fired qeneratinq
capacity and FGD capacity, 1984.1~7
xv
-------
Based on known commitments of utilities to FGD (as presented
in Table 1) and other coal-fired generating capacity expected to
be required to incorporate FGD (Figure 3), current and projected
percentages of electrical generating capacity controlled by FGD
are shown in Table 5.
TABLE 5. FGD-CONTROLLED GENERATING CAPACITY: PRESENT AND FUTURE
1,6
September 1984a
December 1992
Coal -fired generating capac-
ity controlled by FGD, %
17.2
31.0
Total generating capaci
controlled by FGD, %
ty
7.4
13.6
The September 1984 FGD capacity figures are based on reports by utilities.
The figures used for the total generating capacity and the December 1992
coal-fired generating capacity are based on December 1982 DOE projected
figures.
Table 6 shows both the current (September 1984) and project-
ed (December 1999) breakdown of throwaway-product FGD systems
versus salable-product FGD systems as a percentage of the total
known commitments to FGD.
Table 7 presents categorical FGD system cost data in common
1981 dollars.
xvi
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TABLE 6. SUMMARY OF FGD SYSTEMS BY PROCESS
(percentage of total MW)
Process
Throwaway-product process
Wet systems
Lime
Limestone
Lime/alkaline flyash
Limestone/alkaline flyash
Dual alkali
Sodium carbonate
NAD
Dry systems
Lime
Sodium carbonate
NAD
Dry injection
Trona/dry injection
Saleable-product process
Aqueous carbonate/
spray drying
Limestone
Magnesium oxide
Wellman Lord
Process undecided
TOTAL
Byproduct
Elemental sulfur
Gypsum
Sulfuric acid
Sulfuric acid
September
1984
23.9
46.7
7.7
3.2
3.3
3.2
-
4.8
0.9
-
-
0.2
0.4
1.5
4.2
_
100.0
December
1999
13.2
43.1
4.3
1.5
2.2
3.1
1.8
6.2
0.4
2.2
0.5
0.1
1.4
0.7
1.9
17.4
100.0
December
1999
(Normalized)3
16.0
52.2
5.2
1.8
2.7
3.7
2.1
7.5
0.5
2.7
0.6
.
0.1
1.7
0.9
2.3
_
100.0
The effect of those systems listed as "Process undecided" is removed.
3NA - Not available (These systems are committed to a throwaway-product
process; however, the actual process is unknown at this time.)
xvn
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TABLE 7. CATEGORICAL RESULTS OF THE REPORTED AND
ADJUSTED CAPITAL AND ANNUAL COSTS FOR OPERATIONAL FGD SYSTEMS
All
New
Retrofit
Saleable
Throwaway
Alkaline
flyash/llme
Alkaline flyash/
limestone
Dual alkali
line
Limestone
Sod 1 un carbonate
Hellman Lord
Reported
Capital
Range. $/kW
23.7-213.6
23.7-213.6
29.4-157.4
132.8-185.0
23.7-213.6
43.4-173.8
49.3- 49.3
47.2-174.8
29.4-213.6
23.7-170.4
42.9-100.8
132.8-18S.O
Average,
$/W
80.2
80.4
79.7
153.1
75.8
93.9
49.3
97.8
81.8
67.9
69.2
153.1
o
44.3
46.1
39.4
20.6
41.5
44.0
0.0
55.3
43.7
37.2
26.6
20.6
Annual
Range,
mllls/kUh
0.1-13.0
0.1- 5.5
0.5-13.0
13.0-13.0
0.1-11.3
0.4- 5.4
0.8- 0.8
1.3- 1.3
0.3-11.3
0.1- 7.8
0.2- 0.5
13.0-13.0
Average,
mflls/kWn
2.3
1.7
4.5
13.0
2.1
2.1
0.8
1.3
3.2
1.6
0.4
13.0
0
2.8
1.8
4.4
0.0
2.4
1.9
0.0
0.0
2.7
2.2
0.1
0.0
Adjusted
Capital
Range, $/kW
38.3-282.2
38.3-263.9
60.4-282.2
254.6-282.2
38.3-263.9
52.5-184.4
102.6-102.6
87.8-263.9
60.4-210.0
38.3-194.3
87.1-150.9
254.6-262.2
Average,
$/kW
118.8
110.8
139.3
271.6
110.9
122.8
102.6
146.7
116.5
98.9
110.9
271.6
0
58.1
48.4
73.8
12.1
47.6
51.4
0.0
82.9
44.2
44.0
26.4
12.1
Annual
Range,
mllH/kWh
1.6-20.8
1.6-14.6
4.3-20.8
16.7-20.8
1.6-17.6
3.0-14.1
5.4- 5.4
5.0-13.9
4.0-17.6
1.6-14.6
5.8- 7.4
16.7-20.8
Average,
mills/kWh
7.6
6.8
9.7
18.1
7.0
7.2
5.4
8.7
8.1
6.1
6.4
18.1
a
4.1
3.Z
5.3
1.9
3.4
3.8
0.0
3.6
3.6
3.1
0.7
1.9
X
<
K-
H-
H-
-------
HIGHLIGHTS: OCTOBER 1983-SEPTEMBER 1984
The following paragraphs highlight FGD system developments
during the period of October 1983 through September 1984.
Arizona Electric Power reported that the Apache 2 and 3
limestone FGD systems demonstrated high dependabilities
during the months of October 1983 through July 1984. No
major FGD-related problems were encountered.
Arizona Public Service announced plans to construct a new
unit, Cholla 5, in Joseph City, Arizona. The 375-MW (gross)
pulverized-coal-fired boiler (supplied by Combustion Engineer-
ing) will have an FGD system for the control of S02 emissions.
The unit is scheduled to start up in 1997.
Atlantic City Electric announced that they have postponed
indefinitely their plans to install Cumberland 1 in Milville,
New Jersey, because power demand has not met projections.
Basin Electric Power reported that the limestone FGD systems
on Laramie River 1 and 2 achieved high dependabilities
during most of the period. Minor FGD-related problems
encountered included maintenance on welds in the quencher
section on Unit 2 and repairs to the absorber recycle and
feed tank mixers on both units.
Big Rivers Electric reported that initial operation of the
FGD system on D. B. Wilson 1 in Centertown, Kentucky, began
in September 1984. This 440-MW (gross) unit fires coal with
an average sulfur content of 3.75 percent. The emission
control system consists of an ESP followed by an M. W.
Kellogg wet-lime FGD system.
New Boston 1 and 2 of Boston Edison in Boston, Massachusetts,
are being converted from oil- to coal-fired units. The
388-MW (gross) Babcock and Wilcox units will fire subbitumin-
ous coal with an average sulfur content of 2.3 percent and
heat content of 12,600 Btu/lb. Bids are currently being
requested/evaluated for a wet-limestone FGD system with
salable gypsum byproduct recovery. Particulate control will
be provided by ESP's, and the flue gas will exit via a
359-ft acid-brick-lined stack. Forced oxidation will be
xix
-------
utilized for sludge treatment. New Boston 1 and 2 are
scheduled to start up in October 1987 and June 1988 respec-
tively -
Cajun Electric Power announced that their plans to install
Oxbox 1 in De Soto Parish, Louisiana, have been postponed
indefinitely because power demand has not met projections.
Central Illinois Light reported that the Duck Creek 1 lime-
stone FGD system demonstrated high dependabilities during
the period of October 1983 through July 1984, except during
May, when the FGD system was down for general inspection and
maintenance. The utility also announced that they had
cancelled plans for the construction of a second unit at the
Duck Creek Station in Canton, Illinois, because of a reduction
in projected power demand.
Central Illinois Public Service reported that the Newton 1
dual-alkali FGD system demonstrated high dependabilities
during the period of October 1983 through August 1984,
except for June, when the FGD system was down because of
repairs to the absorber tower lining.
Cincinnati Gas and Electric announced plans to convert the
Zimmer 1 nuclear facility in Moscow, Ohio, to coal. The
retrofit 1386-MW (gross) coal-fired boiler will have an FGD
system for control of S02 emissions. The unit is scheduled.
to start up in 1991.
Colorado Ute Electric indicated that initial operation of
the FGD system on Craig 3 in Craig, Colorado, commenced in
June 1984. This 447-MW (gross) unit fires coal with an
average sulfur content of 0.45 percent. Babcock and Wilcox
supplied this lime/spray drying process. A fabric filter is
used for particulate removal.
Cooperative Power, not Buckeye Power as previously reported,
plans to construct a 750-MW (gross) unit in Ohio. The
facility has not yet been named, nor has a site been finalized.
This unit is expected to fire Ohio coal. A wet-limestone
FGD system will control S0? emissions, and ESP's will control
particulate emissions. Initial startup is tentatively
scheduled for 1994.
Deseret Generating and Transmission reported that initial
operation of the FGD system on Bonanza 1 in Vernal, Utah,
began in September 1984. This 410-MW (gross) unit fires
coal with an average sulfur content of 0.5 percent. Combus-
tion Engineering supplied the wet-limestone FGD system. A
fabric filter supplied by Ecolaire is used to control particu-
late emissions. The unit operates in a closed-water-loop
mode and the sludge is disposed of in an onsite landfill.
xx
-------
General Public Utilities, not Jersey Central Power & Light
as previously reported, will be the operating utility of the
690-MW (gross) Coal 1 unit (reported earlier as 625 MW).
The unit and FGD system are still in the planning stage.
The coal-fired (3.5 percent sulfur) unit is scheduled to
start up sometime in 1993.
Iowa Electric Light and Power announced that they are post-
poning indefinitely their plans to install Guthrie County 1
in Panora, Iowa, because power demand has not met
projections.
Kentucky Utilities announced that they have postponed indefin-
itely their plans to install a second unit at the Hancock
station in Hawesville, Kentucky, because of a reduction in
projected power demand.
The Los Angeles Department of Water and Power reported that
the FGD system on Intermountain 2 in Delta, Utah, is now
under construction. Fabric filters will control particulate
emissions from this 820-MW (gross) unit. The wet limestone
FGD system will control S02 in the flue gas downstream from
the particulate collection equipment. Flue gas reheat will
be provided by in-line heat exchangers prior to the 710-foot
stack. The fly ash-stabilized sludge will be disposed of on
site at this closed-loop facility. The unit is expected to
begin operations in July 1987.
The Lower Colorado River Authority reported that the Fayette
Power Project 3 in La Grange, Texas, is now under construction.
This lignite-fired 451-MW (gross) unit will be equipped with
a wet-limestone FGD system designed to remove 90 percent of
the S02. An ESP supplied by Flakt will control particulate
emissions, and the cleaned flue gas will exit through a
535-ft acid-brick-lined stack. Sludge will be disposed of
in an onsite landfill. The unit is expected to begin opera-
tions in November 1987. The utility also announced plans to
construct a fourth unit at the Fayette Power Project Station
in La Grange, Texas. This lignite-fired (1.7 percent sulfur,
4300 Btu/lb) boiler will also use a wet-limestone FGD system
for S02 control and ESP's for particulate removal. Initial
startup is scheduled for June 1990.
Middle South Utilities announced the cancellation of their
plans to install Arkansas Lignite 5 and 6 and two other
plants (name undecided), which were to be located in Louisiana,
The utility has also announced that they have postponed
indefinitely their plans to install Wilton 1 and 2 in Convent,
Louisiana, because of a reduction in projected power demand.
Minnesota Power and Light reported that the Clay Boswell 4
lime/alkaline fly ash FGD system demonstrated high dependa-
bilities during the months of October 1983 through June
1984. No major FGD-related problems were encountered.
xxi
-------
Minnkota Power reported that the Milton R. Young 2 lime/al-
kaline fly ash FGD system demonstrated high dependability
during the period of October 1983 through June 1984, except
during December and January, when the system was shut down
for repairs on the absorber spray recycle system.
Montana Power reported that initial operation of the FGD
system on Colstrip 3 in Colstrip, Montana, began in October
1983. This 778-MW (gross) unit fires low^sulfur coal (0.7
percent sulfur, 8500 Btu/lb). The lime/alkaline fly ash FGD
system was supplied by Bechtel/Montana Power. Particle
scrubbers are used to control particulate emissions, and the
system operates in a closed-water-loop mode. Flue gas exits
via a 692-ft stack.
New York State Electric and Gas indicated that initial oper-
ation of the FGD system on Somerset 1 in Somerset, New York,
began in September 1984. This 625-MW (gross) unit fires
coal with an average sulfur content of 2.2 percent. A
cold-side ESP with a design efficiency of 99.7 percent is
used for particulate control. The wet-limestone FGD system
was supplied by Peabody Process Systems. The system operates
in a closed-water-loop mode, and the flue gas exits via a
450-ft stack. The sludge is dewatered and stabilized before
being landfilled.
Nevada Power reported that the Reid Gardner 1, 2, 3, and 4
sodium carbonate FGD systems demonstrated high dependabili-
ties during the months of October 1983 through August 1984.
Only minor FGD-related problems were encountered.
Northern Indiana Public Service reported that the Schahfer
17 dual-alkali FGD system demonstrated high dependabilities
during the months of October 1983 through July 1984. No
major FGD-related problems were encountered.
Orlando Utilities Commission announced that the Combustion
Engineering wet-limestone FGD system on C. H. Stanton 1 in
Orlando, Florida, is now under construction. The utility
will control particulate emissions with an ESP. Initial
startup is scheduled for 1987.
Pacific Power and Light announced that construction of the
retrofit wet sodium carbonate FGD system on Jim Bridger 2
began during the first quarter of 1984. The retrofit system
will treat 2,700,000 acfm of flue gas from a 550-MW (gross)
bituminous coal-fired boiler located in Rock Springs, Wyoming.
A cold-side ESP is currently in operation for primary particu-
late control. The FGD system will operate in a closed-water-
loop mode and flue gas will exit via a 500-ft stack. The
FGD system is scheduled to start up in 1986. The utility
also announced that a contract has been awarded to Joy
xxii
-------
Manufacturing/Niro Atomizer for a retrofit lime/spray-drying
system to control particulate matter and S02 emissions from
Wyodak 1. This 330-MW (gross) mine mouth plant is located
in Joliet, Wyoming, and has been operational since 1978.
The FGD system is scheduled to start up in 1986.
The Platte River Power Authority reported that initial
operation of the FGD system on Rawhide 1 in Wellington,
Colorado, began in December 1983. The 279-MW (gross) unit
supplied by Combustion Engineering fires low-sulfur coal
(0.34 percent sulfur, 8500 Btu/lb). Joy Manufacturing/Niro
Atomizer supplied the dry-lime FGD system for S02 control
and the fabric filters for particulate removal. The system
operates in a closed-water-loop mode, and sludge is disposed
of in a landfill. Flue gas exits via a 505-ft stack.
Public Service Company of Colorado has plans for a new unit,
Pawnee 2, to be located near Rush, Colorado. The 500-MW
(gross) Babcock & Wilcox boiler will fire subbituminous coal
(0.35 percent sulfur, 8290 Btu/lb). Fabric filters will be
utilized for particulate removal and S02 emissions will be
controlled through injection of dry trona. The trona will
be pulverized and blown into the ductwork upstream of the
fabric filter system for contact with flue gas on the duct
and fabric filter surfaces. Flue gas will exit via a 500-ft
stack. Initial startup of the unit is scheduled for 1990.
Public Service of New Mexico reported that the San Juan 1,
2, and 3 Wellman Lord FGD systems achieved high dependabili-
ties for most of the period. Minor FGD-related problems
encountered included replacing the absorber lining, repairing
absorber trays, and replacing broken mist eliminator pads.
San Antonio Public Service reported plans to construct four
new units (name and location undecided) instead of two, as
previously reported. The lignite-fired (1 to 2 percent
sulfur, 5600 Btu/lb) units will have a gross megawatt rating
of 500 each and each will have a wet-limestone FGD system.
The four units are scheduled to commence operations in 1993,
1995, 1999, and 2001, respectively.
Seminole Electric reported that initial operation of the FGD
system on Seminole 2 in Palatka, Florida, began in September
1984. This 620-MW (gross) unit fires coal with an average
sulfur content of 2.75 percent. The Peabody Process Systems
wet-limestone FGD system is downstream of an ESP used for
particulate control. The cleaned flue gas exits via a
675-ft stack. The utility also announced they have indefin-
itely postponed their plans to install Taylor 1 and 2 in
Perry, Florida, because power demand has not met projections.
XXlll
-------
South Carolina Public Service reported that initial opera-
tion of the FGD system on Cross 2 in Cross, South Carolina,
began in October 1983. This 450-MW (gross) unit fires coal
with an average sulfur content of 1.8 percent. The wet-lime-
stone scrubbing system, supplied by Peabody Process Systems,
controls S02 emissions, and a cold-side ESP controls
particulate emissions. The system operates in a closed-water-
loop mode, and the cleaned flue gas exits via a 600-ft
stack. The utility also announced that the Winyah 2 limestone
FGD system achieved high dependabilities during the months
of October 1983 through March 1984. Minor FGD-related
problems encountered included cleaning the mist eliminators
and repairing frozen slurry and water pipe lines.
South Mississippi Electric Power reported that the R. D.
Morrow, Sr. 1 and 2 limestone FGD systems demonstrated high
dependabilities during the period of October 1983 through
July 1984 except for October. The R. D. Morrow, Sr. 1 FGD
system was off line most of October for absorber ductwork
repairs and the other FGD system was also unavailable that
month because of scheduled maintenance.
Southern Indiana Gas and Electric announced that the FMC
dual-alkali FGD system on A. B. Brown 2 in West Franklin,
Indiana, is now under construction. The 265-MW (gross) unit
will fire bituminous coal (3.35 percent sulfur, 11,100
Btu/lb). A cold-side ESP will provide primary particulate
matter control. The cleaned flue gas will" exit via a 498-ft
stack. The system will operate in a closed-water-loop mode,
and the sludge will be disposed of in an onsite landfill.
Operation of the FGD is scheduled to start up in January
1985.
Southwestern Public Service reported that the wet-limestone
FGD system on Dolet Hills 1 in Mansfield, Louisiana, is now
under construction. Flue gas from this 720-MW (gross)
lignite-fired unit will exit via a 525-ft stack, and the
system will operate in a closed-water-loop mode. Initial
startup is scheduled for December 1985.
Southwestern Public Service announced plans to construct a
new unit, South Plains 1, to be located near Idalou, Texas.
The 572-MW (gross) unit will burn low-sulfur Western coal
and will be equipped with an FGD system to control SO
emissions. Initial startup is scheduled for 1990.
United Power Association reported that the Stanton 1A lime/
spray drying FGD system demonstrated high dependabilities
during the months of October 1983 through June 1984. No
major FGD-related problems were encountered.
xxiv
-------
West Texas Utilities reported that the GEESI wet-limestone
FGD system on Oklaunion 1 in Oklaunion, Texas, is now under
construction. The 720-MW (gross) coal-fired unit will also
be equipped with a Lodge-Cottrell rigid-frame, cold-side ESP
for particulate control. The system will operate in a
closed-loop mode, and the cleaned flue gas will exit via a
453-ft acid-brick-lined stack. Initial operations are
scheduled for September 1986.
XXV
-------
REFERENCES
1. U.S. Environmental Protection Agency- Flue Gas Desulfuri-
zation Information System (FGDIS). Computerized Data Base.
Industrial Environmental Research Laboratory, Research
Triangle Park, N.C. (Access to FGDIS can be obtained through
Walter Finch, NTIS, 5285 Port Royal Road, Springfield,
Virginia 22161).
2. U.S. Department of Energy. Inventory of Power Plants in the
United States. Office of Utility Project Operations.
DOE/RA-0001, December 1977.
3. U.S. Department of Energy. Inventory of Power Plants in the
United States - December 1979. Energy Information Administra-
tion. DOE/EIA-0095(79), June 1980.
4. U.S. Department of Energy. Inventory of Power Plants in the
United States - 1980 Annual. Energy Information Administra-
tion. DOE/EIA-0095(80), June 1981.
5. U.S. Department of Energy. Inventory of Power Plants in the
United States - 1981 Annual. Energy Information Administra-
tion Office of Coal, Nuclear, Electric, and Alternate Fuels.
DOE/EIA-0095(81), September 1982.
6. U.S. Department of Energy. Inventory of Power Plants in the
United States - 1982 Annual. Energy Information Administra-
tion Office of Coal, Nuclear, Electric, and Alternate Fuels.
DOE/EIA-0095(82), June 1983.
7. Personal communication from Mr. Skeer, Office of Policy
Planning and Analysis, U.S. Department of Energy, August
1983.
8. U.S. Department of Energy. Energy Information Administra-
tion. Office of Coal, Nuclear, Electric, and Alternate
Fuels. Electric Power Monthly, DOE/EIA-0226 (83/01), January
1983. *
XXVI
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
ALABAMA ELECTRIC
TOMBIGBEE
TOMBIGBEE
ARIZONA ELECTRIC POWER
APACHE
APACHE
ARIZONA PUBLIC SERVICE
CHOLLA
CHOLLA
CHOLLA
CHOLLA
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
UNIT NO.
2
3
2
3
1
2
4
5
1
2
3
4
5
UNIT LOCATION
LEROY
LEROY
COCHISE
COCHISE
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FRUITLAND
FRUITLAND
FRUITLAND
FARMINGTON
FARMINGTON
ALABAMA
ALABAMA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
START-UP
DATE
9/78
6/79
8/78
6/79
10/73
4/78
3/81
0/97
11/79
11/79
11/79
10/84
10/84
STATUS
1
1
1
1
1
1
1
6
1
1
1
Z
2
REG
CLASS
D
D
C
c
C
c
A
A
C
C
C
A
A
ASSOCIATED ELECTRIC
THOMAS HILL
ATLANTIC CITY ELECTRIC
CUMBERLAND
BASIN ELECTRIC POWER
ANTELOPE VALLEY
ANTELOPE VALLEY
ANTELOPE VALLEY
LARAMIE RIVER
LARAMIE RIVER
LARAMIE RIVER
BIG RIVERS ELECTRIC
D.B. WILSON
GREEN
GREEN
BOSTON EDISON
NEW BOSTON
NEW BOSTON
CAJUN ELECTRIC POWER
OXBOW
CENTRAL ILLINOIS LIGHT
DUCK CREEK
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
CENTRAL MAINE POWER
SEARS ISLAND
MOBERLY
MILLVILLE
MISSOURI
NEW JERSEY
10/62
99/99
BEULAH
BEULAH
BEULAH
WHEAT LAND
WHEATLAND
WHEATLAND
CENTERTOWN
SEBREE
SEBREE
BOSTON
BOSTON
DE SOTO PARISH
CANTON
NEWTON
PENOBSCOT BAY
NORTH DAKOTA
NORTH DAKOTA
NORTH DAKOTA
WYOMING
WYOMING
WYOMING
KENTUCKY
KENTUCKY
KENTUCKY
MASSACHUSETTS
MASSACHUSETTS
LOUISIANA
ILLINOIS
ILLINOIS
MAINE
5/83
11/85
0/92
7/80
7/81
11/62
9/84
12/79
11/80
10/87
6/88
99/99
7/76
9/79
11/95
5
5
3
1
B
D
D
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 FOR S02 CONTROL
7. PLANNED - CONSIDERING FGD SYSTEMS! ALSO ALTERNATIVE METHODS
A. STANDARD!S) MORE STRINGENT THAN NSPS (6/79)
B. FEDERAL NSPS (6/79)
C. STAK'DARD(S) MORE STRINGENT THAN NSPS (12/71) BUT NOT MORE STRINGENT THAN NSPS (6/79)
D. FEDERAL NSPS (12/71)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS (12/71)
1-1
-------
UTILITY FGD SUPVEY: OCTOBER 1983 - SEPTEMBER
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP
DATE STATUS CLASS
CENTRAL POWER & LIGHT
COLETO CREEK 2
CINCINNATI GAS 4 ELECTRIC
EAST BEND 1
EAST BEND Z
ZIMMER 1
COLORADO UTE ELECTRIC
CRAIG 1
CRAIG Z
CRAIG 3
COLUMBUS t SOUTHERN OHIO ELEC
COHESVILLE 5
CONESVILLE 6
COOPERATIVE POWER
N/D 1
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
COAL CREEK 2
DELMARVA POWER & LIGHT
DELAWARE CITY 1
DELAWARE CITY 2
DELAWARE CITY 3
VIENNA 9
DESERET GEN t TRANS
BONANZA 1
BONANZA 2
DUQUESNE LIGHT
ELRAMA 1-4
PHILLIPS 1-6
EAST KENTUCKY POWER
J.K. SMITH 1
SPUR LOCK 2
FLORIDA POWER & LIGHT
MARTIN 3
MARTIN *
GENERAL PUBLIC UTILITIES
COAL 1
COAL 2
GRAND HAVEN BRD OF LIGHT & PWR
J.B. SIMS 3
GRAND RIVER DAM AUTHORITY
GRDA 2
FANNIN
RABBIT HASH
RABBIT HASH
MOSCOW
CRAIG
CRAIG
CRAIG
CONESVILLE
CONESVILLE
UNDECIDED
UNDERWOOD
UNDERWOOD
TEXAS
KENTUCKY
KENTUCKY
OHIO
COLORADO
COLORADO
COLORADO
OHIO
OHIO
OHIO
NORTH DAKOTA
NORTH DAKOTA
10/93
DELAWARE CITY DELAWARE
DELAWARE CITY DELAWARE
DELAWARE CITY DELAWARE
VIENNA MARYLAND
VERNAL
VERNAL
UTAH
UTAH
ELRAMA PENNSYLVANIA
SOUTH HEIGHTS PENNSYLVANIA
WINCHESTER KENTUCKY
MAYSVILLE KENTUCKY
MARTIN COUNTY FLORIDA
MARTIN COUNTY FLORIDA
FORKED RIVER NEW JERSEY
UNDECIDED UNDECIDED
GRAND HAVEN MICHIGAN
0/89
3/81
0/91
10/80
12/79
6/8*
1/77
6/78
0/9*
7/79
7/80
5/80
5/80
5/80
0/95
9/8*
0/92
10/75
7/73
6
1
6
1
1
1
1
1
6
1
1
1
1
1
6
1
6
1
1
A
C
C
C
C
D
D
B
D
D
E
E
E
B
A
A
C
C
PRYOR
OKLAHOMA
0/92
12/82
0/9*
0/95
0/93
0/97
5/83
3/85
A
C
B
B
B
B
B
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
*.
5.
6.
7.
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS FOR S02 CONTROL
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. STANDARD(S) MORE STRINGENT THAN NSPS (6/79)
B. FEDERAL NSPS (6/79)
C. STANDARD(S) MORE STRINGENT THAN NSPS (12/71) BUT NOT MORE STRINGENT THAN NSPS
D. FEDERAL NSPS (12/71)
E. STANDARD!S) EQUAL TO OR LESS STRINGENT THAN NSPS (12/71)
1-2
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
HOOSIER ENERGY
MEROM
MEROM
HOUSTON LIGHTING * POWER
LIMESTONE
LIMESTONE
MALAKOFF
MALAKOFF
W.A. PARISH
INDIANAPOLIS POWER t LIGHT
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
UNIT NO.
1
Z
I
Z
1
2
8
1
2
3
3
4
UNIT LOCATION
MEROM
MEROM
JEWITT
JEWITT
MALAKOFF
MALAKOFF
THOMPSONS
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
INDIANA
INDIANA
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
START-UP
DATE
8/82
12/81
12/85
12/86
12/89
12/90
10/82
0/93
O/ 0
O/ 0
12/77
3/86
STATUS
1
1
Z
Z
3
3
1
6
6
6
1
Z
REG
CLASS
D
D
B
B
B
B
B
A
A
A
D
D
IOWA ELECTRIC LIGHT ft
GUTHRIE CO.
PWR
JACKSONVILLE ELEC AUTHORITY
ST.JOHNS RVR PWR PRK
ST.JOHNS RVR PWR PRK
KANSAS CITY POWER « LIGHT
LA CYGNE
KANSAS POWER t LIGHT
JEFFREY
JEFFREY
JEFFREY
LAWRENCE
LAWRENCE
KENTUCKY UTILITIES
GREEN RIVER
HANCOCK
HANCOCK
LAKELAND UTILITIES
MCINTOSH
LOS ANGELES DEPT OF WTR t PWR
INTERMOUNTAIN
INTERHOUNTAIN
LOUISVILLE GAS & ELECTRIC
CANE RUN
CANE RUN
CANE RUN
MILL CREEK
MILL CREEK
MILL CREEK
MILL CREEK
PADDY'S RUN
1. OPERATIONAL UNITS 4.
2. UNITS UNDER CONSTRUCTION 5.
3. PLANNED - CONTRACT AWARDED 6.
7.
PANORA
JACKSONVILLE
JACKSONVILLE
LA CYGNE
IOWA
FLORIDA
FLORIDA
KANSAS
1
2
3
4
5
UAMEGO
WAMEGO
WAMEGO
LAWRENCE
LAWRENCE
KANSAS
KANSAS
KANSAS
KANSAS
KANSAS
1-3
1
2
CENTRAL CITY
HAWESVILLE
HAWESVILLE
LAKELAND
DELTA
DELTA
KENTUCKY
KENTUCKY
KENTUCKY
FLORIDA
UTAH
UTAH
4
5
6
1
2
3
4
6
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
99/99
4/87
10/88
12/72
8/78
1/80
5/83
1/77
4/78
9/75
10/93
99/99
7/82
7/86
7/87
1
3
6
A
A
C
c
C
c
c
c
A
A
8/76
12/77
4/79
12/80
12/81
8/78
7/82
4/73
1
1
1
1
1
1
1
1
E
E
E
E
E
D
D
E
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS FOR S02 CONTROL
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. STANDARD(S) MORE STRINGENT THAN NSPS (6/79)
B. FEDERAL NSPS (6/79)
C. STANDARD(S) MORE STRINGENT THAN NSPS (12/71) BUT NOT MORE STRINGENT THAN NSPS (6/79)
D. FEDERAL NSPS (12/71)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS (12/71)
1-3
-------
UTIUITt FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
LOUISVILLE GAS & ELECTRIC
TRIMBLE COUNTY
TRIMBLE COUNTY
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT
FAYETTE POWER PROJECT
MARQUETTE BOARD OF LIGHT & PWR
SHIRAS
MICHIGAN SO CENTRAL PWR AGENCY
PROJECT
MIDDLE SOUTH UTILITIES
WILTON
WILTON
MINNESOTA POWER * LIGHT
CLAY BOSWELL
MINNKOTA POWER
MILTON R. YOUNG
MONONGAHELA POWER
PLEAS ANTS
PLEASANTS
MONTANA POWER
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
UNIT NO.
1
2
3
4
3
1
1
Z
4
2
1
2
1
2
3
4
UNIT LOCATION
BEDFORD
BEDFORD
LA GRANGE
LA GRANGE
MARQUETTE
LITCHFIELD
CONVENT
CONVENT
COHASSET
CENTER
WILLOW ISLAND
WILLOW ISLAND
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
KENTUCKY
KENTUCKY
TEXAS
TEXAS
MICHIGAN
MICHIGAN
LOUISIANA
LOUISIANA
MINNESOTA
NORTH DAKOTA
WEST VIRGINIA
WEST VIRGINIA
MONTANA
MONTANA
MONTANA
MONTANA
START-UP
DATE
7/87
7/90
11/87
6/90
3/83
5/83
99/99
99/99
2/80
9/77
12/78
10/80
9/75
5/76
10/83
10/85
STATUS
5
5
2
6
1
1
4
4
1
1
1
1
1
1
1
2
REG
CLASS
A
A
B
B
B
B
B
B
D
D
D
D
D
D
A
A
MONTANA-DAKOTA UTILITIES
COYOTE 1
MUSCATINE POWER t WATER
MUSCATINE 9
NEBRASKA PUBLIC POWER DISTRICT
FOSSIL III 1
NEVADA POWER
HARRY ALLEN
HARRY ALLEN
HARRY ALLEN
HARRY ALLEN
REID GARDNER
REID GARDNER
REID GARDNER
REID GARDNER
NEW YORK STATE ELEC t
SOMERSET
1
2
3
4
1
2
3
4
GAS
BEULAH
MUSCATINE
SARGENT
LAS VEGAS
LAS VEGAS
LAS VEGAS
LAS VEGAS
MOAPA
MOAPA
MOAPA
MOAPA
SOMERSET
NORTH DAKOTA
IOWA
NEBRASKA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEW YORK
4/81
4/83
3/96
0/94
0/95
0/96
0/97
3/74
4/74
6/76
6/83
6
6
6
6
1
1
1
1
B
B
B
B
D
D
D
B
7/84
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4.
5.
6.
7.
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS FOR S02 CONTROL
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. STANDARD(S) MORE STRINGENT THAN NSPS (6/79)
B. FEDERAL NSPS (6/79)
C. STANDARD(S) MORE STRINGENT THAN NSPS (12/71) BUT NOT MORE STRINGENT THAN N«?P<;
D. FEDERAL NSPS (12/71) 3 s
E. STANDARD!S) EQUAL TO OR LESS STRINGENT THAN NSPS (12/71)
1-4
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP REG
DATE STATUS CLASS
NIAGARA MOHAMK POWER
CHARLES R. HUNTLEY 66
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
SCHAHFER 18
NORTHERN STATES POWER
RIVERSIDE 6-7
SHERBURNE 1
SHERBURNE 2
SHERBURNE 3
ORLANDO UTILITIES COMMISSION
C.H. STANTON 1
PACIFIC POWER & LIGHT
JIM BRIDGER 1
JIM BRIDGER 2
JIM BRIDGER 3
JIM BRIDGER 4
WYODAK 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
BRUCE MANSFIELD 2
BRUCE MANSFIELD 3
PHILADELPHIA ELECTRIC
CROMBY 1
EDDYSTONE 1
EDDYSTONE 2
PLAINS ELECTRIC G & T
PLAINS ESCALANTE 1
PLATTE RIVER POWER AUTHORITY
RAWHIDE 1
PUBLIC SERVICE INDIANA
GIBSON 5
PUBLIC SERVICE OF NEW MEXICO
NEW MEXICO
SAN JUAN
SAN JUAN
SAN JUAN
SAN JUAN
PUB. SER. CO. OF COLORADO
PAWNEE
SALT RIVER PROJECT
COROHADO 1
CORONADO 2
CORONADO 3
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
BUFFALO
NEW YORK
4.
5.
6.
7.
WHEATFIELD
WHEATFIELD
MINNEAPOLIS
BECKER
BECKER
BECKER
INDIANA
INDIANA
MINNESOTA
MINNESOTA
MINNESOTA
MINNESOTA
ORLANDO
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
JOLIET
SHIPPINGPORT
SHIPPINGPORT
SHIPPINGPORT
PHOENIXVILLE
EDDYSTONE
EDDYSTONE
PREWITT
WELLINGTON
PRINCETON
FLORIDA
WYOMING
WYOMING
WYOMING
WYOMING
WYOMING
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
NEW MEXICO
COLORADO
INDIANA
4/82
4/83
6/86
11/80
3/76
3/77
0/88
0/87
0/90
0/86
0/88
9/79
0/86
12/75
7/77
6/80
PENNSYLVANIA 10/82
PENNSYLVANIA 9/82
PENNSYLVANIA 11/82
10/84
12/83
10/82
RUSH
ST. JOHNS
ST. JOHNS
ST. JOHNS
COLORADO
ARIZONA
ARIZONA
ARIZONA
0/90
11/79
7/80
0/92
3
2
3
1
3
1
1
6
B
B
E
C
c
A
C
C
c
c
A
C
C
c
c
c
c
1
1
2
3
4
BISTI
WATERFLOW
MATERFLOW
WATERFLOW
WATERFLOW
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
0/95
4/78
8/78
12/79
5/82
6
1
1
1
1
A
A
A
A
A
C
c
B
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS FOR S02 CONTROL
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. STANDARD(S) MORE STRINGENT THAN NSPS (6/79)
B. FEDERAL NSPS (6/79)
C. STANDARD(S) MORE STRINGENT THAN NSPS (12/71) BUT NOT MORE STRINGENT THAN NSPS (6/79)
D. FEDERAL NSPS (12/71)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS (12/71)
1-5
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
SAN ANTONIO PUBLIC SERVICE
N/D
N/D
N/D
N/D
UNIT NO.
1
2
3
4
UNIT LOCATION
UNDECIDED
UNDECIDED
UNDECIDED
UNDECIDED
TEXAS
TEXAS
TEXAS
TEXAS
START-UP
DATE
0/93
0/95
0/99
99/99
REG
STATUS CLASS
6 B
6 B
6 B
6 B
SAN MIGUEL ELECTRIC
SAN MIGUEL
SEMINOLE ELECTRIC
SEMINOLE
SEMINOLE
TAYLOR
TAYLOR
SIERRA PACIFIC POWER
THOUSAND SPRINGS
THOUSAND SPRINGS
THOUSAND SPRINGS
VALMY
SIKESTON BRD OF MUNICIPAL UTIL
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
CROSS
CROSS
WINYAH
WINYAH
WINYAH
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR.
R.D. MORROW, SR.
SOUTHERN ILLINOIS POWER
MARION
SOUTHERN INDIANA GAS i. ELEC
A.B. BROWN
A.B. BROWN
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS
HENRY W. PIRKEY
WALKER CO.
WALKER CO.
SOUTHWESTERN PUBLIC SERVICE
SOUTH PLAINS
SPRINGFIELD CITY UTILITIES
SOUTHWEST
SAN MIGUEL
PALATKA
PALATKA
PERRY
PERRY
WELLS
HELLS
WELLS
VALMY
SIKESTON
TEXAS
FLORIDA
FLORIDA
FLORIDA
FLORIDA
NEVADA
NEVADA
NEVADA
NEVADA
MISSOURI
8/81
5/83
9/84
99/99
99/99
0/90
0/95
0/99
6/85
6/81
MARION
ILLINOIS
WEST FRANKLIN INDIANA
WEST FRANKLIN INDIANA
4/79
3/79
1/85
IDALOO
SPRINGFIELD
TEXAS
MISSOURI
0/90
4/77
1
1
6
6
B
B
B
B
1
2
2
3
4
1
2
CROSS
CROSS
GEORGETOWN
GEORGETOWN
GEORGETOWN
PURVIS
PURVIS
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
MISSISSIPPI
MISSISSIPPI
5/91
10/83
7/77
7/80
7/81
8/78
6/79
3
1
1
1
1
1
1
A
A
C
C
A
D
D
D
B
1
1
1
2
MANSFIELD
HALLSVILLE
HUNTSVILLE
HUNTSVILLE
LOUISIANA
TEXAS
TEXAS
TEXAS
12/85
12/84
12/93
12/93
2
2
6
6
B
D
B
B
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4.
5.
6.
7.
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGO SYSTEMS FOR S02 CONTROL
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. STANDARD(S) MORE STRINGENT THAN NSPS (6/79)
B. FEDERAL NSPS (6/79)
C. STANDARD(S) MORE STRINGENT THAN NSPS (12/71) BUT NOT MORE STRINGENT THAN NSPS (6/79)
D. FEDERAL NSPS (12/71)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS (12/71)
1-6
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP REG
DATE STATUS CLASS
SPRINGFIELD WATER, LIGHT t PWR
DALLMAN 3
SUNFLOWER ELECTRIC
HOLCOMB 1
TAMPA ELECTRIC
BIG BEND 4
TENNESSEE VALLEY AUTHORITY
PARADISE 1
PARADISE 2
WIDOWS CREEK 7
WIDOWS CREEK 8
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
TEXAS POWER S LIGHT
SANDOW 4
TWIN OAKS 1
TWIN OAKS 2
TEXAS UTILITIES
FOREST GROVE 1
MARTIN LAKE 1
MARTIN LAKE 2
MARTIN LAKE 3
MARTIN LAKE <»
MONTICELLO 3
TUCSON ELECTRIC POWER
SPRINGERVILLE 1
SPRINGERVILLE 2
SPRINGERVILLE 3
UNITED POWER ASSOCIATION
STANTON 1A
SPRINGFIELD ILLINOIS
HOLCOMB
TAMPA
PARADISE
PARADISE
BRIDGEPORT
STEVENSON
CARLOS
KANSAS
FLORIDA
KENTUCKY
KENTUCKY
ALABAMA
ALABAMA
TEXAS
ROCKDALE
BREMOND
BREMOND
ATHENS
TATUM
TATUM
TATUM
TATUM
MT. PLEASANT
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
SPRINGERVILLE ARIZONA
SPRINGERVILLE ARIZONA
SPRINGERVILLE ARIZONA
STANTON
NORTH DAKOTA
10/80
7/83
1/85
5/83
7/83
3/61
5/77
11/82
12/80
8/89
8/91
0/88
4/77
5/78
2/79
0/89
5/76
2/65
2/89
0/91
7/82
3
1
1
1
3
1
2
3
6
C
c
C
c
D
B
B
B
D
D
D
B
D
D
D
A
UTAH POWER & LIGHT
HUNTER
HUNTER
HUNTER
HUNTINGTON
NAUGHTON
WASHINGTON WATER POWER
CRESTON COAL
CRESTON COAL
CRESTON COAL
CRESTON COAL
1
2
3
1
3
1
2
3
4
CASTLE DALE
CASTLE DALE
CASTLE DALE
HUNTINGTON
KEMMERER
CRESTON
CRESTON
CRESTON
CRESTON
UTAH
UTAH
UTAH
UTAH
WYOMING
WASHINGTON
WASHINGTON
WASHINGTON
WASHINGTON
3/79
6/80
4/83
5/78
9/81
0/95
0/97
0/98
0/99
1
1
1
1
1
6
6
6
6
C
C
B
C
A
A
A
A
A
WEST PENN POWER
MITCHELL 33
COURTNEY
PENNSYLVANIA
8/82
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
<». PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS FOR S02 CONTROL
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
STANDARD(S) MORE STRINGENT THAN NSPS (6/79)
FEDERAL NSPS (6/79)
STANDARD(S) MORE STRINGENT THAN NSPS (12/71) BUT NOT MORE STRINGENT THAN NSPS (6/79)
FEDERAL NSPS (12/71)
A.
B.
C.
D.
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS (12/71)
1-7
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 1
SUMMARY LIST OF F6D SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP
DATE
REG
STATUS CLASS
WEST TEXAS UTILITIES
OKLAUNION
OKLAUNION
WHITE PINE COUNTY
WHITE PINE PWR PROJ.
WHITE PINE PWR PROJ.
OKLAUNION
OKLAUNION
ELY
ELY
TEXAS
TEXAS
NEVADA
NEVADA
9/86
0/96
3/91
3/92
2
6
B
B
B
B
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
5.
6.
7.
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS FOR S02 CONTROL
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A.
B.
C.
D.
E.
STAW)ARD(S) MORE STRINGENT THAN NSPS (6/79)
FEDERAL NSPS (6/79)
STANDARD(S) MORE STRINGENT THAN NSPS (12/71) BUT NOT MORE STRINGENT THAN NSPS (6/79)
rCutRAL N5P5 (12//1)
STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS (12/71)
1-8
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ALABAMA ELECTRIC
TOMBI6BEE
Z
NEW ZS5 MM (GROSS)
179 MW (ESC)
COAL
1.61 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.IX
STATUS 1 STARTUP 9/76
TOMBIGBEE Z OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA. THE BOILER GENERATES A MAXIMUM FLUE GAS FLOW OF 953,000
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.61X AND
AN AVERAGE HEAT CONTENT OF 11,42* BTU/LB. THE UNIT S02 EMMISSION LIMITA-
TION VALUE IS 1.2 LB/MMBTU. PRIMARY PARTICULATE MATTER CONTROL IS PROVID-
ED BY A HOT SIDE ESP. THE S02 REMOVAL EQUIPMENT CONSISTS OF TWO SPRAY
TOWERS SUPPLIED BY PEABODY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REA-
GENT. A CHEVRON MIST ELIMINATOR IS INCLUDED FOR EACH TOHER AND THE FLUE
GAS IS REHEATED WITH BYPASSED GAS BEFORE BEING VENTED TO A 400 FOOT ACID-
BRICK LINED STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND
SPENT ABSORBENT IS DISPOSED OF IN AN ON-SITE LINED POND.
ALABAMA ELECTRIC
TOMBIGBEE
3
NEW 255 MW (GROSS)
179 MW (ESC)
COAL
1.61 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.IX
STATUS 1 STARTUP 6/79
TOMBIGBEE 3 OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA. THE BOILER GENERATES A MAXIMUM FLUE GAS FLOW OF 953,000
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.61 AND
AN AVERAGE HEAT CONTENT OF 11,424 BTU/LB. THE UNIT S02 EMISSION LIMITATION
VALUE IS 1.2 LB/MMBTU. PRIMARY PARTICULATE CONTROL IS PROVIDED BY A HOT
SIDE ESP. THE S02 REMOVAL EQUIPMENT CONSISTS OF TWO SPRAY TOWERS SUPPLIED
BY PEABODY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REAGENT. A CHEVRON
MIST ELIMINATOR IS INCLUDED IN EACH TOWER, AND THE FLUE GAS IS REHEATED
WITH BYPASSED GAS BEFORE BEING VENTED TO A 400 FOOT ACID BRICK LINED
STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE, AND SPENT ABSORB-
ENT IS DISPOSED IN AN ON-SITE LINED POND.
ARIZONA ELECTRIC POWER
APACHE
2
NEW 195 MW (GROSS)
98 MW (ESC)
COAL
.70 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.IX
STATUS 1 STARTUP 8/78
APACHE 2 OF ARIZONA ELECTRIC POWER COOP IS LOCATED IN COCHISE, ARIZONA AND
IS A DRY BOTTOM PULVERIZED COAL FIRED UNIT WITH A FLUE GAS FLOW OF 735,000
ACFM. SUBBITUMINOUS COAL WITH A HEATING VALUE OF 10,000 BTU/LB, A SULFUR
CONTENT OF 0.70X AND AN ASH CONTENT OF 15X IS THE FUEL USED FOR THIS UNIT.
PARTICULATE MATTER IS CONTROLLED BY A HOT SIDE ESP. HALF THE FLUE GAS
PASSES THROUGH TWO RESEARCH-COTTRELL PACKED TOWERS EMPLOYING LIMESTONE
ABSORBENT AND HAVING A DESIGN S02 REMOVAL OF 85X. ENTRAINED DROPLETS ARE
REMOVED BY CHEVRON TYPE MIST ELIMINATORS. NO REHEAT IS EMPLOYED. A 400
FT COLE BRAND CXL2000 LINED STACK IS IN USE. THE SYSTEM OPERATES IN AN
OPEN WATER LOOP MODE AND WASTE MATERIAL IS DISPOSED OF IN OFF-SITE
SLUDGE PONDS. OPERATIONS COMMENCED IN AUGUST 1978.
ARIZONA ELECTRIC POWER
APACHE
3
NEW 195 MW (GROSS)
98 MW (ESC)
COAL
.70 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.IX
STATUS 1 STARTUP 6/79
APACHE 3 OF ARIZONA ELECTRIC POWER COOP IS A DRY BOTTOM, PULVERIZED COAL
FIRED UNIT IN COCHISE, ARIZONA. LOW (0.70X) SULFUR SUBBITUMINOUS COAL WITH
AN AVERAGE HEATING VALUE OF 10,000 BTU/LB PRODUCES A MAXItflJM FLUE GAS FLOW
OF 735,000 ACFM. HALF OF THE FLUE GAS PASSES THROUGH A HOT SIDE ESP TO TWO
RESEARCH COTTRELL PACKED TOWERS, WHERE LIMESTONE IS USED TO REMOVE 85X OF
THE S02. THE GAS EXITS A HORIZONTAL CHEVRON MIST ELIMINATOR INTO ITS OUN
CEILCOTE LINED FLUE IN THE 400 FOOT STACK IT SHARES WITH UNIT 2. THE FGD
SYSTEM WHICH HAS BEEN OPERATIONAL SINCE JUNE OF 1979, USES NO REHEAT. THE
SYSTEM OPERATES IN AN OPEN WATER LOOP AND SLUDGE IS DISPOSED OF IN TWO OFF
SITE LINED PONDS WITH 20 YEARS EXPECTED LIFESPAN. TWO ADDITIONAL PONDS ARE
PLANNED, WHICH WOULD ADD ANOTHER 20 YEARS OF DISPOSAL CAPACITY.
ARIZONA PUBLIC SERVICE
CHOLLA
1
RETROFIT 119 MW (GROSS)
119 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 3.4X
STATUS 1 STARTUP 10/73
ARIZONA PUBLIC SERVICE'S CHOLLA 1 IS LOCATED IN JOSEPH CITY, ARIZONA AND
IS A TANGENTIALLY FIRED, WET BOTTOM PULVERIZED COAL UNIT. IT IS FUELED BY
BITUMINOUS COAL THAT HAS A SULFUR CONTENT OF 0.5X AND A HEATING VALUE OF
10,150 BTU/LB. PARTICULATE MATTER IS CONTROLLED BY TWO FLOODED DISC SCRUB-
BERS. THE FGD SYSTEM STARTED UP IN OCTOBER, 1973 AND IS NOW OPERATIONAL.
S02 IS CONTROLLED BY ONE TOWER WITH HUNTERS PACKING EMPLOYING A LIMESTONE
ABSORBENT. THE UNIT, SUPPLIED BY RESEARCH COTTRELL, HAS A DESIGN S02 RE-
REMOVAL EFFICIENCY OF 92X. CHEVRON MIST ELIMINATORS ARE LOCATED PRIOR TO
AN IN-LINE STEAM REHEAT SYSTEM. THE TREATED FLUE GAS IS VENTED TO A 250 FT
ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE
AND THE UNTREATED WASTE IS DISPOSED OF IN AN ON-SITE UNLINED POND.
ARIZONA PUBLIC SERVICE
CHOLLA
2
NEW 285 MW (GROSS)
285 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 5.3X
STATUS 1 STARTUP 4/78
CHOLLA 2 OF ARIZONA PUBLIC SERVICE IS LOCATED IN JOSEPH CITY, ARIZONA. THE
BOILER BURNS PULVERIZED BITUMINOUS COAL (0.5X S, 10,150 BTU/LB). MECHANI-
CAL COLLECTORS PROVIDE INITIAL PARTICULATE CONTROL. FOUR PARALLEL
FLOODED DISC AND PACKED TOWER S02 ABSORBER TRAINS (THREE ARE REQUIRED FOR
FULL LOAD) PROVIDE PRIMARY PARTICULATE AND S02 CONTROL. THE DESIGN S02
REMOVAL FOR THE SYSTEM, WHICH BEGAN OPERATIONS IN APRIL, 1978, IS 75X.
THE CLEANED GAS PASSES THROUGH AN IN-LINE STEAM REHEATER INTO A 550 FOOT
ACID BRICK LINED STACK. SLUDGE FROM THE OPEN WATER LOOP SYSTEM IS
DEPOSITED IN A FLY ASH POND.
2-1
-------
UTILITY FGD SURVEY'- OCTOBER 1983 - SEPTEMBER
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZONA PUBLIC SERVICE
CHOLLA
4
NEW 375 MW (GROSS)
126 MW (ESC)
COAL
.50 XS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 3/81
CHOLLA 4 OF ARIZONA PUBLIC SERVICE IS LOCATED IN JOSEPH CITY, ARIZONA.
THE PULVERIZED COAL (0.5X S, 10150 BTU/LB) FIRED BOILER EXHAUSTS FLUE
GAS THROUGH AN ESP TO A DOUBLE LOOP COMBINATION TOWER (RESEARCH-COTTRELL
DESIGN) WHICH TREATS 36X OF THE GAS WITH LIMESTONE. OPERATIONS COMMENCED
IN MARCH, 1981.
ARIZONA PUBLIC SERVICE
CHOLLA
5
NEW 375 MW (GROSS)
126 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «**«X
STATUS 6 STARTUP 0/97
ARIZONA PUBLIC SERVICE HAS PLANS FOR A NEW UNIT, CHOLLA 5, TO BE LOCATED
IN JOSEPH CITY, ARIZONA. THE 375 MW (GROSS) PULVERIZED COAL (10150 BTU/LB
13.5X S) FIRED BOILER SUPPLIED BY COMBUSTION ENGINEERING WILL EMPLOY AN
FGD SYSTEM FOR CONTROL OF 502 EMISSIONS. START-UP IS SCHEDULED FOR 1997.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT 195 MW (GROSS)
195 MW (ESC)
COAL
.75 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 2.6X
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1, 2, AND 3 IN FRUITLAND, NEW MEXICO TO HANDLE ADDITIONAL
S02 REMOVAL. THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 8600 BTU/LB) UNITS 1 AND 2 SUPPLY 814,000 ACFM EACH
INTO 2 GEESI VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICLE CONTROL
AND APPROXIMATELY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN 502
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67;5X. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE AND
FLUE GAS EXITS A 250 FOOT STACK. OPERATIONS COMMENCED IN NOVEMBER 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
RETROFIT 195 MW (GROSS)
195 MW (ESC)
COAL
.75 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 2.6X
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1,2, AND 3 IN FRUITLAND, NEW MEXICO TO HANDLE ADDITIONAL
502 REMOVAL. THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 8600 BTU/LB) UNITS 1 AND 2 SUPPLY 614,000 ACFM EACH
INTO 2 GEESI VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICLE CONTROL
AND APPROXIMATELY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN SOS
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67.5X. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE AND
FLUE GAS EXITS A 250 FOOT STACK. OPERATIONS COMMENCED IN NOVEMBER 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
3
RETROFIT 225 MW (GROSS)
225 MW (ESC)
COAL
.75 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1,2, AND 3 IN FRUITLAND, NEW MEXICO TO HANDLE ADDITIONAL
S02 REMOVAL. THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUBBITUMINOUS,
0.75X S, 8600 BTU/LB) UNIT 3 SUPPLIES 1,030,000 ACFM INTO 2 GEESI VENTUPI
SCRUBBERS PER UNIT FOR PRIMARY PARTICLE CONTROL AND APPROXIMATELY 30X S02
REMOVAL USING ALKALINE FLY ASH. THE DESIGN 502 REMOVAL EFFICIENCY SINCE
THE CONVERSION TO LIME AND ALKALINE FLY ASH SCRUBBING IS 67 5X THE SYSTEH
OPERATES IN AN OPEN WATER LOOP MODE AND FLUE GAS EXITS A 250 FOOT STACK.
OPERATIONS COMMENCED IN NOVEMBER 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
4
RETROFIT 745 MW (GROSS)
745 MW (ESC)
COAL
.75 XS SUBBITUMINOUS
LIME
BABCOCK t WILCOX
ENERGY CONSUMPTION: ##**X
STATUS 2 STARTUP 10/64
ARIZONA PUBLIC SERVICE'S FOUR CORNERS 4 AND 5 RETROFIT FGD SYSTEMS ARE
UNDER CONSTRUCTION IN FARMINGTON, NEW MEXICO. THE 745 MW (GROSS) UNITS
WILL BURN SUBBITUMINOUS COAL (0.75X S, 8650 BTU/LB) AND WILL EACH EMPLOY
A BABCOCK t WILCOX WET LIME FGD SYSTEM FOR S02 CONTROL FABRIcVlLTERS
WILL BE USED FOR CONTROL OF PARTICULATE MATTER. THE UNIT WILL SUPPLY
560,000 ACFM TO EACH OF 10 ABSORBER MODULES WITH AN OVERALL DESIGN S02
REMOVAL EFFICIENCY OF 90X. INITIAL START-UP IS SCHEDULED FOR OCTOBER
1984.
2-2
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5
RETROFIT 745 MW (GROSS)
745 MW (ESC)
COAL
.75 XS SUBBITUMINOUS
LIME
BABCOCK & MILCOX
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 10/84
ARIZONA PUBLIC SERVICE'S FOUR CORNERS 4 AND 5 RETROFIT FGD SYSTEMS ARE
UNDER CONSTRUCTION IN FARMINGTON, NEW MEXICO. THE 745 MW (GROSS) UNITS
WILL BURN SUBBITUMINOUS COAL (0.75X S, 8650 BTU/LB) AND WILL EACH EMPLOY
A BABCOCK t WILCOX WET LIME FGD SYSTEM FOR S02 CONTROL. FABRIC FILTERS
WILL BE USED FOR CONTROL OF PARTICULATE MATTER. THE UNIT WILL SUPPLY
560,000 ACFM TO EACH OF 10 ABSORBER MODULES WITH AN OVERALL DESIGN 502
REMOVAL EFFICIENCY OF 90X. INITIAL START-UP IS SCHEDULED FOR OCTOBER
1984.
ASSOCIATED ELECTRIC
THOMAS HILL
3
NEW 730 MW (GROSS)
670 MW (ESC)
COAL
4.80 XS
LIMESTONE
M.W. KELLOGG
ENERGY CONSUMPTION: *#*»X
STATUS 1 STARTUP 10/82
THOMAS HILL 3 OF ASSOCIATED ELECTRIC COOP IS A PULVERIZED COAL (4.8X S,
10,500 BTU/LB) FIRED UNIT LOCATED IN MOBERLY, MISSOURI. TWO COLD SIDE
ESP'S PRECEDE THE FOUR 91.5X EFFICIENT M. W. KELLOGG HORIZONTAL
WEIR FGD MODULES USING MAG-PROMOTED LIMESTONE AS THE ABSORBENT. THE
CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR TO A 650
FOOT BRICK LINED STACK. REHEAT IS ACCOMPLISHED BY FLUE GAS BYPASS. THE
FIXATED SLUDGE IS TRUCKED TO AN ACTIVE STRIP MINE. THE SYSTEM OPERATES
IN A CLOSED WATER LOOP. THE FGD SYSTEM HAS BEEN OPERATIONAL SINCE OCTOBER
1982.
ATLANTIC CITY ELECTRIC
CUMBERLAND
1
NEW 330 MW (GROSS)
330 MW (ESC)
COAL
3.25 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 99/99
CUMBERLAND 1 IS A PULVERIZED COAL (3.25X S) FIRED BOILER TO BE LOCATED IN
MILVILLE, NEW JERSEY. THE UTILITY IS CONSIDERING A LIMESTONE
FGD SYSTEM WITH NO BYPRODUCT RECOVERY FOR S02 CONTROL. START-UP FOR THE
UNIT HAS BEEN DEFERRED INDEFINITELY.
BASIN ELECTRIC POWER
ANTELOPE VALLEY
1
NEW 440 MW (GROSS)
440 MW (ESC)
COAL
.68 XS LIGNITE
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: «K**X
STATUS 1 STARTUP 5/83
ANTELOPE VALLEY 1 OF BASIN ELECTRIC POWER IS A PULVERIZED COAL (0.68X S,
6600 BTU/LB LIGNITE) FIRED UNIT LOCATED IN BEULAH, NORTH DAKOTA. THE
BOILER FEEDS 2,055,000 ACFM OF FLUE GAS TO A LIME/SPRAY DRYING SYSTEM
SUPPLIED BY JOY MFG/NIRO ATOMIZER. THE 62X EFFICIENT SYSTEM CONSISTS OF
FIVE NIRO ATOMIZER SPRAY DRYERS FOLLOWED BY TWO JOY MFG BAGHOUSES. THE
CLEANED GAS, ALONG WITH A 4X BYPASS REHEAT, EXIT A 600 FOOT PVC LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP AND THE SLUDGE IS USED
FOR LANDFILL IN A COAL MINE. INITIAL OPERATIONS COMMENCED IN
MAY, 1983.
BASIN ELECTRIC POWER
ANTELOPE VALLEY
2
NEW 440 MW (GROSS)
440 MW (ESC)
COAL
.68 XS LIGNITE
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 11/85
ANTELOPE VALLEY 2 OF BASIN ELECTRIC POWER COOP IS UNDER CONSTRUCTION IN
BEULAH, NORTH DAKOTA. JOY/NIRO WAS AWARDED A CONTRACT FOR THIS LIGNITE
(0.68Z S, 6600 BTU/LB) FIRED UNIT. A LIME/SPRAY DRYING FGD SYSTEM ANT)
FABRIC FILTERS WILL BE EMPLOYED FOR S02 AND PARTICULATE CONTROL.
THE SYSTEM WILL OPERATE IN AN OPEN WATER LOOP MODE AND BE REQUIRED
TO COMPLY WITH STATE EMISSIONS STANDARDS VIA BEST AVAILABLE CONTROL TECH-
NOLOGY. START-UP IS SCHEDULED FOR NOVEMBER, 1985.
BASIN ELECTRIC POWER
ANTELOPE VALLEY
3
NEW 560 MW (GROSS)
560 MW (ESC)
LIGNITE
.68 XS
LIME/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«**X
STATUS 6 STARTUP 0/92
ANTELOPE VALLEY 3 OF BASIN ELECTRIC POWER IS A PLANNED 560 MW (GROSS)
LIGNITE FIRED BOILER TO BE LOCATED IN BEULAH, NORTH DAKOTA. THE UTILITY
IS PRESENTLY INVESTIGATING LIME/SPRAY DRYING AS THE POSSIBLE EMISSION
CONTROL STRATEGY. START-UP IS EXPECTED IN 1992.
2-3
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
BASIN ELECTRIC POWER
LARAMIE RIVER
1
NEW 570 MW (GROSS)
570 MW (ESC)
COAL
.54 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: .9X
STATUS 1 STARTUP 7/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 1 IS A PULVERIZED COAL
(0.54X S, 8400 BTU/LB) FIRED UNIT LOCATED IN WHEATLAND, WYOMING.
THE BOILER FEEDS 2,300,000 ACFM OF FLUE GAS THROUGH A COLD SIDE
ESP TO FIVE RESEARCH COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH
REMOVE 90X OF THE S02. THE CLEANED GAS EXITS FROM A VERTICAL CHEVRON
MIST ELIMINATOR INTO A 600 FOOT ACID BRICK LINED STACK. NO REHEAT IS
USED. THE FLYASH STABLIIZED SLUDGE IS DEWATERED TO 83X SOLIDS BEFORE
BEING LANDFILLED, AND THE SYSTEM EMPLOYS A CLOSED WATER LOOP. OPERATIONS
BEGAN ON JULY 1, 1980.
BASIN ELECTRIC POWER
LARAMIE RIVER
Z
NEW 570 MW (GROSS)
570 MW (ESC)
COAL
.54 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 7/81
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 2 IS A NEW UNIT LOCATED
IN WHEATLAND, WYOMING. THE PULVERIZED SUBBITUMINOUS COAL (0.54X S, 8400
BTU/LB) FIRED BOILER FEEDS 2,300,000 ACFM OF FLUE GAS THROUGH A COLD SIDE
ESP TO FIVE RESEARCH-COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH
REMOVE 90X OF THE S02. THE CLEANED GAS EXITS FROM A VERTICAL CHEVRON
MIST ELIMINATOR INTO A 600 FOOT ACID BRICK LINED STACK. NO REHEAT IS
USED. THE FLYASH FIXATED SLUDGE IS DEWATERED TO 83X SOLIDS BEFORE
BEING LANDFILLED IN THIS CLOSED WATER LOOP SYSTEM. START-UP TOOK PLACE
IN JULY 1981.
BASIN ELECTRIC POWER
LARAMIE RIVER
3
NEW 570 MW (GROSS)
570 MW (ESC)
COAL
.54 XS SUBBITUMINOUS
LIME/SPRAY DRYING
BABCOCK t WILCOX
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 11/82
LARAMIE RIVER 3 OF BASIN ELECTRIC POWER COOP IS A NEW UNIT LOCATED IN
WHEATLAND, WYOMING. IT UTILIZES FOUR BABCOCK & WILCOX LIME SPRAY DRIERS
AND A COLD SIDE ESP. THE BOILER FIRES PULVERIZED COAL (0.54X S,
8400 BTU/LB) AND SUPPLYS 2,800,000 ACFM OF FLUE GAS TO THE FGD
SYSTEM, WHICH REMOVES 85X OF THE S02 BEFORE THE GAS EXITS THROUGH
A 600 FOOT FIBER-REINFORCED POLYESTER LINED STACK. A 3X BYPASS IS USED
FOR REHEAT. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND THE DRY POWDER
WASTE IS LANDFILLED.
BIG RIVERS ELECTRIC
D.B. WILSON
1
NEW 440 MW (GROSS)
440 MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
M.W. KELLOGG
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 9/64
BIG RIVERS ELECTRIC'S D.B. WILSON 1 IS A NEW UNIT LOCATED IN CENTERTOWN,
KENTUCKY. THE PULVERIZED BITUMINOUS COAL (3.75X S) FIRED FOSTER WHEEL-
ER BOILER HAS A GROSS MW RATING OF 440. A COLD SIDE ESP IS EMPLOYED FOR
PARTICULATE CONTROL AND SLUDGE IS TREATED VIA FORCED OXIDATION. THE M. W.
KELLOG WET LIME FGD SYSTEM AT UNIT 1 BEGAN INITIAL OPERATIONS IN SEPTEMBER
1984.
BIG RIVERS ELECTRIC
GREEN
1
NEW 242 MW (GROSS)
242 MW (ESC)
COAL
3.91 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION'- ****X
STATUS 1 STARTUP 12/79
UNIT 1 OF BIG RIVERS ELECTRIC'S GREEN STATION IS LOCATED IN
SEBREE,KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.91X S, 9600 BTU/LB)
FIRED BOILER SUPPLIES 1,000,000 ACFM TO A COLD SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH REMOVE 90X OF THE
S02. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND
EXITS A 350 FT SAUERISEN 72 LINED STACK AFTER IT IS HEATED BY A STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM IS POZ-0-TEC
STABILIZED. OPERATIONS COMMENCED IN DECEMBER 1979
BIG RIVERS ELECTRIC
GREEN
2
NEW 242 MW (GROSS)
242 MW (ESC)
COAL
3.91 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: #*#*X
STATUS 1 STARTUP 11/80
UNIT 2 OF BIG RIVERS ELECTRIC'S GREEN STATION IS LOCATED IN SEBREE,
KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.91X S, 9800 BTU/LB)
FIRED BOILER SUPPLIES 1,000,000 ACFM TO A COLD SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH REMOVE 90X OF THE
S02. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND
EXITS A 350 FT SAUERISEN 72 LINED STACK AFTER IT IS HEATED BY A STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM IS POZ-0-TEC
STABILIZED. OPERATIONS COMMENCED IN NOVEMBER 1980
2-4
-------
UTILITY FED SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
BOSTON EDISON
NEW BOSTON
1
NEW 388 MM (GROSS)
388 MM (ESC)
COAL
2.30 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«*«X
STATUS 5 STARTUP 10/87
NEW BOSTON 1 AND 2 OF BOSTON EDISON ARE TWO OIL TO COAL CONVERSION UNITS
LOCATED IN BOSTON MASSACHUSETTS. THE 388 MW (GROSS) BABCOCK AND WILCOX
UNITS WILL FIRE SUBBITUMINOUS COAL (12,600 BTU/LB, 2.3X S). BIDS ARE
CURRENTLY BEING REQUESTED/EVALUATED FOR A WET LIMESTONE FGD SYSTEM WITH
GYPSUM GENERATED AS A SALEABLE BYPRODUCT. ESP'S WILL PROVIDE PARTICULATE
CONTROL AND FLUE GAS WILL EXIT A 359 FT ACID BRICK LINED STACK. FORCED
OXIDATION WILL BE UTILIZED FOR SLUDGE TREATMENT. UNIT 1 IS SCHEDULED
TO START UP IN OCTOBER, 1987 AND UNIT 2 IN JUNE, 1988.
BOSTON EDISON
NEW BOSTON
2
NEW 388 MW (GROSS)
388 MW (ESC)
COAL
2.30 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «**«X
STATUS 5 STARTUP 6/88
NEW BOSTON 1 AND 2 OF BOSTON EDISON ARE TWO OIL TO COAL CONVERSION UNITS
LOCATED IN BOSTON MASSACHUSETTS. THE 388 MW (GROSS) BABCOCK AND WILCOX
UNITS WILL FIRE SUBBITUMINOUS COAL (12,600 BTU/LB, 2.3X S). BIDS ARE
CURRENTLY BEING REQUESTED/EVALUATED FOR A WET LIMESTONE FGD SYSTEM WITH
GYPSUM GENERATED AS A SALEABLE BY PRODUCT. ESP'S WILL PROVIDE PARTICULATE
CONTROL AND FLUE GAS WILL EXIT A 359 FT ACID BRICK LINED STACK. FORCED
OXIDATION WILL BE UTILIZED FOR SLUDGE TREATMENT. UNIT 1 IS SCHEDULED
TO START UP IN OCTOBER, 1987 AND UNIT 2 IN JUNE, 1988.
CAJUN ELECTRIC POWER
OXBOW
1
NEW 540 MW (GROSS)
540 MW (ESC)
COAL
.60 XS LIGNITE
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****x
STATUS 3 STARTUP 99/99
CAJUN ELECTRIC HAS PLANS TO CONSTRUCT A 540 MW UNIT, OXBOW 1, TO BE LOCAT-
ED IN DE SOTO PARISH, LOUISIANA. THE UTILITY HAS AWARDED A CONTRACT TO
JOY MANUFACTURING/NIRO ATOMIZER FOR A LIME/SPRAY DRYING FGD SYSTEM TO
CONTROL S02 EMISSIONS FROM THE PULVERIZED COAL (.6X S, 6750 BTU/LB) FIRED
BOILER. THE UNIT HAS BEEN DEFERRED INDEFINITELY.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
NEW 416 MW (GROSS)
416 MW (ESC)
COAL
3.40 XS BITUMINOUS
LIMESTONE
ENVIRONEERING, RILEY STOKER
ENERGY CONSUMPTION: 2.9X
STATUS 1 STARTUP 7/76
DUCK CREEK 1 OF CENTRAL ILLINOIS LIGHT IS LOCATED IN CANTON, ILLINOIS. THE
BALANCED DRAFT, FRONT FIRED, DRY BOTTOM UNIT BURNS PULVERIZED BITUMINOUS
COAL (3.40X S, 10,396 BTU/LB) AND SUPPLIES 2,415,000 ACFM OF FLUE GAS TO
TWO COLD SIDE ESP'S FOLLOWED BY FOUR RILEY STOKER/ENVIRONEERING ROD DECK
SPRAY TOWER MODULES. THE LIMESTONE FGD SYSTEM HAS BEEN OPERATIONAL (AT
LEAST ONE MODULE) SINCE JULY, 1976. IT IS DESIGNED TO REMOVE 65X OF THE
S02. HORIZONTAL CHEVRON MIST ELIMINATORS FOLLOW THE ABSORBERS, AND THE
CLEANED GAS EXITS TO A 500 FOOT CEILCOTE LINED STACK WITHOUT REHEAT.
SLUDGE FROM THE CLOSED WATER LOOP SYSTEM IS DIPOSED OF IN AN ON-SITE CLAY
LINED POND.
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
NEW 617 MW (GROSS)
617 MW (ESC)
COAL
3.00 XS BITUMINOUS
DUAL ALKALI
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 9/79
NEWTON 1 OF CENTRAL ILLINOIS PUBLIC SERVICE IS A TANGENTIALLY FIRED, DRY
BOTTOM, PULVERIZED BITUMINOUS COAL (3.00X S, 10,900 BTU/LB) FIRED UNIT
LOCATED IN NEWTON, ILLINOIS. A COLD SIDE ESP RECEIVES 2,163,480 ACFM
OF FLUE GAS AND FEEDS IT TO FOUR GEESI POLYSPHERE PACKED TRAY TOWER
ABSORBERS FOLLOWED BY TWO VERTICAL MIST ELIMINATORS PER MODULE. THE
CLEANED GAS IS BOOSTED 25 DEG F BY A COMBINATION OF TWO DIFFERENT TYPES
OF IN-LINE REHEATERS PLUS BYPASS REHEAT, AND THEN EXITS A 530 FOOT
PRECRETE-LINED STACK. THE WATER LOOP IS CLOSED, AND THE SLUDGE IS
POZ-0-TEC TREATED. OPERATIONS COMMENCED IN SEPTEMBER, 1979.
CENTRAL MAINE POWER
SEARS ISLAND
1
NEW 600 MW (GROSS)
600 MW (ESC)
COAL
2.23 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 11/95
SEARS ISLAND 1 IS A PLANNED UNIT TO BE BUILT ON PENOBSCOT BAY BY CENTRAL
MAINE POWER. BECAUSE OF THE DISCOVERY OF A GEOLOGICAL FAULT ON SEARS
ISLAND, PLANS FOR A 1150 MW NUCLEAR POWER PLANT HAVE BEEN REPLACED WITH
PLANS FOR A 600 MW COAL (2.23X S, 12,500 BTU/LB) FIRED PLANT. LIME AND
LIMESTONE SCRUBBING ARE THE PRIMARY METHODS BEING CONSIDERED FOR COMPLI-
ANCE WITH THE NSPS. IT WILL BE TWO YEARS BEFORE ALL PERMITS REQUIRED HAVE
BEEN RECEIVED. START UP IS SCHEDULED FOR NOVEMBER 1995.
2-5
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CENTRAL POWER 4 LIGHT
COLETO CREEK
2
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
.39 7.5 SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 10/93
COLETO CREEK 2 OF CENTRAL POWER AND LIGHT IS A COAL SUBBITUMINOUS (.39-
.60X S) FIRED UNIT PLANNED FOR CONSTRUCTION IN FANNIN, TEXAS. A CONTRACT
HAS BEEN AWARDED TO JOY MFG/NIRO ATOMIZER FOR A LIME/SPRAY DRYING FGD SYS-
TEM ON THIS UNIT. PARTICULATE MATTER WILL BE CONTROLLED VIA A RIGID FRAME
COLD SIDE ESP. THE BOILER WILL BE SUPPLIED BY COMBUSTION ENGINEERING AW
FLUE GAS WILL EXIT THROUGH A 450 FOOT STACK. SLUDGE WILL BE DISPOSED OF
IN A LANDFILL. THE UNIT WILL BY CENTRAL AND SOUTHWEST SERVICES, BUT WILL
BUT WILL BE OPERATED BY CENTRAL POWER & LIGHT. START UP IS TENTATIVELY
SCHEDULED FOR OCTOBER 1993..1993.
CINCINNATI GAS & ELECTRIC
EAST BEND
1
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
4.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.9/C
STATUS 6 STARTUP 0/89
CINCINNATI GAS AND ELECTRIC HAS PLANS FOR A NEW UNIT, EAST BEND 1, TO BE
LOCATED ADJACENT TO EAST BEND 2 AT THE RABBIT HASH, KENTUCKY SITE. THE
COAL (4.00X S) FIRED BOILER WILL HAVE A GENERATING CAPACITY OF 650 MW AND
FLUE GAS WILL EXIT THROUGH A 650 FT STACK. THE SYSTEM WILL OPERATE IN A
CLOSED WATER LOOP MODE. START-UP IS SCHEDULED FOR 1989.
CINCINNATI GAS
EAST BEND
2
NEW
4 ELECTRIC
650 MW (GROSS)
650 MW (ESC)
BITUMINOUS
COAL
2.60 XS
LIME
BAECOCK i WILCOX
ENERGY CONSUMPTION: 2.9X
STATUS 1 STARTUP 3/81
EAST BEND 2 OF CINCINNATI GAS AND ELECTRIC IS A PULVERIZED COAL (2.60X S,
11,000 BTU/LB) FIRED BOILER LOCATED IN RABBIT HASH, KENTUCKY. THE EMIS-
SION CONTROL SYSTEM CONSISTS OF A HOT-SIDE ESP FOLLOWED BY THREE BABCOCK
& WILCOX LIME FGD MODULES [67X S02 REMOVAL EFFICIENCY). THE CLEANED GAS
PASSES THROUGH A CHEVRON MIST ELIMINATOR BEFORE BEING HEATED BY AN IN-
DIRECT AIR REHEATER AND EXITS THROUGH A BRICK LINED 650 FOOT STACK. THE
SLUDGE FROM THIS CLOSED WATER LOOP IS POZ-0-TEC STABILIZED BEFORE DISPOSAL
IN AN ON-SITE LANDFILL. OPERATIONS COMMENCED IN MARCH 1981.
CINCINNATI GAS & ELECTRIC
ZIMMER
1
NEW 1386 MW (GROSS)
1386 MW (ESC)
COAL
3.50 XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «**«X
STATUS 6 STARTUP 0/91
CINCINNATI GAS AND ELECTRIC HAS PLANS FOR A NUCLEAR TO COAL CONVERSION
UNIT LOCATED IN MOSCOW, OHIO. S02 EMISSIONS FROM THE 1386 MW (GROSS) COAL
FIRED BALANCED DRAFT BOILER WILL BE CONTROLLED WITH FGD. INITIAL START-UP
IS TENTATIVELY SCHEDULED FOR 1991.
COLORADO UTE ELECTRIC
CRAIG
1
NEW 455 MW (GROSS)
455 MW (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 10/80
THE COLORADO UTE ELECTRIC ASSN HAS CONSTRUCTED A NEW UNIT, CRAIG 1, LOCAT-
ED IN CRAIG, COLORADO. CRAIG 1 FIRES PULVERIZED SUBBITUMINOUS COAL
(0.45X S, 10,000 BTU/LB). THE EMISSION CONTROL SYSTEM FOR THIS UNIT CON-
SISTS OF A HOT SIDE ESP AND FOUR LIMESTONE SPRAY TOWERS (PEABODY PROCESS
SYSTEMS) FOR REMOVAL OF PARTICULATE MATTER AND 85X OF THE S02. THE
SCRUBBER EXHAUST IS REHEATED BYPASS GAS AND PASSES THROUGH A 600 FOOT
ACID LINED STACK. THE SYSTEM OPERATES IN A CLOSED MATER LOOP ANT) THE
STABILIZED SLUDGE IS DISPOSED OF IN AN OFF-SITE MINEFILL. UNIT 1 HAS
BEEN OPERATING SINCE OCTOBER 1980.
COLORADO UTE ELECTRIC
CRAIG
2
NEW 455 MM (GROSS)
455 MW (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 12/79
THE CRAIG 2 UNIT OF THE COLORADO UTE ELECTRIC ASSN IS LOCATED IN CRAIG,
COLORADO AND FIRES PULVERIZED SUBBITUMINOUS COAL (0.45XS, 10,000 BTU/LB).
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP AND
FOUR PEABODY PROCESS SYSEMS LIMESTONE SPRAY TOWERS FOR REMOVAL OF PARTIC-
ULATE AND 85X OF THE S02. THE SCRUBBER EXHAUST IS HEATED BY A BYPASS
REHEATER AND PASSES THROUGH A 600 FOOT ACID BRICK LINED STACK. THE SYSTEM
OPERATES IN A CLOSED LOOP. AND THE STABILIZED SLUDGE IS DISPOSED OF IN AN
OFF-SITE MINEFILL. START-UP OF UNIT 2 WAS IN DECEMBER 1979.
2-6
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COLORADO UTE ELECTRIC
CRAIG
3
NEW 447 MM (GROSS)
447 MW (ESC)
COAL
.45 XS SUBBITUMINOUS
LIME/SPRAY DRYING
BABCOCK & MILCOX
ENERGY CONSUMPTION: »***X
STATUS 1 STARTUP 6/84
CRAIG 3 OF COLORADO UTE ELECTRIC ASSN. IS LOCATED IN CRAIG, COLORADO.
THE UNIT, SUPPLIED BY BABCOCK & MILCOX FIRES PULVERIZED SUBBITUUMINOUS
COAL (0.45X S, 10,000 BTU/LB). THE DRY SCRUBBING SYSTEM UTILIZING
LIME/SPRAY DRYING WITH A DESIGN REMOVAL EFFICIENCY OF 85X IS SUPPLIED BY
BABCOCK AND WILCOX. THE UNIT HAS A FABRIC FILTER FOR PARTICULATE MATTER B
CONTROL AND FLUE GAS EXITS A 600 FT STACK. OPERATION OF THE FGD SYSTEM
COMMENCED IN JUNE 1984.
COLUMBUS S SOUTHERN OHIO ELEC
CONESVILLE
5
NEW 405 MM (GROSS)
350 MM (ESC)
COAL
4.50 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 1.7X
STATUS 1 STARTUP 1/77
CONESVILLE 5 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.SOX S, 10,850 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TWO THIOSORBIC LIME TCA MODULES SUPPLIED BY UOP.
THE S02 REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH BEGAN INITIAL
OPERATION IN JANUARY 1977, IS 89.5X (DESIGN). EACH MODULE HAS ONE
BULK ENTRAINMENT SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 600 FOOT ACID BRICK LINED STACK. THE
POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON-SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN A CLOSED WATER LOOP.
COLUMBUS & SOUTHERN OHIO ELEC
CONESVILLE
6
NEW 405 MW (GROSS)
350 MW (ESC)
COAL
4.50 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 1.7X
STATUS 1 STARTUP 6/78
CONESVILLE 6 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.SOX S, 10,850 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TWO THIOSORBIC LIME TCA MODULES SUPPLIED BY UOP.
THE SOS REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH BEGAN INITIAL
OPERATION IN JUNE 1978, IS 89.5X (DESIGN). EACH MODULE HAS ONE
BULK ENTRAINMENT SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 800 FOOT ACID BRICK LINED STACK. THE
POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON-SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN A CLOSED WATER LOOP.
COOPERATIVE POWER
N/D
1
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
***** XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/94
COOPERATIVE POWER HAS PLANS TO CONSTRUCT A 750 MW (GROSS) UNIT IN OHIO.
THE FACILITY NAME HAS NOT YET BEEN DECIDED NOR HAS THE SITE LOCATION BEEN
FINALIZED. THE UNIT IS EXPECTED TO FIRE OHIO COAL. A WET LIMESTONE
FGD SYSTEM WILL BE EMPLOYED TO CONTROL S02 EMISSIONS AND PARTICLE MATTER
WILL BE CONTROLLED BY ESP'S. INITIAL START-UP IS TENTATIVELY SCHEDULED
FOR 1994.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
1
NEW 550 MM (GROSS)
327 MW (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ,2X
STATUS 1 STARTUP 7/79
COAL CREEK 1 AND 2, LOCATED IN UNDERWOOD, NORTH DAKOTA ARE TWO PULVERIZED
LIGNITE (0.63X S, 6258 BTU/LB) FIRED UNITS OWNED BY THE COOPERATIVE POWER
ASSN AND UNITED POWER. A COLD SIDE ESP RECEIVES 2,200,000 ACFM OF FLUE
GAS AND EXHAUSTS IT TO FOUR COUNTERCURRENT SPRAY TOWERS SUPPLIED BY COM-
BUSTION ENGINEERING. MIST ELIMINATION IS PROVIDED BY A BULK ENTRAINMENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40X BYPASS RE-
HEAT IS PROVIDED BEFORE THE CLEANED GAS EXITS A 658 FT ACID BRICK LINED
STACK. THE LIME/ALKALINE FLYASH SYSTEM DESIGN S02 REMOVAL EFFICIENCY IS
90X. IT OPERATES IN AN OPEN WATER LOOP, AND THE FLYASH FIXATED SLUDGE IS
DISPOSED OF IN A CLAY LINED POND. UNIT 1 OPERATIONS BEGAN IN JULY 1979.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
2
NEW 550 MW (GROSS)
327 MM (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: .2X
STATUS 1 STARTUP 7/80
COAL CREEK 1 AND 2, LOCATED IN UNDERWOOD, NORTH DAKOTA ARE TWO PULVERIZED
LIGNITE (0.63X S, 6258 BTU/LB) FIRED UNITS OWNED BY THE COOPERATIVE POWER
ASSN AND UNITED POWER. A COLD SIDE ESP RECEIVES 2,200,000 ACFM OF FLUE
GAS AND EXHAUSTS IT TO FOUR COUNTERCURRENT SPRAY TOWERS SUPPLIED BY COM-
BUSTION ENGINEERING. MIST ELININATION IS PROVIDED BY A BULK ENTRAINMENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40X BYPASS RE-
HEAT IS PROVIDED BEFORE THE CLEANED GAS EXITS A 658 FT ACID BRICK LINED
STACK. THE LIME/ALKALINE FLYASH SYSTEM DESIGN S02 REMOVAL EFFICIENCY IS
90X. IT OPERATES IN AN OPEN WATER LOOP, AND THE FLYASH STABILIZED SLUDGE
IS DISPOSED OF IN A CLAY LINED POND. UNIT 2 COMMENCED OPERATIONS IN JULY,
1980.
2-7
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
DELMARVA POWER & LIGHT
DELAWARE CITY
1
RETROFIT 60 MW (GROSS)
60 MW (ESC)
COKE
7.00 XS BITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: ****x
STATUS 1 STARTUP 5/80
DELAWARE CITY 1, 2, AND 3 OF DELMARVA POWER AND LIGHT ARE THREE RETRO-
FITTED COKE (7.OX Si 14,000 BTU/LB) FIRED BOILERS WHICH HAVE A STEAM CAP-
ACITY OF 500K LB/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS ELECTRI-
CITY FOR GETTY REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACFM
OF FLUE GAS TO A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER
FOR PARTICULATE CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE
MIST ELIMINATOR TO A WET ESP FOR BOTH PARTICULATE AND ACID MIST REMOVAL. A
FOUR STAGE WELLMAN-LORD SYSTEM, WHICH IS DESIGNED FOR 90X REMOVAL, IS USED
FOR S02 CONTROL. HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS EXITS
OUT A 500 FT STACK. THE EMISSION CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE.
IT IS A CLOSED LOOP WATER SYSTEM. THE SYSEM BEGAN OPERATING IN MAY 1980.
DELMARVA POWER * LIGHT
DELAWARE CITY
2
RETROFIT 60 MW (GROSS)
60 MW (ESC)
COKE
7.00 XS BITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: *»**•/
STATUS 1 STARTUP 5/80
DELAWARE CITY 1, 2, AND 3 OF DELMARVA POWER AND LIGHT ARE THREE RETRO-
FITTED COKE (7.OX S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF BOOK
LB/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACFM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER FOR PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMINATOR
TO A WET ESP FOR BOTH PARTICULATE AND ACID MIST REMOVAL. A FOUR STAGE
WELLMAN-LORD SYSTEM DESIGNED FOR 90X REMOVAL, IS USED FOR S02 CON-
TROL. HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS EXITS OUT A 500 FT.
STACK. THE EMISSION CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE. IT IS A
CLOSED LOOP WATER SYSTEM. THE SYSTEM BECAME OPERATIONAL IN MAY 1980.
DELMARVA POWER & LIGHT
DELAWARE CITY
3
RETROFIT 60 MW (GROSS)
60 MW (ESC)
COKE
7.00 XS BITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 5/80
DELAWARE CITY 1, 2, AND 3 OF DELMARVA POWER AND LIGHT ARE THREE RETRO-
FITTED COKE (7.OX S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF 500K
LB/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACFM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER FOR PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMINATOR
TO A WET ESP FOR BOTH PARTICULATE AND ACID MIST REMOVAL. A FOUR STAGE
WELLMAN-LORD SYSTEM DESIGNED FOR 90X REMOVAL, IS USED FOR S02 CON-
TROL. HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS EXITS OUT A 500 FT.
STACK. THE EMISSION CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE. IT IS A
CLOSED LOOP WATER SYSTEM. THE SYSTEM BECAME OPERATIONAL IN MAY 19SO.
DELMARVA POWER 8 LIGHT
VIENNA
9
NEW 550 MW (GROSS)
550 MW (ESC)
COAL
2.50 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.7X
STATUS 6 STARTUP 0/95
DELMARVA POWER AND LIGHT IS PLANNING A NEW 550 MW (GROSS) UNIT, VIENNA 9,
TO BE CONSTRUCTED IN VIENNA, MARYLAND. THE UTILITY IS PRESENTLY CONSIDER-
ING A LIMESTONE FGD UNIT FOR S02 CONTROL AND AN ESP FOR PARTICULATE REMOV-
AL. THE PULVERIED COAL (2.5X S, 12,200 BTU/LB) FIRED UNIT IS EXPECTED TO
COMMENCE OPERATIONS IN MAY 1995.
DESERET GEN 4 TRANS
BONANZA
1
NEW 410 MM (GROSS)
410 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.9X
STATUS 1 STARTUP 9/84
BONANZA 1, OF DESERET GEN. & TRANS. IS A 410 MW (GROSS) UNIT LOCATED IN
VERNAL UTAH. THE PULVERIZED COAL (10,500 BTU/LB, .5X S) FIRED BOILER
SUPPLIES FLUE GAS TO A COMBUSTION ENGINERING WET LIMESTONE FGD SYSTEM
WITH A DESIGN S02 REMOVAL EFFICIENCY OF 95X. PARTICULATE MATTER IS CON-
TROLLED WITH AN ECOLAIRE FABRIC FILTER AT 99.6X DESIGN REMOVBAL EFFICIEN-
CY. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND SLUDGE IS DIS-
POSED AT AN ON-SITE LANDFILL. OPERATIONS COMMENCED IN SEPTEMBER 1984.
DESERET GEN t TRANS
BONANZA
2
NEW 410 MW (GROSS)
410 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.9X
STATUS 6 STARTUP 0/92
BONANZA (FORMERLY MOON LAKE) 2 IS A PULVERIZED COAL ( .5X S, 10,500 BTU/LB)
FIRED UNIT PLANNED BY DESERET GENERATION & TRANS. COOP TO BE LOCATED IN
VERNAL, UTAH. A WET LIMESTONE SCRUBBING SYSTEM WITH AN S02 REMOVAL EF-
FICIENCY OF 95X WILL BE EMPLOYED FOR S02 CONTROL. THE SYSTEM
WILL FEATURE A BAGHOUSE DESIGNED TO REMOVE 99.6X OF THE PARTICULATE. THE
UNIT WILL OPERATE IN A CLOSED WATER LOOP WITH SLUDGE DISPOSAL ON-SITE
IN A LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1992.
2-8
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
DUQUESNE LIGHT
ELRAMA
1-4
RETROFIT 510 MW (GROSS)
510 MM (ESC)
COAL
2.05 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 1.4X
STATUS 1 STARTUP 10/75
ELRAMA 1-4 OF DUQUESNE LIGHT CONSISTS OF FOUR PULVERIZED COAL (2.05X S,
11,568 BTU/LB) FIRED UNITS LOCATED IN ELRAMA, PENNSYLVANIA. THE RETROFIT
EMISSION CONTROL SYSTEM FOR EACH UNIT CONSISTS OF MECHANICAL COLLECTORS
FOLLOWED BY ESP'S AND FIVE VARIABLE THROAT VENTURI LIME ABSORBER MODULES
SUPPLIED BY GEESI, WHICH ARE DESIGNED TO REMOVE 83X OF THE S02 FROM THE
FLUE GAS. THE CLEANED GAS EXITS VIA A 398 FOOT ACID BRICK LINED STAf.K.
THE SYSTEM OPERATES IN AN OPEN WATER LOOP AND THE POZ-0-TEC STABILIZED
SLUDGE IS HAULED TO AN OFF-SITE LANDFILL. THE SYSTEM HAS BEEN
OPERATIONAL SINCE OCTOBER 1975.
DUQUESNE LIGHT
PHILLIPS
1-6
RETROFIT 408 MW (GROSS)
408 MW (ESC)
COAL
2.05 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 3.4X
STATUS 1 STARTUP 7/73
THE PHILLIPS POWER STATION OF DUQUESNE LIGHT CONSISTS OF SIX DRY BOTTOM
PULVERIZED COAL (2.05X S, 11568 BTU/LB) FIRED UNITS LOCATED IN SOUTH
HEIGHTS, PENNSYLVANIA. PARTICULATE CONTROL IS ACCOMPLISHED BY SIX MECHAN-
ICAL COLLECTORS FOLLOWED BY SIX ESP'S (ONE/BOILER). ONE TWO STAGE AND
THREE SINGLE STAGE VARIABLE THROAT VENTURI LIME FGD MODULES SUPPLIED BY
GEESI ARE DESIGNED TO REMOVE 83X OF THE S02 FROM THE FLUE GAS. THE CLEANED
FLUE GAS PASSES THROUGH TWO CHEVRON MIST ELIMINATORS (EACH MODULE) AND
EXITS VIA A 340 FT ACID BRICK LINED STACK. THE RETROFIT SYSTEM OPERATES
IN AN OPEN WATER LOOP, AND THE POZ-0-TEC STABILIZED SLUDGE IS TRUCKED TO
AN OFF-SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL SINCE JULY
1973.
EAST KENTUCKY POWER
J.K. SMITH
1
NEW
650 MW (GROSS)
650 MW (ESC)
BITUMINOUS
THE EAST KENTUCKY POWER COOP HAS PLANS TO BUILD A NEW UNIT, J.K. SMITH 1,
IN WINCHESER, KENTUCKY. A CONTRACT WAS AWARDED TO BABCOCK & WILCOX FOR A
WET LIME PROCESS TO CONTROL S02 EMISSIONS. AN ESP WILL BE EMPLOYED FOR
PARTICULATE REMOVAL AND THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP.
INITIAL START-UP IS EXPECTED IN 1992.
COAL
1.50 XS
LIME
BABCOCK S WILCOX
ENERGY CONSUMPTION: «***X
STATUS 3 STARTUP 0/92
EAST KENTUCKY POWER
SPURLOCK
2
NEW 500 MW (GROSS)
500 MM (ESC)
COAL
3.50 XS
LIME
THYSSEN/CEA
ENERGY CONSUMPTION: *»*«x
STATUS 1 STARTUP 12/82
SPURLOCK 2 OF EAST KENTUCKY POWER COOPERATIVE IS A BALANCED DRAFT PULVER-
IZED COAL (3.5X S, 11,000 BTU/LB) FIRED UNIT LOCATED IN MAYSVILLE, KY. THE
EMISSION CONTROL SYSTEM CONSISTS OF AN ESP FOLLOWED BY A THYSSEN/CEA LIME
FGD SYSTEM (90X DESIGN S02 REMOVAL EFFICIENCY). FLUE GAS FROM UNIT 1 IS
USED TO REHEAT THE CLEANED GAS WHICH EXITS THROUGH AN 802 FT STACK. THE
CLOSED WATER LOOP SYSTEM EMPLOYS A POZ-0-TEC SLUDGE STABILIZATION
FACILITY. UNIT 2 OPERATIONS COMMENCED IN DECEMBER 1982.
FLORIDA POWER & LIGHT
MARTIN
3
NEW 800 MW (GROSS)
800 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****•/.
STATUS 6 STARTUP 0/94
FLORIDA POWER AND LIGHT HAS PLANS FOR TWO NEW UNITS, MARTIN 3 AND 4 TO BE
LOCATED IN MARTIN COUNTY, FLORIDA. THE PULVERIZED COAL FIRED BOILERS
WILL HAVE A MW RATING OF 800 EACH. THE UTILITY IS PRESENTLY CONSIDERING
ONLY FGD AS THE EMISSION CONTROL STRATEGY. THE START-UP FOR UNIT 3 IS
PROJECTED FOR 1994.
FLORIDA POWER * LIGHT
MARTIN
4
NEW 800 MW (GROSS)
800 MW (ESC)
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **»*X
STATUS 6 STARTUP 0/95
FLORIDA POWER AND LIGHT HAS PLANS FOR TWO NEW UNITS, MARTIN 3 AND 4 TO BE
LOCATED IN MARTIN COUNTY, FLORIDA. THE PULVERIZED COAL FIRED BOILERS
WILL HAVE A MW RATING OF 800 EACH. THE UTILITY IS PRESENTLY CONSIDERING
ONLY FGD AS THE EMISSION CONTROL STRATEGY. THE START-UP FOR UNIT 4 IS
PROJECTED FOR 1995.
2-9
-------
UTILITY FGD SURVEY'- OCTOBER 1983 - SEPTEMBER
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
GENERAL PUBLIC UTILITIES
COAL
1
NEW 690 MW (GROSS)
690 MW (ESC)
COAL
2.00 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/93
GENERAL PUBLIC UTILITIES HAS PLANS FOR A 625 MW UNIT, COAL 1, TO BE LO-
CATED IN FORKED RIVER NEW JERSEY. THE PULVERIZED COAL (2.OX S, 13,800
BTU/LB) FIRED BABCOCK k WILCOX UNIT WILL HAVE A GROSS RATING OF 625 MW AND
WILL UTILIZE A WET LIMESTONE FGD SYSTEM FOR CONTROL OF S02 EMISSIONS.
PARTICULATE MATTER WILL BE CONTROLLED WITH AN ESP. THE SYSTEM WILL
OPERATE IN A CLOSED WATER LOOP MODE AND FLUE GAS WILL EXIT A 650 FT STACK.
START-UP IS SCHEDULED FOR 1993.
GENERAL PUBLIC UTILITIES
COAL
2
NEW 690 MW (GROSS)
690 MW (ESC)
COAL
3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/97
GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 690 MW UNIT, COAL 2,
IN THE WESTERN U.S. THE UTILITY IS PRESENTLY CONSIDERING A WET LIMESTONE
FGD SYSTEM AS THE EMISSION CONTROL STRATEGY. THE COAL FIRED (3.5X S) UNIT
IS SCHEDULED TO COMMENCE OPERATIONS IN 1997.
GRAND HAVEN BRD OF
J.B. SIMS
3
NEW
COAL
2.75 XS
LIME
BABCOCK t
65 MW (GROSS)
65 MW (ESC)
BITUMINOUS
LIGHT 4 PWR J.B. SIMS 3 OF GRAND HAVEN BOARD OF LIGHT AND POWER IS A BITUMINOUS COAL
(2.75X S, 11,000 BTU/LB) FIRED UNIT LOCATED IN GRAND HAVEN, MICHIGAN. THE
BABCOCK & WILCOX EMISSION CONTROL SYSTEM CONSISTS OF TWO LIME SPRAY TOWERS
WITH AN S02 REMOVAL EFFICIENCY OF 90-95X. EACH TOWER IS EQUIPPED WITH A
CHEVRON MIST ELIMINATOR FOLLOWED BY AN IN-LINE REHEATER. AN ESP IS EM-
PLOYED FOR PARTICULATE CONTROL AND FLUE GAS EXITS A 360 FT STACK. IT
OPERATES IN A CLOSED WATER LOOP MODE AND THE SLUDGE IS DISPOSED OF IN AN
OFF-SITE LANDFILL. INITIAL OPERATIONS OF THE FGD SYSTEM BEGAN IN MAY 1983.
WILCOX
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 5/83
GRAND RIVER DAM AUTHORITY
GRDA
2
NEW 575 MW (GROSS)
520 MW (ESC)
COAL
.95 XS SUBBITUMINOUS
LIME/SPRAY DRYING
FLAKT
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 3/85
GRDA 2 OF GRAND RIVER DAM AUTHORITY IS A 575 MW (GROSS) UNIT UNDER CON-
STRUCTION IN PRYOR, OKLAHOMA. FLAKT IS SUPPLYING A TURNKEY LIME/SPRAY
DRYING FGD SYSTEM CONSISTING OF FOUR SPRAY DRYERS WITH THREE ROTARY ATOM-
IZERS EACH FOLLOWED BY TWO ESP'S FOR PARTICULATE (FLY ASH AND REACTOR
PRODUCT) REMOVAL. INITIAL START-UP IS SCHEDULED FOR MARCH 1985.
HOOSIER ENERGY
MEROM
1
NEW 490 MW (GROSS)
441 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: 1.2X
STATUS 1 STARTUP 8/82
MEROM 1, OF HOOSIER ENERGY IS LOCATED IN MEROM, INDIANA. THIS
PULVERIZED COAL (3.5X S) FIRED UNIT PRODUCES 866,000 ACFM OF FLUE GAS
WHICH IS BEING CLEANED BY A COLD SIDE ESP UPSTREAM OF A MITSUBISHI
LIMESTONE GRID TOWER ABSORBER (90X DESIGN S02 REMOVAL). THE SYSTEM
UTILIZES BYPASS REHEAT AND A 702 FOOT STACK. THE SLUDGE IS BEING
FORCIBLY OXIDIZED AND LANDFILLED, AND THE SYSTEM OPERATES IN A CLOSED
WATER LOOP MODE. UNIT 1 COMMENCED OPERATIONS IN AUGUST 1982.
HOOSIER ENERGY
MEROM
2
NEW 490 MW (GROSS)
441 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: 1.2X
STATUS 1 STARTUP 12/81
MEROM 2, OF HOOSIER ENERGY IS LOCATED IN MEROM, INDIANA. THIS
PULVERIZED COAL (3.5X S) FIRED UNIT PRODUCES 666,000 ACFM OF FLUE GAS
WHICH IS BEING CLEANED BY A COLD SIDE ESP UPSTREAM OF A MITSUBISHI
LIMESTONE GRID TOWER ABSORBER (90X DESIGN S02 REMOVAL). THE SYSTEM
UTILIZES BYPASS REHEAT AND A 702 FOOT STACK. THE SLUDGE IS BEING
FORCIBLY OXIDIZED AND LANDFILLED, AND THE SYSTEM OPERATES IN A CLOSED
WATER LOOP MODE. UNIT 2 COMMENCED OPERATIONS IN DECEMBER 1961.
2-10
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
HOUSTON LIGHTING & POWER
LIMESTONE
1
NEW 750 MM (GROSS)
750 MW (ESC)
COAL
1.08 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 12/85
HOUSTON LIGHTING AND POWER CO HAS PLANS FOR TWO NEW UNITS, LIMESTONE 1
AND 2, UNDER CONSTRUCTION IN JEWITT TEXAS. THE PULVERIZED COAL (1.08X S,
6177 BTU/LB) FIRED BOILER WILL UTILIZE A WET LIMESTONE SCRUBBING PROCESS
FOR PRIMARY S02 COLLECTION. A COLD SIDE ESP WILL ALSO BE USED FOR PRIMARY
PARTICLE CONTROL. THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP MODE AND
FLUE GAS WILL EXIT THROUGH A 563 FT STACK. THE UILITY AWARDED A CONTRACT
TO COMBUSTION ENGINEERING FOR THE INSTALLATION OF THIS SYSTEM. UNIT 1 IS
SCHEDULED TO COMMENCE OPERATIONS IN DECEMBER 1985.
HOUSTON LIGHTING & POWER
LIMESTONE
2
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
1.08 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ***«X
STATUS 2 STARTUP 12/86
HOUSTON LIGHTING AND POWER CO HAS PLANS FOR TWO NEW UNITS, LIMESTONE 1
AND 2, UNDER CONSTRUCTION IN JEWITT, TEXAS. THE PULVERIZED COAL (1.08X S,
6177 BTU/LB) FIRED BOILER WILL UTILIZE A WET LIMESTONE SCRUBBING PROCESS
FOR PRIMARY S02 COLLECTION. A COLD SIDE ESP WILL BE USED FOR PRIMARY
PARTICLE CONTROL. THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP MODE AND
FLUE GAS WILL EXIT THROUGH A 563 FT STACK. THE UTILITY AWARDED A CONTRACT
TO COMBUSTION ENGINEERING FOR THE INSTALLATION OF THIS SYSTEM. UNIT 2 IS
SCHEDULED TO COMMENCE OPERATIONS IN DECEMBER 1986.
HOUSTON LIGHTING 8 POWER
MALAKOFF
1
NEW 690 MW (GROSS)
690 MW (ESC)
COAL
1.10 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 12/89
HOUSTON LIGHTING AND POWER HAS PLANS FOR TWO NEW UNITS, MALAKOFF 1 AND 2,
TO BE LOCATED IN MALAKOFF, TEXAS. EACH PULVERIZED COAL (1.1X S, 6112
BTU/LB LIGNITE) FIRED BABCOCK & WILCOX BOILER WILL UTILIZE A WET LIMESTONE
SCRUBBING PROCESS FOR S02 CONTROL. A COLD SIDE ESP SUPPLIED BY WHEELABRA-
TOR FRYE WILL CONTROL PARTICULATE MATTER. THE CLEANED FLUE GAS WILL EXIT
THROUGH A 625 FOOT ACID RESISTANT BRICK LINED STACK. THE UTILITY HAS
AWARDED A CONTRACT TO GE ENVIRONMENTAL SERVICES FOR INSTALLATION OF THE
FGD SYSTEMS. UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS IN DECEMBER 1989.
HOUSTON LIGHTING & POWER
MALAKOFF
2
NEW 690 MW (GROSS)
690 MW (ESC)
COAL
1.10 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: **»«*
STATUS 3 STARTUP 12/90
HOUSTON LIGHTING AND POWER HAS PLANS FOR TWO NEW UNITS, MALAKOFF 1 AND 2,
TO BE LOCATED IN MALAKOFF, TEXAS. EACH PULVERIZED COAL (1.1X S, 6112
BTU/LB LIGNITE) FIRED BABCOCK & WILCOX BOILER WILL UTILIZE A WET LIMESTONE
SCRUBBING PROCESS FOR S02 CONTROL. A COLD SIDE ESP SUPPLIED BY WHEELABRA-
TOR FRYE WILL CONTROL PARTICULATE MATTER. THE CLEANED FLUE GAS WILL EXIT
THROUGH A 625 FOOT ACID RESISTANT BRICK LINED STACK. THE UTILITY HAS
AWARDED A CONTRACT TO GE ENVIRONMENTAL SERVICES FOR INSTALLATION OF THE
FGD SYSTEMS. UNIT 2 IS SCHEDULED TO COMMENCE OPERATIONS IN DECEMBER 1990.
HOUSTON LIGHTING & POWER
W.A. PARISH
8
NEW 600 MW (GROSS)
492 MW (ESC)
COAL
.41 XS SUBBITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: l.OX
STATUS 1 STARTUP 10/82
W.A. PARISH 8 OF HOUSTON LIGHTING t POWER IS A PULVERIZED COAL (0.41X S,
8942 BTU/LB) FIRED UNIT LOCATED IN BOOTH, TEXAS. GEESI HAS SUPPLIED A
LIMESTONE FGD SYSTEM THAT REMOVES 82X OF THE FLUE GAS S02. FABRIC FILTERS
ARE EMPLOYED FOR PARTICULATE CONTROL AND REHEAT IS PROVIDED BY BYPASSING
18X OF THE CLEANED FLUE GAS. SLUDGE IS DEWATERED, BLENDED WITH FLYASH, AND
DISPOSED OF IN AN ON-SITE LANDFILL. THE SYSTEM OPERATES IN A CLOSED WATER
LOOP MODE AND FLUE GAS EXITS THROUGH A 500 FT STACK. THE UNIT HAS BEEN
OPERATINAL SINCE OCTOBER 1982.
INDIANAPOLIS POWER & LIGHT
PATRIOT
1
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/93
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL AND A LOCAL COAL WITH A
SULFUR CONTENT OF 3.5X.
2-11
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
INDIANAPOLIS POWER & LIGHT
PATRIOT
2
NEW 650 MM (GROSS)
650 MM (ESC)
COAL
3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP O/ 0
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS TO UTILIZE
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL AND A LOCAL COAL WITH A
SULFUR CONTENT OF 3.5X.
INDIANAPOLIS POWER S LIGHT
PATRIOT
3
NEW 650 MW (GROSS)
650 MM (ESC)
COAL
3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION; »»**x
STATUS 6 STARTUP O/ 0
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL AND A LOCAL COAL WITH A
SULFUR CONTENT OF 3.5X.
INDIANAPOLIS POWER & LIGHT
PETERSBURG
3
NEW 532 MM (GROSS)
532 MW (ESC)
COAL
3.25 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 12/77
PETERSBURG 3 OF INDIANAPOLIS POWER AND LIGHT IS LOCATED IN PETERSBURG,
INDIANA, AND BURNS BITUMINOUS COAL (3.25X S, 10,750 BTU/LB). TWO COLD
SIDE ESP'S ARE LOCATED UPSTREAM OF FOUR 85X EFFICIENT UOP LIMESTONE TCA
MODULES. A HORIZONTAL MIST ELIMINATOR PRECEDES AN INDIRECT HOT AIR REHEAT-
ER THAT BOOSTS THE GAS TEMPERATURE BY 30 DEC F BEFORE IT EXITS THE 616
FOOT RIGIFLAKE 4850 LINED STACK. STABILIZED SLUDGE IS DISPOSED OF IN AN
ON-SITE POND, AND THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.
THE UNIT HAS BEEN OPERATIONAL SINCE DECEMBER 1977.
INDIANAPOLIS POWER « LIGHT
PETERSBURG
4
NEW 530 MM (GROSS)
530 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 2.IX
STATUS 2 STARTUP 3/86
PETERSBURG 4 OF INDIANAPOLIS POWER AND LIGHT IS A BITUMINOUS COAL (3.SOX S
11,000 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN PETERSBURG, INDIANA. THE
BOILER WILL BE SUPPLIED BY COMBUSTION ENGINEERING AND THE LIMESTONE FGD
SYSTEM FOR THIS UNIT WILL BE SUPPLIED BY RESEARCH-COTTRELL AND AN ESP WILL
BE EMPLOYED FOR PARTICULATE CONTROL. THE SYSTEM WILL OPERATE IN A CLOSED_
WATER LOOP AND SLUDGE WILL BE POZ-0-TEC STABILIZED BEFORE PONDING. START-
UP IS SLATED FOR MARCH 1986.
IOWA ELECTRIC LIGHT & PWR
GUTHRIE CO.
1
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
.40 XS SUBBITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *«**X
STATUS 4 STARTUP 99/99
IOWA ELECTRIC LIGHT AND POWER HAS PLANS TO CONSTRUCT A 720 MW UNIT,
GUTHRIE COUNTY 1, SUPPLIED BY COMBUSTION ENGINEERING IS TO BE LOCATED IN
PANORA, IOWA. A LETTER OF INTENT WAS SIGNED WITH COMBUSTION ENGINEERING
TO PROVIDE A WET LIMESTONE FGD SYSTEM TO CONTROL S02 EMISSIONS FROM THE
PULVERIZED COAL (0.4X S, 8180 BTU/LB) FIRED BOILER. AN ESP IS TO BE USED
FOR PARTICULATE MATTER REMOVAL. THE SYSTEM WILL OPERATE IN A CLOSED WATER
LOOP MODE AND FLUE GAS WILL EXIT A 650 FOOT STACK. START UP HAS BEEN
DEFERRED INDEFINITELY.
JACKSONVILLE ELEC AUTHORITY
ST.JOHNS RVR PWR PRK
1
NEW 612 MW (GROSS)
612 MW (ESC)
COAL
2.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ****•/.
STATUS 2 STARTUP 4/87
THE JACKSONVILLE ELECTRIC AUTHORITY HAS STARTED CONSTRUCTION ON TWO NEW
UNITS, ST. JOHNS RIVER POWER PARK 1 AND 2, LOCATED IN EAST PORT, FLORIDA.
EACH UNIT WILL BURN PULVERIZED COAL (2-4X S) AND SUPPLY 2,500,000 ACFM TO
A MET LIMESTONE FGD PROCESS AND AN ESP FOR EMISSION CONTROL. THE CLEANED
FLUE GAS WILL EXIT THROUGH A 640 FOOT DOUBLE LINED SINGLE STACK. THE
UTILITY HAS AWARDED A CONTRACT TO RESEARCH-COTTRELL FOR INSTALLATION OF
THE CONTROL SYSTEMS. START-UP IS SCHEDULED FOR APRIL 1987.
2-12
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
JACKSONVILLE ELEC AUTHORITY
ST.JOHNS RVR PWR PRK
Z
NEW 612 MM (GROSS)
612 MW (ESC)
COAL
2.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: *«*«X
STATUS 2 STARTUP 10/68
THE JACKSONVILLE ELECTRIC AUTHORITY HAS STARTED CONSTRUCTION ON TWO NEW
UNITS, ST. JOHNS RIVER POWER PARK 1 AND 2, LOCATED IN EAST PORT, FLORIDA.
EACH UNIT WILL BURN PULVERIZED COAL (2-4X S) AND SUPPLY 2,500,000 ACFM TO
A WET LIMESTONE FGD PROCESS AND AN ESP FOR EMISSION CONTROL. THE CLEANED
FLUE GAS WILL EXIT THROUGH A 640 FOOT DOUBLE LINED SINGLE STACK. THE
UTILITY HAS AWARDED A CONTRACT TO RESEARCH-COTTRELL FOR INSTALLATION OF
THE CONTROL SYSTEMS. START-UP IS SCHEDULED FOR OCTOBER 1988.
KANSAS CITY POWER & LIGHT
LA CYGNE
1
NEW 874 MW (GROSS)
874 MW (ESC)
COAL
5.39 XS SUBBITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: 3.2X
STATUS 1 STARTUP 12/72
LA CYGNE 1 IS A WET BOTTOM, CYCLONE-FIRED UNIT LOCATED IN LA CYGNE,
KANSAS. THE UNIT BURNS SUBBITUMINOUS COAL (5.39X S, 9400 BTU/LB).
THE EMISSION CONTROL SYSTEM CONSISTS OF EIGHT VARIABLE THROAT
VENTURI/LIMESTONE SIEVE TRAY TOWER TRAINS SUPPLIED BY BABCOCK AND WILCOX.
EACH 80X (S02 REMOVAL, DESIGN) EFFICIENT TRAIN IS FOLLOWED BY A
COMBINATION SIEVE TRAY AND CHEVRON MIST ELIMINATOR, AND BOTH A DIRECT AND
INDIRECT REHEATER. THE CLEANED GAS EXITS THROUGH A 700 FOOT STEEL LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND THE SLUDGE IS
DISPOSED IN AN UNLINED POND. OPERATIONS COMMENCED IN DECEMBER 1972.
KANSAS POWER
JEFFREY
1
NEW
& LIGHT
720 MW (GROSS)
540 MW (ESC)
COAL
.32 XS SUBBITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »***X
STATUS 1 STARTUP 8/78
KANSAS POWER & LIGHT'S JEFFREY 1 IS A TANGENTIAL FIRED PULVERIZED
COAL (0.32X S, 8125 BTU/LB) UNIT IN WAMEGO, KANSAS. THE EMISSION CONTROL
SYSTEM FOR THIS UNIT CONSISTS OF A COLD SIDE ESP FOLLOWED BY SIX (ONE
SPARE) LIMESTONE SPRAY TOWER MODULES SUPPLIED BY COMBUSTION ENGINEERING.
THE DESIGN S02 REMOVAL EFFICIENCY IS SOX (INCLUDING A 30X BYPASS REHEAT).
THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND FLUE GAS EXITS A 600
FOOT STACK. THE UNIT HAS BEEN OPERATIONAL SINCE AUGUST 1978.
KANSAS POWER
JEFFREY
2
NEW
& LIGHT
720 MW (GROSS)
540 MW (ESC)
COAL
.32 XS SUBBITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *#**X
STATUS 1 STARTUP 1/80
UNIT 2, PRESENTLY OPERATING AT KANSAS POWER AND LIGHT'S JEFFREY ENERGY
CENTER IN WAMEGO, KANSAS, BURNS 0.32X S PULVERIZED COAL (8125 BTU/LB).
THIS UNIT'S EMISSION CONTROL SYSTEM CONSISTS OF A COLD SIDE ESP
AND COMBUSTION ENGINEERING LIMESTONE SPRAY TOWERS. A 30X FLUE GAS
BYPASS PROVIDES REHEAT OF THE CLEANED GAS BEFORE IT EXITS THROUGH A
600 FOOT STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE, AND
THE SLUDGE IS STABILIZED WITH BOTTOM ASH AND PIPED TO AN ON-SITE CLAY
LINED POND. INITIAL OPERATIONS COMMENCED IN JANUARY 1980.
KANSAS POWER * LIGHT
JEFFREY
3
NEW 730 MW (GROSS)
540 MW (ESC)
COAL
.32 XS SUBBITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ***«X
STATUS 1 STARTUP 5/83
JEFFREY 3 OF KANSAS POWER & LIGHT IS A TANGENTIAL FIRED PULVERIZED COAL
(.32X S, 8125 BTU/LB) UNIT LOCATED IN WAMEGO, KANSAS. EMISSIONS
ARE CONTROLLED VIA A COLD SIDE ESP AND FOUR COMBUSTION ENGINEERING
LIMESTONE SPRAY TOWERS. THE ABSORBERS OUTLET INTO A COMMON BYPASS DUCT
(FOR CONTINUOUS REHEAT) THAT FEEDS THE 600 FOOT STACK. THE SYSTEM OPER-
ATES IN A CLOSED WATER LOOP MODE AND SLUDGE IS STABILIZED WITH
BOTTOM ASH BEFORE BEING PIPED TO AN ON-SITE CLAY LINED POND. INITIAL
OPERATIONS COMMENCED IN MAY 1983.
KANSAS POWER
LAWRENCE
4
RETROFIT
I LIGHT
125 MW (GROSS)
125 MW (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: **»*X
STATUS 1 STARTUP 1/77
LAWRENCE 4 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 10,000 BTU/LB) UNIT LOCATED IN LAWRENCE, KANSAS.
A NEW COMBUSTION ENGINEERING LIMESTONE ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MARBLE BED TAIL END SCRUBBER IN JANUARY 1977. THE
SYSTEM TREATS 403,000 ACFM OF FLUE GAS, WITH A DESIGN SOS REMOVAL OF
73X. MIST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS AND ONE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DEG F BEFORE
IT IS EXHAUSTED THROUGH A 200 FOOT STACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP.
2-13
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KANSAS POWER t LIGHT
LAWRENCE
5
RETROFIT 420 MW (GROSS)
420 MW (ESC)
COAL
.55 XS SUBBITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 4/78
LAWRENCE 5 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 10,000 BTU/LB) UNIT LOCATED IN LAWRENCE, KANSAS.
A NEW COMBUSTION ENGINEERING LIMESTONE ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MARBLE BED TAIL END SCRUBBER IN APRIL 1978. THE
SYSTEM TREATS 403,000 ACFM OF FLUE GAS, WITH A DESIGN S02 REMOVAL OF
73X. MIST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS AND ONE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DEG F BEFORE
IT IS EXHAUSTED THROUGH A 350 FOOT STACK. THE SLUDGE IS DISPOSED OF IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP.
KENTUCKY UTILITIES
GREEN RIVER
1-3
RETROFIT 65 MW (GROSS)
65 MW (ESC)
COAL
2.23 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 4.6X
STATUS 1 STARTUP 9/75
GREEN RIVER 1-3 OF KENTUCKY UTILITIES ARE THREE DRY BOTTOM PULVERIZED
BITUMINOUS COAL (2.23X S, 11,250 BTU/LB) FIRED UNITS LOCATED IN CENTRAL
CITY, KENTUCKY. THE BOILER SUPPLIES A TOTAL OF 360,000 ACFM OF FLUE GAS TO
A VARIABLE THROAT VENTURI FOLLOWED BY AN AMERICAN AIR FILTER LIME MOBILE
BED CONTACTOR (BOX DESIGN S02 REMOVAL EFFICIENCY). A RADIAL VANE MIST
ELIMINATOR IS FOLLOWED BY A STEAM TUBE REHEATER AND A 165 FOOT STACK.
SLUDGE IS DISPOSED IN AN ON-SITE UNLINED POND, AND THE SYSTEM OPERATES
IN A CLOSED WATER LOOP. THIS RETROFIT SYSTEM HAS BEN OPERATIONAL SINCE
SEPTEMBER 1975.
KENTUCKY UTILITIES
HANCOCK
1
NEW 708 MW (GROSS)
650 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: «*«*X
STATUS 3 STARTUP 10/93
KENTUCKY UTILITIES HAS PLANS TO CONSTRUCT TWO NEW 650 MW (NET) PULVERIZED
BITUMINOUS COAL (3.5X S, 10,500 BTU/LB) FIRED BOILERS, SUPPLIED BY
COMBUSTION ENGINEERING. THE UNITS, HANCOCK 1 AND 2, ARE TO BE LOCATED IN
HAWESVILLE, KENTUCKY. THE UTILITY HAS AWARDED A CONTRACT TO B & W FOR A
WET LIMESTONE SCRUBBING SYSTEM WHICH WILL OPERATE IN A CLOSED WATER LOOP
MODE TO CONTROL EMISSIONS AT A DESIGN REMOVAL EFFICIENCY OF 91.8X. AN ESP
WILL BE EMPLOYED FOR PARTICULATE CONTROL AND FLUE GAS WILL BE REHEATED BY
ZZZZ
PLOYED FOR SLUDGE TREATMENT. HANCOCK 1 IS SCHEDULED TO COMMENCE IN
OCTOBER 1993.
KENTUCKY UTILITIES
HANCOCK
2
NEW 708 MW (GROSS)
650 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *#**X
STATUS 6 STARTUP 99/99
KENTUCKY UTILITIES HAS PLANS TO CONSTRUCT TWO NEW 650 MW (NET) PULVERIZED
BITUMINOUS COAL (3.5X S, 10,500 BTU/LB) FIRED BOILERS, SUPPLIED BY
COMBUSTION ENGINEERING. THE UNITS, HANCOCK 1 AND 2, ARE TO BE LOCATED IN
HAWESVILLE, KENTUCKY. THE UTILITY IS PRESNTLY INVESTIGATING A WET LIME-
STONE SCRUBBING SYSTEM WHICH WILL OPERATE IN A CLOSED WATER LOOP MODE TO
CONTROL EMISSIONS AT A DESIGN REMOVAL EFFICIENCY OF 91.8X. AN ESP WILL BE
EMPLOYED FOR PARTICULATE CONTROL AND FLUE GAS WILL BE REHEATED BY INDIRECT
HOT AIR BEFORE EXITING A 600 FT STACK. FORCED OXIDATION IS EMPLOYED FOR
SLUDGE TREATMENT. HANCOCK 2 HAS BEEN DEFERRED INDEFINITELY.
LAKELAND UTILITIES
MCINTOSH
3
NEW 364 MW (GROSS)
364 MW (ESC)
COAL
2.56 XS BITUMINOUS
LIMESTONE
BABCOCK * WILCOX
ENERGY CONSUMPTION: *«*#X
STATUS 1 STARTUP 7/82
MCINTOSH 3 OF LAKELAND UTILITIES IS A PULVERIZED BITUMINOUS COAL FIRED
BOILER LOCATED IN LAKELAND, FLORIDA. BABCOCK AND WILCOX WAS AWARDED A
CONTRACT TO SUPPLY AN 85X EFFICIENT (S02) LIMESTONE FGD SYSTEM FOR THIS
UNIT. THE EMISSION CONTROL SYSTEM CONSISTS OF A COLD SIDE ESP FOLLOWED
BY TWO PARALLEL FGD MODULES AND A 250 FOOT ACID BRICK LINED STACK. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP WITH POZ-0-TEC BEING USED TO STAB-
ILIZE THE SLUDGE.
LOS ANGELES DEPT OF WTR t PWR
INTERMOUNTAIN
1
NEW 820 MM (GROSS)
820 MW (ESC)
COAL
.79 XS SUBBITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 7/86
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAS STARTED CONSTRUCTION ON
TWO NEW BOILERS, INTERMOUNTAIN 1 AND 2 TO BE LOCATED IN DELTA, UTAH
EACH 820 MW BOILER WILL FIRE PULVERIZED SUBBITUMINOUS COAL (0.79X si
10,200 BTU/LB) AND WIIL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A GEESI WET
LIMESTONE SCRUBBING SYSTEM. HOT SIDE ESP'S WILL BE USED FOR PARTICLUATE
CONTROL. THE FLUE GAS WILL PASS THROUGH A CHEVRON-TYPE MIST ELIMINATOR
DESIGNED FOR 90X S02 REMOVAL EFFICIENCY AND WILL BE REHEATED BY IN-LINE
HEAT EXCHANGERS BEFORE EXITING A 710 FT STACK. THE SYSTEM WILL OPERATE IN
A CLOSED WATER LOOP MODE AND THE SLUDGE WILL BE FLYASH STABILIZED BEFORE
BEING DISPOSED ON-SITE. UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS IN
JULY 1986.
2-14
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOS ANGELES DEPT OF WTR S PUR
INTERMOUNTAIN
Z
NEW 820 MM (GROSS)
620 MM (ESC)
COAL
.79 XS SUBBITUMINOUS
LIMESTONE
6E ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 7/67
THE LOS ANGELES DEPARTMENT OF WATER AND POMER HAS STARTED CONSTRUCTION ON
TWO NEW BOILERS, INTERMOUNTAIN 1 AND 2 TO BE LOCATED IN DELTA, UTAH.
EACH 820 MM BOILER WILL FIRE PULVERIZED SUBBITUMINOUS COAL (0.79X S,
10,200 BTU/LB) AND Will SUPPLY 5,400,000 ACFM OF FLUE GAS TO A GEESI WET
LIMESTONE SCRUBBING SYSTEM. HOT SIDE ESP'S WILL BE USED FOR PARTICLUATE
CONTROL. THE FLUE GAS WILL PASS THROUGH A CHEVRON-TYPE MIST ELIMINATOR
DESIGNED FOR 90X S02 REMOVAL EFFICIENCY AND WILL BE REHEATED BY IN-LINE
HEAT EXCHANGERS BEFORE EXITING A 710 FT STACK. THE SYSTEM WILL OPERATE IN
A CLOSED WATER LOOP MODE AND THE SLUDGE WILL BE FLYASH STABILIZED BEFORE
BEING DISPOSED ON-SITE. UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS IN
JULY 1987.
LOUISVILLE GAS & ELECTRIC
CANE RUN
4
RETROFIT 186 MW (GROSS)
168 MW (ESC)
COAL
3.87 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 8/76
UNIT 4 AT LOUISVILLE GAS AND ELECTRIC'S CANE RUN STATION IS A PULVERIZED
BITUMINOUS COAL (3.87X S, 11,300 BTU/LB) FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. AN ESP AND TWO AMERICAN AIR FILTER CARBIDE LIME MOBILE BED ABSORBER
MODULES (85X DESIGN S02 REMOVAL) TREAT 734,000 ACFM OF FLUE GAS FROM THE
BOILER. TWO CHEVRON MIST ELIMINATORS/MODULE ARE FOLLOWED BY A DIRECT
COMBUSTION REHEATER AND A 250 FOOT STACK. THE WATER LOOP IS OPEN, AND
THE POZ-0-TEC FIXATED SLUDGE IS DISPOSED IN AN ON-SITE LANDFILL. THIS
RETROFIT SYSTEM HAS BEEN OPERATIONAL SINCE AUGUST 1976.
LOUISVILLE GAS * ELECTRIC
CANE RUN
5
RETROFIT 200 MW (GROSS)
200 MM (ESC)
COAL
3.80 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.5X
STATUS 1 STARTUP 12/77
CANE RUN 5 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS COAL
(3.8X S, 11,0000 BTU/LB) FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY. THE
BOILER SUPPLIES 700,000 ACFM OF FLUE GAS TO AN EMISSION CONTROL SYSTEM
CONSISTING OF AN ESP FOLLOWED BY TWO COMBUSTION ENGINEERING 85X EFFICIENT
(DESIGN) CARBIDE LIME SPRAY TOMERS. A STEAM TUBE REHEATER RAISES THE GAS
TEMPERATURE 40 DEC F. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE, AND
THE SLUDGE IS POZ-0-TEC STABILIZED. THE CLEANED FLUE GAS EXITS A"250 FT
STACK. OPERATION OF THIS RETROFIT SYSTEM BEGAN IN DECEMBER 1977.
LOUISVILLE GAS 4 ELECTRIC
CANE RUN
6
RETROFIT 299 MW (GROSS)
299 MM (ESC)
COAL
4.80 XS BITUMINOUS
DUAL ALKALI
THYSSEN/CEA
ENERGY CONSUMPTION: l.OX
STATUS 1 STARTUP 4/79
LOUISVILLE GAS AND ELECTRIC'S CANE RUN 6 IS A 299-MW (GROSS) BITUMINOUS
COAL (4.80X S, 11,000 BTU/LB) FIRED UNIT LOCATED IN LOUISVILLE,
KENTUCKY. THYSSEN/CEA SUPPLIED A RETROFIT DUAL ALKALI DEMONSTRATION
FGD SYSTEM FOR THIS UNIT. THE EMISSION CONTROL SYSTEM, DESIGNED TO REMOVE
95X OF THE FLUE GAS S02, CONSISTS OF A COLD SIDE ESP AND TWO TRAY TOWER
MODULES. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND TWO
DIRECT COMBUSTION REHEATERS BEFORE EXITING A 518 FOOT STACK. THE WATER
LOOP IS CLOSED, AND THE SLUDGE IS DISPOSED IN AN ON-SITE LANDFILL.
LOUISVILLE GAS t ELECTRIC
MILL CREEK
1
RETROFIT 358 MW (GROSS)
358 MM (ESC)
COAL
3.75 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 1 STARTUP 12/80
MILL CREEK 1 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT LIME FGD SYSTEM IS PRESENTLY OPERATING ON THIS PULVER-
IZED COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT SUPPLIED BY COMBUSTION EN-
GINEERING. AN ESP IS EMPLOYED FOR PARTICULATE CONTROL AND THE CLEANED
FLUE GAS EXITS A 600 FT STACK. THE SYSTEM CAN OPERATE IN AN OPEN OR
CLOSED WATER LOOP MODE. OPERATIONS BEGAN IN DECEMBER I960.
LOUISVILLE GAS t ELECTRIC
MILL CREEK
2
RETROFIT 350 MW (GROSS)
350 MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 1 STARTUP 12/81
MILL CREEK 2 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT LIME FGD SYSTEM IS PRESENTLY OPERATING ON THIS PULVER-
IZED COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT SUPPLIED BY COMBUSTION EN-
GINEERING. AN ESP IS EMPLOYED FOR PARTICULATE CONTROL AND THE CLEANED
FLUE GAS EXITS A 600 FT STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP
MODE. INITIAL START-UP TOOK PLACE IN DECEMBER 1981.
2-15
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE GAS i ELECTRIC
MILL CREEK
3
NEW 427 MW (GROSS)
427 MW (ESC)
COAL
3.87 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *»**x
STATUS 1 STARTUP 8/78
LOUISVILLE GAS AND ELECTRIC'S MILL CREEK 3 IS A 3.87X S COAL (11,300 BTU/
LB) FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY. AMERICAN AIR FILTER SUP-
PLIED A CARBIDE LIME FGD SYSTEM FOR THIS UNIT WHICH WAS DESIGNED TO REMOVE
857. OF THE S02 FROM THE FLUE GAS. AN ESP IS FOLLOWED BY FOUR MOBILE BED
CONTACTORS AND A STEAM TUBE REHEATER. CLEANED FLUE GAS EXITS A 600 FT
STACK. THE WATER LOOP IS OPEN AND THE LIME/FLYASH STABILIZED SLUDGE IS -
PONDED. THIS UNIT HAS BEEN OPERATIONAL SINCE AUGUST 1978.
LOUISVILLE GAS t ELECTRIC
MILL CREEK
4
NEW 495 MW (GROSS)
495 MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: **«*X
STATUS 1 STARTUP 7/82
MILL CREEK 4 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS
COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY.
THE EMISSION CONTROL SYSTEM CONSISTS OF AN ESP AND FOUR MOBILE BED CON-
TACTORS. THE LIME FGD SYSTEM FOR THIS UNIT WAS SUPPLIED BY AMERICAN AIR
FILTER. THE SYSTEM'S WATER LOOP IS CLOSED AND THE SLUDGE IS STABILIZED
WITH LIME AND FLYASH. STEAM TUBES PROVIDE REHEAT OF THE CLEANED GASES
WHICH EXIT A 600 FT STACK. INITIAL START-UP WAS IN JULY 1982.
LOUISVILLE GAS £ ELECTRIC
PADDY'S RUN
6
RETROFIT 72 MW (GROSS)
72 MW (ESC)
COAL
3.70 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: E.8X
STATUS 1 STARTUP 4/73
UNIT 6 AT LOUISVILLE GAS AND ELECTRIC'S PADDY'S RUN STATION IS A DRY BOT-
TOM PULVERIZED COAL (3.8X S, 11,300 BTU/LB) FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. A RETROFIT CARBIDE LIME FGD SYSTEM BY COMBUSTION ENGINEERING TREATS
400,000 ACFM OF FLUE GAS FROM THE BOILER. AN ESP IS FOLLOWED BY TWO MARBLE
BED ABSORBERS, A DIRECT COMBUSTION REHEATER, AND A 250 FOOT STACK. MIST
ELIMINATION IS PROVIDED BY ONE CHEVRON/MODULE. THE LIME FIXATED SLUDGE IS
TRUCKED TO AN UNLINED POHD, AND THE WATER LOOP IS CLOSED. THE FGD SYSTEM
BEGAN INITIAL OPERATIONS IN APRIL 1973.
LOUISVILLE GAS * ELECTRIC
TRIMBLE COUNTY
1
NEW 575 MW (GROSS)
575 MW (ESC)
COAL
4.00 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 7/87
LOUISVILLE GAS AND ELECTRIC WILL BE INSTALLING FGD SYSTEMS ON TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 4X S (IF NO COAL WASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS WILL BE CLEANED BY ESP'S AND WET SCRUBBING ( 90X REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 1 IS SCHEDULED
FOR START-UP IN JULY 1987.
LOUISVILLE GAS & ELECTRIC
TRIMBLE COUNTY
2
NEW 575 MW (GROSS)
575 MW (ESC)
COAL
4.00 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 7/90
LOUISVILLE GAS AND ELECTRIC WILL BE INSTALLING FGD SYSTEMS ON TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 4X S (IF NO COAL WASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS WILL BE CLEANED BY ESP'S AND WET SCRUBBING (90X REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 2 IS SCHEDULED
FOR START-UP IN 1990.
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT
3
NEW 451 MW (GROSS)
451 MW (ESC)
LIGNITE
1.70 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: -.7X
STATUS 2 STARTUP 11/87
LOWER COLORADO RIVER AUTHORITY HAS STARTED CONSTRUCTION ON A 451 MW UNIT,
FAYETTE POWER PROJECT 3, IN LA GRANGE, TEXAS. THE LIGNITE (1.7X S, 4300
BTU/LB) FIRED BOILER WILL UTILIZE A WET LIMESTONE SCRUBBING SYSTEM
DESIGNED TO REMOVE 90X 502. AN ESP SUPPLIED BY FLAKT WILL CONTROL
PARTICLE EMISSIONS AND THE CLEANED FLUE GAS WILL EXIT THROUGH A 535 FOOT
ACID BRICK LINED STACK. SLUDGE WILL BE FORCIBLY OXIDIZED BEFORE BEING
DISPOSED IN AN ON-SITE LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN
1988.
2-16
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT
4
NEW 451 MM (GROSS)
451 MW (ESC)
LIGNITE
1.70 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «***X
STATUS 6 STARTUP 6/90
LOWER COLORADO RIVER AUTHORITY HAS PLANS FOR A 451 MW UNIT, FAYETTE
POWER PROJECT 4, TO BE LOCATED IN LA GRANGE TEXAS. THE LIGNITE (1.7X S,
4300 BTU/LB) FIRED BOILER WILL UTILIZE A WET LIMESTONE SCRUBBING SYSTEM
DESIGNED TO REMOVE 90X 302. AN EDP WILL CONTROL PARTICLE EMISSIONS AND
THE CLEANED FLUE GAS WILL EXIT THROUGH A 535 FOOT ACID BRICK LINED STACK.
SLUDGE WILL BE FORCE OXIDIZED BEFORE BEING DISPOSED IN AN ON-SITE LAND-
FILL. INITIAL START-UP IS SCHEDULED FOR JUNE 1990.
MARQUETTE BOARD OF
SHIRAS
3
NEW
44 MW (GROSS)
44 MW (ESC)
COAL
.30 XS SUBBITUMINOUS
LIME/SPRAY DRYING
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: *«**X
STATUS 1 STARTUP 3/83
LIGHT t PWR SHIRAS 3 OF THE MARQUETTE BOARD OF LIGHT AND POWER IS A PULVERIZED SUBBI-
TUMINOUS COAL (.3X S, 8654 BTU/LB) FIRED BOILER LOCATED IN MARQUETTE,
MICHIGAN. GE ENVIRONMENTAL SERVICES HAS SUPPLIED A LIME/SPRAY DRYING PRO-
CESS TO CONTROL EMISSIONS. FABRIC FILTERS WITH 99.8X REMOVAL EFFICIENCY
CONTROL PARTICULATE MATTER AND THE CLEANED FLUE GAS EXITS A 350 FT STACK.
THE FGD WASTE IS DISPOSED AT AN OFF-SITE LANDFILL. OPERATIONS COMMENCED
IN MARCH 1983.
MICHIGAN SO CENTRAL PWR AGENCY
PROJECT
1
NEW 55 MW (GROSS)
55 MW (ESC)
COAL
3.25 XS BITUMINOUS
LIMESTONE
BAECOCK & WILCOX
ENERGY CONSUMPTION: 1.8X
STATUS 1 STARTUP 5/83
THE PROJECT 1 UNIT OF MICHIGAN SOUTH CENTRAL POWER AGENCY IS A PULVERIZED
COAL FIRED BOILER LOCATED IN LICHTFIELD, MICHIGAN. THE EMISSION CONTROL
SYSTEM CONSISTS OF A HOT SIDE ESP AND A BABCOCK t WILCOX LIMESTONE SPRAY
TOWER. THE SPRAY TOWER MIST ELIMINATOR IS FOLLOWED BY AN IN-LINE REHEAT-
ER AND A 250 FOOT STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP AND
SLUDGE IS DISPOSED AT AN OFF-SITE LANDFILL. OPERATIONS COMMENCED IN MAY
1983.
MIDDLE SOUTH UTILITIES
WILTON
1
NEW 890 MW (GROSS)
890 MW (ESC)
COAL
.50 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 4 STARTUP 99/99
WILTON 1 IS A COAL (.50X S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUS-
TION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CONTROL. START-UP HAS BEEN DEFERRED INDEFINITELY.
MIDDLE SOUTH UTILITIES
WILTON
2
NEW 890 MW (GROSS)
890 MW (ESC)
COAL
.50 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 4 STARTUP 99/99
WILTON 2 IS A COAL (.50X S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUS-
TION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CONTROL. START-UP HAS BEEN DEFERRED INDEFINITELY.
MINNESOTA POWER & LIGHT
CLAY BOSWELL
4
NEW 554 MW (GROSS)
475 MW (ESC)
COAL
.94 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 2/80
CLAY BOSWELL 4 OF MINNESOTA POWER AND LIGHT IS A SUBBITUMINOUS COAL (0.94X
S, 8287 BTU/LB) FIRED UNIT LOCATED IN COHASSET, MINNESOTA. PEABODY PRO-
CESS SYSTEMS HAS SUPPLIED A LIME/ALKALINE FLYASH SYSTEM WHICH IS DESIGNED
TO REMOVE 64.6X OF THE S02 IN THE FLUE GAS. PARTICULATE MATTER AND ADD-
ITIONAL S02 CONTROL IS ACHIEVED WITH VENTURI SCRUBBERS (ONE HOT SIDE ESP
CONTROLS PARTICULATE MATTER IN THE BYPASS FLUE GAS STREAM). MIST ELIMINA-
TION IS PROVIDED BY A SIEVE TRAY FOLLOWED BY A SPIN VANE CHEVRON, AND RE-
HEAT IS SUPPLIED BY BYPASSING 5X OF THE FLUE GAS. THE SYSTEM OPERATES IN
A CLOSED WATER LOOP MODE, SLUDGE IS DISPOSED IN A LINED POND AND FLUE GAS
EXITS A 600 FT STACK. OPERATIONS COMMENCED IN FEBRUARY 1980.
2-17
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MINNKOTA POWER
MILTON R. YOUNG
Z
NEW 440 MW (GROSS)
374 MW (ESC)
COAL
.60 XS LIGNITE
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 9/77
MINNKOTA POWER COOPERATIVE'S MILTON R. YOUNG 2 IS A CYCLONE FIRED LIGNITE
(0.60XS, 6500 BTU/LB) BOILER LOCATED IN CENTER, NORTH DAKOTA. THE BOILER
PRODUCES 2,021,400 ACFM OF FLUE GAS, HALF OF WHICH IS CLEANED BY TWO ESP'S
AND TWO THYSSEN/CEA LIME/ALKALINE FYLASH SPRAY TOWERS (75X DESIGN
S02 REMOVAL EFFICIENCY). THE CLEANED GAS PASSES THROUGH A CHEVRON
MIST ELIMINATOR BEFORE IT JOINS A 15X BYPASS REHEAT (HOT UNSCRUEBED
GAS), AND EXITS A 550 FOOT STACK. THE WATER LOOP IS CLOSED, AND THE
SLUDGE IS TRUCKED TO AN OFF-SITE MINEFILL. OPERATIONS BEGAN IN 1977.
MONONGAHELA POWER
PLEASANTS
1
NEW
626 MW (GROSS)
626 MW (ESC)
BITUMINOUS
COAL
3.00 XS
LIME
BABCOCK t WILCOX
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 12/78
MONONGAHELA POWER PLEASANTS 1 IS A BITUMINOUS COAL (3.00X S, 12,500
BTU/LB) FIRED BOILER IN WILLOW ISLAND, WEST VIRGINIA. BABCOCK AMD WIL-
COX SUPPLIED A LIME FGD SYSTEM DESIGNED TO REMOVE 90X OF THE FLUE GAS S02
FROM THIS UNIT. THE EMISSION CONTROL SYSTEM INCLUDES AN ESP UPSTREAM OF
FOUR SPRAY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM PROVIDES REHEAT OF
THE CLEANED GAS BEFORE IT IS DISCHARGED THROUGH A 1000 FOOT PLACITE LINED
STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP. THE FGD SYSTEM ON THIS
UNIT HAS BEEN OPERATIONAL SINCE DECEMBER 1978.
MONONGAHELA POWER
PLEASANTS
2
NEW 626 MW (GROSS)
626 MW (ESC)
COAL
3.00 XS BITUMINOUS
LIME
BAECOCK & WILCOX
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 10/80
MONONGAHELA POWER PLEASANTS 2 IS A BITUMINOUS COAL (3.00 XS, 12,500 BTU/
LB) FIRED BOILER LOCATED IN WILLOW ISLAND, WEST VIRGINIA. BABCOCK AND
WILCOX SUPPLIED A LIME FGD SYSTEM DESIGNED TO REMOVE 90X OF THE BOILER
FLUE GAS SOS. THE EMISSION CONTROL SYSTEM ON THIS UNIT INCLUDES AN ESP
UPSTREAM OF FOUR SPRAY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM PROVIDES
REHEAT OF THE CLEANED GAS BEFORE IT IS DISCHARGED THROUGH A 1000 FOOT
ACID BRICK STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP. THE FGD
SYSTEM OPERATION COMMENCED IN OCTOBER 1980.
MONTANA POWER
COLSTRIP
1
NEW 360 MW (GROSS)
360 MW (ESC)
COAL
.78 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 9/75
COLSTRIP 1 OF MONTANA POWER IS A 360-MW (GROSS) SUBBITUMINOUS COAL
(0.78X S, 8843 BTU/LB) FIRED UNIT LOCATED IN COLSTRIP, MONTANA. THYSSEN/
CEA SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER MODULES. THE TOWERS ARE FOLLOWED
BY HORIZONTAL CHEVRON MIST ELIMINATORS, A STEAM TUBE REHEATER, AND A 503
FOOT STACK. THE UNSTABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN SEPTEMBER 1975.
MONTANA POWER
COLSTRIP
2
NEW 360 MM (GROSS)
360 MW (ESC)
COAL
.78 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 5/76
COLSTRIP 2 OF MONTANA POWER IS A 360-MW (GROSS) SUBBITUMINOUS COAL
(0.78X S, 8843 BTU/LB) FIRED UNIT LOCATED IN COLSTRIP, MONTANA. THYSSEN/
CEA SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON MIST ELIMINATORS, A STEAM TUBE REHEATER, AND A 503
FOOT STACK. THE UHSTABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN MAY 1976.
MONTANA POWER
COLSTRIP
3
NEW 778 MW (GROSS)
778 MW (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
BECHTEL/MONTANA POWER
ENERGY CONSUMPTION: **»*X
STATUS 1 STARTUP 10/83
MONTANA POWER'S COLSTRIP 3 IS A LOW SULFUR COAL (0.7X S, 8500 BTU/LB)
FIRED UNIT LOCATED IN COLSTRIP, MONTANA. A LIME/ALKALINE FLY-
ASH FGD SYSTEM SUPPLIED BY BECHTEL/MONTANA POWER CONTROLS S02 EMISSIONS
AT THIS UNIT. PARTICLE SCRUBBERS ARE EMPLOYED FOR THE CONTROL OF PART-
TICULATE MATTER AND THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE
FLUE GAS EXITS A 692 FT STACK. START-UP COMMENCED IN OCTOBER 1983
2-18
-------
UTILITY FGD SURVEY: OCTOBER 1963 - SEPTEMBER 1984
SECTION Z
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MONTANA POWER
COLSTRIP
4
NEW 778 MW (GROSS)
778 MW (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
BECHTEL/MONTANA POWER
ENERGY CONSUMPTION: ****X
STATUS Z STARTUP 10/85
MONTANA POWER'S COLSTRIP 4 IS A LOW SULFUR COAL (0.7X S, 8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A LIME/ALKALINE FLY-
ASH FGD SYSTEM IS BEING BUILT BY BECHTEL/MONTANA POWER FOR 95X S02 REMOVAL
EFFICIENCY AT THIS UNIT. PARTICLE SCRUBBERS WILL BE EMPLOYED FOR THE
CONTROL OF PARTICULATE MATTER WITH REHEAT FROM IN-LINE STEAM AND THE SYS-
TEM WILL OPERATE IN A CLOSED WATER LOOP MODE. SLUDGE WILL BE FORCE
OXIDIZED BEFORE BEING DISPOSED IN AN ON-SITE POND. START-UP IS SCHEDULED
FOR OCTOBER 1985.
MONTANA-DAKOTA UTILITIES
COYOTE
1
NEW 440 MW (GROSS)
440 MW (ESC)
COAL
.87 XS LIGNITE
SODIUM CARBONATE/SPRAY DRYING
WHEE LA3RATOR-FRYE/R.I.
ENERGY CONSUMPTION: 1.1X
STATUS 1 STARTUP 4/81
COYOTE 1 IS A CYCLONE FIRED PULVERIZED LIGNITE (0.87X S, 7050 BTU/LB)
BOILER OPERATING IN BEULAH, NORTH DAKOTA. THIS UNIT IS JOINTLY OWNED
BY FIVE UTILITIES, WITH MONTANA-DAKOTA UTILITIES BEING THE MAJOR
OWNER AND CONSTRUCTOR. A SODIUM CARBONATE DRY FGD SYSTEM DESIGNED TO
REMOVE 70X OF THE S02 WAS SUPPLIED BY WHEELABRATOR-FRYE AND ROCKWELL
INTERNATIONAL. THE SPRAY DRYER/BAGHOUSE SYSTEM COMMENCED OPERATION IN
APRIL 1981.
MUSCATINE
MUSCATINE
9
NEW
POWER & WATER
166 MW (GROSS)
166 MW (ESC)
COAL
3.21 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.8X
STATUS 1 STARTUP 4/83
MUSCATINE 9 IS A PULVERIZED BITUMINOUS COAL (3.21X S, 11,220 BTU/LB) FIRED
UNIT LOCATED IN MUSCATINE, IOWA. RESEARCH-COTTRELL SUPPLIED A LIMESTONE
SCRUBBING SYSTEM FOR EMISSION CONTROL. THE FGD SYSTEM FEATURES AN ESP,
TWO 100X CAPACITY ABSORBER TOWERS, STEAM COIL REHEAT, A CLOSED WATER LOOP,
FORCED OXIDATION OF THE SLUDGE BEFORE LANDFILL AND A 300 FOOT STACK. THE
DESIGN S02 REMOVAL EFFICIENCY IS 94X. OPERATIONS INITIALLY BEGAN IN
APRIL 1983.
NEBRASKA PUBLIC POWER DISTRICT FOSSIL III 1 IS A PULVERIZED SUBBITUMINOUS COAL (0.36X S, 8000 BTU/LB)
FOSSIL III
1
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
.36 XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****x
STATUS 6 STARTUP 3/96
FIRED UNIT PLANNED BY THE NEBRASKA PUBLIC POWER DISTRICT TO BE LOCATED
NEAR SARGENT, NEBRASKA. THE UTILITY IS CONSIDERING A DRY SCRUBBING
FGD PROCESS TO CONTROL EMISSIONS FROM THE 650 MW BOILER. START-UP FOR
THE UNIT IS TENTATIVELY SCHEDULED FOR MARCH 1996.
NEVADA POWER
HARRY ALLEN
1
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/94
NEVADA POWER'S HARRY ALLEN 1 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEtN PREPARED. START-
UP IS SCHEDULED FOR 1994.
NEVADA POWER
HARRY ALLEN
2
NEW 500 MM (GROSS)
500 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/95
NEVADA POWER'S HARRY ALLEN 2 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
UP IS SCHEDULED FOR 1995.
2-19
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEVADA POKER
HARRY ALLEN
3
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/96
NEVADA POWER'S HARRY ALLEN 3 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
UP IS SCHEDULED FOR 1996.
NEVADA POWER
HARRY ALLEN
4
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/97
NEVADA POWER'S HARRY ALLEN 4 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
UP IS SCHEDULED FOR 1997.
NEVADA POWER
REID GARDNER
1
RETROFIT 125 MW (GROSS)
125 MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: ****x
STATUS 1 STARTUP 3/74
REID GARDNER 1 IS A 125-MW (GROSS) WET BOTTOM LOW SULFUR COAL (0.5X S,
12,450 BTU/LB) FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA.
THE THYSSEN/CEA SODIUM CARBONATE-BASED (TRONA) SCRUBBING SYSTEM
CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFORATED PLATE WASH
TOWER. PRIMARY PARTICULATE CONTROL IS PROVIDED BY UPSTREAM MULTICLOK'ES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM COIL REHEATER
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION POND. THE
DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
SINCE MARCH 1974.
NEVADA POWER
REID GARDNER
2
RETROFIT 125 MW (GROSS)
125 MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 4/74
REID GARDNER 2 IS A 125-MW (GROSS) WET BOTTOM LOW SULFUR COAL (0.5X S,
12,450 BTU/LB) FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA.
THE THYSSEN/CEA SODIUM CARBONATE-BASED (TRONA) SCRUBBING SYSTEM
CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFORATED PLATE WASH
TOWER. PRIMARY PARTICULATE CONTROL IS PROVIDED BY UPSTREAM MULTICLONES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM COIL REHEATER
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION POND. THE
DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL 1974.
NEVADA POWER
REID GARDNER
3
NEW 125 MW (GROSS)
125 MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: ****x
STATUS 1 STARTUP 6/76
REID GARDNER 3 IS A 125-MW (GROSS) WET BOTTOM LOW SULFUR BITUMINOUS COAL
(0.5X S, 12,450 BTU/LB) FIRED FOSTER WHEELER UNIT LOCATED IN MOAPA,
NEVADA. THE THYSSEN/CEA SODIUM CARBONATE-BASED (TRONA) SCRUBBING SYSTEM
CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH A SINGLE STAGE PERFORATED PLATE WASH
TOWER. PRIMARY PARTICULATE CONTROL IS PROVIDED BY UPSTREAM MULTICLONES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM COIL REHEATER
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION POND. THE
DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE 1976.
NEVADA POWER
REID GARDNER
4
NEW 295 MW (GROSS)
250 MW (ESC)
COAL
.75 XS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: **#*x
STATUS 1 STARTUP 6/83
REID GARDNER 4 IS A 295 MW (GROSS) LOW SULFUR COAL (0.75X S, 11,500 BTU/
LB) FIRED UNIT LOCATED IN MOAPA, NEVADA. THE EMISSION CONTROL SYSTEM CON-
SISTS OF A THYSSEN/CEA SODIUM CARBONATE FGD SYSTEM FOR S02 CONTROL. A
BAGHOUSE PRECEDES THE FGD SYSTEM FOR PARTICULATE MATTER CONTROL. THE SYS-
TEM OPERATES IN AN OPEN WATER LOOP MODE AND FLUE GAS EXITS A 500 FT STACK
OPERATIONS COMMENCED IN JUNE 1983.
2-20
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEW YORK STATE ELEC t GAS
SOMERSET
1
NEW 625 MM (GROSS)
625 MM (ESC)
COAL
2.70 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: »***X
STATUS 1 STARTUP 7/84
THE NEW YORK STATE ELECTRIC & GAS CORP. IS OPERATING A PULVERIZED BITUMI-
NOUS COAL (2.2X S, 13,000 BTU/LB) FIRED BOILER SUPPLIED BY BABCOCK ft
WILCOX, IN SOMERSET, NEW YORK WHICH GENERATES A FLUE GAS FLOW OF 2,862,000
ACFM. A COLD SIDE ESP WITH A DESIGN EFFICIENCY OF 99.7X PROVIDES THE PRI-
MARY PARTICULATE REMOVAL. PEABODY PROCESS SYSTEMS SUPPLIED A LIMESTONE
FGD SYSTEM WITH A DESIGN REMOVAL EFFICIENCY OF 90X FOR S02 CONTROL. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND FLUE GAS PASSES THROUGH AN
IN-LINE STEAM REHEATER INTO A 450 FT STACK. THE SLUDGE IS DEWATERED AND
STABILIZED BEFORE ON-SITE LANDFILLED. OPERATIONS COMMENCED IN JULY 1984.
NIAGARA MOHAWK POWER
CHARLES R. HUNTLEY
66
RETROFIT 100 MW (GROSS)
100 MM (ESC)
COAL
1.80 XS
AQUEOUS CARBONATE/SPRAY DRYING
ROCKWELL INTERNATIONAL
ENERGY CONSUMPTION: **»*X
STATUS 1 STARTUP 4/82
CHARLES R. HUNTLEY 66 OF NIAGARA POWER COOP IS A PULVERIZED COAL (1.8X S,
12,500 BTU/LB) FIRED UNIT LOCATED IN BUFFALO, NEW YORK. ROCKWELL INTER-
NATIONAL DESIGNED AND INSTALLED A 90X EFFICIENT AQUEOUS CARBONATE
FGD SYSTEM WHICH PRODUCES ELEMENTAL SULFUR AS AN END PRODUCT. FUNDS
WERE PROVIDED BY THE U.S. EPA AND THE EMPIRE STATE ELECTRIC ENERGY
RESEARCH CORP. A SPRAY DRYER IS FOLLOHED BY TMO BANKS OF 8 CYCLONES, AN
ESP, AND A LINED 200 FOOT CARBON STEEL STACK. THE WATER LOOP IS OPEN.
START-UP OF THE FGD SYSTEM WAS IN APRIL, 1982.
NORTHERN INDIANA PUB SERVICE
SCHAHFER
17
NEW 391 MW (GROSS)
391 MW (ESC)
COAL
3.20 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: ****•/.
STATUS 1 STARTUP 4/83
SCHAHFER 17 OF NORTHERN INDIANA PUBLIC SERVICE IS A 391 MW (GROSS) COAL
(3.2X S, 10,900 BTU/LB) FIRED UNIT LOCATED IN WHEATFIELD, INDIANA. THE
FMC EMISSION CONTROL SYSTEM CONSISTS OF AN ESP FOLLOWED BY FOUR DUAL
ALKALI WET ABSORBERS. THE CLEANED FLUE GAS IS REHEATED AND EXITS VIA A
500 FOOT STACK. INITIAL OPERATIONS COMMENCED IN APRIL 1983.
NORTHERN INDIANA PUB SERVICE
SCHAHFER
16
NEW 391 MM (GROSS)
391 MW (ESC)
COAL
3.20 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: ««**X
STATUS 2 STARTUP 6/86
SCHAHFER 18 OF NORTHERN INDIANA PUBLIC SERVICE IS A COAL (3.2X S, 11,085
BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN WHEATFIELD, INDIANA. THE UTILITY
AWARDED A CONTRACT TO FMC FOR THE INSTALLATION OF A DUAL ALKALI
FGD SYSTEM AT THIS UNIT. PARTICULATE MATTER WILL BE COLLECTED BY AN ESP
AND THE SYSTEM WILL INCLUDE A REHEATER. START-UP OF THIS UNIT IS
SCHEDULED FOR JUNE 1986.
NORTHERN STATES POWER
RIVERSIDE
6-7
RETROFIT 110 MW (GROSS)
110 MW (ESC)
COAL
1.20 XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: *«**X
STATUS 1 STARTUP 11/80
RIVERSIDE 6 AND 7 ARE TWO COAL FIRED BOILERS OWNED BY NORTHERN STATES
POWER AND LOCATED IN MINNEAPOLIS, MINNESOTA. EACH BOILER GENERATES A FLUE
GAS FLOW OF 340,000 ACFM AT 350 F. CURRENTLY, A DEMONSTRATION LIME/SPRAY
DRYING FGD SYSTEM THAT IS CAPABLE OF TREATING THE FLUE GAS FROM BOTH
BOILERS IS BEING TESTED AT THIS UNIT. THE SYSTEM WAS SUPPLIED BY NIRO
ATOMIZER/JOY MANUFACTURING AND CONSISTS OF A SPRAY DRYER FOLLOWED BY
A BAGHOUSE. THE CLEAN FLUE GAS IS VENTED TO TWO 275 FT CONCRETE STACKS
WITH FIRE BRICK LINERS. SPENT ABSORBENT IS BEING DISPOSED OF IN AN
OFF-SITE LANDFILL. OPERATIONS COMMENCED IN NOVEMBER 1980.
NORTHERN STATES POWER
SHERBURNE
1
NEW 750 MM (GROSS)
750 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 4.OX
STATUS 1 STARTUP 3/76
NORTHERN STATES POWER'S SHERBURNE 1 IS A BALANCED DRAFT PULVERIZED SUBBI-
TUMINOUS COAL (0.80X S, 8400 BTU/LB) FIRED BOILER IN BECKER, MINNESOTA. A
SOX EFFICIENT (DESIGN) LIMESTONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MARCH
1976. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MIST ELIMINATOR/TRAIN, AN IN-LINE HOT WATER
REHEATER, AND A 650 FOOT COR-TEN LINED STACK. THE SLUDGE IS FORCIBLY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LOOP IS OPEN.
2-21
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NORTHERN STATES POWER
SHERBURNE
2
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 4.OX
STATUS 1 STARTUP 3/77
NORTHERN STATES POWER'S SHERBURNE 2 IS A BALANCED DRAFT PULVERIZED SUBBI-
TUMINOUS COAL (0.80X S, 8400 BTU/LB) FIRED BOILER IN BECKER, MINNESOTA. A
SOX EFFICIENT (DESIGN) LIMESTONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MARCH
1977. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MIST ELIMINATOR/TRAIN, AN IN-LINE HOT WATER
REHEATER, AND A 650 FOOT COR-TEN LINED STACK. THE SLUDGE IS FORCIBLY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LOOP IS OPEN.
NORTHERN STATES POWER
SHERBURNE
3
NEW 860 MW (GROSS)
810 MW (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS Z STARTUP 0/88
NORTHERN STATES POWER, SHERBURNE 3 IS A 800 MW (NET) PULVERIZED COAL
(l.OX S, 8700 BTU/LB) FIRED BOILER UNDER CONSTRUCTION AND ADJACENT TO
THE SHERBURNE 1 AND 2 UNITS IN BECKER, MINNESOTA. THE UTILITY AWARDED A
CONTRACT TO JOY MFG/NIRO ATOMIZER FOR A LIME SPRAY DRYING SYSTEM TO CON-
TROL SOS EMISSIONS. FABRIC FILTERS WILL BE EMPLOYED FOR PARTICULATE CON-
TROL. THE SYSTEM WILL OPERATE IN A CLOSED MATER LOOP MODE. INITIAL START
UP IS SCHEDULED FOR JANUARY 1988.
ORLANDO UTILITIES COMMISSION
C.H. STANTON
1
NEW 465 MW (GROSS)
465 MW (ESC)
COAL
***** XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 0/87
ORLANDO UTILITIES COMMISSION IS CONSTRUCTING A 465 MW (GROSS), COAL FIRED
UNIT, C.H. STANTON 1, NEAR ORLANDO, FLORIDA. THE UTILITY WILL CONTROL
PARTICLE MATTER VIA ESP. S02 EMISSIONS WILL BE CONTROLLED WITH A WET
LIMESTONE FGD SYSTEM WITH A REMOVAL EFFICIENCY OF 90X, SUPPLIED BY
COMBUSTION ENGINEERING. INITIAL START-UP IS SET FOR THE FALL OF 1987.
PACIFIC POWER & LIGHT
JIM BRIDGER
1
RETROFIT 550 MW (GROSS)
550 MW (ESC)
COAL
.56 XS SUBBITUMINOUS
SODIUM CARBONATE
BABCOCK & WILCOX
ENERGY CONSUMPTION: .2X
STATUS 3 STARTUP 0/90
PACIFIC POWER AND LIGHT'S JIM BRIDGER 1 IS A DRY BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB) FIRED BOILER SUPPLIED BY COMBUSTION
ENGINEERING AND LOCATED IN ROCK SPRINGS, WYOMING. THE UTILITY HAS AWARD-
ED A CONTRACT TO BABCOCK & WILCOX FOR A RETROFIT WET SODIUM CARBONATE FGD
SYSTEM, WHICH TREATS 2,700,000 ACFM OF FLUE GAS. A COLD-SIDE ESP IS CUR-
RENTLY IN OPERATION FOR PRIMARY PARTICULATE CONTROL. THE FGD SYSTEM WILL
OPERATE IN A CLOSED WATER LOOP MODE AND FLUE GAS WILL EXIT A 500 FT STACK.
START-UP IS SCHEDULED FOR 1990.
PACIFIC POWER t LIGHT
JIM BRIDGER
2
RETROFIT 550 MW (GROSS)
550 MW (ESC)
COAL
.56 XS SUBBITUMINOUS
SODIUM CARBONATE
BABCOCK & WILCOX
ENERGY CONSUMPTION: ,2X
STATUS 2 STARTUP 0/86
PACIFIC POWER AND LIGHT'S JIM BRIDGER 2 IS A DRY BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56X S, 9300 BTU/LB) FIRED BOILER SUPPLIED BY COMBUSTION
ENGINEERING AND LOCATED IN ROCK SPRINGS, WYOMING. BABCOCK & WILCOX IS
CONSTRUCTING A RETROFIT WET SODIUM CARBONATE FGD SYSTEM, WHICH WILL TREAT
2,700,000 ACFM OF FLUE GAS. A COLD-SIDE ESP IS CURRENLY IN OPERATION FOR
PRIMARY PARTICULATE CONTROL. THE FGD SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP AND FLUE GAS WILL EXIT A 500 FT STACK. INITIAL START-UP IS
SCHEDULED FOR 1986.
PACIFIC POWER & LIGHT
JIM BRIDGER
3
RETROFIT 550 MW (GROSS)
550 MW (ESC)
COAL
.56 XS SUBBITUMINOUS
SODIUM CARBONATE
BABCOCK * WILCOX
ENERGY CONSUMPTION: .2X
STATUS 3 STARTUP 0/88
PACIFIC POWER AND LIGHT'S JIM BRIDGER 3 IS A DRY BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB.) FIRED BOILER SUPPLIED BY COMBUSTION
ENGINEERING AND LOCATED IN ROCK SPRINGS, WYOMING. THE UTILITY HAS Ats'AnnFP
A CONTRACT TO BABCOCK 4 WILCOX FOR A RETROFIT WET SODIUM CARBONATE FGD
SYSTEM, WHICH TREATS 2,700,000 ACFM OF FLUE GAS. A COLD-SIDE ESP IS CUR-
RENTLY IN OPERATION FOR PRIMARY PARTICULATE CONTROL. THE FGD SYSTEM WILL
OPERATE IN A CLOSED WATER LOOP MODE AND FLUE GAS WILL EXIT A 500 FT STACK.
INITIAL START-UP IS SCHEDULED FOR 1988.
2-22
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION Z
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PACIFIC POWER & LIGHT
JIM BRIDGER
4
NEW 550 MW (GROSS)
550 MM (ESC)
COAL
.56 XS SUBBITUMINOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION; .ax
STATUS 1 STARTUP 9/79
PACIFIC POWER AND LIGHT'S JIM BRIDGER 4 IS A DRY BOTTOM PULVERIZED
SUBBITUMINOUS COAL (0.56X Si 9300 BTU/LB) FIRED BOILER LOCATED IN
ROCK SPRINGS, WYOMING. A 91X EFFICIENT SODIUM CARBONATE FGD SYSTEM FOR
THIS UNIT WAS SUPPLIED BY THE AIR CORRECTION DIVISION OF UOP. A COLD
SIDE ESP TREATS 2,720,000 ACFM OF FLUE GAS, FOLLOWED BY THREE SIEVE
TRAY ABSORBERS. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND FLUE
GAS EXITS A 500 FT STACK. A SYSTEM CHECK OUT WAS CONDUCTED IN JULY 1979
AND OPERATIONS BEGAN IN SEPTEMBER 1979.
PACIFIC POWER « LIGHT
WYODAK
1
RETROFIT 330 MW (GROSS)
330 MW (ESC)
COAL
***** XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY/NIRO
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 0/86
PACIFIC POWER AND LIGHT HAS AWARDED A CONTRACT TO JOY/NIRO TO RETROFIT A
LIME SPRAY DRYING FGD SYSTEM WITH RECYCLE ASH ON WYODAK 1, A 330 MW( GROSS)
SUBBITUMINOUS COAL FIRED UNIT. THE UNIT IS LOCATED IN JOLIET, WYOMING AND
IS A MINE MOUTH PLANT. THE UNIT STARTED IN 1978 AND THE FGD SYSTEM IS
SCHEDULED TO START-UP IN 1986.
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
NEW 917 MW (GROSS)
917 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 4.IX
STATUS 1 STARTUP IE/75
BRUCE MANSFIELD 1 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.5X S, 12,000 BTU/LB) IN SHIPPINGPORT,
PENNSYLVANIA. A GEESI THIOSORBIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (92.IX) FROM 3,350,000 ACFM OF FLUE GAS. THE FGD SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIX FIXED
THROAT VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT COMBUS-
TION REHEATERS (INCLUDED IN ORIGINAL DESIGN BUT LATER REMOVED FROM
SERVICE) AND A 950 FOOT FLAKEGLASS STACK SHARED BY UNITS 1 AND Z. THE .
WATER LOOP IS OPEN, AND THE CALCILOX FIXED SLUDGE IS DISPOSED IN
AN OFF-SITE POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE DECEMBER 1975.
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
NEW 917 MW (GROSS)
917 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 4. IX
STATUS 1 STARTUP 7/77
BRUCE MANSFIELD 2 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.5X S, 12,000 BTU/LB) IN SHIPPINGPORT,
PENNSYLVANIA. A GEESI THIOSORBIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (92.IX) FROM 3,350,000 ACFM OF FLUE GAS. THE FGD SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIX FIXED
THROAT VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT COMBUS-
TION REHEATERS (INCLUDED IN ORIGINAL DESIGN BUT LATER REMOVED FROM
SERVICE) AND A 950 FOOT FLAKEGLASS STACK SHARED BY UNITS 1 AND 2. THE
WATER LOOP IS OPEN, AND THE CALCILOX FIXED SLUDGE IS DISPOSED IN
AN OFF-SITE POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
PENNSYLVANIA POWER
BRUCE MANSFIELD
3
NEW 917 MW (GROSS)
917 MW (ESC)
COAL
4.30 XS BITUMINOUS
LIME
M.W. KELLOGG
ENERGY CONSUMPTION: 3.IX
STATUS 1 STARTUP 6/80
BRUCE MANSFIELD 3 OF PENNSYLVANIA POWER IS A SUPERCRITICAL PULVERIZED
COAL (4.3X S, 12,000 BTU/LB) FIRED BOILER LOCATED IN SHIPPINSPORT,
PENNSYLVANIA. FOUR ESP'S TREAT 3,308,000 ACFM OF FLUE GAS, FOLLOWED
BY FIVE (ONE SPARE) M. W. KELLOGG THIOSORBIC LIME ABSORBERS WHICH
REMOVE 92.2X OF THE S02. THE CLEANED GAS PASSES THROUGH
CHEVRON MIST ELIMINATORS AND DIRECT COMBUSTION REHEATERS BEFORE
DISCHARGE THROUGH A 600 FOOT INCONEL 625 STACK FLUE. THE SYSTEM OPER-
ATES IN AN OPEN WATER LOOP MODE AND FLYASH STABILIZED SLUDGE IS PIPED TO
AN OFF-SITE LANDFILL. OPERATIONS COMMENCED IN JUNE 1980.
PHILADELPHIA ELECTRIC
CROMBY
1
RETROFIT 160 MW (GROSS)
150 MW (ESC)
COAL
2.00 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: «**«X
STATUS 1 STARTUP 10/82
PHILADELPHIA ELECTRIC HAS RETROFITTED AN FGD SYSTEM ON ONE OF THE
TWO 2.OX SULFUR COAL FIRED BOILERS AT CROMBY STATION IN PHOENIXVILLE,
PENNSYLVANIA. THE MAGNESIUM OXIDE SYSTEM WAS SUPPLIED BY UNITED
ENGINEERS. FABRIC FILTERS AND PARTICLE SCRUBBERS ARE EMPLOYED FOR
PARTTICULATE CONTROL. THE SYSTEM BECAME OPERATIONAL IN OCTOBER 1982.
2-23
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PHILADELPHIA ELECTRIC
EDDYSTONE
1
RETROFIT 240 MW (GROSS)
240 MW (ESC)
COAL
2.00 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 9/82
UNIT 1 OF PHILADELPHIA ELECTRIC'S EDDYSTONE, PENNSYLVANIA STATION IS A
BITUMINOUS COAL (2.OX S, 13,600 BTU/LB) FIRED UNIT WHICH USES ESP'S,
MECHANICAL COLLECTORS, AND THREE PARTICLE SCRUBBERS (TWO ROD DECK SPRAY
TOWERS AND ONE VENTURI) FOR PRIMARY PARTICLE CONTROL. THE UNIT 1 FGD
SYSTEM FOLLOWS THE TWO ROD DECK SPRAY TOWERS. UNITED ENGINEERS
SUPPLIED A MAGNESIUM OXIDE FGD SYSTEM FOR S02 EMISSION CONTROL SIMILAR
TO THE MAGNESIUM OXIDE PROTOTYPE SYSTEM THAT WAS PREVIOUSLY OPERATED
AT THIS UNIT. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE.
OPERATIN OF THE FGD SYSTEM COMMENCED IN SEPTEMBER 19S2.
PHILADELPHIA ELECTRIC
EDDYSTONE
2
RETROFIT 334 MW (GROSS)
334 MW (ESC)
COAL
2.00 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: «**«X
STATUS 1 STARTUP 11/82
EDDYSTONE 2 OF PHILADELPHIA ELECTRIC IS A 2.OX SULFUR COAL FIRED BOILER
LOCATED IN EDDYSTONE, PENNSYLVANIA. THE PLANT'S GENERATING
CAPACITY IS 334 MW. UNITED ENGINEERS HAS SUPPLIED A MAGNESIUM OXIDE
FGD SYSTEM FOR EMISSION CONTROL AND PARTICLE SCRUBBERS ARE EMPLOYED FOR
PARTICULATE REMOVAL. OPERATIONS COMMENCED IN NOVEMBER 1982.
PLAINS ELECTRIC G 4 T
PLAINS ESCALANTE
1
NEW 233 MW (GROSS)
233 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *«**X
STATUS 2 STARTUP 10/84
PLAINS ESCALANTE 1 OF PLAINS ELECTRIC G t T IS A PULVERIZED SUBBITUMINOUS
COAL (.80X S) FIRED UNIT UNDER CONSTRUCTION IN PREWITT, NEW MEXICO. THE
233 MW UNIT SUPPLIED BY COMBUSTION ENGINEERING WILL UTILIZE A WET LIME-
STONE SCRUBBING PROCESS WITH A S02 REMOVAL EFFICIENCY OF 75X. A FABRIC
FILTER SUPPLIED BY GE ENVIRONMENTAL SERVICES WILL PROVIDE PRIMARY PARTICLE
CONTROL. SLUDGE WILL BE MIXED WITH FLYASH AND DISPOSED AT AN ON-SITE
LANDFILL. A CONTRACT WAS AWARDED TO COMBUSTION ENGINEERING FOR THE WET
LIMESTONE SYSTEM. INITIAL START-UP IS SCHEDULED FOR OCTOBER 1984.
PLATTE RIVER POWER AUTHORITY
RAWHIDE
1
NEW 279 MW (GROSS)
279 MW (ESC)
COAL
.34 XS BITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: **«*X
STATUS 1 STARTUP 12/83
RAWHIDE 1, OF THE PLATTE RIVER POWER AUTHORITY, IS LOCATED IN
WELLINGTON, COLORADO. THE 279 MW PULVERIZED COAL (0.34X S, 8500 BTU/LB)
FIRED BOILER WAS SUPPLIED BY COMBUSTION ENGINEERING. JOY MANUFACT-
URING/NIRO ATOMIZER SUPPLYED A DRY LIME SCRUBBING SYSTEM FOR S02
CONTROL AND FABRIC FILTERS ARE EMPLOYED FOR PARTICULATE REMOVAL. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND SLUDGE IS DIS-
POSED OF IN A LANDFILL. FLUE GAS EXITS A 505 FT STACK. THE UNIT
COMMENCED INITIAL OPERATIONS IN DECEMBER 1983.
PUBLIC SERVICE INDIANA
GIBSON
5
NEW 670 MW (GROSS)
670 MW (ESC)
COAL
3.30 XS
LIMESTONE
M.W. KELLOGG
ENERGY CONSUMPTION: *»**X
STATUS 1 STARTUP 10/62
GIBSON 5 OF PUBLIC SERVICE OF INDIANA IS A 3.3X SULFUR COAL FIRED UNIT
LOCATED IN PRINCETON, INDIANA. THE SYSTEM SUPPLIER, M.W. KELLOG,
HAS INSTALLED A LIMESTONE FGD SYSTEM CONSISTING OF FOUR KELLOGG-
WEIR ABSORBER-REACTOR MODULES. THE SYSTEM USES KELLOGG'S PROPRIETARY
MAGNESIUM-PROMOTED LIMESTONE. ESP'S ARE EMPLOYED FOR PARTICULATE CONTROL
AND FLUE GAS EXITS A 500 FT STACK. THE SYSTEM OPERATES IN A CLOSED WATER
LOOP MODE. OPERATINS COMMENCED IN OCTOBER 1982.
PUBLIC SERVICE OF NEW MEXICO
NEW MEXICO
1
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
*»*** XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***x
STATUS 6 STARTUP 0/95
PUBLIC SERVICE OF NEW MEXICO HAS PLANS FOR A NEW UNIT, NEW MEXICO 1, TO BE
LOCATED IN BISTI, NEW MEXICO. THE PULVERIZED SUBBITUMINOUS COAL (9000
BTU/LB) FIRED UNIT WILL HAVE A GROSS MEGAWATT RATING OF 500. THE UTILITY
IS CONSIDERING WET LIMESTONE OR LIME/SPRAY DRYING FGD SYSTEMS FOR S02
CONTROL AND FABRIC FILTER FOR PARTICULATE CONTROL. THE SYSTEM WILL OPER-
ATE IN A CLOSED WATER LOOP MODE. INITIAL START-UP IS SCHEDULED FOR 1995.
2-24
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
1
RETROFIT 361 MW (GROSS)
361 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 4.4X
STATUS 1 STARTUP 4/78
SAN JUAN 1 OF PUBLIC SERVICE OF NEW MEXICO IN WATERFLOW, NEW MEXICO IS A
COAL (0.8X S, 9000 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,000 ACFM OF
FLUE GAS TO A RETROFIT WELLMAN LORD FGD SYSTEM BY DAVY MCKEE. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE APRIL 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSOR-
BER TRAINS WHICH WERE DESIGNED TO REMOVE 85X OF THE FLUE GAS S02. AN IN-
DIRECT HOT AIR REHEATER PRECEDES A 400 FT BRICK LINED STACK. ACCORDING
TO THE ORIGINAL DESIGN, THE SYSTEM EMPLOYED THE ALLIED CHEMICAL PROCESS
FOR ELEMENTAL SULFUR RECOVERY. THE SYSTEM HAS SINCE BEEN MODIFIED TO
PRODUCE SULFURIC ACID. THE WATER LOOP IS CLOSED.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
RETROFIT 350 MW (GROSS)
350 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 4.6X
STATUS 1 STARTUP 8/78
SAN JUAN Z OF PUBLIC SERVICE OF NEW MEXICO IN WATERFLOW, NEW MEXICO IS A
COAL (0.8X S, 9000 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,000 ACFM OF
FLUE GAS TO A RETROFIT WELLMAN LORD FGD SYSTEM BY DAVY MCKEE. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE AUGUST 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSOR-
BER TRAINS WHICH MERE DESIGNED TO REMOVE 85X OF THE FLUE GAS S02. AN IN-
DIRECT HOT AIR REHEATER PRECEDES A 400 FT BRICK LINED STACK. ACCORDING
TO THE ORIGINAL DESIGN, THE SYSTEM EMPLOYED THE ALLIED CHEMICAL PROCESS
FOR ELEMENTAL SULFUR RECOVERY. THE SYSTEM HAS SINCE BEEN MODIFIED TO
PRODUCE SULFURIC ACID. THE WATER LOOP IS CLOSED.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
3
NEW 534 MW (GROSS)
534 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 3.6X
STATUS 1 STARTUP 12/79
SAN JUAN 3 IS A COAL (0.8X S, 9000 BTU/LB) FIRED UNIT OF THE PUBLIC
SERVICE OF NEW MEXICO AND IS LOCATED IN WATERFLOW, NEW MEXICO. THE FGD
SYSTEM, SUPPLIED BY DAVY MCKEE UTILIZES THE WELLMAN LORD S02 RECOVERY
RECOVERY PROCESS AND SULFURIC ACID IS PRODUCED AS THE END PRODUCT. FIVE
(ONE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSORBER (90X OESIGN S02 REMOVAL)
TRAINS FOLLOW A HOT SIDE ESP AND FLUE GAS EXITS A 400 FT STACK. AN INDI-
RECT HOT AIR REHEATER BOOSTS THE GAS TEMPERATURE 50 DEG F. THE SYSTEM
OPERATES IN A CLOSED WATER LOOP MODE. OPERATIONS COMMENCED IN DECEMBER
1979.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
4
NEW 534 MW (GROSS)
534 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 3.6X
STATUS 1 STARTUP 5/82
SAN JUAN 4 IS A COAL (0.8X S, 8100 BTU/LB) FIRED UNIT OF THE PUBLIC SER-
VICE OF NEW MEXICO LOCATED IN WATERFLOW, NEW MEXICO. THE FGD SYSTEM,
WHICH WAS SUPPLIED BY DAVY MCKEE, UTILIZES THE WELLMAN LORD S02 RECOVERY
PROCESS AND SULFURIC ACID IS PRODUCED AS THE END PRODUCT. FIVE (ONE
SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSORBER (90X DESIGN S02 REMOVAL)
TRAINS FOLLOW A HOT SIDE ESP AND FLUE GAS EXITS A 400 FT STACK. AN INDI-
RECT HOT AIR REHEATER BOOSTS THE GAS TEMPERATURE 50 DEG F. THE SYSTEM
OPERAES WATER LOOP MODE. THE SYSTEM COMMENCED OPERATIONS IN MAY
1982.
PUB. SER. CO. OF COLORADO
PAWNEE
2
NEW 500 MW (GROSS)
500 MW (ESC)
.35 XS
TRONA/DRY INJECTION
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***X
STATUS 6 STARTUP 0/90
PUBLIC SERVICE COMPANY OF COLORADO HAS PLANS FOR A NEW UNIT, PAWNEE 2, TO
BE LOCATED NEAR RUSH, COLORADO. THE 500 MW (GROSS) BABCOCK & WILCOX
BOILER WILL FIRE SUBBITUMINOUS COAL (8290 BTU/LB, .35X S). FABRIC FILTERS
WILL BE UTILIZED FOR PARTICULATE REMOVAL AND S02 EMISSIONS HILL BE CON-
TROLLED THROUGH INJECTION OF DRY TRONA. THE TRONA WILL BE PULVERIZED AND
BLOWN INTO THE DUCTWORK UPSTREAM OF THE BAGHOUSE FOR CONTACT WITH FLUE GAS
ON THE DUCT AND BAGHOUSE SURFACES. FLUE GAS WILL EXIT A 450 FOOT STACK.
INITIAL START UP IS SCHEDULED FOR 1990.
SALT RIVER PROJECT
CORONADO
1
NEW 400 MW (GROSS)
320 MW (ESC)
COAL
.55 XS SUBBITUMINOUS
LIMESTONE
M.W. KELLOGG
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 11/79
SALT RIVER PROJECT'S CORONADO 1 IS A DRY BOTTOM PULVERIZED SUBBITUMINOUS
COAL (0.55X S, 10,600 BTU/LB) FIRED BOILER LOCATED IN ST. JOHNS, ARIZONA.
M. W. KELLOGG SUPPLIED THE TWO LIMESTONE HORIZONTAL WEIR SPRAY TOWERS
WHICH REMOVE 82.5X OF THE S02 FROM THE FLUE GAS PASSED THROUGH THEM.
PARTICLE SCRUBBERS AND ESP'S ARE EMPLOYED FOR PARTICULATE REMOVAL AND VER-
TICAL HEIL MIST ELIMINATORS PRECEDE A 500 FT STACK. A MINIMUM OF 20X BY-
PASS PROVIDES REHEAT. THE WATER LOOP IS OPEN, AND THE UNSTABILIZED SLUDGE
IS DISPOSED OF IN AN UNLINED POND. START-UP WAS IN NOVEMBER 1979.
2-25
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SALT RIVER PROJECT
CORONADO
Z
NEW 400 MW (GROSS)
320 MW (ESC)
COAL
.55 7.5 SUBBITUMINOUS
LIMESTONE
M.W. KELLOGG
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 7/80
SALT RIVER PROJECT'S CORONADO 2 IS A DRY BOTTOM PULVERIZED SUBBITUMINOUS
COAL (0.55X S, 10,800 BTU/LB) FIRED BOILER LOCATED IN ST. JOHNS, ARIZONA.
M. W. KELLOGG SUPPLIED TWO LIMESTONE HORIZONTAL WEIR SPRAY TOWERS WHICH
REMOVE 82.5X OF THE S02 FROM THE FLUE GAS PASSED THROUGH THEM. PARTICLE
SCRUBBERS AND ESP'S ARE EMPLOYED FOR PARTICULATE REMOVAL AND VERTICAL HEIL
MIST ELIMINATORS PRECEDE A 500 FT STACK. A MINIMUM OF 20X BYPASS PROVIDES
REHEAT. THE WATER LOOP IS OPEN, AND THE UNSTABILIZED SLUDGE IS DISPOSED
OF IN AN UNLINED POND. START-UP WAS IN JULY 1980.
SALT RIVER PROJECT
CORONADO
3
NEW 400 MW (GROSS)
280 MW (ESC)
COAL
.60 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.ex
STATUS 6 STARTUP 0/92
CORONADO 3 IS A DRY BOTTOM PULVERIZED SUBBITUMINOUS COAL (.60X S, 8300 BTU
/LB) FIRED UNIT PLANNED BY SALT RIVER PROJECT TO BE LOCATED IN ST. JOHN'S,
ARIZONA. THE UTILITY IS PRESENTLY CONSIDERING THE INSTALLATION OF TWO HOR-
IZONTAL LIMESTONE SPRAY TOWERS FOR S02 CONTROL AND FABRIC FILTERS FOR PAR-
TICULATE REMOVAL. THE SYSTEM WILL HAVE A 20X BYPASS REHEAT, AN OPEN WATER
LOOP, A 200 FT STACK AND THE SLUDGE WILL BE PONDED. SCHEDULED OPERATIONS
ARE PLANNED TO BEGIN IN 1992.
SAN ANTONIO PUBLIC SERVICE
N/D
1
NEW 500 MW (GROSS)
500 MW (ESC)
LIGNITE
1.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****•/
STATUS 6 STARTUP 0/93
SAN ANTONIO PUBLIC SERVICE HAS PLANS FOR FOUR NEW UNITS (NAME AND LOCATION
UNDECIDED). THE LIGNITE (5600 BTU/LB, 1-2X S) FIRED UNITS WILL HAVE A
GROSS MEGAWATT RATING OF 500 EACH AND WILL UTILIZE A LIMESTONE FGD SYSTEM.
THE FOUR UNITS ARE SCHEDULED TO COMMENCE OPERATIONS IN 1993, 1995, 1999,
AND 2001 RESPECTIVELY. ND 2001 RESPECTIVELY.
SAN ANTONIO PUBLIC SERVICE
N/D
2
NEW 500 MW (GROSS)
500 MW (ESC)
LIGNITE
1.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «***X
STATUS 6 STARTUP 0/95
SAN ANTONIO PUBLIC SERVICE HAS PLANS FOR FOUR NEW UNITS (NAME AND LOCATION
UNDECIDED). THE LIGNITE (5600 BTU/LB, 1-2X S) FIRED UNITS WILL HAVE A
GROSS MEGAWATT RATING OF 500 EACH AND WILL UTILIZE A LIMESTONE FGD SYSTEM.
THE FOUR UNITS ARE SCHEDULED TO COMMENCE OPERATION IN 1993, 1995, 1999,
AND 2001 RESPECTIVELY.
SAN ANTONIO PUBLIC SERVICE
N/D
3
NEW 500 MW (GROSS)
500 MW (ESC)
LIGNITE
1.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/99
SAN ANTONIO PUBLIC SERVICE HAS PLANS FOR FOUR NEW UNITS (NAME AND LOCATION
UNDECIDED). THE LIGNITE (5600 BTU/LB, 1-2X S) FIRED UNITS WILL HAVE A
GROSS MEGAWATT RATING OF 500 EACH AND WILL UTILIZE A LIMESTONE FGD SYSTEM.
THE FOUR UNITS ARE SCHEDULED TO COMMENCE OPERATIONS IN 1993, 1995, 1999,
AND 2001 RESPECTIVELY.
SAN ANTONIO PUBLIC SERVICE
N/D
4
NEW 500 MW (GROSS)
500 MW (ESC)
LIGNITE
1.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 99/99
SAN ANTONIO PUBLIC SERVICE HAS PLANS FOR FOUR NEW UNITS (NAME AND LOCATION
UNDECIDED). THE LIGNITE (5600 BTU/LB, 1-2X S) FIRED UNITS WILL HAVE A
GROSS MEGAWATT RATING OF 500 EACH AND WILL UTILIZE A LIMESTONE FGD SYSTEM.
THE FOUR UNITS ARE SCHEDULED TO COMMENCE OPERATIONS IN 1993, 1995, 1999,
AND 2001 RESPECTIVELY.
2-26
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SAN MIGUEL ELECTRIC
SAN MIGUEL
1
NEW 400 MW (GROSS)
400 MM (ESC)
COAL
3.39 XS LIGNITE
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: 5.OX
STATUS 1 STARTUP 8/81
SAN MIGUEL 1 OF THE SAN MIGUEL ELECTRIC COOP IS A LIGNITE (2.39X S, 5000
BTU/LB) FIRED RADIANT BOILER LOCATED IN SAN MIGUEL, TEXAS. THE
EMISSION CONTROL SYSTEM ON THIS UNIT CONSISTS OF A COLD SIDE ESP FOL-
LOWED BY FOUR BABCOCK AND WILCOX 86X EFFICIENT LIMESTONE TRAY TOWERS.
CHEVRON MIST ELIMINATORS PRECEDE AN IN-LINE REHEATER AND A 450 FT ACID
BRICK LINED STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.
WASTE SLUURY IS DEWATERED, MIXED WITH FLYASH AND DISPOSED OF IN AN OFF-
SITE LANDFILL. OPERATIONS COMMENCED IN AUGUST 1981.
SEMINOLE ELECTRIC
SEMINOLE
1
NEW 620 MW (GROSS)
620 MW (ESC)
COAL
2.75 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 5/83
SEMINOLE 1 OF SEMINOLE ELECTRIC IS A PULVERIZED COAL (2.75X S, 11,700
BTU/LB) UNIT LOCATED IN PALATKA, FLORIDA. THE EMISSION CONTROL SYSTEM
CONSISTS OF RESEARCH-COTTRELL ESP'S WITH 99.6X REMOVAL EFFICIENCY AND A
PEABODY PROCESS LIMESTONE FGD SYSTEM DESIGNED TO REMOVE 86X OF THE S02.
AN ADDITIONAL 4X S02 REMOVAL IS ACHIEVED THROUGH COAL WASHING. THE
CLEANED FLUE GAS EXITS THROUGH A 675 FOOT ACID BRICK LINED STACK AND
SLUDGE DISPOSAL IS HANDLED VIA THE POZ-0-TEC CONVERSION SYSTEM. START-
UP COMMENCED IN MAY 1983.
SEMINOLE ELECTRIC
SEMINOLE
2
NEW 620 MM (GROSS)
620 MW (ESC)
COAL
2.75 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 9/84
SEMINOLE 2 OF SEMINOLE ELECTRIC IS A PULVERIZED COAL (2.75X S, 11,700
BTU/LB) UNIT LOCATED IN PALATKA, FLORIDA. THE EMISSION CONTROL SYSTEM
CONSISTS OF RESEARCH-COTTRELL ESP'S WITH 99.6X REMOVAL EFFICIENCY AND A
PEABODY PROCESS LIMESTONE FGD SYSTEM DESIGNED TO REMOVE 86X OF THE S02.
AN ADDITIONAL 4X SOa REMOVAL IS ACHIEVED THROUGH COAL WASHING. THE
CLEANED FLUE GAS EXITS THROUGH A 675 FOOT ACID BRICK LINED STACK AND
SLUDGE DISPOSAL IS HANDLED VIA THE POZ-0-TEC CONVERSION SYSTEM. START-
UP COMMENCED IN SEPTEMBER 1984.
SEMINOLE ELECTRIC
TAYLOR
1
NEW 620 MW (GROSS)
620 MM (ESC)
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 99/99
SEMINOLE ELECTRIC HAS PLANS TO CONSTRUCT A 620 MW (GROSS) UNIT, TAYLOR 1,
TO BE LOCATED IN PERRY, FLORIDA. THE UTILITY IS PRESENTLY CONSID-
ERING ONLY FGD SYSTEMS AS THE CONTROL STRATEGY. START-UP HAS BEEN
DEFERRED INDEFINITELY.
SEMINOLE ELECTRIC
TAYLOR
2
NEW 620 MW (GROSS)
620 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 99/99
SEMINOLE ELECTRIC HAS PLANS TO CONSTRUCT A 620 MW (GROSS) UNIT, TAYLOR 2,
TO BE LOCATED IN PERRY, FLORIDA. THE UTILITY IS PRESENTLY CONSID-
ERING ONLY FGD SYSTEMS AS THE CONTROL STRATEGY. START-UP HAS BEEN
DEFERRED INDEFINITELY.
SIERRA PACIFIC POWER
THOUSAND SPRINGS
1
NEW 500 MW (GROSS)
500 MM (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/90
SIERRA PACIFIC POWER HAS PLANS FOR THREE NEW UNITS, THOUSAND SPRINGS 1,2
AND 3 TO BE LOCATED IN WELLS, NEVADA. THE UNITS WILL HAVE A GROSS MEGAWATT
RATING OF 500 EACH AND WILL UTILIZE AN FGD SYSTEM FOR CONTROL OF S02
EMISSIONS. UNITS 1,2 AND 3 ARE SCHEDULED TO START UP IN 1990, 1995 AND
1999 RESPECTIVELY.
2-27
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SIERRA PACIFIC POWER
THOUSAND SPRINGS
2
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/95
SIERRA PACIFIC POWER HAS PLANS FOR THREE NEW UNITS, THOUSAND SPRINGS 1,2
AND 3 TO BE LOCATED IN WELLS, NEVADA. THE UNITS MILL HAVE A GROSS MEGAWATT
RATING OF 500 EACH AND WILL UTILIZE AN FGD SYSTEM FOR CONTROL OF S02
EMISSIONS. UNITS 1,2 AND 3 ARE SCHEDULED TO START UP IN 1990, 1995 AND
1999 RESPECTIVELY.
SIERRA PACIFIC POWER
THOUSAND SPRINGS
3
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *»**X
STATUS 6 STARTUP 0/99
SIERRA PACIFIC POWER HAS PLANS FOR THREE NEW UNITS, THOUSAND SPRINGS 1,2
AND 3 TO BE LOCATED IN WELLS, NEVADA. THE UNITS WILL HAVE A GROSS MEGAWATT
RATING OF 500 EACH AND WILL UTILIZE AN FGO SYSTEM FOR CONTROL OF S02
EMISSIONS. UNITS 1,2 AND 3 ARE SCHEDULED TO START UP IN 1990, 1995 AND
1999 RESPECTIVELY.
SIERRA PACIFIC POWER
VALMY
2
NEW 276 MW (GROSS)
276 MW (ESC)
COAL
.50 XS
LIME/SPRAY DRYING
ROCKWELL INTERNATIONAL
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 6/85
SIERRA PACIFIC POWER IS CONSTRUCTING A 276 MW UNIT LOCATED IN VALMY,
NEVADA. THE FOSTER WHEELER PULVERIZED COAL (.5X S) FIRED BOILER AT THE
VALMY 2 STATION WILL UTILIZE A LIME/SPRAY DRYING FGD SYSTEM SUPPLIED BY
ROCKWELL INTERNATIONAL. A FABRIC FILTER WILL CONTROL PARTICLE EMISSIONS
AND FLUE GAS WILL EXIT A 500 FT STACK. THE UNIT IS SCHEDULED TO COMMENCE
OPERATIONS IN JUNE 1985.
SIKESTON BRD OF MUNICIPAL UTIL
SIKESTON
1
NEW 235 MW (GROSS)
235 MW (ESC)
COAL
2.80 XS BITUMINOUS
LIMESTONE
BABCOCK 4 WILCOX
ENERGY CONSUMPTION: 1.7X
STATUS 1 STARTUP 6/81
THE SIKESTON BOARD OF MUNICIPAL UTILITIES' SIKESTON 1 IS A PULVERIZED COAL
(2.8X S, 11,340 BTU/LB) FIRED BOILER LOCATED IN SIKESTON, MISSOURI.
BABCOCK AND WILCOX SUPPLIED THE EMISSION CONTROL SYSTEM CONSIST-
ING OF TWO ESP'S AND THREE SOX CAPACITY LIMESTONE VENTURI FGD MODULES. THE
CLEANED GAS PASSES THROUGH CHEVRON MIST ELIMINATORS BEFORE EXITING A
450 FOOT FRP LINED FLUE (A SECOND CARBON STEEL LINED FLUE, USED FOR EMER-
GENCY BYPASS, IS ALSO IN THE STACK). THE WATER LOOP MODE IS OPEN, AND THE
SLUDGE IS PONDED. THE SYSTEM STARTED OPERATIONS IN JUNE 1981.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
1
NEW 450 MW (GROSS)
450 MW (ESC)
COAL
1.60 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 5/91
SOUTH CAROLINA PUBLIC SERVICE HAS PLANS TO CONSTRUCT A NEW UNIT,
CROSS 1 TO BE LOCATED IN CROSS, SOUTH CAROLINA. THE 450 MW
BOILER WILL FIRE COAL (1.8X S, 11,200 BTU/LB). THE UTILITY HAS SIGNED A
CONTRACT WITH PEABODY PROCESS SYSTEMS FOR THE INSTALLATION OF A WET LIME-
STONE SCRUBBING SYSTEM TO CONTROL S02 EMISSIONS. A COLD SIDE ESP WILL
CONTROL PARTICLE EMISSIONS AND THE CLEANED FLUE GAS WILL EXIT A 600 FOOT
STACK. THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP MODE. UNIT 1 IS
SCHEDULED TO COMMENCE OPERATIONS IN MAY 1991.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
2
NEW 450 MW (GROSS)
450 MW (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 10/83
SOUTH CAROLINA PUBLIC SERVICE HAS ANNOUNCED THE INITIAL START-UP OF
CROSS 2, LOCATED IN CROSS, SOUTH CAROLINA. THE 450 MW BOILER FIRES
1.8X S, 11,200 BTU/LB COAL. A WET LIMESTONE SCRUBBING SYSTEM SUPPLIED
BY PEABODY PROCESS SYSTEMS CONTROLS S02 EMISSIONS AND PARTICULATE MATTER
IS CONTROLLED VIA A COLD SIDE ESP. THE CLEANED FLUE GAS EXITS A 600 FT
STACK AND THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE. INITIAL
START-UP COMMENCED IN OCTOBER 1983.
2-28
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UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
Z
NEW 280 MM (GROSS)
140 MM (ESC)
COAL
1.00 XS BITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: 1.1X
STATUS 1 STARTUP 7/77
WINYAH Z OF SOUTH CAROLINA PUBLIC SERVICE IS A PULVERIZED BITUMINOUS COAL
(l.OOX S, 11,500 BTU/LB) FIRED UNIT LOCATED IN GEORGETOWN, SOUTH CAROLINA.
A COLD SIDE ESP AND A BABCOCK AND WILCOX VENTURI SCRUBBER/LIMESTONE TRAY
TOWER ABSORBER TRAIN DESIGNED TO REMOVE 45X OF THE S02 FROM THE BOILER
FLUE GAS (BOX GAS BYPASSES SCRUBBER) MAKE UP THE EMISSION CONTROL SYSTEM
ON THIS UNIT. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, THE SLUDGE
IS DISPOSED IN AN UNLINED POND AND FLUE GAS EXITS A 400 FT STACK. OPERA-
TIONS COMMENCED IN JULY 1977.
SOUTH CAROLINA PUBLIC SERVICE WINYAH 3 OF SOUTH CAROLINA PUBLIC SERVICE IS A DRY BOTTOM BOILER WHICH
WINYAH
3
NEW 280 MM (GROSS)
280 MM (ESC)
COAL
1.00 XS BITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: 2.IX
STATUS 1 STARTUP 7/80
FIRES l.OX SULFUR COAL (11,500 BTU/LB) AND IS LOCATED IN GEORGETOWN,
SOUTH CAROLINA. AN ESP PRECEDES A BABCOCK AND WILCOX LIMESTONE FGD
SYSTEM AND AN INDIRECT STEAM REHEATER. THE SYSTEM OPERATES IN A CLOSED
WATER LOOP MODE AND FLUE GAS EXITS A 400 FT STACK. OPERATIONS COMMENCED
IN MAY 1980.
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
4
NEW 280 MM (GROSS)
280 MW (ESC)
COAL
1.70 XS BITUMINOUS
LIMESTONE
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 2.IX
STATUS 1 STARTUP 7/81
SOUTH CAROLINA PUBLIC SERVICE'S WINYAH 4 IS A BITUMINOUS COAL (1.70X S,
11,500 BTU/LB) FIRED UNIT LOCATED IN GEORGETOWN, SOUTH CAROLINA.
TWO AMERICAN AIR FILTER LIMESTONE SLURRY SPRAY TOWERS FOLLOW AN ESP.
THE TEMPERATURE OF THE CLEANED GAS IS RAISED BY AN INDIRECT STEAM
REHEATER. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE. INITIAL
OPERATIONS COMMENCED IN JULY 1981.
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR.
1
NEW 200 MW (GROSS)
124 MW (ESC)
COAL
1.64 XS BITUMINOUS
LIMESTONE
ENVIRONEERIHG, RILEY STOKER
ENERGY CONSUMPTION: 2.5X
STATUS 1 STARTUP 8/78
R.D. MORROW 1 OF SOUTHERN MISSISSIPPI ELEC. IS A PULVERIZED COAL (1.64X
S, 12,250 BTU/LB) FIRED UNIT IN PURVIS, MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-ROD ABSORBER SUPPLIED BY RILEY STOKER/ENVIRONEERING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT IS
JOINED BY A 36X BYPASS REHEAT BEFORE IT IS DISCHARGED THROUGH A 400 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUDGE IS
HAULED BY TRUCK TO AN OFF-SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE AUGUST 1978.
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR.
2
NEW 200 MM (GROSS)
124 MW (ESC)
COAL
1.64 XS BITUMINOUS
LIMESTONE
ENVIRONEERING, RILEY STOKER
ENERGY CONSUMPTION: 2.5X
STATUS 1 STARTUP 6/79
R.D. MORROW 2 OF SOUTHERN MISSISSIPPI ELEC. IS A PULVERIZED COAL (1.64X
S, 12,250 BTU/LB) FIRED UNIT IN PURVIS, MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-ROD ABSORBER SUPPLIED BY RILEY STOKER/ENVIRONEERING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT IS
JOINED BY A 38X BYPASS REHEAT BEFORE IT IS DISCHARGED THROUGH A 400 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUDGE IS
HAULED BY TRUCK TO AN OFF-SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE 1979.
SOUTHERN ILLINOIS POWER
MARION
4
NEW 184 MW (GROSS)
184 MW (ESC)
COAL/REFUS
3.75 XS BITUMINOUS
LIMESTONE
BABCOCK t WILCOX
ENERGY CONSUMPTION: 2.2X
STATUS 1 STARTUP 4/79
UNIT 4 AT SOUTHERN ILLINOIS POWER COOP'S MARION STATION IN MARION, ILLI-
NOIS IS A CYCLONE FIRED COAL (3.75X S, 11000 BTU/LB) UNIT WHICH IS SERVED
BY A 89.4X EFFICIENT (DESIGN) LIMESTONE FGD SYSTEM SUPPLIED BY BABCOCK AMD
WILCOX. TWO SPRAY TOWERS AND A 400 FT BRICK LINED STACK ARE DOWNSTREAM OF
AN ESP IN THIS SYSTEM. THE WATER LOOP IS CLOSED, AND THE FLYASH STABIL-
IZED SLUDGE IS DEWATERED AND LANDFILLED. THE SYSTEM BECAME OPERATIONAL
DURING APRIL 1979.
2-29
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UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTHERN INDIANA GAS & ELEC
A.B. BROWN
1
NEW 265 MW (GROSS)
265 MW (ESC)
COAL
3.35 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: .ex
STATUS 1 STARTUP 3/79
SOUTHERN INDIANA GAS AND ELECTRIC'S A.B.BROWN 1 IS A DRY BOTTOM PULVERIZED
COAL (3.35X S, 11,100 BTU/LB) FIRED UNIT IN WEST FRANKLIN, INDIANA. FMC
SUPPLIED A DUAL ALKALI FGD SYSTEM DESIGNED TO REMOVE 85X OF THE FLUE GAS
S02. THE UNIT CONSISTS OF TWO THREE STAGE DISC CONTACTORS. A COLD SIDE ESP
PROVIDES PRIMARY PARTICULATE CONTROL, AND ONE CHEVRON MIST ELIMINATOR/MOD-
ULE PRECEDES A 498 FOOT ACID BRICK LINED STACK. THE SYSTEM PRODUCES A
FILTER CAKE WASTE PRODUCT WHICH IS DISPOSED IN AN ON-SITE LANDFILL. THE
WATER LOOP CAN BE EITHER OPEN OR CLOSED. THE SYSTEM HAS BEEN OPERATIONAL
SINCE MARCH 1979.
SOUTHERN INDIANA GAS t ELEC
A.B. BROWN
2
NEW 265 MW (GROSS)
265 MW (ESC)
COAL
3.35 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: .ex
STATUS 2 STARTUP 1/85
SOUTHERN INDIANA GAS AND ELECTRIC HAS A NEW UNIT, A.B. BROWN 2, UNTDER CON-
STRUCTION IN WEST FRANKLIN, INDIANA. THE 265-MW (GROSS) UNIT SUPPLIED BY
BABCOCK & WILCOX WILL FIRE BITUMINOUS COAL (3.35X S, 11,100 BTU/LB). A
COLD SIDE ESP WILL PROVIDE PRIMARY PARTICULATE MATTER CONTROL AND A DUAL
ALKALI FGD SYSTEM WITH A S02 REMOVAL EFFICIENCY OF 90X WILL BE SUPPLIED BY
FMC TO CONTROL EMISSIONS. THE FLUE GAS WILL EXIT THROUGH A 498-FOOT
STACK. THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP MODE AND THE SLUDGE
WILL BE DISPOSED IN AN ON-SITE LANDFILL. OPERATIONS ARE SCHEDULED TO COM-
MENCE IN JANUARY 1985.
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS
1
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: *#**X
STATUS 2 STARTUP 12/85
DOLET HILLS 1 OF SOUTHWESTERN ELECTRIC POWER IS A 720 MW LIGNITE (0.7X S,
7100 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN MANSFIELD, LOUISIANA.
THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP FOR PARTICULATE CONTROL
AND A WET LIMESTONE FGD SYSTEM FOR S02 CONTROL. THE FLUE GAS WILL EXIT
THROUGH A 525 FOOT STACK AND THE SYSTEM WILL OPERRATE IN A CLOSED WATER
LOOP MODE. INITIAL START-UP IS SCHEDULED FOR DECEMBER 1985 AND
COMMERCIAL OPERATIONS ARE SCHEDULED FOR MARCH 1986.
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY
1
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
.80 XS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: »***X
STATUS 2 STARTUP 12/64
HENRY W. PIRKEY 1 OF SOUTHWESTERN ELECTRIC POWER IS A WET BOTTOM LIGNITE
(0.8X S, 6300 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN HALLSVILLE, TEXAS.
A CONTRACT WAS AWARDED TO THE AIR CORRECTION DIVISION OF UOP FOR FOUR
LIMESTONE SPRAY TOWERS (99+X EFFICIENCY) AND PARTICULATE WILL BE CON-
TROLLED WITH ESP'S. MIST ELIMINATION WILL BE PROVIDED BY TWO STAGE CHEV-
RONS AND THE 525 FT STACK WILL BE ACID BRICK LINED. NO REHEAT IS PLANNED.
THE WATER LOOP WILL BE CLOSED AND THE SLUDGE WILL BE POZ-0-TEC FIXATED.
START-UP IS EXPECTED BY DECEMBER 1984.
SOUTHWESTERN ELECTRIC POWER
WALKER CO.
1
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
1.49 XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 12/93
WALKER COUNTY 1 OF SOUTHWESTERN ELECTRIC POWER IS A PLANNED 720 MW (GROSS)
LIGNITE (1.49X S) FIRED BOILER TO BE LOCATED IN HUNTSVILLE, TEXAS. THE
UTILITY IS PRESENTLY CONSIDERING BOTH WET LIMESTONE AND DRY SCRUBBING AS
THE POSSIBLE EMISSION CONTROL STRATEGY WITH A DESIGN S02 REMOVAL EFFICIENC
OF 90X. COMMERCIAL START-UP IS SCHEDULED FOR DECEMBER 1993.
SOUTHWESTERN ELECTRIC POWER
WALKER CO.
2
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
1.49 XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION-' *»*«X
STATUS 6 STARTUP 12/93
WALKER COUNTY 2 OF SOUTHWESTERN ELECTRIC POWER IS A PLANNED 720 MW (GROSS)
LIGNITE (1.49X S) FIRED BOILER TO BE LOCATED IN HUNTSVILLE, TEXAS. THE
UTILITY IS PRESENTLY CONSIDERING BOTH WET LIMESTONE AND DRY SCRUBBING AS
THE POSSIBLE EMISSION CONTROL STRATEGY WITH A DESIGN S02 REMOVAL EFFICIENC
OF 90X. COMMERCIAL START-UP IS SCHEDULED FOR DECEMBER 1993.
2-30
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UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTHWESTERN PUBLIC SERVICE
SOUTH PLAINS
1
NEW 572 MM (GROSS)
572 MW (ESC)
COAL
***»* XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *««*X
STATUS 6 STARTUP 0/90
SOUTHWESTERN PUBLIC SERVICE HAS PLANS FOR A 572 MW (GROSS) UNIT, SOUTH
PLAINS 1 TO BE LOCATED NEAR IDALOO TEXAS IN LUBOCK COUNTY. THE UNIT WILL
BURN LOW SULFUR WESTERN COAL AND WILL UTILIZE AN FGD SYSTEM FOR CONTROL OF
S02 EMISSIONS. INITIAL START-UP IS SCHEDULED FOR 1990.
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
NEW 194 MW (GROSS)
194 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 4.6X
STATUS 1 STARTUP 4/77
SPRINGFIELD CITY UTILITIES' SOUTHWEST 1 IS A PULVERIZED BITUMINOUS COAL
(3.5X S, 11,000 BTU/LB) FIRED BOILER LOCATED IN SPRINGFIELD, MISSOURI. THE
EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A COLD SIDE ESP FOLLOWED
BY TWO UOP LIMESTONE TCA MODULES WHICH WERE DESIGNED TO REMOVE BOX OF THE
FLUE GAS S02. ONE CHEVRON/MODULE LEADS TO A 385 FOOT CEILCOTE LINED STACK.
THE DRY FLYASH STABILIZED SLUDGE IS DEWATERED BY A ROTARY DRUM VACUUM FIL-
TER AND TRUCKED TO A LANDFILL. THE SYSTEM OPERATES IN A CLOSED WATER LOOP
MODE. OPERATIONS COMMENCED IN APRIL 1977.
SPRINGFIELD WATER, LIGHT t PUR
DALLMAN
3
NEW 205 MW (GROSS)
205 MW (ESC)
COAL 1 ISO
3.05 xs BITUMINOUS; BITUMINO
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.9X
STATUS 1 STARTUP 10/80
DALLMAN 3 OF SPRINGFIELD WATER, LIGHT, AND POWER IS A PULVERIZED COAL
(3.05X S, 11,369 BTU/LB) FIRED BOILER LOCATED IN SPRINGFIELD, ILLINOIS.
RESEARCH COTTRELL SUPPLIED A LIMESTONE FGD SYSTEM DESIGNED TO REMOVE
95X OF THE S02 FROM 650,000 ACFM OF BOILER FLUE GAS. A HOT SIDE ESP
PRECEDES TWO PACKED TOWER ABSORBERS, ONE HORIZONTAL CHEVRON PER MODULE,
AND A 500 FOOT ACID BRICK LINED STACK. NO REHEAT IS PROVIDED. THE SYS-
TEM OPERATES IN A CLOSED WATER LOOP MODE AND SLUDGE IS DISPOSED OF IN A
LANDFILL. FGD OPERATIONS COMMENCED IN OCTOBER 1980.
SUNFLOWER ELECTRIC
HOLCOMB
1
NEW 347 MW (GROSS)
347 MU (ESC)
COAL
.34 XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: .OX
STATUS 1 STARTUP 7/83
SUNFLOWER ELECTRIC COOP'S HOLCOMB 1 STATION IS A 347 MW UNIT LOCATED IN
HOLCOMB, KANSAS. THE PULVERIZED COAL (0.47X S, 8065 BTU/LB) FIRED BAB-
COCK AND WILCOX BOILER UTILIZES A JOY MANUFACTURING/NIRO ATOMIZER LIME/
SPRAY DRYING PROCESS FOR S02 CONTROL. A FABRIC FILTER IS UTILIZED FOR
PRIMARY PARTICULATE CONTROL AND THE FLUE GAS EXITS A 475 FT STACK.
INITIAL START-UP OF THE FGD SYSTEM COMMENCED IN JULY 1983.
TAMPA ELECTRIC
BIG BEND
4
NEW 458 MW (GROSS)
458 MW (ESC)
COAL
3.50 XS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 3.5X
STATUS 2 STARTUP 1/85
UNIT 4 AT TAMPA ELECTRIC'S BIG BEND STATION, LOCATED IN TAMPA, FLORIDA,
IS A DRY BOTTOM PULVERIZED COAL (3.50X S, 10,495 BTU/LB) FIRED UNIT.
RESEARCH-COTTRELL WILL SUPPLY A LIMESTONE SCRUBBING PROCESS. A COLD SIDE
ESP AND MECHANICAL COLLECTORS MILL PROVIDE PARTICULATE CONTROL. THE FGD
SYSTEM, PRESENTLY UNDER CONSTRUCTION, WILL REMOVE 90X OF THE FLUE GAS S02,
AND WILL INCLUDE AN INDIRECT HOT AIR REHEATER LEADING TO A 490 FOOT CON-
CRETE LINED STACK. THE SYSTEM WILL OPERATE IN AN OPEN WATER LOOP MODE
AND WILL PRODUCE GYPSUM AS A SALEABLE PRODUCT. INITIAL START-UP IS
SCHEDULED FOR JANUARY 1985.
TENNESSEE VALLEY AUTHORITY
PARADISE
1
RETROFIT 704 MW (GROSS)
704 MW (ESC)
COAL
3.20 XS BITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 2.6X
STATUS 1 STARTUP 5/83
PARADISE 1 OF TVA IS A 3.2X SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT WAS AWARDED TO GEESI FOR AN 84.2X EFFICIENT LIMESTONE
FGD SYSTEM TO BE RETROFITTED ON THIS BOILER. THE FGD SYSTEM CONSISTS OF
SIX VENTURI SCRUBBERS AND VENTURI ABSORBER TRAINS PRECEDED BY AN ESP.
INLET FLUE GAS IS USED TO HEAT GLYCOL, WHICH IN TURN IS USED TO REHEAT
THE OUTLET FLUE GAS. UNTREATED SLUDGE IS PUMPED DIRECTLY TO A POND FOR
DISPOSAL. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND FLUE GAS
EXITS A 600 FT STACK. OPERATIONS COMMENCED IN MAY 1983.
2-31
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UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION Z
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TENNESSEE VALLEY AUTHORITY
PARADISE
Z
RETROFIT 70* MW (GROSS)
704 MW (ESC)
COAL
3.20 XS BITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 2.6X
STATUS 1 STARTUP 7/83
PARADISE 2 OF TVA IS A 3.2X S COAL FIRED LOCATED UNIT IN PARADISE,
KENTUCKY. A CONTRACT WAS AWARDED TO GEESI FOR AN 8*.Z'/. EFFICIENT
LIMESTONE FGD SYSTEM RETROFITTED ON THIS BOILER. SIX VENTURI SCRUB-
BERS AND VENTURI ABSORBER TRAINS FOLLOW AN ESP. INLET FLUE GAS IS
USED TO HEAT GLYCOL, WHICH IN TURN IS USED TO REHEAT THE OUTLET
FLUE GAS. UNTREATED SLUDGE IS PUMPED DIRECTLY TO A POND FOR DISPOSAL. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND FLUE GAS EXITS A 600 FOOT
STACK. OPERATIONS COMMENCED IN JULY 1983.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
7
RETROFIT 575 MW (GROSS)
575 MW (ESC)
COAL
3.70 XS BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 3/81
WIDOWS CREEK 7 IS A PULVERIZED BITUMINOUS COAL (3.7X S, 11,100 BTU/LB)
FIRED BOILER OF TVA LOCATED IN BRIDGEPORT, ALABAMA. COMBUSTION ENGINEERING
SUPPLIED A LIMESTONE VENTRI ROD SCRUBBER/SPRAY TOWER ABSORBER FGD SYSTEM
ON THIS UNIT. AN ESP PRECEDES THE SCRUBBING TRAIN, AND A COMBINATION OF
A BULK ENTRAINMENT SEPERATOR, TWO CHEVRON MIST ELIMINATORS AND A FINNED
TUBE REHEATER FOLLOW THE SYSTEM. A FORCED OXIDATION SYSTEM IS EMPLOYED
FOR SLUDGE TREATMENT. OPERATIONS COMMENCED IN MARCH 1981.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
RETROFIT 550 MW (GROSS)
550 MW (ESC)
COAL
3.30 XS BITUMINOUS
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION: 4.7X
STATUS 1 STARTUP 5/77
WIDOWS CREEK 8 OF TVA IS A BALANCED DRAFT, TANGENTIALLY FIRED COAL (3.30X
S, 11,810 BTU/LB) BOILER IN STEVENSON, ALABAMA. TVA RETROFITTED THIS UNIT
WITH A LIMESTONE FGD SYSTEM (SOX DESIGN S02 REMOVAL EFFICIENCY) WHICH BE-
GAN OPERATIONS IN MAY 1977. AN ESP PRECEDES FOUR VARIABLE THROAT VENTURI
SCRUBBER/MULTIGRID TOWER ABSORBER TRAINS (ONE OF THE TOWERS IS PACKED).
ONE VERTICAL CHEVRON/TRAIN AND AN INDIRECT HOT AIR REHEATER ARE INCLUDED
IN THE SYSTEM. THE SYSTEM OPERATES IN A CLOSED WATER LOOP AND FLUE GAS
EXITS A 500 FT STACK. A FORCED OXIDATION SYSTEM IS EMPLOYED FOR SLUDGE
TREATMENT.
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK
1
NEW 443 MW (GROSS)
400 MW (ESC)
COAL
1.06 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 1 STARTUP 11/82
GIBBONS CREEK 1 OF THE TEXAS MUNICIPAL POWER AGENCY IS A DRY BOTTOM PUL-
VERIZED LIGNITE (1.06X S, 4860 BTU/LB) FIRED UNIT LOCATED IN
CARLOS, TEXAS. THE EMISSION CONTROL SYSTEM CONSISTS OF A COLD SIDE ESP
FOLLOWED BY THREE SOX CAPACITY LIMESTONE SPRAY TOWERS. THE COMBUSTION EN-
GINEERING FGD SYSTEM INCLUDES A CHEVRON MIST ELIMINATOR AND A STEAM COIL
REHEATER. CLEANED FLUE GAS IS DISCHARGED THROUGH A 465 FT ACID BRICK
LINED STACK. THE WATER LOOP IS OPEN AND THE POZ-0-TTEC STABILIZED SLUDGE
IS USED AS STRIP MINE LANDFILL. OPERATIONS COMMENCED IN NOVEMBER
1982.
TEXAS POWER & LIGHT
SANDOW
4
NEW 545 MW (GROSS)
382 MW (ESC)
COAL
1.60 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 12/80
SANDOW 4 IS A PULVERIZED 1.6X SULFUR LIGNITE FIRED BOIL'R OF TEXAS POWER
AND LIGHT LOCATED IN ROCKDALE, TEXAS. COMBUSTION ENGINEERING SUPPLIED
THREE LIMESTONE SPRAY TOWERS FOR THIS UNIT. A COLD SIDE ESP PROVIDES
PRIMARY PARTICULATE CONTROL. A 30X BYPASS IS EMPLOYED TO PROVIDE REHEAT,
AND THE OVERALL S02 REMOVAL EFFICIENCY IS 75X. THE SYSTEM OPERATES IN A
CLOSED WATER LOOP, AND THE SLUDGE IS PONDED. OPERATIONS COMMENCED IN
DECEMBER 1980.
TEXAS POWER & LIGHT
TWIN OAKS
1
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: **#*X
STATUS 3 STARTUP 8/89
TWIN OAKS 1 IS A 750 MW (GROSS) LIGNITE (.7X S) FIRED BOILER PLANNED BY
TEXAS POWER AND LIGHT AND ALCOA FOR LOCATION IN BREMOND, TEXAS. A CON-
TRACT HAS BEEN AWARDED TO GE ENVIRONMENTAL SERVICES FOR A LIMESTONE FGD
SYSTEM WITH A DESIGN S02 REMOVAL EFFICIENCY OF 70X. ESP'S WILL CONTROL
PARTICULATE MATTER AND THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP
MODE. START-UP IS SCHEDULED FOR AUGUST 1989.
2-32
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UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS POWER & LIGHT
TWIN OAKS
Z
NEW 750 MM (GROSS)
750 MW (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: «*««x
STATUS 3 STARTUP 8/91
TWIN OAKS 1 IS A 750 MW (GROSS) LIGNITE (.7X S) FIRED BOILER PLANNED BY
TEXAS POWER AND LIGHT AND ALCOA FOR LOCATION IN BREMOND, TEXAS. A CON-
TRACT HAS BEEN AWARDED TO GE ENVIRONMENTAL SERVICES FOR A LIMESTONE FGD
SYSTEM WITH A DESIGN S02 REMOVAL EFFICIENCY OF 70X. ESP'S WILL CONTROL
PARTICULATE MATTER AND THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP
MODE. START-UP IS SCHEDULED FOR AUGUST 1991.
TEXAS UTILITIES
FOREST GROVE
1
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
.80 XS LIGNITE
LIMESTONE
WHEELABRATOR AIR POLTN. CNTRL.
ENERGY CONSUMPTION: «*««X
STATUS 3 STARTUP 0/88
TEXAS UTILITIES IS PLANNING A LIGNITE (0.8X S, 7000 BTU/LB) FIRED BOILER,
FOREST GROVE 1, WHICH WILL BE LOCATED IN ATHENS, TEXAS. A CONTRACT HAS
BEEN AWARDED TO WHEELABRATOR AIR POLLUTION CONTROL FOR A WET LIMESTONE FGD
SYSTEM AT THIS UNIT. TWO ESP'S WILL PROVIDE PRIMARY PARTICULATE CONTROL
AND NO STACK GAS REHEAT IS PLANNED. START-UP IS SCHEDULED FOR 1988.
TEXAS UTILITIES
MARTIN LAKE
1
NEW 793 MW (GROSS)
595 MW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 4/77
TEXAS UTILITIES' MARTIN LAKE 1 IS A LIGNITE (0.9X S, 7380 BTU/LB) FIRED
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGD SYSTEM CONSISTS OF SIX PACKED SPRAY
TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02 REMOVAL EFFICI-
ENCY IS 70.5X. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND FLUE GAS EXITS A 450
FT STACK. INITIAL OPERATIONS COMMENCED IN APRIL 1977.
TEXAS UTILITIES
MARTIN LAKE
Z
NEW 793 MW (GROSS)
595 MW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION
STATUS 1
1.3X
STARTUP 5/78
TEXAS UTILITIES' MARTIN LAKE 2 IS A LIGNITE (0.9X S, 7380 BTU/LB) FIRED
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGD SYSTEM CONSISTS OF SIX PACKED SPRAY
TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02 REMOVAL EFFICI-
ENCY IS 70.5X. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND FLUE GAS EXITS A 450
FT STACK. INITIAL OPERATIONS COMMENCED IN MAY 1978.
TEXAS UTILITIES
MARTIN LAKE
3
NEW 793 MW (GROSS)
595 MW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:
STATUS 1
1.3X
STARTUP 2/79
TEXAS UTILITIES' MARTIN LAKE 3 IS A LIGNITE (0.9X S, 7380 BTU/LB) FIRED
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGD SYSTEM CONSISTS OF SIX PACKED SPRAY
TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02 REMOVAL EFFICI-
ENCY IS 70.5X. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE AND FLUE GAS EXITS A 450
FT STACK. INITIAL OPERATIONS COMMENCED IN FEBRUARY 1979.
TEXAS UTILITIES
MARTIN LAKE
4
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: «***X
STATUS 3 STARTUP 0/89
MARTIN LAKE 4 OF TEXAS UTILITIES IS A LIGNITE (0.9X S, 7380 BTU/LB) FIRED
BOILER UNDER CONSTRUCTION IN TATUM, TEXAS. A CONTRACT FOR A LIMESTONE FGD
SYSTEM FOR THIS UNIT HAS BEEN AWARDED TO RESEARCH COTTRELL. ESP'S WILL BE
EMPLOYED FOR PARTICULATE CONTROL. FGD START-UP IS EXPECTED IN
1989.
2-33
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS UTILITIES
MONTICELLO
3
NEW 800 MW (GROSS)
800 MW (ESC)
COAL
.50 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 5/78
MONTICELLO 3 OF TEXAS UTILITIES IS A LIGNITE ( .5X S, 7000 BTU/LB) FIRED
UNIT IN MT. PLEASANT, TEXAS. THIS UNIT'S EMISSION CONTROL SYSTEM CONSISTS
OF TWO COLD SIDE ESP'S FOLLOWED BY THREE GEESI LIMESTONE SPRAY TOWERS
(74X DESIGN S02 REMOVAL EFFICIENCY), ONE HORIZONTAL CHEVRON MIST ELIMINA-
TOR/MODULE, AND AN INDIRECT HOT AIR REHEATER. THE WATER LOOP IS CLOSED,
AND THE FLYASH STABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LANDFILL. THE
CLEANED FLUE GAS FROM THIS UNIT EXITS A 600 FT STACK. INITIAL START-UP
OCCURRED IN MAY 1978.
TUCSON ELECTRIC POWER
SPRINGERVILLE
1
NEW 370 MW (GROSS)
370 MW (ESC)
COAL
.61 XS SUEBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****•/.
STATUS 2 STARTUP 2/85
TUCSON ELECTRIC POWER WILL BE BUILDING TWO NEW UNITS IN SPRINGERVILLE,
ARIZONA, SPRINGERVILLE 1 AND 2. THE UNITS WILL FIRE PULVERIZED SUBBITU-
MINOUS COAL (0.53-0.69X S AND 8500-8900 BTU/LB). A CONTRACT WAS
AWARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A LIME/SPRAY DRYING FGD
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS. THE SYSTEM WILL
BE DESIGNED TO ACCOMODATE A REHEATER (SHOULD ONE BE REQUIRED) AND WILL
OPERATE IN A CLOSED WATER LOOP. CLEANED FLUE GAS WILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK. START-UP IS SCHEDULED FOR FEBRUARY 1985.
TUCSON ELECTRIC POWER
SPRINGERVILLE
2
NEW 370 MW (GROSS)
370 MW (ESC)
COAL
.61 XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 2/89
TUCSON GAS AND ELECTRIC WILL BE BUILDING TWO NEW UNITS IN SPRINGERVILLE,
ARIZONA, SPRINGERVILLE 1 AND 2. THE UNITS WILL FIRE PULVERIZED SUBBITU-
MINOUS COAL (0.53-0.69X S AND 8500-8900 BTU/LB). A CONTRACT HAS BEEN
AWARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A LIME/SPRAY DRYING FGD
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS. THE SYSTEM WILL
BE DESIGNED TO ACCOMODATE A REHEATER (SHOULD ONE BE REQUIRED) AST) WILL
OPERATE IN A CLOSED WATER LOOP. CLEANED FLUE GAS WILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK. START-UP IS SCHEDULED FOR FEBRUARY 1989.
TUCSON ELECTRIC POWER
SPRINGERVILLE
3
NEW 370 MW (GROSS)
370 MW (ESC)
COAL
.61 XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *#**X
STATUS 6 STARTUP 0/91
TUCSON ELECTRIC POWER HAS PLANS FOR A NEW UNIT, SPRINGERVILLE 3, TO BE
LOCATED IN SPRINGERVILLE, ARIZONA. THE PULVERIZED COAL (.53-.69X S, 8500-
8900 BTU/LB) FIRED UNIT WILL HAVE A GROSS MEGAWATT RATING OF 370 AND WILL
UTILIZE A FGD SYSTEM FOR CONTROL OF S02 EMISSIONS. INITIAL START-UP IS
SCHEDULED FOR 1991.
UNITED POWER ASSOCIATION
STANTON
1A
NEW 60 MW (GROSS)
50 MW (ESC)
COAL
.77 XS LIGNITE
LIME/SPRAY DRYING
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ****X
STANTON 1A OF THE UNITED POWER ASSOCIATION IS A PULVERIZED COAL (0.77X S,
7000 BTU/LB) FIRED UNIT LOCATED IN STANTON, NORTH DAKOTA. THE LIME/SPRAY
DRYING SYSTEM, SUPPLIED BY RESEARCH-COTTRELL, CONSISTS OF A SPRAY DRYER
FOLLOWED BY A FABRIC FILTER FOR S02 I PARTICULATE REMOVAL. KOMLINE AND
SANDERSON, THE SUBCONTRACTOR TO RESEARCH-COTTRELL, SUPPLIED THE ROTARY
ATOMIZER AND ASSOCIATED EQUIPMENT FOR THE REACTOR VESSEL. THE SYSTEM OP-
ERATES IN AN OPEN LOOP MODE WITH SLUDGE DISPOSED IN A CLAY LINED SETTLING
POND. THE CLEANED FLUE GAS EXITS A 25* FT STACK. OPERATIONS COMMENCED
IN JULY 1982.
STATUS 1
STARTUP 7/82
UTAH POWER & LIGHT
HUNTER
1
NEW 420 MW (GROSS)
360 MW (ESC)
COAL
.52 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 1.7X
STATUS 1 STARTUP 3/79
HUNTER 1 OF UTAH POWER AND LIGHT IS A COAL (0.52X S, 11,500 BTU/LB) FIRED
UNIT IN CASTLEDALE, UTAH. GEESI SUPPLIED A PEBBLE LIME WET SCRUBBING
SYSTEM WHICH BECAME OPERATIONAL IN MARCH 1979. THE SYSTEM IS DE-
SIGNED TO OPERATE IN AN OPEN WATER LOOP WITH AN S02 REMOVAL EFFICIENCY OF
SOX. PRIMARY PARTICULATE CONTROL IS PROVIDED BY AN UPSTREAM ESP, AND STACK
GAS REHEAT IS PROVIDED BY BYPASS. THE CLEANED FLUE GAS EXITS A 600 FT
STACK. THE SLUDGE IS FLYASH STABILIZED AND DISPOSED ON-SITE.
2-34
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
UTAH POWER * LIGHT
HUNTER
2
NEW 420 MM (GROSS)
360 MM (ESC)
COAL
.52 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 1.7X
STATUS 1 STARTUP 6/80
UTAH POWER AND LIGHT'S HUNTER 2 IS A COAL (0.52X S, 11,500 BTU/LB) FIRED
UNIT LOCATED IN CASTLEDALE, UTAH. FOR EMISSION CONTROL, GEESI SUPPLIED
A PEBBLE LIME MET SCRUBBING SYSTEM DESIGNED TO OPERATE IN AN OPEN MATER
LOOP MITH AN S02 REMOVAL EFFICIENCY OF 80X. AN UPSTREAM ESP PROVIDES
PRIMARY PARTICLE CONTROL, AND A BYPASS SYSTEM PROVIDES STACK GAS REHEAT.
THE SLUDGE IS FLYASH STABILIZED AND DISPOSED OF ON-SITE. START-UP OF BOTH
THE BOILER AND FGD SYSTEM TOOK PLACE IN JUNE 1980.
UTAH POWER & LIGHT
HUNTER
3
NEM 400 MM (GROSS)
400 MM (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: «***X
STATUS 1 STARTUP 4/83
HUNTER 3 OF UTAH POWER AND LIGHT IS A PULVERIZED COAL (0.55X S, 12500
BTU/LB) FIRED UNIT LOCATED IN CASTLE DALE, UTAH. A LIMESTONE NONREGENER-
ABLE FGD UNIT WAS SUPPLIED BY GEESI FOR 502 CONTROL AND ESP'S ARE EM-
PLOYED FOR PARTICULATE REMOVAL. THE SYSTEM OPERATES IN A CLOSED HATER
LOOP MODE AND FLUE GAS EXITS A 600 FT STACK. INITIAL OPERATIONS COM-
MENCED IN APRIL 1983.
UTAH POWER S LIGHT
HUNTINGTON
1
NEW 432 MM (GROSS)
366 MM (ESC)
COAL
.43 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 5/78
HUNTINGTON 1 OF UTAH POWER IS A TANGENTIALLY FIRED PULVERIZED COAL (0.43X
S, 11,650 BTU/LB) BOILER IN HUNTINGTON, UTAH. A COLD SIDE ESP TREATS
1,742,000 ACFM OF FLUE GAS AND IS FOLLOMED BY A GEESI LIME FGD SYSTEM
CONSISTING OF FOUR SPRAY TOMERS (SOX DESIGN EFFICIENCY). ONE FOUR PASS
CHEVRON/MODULE PROVIDES MIST ELIMINATION, AND A COMBINATION OF A STEAM
TUBE AND 10-20X BYPASS REHEATERS BOOST THE GAS TEMPERATURE 45-50 DEC F.
THE SYSTEM OPERATES IN A CLOSED MATER LOOP, AND THE FLYASH STABILIZED
SLUDGE IS TRUCKED TO AN ON-SITE LANDFILL. THE SYSTEM INCLUDES A 600 FOOT
ACID BRICK LINED STACK, AND HAS BEEN OPERATIONAL SINCE MAY 1978.
UTAH POWER * LIGHT
NAUGHTON
3
RETROFIT 330 MW (GROSS)
330 MW (ESC)
COAL
.55 XS SUBBITUMINOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 1.5X
STATUS 1 STARTUP 9/81
NAUGHTON 3 OF UTAH POWER AND LIGHT IS A PULVERIZED COAL (.55X S, 9500
BTU/LB) FIRED BOILER LOCATED IN KEMMERER, WYOMING. THE BOILER SUPPLIES
1,500,000 ACFM OF FLUE GAS TO AN ESP FOR PARTICULATE MATTER CONTROL. THE
UNIT WAS RETROFITTED WITH A UOP WET SODA ASH FGD SYSTEM FOR S02
CONTROL. THE FGD SYSTEM IS DESIGNED TO REMOVE 70X OF THE S02 BEFORE THE
FLUE GAS EXITS OUT A 475 FOOT STACK. INITIAL START-UP TOOK PLACE IN
SEPTEMBER 1981.
WASHINGTON WATER POWER
CRESTON COAL
1
NEW 570 MM (6ROSS)
' 570 MW (ESC)
COAL
***** XS UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **«*X
STATUS 6 STARTUP 0/95
MASHINGTON MATER POMER HAS PLANS FOR A NEM UNIT, CRESTON COAL 1, TO BE
LOCATED IN CRESTON, WASHINGTON. THE COAL FIRED BOILER WILL HAVE A GROSS
GENERATING CAPACITY OF 570 MW AND MILL UTILIZE A MET LIMESTONE FGD SYSTEM
FOR CONTROL OF S02 EMISSIONS. FGD OPERATIONS ARE SCHEDULED TO COMMENCE
IN 1995.
MASHINGTON HATER POMER
CRESTON COAL
2
570 MM (GROSS)
570 MM (ESC)
NEM
COAL
***** XS UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/97
HASHINGTON WATER POWER HAS PLANS FOR A NEW UNIT, CRESTON 2, TO BE LOCATED
IN CRESTON, WASHINGTON. THE COAL FIRED BOILER HILL HAVE A GROSS GENERAT-
ING CAPACITY OF 570 MM AND HILL USE A MET LIMESTONE FGD SYSTEM FOR CONTROL
OF S02 EMISSIONS. FGD OPERATIONS ARE SCHEDULED TO COMMENCE IN 1997.
2-35
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
WASHINGTON WATER POWER
CRESTON COAL
3
NEW 570 MW (GROSS)
570 MW (ESC)
COAL
*»*** XS UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 12.37.
STATUS 6 STARTUP 0/98
WASHINGTON WATER POWER HAS PLANS FOR A NEW UNIT, CRESTON 3, TO BE LOCATED
IN CRESTON, WASHINGTON. THE COAL FIRED BOILER WILL HAVE A GROSS GENERAT-
ING CAPACITY OF 570 MW AND WILL USE A WET LIMESTONE FGD SYSTEM FOR CONTROL
OF S02 EMISSIONS. FGD OPERATIONS ARE SCHEDULED TO COMMENCE IN 1998.
WASHINGTON WATER POWER
CRESTON COAL
4
NEW 570 MW (GROSS)
570 MW (ESC)
COAL
***** XS UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 12.3X
STATUS 6 STARTUP 0/99
WASHINGTON WATER POWER HAS PLANS FOR A NEW UNIT, CRESTON 4, TO BE LOCATED
IN CRESTON, WASHINGTON. THE COAL FIRED BOILER WILL HAVE A GROSS GENERAT-
ING CAPACITY OF 570 MW AND WILL USE A WET LIMESTONE FGD SYSTEM FOR CONTROL
OF S02 EMISSIONS. FGD OPERATIONS ARE SCHEDULED TO COMMENCE IN 1999.
WEST PENN POWER
MITCHELL
33
RETROFIT 300 MW (GROSS)
300 MW (ESC)
COAL
2.80 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: l.OX
STATUS 1 STARTUP 8/82
UNIT 33 AT ALLEGHENY POWER SYSTEM'S MITCHELL POWER STATION IN COURTNEY,
PENNSYLVANIA IS A COAL (2.8X S, 12,520 BTU/LB) FIRED BOILER. GEESI HAS
INSTALLED A LIME SCRUBBING PROCESS WITH AN S02 REMOVAL EFFICIENCY OF 95X.
PARTICULATE MATTER IS CONTROLLED WITH ESP'S. OPERATIONS COMMENCED IN
AUGUST 1982.
WEST TEXAS UTILITIES
OKLAUNION
1
NEW 720 MW (GROSS)
504 MW (ESC)
COAL
.34 XS SUBBITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 9/86
WEST TEXAS UTILITIES HAS STARTED CONSTRUCTION ON A PULVERIZED SUBBITUMI-
NOUS COAL (.34X S, 8227 BTU/LB) FIRED BOILER LOCATED NEAR OKLAUNIOH,
TEXAS. THE FOSTER WHEELER BOILER WILL SUPPLY 2,382,679 ACFM OF FLUE GAS
TO A WET LIMESTONE FGD SYSTEM SUPPLIED BY GE ENVIRONMENTAL SYSTEMS FOR
CONTROL OF S02 EMISSIONS (70X DESIGN REMOVAL EFFICIENCY). LODGE-COTTRELL
WILL SUPPLY A RIGID FRAME COLD SIDE ESP FOR PARTICULATE CONTROL. THE SYS-
TEM WILL OPERATE IN A CLOSED WATER LOOP MODE AND FLUE GAS WILL EXIT
THROUGH A 453 FT ACID BRICK LINED STACK. INITIAL OPERATIONS ARE SCHEDULED
FOR SEPTEMBER 1986.
WEST TEXAS UTILITIES
OKLAUNION
2
NEW 720 MW (GROSS)
504 MW (ESC)
COAL
.34 XS SUEBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: .OX
STATUS 6 STARTUP 0/96
WEST TEXAS UTILITIES HAS PLANS TO BUILD A SECOND COAL (.34X S, 8227
BTU/LB) FIRED BOILER TO BE LOCATED NEAR OKLAUNION, TEXAS. THE UTILITY
WILL INCLUDE AN FGD SYSTEM FOR S02 CONTROL FROM THE 720 MW UNIT. LODGE-
COTTRELL WILL SUPPLY A RIGID FRAME COLD SIDE ESP FOR CONTROL OF PARTICU-
LATE MATTER. THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP MODE. UNIT
2 IS SCHEDULED TO COMMENCE OPERATIONS IN 1996.
WHITE PINE COUNTY
WHITE PINE PWR PROJ.
1
NEW 820 MW (GROSS)
820 MW (ESC)
COAL
.60 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 3/91
WHITE PINE COUNTY HAS PLANS FOR TWO NEW UNITS, WHITE PINE POWER PROJECT
1 AND 2, TO BE LOCATED NEAR ELY NEVADA. THE PULVERIZED COAL (10,530 BTU/
LB, 0.6X S) FIRED UNITS WILL HAVE A GROSS MEGAWATT RATING OF 820 EACH AND
WILL UTILIZE A SPRAY DRYING FGD SYSTEM FOR CONTROL OF S02 EMISSIONS. FAB-
RIC FILTERS WILL BE EMPLOYED FOR PARTICULATE CONTROL. UNITS 1 ANT) 2 ARE
SCHEDULED TO COMMENCE OPERATIONS IN 1991 AND 1992 RESPECTIVELY.
2-36
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION Z
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
WHITE PINE COUNTY
WHITE PINE PWR PROJ.
Z
NEW 820 MM (GROSS)
820 MM (ESC)
COAL
.60 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »»»*X
STATUS 6 STARTUP 3/92
WHITE PINE COUNTY HAS PLANS FOR TWO NEW UNITS, WHITE PINE POWER PROJECT
1 AND 2 TO BE LOCATED NEAR ELY NEVADA. THE PULVERIZED COAL (10,530 BTU/
LB, 0.6X S) FIRED UNITS WILL HAVE A GROSS MEGAWATT RATING OF 820 EACH AND
WILL UTILIZE A SPRAY DRYING FGD SYSTEM FOR CONTROL OF S02 EMISSIONS. FAB-
RIC FILTERS WILL BE EMPLOYED FOR PARTICULATE CONTROL. UNITS 1 AND 2 ARE
SCHEDULED TO COMMENCE OPERATIONS IN 1991 AND 1992 RESPECTIVELY.
2-37
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 3
SUMMARY OF FGD SYSTEMS BY COMPANY
TOTAL
STATUS
OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
PLANNED
COMPANY NAME
ALABAMA ELECTRIC
ARIZONA ELECTRIC POWER
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC
ATLANTIC CITY ELECTRIC
BASIN ELECTRIC POWER
BIG RIVERS ELECTRIC
BOSTON EDISON
CAJUN ELECTRIC POWER
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CENTRAL POWER t LIGHT
CINCINNATI GAS & ELECTRIC
COLORADO UTE ELECTRIC
COLUMBUS * SOUTHERN OHIO ELEC
COOPERATIVE POWER
COOPERATIVE POWER ASSOCIATION
DELMARVA POWER t LIGHT
DESERET GEN & TRANS
DUQUESNE LIGHT
EAST KENTUCKY POWER
FLORIDA POWER i LIGHT
GENERAL PUBLIC UTILITIES
GRAND HAVEN BRD OF LIGHT & PWR
GRAND RIVER DAM AUTHORITY
HOOSIER ENERGY
HOUSTON LIGHTING £ POWER
INDIANAPOLIS POWER & LIGHT
IOWA ELECTRIC LIGHT t PHR
JACKSONVILLE ELEC AUTHORITY
KANSAS CITY POWER « LIGHT
KANSAS POWER i LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LOS ANGELES DEPT OF WTR t PWR
LOUISVILLE GAS t ELECTRIC
LOWER COLORADO RIVER AUTH
MARG'JETTE BOARD OF LIGHT t PWR
MICHIGAN SO CENTRAL PWR AGENCY
MIDDLE SOUTH UTILITIES
MINNESOTA POWER t LIGHT
MINNKOTA POWER
MONONGAHELA POWER
MONTANA POWER
MONTANA-DAKOTA UTILITIES
MUSCATINE POWER t WATER
NEBRASKA PUBLIC POWER DISTRICT
NEVADA POWER
NEW YORK STATE ELEC t GAS
NIAGARA MOHAWK POWER
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
ORLANDO UTILITIES COMMISSION
PACIFIC POWER & LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
PLAINS ELECTRIC G & T
PLATTE RIVER POWER AUTHORITY
PUBLIC SERVICE INDIANA
NO.
Z
2
9
1
1
6
3
2
1
1
1
1
1
3
3
2
1
2
4
2
2
2
2
2
1
1
2
5
5
1
2
1
5
3
1
2
10
2
1
1
2
1
1
2
4
1
1
1
8
1
1
2
4
1
S
3
3
1
1
1
MW
358.
196.
2761.
670.
330.
3150.
924.
776.
540.
416.
617.
600.
720.
2686.
1357.
700.
750.
654.
730.
820.
918.
1150.
1600.
1380.
65.
520.
882.
3372.
3012.
720.
1224.
874.
2165.
1365.
364.
1640.
3539.
902.
44.
55.
1780.
475.
374.
1252.
2276.
440.
166.
650.
2625.
625.
100.
782.
2420.
465.
2530.
2751.
724.
233.
279.
670.
NO.
2
2
6
1
0
4
3
0
0
1
1
0
0
1
3
2
0
2
3
1
2
1
0
0
1
0
2
1
1
0
0
1
5
1
1
0
6
0
1
1
0
1
1
2
3
1
1
0
4
1
1
1
3
0
1
3
3
0
1
1
MM
358.
196.
1145.
670.
0.
2150.
924.
0.
0.
416.
617.
0.
0.
650.
1357.
700.
0.
654.
180.
410.
918.
500.
0.
0.
65.
0.
882.
492.
532.
0.
0.
874.
2165.
65.
364.
0.
2389.
0.
44.
55.
0.
475.
374.
1252.
1498.
440.
166.
0.
625.
625.
100.
391.
1610.
0.
550.
2751.
724.
0.
279.
670.
NO.
0
0
2
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
2
1
0
2
0
0
0
0
2
0
1
0
0
0
0
0
0
1
0
0
0
0
0
0
1
1
1
1
0
0
1
0
0
MM
0.
0.
1490.
0.
0.
440.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
520.
0.
1500.
530.
0.
1224.
0.
0.
0.
0.
1640.
0.
451.
0.
0.
0.
0.
0.
0.
778.
0.
0.
0.
0.
0.
0.
391.
810.
465.
550.
0.
0.
233.
0.
0.
NO.
0
0
0
0
0
0
0
0
1
0
0
0
1
0
0
0
0
0
0
0
0
1
0
0
0
0
0
2
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
3
0
0
0
0
0
MM
0.
0.
0.
0.
0.
0.
0.
0.
540.
0.
0.
0.
720.
0.
0.
0.
0.
0.
0.
0.
0.
650.
0.
0.
0.
0.
0.
1380.
0.
0.
0.
0.
0.
650.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
1430.
0.
0.
0.
0.
0.
NO.
0
0
1
0
1
1
0
2
0
0
0
1
0
2
0
0
1
0
1
1
0
0
2
2
0
0
0
0
3
1
0
0
0
1
0
0
2
1
0
0
2
0
0
0
0
0
0
1
4
0
0
0
0
0
0
0
0
0
0
0
MW
0.
0.
126.
0.
330.
560.
0.
776.
0.
0.
0.
600.
0.
2036.
0.
0.
750.
0.
550.
410.
0.
0.
1600.
1380.
0.
0.
0.
0.
1950.
720.
0.
0.
0.
650.
0.
0.
1150.
451.
0.
0.
1760.
0.
0.
0.
0.
0.
0.
650.
2000.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIGNED,
AND CONSIDERING ONLY FGD SYSTEMS
REQUESTING/EVALUATING BIDS,
3-1
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 3
SUMMARY OF FGD SYSTEMS BY COMPANY
TOTAL
COMPANY NAME
PUBLIC SERVICE OF NEW MEXICO
PUB. SER. CO. OF COLORADO
SALT RIVER PROJECT
SAN ANTONIO PUBLIC SERVICE
SAN MIGUEL ELECTRIC
SEMINOLE ELECTRIC
SIERRA PACIFIC POWER
SIKESTON BRD OF MUNICIPAL UTIL
SOUTH CAROLINA PUBLIC SERVICE
SOUTH MISSISSIPPI ELEC PWR
SOUTHERN ILLINOIS POWER
SOUTHERN INDIANA GAS & ELEC
SOUTHWESTERN ELECTRIC POWER
SOUTHWESTERN PUBLIC SERVICE
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER, LIGHT & PWR
SUNFLOWER ELECTRIC
TAMPA ELECTRIC
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER & LIGHT
TEXAS UTILITIES
TUCSON ELECTRIC POWER
UNITED POWER ASSOCIATION
UTAH POWER t LIGHT
WASHINGTON WATER POWER
WEST PENH POWER
WEST TEXAS UTILITIES
WHITE PINE COUNTY
NO.
5
1
3
4
1
4
4
1
5
2
1
Z
4
1
1
1
1
1
4
1
3
6
3
1
5
(t
1
2
z
MW
2279.
500.
920.
2000.
400.
2480.
1776.
235.
1600.
248.
184.
530.
2880.
572.
194.
205.
347.
458.
2533.
400.
1882.
4085.
1110.
50.
1816.
2280.
300.
1008.
1640.
OPERATIONAL
NO.
4
0
2
0
1
2
0
1
4
2
1
1
0
0
1
1
1
0
4
1
1
4
0
1
5
0
1
0
0
MM
1779.
0.
640.
0.
400.
1240.
0.
235.
1150.
248.
184.
265.
0.
0.
194.
205.
347.
0.
2533.
400.
382.
2585.
0.
50.
1816.
0.
300.
0.
0.
CONSTRUCTION CONTRACT
AWARDED
NO.
0
0
0
0
0
0
1
0
0
0
0
1
2
0
0
0
0
1
0
0
0
0
1
0
0
0
0
1
0
MW
0.
0.
0.
0.
0.
0.
276.
0.
0.
0.
0.
265.
1440.
0.
0.
0.
0.
458.
0.
0.
0.
0.
370.
0.
0.
0.
0.
504.
0.
NO.
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
2
2
1
0
0
0
0
0
0
MW
0.
0.
0.
0.
0.
0.
0.
0.
450.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
1500.
1500.
370.
0.
0.
0.
0.
0.
0.
PLANNED
NO.
1
1
1
4
0
2
3
0
0
0
0
0
2
1
0
0
0
0
0
0
0
0
1
0
0
4
0
1
2
MW
500.
500.
280.
2000.
0.
1240.
1500.
0.
0.
0.
0.
0.
1440.
572.
0.
0.
0.
0.
0.
0.
0.
0.
370.
0.
0.
2280 .
0.
504.
1640.
TOTALS
217 102075.
124 47255.
25 14335.
15 9190.
53 31295.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIGNED, REQUESTING/EVALUATING BIDS,
AND CONSIDERING ONLY FGD SYSTEMS
3-2
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 4
SUMMARY OF FGD SYSTEMS BY SYSTEM SUPPLIER
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
SYSTEM SUPPLIER/PROCESS
AIR CORRECTION DIVISION, UOP
LIME
LIMESTONE
SODIUM CARBONATE
TOTAL -
AMERICAN AIR FILTER
LIME
LIMESTONE
TOTAL -
BABCOCK * WILCOX
LIME
LIMESTONE
LIME/SPRAY DRYING
SODIUM CARBONATE
TOTAL -
BECHTEL/MONTANA POWER
LIME/ALKALINE FLY ASH
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTONE/ALKALINE FLY ASH
LIME/ALKALINE FLY ASH
TOTAL -
DAVY MCKEE
WELLMAN LORD
TOTAL -
ENVIRONEERING, RILEY STOKER
LIMESTONE
TOTAL -
FLAKT
LIME/SPRAY DRYING
TOTAL -
FMC
DUAL ALKALI
TOTAL -
GE ENVIRONMENTAL SERVICES
DUAL ALKALI
LIME
LIMESTONE
LIME/ALKALINE FLYASH
LIME/SPRAY DRYING
TOTAL -
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
TOTAL -
NO.
2
4
2
8
6
1
7
7
9
2
3
21
2
2
4
14
2
2
22
7
7
3
3
1
1
4
4
1
8
12
3
1
25
10
10
MM
700.
2166.
880.
3746.
1659.
280.
1939.
4107.
3182.
1017.
1650.
9956.
1556.
1556.
980.
6581.
1500.
654.
9715.
1959.
1959.
664.
664.
520.
520.
1312.
1312.
617.
4138.
8124.
615.
44.
13538.
4426.
4426.
NO.
2
2
2
6
6
1
7-
4
8
2
0
14
1
1
4
9
2
2
17
7
7
3
3
0
0
2
2
1
8
5
3
1
18
4
4
MM
700.
726.
680.
2306.
1659.
280.
1939.
1967.
2532.
1017.
0.
5516.
778.
778.
980.
3932.
1500.
654.
7066.
1959.
1959.
664.
664.
0.
0.
656.
656.
617.
4138.
3100.
615.
44.
8514.
1176.
1176.
NO.
0
2
0
2
0
0
0
2
0
0
1
3
1
1
0
5
0
0
5
0
0
0
0
1
1
2
2
0
0
3
0
0
3
3
3
MM
0.
1440.
0.
1440.
0.
0.
0.
1490.
0.
0.
550.
2040.
778.
778.
0.
2649.
0.
0.
2649.
0.
0.
0.
0.
520.
520.
656.
656.
0.
0.
2144.
0.
0.
2144.
1620.
1620.
NO.
0
0
0
0
0
0
0
1
1
0
2
4
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
4
0
0
4
3
3
MM
0.
0.
0.
0.
0.
0.
0.
650.
650.
0.
1100.
2400.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
2-veo.
0.
0.
2880.
1630.
1630.
4-1
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION ^
SUMMARY OF FGD SYSTEMS BY SYSTEM SUPPLIER
TOTAL
SYSTEM SUPPLIER/PROCESS
JOY/NIRO
LIME/SPRAY DRYING
TOTAL -
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
TOTAL -
M.W. KELLOGG
LIME
LIMESTONE
TOTAL -
PEABODY PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
RESEARCH-COTTRELL
LIMESTONE
LIME/SPRAY DRYING
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE/SPRAY DRYING
LIME/SPRAY DRYING
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
THYSSEN/CEA
DUAL ALKALI
LIME
LIME/ALKALINE FLYASH
SODIUM CARBONATE
TOTAL -
UNITED ENGINEERS
MAGNESIUM OXIDE
TOTAL -
KHEELABRATOR AIR POLTN. CNTRL.
LIMESTONE
TOTAL -
WHEELABRATOR-FRYE/R.I.
SODIUM CARBONATE/SPRAY DRYING
TOTAL -
NO.
1
1
2
Z
2
4
6
9
1
10
17
1
18
1
1
2
1
1
1
1
3
4
9
3
3
1
1
1
1
MM
330.
330.
882.
882.
1357.
1980.
3337.
4033.
475.
4508.
6984.
50.
7034.
100.
276.
376.
550.
550.
299.
500.
1094.
625.
2518.
724.
724.
750.
750.
440.
440.
OPERATIONAL
NO.
0
0
2
2
2
4
6
8
1
9
12
1
13
1
0
1
1
1
1
1
3
4
9
3
3
0
0
1
1
MW
0.
0.
882.
882.
1357.
1980.
3337.
3583.
475.
4058.
4022.
50.
4072.
100.
0.
100.
550.
550.
299.
500.
1094.
625.
2518.
724.
724.
0.
0.
440.
440.
CONSTRUCTION
NO.
0
0
0
0
0
0
0
0
0
0
4
0
4
0
1
1
0
0
0
0
0
0
0
0
0
0
0
0
0
MM
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
2212.
0.
2212.
0.
276.
276.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
CONTRACT
AWARDED
NO.
1
1
0
0
0
0
0
1
0
1
1
0
1
0
0
0
0
0
0
0
0
0
0
0
0
1
1
0
0
MM
330.
330.
0.
0.
0.
0.
0.
450.
0.
450.
750.
0.
750.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
750.
750.
0.
0.
TOTAL -
164 70780.
124 47255.
25 14335.
15 9190.
4-2
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 5
SUMMARY OF FGD SYSTEMS BY PROCESS
TOTAL
STATUS
OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
PROCESS
NO. MM
NO.
NO.
NO.
MW
SUBTOTAL - SALEABLE PRODUCT 15 4183. 12 2949.
DUAL ALKALI
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLYASH
LIME/SPRAY DRYING
PROCESS NOT SELECTED
SODIUM CARBONATE
SODIUM CARBONATE/SPRAY DRYING
TRONA/DRY INJECTION
SUBTOTAL - THROWAWAY PRODUCT 172 80089. 112 44306.
458.
23 13412.
14 8860.
PLANNED
NO.
MW
AQUEOUS CARBONATE/SPRAY DRYING
LIMESTONE
MAGNESIUM OXIDE
WELLMAN LORD
1
4
3
7
100.
1400.
724.
1959.
1
1
3
7
100.
166.
724.
1959.
0
1
0
0
0.
458.
0.
0.
0
0
0
0
0.
0.
0.
0.
0
2
0
0
0.
776.
0.
0.
776.
6
30
90
2
11
16
6
9
1
1
2228.
13441.
44008.
1500.
4394.
6333.
4090.
3155.
440.
500.
4
27
54
2
10
8
0
6
1
0
1572.
11301.
22085.
1500.
3616.
2287.
0.
1505.
440.
0.
2
2
12
0
1
5
0
1
0
0
656.
1490.
7522.
0.
778.
2416.
0.
550.
0.
0.
0
1
8
0
0
3
0
2
0
0
0.
650.
5480.
0.
0.
1630.
0.
1100.
0.
0.
0
0
16
0
0
0
6
0
0
1
0.
0.
8921.
0.
0.
0.
4090.
0.
0.
500.
23 13511.
TOTALS 187 84272. 124 47255. 24 13870. 14 8860. 25 14287.
SALEABLE PRODUCT PROCESS
Y. OF TOTAL MW 56305
NOTE: 30 UNITS ARE UNDECIDED (WITH RESPECT TO SALEABLE/THROWAWAY PRODUCT) AND ARE NOT INCLUDED
IN THIS TABLE. THE 6 UNITS LISTED AS PROCESS NOT SELECTED ABOVE ARE PLANNED THROWAWAY
PRODUCT FGD SYSTEMS; HOWEVER A SPECIFIC PROCESS HAS NOT YET BEEN CHOSEN.
5-1
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 6
SUMMARY OF OPERATIONAL F6D SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
UNIT NO.
CAPACITY
MM
INITIAL
STARTUP
COMMERCIAL
STARTUP
AQUEOUS CARBONATE/SPRAY DRYING
CHARLES R. HUNTLEY 66
DUAL ALKALI
A.B. BROWN
CANE RUN
NEWTON
SCHAHFER
LIME
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
CANE RUN
CANE RUN
CONESVILLE-
CONESVILLE
D.B. WILSON
EAST BEND
ELRAMA
GREEN
GREEN
GREEN RIVER
HUNTER
HUNTER
HUNTINGTON
J.B. SIMS
MILL CREEK
MILL CREEK
MILL CREEK
MILL CREEK
MITCHELL
PADDY'S RUN
PHILLIPS
PLEASANTS
PLEASANTS
SPURLOCK
LIMESTONE
APACHE
APACHE
BONANZA
CHOLLA
CHOLLA
CHOLLA
CORONADO
CORONADO
CRAIG
CRAIG
CROSS
DALLMAN
DUCK CREEK
GIBBOUS CREEK
GIBSON
HUNTER
1
6
1
17
3
2
1
5
4
6
5
1
2
1-4
1
2
1-3
1
2
1
3
4
3
2
1
33
6
1-6
1
2
2
100.
100.
265.
299.
617.
391.
1572.
11301.
98.
98.
410.
126.
285.
119.
320.
320.
455.
455.
450.
205.
416.
400.
670.
400.
4/82
3/79
4/79
9/79
4/83
6/79
8/78
9/84
3/81
4/78
10/73
7/80
11/79
12/79
10/60
10/83
10/80
7/76
11/82
10/82
4/83
8/82
4/79
4/79
12/79
6/83
917.
917.
917.
200.
188.
350.
350.
440.
650.
510.
242.
242.
65.
360.
360.
366.
65.
495.
427.
350.
358.
300.
72.
408.
626.
626.
500.
6/80
7/77
12/75
12/77
8/76
6/78
1/77
9/84
3/81
10/75
12/79
11/80
9/75
3/79
6/80
5/78
5/83
7/82
8/78
12/81
12/60
8/82
4/73
7/73
12/78
10/80
12/82
10/80
10/77
6/76
7/78
8/77
7/78
2/77
9/84
3/81
10/75
12/79
12/80
6/76
5/79
6/80
5/76
8/83
10/82
3/79
4/82
4/81
9/82
4/73
6/74
12/80
12/80
4/83
6/79
1/79
12/84
6/81
6/78
12/73
10/81
12/79
5/80
12/80
5/84
1/81
8/78
10/83
3/83
6/83
THIS TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANIES CAN BE FOUND IN SECTION 1.
6-1
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 6
SUMMARY OF OPERATIONAL FGD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
JEFFREY
JEFFREY
JEFFREY
LA CYGNE
LARAMIE RIVER
LARAMIE RIVER
LAWRENCE
LAWRENCE
MARION
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MCINTOSH
MEROM
MEROM
MONTICELLO
MUSCATINE
PARADISE
PARADISE
PETERSBURG
PROJECT
R.D. MORROW, SR.
R.D. MORROW, SR.
SAN MIGUEL
SANDOW
SEMINOLE
SEMINOLE
SIKESTON
SOMERSET
SOUTHWEST
THOMAS HILL
TOMBIGBEE
TOMBIGSEE
WIDOUS CREEK
WIDOWS CREEK
WINYAH
WINYAH
WINYAH
W.A. PARISH
UNIT NO.
3
Z
1
1
Z
1
5
*
*
1
3
2
3
Z
1
3
9
1
Z
3
1
Z
1
1
*
Z
1
1
1
1
3
3
Z
8
7
Z
ft
3
8
CAPACITY
MM
5*0.
5*0.
5*0.
87*.
570.
570.
*20.
125.
18*.
595.
595.
595.
36*.
**1.
**1.
800.
166.
70*.
70*.
532.
55.
12*.
12*.
*00.
382.
620.
620.
235.
625.
19*.
670.
179.
179.
550.
575.
1*0.
280.
280.
*92.
INITIAL
STARTUP
5/83
1/60
8/78
12/72
7/81
7/80
*/78
1/77
*/79
*/77
2/79
5/78
7/82
12/81
8/82
5/78
*/83
5/83
7/83
12/77
5/83
6/79
8/78
8/81
12/80
9/8*
5/83
6/81
7/8*
*/77
10/82
6/79
9/78
5/77
3/81
7/77
7/81
7/80
10/82
COMMERCIAL
STARTUP
5/83
5/80
8/78
6/73
7/86
7/80
*/78
1/77
6/79
10/77
2/79
5/78
9/82
2/62
8/82
10/78
8/83
7/83
12/83
12/77
5/83
6/79
8/78
10/81
1/81
1/85
2/8*
9/81
8/8*
9/77
12/82
6/79
9/78
1/78
9/81
7/77
9/81
7/80
12/82
LIMESTONE/ALKALINE FLYASH
SHERBURNE 2
SHERBURHE 1
LIME/ALKALINE FLYASH
CLAY BOSWELL *
COAL CREEK 1
COAL CREEK 2
COLSTRIP 1
COLSTRIP 3
COLSTRIP 2
FOUR CORNERS 3
FOUR CORNERS 2
FOUR CORNERS 1
MILTON R. YOUNG 2
22251.
750.
750.
1500.
*75.
327.
327.
360.
778.
360.
225.
195.
195.
37*.
3616.
3/77
3/76
2/60
7/79
7/80
9/75
10/83
5/76
11/79
11/79
11/79
9/77
*/77
5/76
*/80
8/79
9/80
11/75
1/8*
10/76
11/79
11/79
11/79
6/78
THIS TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANIES CAN BE FOUND IN SECTION 1.
6-2
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 6
SUMMARY OF OPERATIONAL FGO SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
LIME/SPRAY DRYING
ANTELOPE VALLEY
CRAIG
HOLCOMB
LARAMIE RIVER
RAWHIDE
RIVERSIDE
SHIRAS
STANTON
MAGNESIUM OXIDE
CROMBY
EDDYSTONE
EDDYSTONE
SODIUM CARBONATE
JIM BRIDGER
NAUGHTON
REID GARDNER
REID GARDNER
REID GARDNER
REID GARDNER
SODIUM CARBONATE/SPRAY
COYOTE
WELLMAN LORD
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
SAN JUAN
SAN JUAN
SAN JUAN
SAN JUAN
UNIT NO.
1
3
1
3
1
6-7
3
1A
1
2
1
4
3
4
3
Z
1
DRYING
1
3
Z
1
1
3
2
4
CAPACITY
MW
440.
447.
347.
570.
279.
110.
44.
50.
2287.
150.
334.
240.
724.
550.
330.
250.
125.
125.
125.
1505.
440.
440.
60.
60.
60.
361.
534.
350.
534.
1959.
INITIAL
STARTUP
5/83
6/84
7/83
11/62
12/83
11/80
3/83
7/82
10/82
11/82
9/82
9/79
9/81
6/83
6/76
4/74
3/74
4/81
5/80
5/80
5/80
4/78
12/79
8/78
5/82
COMMERCIAL
STARTUP
7/84
2/85
8/83
11/82
4/84
12/80
4/83
11/82
1/63
12/82
12/82
2/80
12/81
7/83
7/76
4/74
4/74
5/81
5/80
5/80
5/80
4/78
12/79
8/78
7/82
TOTAL
47255.
6-3
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 7
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
PROCESS/
UNIT NAME
THROWAWAY
UNIT NO LANDFILL POND
BYPRODUCT
TYPE DISPOSITION
AQUEOUS CARBONATE/SPRAY DRYING
CHARLES R. HUNTLEY 66
DUAL ALKALI
A.B. BROWN 1
CANE RUN 6
NEWTON 1
SCHAHFER 17
LIME
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
CANE RUM
CANE RUN
CONESVILLE
CONESVILLE
D.B. WILSON
EAST BEND
ELRAMA
GREEN
GREEN
GREEN RIVER
HUNTER
HUNTER
HUNTINGTON
J.B. SIMS
MILL CREEK
MILL CREEK
MILL CREEK
MILL CREEK
MITCHELL
PADDY'S RUN
PHILLIPS
PLEASANTS
PLEASANTS
SPUR LOCK
3
2
1
5
4
6
5
1
2
1-4
1
2
1-3
1
2
1
3
4
3
2
1
33
6
1-6
1
2
2
LIMESTONE
APACHE
APACHE
BONANZA
CHOLLA
CHOLLA
CHOLLA
CORONADO
COROHADO
CRAIG
CRAIG
CROSS
DALLMAN
DUCK CREEK
GIBBONS CREEK
GIBSON
HUNTER
JEFFREY
JEFFREY
JEFFREY
LA CYGNE
LARAMIE RIVER
LARAMIE RIVER
LAWRENCE
3
2
1
4
2
1
2
1
2
1
2
3
1
1
S
3
3
2
1
1
2
1
5
ELEMENTAL SULFUR
MARKETED
UNSTABILIZED
FIXATION
FIXATION
UNSTABILIZED
FIXATION
FIXATION
FIXATION
FIXATION
FIXATION
FIXATION
FIXATION
FIXATION
FIXATION
STABILIZATION
STABILIZATION
STABILIZATION
STABILIZATION
STABILIZATION
FIXATION
FIXATION
FIXATION
FIXATION
FIXATION
FIXATION
UNSTABILIZED
FIXATION
FIXATION
FIXATION
UNSTABILIZED
FORCED-OX
FORCED-OX
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
STABILIZATION
UNSTABILIZED
UNSTABILIZED
UNSTABILIZED
STABILIZATION
FORCED-OX
FIXATION
STABILIZATION
NONE
UNSTABILIZED
FORCED-OX
FORCED-OX
FORCED-OX
UNSTABILIZED
FORCED-OX
7-1
-------
UTILITY FGD SURVEY'- OCTOBER 1983 - SEPTEMBER 1984
SECTION 7
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
PROCESS/
UNIT NAME
LAWRENCE
MARION
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MCINTOSH
MEROM
MEROM
MONTICELLO
MUSCATINE
PARADISE
PARADISE
PETERSBURG
PROJECT
R.D. MORROW, SR.
R.D. MORROW, SR.
SAN MIGUEL
SANDOW
SEMINOLE
SEMINOLE
SIKESTON
SOMERSET
SOUTHWEST
THOMAS HILL
TOMBIGBEE
TOMBIG3EE
WIDOWS CREEK
WIDOWS CREEK
WINYAH
WINYAH
WINYAH
W.A. PARISH
UNIT
4
4
1
3
2
3
2
1
3
9
1
2
3
1
2
1
1
<+
2
1
1
1
1
3
3
2
8
7
2
4
3
8
NO LANDFILL POND TYPE DISPOSITION
FORCED-OX
STABILIZATION
STABILIZATION
STABILIZATION
STABILIZATION
FIXATION
FORCED-OX
FORCED-OX
STABILIZATION
FORCED-OX GYPSUM
FORCED-OX
FORCED-OX
FIXATION
FORCED-OX
FIXATION
FIXATION
STABILIZATION
FORCED-OX
FIXATION
FORCED-OX
UNSTABILIZED
STABILIZATION
STABILIZATION
FORCED-OX
UNSTABILIZED
UNSTABILIZED
FORCED-OX
FORCED-OX
UNSTABILIZED
STABILIZATION
MARKETED
LIMESTONE/ALKALINE FLYASH
SHERBURNE
SHERBURNE
LIME/ALKALINE FLYASH
CLAY BOSWELL
COAL CREEK
COAL CREEK
COLSTRIP
COLSTRIP
COLSTRIP
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
MILTON R. YOUNG
LIME/SPRAY DRYING
ANTELOPE VALLEY
CRAIG
HOLCOMB
LARAMIE RIVER
RAWHIDE
RIVERSIDE
SHIRAS
STANTON
MAGNESIUM OXIDE
CROMBY
EDDYSTONE
EDDYSTONE
2
1
4
1
2
1
3
2
3
Z
I
Z
1
3
1
3
1
6-7
3
1A
1
2
1
FORCED-OX
FORCED-OX
UNSTABILIZED
UNSTABILIZED
FORCED-OX
UNSTABILIZED
UNSTABILIZED
SULFURIC ACID
SULFURIC ACID
SULFURIC ACID
MARKETED
MARKETED
MARKETED
7-2
-------
UTILITY FGD SURVEY: OCTOBER 19S3 - SEPTEMBER 1984
SECTION 7
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
PROCESS/
UNIT NAME
THROWAWAY
UNIT NO LANDFILL POND
BYPRODUCT
TYPE DISPOSITION
SODIUM CARBONATE
JIM BRIDGER
NAUGHTON
REID GARDNER
REID GARDNER
REID GARDNER
REID GARDNER
UNSTABILIZED
UNSTABILIZED
UNSTABILIZED
UNSTABILIZED
SODIUM CARBONATE/SPRAY DRYING
COYOTE 1
WELLMAN LORD
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
SAN JUAN
SAN JUAN
SAN JUAN
SAN JUAN
SULFURIC
SULFUR1C
SULFURIC
SULFURIC
SULFURIC
SULFURIC
SULFURIC
ACID
ACID
ACID
ACID
ACID
ACID
ACID
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
7-3
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 8
SUMMARY OF FGO SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
ALABAMA ELECTRIC
TOMBIGBEE 2
ALABAMA ELECTRIC
TOMBIGBEE 3
ARIZONA ELECTRIC POWER
APACHE 2
ARIZONA ELECTRIC POWER
APACHE 3
ARIZONA PUBLIC SERVICE
CHOLLA 1
ARIZONA PUBLIC SERVICE
CHOLLA Z
ARIZONA PUBLIC SERVICE
CHOLLA 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZONA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
ASSOCIATED ELECTRIC
THOMAS HILL t
BASIN ELECTRIC POWER
ANTELOPE VALLEY 1
BASIN ELECTRIC POWER
URAMIE RIVER 1
BASIN ELECTRIC POWER
LARAMIE RIVER 2
BASIN ELECTRIC POWER
LARAMIE RIVER 3
BIG RIVERS ELECTRIC
D.B. WILSON 1
BIG RIVERS ELECTRIC
GREEN 1
BIG RIVERS ELECTRIC
GREEN 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
CINCINNATI GAS 8 ELECTRIC
EAST BEND 2
COLORADO UTE ELECTRIC
CRAIG 1
COLORADO UTE ELECTRIC
NEW OR C
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
:APACITY
MW
179.
179.
98.
98.
119.
285.
126.
195.
195.
225.
670.
440.
570.
570.
570.
440.
242.
242.
416.
617.
650.
455.
455.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
LIMESTONE
M.W. KELLOGG
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIME/SPRAY DRYING
BABCOCK t WILCOX
LIME
M.W. KELLOGG
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIMESTONE
ENVIRONEERING, RILEY STOKER
DUAL ALKALI
GE ENVIRONMENTAL SERVICES
LIME
BABCOCK t WILCOX
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
START-UP
DATE
9/78
6/79
8/78
6/79
10/73
4/78
3/81
11/79
11/79
11/79
10/82
5/83
7/80
7/81
11/82
9/84
12/79
11/80
7/76
9/79
3/81
10/80
12/79
PEABODY PROCESS SYSTEMS
8-1
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 8
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
COLORADO UTE ELECTRIC
CRAIG 3
COLUMBUS 8 SOUTHERN OHIO ELEC
CONESVILLE 5
COLUMBUS & SOUTHERN OHIO ELEC
CONESVILLE 6
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
COOPERATIVE POWER ASSOCIATION
COAL CREEK 2
DELMARVA POWER t LIGHT
DELAWARE CITY 1
DELMARVA POWER t LIGHT
DELAWARE CITY 2
DELMARVA POWER ft LIGHT
DELAWARE CITY 3
DESERET GEN & TRANS
BONANZA 1
DUQUESNE LIGHT
ELRAMA 1-4
DUQUESNE LIGHT
PHILLIPS 1-6
EAST KENTUCKY POWER
SPUR LOCK 2
GRAND HAVEN BRD OF LIGHT ft PWR
J.B. SIMS 3
HOOSIER ENERGY
MEROM 1
HOOSIER ENERGY
MEROM 2
HOUSTON LIGHTING t POWER
W.A. PARISH 8
INDIANAPOLIS POWER & LIGHT
PETERSBURG 3
KANSAS CITY POWER ft LIGHT
LA CYGNE 1
KANSAS POWER ft LIGHT
JEFFREY 1
KANSAS POWER ft LIGHT
JEFFREY 2
KANSAS POWER ft LIGHT
JEFFREY 3
KANSAS POWER ft LIGHT
LAWRENCE 4
KANSAS POWER ft LIGHT
LAWRENCE 5
NEW OR CAPACITY
RETROFIT MW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
447.
350.
350.
327.
327.
60.
60.
60.
410.
510.
408.
500.
65.
441.
441.
492.
532.
874.
540.
540.
540.
125.
420.
PROCESS/
SYSTEM SUPPLIER
LIME/SPRAY DRYING
BABCOCK ft WILCOX
LIME
AIR CORRECTION DIVISION, UOP
LIME
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
MELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
LIMESTONE
COMBUSTION ENGINEERING
LIME
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
LIME
THYSSEN/CEA
LIME
BABCOCK ft WILCOX
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
BABCOCK ft WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
START-UP
DATE
6/84
1/77
6/78
7/79
7/80
5/80
5/80
5/80
9/84
10/75
7/73
12/82
5/83
8/82
12/81
10/82
12/77
12/72
8/78
1/80
5/83
1/77
4/78
8-2
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 8
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
KENTUCKY UTILITIES
GREEN RIVER 1-3
LAKELAND UTILITIES
MCINTOSH 3
LOUISVILLE GAS * ELECTRIC
CANE RUN 4
LOUISVILLE GAS & ELECTRIC
CANE RUN 5
LOUISVILLE GAS 4 ELECTRIC
CANE RUN 6
LOUISVILLE GAS 4 ELECTRIC
MILL CREEK 1
LOUISVILLE GAS 8 ELECTRIC
MILL CREEK 2
LOUISVILLE GAS & ELECTRIC
MILL CREEK 3
LOUISVILLE GAS & ELECTRIC
MILL CREEK 4
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN 6
MARQUETTE BOARD OF LIGHT 4 PMR
SHIRAS 3
MICHIGAN SO CENTRAL PWR AGENCY
PROJECT 1
MINNESOTA POWER & LIGHT
CLAY BOSWELL 4
MINNKOTA POWER
MILTON R. YOUNG Z
MONONGAHELA POWER
PLEASANTS 1
MONOHGAHEU POWER
PLEASANTS 2
MONTANA POWER
COLSTRIP 1
MONTANA POWER
COLSTRIP 2
MONTANA POWER
COLSTRIP 3
MONTANA-DAKOTA UTILITIES
COYOTE 1
MUSCATINE POWER & WATER
MUSCATINE 9
NEVADA POWER
REID GARDNER 1
NEVADA POWER
REID GARDNER 2
NEW OR CAPACITY
RETROFIT MW
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
65.
364.
188.
200.
299.
358.
350.
427.
495.
72.
44.
55.
475.
374.
626.
626.
360.
360.
778.
440.
166.
125.
125.
PROCESS/
SYSTEM SUPPLIER
LIME
AMERICAN AIR FILTER
LIMESTONE
BABCOCK 4 WILCOX
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
DUAL ALKALI
THYSSEN/CEA
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
GE ENVIRONMENTAL SERVICES
LIMESTONE
BABCOCK 4 WILCOX
LIME/ALKALINE FLYASH
PEABODY PROCESS SYSTEMS
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIME
BABCOCK & WILCOX
LIME
BABCOCK 4 WILCOX
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIME/ALKALINE FLYASH
BECHTEL/MONTANA POWER
SODIUM CARBONATE/SPRAY DRYING
WHEELABRATOR-FRYE/R.I.
LIMESTONE
RESEARCH-COTTPELL
SODIUM CARBONATE
THYSSEN/CEA
SODIUM CARBONATE
THYSSEN/CEA
START-UP
DATE
9/75
7/82
8/76
12/77
4/79
12/80
12/81
8/78
7/82
4/73
3/83
5/83
2/80
9/77
12/76
10/80
9/75
5/76
10/83
4/81
4/83
3/74
4/74
8-3
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 8
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
NEVADA POWER
REID GARDNER 3
NEVADA POWER
REID GARDNER 4
NEW YORK STATE ELEC & GAS
SOMERSET 1
NIAGARA MOHAWK POWER
CHARLES R. HUNTLEY 66
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
NORTHERN STATES POWER
RIVERSIDE 6-7
NORTHERN STATES POWER
SHERBURNE 1
NORTHERN STATES POWER
SHERBURNE 2
PACIFIC POWER i LIGHT
JIM BRIDGER 4
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
PENNSYLVANIA POWER
BRUCE MANSFIELD 3
PHILADELPHIA ELECTRIC
CROMBY 1
PHILADELPHIA ELECTRIC
EDDYSTOHE 1
PHILADELPHIA ELECTRIC
EDDYSTONE 2
PLATTE RIVER POWER AUTHORITY
RAWHIDE 1
PUBLIC SERVICE INDIANA
GIBSON 5
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 2
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 4
SALT RIVER PROJECT
CORONADO 1
SALT RIVER PROJECT
CORONADO 2
NEW OR CAPACITY
RETROFIT MW
NEW
NEW
NEW
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
125.
250.
625.
100.
391.
110.
750.
750.
550.
917.
917.
917.
150.
240.
334.
279.
670.
361.
350.
534.
534.
320.
320.
PROCESS/
SYSTEM SUPPLIER
SODIUM CARBONATE
THYSSEN/CEA
SODIUM CARBONATE
THYSSEN/CEA
LIMESTONE
PEABODY PROCESS SYSTEMS
AQUEOUS CARBONATE/SPRAY DRYING
ROCKWELL INTERNATIONAL
DUAL ALKALI
FMC
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
LIME
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
LIME
M.W. KELLOGG
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
M.W. KELLOGG
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
LIMESTONE
M.W. KELLOGG
LIMESTONE
M.W. KELLOGG
START-UP
DATE
6/76
6/83
7/84
4/82
4/83
11/80
3/76
3/77
9/79
12/75
7/77
6/80
10/82
9/82
11/82
12/83
10/82
4/78
8/78
12/79
5/82
11/79
7/80
8-4
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 8
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
SAN MIGUEL ELECTRIC
SAN MIGUEL 1
SEMINOLE ELECTRIC
SEMINOLE 1
SEMINOLE ELECTRIC
SEMINOLE 2
SIKESTON BRD OF MUNICIPAL UTIL
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
CROSS 2
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 2
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 3
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 4
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR. 1
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR. 2
SOUTHERN ILLINOIS POWER
MARION 4
SOUTHERN INDIANA GAS & ELEC
A.B. BROWN 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
SPRINGFIELD WATER, LIGHT & PWR
DALLMAN 3
SUNFLOWER ELECTRIC
HOLCOMB 1
TENNESSEE VALLEY AUTHORITY
PARADISE 1
TENNESSEE VALLEY AUTHORITY
PARADISE 2
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 8
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
TEXAS POWER t LIGHT
SANOOW 4
TEXAS UTILITIES
MARTIN LAKE 1
TEXAS UTILITIES
NEW OR C
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
IAPACITY
MW
400.
620.
620.
235.
450.
140.
280.
280.
124.
124.
184.
265.
194.
205.
347.
704.
704.
575.
550.
400.
382.
595.
595.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
ENVIRONEERING, RILEY STOKER
LIMESTONE
ENVIRONEERING. RILEY STOKER
LIMESTONE
BABCOCK t WILCOX
DUAL ALKALI
FMC
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
RESEARCH-COTTRELL
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
START-UP
DATE
8/81
5/83
9/84
6/81
10/83
7/77
7/80
7/81
6/78
6/79
4/79
3/79
4/77
10/80
7/83
5/83
7/83
3/81
5/77
11/82
12/80
4/77
5/78
MARTIN LAKE
RESEARCH-COTTRELL
8-5
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 8
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME
TEXAS UTILITIES
MARTIN LAKE
TEXAS UTILITIES
MONTICELLO
NEW OR CAPACITY PROCESS/
UNIT NO. RETROFIT MW SYSTEM SUPPLIER
3
3
UNITED POWER ASSOCIATION
STAHTON 1A
UTAH POWER & LIGHT
HUNTER
UTAH POWER S LIGHT
HUNTER
UTAH POWER & LIGHT
HUUTER
UTAH POWER t LIGHT
HUNTINGTON
UTAH POWER & LIGHT
NAUGHTON
WEST PENN POWER
MITCHELL
1
Z
3
1
3
33
NEW 595. LIMESTONE
RESEARCH-COTTRELL
NEW 800. LIMESTONE
GE ENVIRONMENTAL SERVICES
NEW 50. LIME/SPRAY DRYING
RESEARCH-COTTRELL
NEW 360. LIME
GE ENVIRONMENTAL SERVICES
NEW 360 . LIME
GE ENVIRONMENTAL SERVICES
NEW 400. LIMESTONE
GE ENVIRONMENTAL SERVICES
NEW 366. LIME
GE ENVIRONMENTAL SERVICES
RETROFIT 330. SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
RETROFIT 300. LIME
GE ENVIRONMENTAL SERVICES
START-UP
DATE
2/79
5/78
7/82
3/79
6/80
4/83
5/78
9/81
8/82
TOTAL
47255.
8-6
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 9
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
BASIN ELECTRIC POWER
ANTELOPE VALLEY 2
GRAND RIVER DAM AUTHORITY
GRDA Z
HOUSTON LIGHTING & POWER
LIMESTONE 1
HOUSTON LIGHTING ft POWER
LIMESTONE Z
INDIANAPOLIS POWER t LIGHT
PETERSBURG 4
JACKSONVILLE ELEC AUTHORITY
ST. JOHNS RVR PWR PRK 1
JACKSONVILLE ELEC AUTHORITY
ST. JOHNS RVR PWR PRK Z
LOS ANGELES DEPT OF WTR t PWR
INTERMOUNTAIN 1
LOS ANGELES DEPT OF WTR & PWR
INTERMOUNTAIN ^
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT 3
MONTANA POWER
COLSTRIP 4
NORTHERN INDIANA PUB SERVICE
SCHAHFER 18
NORTHERN STATES POWER
SHERBURNE 3
ORLANDO UTILITIES COMMISSION
C.H. STANTON 1
PACIFIC POWER t LIGHT
JIM BRIDGER Z
PLAINS ELECTRIC G 1 T
PLAINS ESCALANTE 1
SIERRA PACIFIC POWER
VALMY 2
SOUTHERN INDIANA GAS & ELEC
A.B. BROWN 2
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS 1
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY 1
TAMPA ELECTRIC
BIG BEND 4
NEW OR C
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
:APACITY
MW
745.
745.
440.
520.
750.
750.
530.
612.
612.
820.
820.
451.
778.
391.
610.
465.
550.
233.
276.
265.
720.
720.
458.
PROCESS/
SYSTEM SUPPLIER
LIME
BABCOCK t WILCOX
LIME
BABCOCK I WILCOX
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
FLAKT
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
COMBUSTION ENGINEERING
LIME/ALKALINE FLYASH
BECHTEL/MONTANA POWER
DUAL ALKALI
FMC
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
COMBUSTION ENGINEERING
SODIUM CARBONATE
BABCOCK t WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
ROCKWELL INTERNATIONAL
DUAL ALKALI
FMC
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
RESEARCH-COTTRELL
START-UP
DATE
10/64
10/84
11/85
3/85
12/85
12/86
3/86
4/87
10/68
7/86
7/87
11/87
10/85
6/86
0/88
0/87
0/86
10/84
6/85
1/85
12/85
12/84
1/85
9-1
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 9
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME
NEW OR CAPACITY PROCESS/
UNIT NO. RETROFIT MW SYSTEM SUPPLIER
START-UP
DATE
TUCSON ELECTRIC POWER
SPRINGERVILLE
WEST TEXAS UTILITIES
OKLAUNION
NEW
NEW
370. LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
504. LIMESTONE
GE ENVIRONMENTAL SERVICES
2/85
9/86
TOTAL
14335.
9-2
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
SECTION 10
SUMMARY OF CONTRACT AWARDED FGD SYSTEMS
COMPANY NAME/
UNIT NAME
CAJUN ELECTRIC POWER
OXBOW
CENTRAL POWER ft LIGHT
COLETO CREEK
EAST KENTUCKY POWER
J.K. SMITH
NEW OR CAPACITY
UNIT NO. RETROFIT MW
NEW
1
NEW
2
NEW
1
HOUSTON LIGHTING ft POWER NEW
MALAKOFF 1
HOUSTON LIGHTING ft POWER NEW
MALAKOFF 2
KENTUCKY UTILITIES
HANCOCK
PACIFIC POWER ft LIGHT
JIM BRIDGER
PACIFIC POWER ft LIGHT
JIM BRIDGER
PACIFIC POWER ft LIGHT
WYODAK
SOUTH CAROLINA PUBLIC
CROSS
TEXAS POWER ft LIGHT
TWIN OAKS
TEXAS POWER ft LIGHT
TWIN OAKS
TEXAS UTILITIES
FOREST GROVE
TEXAS UTILITIES
MARTIN LAKE
TUCSON ELECTRIC POWER
SPRINGERVILLE
NEW
1
RETROFIT
1
RETROFIT
3
RETROFIT
1
SERVICE NEW
1
NEW
1
NEW
2
NEW
1
NEW
4
NEW
2
540.
720.
650.
690.
690.
650.
550.
550.
330.
450.
750.
750.
750.
750.
370.
PROCESS/
SYSTEM SUPPLIER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME
BABCOCK ft WILCOX
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
BABCOCK ft WILCOX
SODIUM CARBONATE
BABCOCK ft WILCOX
SODIUM CARBONATE
BABCOCK ft WILCOX
LIME/SPRAY DRYING
JOY/NIRO
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
WHEELABRATOR AIR POLTN. CNTRL.
LIMESTONE
RESEARCH-COTTRELL
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
START-UP
DATE
99/99
10/93
0/92
12/89
12/90
10/93
0/90
0/88
0/86
5/91
8/89
8/91
0/88
0/89
2/89
TOTAL
9190.
10-1
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
SECTION 11
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT
LETTER OF INTENT
IOWA ELECTRIC LIGHT & PWR
GUTHRIE CO. 1
MIDDLE SOUTH UTILITIES
WILTON 1
MIDDLE SOUTH UTILITIES
WILTON 2
TOTAL
REQUESTING/EVALU
BOSTON EDISON
NEW BOSTON 1
BOSTON EDISON
NEW BOSTON Z
LOUISVILLE GAS & ELECTRIC
TRIMBLE COUNTY 1
LOUISVILLE GAS t ELECTRIC
TRIMBLE COUNTY Z
TOTAL
CONSIDERING FGD
ARIZONA PUBLIC SERVICE
CHOLLA 5
ATLANTIC CITY ELECTRIC
CUMBERLAND 1
BASIN ELECTRIC POWER
ANTELOPE VALLEY 3
CENTRAL MAINE POWER
SEARS ISLAND 1
CINCINNATI GAS ft ELECTRIC
EAST BEND 1
CINCINNATI GAS ft ELECTRIC
ZIMMER 1
COOPERATIVE POWER
N/D 1
DELMARVA POWER ft LIGHT
VIENNA 9
DESERET GEN ft TRANS
BONANZA 2
FLORIDA POWER ft LIGHT
MARTIN 3
FLORIDA POWER t LIGHT
MARTIN 4
GENERAL PUBLIC UTILITIES
NEW OR
NO. RETROFIT
SIGNED
NEW
NEW
NEW
ATING BIDS
NEW
NEW
NEW
NEW
SYSTEMS
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW
720.
890.
890.
2500.
388.
388.
575.
575.
1926.
126.
330.
560.
600.
650.
1386.
750.
550.
410.
800.
800.
690.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
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
LIMESTONE
VENDOR NOT SELECTED
LIME/SPRAY DRYING
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
START-UP
DATE
99/99
99/99
99/99
10/87
6/88
7/87
7/90
0/97
99/99
0/92
11/95
0/89
0/91
0/94
0/95
0/92
0/94
0/95
0/93
VENDOR NOT SELECTED
11-1
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 11
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
GENERAL PUBLIC UTILITIES
COAL Z
INDIANAPOLIS POWER t LIGHT
PATRIOT 1
INDIANAPOLIS POWER & LIGHT
PATRIOT 2
INDIANAPOLIS POWER » LIGHT
PATRIOT 3
KENTUCKY UTILITIES
HANCOCK 2
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT 4
NEBRASKA PUBLIC POWER DISTRICT
FOSSIL III 1
NEVADA POWER
HARRY ALLEN 1
NEVADA POWER
HARRY ALLEN 2
NEVADA POWER
HARRY ALLEN 3
NEVADA POWER
HARRY ALLEN 4
PUBLIC SERVICE OF NEW MEXICO
NEW MEXICO 1
PUB. SER. CO. OF COLORADO
PAWNEE 2
SALT RIVER PROJECT
CORONADO 3
SAN ANTONIO PUBLIC SERVICE
N/D 1
SAN ANTONIO PUBLIC SERVICE
N/D 2
SAN ANTONIO PUBLIC SERVICE
N/D 3
SAN ANTONIO PUBLIC SERVICE
N/D 4
SEMINOLE ELECTRIC
TAYLOR 1
SEMINOLE ELECTRIC
TAYLOR 2
SIERRA PACIFIC POWER
THOUSAND SPRINGS 1
SIERRA PACIFIC POWER
THOUSAND SPRINGS 2
SIERRA PACIFIC POWER
THOUSAND SPRINGS 3
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW
690.
650.
650.
650.
650.
451.
650.
500.
500.
500.
500.
500.
500.
280.
500.
500.
500.
500.
620.
620.
500.
500.
500.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
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
TRONA/DRY INJECTION
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
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
START-UP
DATE
0/97
0/93
O/ 0
O/ 0
99/99
6/90
3/96
0/94
0/95
0/96
0/97
0/95
0/90
0/92
0/93
0/95
0/99
99/99
99/99
99/99
0/90
0/95
0/99
11-2
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 11
SUMMARY OF PLANNED F6D SYSTEMS
COMPANY NAME/ NEW OR
UNIT NAME UNIT NO. RETROFIT
SOUTHWESTERN ELECTRIC POWER NEW
WALKER CO. 1
SOUTHWESTERN ELECTRIC POWER NEW
WALKER CO. 2
SOUTHWESTERN PUBLIC SERVICE NEW
SOUTH PLAINS 1
TUCSON ELECTRIC POWER NEW
SPRINGERVILLE 3
WASHINGTON MATER POWER NEW
CRESTON COAL 1
WASHINGTON WATER POWER NEW
CRESTON COAL 2
WASHINGTON WATER POWER NEW
CRESTON COAL 3
WASHINGTON WATER POWER NEW
CRESTON COAL 4
WEST TEXAS UTILITIES NEW
OKLAUNION 2
WHITE PINE COUNTY NEW
WHITE PINE PWR PROJ. 1
WHITE PINE COUNTY NEW
WHITE PINE PWR PROJ. 2
CAPACITY PROCESS/
MW SYSTEM SUPPLIER
720. PROCESS NOT SELECTED
VENDOR NOT SELECTED
720. PROCESS NOT SELECTED
VENDOR NOT SELECTED
572. PROCESS NOT SELECTED
VENDOR NOT SELECTED
370. PROCESS NOT SELECTED
VENDOR NOT SELECTED
570 . LIMESTONE
VENDOR NOT SELECTED
570. LIMESTONE
VENDOR NOT SELECTED
570 . LIMESTONE
VENDOR NOT SELECTED
570. LIMESTONE
VENDOR NOT SELECTED
504. PROCESS NOT SELECTED
VENDOR NOT SELECTED
620. PROCESS NOT SELECTED
VENDOR NOT SELECTED
820. PROCESS NOT SELECTED-
VENDOR NOT SELECTED
START-UP
DATE
12/93
12/93
0/90
0/91
0/95
0/97
0/98
0/99
0/96
3/91
3/92
TOTAL
26869.
11-3
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SECTION 12
TOTAL FGD UNITS AND CAPACITY (MW) INSTALLED BY YEAR
YEAR
1968
1969
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
UNDEFINED
NEW ON LINE
NO. MW
1
0
1
10
5
4
9
7
11
15
19
20
11
17
16
9
9
7
6
5
5
7
5
5
7
3
8
3
4
1
12
2
140.
0.
80.
1548.
854.
586.
2279.
2709.
4727.
5544.
5824.
6817.
4397.
6410.
6233.
4985.
4577.
3875.
3311.
3110.
3210.
3838.
3776.
2720.
4650.
2050.
4520.
1654.
1886.
570.
7330.
1300.
TERMINATED
NO. MM
0
1
0
0
1
3
5
4
2
0
2
0
1
7
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.
140.
0.
0.
10.
340.
628.
1014.
215.
0.
143.
0.
20.
825.
100.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
TOTAL
NO.
1
0
1
11
15
16
20
23
32
47
64
84
94
104
119
128
137
144
150
155
160
167
172
177
184
187
195
198
202
203
215
ON LINE
MW
140.
0.
80.
1628.
2472.
2718.
4369.
6064.
10576.
16120.
21801.
28618.
32995.
38580 .
44713.
49698.
54275.
58150.
61461.
64571.
67781.
71619.
75395.
78115.
82765.
84815.
89335.
90989.
92875.
93445.
100775.
12-1
-------
APPENDIX A
DEFINITIONS
A-:.
-------
DEFINITIONS
Boiler Commercial Service Date
Byproduct Nature
Commercial Service Date
(FGD System)
Company Name
Disposal
Efficiency:
Total Unit Design Particle
Removal Efficiency
Total Unit SC-2 Design
Removal Efficiency
A-2
Date when boiler and auxiliary
equipment (including FGD sys-
tem for new boilers) has met
initial supplier guarantees
and begins to contribute elec-
trical power to the power
grid.
The nature (e.g. elemental
sulfur, sulfuric acid) and
disposition (e.g. stockpile on
site, marketed) of the end
product by systems that gen-
erate a saleable product.
Date when the FGD system suc-
cessfully completes compliance
testing and the utility is
satisfied that the system
meets supplier contractual
guarantees.
Name of corporation as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - as space permits.
Disposal method for throwaway
product systems producing
sludge including: interim and
final disposal sites and
disposal type (minefill,
landfill, etc.) as well as
disposal location and site
capacity.
The actual percentage of par-
ticulate matter removed by the
emission control system (me-
chanical collectors, ESP, or
fabric filter and FGD) from
the untreated flue gas.
The actual percentage of S02
removed from the flue gas by
the FGD system.
-------
FGD Viability Indexes
Availability Index
Reliability Index
Several parameters have been
developed to quantify the vi-
ability of FGD system technol-
ogy. Various terms such as
"availability," "reliability,"
"operability," and "utiliza-
tion" are used to accurately
represent the operation of any
FGD system during a given per-
iod. The above-mentioned pa-
rameters are defined below and
discussed briefly. The objec-
tives of this discussion are
to make the reader aware that
several different definitions
are being used and to select
appropriate parameters that
can be used for reporting pur-
poses so that reasonably con-
sistent comparisons can be
made.
Hours the FGD system is avail-
able for operation (whether
operated or not) divided by
hours in period, expressed as
a percentage. This parameter
tends to overestimate the vi-
ability of the FGD system be-
cause it does not penalize for
election not to operate the
system when it could have been
operated. Boiler downtime may
tend to increase the magnitude
of the parameter because FGD
failures generally cannot oc-
cur during such periods.
Hours the FGD system was oper-
ated divided by the hours the
FGD system was called upon to
operate, expressed as a per-
centage. This parameter has
been developed in order not to
penalize the FGD system for
elected outages, e.g., periods
when the FGD system could have
been run but was not run be-
cause of chemical shortages,
lack of manpower, short dura-
tion boiler operations, etc.
The main problem in using this
A-3
-------
FGD Operability Index
FGD Utilization Index
End Product
Sludge
formula is the concise determi-
nation whether or not the sys-
tem was "called upon to oper-
ate" during a given time per-
iod. In addition, an undefined
value can result when the FGD
system is not called upon to
operate for a given period
(e.g., turbine or boiler out-
age when FGD system is avail-
able) .
Hours the FGD system was oper-
ated divided by boiler operat-
ing hours in period, expressed
as a percentage. This param-
eter indicates the degree to
which the FGD system is actu-
ally used, relative to boiler
operating time. The parameter
is penalized when options are
exercised not to use the FGD
system in periods when the
system is operable. In addi-
tion, an undefined value can
result when neither the boiler
nor the FGD system is operated
for a given period (e.g., tur-
bine or boiler outage when FGD
system is available).
Hours that the FGD system op-
erated divided by total hours
in period. This parameter is
a relative stress factor for
the FGD system. It is not a
complete measure of FGD system
viability because the parameter
can be strongly influenced by
conditions that are external
to the FGD system (e.g., in-
frequent boiler operation will
lower the value of the parame-
ter although the FGD system
may be highly dependable in
its particular application).
The S02 removed from the flue
gas is not recovered in a us-
able or marketable form and
resulting sulfur-bearing waste
A-4
-------
Recoverable Byproduct
Energy Consumption, %
Equivalent Scrubbed Capacity
(ESC)
FGD Status:
Category 1
Category 2
Category 3
Cateogry 4
Category 5
products must be disposed in
an environmentally acceptable
fashion.
The SC-2 removed from the flue
gas is recovered in a usable
or marketable form (e.g., sul-
fur, sulfuric acid, gypsum,
ammonium sulfate, sodium sul-
fate).
The percentage of gross unit
electrical generating capacity
consumed by the FGD system, as
defined by the following equa-
tion:
[Net MW w/o FGD - Net MW w/FGD]/
[Gross unit rating]
The effective scrubbed flue
gas in equivalent MW based on
the percent of flue gas scrubbed
by the FGD system.
Operational - FGD system is in
service removing S02.
Under construction - ground
has been broken for installa-
tion of FGD system, but FGD
system has not become opera-
tional .
Planned, Contract Awarded -
contract has been signed for
purchase of FGD system but
ground has not been broken for
installation.
Planned, Letter of Intent
Signed - letter of intent has
been signed, but legal con-
tract for purchase has not
been awarded.
Planned, Requesting/Evaluating
Bids - bid requests have been
released but no letter of in-
tent or contract has been is-
sued.
A-5
-------
Category 6
Category 7
Category 8
Fuel Firing Rate - TPH
Initial Start-Up (FGD System)
NA
N/A
NR
New
Plant Name
Process Additives
Considering only FGD Systems -
an FGD system is proposed as a
means to meet an S02 regula-
tion.
Considering an FGD system as
well as alternative methods.
Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended in-
definite period of time.
Boiler fuel firing rate in
terms of tons per hour at max-
imum continuous load.
Date when flue gas first
passes through any component
of the FGD system (or is
scheduled to do so).
Not available - early status -
information not known at this
time.
Not applicable.
Not reported - the information
is known but for one reason or
another has not been reported
by the utility.
FGD unit and boiler were de-
signed at the same time or
space for addition of an FGD
unit was reserved when boiler
was constructed.
Unit identification as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - or as indicated by
utility representative for in-
stallations in planning stages.
A chemical compound or element
which is added to the process
or normally found with the
main process reagent in small
A-6
-------
Process Type
Regulatory Class
Retrofit
S02 Removal Mode
Spare Capacity Index - %
quantities (e.g., Mg, adipic
acid) to promote improved
process operation (e.g., scale
reduction, increased S02 re-
moval efficiency).
Company name if process is
patented. Generic name if
several companies have similar
processes (e.g., Lime, Lime-
stone, Wellman Lord, Thorough-
bred 121) .
A. Unit(s) subject to stan-
dard (s) more stringent
than NSPS (6/79).
B. Unit(s) subject to Fedei—
al New Source Performance
Standards (NRPS) promul-
gated in June 1979.
C. Unit(s) subject to stan-
dard (s) more stringent
than NSPS (12/71),'but
not more stringent than
NSPS (6/79).
D. Unit(s) subject to Feder-
al New Source Performance
Standards (NSPS) promul-
gated in December 1971.
E. Unit(s) subject to stan-
dard (s) equal to or less
stringent than NSPP
(12/71).
FGD unit will be/was added to
an existing boiler not specif-
ically designed to accommodate
FGD unit.
The manner in which the SC>2
from the flue gas is collected,
e.g., wet scrubbing, spray
drying, dry adsorption.
The summation of the individ-
ual component capacities (%)
minus 100%.
A-7
-------
Spare Component Index
System Supplier
Total Controlled Capacity (TCC)
Unit Rating
Gross
Net w/FGD
Net w/o FGD
The equipment spare capacity
index (%) divided by the indi-
vidual component capacity (%) .
A firm that fabricates and
supplies flue gas desulfuriza-
tion systems.
The gross rating (MW) of a
unit brought into compliance
with FGD, regardless of the
percent of flue gas treated at
the facility. In the case of
prototype and demonstration
FGD systems, this figure will
be identical to the Equivalent
Scrubbed Capacity rather than
the gross unit rating if the
system is not meant to bring
the facility into compliance
with S02 emission standards.
Operational - Maximum contin-
uous gross generation capacity
in MW; Preoperational - maxi-
mum continuous design genera-
tion capacity in MW.
Gross unit rating less the
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.
A-3
-------
APPENDIX B
TABLE OF UNIT NOTATION
B-l
-------
TABLE OF UNIT NOTATION
Classification
Area
Concentration
Flow
W
1
to
Heat Content
Length
L/G Ratio
Mass/Weight
Pressure
Temperature
Volume
English Unit
Acre
Square foot
Grains per standard
cubic foot
Parts per million
Pounds per million
Btu
Actual cubic feet
per minute
Gallons per minute
Pounds per minute
Ton per day
Ton per hour
Btu per pound
Foot
Inch
Mile
Gallons per
thousand actual
cubic feet
Pound
Ton
Inches of water
Degree Fahrenheit
Cubic feet
Acre-feet
Pymbol
acre
ft?
gr/scf
ppm
lb/10 Btu
ft /m i n
(actual )
gal/min
1 b/mi n
t/day
t/h
Btu/lb
ft
in
mi
gal/1000
ft^
(actual )
Ib
t
in. H20
•F
ft3
Acr
-------
APPENDIX C
FGD PROCESS FLOW DIAGRAMS
C-l
-------
n
i
NJ
"in ntctcit
HOT T0!«l)
UNtSTWt 51UHK
I mo toi«i)
\ / "*suJ
» - »B50«B[I WCYClt PUWS - ' ''v™1
IT rwws — ' (siiPKUNii) „»,„
\
\
WS TO STUCK
(PCX UKIT ]
ll"tSTO« SIU»«T
10 U«IT 3
'010
Alabama Electric,
Simplified Process Flow Diagram for Tombigbee 2 and 3
-------
O
SINGLE LOUVER
DAMPER
DOUBLE LOUVER
DAMPER
I.D. FAN
. TO DISPOSAL POND
TO PROCESS
SEAL WATER
(SERVICE WATER)
SLURRY
SUMP PIT
SEAL WATER
1 BOOSTER
1 PUMPS
-— SLURRY
SUMP PUMPS
QUENCHER
PUMPS \
\*~A
ABSORBER
TOWER
CYCLONES
TIDiUCES
nr^'-T-trir
STACK
DOUBLE -BLADED
GUILLOTINE
DAMPER
r-
ii *i
YY LIQUID
ABSORBER
FEED TANK
'
TOTAL PROCESS
HAKE-UP WATER
(COOLING TOWER
SLOWDOWN)
-» TO UNIT NO. 3
— FROM UNIT NO. 3
-»• TO UNIT NO. 3
-»• TO UNIT NO. 3
MET LIMESTONE
GRINDING SYSTEM
-»• TO UNIT NO. 3
ABSORBER REAGENT
FEED PUMPS
Arizona Electric Power Coop, Apache 2 and 3
Process Flow Diagram
-------
lOUVCI
n
i
1—
^
„
STUB
•
/
/
L-^-J
.. I LOUYtK
H
r r^-5U-
a«
IM
PMTICUIMI
KHIUII
DS
|^
1
1
[ iUItU TMK | | UfU
>-< HUW1
HOSUI CUIUOTM
ru
Arizona Public Service, Cholla 1 :
Simplified Process Flow Diagram
-------
MECNAMICAL
DUST COLLECTOR
II ILOUVEI I ILOUVFI
JJpiwi PDAMMI
n
— •• ».
FLUT CAS
ta
n— '"J
LJ IflOSTf*
IMS
FLOODED
DISC
SCIUME
IENEATEI
rV^=-"
<__\ ^
»«cm*
TO M«STt
DISPOSAL
mi
4 LIQUID
CTCLONES
NktEUr
Do
Tl.
ABSOKttS
FEU TAM
AiSOKIE"
FEED rw
SCIMI0
FEED »!»•
AISMtEl
TOHEI
LIICSTOMI
STORA6E
fEtDO
o-o
MCRM 'I"""
^~4L TO KHS1
J^^~" OJS^OSA
s
FEED
KT
REMEKT FEED TAW
ll- 1
MLL HIU
l_
r
"
1| 1
HILL tLM
b1
HILL SLUWT
•mi
Arizona Public Service, Choi!a 2:
Simplified Process Flow Diagram
C-5
-------
o
en
»ru I ' I fS
'!""' 1/21
»«>•, ' ' tV
Central Illinois Light,
Simplified Process Flow Diagram of Duck Creek 1
Power Plant and Emission Control System
-------
n
i
1 BOOSTER FAN
2 CHLORIDE/FLYASH PRECOOLER
3 FLYASH THICKENER
4 ABSORBER
5 NEUTRALIZE
6 REACTOR-CLARIFIER
7 CAUSTICIZERS
8 THICKENER
9 HORIZONTAL BELT FILTER
10 REHEAT FACILITY (EXPERIMENTAL)
STACK
WATER
•
SODA ASH|
(MAKEUP)
SODA ASH
(MAKEUP)
CaS03/CaS04
SOLIDS
r
v
1 ,
Central Illinois Public Service, Newton 1:
Simplified Process Flow Diagram Showing One of Four Absorbers
-------
MKEUP HATER
(POND MATER)-
-»• TO STACK - FLUE GASES
y ) ti >i >.
MIST ELIMINATOR
FROM ESP -
FLUE GASES
LINt FROH
STORAGE
SERVICE
HATER
n
I
00
••TO fUCS
Columbus and Southern Ohio Electric, Conesville 5 and
Simplified Process Flow Diagram for a Riven Module
-------
To Stack
O
vo
From
Precipitator
Mist Eliminator
M.E. Wash Mal"? Up
Flyash Silo
Lime Silo
Flyash Wet'G
Tank
Flyash Feeder
Make Up
I
--:
-v*i
Lime
^ Bleed Feed Pumps
>-
(
e
(
3
] ,_ dtf Li
fH I
i_ limt
Lim«
Feeder
Lime
Slaker
Reaction Tank
In-Tank
Strainer
Lime
Feed Tank
To Disposal
Cooperative Power Association, Coal Creek 1 and 2:
Simplified Process Flow Diagram
-------
o
i
Flue gas
from boilers
Makeup from
overflow
pumps ~
Bleed 10
thickener -^
and clorifier
To thickener trough
Adjustable
throat
dampers
Damper
operator
housing
Sproy
water qas
Mist eliminator
Combustion
air
To thickener
Lime slurry feed line
Service water
I »
IT""*.
Q. . -+
(o
1
H«k
Lime
storage
silo
Vibrator
weigh
feeder
I
t
I
T
Lime
slurry
lank
Lime stoker
Lime slurry
pump
Duquesne Light, Elrama 1-4: Simplified Process Flow Diagram
-------
o
I
1ST STAGE
ADJUSTABLE VENTURI
FOR FLY ASII/SO,
2ND STAGE
ABSORBER SCRUBBER
X
RECYCLE RETURN SYSTEM
CaS03/S04
FLY ASH SLURRY
RETURN_TO_P_OND
Lr_=|.
'THICKENE
ASH POND
TO
STABILIZATION
FACILITIES
Duquesne Light, F. R. Phillips FGD System:
General Diagram.
-------
FROM DISPOSAL POND
FLUE GAS
FROM PLANT
ISOLATION
0/WPER
O
I
REHEATER
NO. ? FUEL OIL
SURGE
TANK
(EXISTING
V-103 I Y-103
EPRI SYST.
FLANGED
CONNECTION TO
CLIENT'S DUCT
THICKENER
HOLD PUMP
I I
I I
•*- i THICKENER
T--,HOLD TANK
- SODA ASH
VIBRATING
HOPPER
O SODA ASH
r1 ' - 1 HEIGH
— . FEEDER
REACTOR NO. I
AND AGITATOR REACTOR NO. ?
AND AGITATOR REACTOR NO. 3
AND AGITATOR
FILTER CAKE
WASH MATER
ADDITIONAL S0? INJECTION
SODA ASH
TANK 1
AGITATOR
REACTOR NO. 4
AND AGITATOR
REACTOR NO. 5
AND AGITATOR
Gulf Power, Scholz 1:
Simplified Process Flow Diagram of the Demonstration
Soda Ash/Limestone Dual Alkali Process
-------
AIR
HEATER
AMBIENT
AIR FAN
MIST
ELIMINATOR
MOBILE PACKING
PRE-SATURATION SPRAY
FLUE GAS IN
Tn c;TnRAr,F ARFA
CLEAN GAS OUT TO STACK
MIST ELIMINATOR
WASH
WASTE
SLURRY TANK
PUMP
Indianapolis Power and Light, Petersburg 3:
Simplified Process Flow Diagram for One of Four Absorbers
C-13
-------
STACK
D. FAN
COAL
SUPPLY
o
i
STACK GAS
REHEATER
AIR HEATER
.DEMISTER
STACK GAS
SCRUBBER
PULVERIZER
LIME
PREPARATION
TANK
CLARIFIER
RECYCLE
PUMP
Kansas City Power and Light, Hawthorn Units 3 and 4:
Simplified Process Flow Diagram of the Lime Scrubbing Process
MAKE UP
WATER
TO ASH DISPOSAL
POND
-------
o
i
M
Ul
ABSORBER
REJCIRCULATION
PUMPS
VENTURI
RECIRCULATION
PUMPS
LIMESTONE
SLURRY
STORAGE'
160 ACRE
SETTLING POND
BOILER
WET BALL
MILL
Kansas City Power and Light,
LaCygne 1 FGD System: General Diagram
-------
FURNACE
DAMPERS
TWO PRECIPITATORS
o
. i
H
cn
FOUR I.D. FANS
ONE
STACK
WATER RETURN TO
REACTION TANKS
BLEED PUMP
FOUR
REACTION
TANKS
SLUDGE DISPOSAL
POND
Kansas Power and Light,
Schematic of Jeffrey Steam Generator and Emission Control Equipment
-------
LIMESTONE
•mnnra
CRUSHED
LIMESTONE
BUCKET
[LEVATOR
wrriH
x/
— v
FEEDER \
MAUN (OR
SLURR»ING
1 SCALPING
f^P SCREEN
V
^ADDITUE
TRANSFER
PUMPS
1 BALI L
| Mill ft
MIIER
n /*
1 J/'
c*o
DOITUE SIOMU
INK U SOLIDS
^T[
~~"ADOHIM LJ
OIIUIION UAIIR
(FIOM RECIRCUIMION !•««)
SUMP
SlURRf PUMPS
STORAGE
PUMPS
10 OTHER
SCRURICR WOU.I
o
M
-O
STACK I POND RETURN
(MAKE-UP)
I WATER
I ' T THICKENER |~0\
l-^U^i — I
WEIR
OVERFLOW
\^P - »• SETTLING
THINNER PONO
UNDERFLOW PUMPS
Kansas Power and Light,
Lawrence 4 Operational FGD System:
Simplified Process Flow Diagram
-------
LlKSTMt «Tt«
DIIUTIW tt»UI> (HI
STOMGC KCIHClMtlOl" TUi
T»H> (0 SOLIDS
o
I
I-1
oo
WOITHI
DILUTION
EC. IH.
i ADOIT(JI[
~5*
SCBUBBFC
MODULI
r~ — ~~
T
F
*
ADDITIVE
(FROM HILL)
/
L
0 STACK /
B
LUE GAS t
UR PREHE)
tDOITIVE
FEED
PUMPS(2)
ONE OF TUO NODULES
OUTLET
1.0. FANS (2) J~
. ' L.
rPASS ^ ^
RON
UER
^
t
1
.IN.
'^X
INLET \
DAMPER \
w
«
ll
MAKEUP I-.
"" Ji
ROO SCRUBBER [!<•
SPRAY PUMP ,| |
' is
DAMPER
— A J pREHEATER
KN
B-E-S- .,3^ NIST ELIMINATOR
r inn BLOWFR
ABSORBER STRAINER HASHER
/(TYP.)
STRAINER HASH
f LINE (TYP 1 - - „ _
' J n 1
fll 1? I *BSORBE*
It III SPWT Pl**
*» JL;J
lEACTION !.
TANK ll —0
TRAINERS:
u
1 ADDITIVE QCW«INUTO«
STORAGE TANK 1
EFFIUFMTQ
BLEED H
"» J__TOPO«
Kansas Power and Light,
Lawrence 5 Operational FGD System:
Simplified Process Flow Diagram
-------
o
I
I-1
vo
ELECTRICAL
GENERATING
UNIT NO. 2
ELECTRICAL
GENERATING
UNIT NO. 1
MAKEUP HATER
MAKEUP MATER
SPARE
Kentucky Utilities,
Green River FGD System: General Process Diagram
-------
QUENCHER
MIST
ELIMINATOR
(CHEVRON)
CONTACTOR
SCRUBBER
~- MODULE
ELECTROSTATIC
PRECIPITATOR
REACTION
TANK
BOILER
FLUE
GAS
O
I
N)
O
CONTACTOR
SCRUBBER
MODULE
MIST
ELIMINATOR
(CHEVRON)
Louisville Gas and Electric, Cane Run 4
FGO System: Simplified Process Flow Diagram
-------
o
to
H
IN LINE REHEATER (STEAM)
I.D. BOOSTER FANS
TO STACK
BYPASS
ESP'S
HIST ELIMINATOR
P MIST ELIMINATOR WASH
— —
-BULK ENTRAPMENT
SEPARATOR
*-SPRAY TOWER ABSORBERS
CRUSHER-
DISINTEGRATOR!
SPRAY PUMPS
OK
IN-TANK STRAINER
oUil
-------
COMBUSTION AIR
EXISTING
FAN T, I
Louisville Gas and Electric, Cane Run 6
Dual Alkali FGD System: Simplified Process Flow Diagram
C-22
-------
IN LINE REHEATER (STEAM)
l.D. BOOSTER FANSi
TO STACK-- 1
.
n
w ESP'S
-i
^
fU
BYPASS
I
"-^
i
1
\ •- \
SPRAY PUMPS
~>
~\
<.J
i
3
6
\—
n
•?
m m « jr
**•.
t
-i
IN-TANK STRAINER
• - - -
5 — y^
ii
.'MIST ELIMINATOR
9 MIST ELIMINATOR WASH
tJo '
*^-BULK ENTRA1NMENT
SEPARATOR CRUSHER- (->
FROM LIME
STORAGE TANK
*• SPRAY TOWER ABSORBERS n 1
a
3C3
A
_&
r
LIME O
FEED PUMPS
c:
^
9EFFLUENT BLEED
J REACTION TANK
LIME FEEDTANK
OVERFLOW
1
THICKNER |
— -~_^_ ^ ' orryri i
\JT
MAK
WA
0-
EUP
fER
•
\L^
"fc^* ***•*• HI- rTi
DUMPC "tL'V
M.E.WASH
Lt PUMP
O. •-"' TANK
rn niconcoi- DUNDERFLOW PUMPS
Louisville Gas and Electric,
Mill Creek 1 and 2 FGD System:
Simplified Process Flow Diagram
-------
GAS 10 STACK
o
GAS REHEATERS
HIST ELIMINATOR
WASHERS
Ml CA(OM)2
ADDITIVE SYSTEM
GAS INLET
Louisville Gas and Electric,
Paddys Run 6 FGD System:
Simplified Process Flow Diagram
-------
TREATED-GAS
DUCT
SPRAY TOWER
ABSORBER
"WET" VENTURI
SCRUBBER
Minnesota Power and Light, Clay Boswell 4:
General Diagram
C-25
-------
RCMCAT BY-MSS
•OOSTM
FAN
n
i
to
CAKC
Minnkota Power Cooperative, Milton R. Young 2:
Simplified Process Flow Diagram for One of Two Absorbers
-------
o
S02 BOOSTER FANS
FLUE GAS)
LIME FEED
SYSTEM
MIST
ELIMINATORS
uuumit
IOCLONE
I
—
U
c
' «i
D
yL
RECYCLE TANK
TO STACK
WASH TRAY
-ABSORBER TRAY
RECYCLE
LIQUOR
*- TO EMERGENCY
DUMP POND
TO DISPOSAL SITE
Monongahela Power, Pleasants 1 and 2:
Simplified Process Flow Diagram for One of Four Modules for Either Unit
-------
n
i
to
CO
FLUE
GAS
EMERGENCY WATER
PLENUM
BLEED
MIST
ELIMINATORS
STEAM
5 »-CLEAN FLUE GAS fc~ >
CXh-SEAL WATER SUPPLY
JJNDERSPRAY ^ MAKEUP
WATER
FLY ASH POND
Montana Power, Col strip 1 and 2:
Process diagram of a given FGD module.
WASH TRAY POND
POND
[RETURN
-------
TO CHIMffT
O
I
NJ
MECHANICAL
OUST
COLLECTOR
(NUITICLONES)
Nevada Power, Reid Gardner 1,2 and 3:
Process diagram of a given FGD system.
-------
DISCHARGE
TO STACK
4
I I TRAY TOWER
I I ABSORBER
CONDENSER
PRESCRUBBER
(VARIABLE-THROAT
VENTURI)
O
L-J
O
FLUE GAS FROM
UNIT #11
FLY ASH PURGE TO POND-*
TREATED
PURGE STREAM
EVAPORATOR/
SCRYSTALLIZER
REDUCTION ~n
PLANT~-®coSmssoR
CRYSTALLIZER
DRIED
SULFATE
PRODUCT
Northern Indiana Public Service,
D. H. Mitchell 11 WeiIman Lord/Allied System:
General Process Diagram.
-------
o
U)
-•:
*J
-
=•
IKWIAI
inn* ••
'•'• it » i .
l**v>J
i emu \ /\ /\ /
•«.»! 'if V/ \/ \/
.«unJ H He
IWKWSf
COLLKTIK
comtio
Simplified Process Flow Diagram
Spray Dryer Cutaway View
Northern States Power, Riverside 6,7: FGD System Flow Diagrams
-------
o
I
OJ
FLUE GAS
TO
SCRUBBER
REHEATER
LIMESTONE —i
MIST
ELIMINATOR
OVERFLOW POTS
AND MARBLE BED
THICKENER
UNDERFLOW
PUMP
ASH POND
RETURN PUMP
Northern States Power, Sherburne 1 and 2 FGD System:
Simplified Process Flow Diagram
-------
o
I
u>
to
\ 1*11 1101 IMtl t»QI«
jiL
sin iftintDiM. i
~ 0"
« - J
i««mt
r*-«Ki i«*»w«
•-"—- r"i5* ~~^^j^ ^ £""5?^_rr^_
._..._ I HKII-OISWUl SII1lllll« ««t«««_M»l Ij^J-1 Km If CWITO •'•• I ~V««
-------
FLUE GAS FROM
UPPER ESP
o
i
U)
HOT REHEAT GAS
EXHAUST PLENUM
EXHAUST
ISOLATION
DAMPERS
(4 PER UNIT)
X
FLUE GAS FROM
LOWER ESP
\
STACK INLET
DAMPERS (2)
(1 EACH SIDE)
STACK
ABSORBERS
(4 PER UNIT)
INLET
PLENUM
INLET ISOLATION
DAMPERS (4 PER UNIT)
BOOSTER FAN FLOW
CONTROL DAMPERS
(4 PER UNIT)
VENTURIS
(4 PER UNIT)
BOOSTER FANS
(4 PER UNIT)
Public Service of New Mexico, San Juan 1, 2, 3, and 4
FGD System Flue Gas Flow Path
-------
FLUE
SCRUBBER-
OUTLET
DUCTWORK
HIST
ELIMINATOR
REACTION
MIX TANK
FLUE GAS FROM
.ELECTROSTATIC
f PRECIPITATORS
INDUCED-
DRAFT FANS
BOOSTER FANS
PRESATURATOR
O
ui
ui
FROM FANS
TO STACK
»
FROM ABSORBER B
TO SEAL-WATER SYSTEM
TO FLUSH CONNECTIONS
TO ALKALI-PREPARATION SYSTEM
ABSORBER -A
OSTER
FAN
ABSORBER-B
BOOSTER FAN
LIMESTONE-SLURRY
MAKEUP
FROM ABSORBER B
FLOCCULENT
ADDITION
TO
ABSORBER B
TO SLUDGE
STORAGE TANKS
Salt River Project, Coronado 1 and 2 FGD System:
Simplified Process Flow Diagram
-------
o
U)
en
Lll
«ESTONE
SILO
Y
i
\
C FECDC* J
1
•^>
CLASSIFIER
LJ
MILL -i
y PUMP
SI
1
I
d:
• jvmi- i^
f
O
SL
reeo
.URRY STORAGE fc/~
TANK
FRESH
MAKEUP
WATER
RECYCLE
WATER
TANK
ESP
RECYCLE WATER
PUMP
OUCNCMCM
PUMP
ABSORBER QUENCHER
TANK TANK
TO POND
South Carolina Public Service Authority, Winyah 2: Simplified Process Flow Diagram
-------
EXISTING
O
I
OJ
VEHTURI SORBER
SCRUBBERTN
(ONE IN USE)
MAKEUP HATER
LIMESTONE
FEED BIN
(ONE IN USE
FOR TWO
HIST ELIMINATOR
I PUMP I
(ONE IN USEP-v
ONE SPARE)V?
MIST
L1MINATOR
TANK (ONE
IN USE)
I I
ELII
B
MET BALL MILL
(ONE IN USE)
MILL SLURRY
TANK
FROM THICKENER
TO THICKENER^
Tutr>vmFBi ^E&'
SLURRY STORAGE
TANK
SLURRY
IAI1K Ifmf tM IKF lrlnlN PIMP
(ONE IN USE) {™[ JJaJI) (ONE IN USE) (0||E ^ USE
ONE SPARE)
RECYCLE TANK
(ONE IN USE)
RECYCLE
PUMP
(TWO IN USE
ONE SPARE)
THICKENER
SUPPLY
TANK
(ONE IN USE)
PUMP
[(ONE IN USE
ONE SPARE)
South Mississippi Electric, R.D. Morrow 1 and 2:
Simplified Process Flow Diagram
-------
LIMESTONE SLURRY
STORAGE TANK
o
I
CO
oo
TO OTHER ABSORBER
LIMESTONE
TRANSFER
PUMP
CYCLONE l~p*1
SEPARATOR X/
MILL PRODUCT PUMP
QUENCHER
REdRCULATING
PUMP
ABSORBER
RECIRC.
PUMP
MILL PRODUCT TANK
MAKEUP WATER
^-RECIRCULATING TANK
• DEMISTER
| WASH
-€?
BOTTOM ASH
DE WATERING
BIN
', ••*«*«. »i*l fry**!*****.
? /o PS
ASH CONVEYOR
PLUG MILL
SLUDGE
TRANSFER PUMP
SLUDGE CONVEYORS
Southern Illinois Power Coop, Marion 4: Simplified Process Flow Diagram
-------
n
U)
vo
FROM
ESP
STACK
VcO/
BOOSTER
FAN
A
SODA ASH
STORAGE
LIME
STORAGE
USE ySLAKER Ca(OH)2
WATER
THICKENER
SULFUR DIOXIDE ABSORPTION
'Na2S03 + s°2 + H2° "•
SURGE
=r=*JJ TANK
vCaS03/CaS04
2 NaHS0
FILTER
SODIUM REGENERATION CAKE
Ca(OH)2 - + CaS03 ' 1/2 H20 * Na2S03 + 1-1/2 H20
Southern Indiana Gas and Electric, A.B. Brown 1:
Dual Alkali FGD System Simplified Process Flow Diagram
-------
SCRUBBER INLET
TEST PORT LOCATION
PREC1PITATOR
INLET TEST
PORT LOCATION
n
I
TOP OF STACK
ELEVATION 1645'
TEST PORT
ELEVATION 1516'
"B" ABSORBER
MODULE
U-TOP OF OUTLET BREECHING
ELEVATION 1372'-2 3/8"
TOP OF BYPASS BREECHING
ELEVATION 1307'- 8 1/Z"
BYPASS DUCT V
-GRADE ELEVATION IMP
A" ABSORBER
MODULE
SCRUBBER INLET
TEST PORT LOCATION
Springfield City Utilities, Southwest 1:
Simplified Process Diagram
-------
o
Springfield Water, Light ft Power, Dallman 3
Process Flow Diagram
-------
H2S GENERATION
METHANE/
CARBON MONOXIDE
BOILER
PREHEATER
LIME
NEUTRALIZER
CRYSTALLIZER
SULFUR
SLURRY SULFUR
SULFUR PRODUCT
FLOTATION
PRECONDITIONING AND
S02 ABSORPTION
SULFUR PRECIPITATION
AND RECOVERY
St. Joe Zinc, G.F. Weaton 1:
Citrate FGD System Simplified Process Flow Diagram
C-42
-------
n
*»
u>
I AIR >---.
JFUEL OIL>—»| REHEATER|—
f
-------
FLUE GAS
MAKE-UP WATER
o
i
SPRAY TOWER EFFLUENT
HOLD TANK
VENT AIR
A
OXIDATION
TANK
u
CLARIFIED LIQUOR
WATER
D
^>
^
tl .*
1
T_
MM—
1
<-
->
L^_, t ^
i
DESUPERSATURATION
TANK
BLEED TO
DEWATERING
-^ SYSTEM
Tennessee Valley Authority, Shawnee 10B Prototype Test Unit:
Modified Venturi/Spray Tower System for 2-Stage Oxidation Testing.
-------
o
I
1 AIR
FUEL OIL >-*•[ REHEATER }
PROCESS
WATER
HOLD TANK
SCRUBBER
EFFLUENT
HOLD
TANK
I LIME >—
SAMPLE POINTS
OGAS COMPOSITION
&PARTICULATE COMPOSITION & LOADING
©SLURRY OR SOLIDS COMPOSITION
GAS STREAM
LIQUOR STREAM
SETTLING POND
Tennessee Valley Authority, Shawnee 10B Prototype Unit:
General Process Diagram.
-------
n
i
ASH
REHEATER
STEAM
ENTRAPMENT
SEPARATOR
DISPOSAL POND
TO STACK PLENUM
O «-
FROM ESP
cz
FAN
^ FROM B. C, AND D TRAIN
"VENTURI CIRCULATION TANK^J_
TO SETTLING POND _
O-l
\t
^
4 r
|
*
t
«
\
N
•
^
\
TO
B,C
TRAINS
, AND [
ABSORBER
fl
TO 1
o r
SLURRY PUMP
SEAL WATER
. HEADER
t-~\ a
FRAINS
Ann n
ft
— f^RIVER
WATER
~^* PUMPS
FROM POND
WATER ,
RECYCLE PUMPS
FROM LIMESTONE SLURRY
VENTURI
CIRCULATION
TANK AND
PUMPS
ABSORBER
CIRCULATION
TANK AND
PUMPS
TO TRAINS,
B.C. AND Dl
LIMESTONE SLURRY
STORAGE TANK
EFFLUENT SLURRY
SURGE TANK AND PUMPS
LIMESTONE SLURRY
FEED PUMPS
Tennessee Valley Authority, Widows Creek 8 FGD System:
Process Flow Diagram for One of the Four Scrubber Trains
-------
FAN OUTLfT DAMPER
TnWFR INLET OAMPFR
TOHE» OUTLET
I DAMPER
FROM BOILER
AIR PREHEATERS
—
LOCAT
TUT
REHE
a
»
»
a
ON
JRE
«TE
—
OF
R
a
•
t
T
FO
—
R FUTUV
TOWERS
-&-
TO OTHER)
MODULES j
1-&-
A
r&~
o
I
CONTINUOUS
RECIRCULATIOII
^-^
HET CYCLONES
. PUMP SEAL HATER.
BALL MILL COOLING
AND HOSE STATIONS
MAKEUP HATER TO
LIMESTONE AREA
SERVICE MATER ASH POND
(LAKE HATER) RETURN HATER
(RECYCLE HATER)
y^U
Texas Utilities,
Simplified Process Flow Diagram for One of the Three Identical
Martin Lake FGD Systems
-------
n
i
ib
00
BYPASS
TO SPRAY TOWER 301
TO SPRAY TOWER 201
BYPASS
FROM SPRAY TOWER 301
FROM
LIMESTONE STORAGE
o_
_D
TO SPRAY TOWER 301
TO SPRAY TOWER 201
TO SPRAY TOWER 301
TO SPRAY TOWER 201
TP SPRAY TOWER 301
TO SPRAY TOWER 201 -*
(V
LIMESTONE
STORAGE
BIN
Sc/
TO SPRAY TOWER 301
TO SPRAY TOWER
r LIMESTONE GRINDING
SYSTEM
LIMESTONE SLURRY
TANK AGITATOR
TOTAL PUMP SEALS AMD
INSTRUMENT PURGE WATER
TO ASH AREA
-SERVICE WATER
FROM ASH WATER
RETENTION POND
SO, REMOVAL AREA
- SUMP PUMPS
LIMESTONE
SLURRY
TANK
S02 REMOVAL AREA SUMP
Texas Utilities,
Simplified Process Flow Diagram for Monticello 3
-------
REHEATERFAfL
n
4*
vo
FROM
ELECTROSTATIC
PRECIP1TATORS
WATER
FROM OTHER
ABSORBERS
TO OTHER
ABSORBERS
t t t
VIBRATING-rf^=^f
HOPPER
Utah Power & Light, FGD System Simplified Process Flow Diagram for Hunter 1, 2 or Huntington 1
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 198*
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
COMMONWEALTH
WILL COUNTY
1
ROMEOVILLE
ILLINOIS
E
86.
77*.
******
11*7
167
137
1**
167
EDISON
( .200 LB/MMBTU)
( 1.800 LB/MMBTU)
(****«* LB/MMBTU)
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RAN3E HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RAN3E MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
BABCOCK » NILCOX
CYCLONE
CYCLING
363.36 (
179.* (
107. (
NR
3.8 (
770000 ACFM)
355 F)
350 FT)
12.* FT)
COAL
******
22260. ( 9570 BTU/LB)
9100-10500
7.*0
3.0-16.0
********
******
1.50
0.3-4.5
********
******
0
NONE
0
NONE
COLD SIDE
WESTERN PREC. DIVISION, JOY
179.* ( 355 F)
90.0
2
*/72
VENTURI TOWER
VARIABLE-THROAT/SIDE-MOVABLE BLADES
N/A
BABCOCK & WILCOX
8.0 X 26.0 X 16.0
CARBON STEEL
AISI 1110
ORGANIC; INORGANIC
INERT FLAKE-FILLED VINYL ESTER; HYDRAULICALLY-BO
NONE
D-l
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
LIQUID RECIRCULATION RATE - LITER/S 365.4
L/G RATIO - LITER/CU.M 2.4
PH CONTROL ADDITIVE LIMESTONE
PRESSURE DROP - KPA 2.2
SUPERFICIAL GAS VELOCITY - M/S 36.6
INLET GAS FLOW RATE - CU.M/S 181.7
INLET GAS TEMPERATURE - C 179.4
PARTICLE REMOVAL EFFICIENCY - X 98.0
ENERGY CONSUMPTION - X 4.2
( 5800 GPM)
(18.0 6AL/1000ACF)
( 9.0 IN-H20)
( 120.0 FT/S)
( 385000 ACFM)
( 355 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/72 SYSTEM
696
** PROBLEMS/SOLUTIONS/COMMENTS
IN FEBRUARY 1972 THE BABCOCK * WILCOX WET LIMESTONE FGD SYSTEM AT WILL
COUNTY COMMENCED OPERATION. THE LONGEST PERIOD OF CONTINUOUS OPERATION
WAS 23 DAYS WITH ONE OF THE TWO MODULES. THE S02 REMOVAL EFFICIENCY WAS
ABOUT 85X AND THE PARTICULATE MATTER REMOVAL EFFICIENCY WAS ABOUT 98X.
THE SYSTEM WAS PLAGUED WITH MANY MECHANICAL PROBLEMS. THE MAIN
PROBLEMS ASSOCIATED WITH THE FGD SYSTEM WERE PLUGGING OF THE MIST
ELIMINATORS, CORROSION OF THE REHEATER TUBES AND SLUDGE DISPOSAL. TO
SOLVE THE MIST ELIMINATOR AND REHEATER PROBLEMS, A CONSTANT UNDERSPRAY AND
INTERMITTENT OVERSPRAY WERE USED TO WASH ALL THE MIST ELIMINATOR COMPART-
MENTS. THE REHEATER UNIT WAS ALSO RETUBED.
DURING THE FIRST TWO MONTHS OF 1975 MODULE A WAS OPERATIONAL WHEN NEEDED
WHILE MODULE B WAS UNDERGOING MODIFICATIONS.
3/72
A
B
SYSTEM
.0
35.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
IN MARCH 1972 MODULE A WAS DOWN FOR REPAIRS AND MODIFICATION OF THE MIST
ELIMINATOR WASH PIPING ASSEMBLY. MODULE B WAS REMOVED EVERY TWO OR THREE
DAYS TO HAND WASH THE MIST ELIMINATOR.
OTHER PROBLEMS ENCOUNTERED DURING THE MONTH INCLUDED VIBRATION OF THE
REHEATER TUBE BUNDLES, RAPID EROSION OF THE SCRUBBER SPRAY NOZZLES, AND
PLUGGING OF THE VENTURI NOZZLES.
4/72
A
B
SYSTEM
34.0
14.0
720
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OUT OF SERVICE FOR SIX DAYS IN APRIL BECAUSE OF A NEAR-
RUPTURE OF A VENTURI PIPE EXPANSION JOINT AND HEAVY BUILDUP OF SOLIDS
ON THE MIST ELIMINATOR.
MODULE B WAS OUT OF SERVICE MOST OF THE TIME FOR SIMILAR REPAIR OF THE
VENTURI PIPE EXPANSION JOINT, AND FOR MODIFICATION OF THE REHEATER UNIT
AND MIST ELIMINATOR WASH SYSTEM.
5/72
A
B
SYSTEM
70.0
32.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE B WAS OUT OF SERVICE FOR TWO WEEKS IN MAY TO REBRACE THE REHEAT,
INSTALL UNDERSPRAY NOZZLES ON THE MIST ELIMINATOR, AND TO INSTALL HEAVIER
SCREENS IN THE SUMP.
D-2
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
REHEATER PLUGGING DURING THE MONTH CAUSED ADDITIONAL OUTAGES.
6/72 A 8.0
B 31.0
SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE BOTH MODULES WERE OUT OF SERVICE PART OF THE MONTH DUE TO
A HIGH DIFFERENTIAL PRESSURE ACROSS THE MIST ELIMINATORS AND PLUGGING
OF THE MIST ELIMINATORS DUE TO A LEAKING BYPASS VALVE.
THE RUBBER LINER IN MODULE A WAS REPLACED DURING THE MONTH.
7/72 SYSTEM
8/72 A 79.0
B 21.0
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
A TWO DAY OUTAGE DURING AUGUST WAS NECESSARY TO UNPLUG THE VENTURI NOZZLES
AND THE MIST ELIMINATOR OF MODULE A.
MODULE B WAS OUT OF SERVICE 22 DAYS FOR CLEANING OF THE MIST ELIMINATOR
AND REHEATER. INSTALLATION OF OVERHEAD SPRAY NOZZLES AND REPLACEMENT OF
SECTIONS OF THE MIST ELIMINATOR.
THE BOILER WAS SHUTDOWN FOR TWO DAYS TO REPAIR THE TURBINE/GENERATOR.
9/72 A . 0
B 30.0
SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS OFF LINE FROM SEPTEMBER 1 TO SEPTEMBER 5 DUE TO A LACK OF
DEMAND.
AN ID FAN PROBLEM CAUSED UNSTABLE OPERATION DURING THE MONTH.
MODULE A WAS OUT OF SERVICE IN SEPTEMBER DUE TO THE NECESSARY MODIFICATION
OFTHE REHEATER AND TO REPAIR THE RECYCLE TANK SCREENS.
10/72 A .0
& .0
SYSTEM 744
*« PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THE BOILER WAS OUT OF SERVICE THE ENTIRE MONTH.
MODULES A AND B WERE OUT OF SERVICE DUE TO THE INSTALLATION OF THE REHEATER
BAFFLE PLATES TO DAMPEN VIBRATIONS AND ALSO THE INSTALLATION OF AN EXPERI-
MENTAL MIST ELIMINATOR WASH SYSTEM.
11/72 A . 0
B .0
SYSTEM 720
D-3
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*# PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINED OUT OF SERVICE DURING THE MONTH OF NOVEMBER.
MODULES A AND B REMAINED OUT OF SERVICE DUE TO UNSTABLE OPERATIONS OF THE
BOILER.
12/72
1/73
A
B
SYSTEM
22.0
30.0
»* PROBLEMS/SOLUTIONS/COMMENTS
MODULES A AND B OPERATED INTERMITTENTLY DURING DECEMBER DUE TO TESTING OF
THE ESP AND MISCELLANEOUS INSTRUMENT PROBLEMS.
A
B
SYSTEM
.0
.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY MODULES A AND B WERE OUT OF SERVICE THE ENTIRE MONTH TO
PERFORM SOME NECESSARY REPAIRS AND MODIFICATIONS TO THE SYSTEM.
2/73 A
B
SYSTEM
22.0
24.0
672
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY MODULES A AND B REMAINED OUT OF SERVICE DUE TO CRACKS
IN THE INLET DUCTWORK OF THE BOOSTER FAN.
THE IMPROPER INSTALLATION OF THE MIST ELIMINATOR IN MODULE B CAUSED
PLUGGING IN THE REHEATER.
3/73 A
B
SYSTEM
65.0
11.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OUT OF SERVICE FOR FIVE DAYS IN MARCH DUE TO PLUGGING OF THE
MIST ELIMINATOR.
DURING MARCH THE BOILER WAS OUT OF SERVICE FOR APPROXIMATELY FOUR DAYS
DUE TO AN INSPECTION.
MODULE B WAS OUT OF SERVICE PART OF THE MONTH DUE TO REHEATER TUBE LEAKS.
4/73 A
B
SYSTEM
6.0
13.0
720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL PROBLEMS OCCURRED DUE TO THE DEPOSITS OF CALCIUM SULFATE
SCALE ON THE REHEATER TUBES OF MODULE A.
PERSISTING PROBLEMS WITH THE MIST ELIMINATOR WERE ENCOUNTERED DURING THE
MONTH.
D-4
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/73
6/73
7/73
8/73
9/73
10/73
11/73
A
B
SYSTEM
.0
.0
** PROBLEMS/SOLUTIONS/COMMENTS
MODULES A AND B WERE OUT OF SERVICE FOR THE ENTIRE MONTH OF MAY.
A
B
SYSTEM
16.0
.0
720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE BOILER-RELATED PROBLEMS WERE RESPONSIBLE FOR MOST OF THE
OUTAGE TIME OF MODULE A. MODULE B WAS TAKEN OUT OF SERVICE TO ALLOW
CONCENTRATION ON THE PROBLEMS OF MODULE A.
A
B
SYSTEM
51.0
.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY PROBLEMS WERE ENCOUNTERED WITH REHEATER TUBE LEAKS ON MODULE A.
HIGH FAN VIBRATIONS CAUSED OUTAGE TIME DURING JULY.
A
B
SYSTEM
19.0
.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING AUGUST MORE REHEATER TUBE LEAKS ON MODULE A ATTRIBUTED TO CHLORIDE
CORROSION ATTACK.
A
B
SYSTEM
.0
.0
720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING SEPTEMBER MODULES A AND B REMAINED OUT OF SERVICE. DURING THIS
TIME THE CHICAGO FLY ASH CO. FINISHED CLEANING AND TREATING THE NORTHEAST
HALF OF THE SLUDGE POND.'
A
B
SYSTEM
32.0
.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER MODULE A TRIPPED SEVERAL TIMES DUE TO BAD LIMIT SWITCHES
IN THE BYPASS AND THE BLOCK DAMPERS.
THE BOILER WAS TAKEN OUT OF SERVICE TO BALANCE THE BOOSTER I.D. FAN.
A
B
SYSTEM
51.0
.0
720
0-5
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING NOVEMBER PROBLEMS OCCURRED WITH THE MIST ELIMINATOR DUE TO POOR GAS
DISTRIBUTION.
MODULE A WAS TAKEN OUT OF SERVICE FOR AN INSPECTION. CLEANING AND MODI-
FICATIONS WERE ALSO DONE DURING NOVEMBER.
13/73 A
B
SYSTEM
1/74
.0
.0
** PROBLEMS/SOLUTIONS/COMMENTS
MODULES A AND B WERE OUT OF SERVICE DURING DECEMBER DUE TO MODIFICA-
TIOMS AND MAINTENANCE TO THE ISOLATION VALVES, PUMPS, VENTURI THROATS AND
THE MIST ELIMINATOR.
A
B
SYSTEM
.0
.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
MODULES A AND B WERE OUT OF SERVICE DUE TO FREEZING IN THE 10-INCH-DIAME-
TER, 4400 FT. LINE BETWEEN THE MODULES AND THE POND.
DAMAGE OCCURRED TO THE SUMP PUMPS AND ALSO SOME OTHER INSTRUMENTS DUE TO
THE FREEZING.
2/74 A
B
SYSTEM
.0
.0
67Z
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE FROZEN PIPELINES WERE THAWED, REANCHORED AND RETURNED
TO SERVICE. THE INSTRUMENTS DAMAGED BY THE FREEZING WERE REPAIRED.
MODULE A REMAINED OUT OF SERVICE UNTIL THE ARRIVAL OF THE SECOND-STAGE
MIST ELIMINATOR.
3/74 A
B
SYSTEM
21.0
.0
744
*» PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OPERABLE MARCH 20, BUT WAS NOT RETURNED TO SERVICE UNTIL
MARCH 27 DUE TO THE BOILER BEING OUT OF SERVICE.
4/74 A
B
SYSTEM
72.0
.0
720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL MODULE A OPERATED ON LOW-SULFUR COAL FOR 23 CONSECUTIVE DAYS.
TWO SHORT INSPECTION OUTAGES OCCURRED DURING THAT TIME.
THE SUMP SCREEN FROM MODULE B WAS SUBSTITUTED FOR THE DAMAGED SCREEN IN
MODULE A.
D-6
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 198*
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/74
6/74
7/74
8/74
A
B
SYSTEM
9/74
10/74
93.0
.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY MODULE A OPERATED MOST OF THE TIME ON HIGH-SULFUR COAL. DURING
THIS TIME A FEW SHORT OUTAGES OCCURRED FOR INSPECTIONS.
A
B
SYSTEM
55.0
.0
720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE MODULE A OPERATED FOR APPROXIMATELY 300 HOURS.
TWO WEEKS OF OUTAGE TIME WAS NECESSARY TO MAKE REPAIRS TO THE VENTURI
THROAT DRIVE.
A
B
SYSTEM
96.0
.0
744
*» PROBLEMS/SOLUTIONS/COMMENTS
MODULE B WILL REMAIN OUT OF SERVICE UNTIL SATISFACTORY OPERATION OF MODULE
A IS ACHIEVED.
A
B
SYSTEM
91.0
.0
744
#* PROBLEMS/SOLUTIONS/COMMENTS
DURING AUGUST THE BOILER WAS TAKEN OFF LINE THREE TIMES DUE TO LACK OF
DEMAND.
TWO OUTAGES OCCURRED DUE TO LEAKS IN THE STEAM PIPING.
ONE OUTAGE OCCURRED DUE TO THE BALANCING OF A FAN.
A
B
SYSTEM
85.0
.0
720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING SEPTEMBER MODULE A WAS OUT OF SERVICE ONCE FOR THE REPAIR OF A
SUPERHEATER LEAK AND ONCE FOR CLEANING OF DEPOSITS FROM THE VENTURI
THROAT.
A
B
SYSTEM
94.0
.0
744
** PROBLEMS/SOLUTIONS/COMMEHTS
11/74 A
DURING OCTOBER REHEATER LEAKS CAUSED MODULE A TO BE OUT OF SERVICE TWICE.
ADDITIONAL OUTAGE TIME WAS A RESULT OF A BOILER OUTAGE AND A INSPECTION
OF THE MODULE.
97.0
D-7
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
B .0
SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS SHUT DOWN THREE TIMES DURING NOVEMBER. TWICE DUE TO LACK OF
DEMAND AND ONCE FOR AN INSPECTION.
12/74 A 99.0
B .0
SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS TAKEN OFF LINE PART OF THE MONTH TO REPAIR THE VALVE IN THE
SPENT LIQUOR LINE TO THE POND AND ALSO FOR AN INSPECTION.
1/75 A 99.0
B .0
SYSTEM 7*4
** PROBLEMS/SOLUTIONS/COMMENTS
MODIFICATIONS OF MODULE B ARE STILL CONTINUING.
DURING JANUARY MODULE A WAS OUT OF SERVICE TWICE; ONCE FOR AN INSPECTION
AND ONCE DUE TO LACK OF DEMAND.
2/75 A 99.0
B .0
SYSTEM 672
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY MODULE A WAS OUT OF SERVICE TWO TIMES DUE TO LACK OF DE-
MAND AND ALSO FOR AN INSPECTION. THE INSPECTION SHOWED THAT CONDITIONS
INSIDE THE MODULE WERE THE SAME AS BEFORE.
DURING THE MONTH A SMALL REHEATER LEAK IN A STAINLESS STEEL BUNDLE CAUSED
THE SYSTEM TO SHUT DOWN.
DURING THE INSPECTION OF MODULE A, THE UNDERWASH NOZZLES WERE CLEANED AND
A SMALL SECTION FO THE MIST ELIMINATOR WAS REPLACED.
CHICAGO FLYASH IS TREATING MATERIAL FROM THE SYSTEM WITH PORTLAND
CEMENT AND FLYASH AND DUMPING THE TREATED MATERIAL INTO THE NORTH HALF
OF THE HOLDING BASIN.
3/75 A 94.0 99.2 81.2
B .0 .0 .0
SYSTEM 744 609
** PROBLEMS/SOLUTIONS/COMMENTS
A VENTURI HOSE LEAK FORCED MODULE A OUT ONCE.
MODULE B WAS OUT OF SERVICE TWICE FOR NO DEMAND AND ONCE AS A RESULT OF AN
ACCIDENTAL 50 MINUTE TRIP.
COAL BURNED THIS MONTH AVERAGED LESS THAN ONE PERCENT SULFUR.
4/75 A 37.0 39.5 35.0
B .0 .0 .0
SYSTEM 720 638
D-8
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO FLY ASH IS TREATING MATERIAL FROM THE SCRUBBER WITH LIME AND FLY
ASH AND DUMPING IT INTO THE HOLDING BASIN.
A BOILER OUTAGE FORCED MODULE A OUT OF SERVICE ONCE THIS MONTH (MODULE B
WAS ALREADY OUT OF SERVICE).
COAL BURNED THIS MONTH WAS RECLAIM COAL AND VARIED IN SULFUR CONTENT.
5/75 A 8"*. 5 84.5 84.5
B 37.1 37.1 37.1
SYSTEM 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE B WAS IN SERVICE ON MAY 20 FOR THE FIRST TIME SINCE APRIL 13, 1973.
RECIRCULATION TANK MIXERS.
MODULE A (WHICH WAS THE ONLY ONE OPERATING) WAS FORCED OUT TWICE IN APRIL
TO AVOID POND OVERBOARDIHG INTO THE DES PLAINES RIVER. THE SECOND OUTAGE
LASTED UNTIL MAY 5. DURING THE PAST SEVERAL MONTHS OF GENERALLY CONTINUOUS
OPERATION OF MODULE A. IT HAS BECOME APPARENT THAT THE PRESENT LIQUID
CIRCULATING SYSTEM CANNOT BE OPERATED IN A CONTINUOUSLY CLOSED CYCLE. THE '
WATER IMBALANCE POSES A HIGH RISK OF OVERBOARDING FROM THE SLUDGE POND
DURING LONG PERIODS OF SUSTAINED OPERATON. THE FOLLOWING REVISIONS HAVE
BEEN MADE TO REDUCE THE WATER IMBALANCE:
1. THE PUMP GLAND WATER FLOWS HAVE BEEN CUT FROM 10 GPM TO S GPM.
2. THE SCRUBBER HOUSE SERVICE WATER FILTER BACKWASH HAS BEEN ROUTED
OUT OF THE SYSTEM.
3. THE CONTINUOUS UNDERSPRAY HAS BEEN CHANGED TO AN INTERMITTENT
SPRAY 5 MINUTES ON, 5 MINUTES OFF.
THE THICKENER HAS BEEN DOWN SINCE APRIL 21 DUE TO A BROKEN GEAR AND A STUCK
SWEEP ARM. THE THICKENER HAS BEEN BYPASSED AND THE SLUDGE IS COINS TO THE
POND.
DURING MAY, MODULE A WAS OUT FOR 45 MINUTES DUE TO A DAMPER TRIP.
MODULE A WAS OUT ONCE FOR SPRAY NOZZLE CLEANING.
MODULE B WAS OUT TWICE AFTER START UP, ONCE FOR A VENTURI PUMP TRIP AND
ONCE FOR A RECIRCULATION TANK LEVEL TRIP.
CHICAGO FLY ASH IS TREATING THE MATERIAL FROM THE SCRUBBER WITH LIME AND
FLY ASH AND DUMPING IT INTO THE HOLDING BASIN. A MIXER HAS BEEN INSTALLED
AT THE THICKENER, WHICH ENABLES THEM TO SUBSTITUTE SEALED DUMP TRUCKS FOR
THE CEMENT TRUCKS WHICH WERE USED IN THE PAST FOR MIXING AND TRANSPORTING
THE WASTE MATERIAL TO THE HOLDING BASIN.
COAL BURNED THIS MONTH VARIED GREATLY IN SULFUR CONTENT, RANGING FROM LOW
SULFUR WESTERN COAL TO HIGH SULFUR ILLINOIS COAL.
6/75 A 64.1 60.6 54.1
B 85.5 84.6 75.4
SYSTEM 720 642
** PROBLEMS/SOLUTIONS/COMMENTS
A REHEATER PLUGGAGE INSPECTION FORCED ONE MODULE A OUTAGE.
A LOW LEVEL TRIP CAUSED A 35 MINUTE OUTAGE, AND NO DEMAND ACCOUNTED FOR TWO
D-9
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUMTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
MORE MODULE A OUTAGES.
MODULE B WAS OUT FOR 95 HOURS TO CLEAN THE BOOSTER FAN AND OEMISTER.
HIGH BOOSTER FAN VIBRATIONS CAUSED MODULE B TO SHUT DOWN ON JUNE 30.
DURING THIS MONTH HIGH SULFUR COAL WAS BURNED IN A TWO WEEK TEST, AND LOW
SULFUR COAL WAS BURNED THE REST OF THE MONTH.
7/75 A
B
SYSTEM
.0
79.2
.0
79.4
.0
73.5
744 689
** PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO FLY ASH IS TREATING THE SCRUBBER WASTE MATERIAL WITH LIME AND FLY
ASH AND DUMPING IT INTO THE ON SITE HOLDING BASIN. THE MATERIAL FROM THE
HOLDING BASIN IS BEING TRUCKED TO AN OFF SITE DUMP.
MODULE B WAS OUT ONCE (30 MINUTES) TO REPAIR A MINOR STEAM HEADER LEAK.
MODULE B WAS OUT ONCE DUE TO NO DEMAND.
LOW SULFUR COAL WAS BURNED MOST OF THIS MONT, WITH HIGH SULFUR COAL BEING
BURNED DURING THE LAST WEEK OF THE MONTH.
8/75
A
B
SYSTEM
.0
93.5
.0
100.0
.0
76.4
744 565
** PRCBLEMS/SOLUTIONS/COMMENTS
IN JUNE, MODULE A ENCOUNTERED PLUGGAGE IN THE DEMISTER, WHICH REQUIRED ITS
REPLACEMENT. THE WORK WAS COMPLETED IN AUGUST.
MODULE A WENT OUT OF SERVICE ON JUNE 20 AND REMAINED OUT THROUGH AUGUST DUE
TO MASSIVE REHEATER LEAKS. THERE IS PRESENTLY A HOLD ON THE NEW REHEATER
ORDER BECAUSE OF MATERIAL FAILURES EXPERIENCED IN MODULE B'S CARBON STEEL
REHEATER.
MODULE B SUFFERED TWO OUTAGES IN JULY AND ONE IN AUGUST BECAUSE OF REHEATER
TUBE LEAKS. THE FAILURES WERE DUE TO VIBRATION FATIGUE. THE REHEATER, WHICH
WAS INSTALLED IN MAY, HAS LOST SIX OF ITS TWELVE TUBE BUNDLES SO FAR. THE
LENGTH OF TIME THAT THE TUBES HAVE LASTED WOULD SEEM TO INDICATE THAT THERE
IS A DIESIGN RELATED MATERIAL DEFICIENCY. THREE OF THE TUBE BUNDLES WERE
REPLACED WITH MARGINAL BUNDLES LEFT OVER FROM MODULE A.
A SMALL STEAM HEADER LEAK CAUSED ONE MODULE B OUTAGE.
MODULE B WAS OUT FOUR TIMES FOR NO DEMAND AND ONCE FOR A LOW FLOW TRIP.
HIGH SULFUR COAL WAS BURNED ALL MONTH, CAUSING AN INCREASE IN SLUDGE
PRODUCTION WHICH HAS FORCED A MINIMUM SIX DAY A WEEK, TEN HOUR A DAY
SLUDGE DISPOSAL OPERATION. THE SLUDGE IS BEING TREATED WITH LIME AND
FLY ASH AND BEING DUMPED INTO THE ON SITE HOLDING POND. STABILIZED
MATERIAL IS BEING TRUCKED FROM THE POND TO AN OFF SITE DISPOSAL AREA.
9/75 A
B
SYSTEM
10/75 A
B
SYSTEM
.0
32.3
.0
100.0
.0
26.6
720
744 194
0-10
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OFF THE ENTIRE 11 DAYS THE BOILER OPERATED THIS MONTH, WAITING
FOR ITS NEW REHEATER, WHICH HAS NOW BEEN RELEASED FOR MANUFACTURING BY
SMED.
MODULE B HAD TWO OUTAGES, ONE FOR NO DEMAND AND ONE MINOR 15 MINUTE TRIP.
HIGH SULFUR COAL WAS BURNED THIS MONTH WHEN THE SCRUBBER WAS IN SERVICE.
THE SLUDGE IS BEING TREATED WITH LIME AND FLY ASH AND HAULED TO AN OFF SITE
DISPOSAL AREA.
11/75 A
B
SYSTEM
12/75 A
B
SYSTEM
1/76 A
B
SYSTEM
2/76 A
B
SYSTEM
3/76
A
B
SYSTEM
.0
.0
.0
.0
.0
.0
.0
.0
30.1
8.8
45.2
20.4
.0
.0
18.8
8.5
720
744
744
696
744 309
*« PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 WAS DOWN FROM OCTOBER 11 THROUGH MARCH 19 FOR ITS BOILER TURBINE
AND SCRUBBER OVERHAUL. THE MAJOR ITEMS TO BE ACCOMPLISHED DURING THE
OUTAGE WERE:
1. SIMPLIFICATION OF THE MILLING SYSTEM CONTROL.
2. PULLING AND CLEANING OF THE MODULE B REHEATER AND RETURNING IT
REPLACED WITH MARGINAL BUNDLES LEFT OVER FROM MODULE A.
3. CLEANING OF THE POND PUMP BAY.
4. REMOVAL OF THE VENTURI AND ABSORBER PUMP CHECK VALVES (ONE OF THEM
FAILED LAST SPRING AND DESTROYED A PUMP LINER AND IMPELLER).
5. CLEANING AND REPAIR OF THE VENTURI NOZZLES AND SUPPORTS.
6. REPAIR OF CORRODED REHEATER SUPPORTS.
7. RESETTING AND ADJUSTMENT OF ALL DAMPERS.
8. REVISION OF SCRUBBER CONTROLS BY REMOVING THE CONTROLS NO LONGER
USED OR NEEDED.
9. INSPECTION AND CLEANING OF THE ENTIRE SCRUBBER AND RELATED
EQUIPMENT.
MODULE A WAS PUT INTO THE GAS PATH ON MARCH 22 AND REMAINED AVAILABLE FOR
SERVICE THE REST OF THE MONTH.
MODULE B HAD TO REMAIN OUT OF SERVICE UNTIL MARCH 29 WHILE ITS REPAIRED
REHEATER WAS INSTALLED.
4/76 A
B
SYSTEM
23.0
20.0
49.3
19.2
47.3
720 691
D-ll
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION V. REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 RETURNED TO SERVICE APRIL Z AFTER A SHORT TURBINE CONTROL OUTAGE.
BOTH MODULES CAME ON LINE JUST BEFORE THE BOILER.
A FIVE DAY OUTAGE OF MODULE B WAS DUE TO REHEATER TUBE BUNDLE LEAKS.
SEVERAL MODULE B OUTAGES WERE DUE TO PLUGGED ABSORBER TANK SCREENS CAUSED
BY MILL AND CLASSIFIER FAILURES WHICH ALLOWED ROCK TO GET INTO THE SYSTEM.
MODULE B WAS THOROUGHLY CLEANED.
ONLY ONE ABSORBER PUMP IS BEING USED IN MODULE B, SINCE THE IBZ PUMP LINER
FAILED AS A RESULT OF A BROKEN DISCHARGE VALVE. A REPLACEMENT LINER IS
BEING INSTALLED.
A SCRUBBER TESTING AND EVALUATING PROGRAM WAS STARTED THIS MONTH. MUCH OF
THE LATTER TWO WEEKS OF THE MONTH WERE SPENT TRAINING THE TESTING PERSON-
NEL. THE PROGRAM WILL PROVIDE CHEMISTRY DATA AND OPERATING CHARACTERISTICS.
5/76 A .0 .0 .0
SYSTEM 744 665
** PROBLEMS/SOLUTIONS/COMMENTS
A VENTRUI HOSE LEAK FORCED MODULE B OFF ONCE THIS MONTH.
MODULE B WAS TAKEN OUT OF SERVICE ONCE BECAUSE OF A PLUGGED ABSORBER TANK
SCREEN.
MODULE B WAS OFF ONCE DUE TO A FOULED I.D. FAN.
MODULE B WAS OUT OF THE GAS PATH ONCE DUE TO NO DEMAND.
6/76 A 52.0 44.2 37.6
B 66.2 84.5 71.9
SYSTEM 720 612
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A SUFFERED VENTURI PUMP LINER FAILURES ON APRIL 78 WHEN AN INLET 16
INCH BUTTERFLY ISOLATION VALVE BROKE APART AND FELL INTO THE VENTURI PUMP.
BOTH THE A AND BACKUP AB VENTURI PUMP LINERS WERE DESTROYED. MODULE A
REMAINED OUT SERVICE UNITL JUNE 9, WHEN THE LINERS WERE REPLACED.
MODULE A WAS OFF ONCE FOR SHEARED BYPASS DAMPER PINS.
I.D. BOOSTER FAN FOULING FORCED MODULE A OFF ONCE THIS MONTH FOR ABOUT
164 HOURS.
BOTH MODULES WERE OFF TWICE DUE TO NO DEMAND. DURING THESE OUTAGES, THE
DEMISTERS WERE WASHED AND ABSORBER TRAY SCALE, IF ANY, WAS KNOCKED OFF.
MODULE B WAS OUT OF THE GAS PATH FOR SEVERAL SHORT VENTURI LOW FLOW TRIP
OUTAGES DUE TO A PLUGGED, SCALED VENTURI TANK SCREEN. AT THE END OF THE
MONTH, THE MODULE WAS TAKEN OUT TO CLEAN THE SCREEN.
THE MODULE B I.D. BOOSTER FAN REQUIRED CLEANING DURING THE MONTH.
THE REHEATER TUBES ARE SCALING, WHICH RESULTS IN A LOWER HEAT TRANSFER RATE
RATE, AND THEREFORE INCREASES I.D. BOOSTER FAN FOULING. THE ONLY WAY TO
CLEAN THE REHEATERS EFFECTIVELY IS TO REMOVE THEM, WHICH DEMANDS A SUBSTAN-
TIAL OUTAGE.
0-12
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/76 A 19.9 .0 .0
B 86.2 90.0 72.3
SYSTEM 744 598
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OFF THE FIRST PART OF THE MONTH DURING REPAIRS TO THE ABSORBER
THE LATTER PART OF THE MONTH THE MODULE WAS READY FOR SERVICE BUT WAS NOT
OPERATED BECAUSE OF THICKENER-POND SLUDGE OVERLOADING.
MODULE B WAS FORCED OFF ONCE TO BALANCE THE I.D. BOOSTER FAN. AND ONCE TO
MASH THE FAN.
MODULE B WAS OUT OF THE GAS PATH TWICE DUE TO NO DEMAND.
8/76 A 98.2 57.6 38.3
B 65.4 61.4 40.9
SYSTEM 744 495
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OUT OF THE GAS PATH THE FIRST HALF OF THE MONTH T AVOID
THICKENER-POND OVERLOADING.
DURING THE LATTER HALF OF THE MONTH, MODULE A WAS USED WITH THREE MINOR
FORCED OUTAGES AND ONE FOUR DAY NO DEMAND OUTAGE.
MODULE B WAS OUT OF THE GAS PATH THREE TIMES DUE TO NO DEMAND.
LOSS OF CHEMICAL CONTROL CAUSED TWO MODULE A OUTAGES.
MODULE B WAS OFF FOR NINE DAYS DUE TO FOULING.
SPENT SLURRY VALVE REPAIRS FORCED A MODULE B OUTAGE.
ON AUGUST 12 THE OPERATING PH CONTROL SET POINT WAS REDUCED FROM 5.4 TO
5.1. IT IS BELIEVED THAT THIS LOWER PH IS THE CAUSE OF THE FOULING OUTAGE
OF MODULE B ON AUGUST 21. MODULE A WAS ALSO OPERATED FOR THREE DAYS, AND
IT, TOO, EXPERIENCED INCREASED SACLE FOULING. THE PH SET POINT WAS THEN
INCREASED BACK TO 5.4.
9/76 A 42.3 28.7 22.6
B 79.4 59.9
SYSTEM 720 566
«* PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WENT OFF ONCE DUE TO A LOW FLOW TRIP.
MODULE A WAS TAKEN OFF ONCE FOR CLEANING OF THE RECIRCULATION TANK AND
PUMPS, AND INSPECTION OF PUMP ISOLATION VALVES.
A LINER LEAK IN 1A2 ABOSORBER PUMP ALSO FORCED MODULE A OFF.
MODULE A WAS OUT OF TH GAS PATH TWICE DUE TO NO DEMAND.
MODULE A WAS TAKEN OFF ONCE TO AVOID THICKENER-POND OVERLOADING.
SPENT SLURRY VALVE TROUBLE CAUSED TWO MODULE B OUTAGES.
10/76 A 27.9 28.9 37.9
D-13
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
B 76.4 56.2 54.8
SYSTEM 744 726
** PROBLEMS/SOLUTIONS/COMMENTS
HIGH SULFUR ILLINOIS COAL WAS BURNED IN THE BOILER FROM MARCH THROUGH
OCTOBER.
THE SCRUBBER WASTE MATERIAL WAS TREATED WITH LIME AND FLY ASH AND HAULED TO
AN OFF SITE DISPOSAL AREA.
MODULE A OPERATED ON ONE ABSORBER PUMP, ALLOWING TESTING ON A LOWER
ABSORBER FAN.
MODULE A WAS OUT OF THE GAS PATH ONCE FOR AN I.D. BOBOOSTER FAN TRIP.
WORK ON RECIRCULATION TANK LEVEL CONTROLS CAUSED A MODULE A OUTAGE.
MODULE B WAS FORCED OFF ONCE TO REPAIR A REHEATER HEADER LEAK.
ONE MODULE B OUTAGE WAS FOR VENTURI NOZZLE CLEANING.
MODULE B WENT OFF FOR A VENTURI LOW FLOW TRIP.
MODULE B REMAINED OUT OF SERVICE WHILE MODULE A WAS BEING TESTED TO AVOID
THICKENER-POND OVERLOADING.
A VACUUM FILTER WAS TIED IN AT THE THICKENER.
11/76 A 20.1 25.6 20.1
B 72.2 69.6 4.7
SYSTEM 720 566
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A OPERATED ON ONE ABSORBER PUMP DURING MODULE B OUTAGE.
MODULE B WAS FORCED OUT OF THE GAS PATH ONCE FOR A MILLING SYSTEM FAILURE.
MODULE B ENCOUNTERED A VENTURI HEADER LEAK.
THE VENTURI NOZZLES REQUIRED CLEANING DURING THE MONTH.
REPLACEMENT OF THE SPENT SLURRY VALVE NECESSITATED A MODULE OUTAGE.
MODULE B WAS OFF ONCE DUE TO A CHEMICAL SYSTEM UPSET.
MODULE B WAS OUT OF THE GAS PATH TWICE DUE TO NO DEMAND (MODULE A WAS NOT
IN SERVICE AT THE TIME OF THE OUTAGE).
12/76 A 44.9 48.3 44.9
B 53.4 51.7 48.0
SYSTEM 744 692
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE LAST WEEK OF NOVEMBER, THE 1A2 ABSORBER PUMP WAS TAKEN OUT OF
SERVICE FOR OVERHAUL. THE REPAIRS WERE COMPLETED ON DECEMBER 6, WHEN THE
MODULE ASSUMED A ONE ABSORBER PUMP STANDBY CAPABILITY UNTIL THE 1A1 ABSOR-
BER PUMP CAN BE REPAIRED.
DURING THE LAST HALF OF THE MONTH, MODUELE A OPERATED WHILE MODULE B WAS
BEING REPAIRED.
D-14
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
MODULE B PERFORMED SATISFACTORILY DURING THE FIRST HALF OF THE MONTH,
EXPERIENCING ONLY ONE NO DEMAND OUTAGE. ON THE 17TH, HOWEVER, THE SPENT
SLURRY VALVE FAILED AND THE MODULE HAS REMAINED OUT OF SERVICE.
1/77 A 98.2 98.7 95.8
B 13.5 1.1 1.1
SYSTEM 744 722
** PROBLEMS/SOLUTIONS/COMMENTS
THE 1A1 ABSORBER PUMP WENT OUT IN LATE SEPTEMBER WITH BURNED OUT BEARINGS
AND REMAINED OUT THROUGH JANUARY WAITING FOR PARTS.
LOW SULFUR COAL WAS BURNED IN THE BOILER FROM NOVEMBER THROUGH JANUARY.
DUE TO THE LOW VOLUME OF SLUDGE PRODUCED WHILE BURNING LOW SULFUR COAL,
MUCH OF THE SLUDGE HANDLING TIME WAS SPENT DIGGING OUT THE ACCUMULATED
SLUDGE IN THE RECIRCULATION POf.-DS. THIS MATERIAL, ALONG WITH SCRUEBER
WASTE MATERIAL, WAS TREATED WITH LIME AND FLYASH AND HAULED TO AN OFF
SITE DISPOSAL AREA.
MODULE A WAS FORCED OUT ONCE BY A FAILED SPENT SLURRY VALVE.
PLUGGED DEMISTER UNDERSPRAYS CAUSED ANOTHER MODULE A OUTAGE.
MODULE A WENT OUT ONCE BECAUSE OF NO DEMAND AND ONCE DUE TO A BOILER OUTAGE
(MODULE B WAS ALREADY OUT OF SERVICE FOR REPAIRS).
MODULE B BECAME AVAILABLE FOR SERVICE ON JANUARY 27, AFTER REPAIRS TO THE
SPENT SLURRY VALVE WERE COMPLETED. DUE TO SEVERE WEATHER CONDITIONS, THE
MODULE WAS PLACED IN THE GAS PATH JANUARY 31.
2/77 A 38.8 42.6 38.8
B 72.0 45.7 41.7
SYSTEM 672 613
** PROBLEMS/SOLUTIONS/COMMENTS
THERE WAS VERY LITTLE DIGGING IN THE RECIRCULATION PONDS. CHICAGO FLYASH
SPENT MOST OF THEIR TIME ON CLEANING AND MAINTENANCE.
3/77 A 96.9 66.7 64.2
B 80.9 75.5 73.9
SYSTEM 744 728
** PROBLEMS/SOLUTIONS/COMMENTS
AN ERT S02 ANALYZER WAS INSTALLED ON THE DISCHARGE SIDE OF MODULE B I.D.
BOOSTER FAN. THIS IS AN "IN SITU" ON-DISPERSIVE ANALYZER THAT CONTINUALLY
MEASURES AND READS OUT CONCENTRATIONS OF S02, CO, C02, AND NO.
AN ABSORBER SUCTION HEADER LEAK FORCED MODULE B FROM THE GAS PATH.
MODULE B WAS FORCED OUT DUE TO A SLURRY VALVE GASKET LEAK.
A PLUGGED FEED SLURRY RECIRCULATION LINE WAS ENCOUNTERED IN MODULE B.
HIGH SULFUR COAL WAS BURNED FOR SEVEN DAYS THIS MONTH TO PROVIDE HIGH
SULFUR SLUDGE FOR THE UOP SLUDGE TEST.
CHICAGO FLYASH SPENT 75X OF THEIR TIME DIGGING IN THE POND. THE REST WAS
SPENT ON THE THICKENER AND VACUUM FILTER IPERATION. THE SCRUBBER WASTE
MATERIAL WAS TREATED WITH LIME FLYASH AND HAULED OFF SITE.
DISPOSAL AREA.
D-15
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
ft/77 A
B
SYSTEM
86.1
45.5
67.7
30.2
61.2
27.3
720 650
** PROBLEMS/SOLUTIONS/COMMENTS
THE PERFORMANCE OF THE ERT S02 ANALYZER TO DATE HAS BEEN, AT BEST, UNRELIA-
BLE AND INCONSISTENT. THE ERT TECHNICIANS ARE OUT TO SERVICE THE ANALYZER
ALMOST EVERY OTHER DAY. THE PROBLEM, ACCORDING TO ERT TECHNICIANS, IS OF A
"THERMAL NATURE". WHEN THE ANALYZER REACHES A CERTAIN TEMPERATURE, A CHIP
SHORTS OUT. THEY HAVE NOT BEEN ABLE TO LOCATE THE FAULTY INTEGRATED CIRCUIT
YET.
A BOILER TUBE LEAK REPAIR FORCED MODULE A OUT OF THE GAS PATH ONCE THIS
MONTH (MODULE B WAS ALREADY DOWN FOR REPAIRS).
MODULE B WAS FORCED OUT OF THE GAS PATH TWICE FOR AN ABSORBER SUCTION
HEADER LEAK REPAIR.
MODULE B WAS OUT OF SERVICE ONCE TO WASH THE I. 0. BOOSTER FAN.
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME DIGGING IN THE SMALL POND,
GETTING READY FOR THE MGO ADDITION AND FORCED OXIDATION TEST. THE SCRUBBER
WASTE MATERIAL WAS TREATED WITH LIME AND FLYASH AND HAULED TO AN OFF SITE
DISPOSAL AREA.
5/77
A
B
SYSTEM
89.4
98.0
2.2
50.9
2.0
47.3
744 691
** PROBLEMS/SOLUTIONS/COMMENTS
THE ERT S02 ANALYZER HAS BEEN REMOVED FROM SERVICE DUE TO A POOR PERFORM-
ANCE RECORD OVER THE LAST THREE MONTHS. ERT IS IN THE PROCESS OF RE-
ENGINEERING THEIR ANALYZER.
THE MGO ADDITION TEST WENT WELL. ALTHOUGH THE MGO INCREASED S02 REMOVAL
EFFICIENCY ABOUT 10X, IT DID PRACTICALLY NOTHING FOR THE TWO MORE SERIOUS
PROBLEMS, SINCE THICKENER AND SLUDGE PRODUCTION AND LIMESTONE CONSUMPTION
RATE WERE ABOUT THE SAME.
MODULE A WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH WHEN THE INLET
VALVE ON 1A2 ABSORBER PUMP FAILED.
MODULE B WAS TAKEN OFF TO CLEAN AND INSPECT THE REHEATER TUBES.
BOTH MODULES WERE FORCED OFF FOR THE FIRST FIFTEEN DAYS OF THE MONTH DUE TO
A FAILED 120V CONTROL TRANSFORMER FOR THE POND RETURN PUMPS. THE TRANSFORM-
ER HAD TO BE ORDERED FROM WESTINGHOUSE.
HIGH SULFUR COAL HAS BURNED FOR ELEVEN DAYS DURING THE MONTH.
6/77 A
B
SYSTEM
31.8
93.2
13.3
93.4
10.5
73.5
720 566
** PROBLEMS/SOLUTIONS/COMMENTS
THE 1A1 ABSORBER PUMP IS STILL OUT OF SERVICE WAITING FOR PARTS 1A2
ABSORBER PUMP'S ISOLATION VALVES FORCED MODULE A OFF FOR MOST OF T(E MONTH.
MODULE A HAD ONE NO DEMAND AND ONE BOILER OUTAGE THIS MONTH.
D-16
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
MODULE B WAS ALSO FORCED OFF TO CLEAN THE I.D. BOOSTER FAN.
NO HIGH SULFUR COAL WAS BURNED THIS MONTH.
70.3 41.4 21.0
7/77
8/77
9/77
10/77
11/77
12/77
B
SYSTEM
744 377
** PROBLEMS/SOLUTIONS/COMMENTS
HIGH SULFUR COAL HAS BURNED FOR EIGHT DAYS THIS MONTH. LIMESTONE OPERATION
WAS NORMAL FOR HIGH SULFUR OPERATION.
MODULE B WAS FORCED OUT OF THE GAS PATH ONCE TO REMOVE A PLUGGED DIFFUSER.
THE FINAL TEST, FORCED OXIDATION SEEMDD TO BE THE MOST SUCCESSFUL OF ALL.
USING LIQUID OXYGEN, UP TO 12,000 CFM OF GASEOUS 02 WAS FED INTO EACH
VENTURI DOWNCOMER, OXIDATION OF SULFITE TO SULFATE WAS INCREASED FROM
35 TO 90 7.
MODULE B WAS ALSO FORCED OFF DUE TO A LOW LEVEL IN THE SLURRY STORAGE TANK.
MODULE B WAS ALSO FORCED OFF DUE TO REHEATER TUBE BUNDLE LEAKS.
A
B
SYSTEM
99.8
9.7
99.6
12.0
80.8
9.7
744 604
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS AVAILABLE THE ENTIRE MONTH WITH JUST THE VENTURI PUMP OPERAT-
ING.
A
B
SYSTEM
61.0
52.3
77.8
75.4
54.0
52.3
720 499
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE B ENCOUNTERED HIGH VIBERATIONS IN ITS BOOSTER FAN DURING THE FIRST
WEEK OF THE MONTH. AFTER THE FAN WAS BALANCED, THE MODULE OPERATED INTIL
THE UNIT OUTAGE ON SEPTEMBER 21.
A
B
SYSTEM
A
B
SYSTEM
.0
.0
.0
8.8
50.1
.0
.0
.0
8.8
744
720 126
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT ONE CAME UP ON NOVEMBER 25 AFTER A SIXTY-THREE DAY OUTAGE.
MODULE B IS IN THE GAS PATH FATER EXPERIENCING SOME DIFICULTY IN BALANCING
ITS BOOSTER FAN.
A
B
SYSTEM
42.5
84.1
42.5
84.1
47.8
94.6
42.5
84.1
744 661
D-17
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
PLUGGAGE WAS ENCOUNTERED IN THE MODULE B REHEATER. BECAUSE NO SPARE REHEAT
COILS WERE AVAILABLE, THE UTILITY TRIED TAKING SOME COILS FROM MODULE A
MODULE B APPEARED TO BE MORE ORE SEVERELY PLUGGED THAN ORIGINALLY THOUGHT.
MODULE A WAS DOWN HALF THE MONTH BECAUSE OF A MAIN STEAM LEAK WHICH COULD
NOT BE ISOLATED.
MODULE A OPERATED UNTIL SEPTEMBER 19, WH E A COMBINATION OF MUD AND SCALE
BUILD-UP ON THE SUMP FLOOR STRUCTURALLY DAMAGED THE MODULE. REPAIRS PUT
THE MODULE OUT OF SERVICE UNTIL MID DECEMBER.
1/78 A 69.0 89.9 66.3
B 22.0 29.8 22.0
SYSTEM 744 549
»* PROBLEMS/SOLUTIONS/COMMENTS
ON JANUARY 7, THE MODULE B I.D. BOOSTER FAN DISCHARGE DUCT STARTED VIBRAT-
ING WILDLY. THIS FORCED THE BOILER OFF WHILE THE SHOP MADE REPAIRS TO THE
DUCTWORK AND BALANCED THE FAN WITH AN I.R.D. MACHINE.
WHEN THE UTILITY ATTEMPTED TO PUT MODULE B BACK IN THE GAS PATH, A LEAK IN
THE SLURRY LINE FORCED IT BACK OFF.
A PLUGGED VENTURI PUMP FORCED MODULE B OFF THE REST OF THE MONTH.
DURING THE OUTAGE, THE REHEATER COILS WERE CLEANED WITH A HIGH PRESSURE
(5000 LB) SPRAYER.
MODULE A WAS FORCED OFF WHEN A STEAM REGULATING VALVE BLEW ITS PACKING.
ON THE 23RD, BOTH MODULES WERE TAKEN OFF AND DRAINED TO ALLOW THE SHOP TO
INSTALL NEW ISOLATION VALVES IN THE ABSORBER AND VENTURI PUMPS.
TOWARD THE END OF THE MONTH, SOME PROBLEMS WERE ENCOUNTERED WITH THE POND
RETURN PUMPS FREEZING.
2/78 A 40.9 56.5 34.4
B 69.5 92.9 56.5
SYSTEM 672 409
»* PROBLEMS/SOLUTIONS/COMMENTS
MODULE A RAN INTO DIFFICULT OPERATIONG CONDITIONS THIS MONTH DUE TO RAPID
PLUGGING OF THE REHEAT COILS.
INSPECTION AND SUBSEQUENT CLEANING OF MODULE A UNCOVERED PLUGGED SPRAY
NOZZLES AND DEMISTER TRAYS DUE TO NOZZLE INEFFICIENCY.
MODULE B OPERATED VERY WELL AND AN INSPECTION SHOWED THE MODULE TO BE VERY
CLEAN.
3/78 A 93.5 100.0 90.6
B 83.5 84.7 76.0 26.2
SYSTEM 7^ 230
#* PROBLEMS/SOLUTIONS/COMMENTS
THIS MONTH, DUE TO COAL CONSERVATION, UNIT 1 WAS ON THE SYSTEM VERY LITTLE.
MODULE B HAD DIFFICULTY FOR SEVERAL DAYS BECAUSE OF A CRACKED SHEAVE ON THE
D-18
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY .UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
VENTURI PUMP.
HIGH PRESSURE CLEANING ON BOTH MODULES DURING THE COAL CONSERVATION ALONG
WITH REMOVING THE VENTURI THROAT RESTRICTOR BLOCKS PROVED BENEFICIAL IN
MAINTAINING BETTER CONTROL OF THE DRAFT CONDITIONS IN THE SCRUBBER.
4/78
A
B
SYSTEM
99.9
100.0
99.7
99.9
92.0
92.2
720 665
** PROBLEMS/SOLUTIONS/COMMENTS
THE PRESSURE DIFFERENTIAL ACROSS THE VENTURIS HAS BEEN REDUCED BY APPROXI-
MATELY <»OX AT l WHICH IN TURN IS A FUNCTION OF PRESSURE DROP. INCREASED SOLIDS CARRY-
OVER COULD POSSIBLY COMPUND REHEATER PLUGGING PROBLEMS. THE UTILITY IS
KEEPING A CLOSE WATCH FOR PLUGGING, BUT HAS NOT YET FOUND ANYTHING UNUSUAL.
MODULE A WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH FOR A VENTURI PIPE
LEAK.
5/78
A
B
SYSTEM
9.5
89.2
99.*
100.0
55.2
56.1
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE LAST PART OF THE MONTH BOTH MODULES WERE FORCED OUT OF THE GAS
PATH DUE TO REHEATER LEAKS. IT REQUIRED A TWO DAY OUTAGE TO REMOVE THE
LEAKING REHEATER BUNDLES. ADDITIONAL REHATERS ARE ON ORDER AND ARE EXPECT-
ED TO ARRIVE IN JUNE.
6/78
A
B
SYSTEM
87.1
85.6
9*.5
100.0
23.7
25.1
720 181
** PROBLEMS/SOLUTIONS/COMMENTS
DURING A SCRUBBER INSPECTION, 25X DIEMISTER AND 75X ABSORBER SPRAY PLUGGAGE
WAS DISCOVERED IN MODULE A. MODULE B WAS NOT AS BAD.
HIGH VIBRATION WAS ENCOUNTERED IN THE TURBINE BEARINGS DURING BOILER START
UP, CAUSING THE BOILER TO SHUT BACK DOWN.
THE PUG MILL FOR CHICAGO ADMIXTURES HAS BEEN APPROVED, AND THE NEW SLUDGE
TREATMENT SYSTEM SHOULD BE OPERATING BY FALL.
THE SCRUBBER WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH WHEN THE 1B1
ABSORBER DISCHARGE VALVE FAILED TO OPEN.
THE BOILER WAS FORCED OFF THE LAST FOUR DAYS OF THE MONTH FOR CYCLONE
LEAKS. DURING THIS OUTAGE, THE A AND B MODULE SPENT SLURRY VALVES
WERE REPLACED.
7/78
A
B
SYSTEM
97.0
99.2
100.0
100.0
11.6
11.6
77
D-19
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS PLAGUED ALL MONTH BY CYCLONE CASING LEAKS. BECAUSE OF THE
CYCLONE PROBLEMS AND THE COAL CONSERVATION PROGRAM, THE BOILER WAS ONLY
OPERATED SEVENTY-SEVEN HOURS FOR THE MONTH.
THE BOILER DOWN TIME WAS USED FOR PREVENTATIVE MAINTENANCE ON THE SCRUBBER.
SIX NEW REHEATERS WERE INSTALLED AND A DRAIN VALVE ON THE SPENT SLURRY LINE
WAS REPAIRED.
A VALVE FAILURE ON THE 1A1 ABSORBER PUMP FORCED THE SCRUBBER FROM THE GAS
PATH ONCE DURING THE MONTH.
MODULE B EXPERIENCED A LEAKING VENTURI HEADER.
8/78 A 97.8 100.0 59.1
B 99.6 100.0 59.1
SYSTEM 744 440
** PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME OPERATING OUT OF THE THICKENER.
THE SCRUBBER WASTE MATERIAL WAS TREATED WITH LIME AND FLY ASH AND HAULED
OFF TO AN OFF SITE DISPOSAL AREA.
REPAIRS TO THE VENTURI EMERGENCY SPRAY VALVE CAUSED ONE BOILER OUTAGE
DURING THE MONTH.
A REHEATER FLANGE LEAK WAS RESPONSIBLE FOR FORCING THE UNIT OFF.
MODULE A WAS FORCED OFF ONCE DUE TO HIGH VIBRATION OF THE I.D. BOOSTER FAN.
THE PROBLEM WAS CORRECTED BY REPACKING THE COUPLING ON THE FAN.
9/78 A 77.7 95.9 55.4
B 77.7 96.0 55.5
SYSTEM 720 416
** PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME OPERATING OUT OF THE THICKENER.
THE SCRUBBER WASTE MATERIAL WAS TREATED WITH LIME AND FLY ASH AND HAULED TO
AN OFF SITE DISPOSAL AREA.
REHEATER TUBE LEAKS, ONE IN MODULE A AND FOUR IN MODULE B, CAUSED ONE
BOILER OUTAGE AND CAUSED THE FGO SYSTEM TO BE UNAVAILABLE FOR A TOTAL
OF NINETY HOURS. SAMPLES OF THE TUBES HAVE BEEN SUBMITTED TO O.A.D. FOR
METALLURGICAL EXAMINATION.
A RUPTURED AIR LINE ON A VENTURI PUMP ISOLATION VALVE WOULD NOT ALLOW THE E
VALVE TO GO COMPLETELY CLOSED.
WHEN THE A VENTURI PUMP WAS STARTED, A VENTURI SPRAY HOSE RUPTURED.
IT WAS DISCOVERED THAT THE MODULE A VENTURI TANK LEVEL PRESSURE SWITCH WAS
NOT WORKING PROPERLY.
THE PUGMILL ORDERED FOR CHICAGO ADMIXTURES HAS ARRIVED ON SITE. IN OCTOBER,
THEY WILL FINISH THE CONVERSION, WHICH WILL ALLOW THE MATERIAL SERVICE
MIXER TRUCKS TO BE ELIMINATED.
IN OCTOBER, THE THICKENER WILL HAVE TO BE BYPASSED WHILE THE UTILITY DOES
MAINTENANCE ON THE RAKE AND REPLACES SOME LEAKING VALVES.
D-20
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/78 A 100.0 100.0 35.0
B 100.0 100.0 35.0
SYSTEM 744 261
** PROBLEMS/SOLUTIONS/COMMENTS
LOW BOILER HOURS WERE DUE TO FOUR OUTAGES CAUSED BY HIGH BEARING METAL
TEMPERATURES AND EXCESSIVE VIBRATION IN THE 1-B FORCED DRAFT TAN.
THE BOILER DOWN TIME WAS UTILIZED FOR CLEANING AND REPAIR OF THE VENTURI
THROAT, SUMP AND SUMP SCREENS, AND INLET BLOCK DAMPERS OF MODULE A, AS
WELL AS THE VENTURI AND ABSORBER TANKS AND SCREENS AND ALL ABSORBER SPRAY
NOZZLES OF BOTH MODULES.
ON INSPECTION, IT WAS DISCOVERED THAT THE B MODULE ABSORBER DEPARTMENTAL
DAMPER HAD SLIPPED SOX CLOSED. THE DAMPERS WERE JACKED OPEN AND WELDED
IN PLACE.
TO CORRECT A HIGH PRESSURE DROP ACROSS THE MODULE B REHEATER, A NEW METHOD
WAS EMPLOYED WHEREBY ONLY THE MIDDLE TUBES WERE REMOVED, ALLOWING THE TOP
AND BOTTOM TUBES TO BE SEEN AND CLEANED, ELIMINATING THE REMOVAL OF ALL THE
TUBES. THIS PROCEDURE CUT OUTAGE TIME FROM ONE OR TWO WEEKS TO TWO DAYS.
11/78 A 96.Z 100.0 48.3
B 85.2 100.0 48.3
SYSTEM 720 348
«* PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT WAS DOWN THREE TIMES THIS MONTH DUE TO A VENTURI PUMP AND TWO
BOOSTER FAN OUTAGES.
12/78 A 65.3 100.0 64.5
B 64.5 100.0 64.5
SYSTEM 744 480
*# PROBLEMS/SOLUTIONS/COMMENTS
REHEATER TUBE LEAKS CAUSED TWO OUTAGES.
THE MODULE B SPENT SLURRY DRAIN WAS REPAIRED.
1/79 A 83.5 100.0 61.3
B 62.2 87.1 53.4
SYSTEM 744 456
** PROBLEMS/SOLUTIONS/COMMENTS
THE S02 PLANT WAS FORCED OFF TWICE THIS MONTH DUE TO REHEATER TUBE LEAKS.
TWO TUBES ON MODULE A AND FOUR TUBES ON MODULE B WERE REPLACED.
THE I.D. BOOSTER FAN ON MODULE B WAS FOULED AND HAD TO BE REPLACED.
TWO SPECIAL SECTIONS OF VENTURI PIPING, A SIXTEEN TO EIGHT INCH ECCENTRIC
REDUCER AND AN OFFSET TEE WERE PREPARED BY LOCKPORT FABRICATING AUD INSTAL-
LED THIS MONTH. THE ORIGINAL REDUCER AND TEE HAD BEEN PATCHED AND WELDED SO
MANY TIMES THAT THEY WERE BEYOND REPAIR.
2/79 A 93.0 91.3 54.2
B 93.0 91.3 54.2
SYSTEM 672 399
D-21
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT WAS FORCED OFF ONCE FOR A MAIN STEAM HEADER LEAK.
3/79 A 100.0 100.0 46.0
B 68.6 100.0 46.0
SYSTEM 744 343
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS FORCED OUT TWICE IN FEBRUARY AND FOUR TIMES IN MARCH DUE E
TO A VENTURI HEADER LEAK. A TEN FOOT SECTION OF PIPE WILL HAVE TO BE
REPLACED DUE TO EXTENSIVE CORROSION.
THE SYSTEM WAS DOWN ONCE FOR A SPRAY HEADER LEAK.
MODULE B EXPERIENCED A LEAK IN THE VENTURI DOWNCOMER. A FIVE FOOT SECTION
OF THE PIPE WILL HAVE TO BE REPLACED.
4/79 A
SYSTEM 720
5/79 A . 0
B .0
SYSTEM 744 0
*» PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 WAS OUT OF SERVICE THE ENTIRE MONTH DUE TO A BOILER OVERHAUL.
CHICAGO ADMIXTURES WILL STOCKPILE THE FIXED SLUDGE ON STATION PROPERTY.
6/79 SYSTEM 720 0
7/79 SYSTEM 744 0
8/79 SYSTEM 744 0
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 WAS OUT OF SERVICE TO REPLACE THE AIR HEATER TUBES, TUBE SHEET AND
HOPPERS. DURING THIS OUTAGE, THE WORN VENTURI SPRAY NOZZLES AND DEMISTERS
WERE REPLACED. WELDING LEAKS AND GENERAL CLEANING OF THE S02 INTERNALS
WAS ALSO DONE AT THIS TIME.
THE BOILER AND THE SCRUBBER ARE SCHEDULED TO RETURN TO SERVICE OCTOBER 1.
1979.
720 0
744 0
85.4
85.4
85.4 720 336 336
** PROBLEMS/SOLUTIONS/COMMENTS
ON NOVEMBER 5, UNIT 1 RETURNED TO SERVICE AFTER A SIX MONTH OUTAGE TO
REPLACE THE AIR HEATER TUBES, TUBE SHEET AND HOPPERS.
DURING THE OUTAGE, SEVERAL LENGTHS OF VENTURI PIPING HAD TO BE REPLACED
WITH NEW RUBBER LINED PIPE.
D-22
9/79
10/79
11/79
SYSTEM
SYSTEM
A
B
SYSTEM
53.3
53.3
53.3
100.0
100.0
100.0
-------
UTILITY F60 SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
THE UNIT DID NOT FORCE THE BOILER OFF AT ANY TIME DURING NOVEMBER.
13/79 A 77.0 99.5 57.5
B 84.9 100.0 57.8
SYSTEM 77.0 99.5 57.5 744 431 428
** PROBLEMS/SOLUTIONS/COMMENTS
ON DECEMBER 4, UNIT 1 CAME OFF LINE SO THAT THE AIR HEATER HOPPERS AND
PRECIPITATOR HOPPERS COULD BE EMPTIED OF CARBON CARRY-OVER AND DEBRIS.
DURING THIS OUTAGE THE SHOP REPAIRED A LEAK IN THE POND RETURN LINE.
ON DECEMBER 10, THE A-MODULE DEVELOPED A SERIOUS STEAM LEAK (25,000 MAKE-
UP) IN A LOWER REHEAT BUNDLE. THE LEAKING BUNDLE HAD TO BE REMOVED AND
REPLACED. THIS RESULTED IN A TWO DAY FORCED OUTAGE. LATER IN THE MONTH
THE A-MODULE BLEW ANOTHER REHEATER TUBE FORCING THE BOILER OFF FOR AN
ADDITIONAL 25 HOURS AND 12 MINUTES.
THE A-MODULE WAS REMOVED FROM THE GAS PATH ON DECEMBER 29, FOR THREE HOURS
TO ALLOW THE MAINTENANCE SHOP TO WELD A LEAKING REHEATER FLANGE.
THE S02 PLANT FORCED THE BOILER OFF TWICE THIS MONTH. TOTAL FORCED OUTAGE
TIME ATTRIBUTED TO THE SCRUBBER WAS 54 HOURS AND 39 MINUTES.
1/80 A 91.0 87.5 63.0
B 88.6 84.1 60.6
SYSTEM 88.6 84.1 60.6 744 536 451
*» PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST SIX DAYS OF JANUARY, UNIT 1 BOILER WAS OFF THE SYSTEM BECAUSE
OF A SLAG SCREEN TUBE LEAK. THE UNIT RETURNED TO SERVICE ON JANUARY 7.
ON JANUARY 16, THE UTILITY HAD TO DERATE UNIT 1 TO 50 MW BECAUSE THE RE-
HEATER SECTIONS ON A ANT) B MODULES WERE PLUGGING. ON JANUARY 17, THE
MODULES WERE TAKEN OUT OF THE GAS PATH TO BEGIN REMOVING AND CLEANING THE
REHEATER SECTIONS WITH A HIGH PRESSURE (4000 PSD WATER SPRAY. UNIT 1
BOILER WAS LEFT ON TO PROVIDE STABILITY FOR THE 138 KV SYSTEM.
IN THE PAST, ALL 42 BUNDLES CONSISTING OF SEVEN TUBES PER BUNDLE,
HAD TO BE TAKEN OUTSIDE TO BE CLEANED ON A CONCRETE SLAB. IN THIS CASE
SINCE TIME WAS THE MOST IMPORTANT FACTOR, A DIFFERENT APPROACH WAS USED.
ONLY THE MIDDLE SIX BUNDLES ON EACH MODULE WERE REMOVED. THIS PROVIDED A
LARGE ENOUGH SPACE SO THAT A LANCE WITH AN EXTENSION ON IT COULD BE USED
TO CLEAN THE BOTTOM OF THE TWO TOP BUNDLES AND THE TOP OF THE TWO BOTTOM
BUNDLES. THERE ARE DOORS THAT ALLOW EASY ACCESS TO THE TOP AND BOTTOM
OF THE REHEATER. USING THIS METHOD, ONLY 12 OR THE 42 BUNDLES WERE
REMOVED. IN THE PAST, THIS JOB HAS TAKEN AS LONG AS TWO WEEKS TO
COMPLETE. USING THE NEW METHOD, ALL THE REHEATER BUNDLES WERE CLEANED IN
20 HOURS.
THE B-MODULE WAS FORCED OFF LINE ON TWO OTHER OCCASIONS IN JANUARY. BOTH
THESE OUTAGES WERE CAUSED BY THE REHEATER (A COIL LEAK AND A FLANGE LEAK)
TOTALING 18 HOURS AND 24 MINUTES.
2/80 A 79.7 90.5 79.7
B 78.6 89.2 78.6
SYSTEM 74.1 84.2 74.1 696 613 516
** PROBLEMS/SOLUTIONS/COMMENTS
SGRU5BER PROBLEMS IN FEBRUARY WERE CAUSED FROM LEAKS IN THE VENTURI SPRAY
HEADER. THESE LEAKS DEVELOP WHERE THE RUBBER LINING INSIDE THE VENTURI
PIPING HAS WORN AWAY SO THAT THE BARE METAL IS EXPOSED. THIS EXPOSED METAL
D-23
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F60 CAP.
S02 PART. HOURS HOURS HOURS FACTOR
IS THEN SUBJECT TO ERROSION/CORROSION. THE LINING IS MOST LIKELY TO WEAR
AT THE WELD HEAD OF THE SPRAY NOZZLE TO THE MAIN HEADER. ALL THE VENTURI
SPRAY PIPING IS BEING REPLACED.
TUBE LEAKS IN THE STEAM COIL REHEAT SYSTEM CAUSED SCRUBBER PROBLEMS THIS
MONTH. MODULE A WAS FORCED OUT ONCE AND MODULE B WAS FORCED OUT THREE
TIMES. THESE TUBES WILL BE REPLACED DURING THE NEXT OUTAGE.
3/80
A
A
SYSTEM
83.9
83.9
83.9
744
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS OUT OF SERVICE FOR ALL OF MARCH DUE TO BOILER TUBE LEAKS IN
THE REHEAT SECTION OF THE BOILER.
4/80
A
B
SYSTEM
100.0
87.7
93.9
71.0
71.0
71.4
17.3
17.3
17.3
720 175
125
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST 15 DAYS OF APRIL THE BOILER WAS OUT OF SERVICE DUE TO
TUBE LEAKS IN THE AIR PREHEATER.
WHEN ATTEMPTS WERE MADE TO BRING THE BOILER ON LINE ON THE 16 THE
B-MODULE OF THE S02 SYSTEM DEVELOPED REHEATER TUBE LEAKS. THIS CAUSED
A FORCED OUTAGE OF 53 HOURS AND 40 MINUTES.
WHEN ATTEMPTS WERE MADE TO RETURN THE BOILER TO SERVICE AGAIN, THE AUXIL-
IARY LOW PRESSURE GOVENOR DEVELOPED AN OIL LEAK CAUSING A FOUR DAY OUTAGE,
FOLLOWED BY ANOTHER REHEATER TUBE LEAK OUTAGE ON THE B MODULE. THIS
OUTAGE LASTED 35 HOURS. THE UNIT RETURNED TO SERVICE ON APRIL 24 AND
WAS AVAILABLE FOR THE REST OF APRIL.
5/80 SYSTEM
** PP.OBLEMS/SOLUTIONS/COMMENTS
744
INFORMATION WAS NOT AVAILABLE FOR THE MONTH OF MAY.
6/80
A
B
SYSTEM
86.5
86.5
86.5
100.0
100.0
100.0
81.2
81.2
81.2
720 584
584
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBING SYSTEM FORCED THE BOILER OUT OF SERVICE FROM JUIIE 6 TO
JUNE 10. THE OUTAGE WAS CAUSED BY PLUGGED REHEATERS ON BOTH MODULES.
THIS WAS THE ONLY FORCED OUTAGE EXPERIENCED DURING JUNE.
7/80
A
B
SYSTEM
87.8
87.8
87.8
78.3
78.3
78.3
55.0
55.0
55.0
744 522
409
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE MONTH OF JULY THERE WERE NO FORCED SCRUBBER OUTAGES.
TWO SLAG LINE OUTAGES, ONE FORCED DRAFT FAN AND ONE BOILER SCREEN WALL
TUBE OUTAGE OCCURRED. THIS ACCOUNTED FOR 193 HOURS OF BOILER-RELATED
OUTAGE TIME DURING THE MONTH.
D-24
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
ON NINE OCCASIONS IN JULY THE SCRUBBER WAS BY-PASSED SO THAT THE BOILER
COULD CARRY MAXIMUM LOAD (163 MW). THE UNIT WAS LIMITED TO 135 MW AFTER
A RECENT STACK EMISSION TEST.
6/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE MONTHS OF AUGUST AND SEPTEMBER.
10/80 A 69.9 100.0 60.9
B 69.9 100.0 60.9
SYSTEM 69.9 100.0 60.9 744 453 453
** PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THERE WAS ONE FORCED OUTAGE DUE TO PROBLEMS WITH THE AB-
SORBER RECIRCULATION PUMP ON MODULE B. DURING THIS OUTAGE THE WALL WASH
HEADERS WERE REPLACED ON BOTH MODULES.
DURING OCTOBER THE BOILER WAS SHUT DOWN TWICE DUE TO A LACK OF DEMAND.
THIS ACCOUNTED FOR APPROXIMATELY 51 HOURS OF DOWN TIME. ADDITIONAL UNIT
OUTAGE TIME WAS DUE TO INTERCEPT VALVE AND AIR HEATER PROBLEMS.
11/80 A 92.4 100.0 83.4 33.0
B 92.4 100.0 83.4 33.0
SYSTEM 92.4 100.0 83.4 33.0 - 720 238 238
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WITH THE SCRUBBING SYSTEM WERE
ENCOUNTERED DURING NOVEMBER.
12/80 A 77.9 100.0 31.5 31.5
B 77.9 100.0 31.5 31.5
SYSTEM 77.9 100.0 31.5 31.5 744 234 234 20.3
** PROBLEMS/SOLUTIONS/COMMENTS
DURING DECEMBER AVAILABILITY OF THE FGD SYSTEM WAS LOW DUE TO PLUGGED
VENTURI NOZZLES AND HEADER, WHICH HAD TO BE HIGH-PRESSURE JETTED.
1/81 A 82.4 100.0 80.8 80.8
B 82.4 100.0 80.8 80.8
SYSTEM 82.4 100.0 80.8 80.8 744 601 601
*» PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE MIST ELIMINATOR TRAY WAS REPLACED ON MODULE A.
2/81 A 75.4 100.0 68.9 68.9
B 75.4 100.0 68.9 68.9
SYSTEM 75.4 100.0 68.9 68.9 672 463 463 59.3
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE BOILER WAS OUT OF SERVICE APPROXIMATELY 209 HOURS DUE
TO TUBE LEAKS.
THE SCRUBBING SYSTEM WAS OUT OF SERVICE 164 HOURS DUE TO CLEANING AND A
TWO HOUR INSPECTION.
D-25
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: MILL COUNTY 1 (COKT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/81 A 70.2 100.0 68.2 68.2
B 70.2 100.0 68.2 68.2
SYSTEM 70.2 100.0 68.2 68.2
744 507 507 63.1
4/81
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH DOWNTIME OCCURRED DUE TO MISCELLANEOUS CLEANING TO THE BOILER
AND THE SCRUBBER.
A
B
SYSTEM
32.9
32.9
32.9
100.0
100.0
100.0
32.9
32.9
32.9
32.9
32.9
32.9
720 237
237 30.1
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE SCRUBBING MODULES AND THE SCRUBBER PIPING WERE CLEANED.
THIS ACCOUNTED FOR THE OUTAGE TIME DURING THE MONTH.
5/81 A
B
SYSTEM
59.1
59.1
59.1
100.0
100.0
100.0
51.0
51.0
51.0
48.1
48.1
48.1
744 358 358 42.7
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE BOILER WAS DOWN FOR 11 DAYS FOR A SCHEDULED OUTAGE.
IN MAY 41 HOURS OF OUTAGE TIME WAS DUE TO A LACK OF DEMAND.
LEAKS IN THE CYCLONE TUBES CAUSED THE SYSTEM TO SHUT DOWN FOR 53 HOURS.
TOWARD THE END OF MAY, THE SYSTEM WAS SHUTDOWN FOR 30 HOURS TO PREPARE
FOR AN EMISSION TEST.
6/81 A
B
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
63.7
63.7
63.7
720 458
458 49.4
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE NO MAJOR PROBLEMS WERE ENCOUNTERED.
D-26
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 198*
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
*» UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
»» FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
**« PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMSER
TYPE
»* ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMSER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
( .600 LB/MMBTU)
( 4.000 LB/MMBTU)
(****** LB/MMBTU)
MINNESOTA POWER & LIGHT
CLAY BOSWELL
3
COHASSET
MINNESOTA
E
258.
1720.
******
1000
364
347
350
350
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
613.47 (1300000 ACFM)
123.3 ( 254 F)
213. ( 700 FT)
CONCRETE
7.9 ( 26.0 FT)
COAL
SUBBITUMINOUS
19538.
9.00
4.8-16.0
26.00
24.0-28.0
.92
0.5-1.5
.01
0.00-0.07
0
NONE
0
NONE
0
NONE
1
5/73
IMPINGEMENT TOWER
NP
NR
KREBS ENGINEERS
18.0 X 126.0 X 52.0
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
1
714.4
1.1
( 8400 BTU/LB)
7500-9900
(11340 GPM)
( 8.3 GAL/1000ACF)
0-27
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
MINNESOTA POWER & LIGHT: CLAY BOSWELL 3 (CONT.)
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
SOS REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
ALKALINE FLYASH
1.0
2.4
613.5
123.3
98.7
.8
( 4.0 IN-H20)
( 8.0 FT/S)
(1300000 ACFM)
( 254 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/73 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN MAY 1973 SCALING AND PLUGGING HAVE OCCURRED IN NOZZLES,
NOZZLE TREES, STRAINERS, ON PUNCH PLATE BAFFLES, IN THE WET/DRY ZONE, AND
ON THE FAN AND THE MIST ELIMINATOR. PLUGGING HAS ALSO RESULTED AS DEPOSITS
HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SCRUBBER. DUE TO THE
CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL BURNED, THE SCALING
IS AGGRAVATED. THE UTILITY HAS CONTROLLED SCALE BY SLOWDOWN OF THE
SCRUBBING SYSTEM. THIS HAS MAINTAINED THE PROCESS CHEMISTRY BELOW SATURA-
TION WITH RESPECT TO CALCIUM SULFITE. A VERY HIGH LEVEL OF MAINTENANCE
HAS BEEN MAINTAINED ALSO TO MINIMIZE SCALE ACCUMULATION AND PLUGGING, THIS
HAS INCLUDED WASHING OF THE WET FAN WHICH HAS RESULTED IN A STACK MIST
PROBLEM. THE USE OF SOOT BLOWERS IN PLACE OF WASHING WAS ATTEMPTED BUT
WAS UNSUCCESSFUL. THE UTILITY HAS REDUCED THE AMOUNT OF WASHING AND HAS
CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEW LOW-VELOCITY
STACK.
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FOURTH QUARTER 1979.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
«* PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
4/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80 SYSTEM
8/80 SYSTEM
100.0
100.0
100.0
100.0
90.3
78.0
720 650 650 60.2
744 580 580 52.3
D-28
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
MINNESOTA POWER & LIGHT: CLAY BOSWELL 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/80 SYSTEM 100.0 100.0 84.0 744 625 625 54.8
** PROBLEMS/SOLUTIONS/COMMENTS
NO OPERATIONAL PROBLEMS WERE REPORTED FOR THE JULY THROUGH SEPTEMBER
PERIOD.
10/80
11/80
12/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100
100
100
.0
.0
.0
85
81
81
.9
.5
.6
744
720
744
639
587
607
639
587
607
62.3
64.6
60.9
«* PROBLEMS/SOLUTIONS/COMMENTS
1/81
2/81
3/81
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
THE UTILITY
THE FOURTH
100.0
100.0
100.0
REPORTED THAT
QUARTER 1980.
100
100
100
.0
.0
.0
NO SCRUBBER
94
97
79
.3
.0
.0
PROBLEMS WERE ENCOUNTERED
744
672
744
702
651
585
DURING
702
651
585
69.1
73.2
65.1
»* PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS MERE ENCOUNTERED
DURING THE FIRST QUARTER 1981.
DURING MARCH THE BOILER WAS OUT OF SERVICE APPROXIMATELY 159 HOURS TO RE-
PAIR STEAM LEAKS AND TO PERFORM MAINTENANCE.
720 447 447 50.9
744 709 709 79.3
720 696 696 75.7
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED DURING THE
SECOND QUARTER 1981.
4/81 SYSTEM
5/81 SYSTEM
6/81 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
62.1
95.3
96.7
D-29
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
( .600 LB/MMBTU)
( 4.000 LB/MMBTU)
(****** LB/MMBTU)
MINNESOTA POWER * LIGHT
SYL LASKIN
1
AURORA
MINNESOTA
E
258.
1720.
******
116
62
57
58
58
COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
141.57 (
171.1 (
91. (
CONCRETE
3.2
300000 ACFM)
340 F)
300 FT)
COAL
SUBBITUMINOUS
20469.
9.00
4.8-16.0
26.70
24.0-28.0
1.00
0.5-1.5
.01
0.00-0.07
0
NONE
0
NONE
0
NONE
1
6/71
IMPINGEMENT TOWER
NR
NR
KREBS ENGINEERS
34.0 X 18.0 X 23.0
STAINLESS STEEL
AUSTENITIC
NOME
N/A
NONE
1
151.2
1.1
( 10.5 FT)
( 8800 BTU/LB)
7509-9923
( 2400 GPM)
( 8.3 GAL/1000ACF)
D-30
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
MINNESOTA POWER * LIGHT: SYL LASKIN 1 (CONT.)
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
ALKALINE FLYASH
.6
2.1
137.4
171.1
• .0
97.8
1.6
( 2.5 IN-H20)
( 7.0 FT/S)
( 291160 ACFM)
( 340 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/71 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JUNE 1971 SCALING AND PLUGGING HAVE OCCURRED IN NOZZLES.
NOZZLE TREES, STRAINERS, ON PUNCH PLATE BAFFLES, IN THE WET/DRY ZONE, AND
ON THE FAN AND THE MIST ELIMINATOR. PLUGGING HAS ALSO RESULTED AS DEPOSITS
HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SCRUBBER. DUE TO THE
CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL BURNED, THE SCALING
IS AGGRAVATED. THE UTILITY HAS CONTROLLED SCALE BY SLOWDOWN OF THE
SCRUBBING SYSTEM. THIS HAS MAINTAINED THE PROCESS CHEMISTRY BELOW SATURA-
TION WITH RESPECT TO CALCIUM SULFITE. A VERY HIGH LEVEL OF MAINTENANCE
HAS BEEN MAINTAINED ALSO TO MINIMIZE SCALE ACCUMULATION AND PLUGGING, THIS
HAS INCLUDED WASHING OF THE WET FAN WHICH HAS RESULTED IN A STACK MIST
PROBLEM. THE USE OF SOOT BLOWERS IN PLACE OF WASHING WAS ATTEMPTED BUT
WAS UNSUCCESSFUL. THE UTILITY HAS REDUCED THE AMOUNT OF WASHING AND HAS
CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEW LOW-VELOCITY
STACK.
THE PROBLEMS AT SYL LASKIN ARE NOT AS SEVERE AS THE PROBLEMS AT CLAY
BOSWELL DUE TO THE FACT THAT THE RECYCLE LOOP IS NOT CLOSED TO THE SAME
EXTENT. THE MIST CARRYOVER PROBLEM IS LESS SEVERE OWING TO OPERATION OF
THE UNIT AT PARTIAL LOAD RESULTING IN A LOWER STACK VELOCITY.
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
744
720
744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FOURTH QUARTER 1979.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
4/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
»* PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
D-31
-------
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
.0
24.3
64.1
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
MINNESOTA POWER & LIGHT: SYL LASKIN 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80 SYSTEM 100.0 100.0 100.0 56.6 744 421 421 25.2
8/80 SYSTEM 100.0 100.0 100.0 19.0 744 140 140 12.0
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO BOILER OR FGD-RELATED PROBLEMS WERE ENCOUNTER-
ED DURING JULY AND AUGUST. LOW UTILIZATION FACTORS WERE DUE TO A LACK
OF POWER DEMAND.
9/80 SYSTEM 100.0 100.0 100.0 4.4 720 33 33 1.9
** PROBLEMS/SOLUTIONS/COMMENTS
NO SCRUBBER OUTAGES OCCURRED DURING SEPTEMBER. THE LOW UTILIZATION FACTOR
WAS AGAIN THE RESULT OF A LACK OF DEMAND FOR POWER.
744 0 744 .0
720 175 175 10.2
744 477 477 23.4
»* PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS OCCURRED DURING
THE FOURTH QUARTER 1980. LOW UTILIZATION FACTORS WERE CAUSED BY A LACK
OF POWER DEMAND.
1/81 SYSTEM 78.5 100.0 100.0 78.5 744 524 524 23.8
*« PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE BOILER WAS OUT OF SERVICE APPROXIMATELY 160 HOURS DUE
TO A TURBINE STEAM LEAK. THE BOILER WAS OUT OF SERVICE AN ADDITIONAL 60
HOURS DUE TO A LACK OF POWER DEMAND.
2/81 SYSTEM 5.4 100.0 100.0 5.4 672 36 36 17.4
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE BOILER REMAINED OFF LINE FOR APPROXIMATELY 708 HOURS
TO REPAIR A TURBINE STEAM LEAK.
3/81 SYSTEM 99.1 100.0 100.0 79.0 744 588 588 44.8
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THE BOILER WAS OUT OF SERVICE SEVEN HOURS TO CLEAN THE ID FANS
AND 77 HOURS DUE TO A LACK OF DEMAND.
4/81 SYSTEM 100.0 100.0 100.0 100.0 720 720 720 46.0
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL 10 HOURS OF OUTAGE TIME WAS NECESSARY TO WORK ON THE EXCITER.
5/81 SYSTEM 64.1 100.0 100.0 64.0 744 476 476 31.3
0-32
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
MINNESOTA POWER £ LIGHT: SYL LASKIN 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE UNIT WAS OUT OF SERVICE 209 HOURS FOR AN OVERHAUL.
SYSTEM DOWN TIME WAS NEEDED TO REPAIR A STEAM DRIVEN OIL PUMP.
FOLLOWING A TEST THE SYSTEM WAS TAKEN OFF-LINE FOR SANDBLASTING ID FANS.
6/81 SYSTEM 100.0 .0 720 0 0
** PROBLEMS/SOLUTIONS/COMMENTS
IN JUNE THE UNIT WAS DOWN DUE TO A LACK OF DEMAND. DURING THIS PERIOD
GENERAL MAINTENANCE WAS PERFORMED.
D-33
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
RANGE ASH CONTENT - V.
• AVERAGE MOISTURE CONTENT - V.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - V.
RANGE SULFUR CONTENT - Y.
AVERAGE CHLORIDE CONTENT - V.
RANGE CHLORIDE CONTENT - Z
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATICN RATE - LITER/S
L/G RATIO - LITER/CU.M
MINNESOTA POMER & LIGHT
SYL LASKIN
2
AURORA
MINNESOTA
E
258.
1720.
******
116
62
57
58
58
COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
141.57 (
171.1 (
91. (
CONCRETE
3.2
( .600 LB/MMBTU)
( 4.000 LB/MMBTU)
(****** LB/MMBTU)
300000 ACFM)
340 F)
300 FT)
( 10.5 FT)
COAL
SUBBITUMINOUS
20469.
9.00
4.8-16.0
26.70
24.0-28.0
1.00
0.5-1.5
.01
0.00-0.07
0
NONE
0
NONE
0
NONE
1
6/71
IMPINGEMENT TOWER
NR
NR
KREBS ENGINEERS
34.0 X 18.0 X 23.0
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
1
151.2 (
1.1 (
( 8800 BTU/LB)
7509-9923
2400 GPM)
8.3 GAL/1000ACF)
D-34
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
MINNESOTA POWER & LIGHT: SYL LASKIN 2 (CONT.)
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
ALKALINE FLYASH
.6
2.1
137.4
171.1
.0
97.8
1.6
( 2.5 IN-H20)
( 7.0 FT/S)
( 291160 ACFM)
( 340 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/71 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JUNE 1971 SCALING AND PLUGGING HAVE OCCURRED IN NOZZLES,
NOZZLE TREES> STRAINERSi ON PUNCH PLATE BAFFLES, IN THE WET/DRY ZONE AND
ON THE FAN AND THE MIST ELIMINATOR. PLUGGING HAS ALSO RESULTED AS DEPOSITS
HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SCRUBBER. DUE TO THE
CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL BURNED, THE SCALING
IS AGGRAVATED. THE UTILITY HAS CONTROLLED SCALE BY SLOWDOWN OF THE
SCRUBBING SYSTEM. THIS HAS MAINTAINED THE PROCESS CHEMISTRY BELOW SATURA-
TION WITH RESPECT TO CALCIUM SULFITE. A VERY HIGH LEVEL OF MAINTENANCE
HAS BEEN MAINTAINED ALSO TO MINIMIZE SCALE ACCUMULATION AND PLUGGING, THIS
HAS INCLUDED WASHING OF THE WET FAN WHICH HAS RESULTED IN A STACK MIST
PROBLEM. THE USE OF SOOT BLOWERS IN PLACE OF WASHING WAS ATTEMPTED BUT
WAS UNSUCCESSFUL. THE UTILITY HAS REDUCED THE AMOUNT OF WASHING AHD HAS
CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEW LOW-VELOCITY
STACK.
THE PROBLEMS AT SYL LASKIN ARE NOT AS SEVERE AS THE PROBLEMS AT CLAY
BOSWELL DUE TO THE FACT THAT THE RECYCLE LOOP IS NOT CLOSED TO THE SAME
EXTENT. THE MIST CARRYOVER PROBLEM IS LESS SEVERE OWING TO OPERATION
OF THE UNIT AT PARTIAL LOAD RESULTING IN A LOWER STACK VELOCITY.
SYSTEM 744
SYSTEM 720
SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FOURTH QUARTER 1979.
SYSTEM 744
SYSTEM 696
SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
10/79
11/79
12/79
1/80
2/80
3/80
4/80
5/80
6/80
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
D-35
-------
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
26.3
76.0
70.8
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
MINNESOTA POWER & LIGHT: SYL LASKIN 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80 SYSTEM 100.0 100.0 100.0 24.5 744 182 182 12.3
«* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER DID NOT OPERATE MOST OF JULY DUE TO A BOILER INSPECTION. NO
PROBLEMS WERE ENCOUNTERED WITH THE FGD UNIT.
8/80 SYSTEM 100.0 100.0 100.0 15.0 744 115 115 5.0
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER OPERATED ONLY 115 HOURS DURING AUGUST DUE TO A LACK OF DEMAND.
9/80 SYSTEM 100.0 100.0 100.0 5.2 720 39 39 2.4
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORT THAT NO SCRUBBER OUTAGES OCCURRED DURING SEPTEMBER.
THE LOW UTILIZATION FACTOR RESULTED FROM A LACK OF DEMAND FOR
POWER.
744 195 195 15.0
720 547 547 37.2
744 527 527 34.9
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS WERE ENCOUNTERED
DURING THE FOURTH QUARTER.
1/81 SYSTEM 100.0 100.0 100.0 45.3 744 337 337 23.8
** PROBLEMS/SOLUTIOHS/COMMENTS
DURING JANUARY THE BOILER WAS OUT OF SERVICE APPROXIMATELY 407 HOURS DUE
TO A LACK OF POWER DEMAND.
2/81 SYSTEM 100.0 100.0 100.0 97.4 672 653 653 28.5
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS
OCCURRED.
3/81 SYSTEM 100.0 .0 744 0 0 .0
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THE BOILER WAS OUT OF SERVICE TO FIND THE CAUSE OF A TURBINE
VIBRATION.
4/81 SYSTEM 88.2 100.0 100.0 56.4 720 406 406 26.9
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL 229 HOURS OF DOWN TIME WAS DUE TO A LACK OF DEMAND.
THE UNIT WAS DOWN 109 HOURS FOR A BEARING CHECK AND REPAIR DUE TO HIGH
VIBRATION.
5/81 SYSTEM 94.1 100.0 100.0 55.0 744 409 409 28.7
D-36
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 198
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANSE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICLE REMOVAL EFFICENCY -7.
** ESP
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
MONTANA-DAKOTA UTILITIES
LEWIS 4 CLARK
1
SIDNEY
MONTANA
E
86. (
430. (
******
200 LB/MMBTU)
000 LB/MMBTU)
I****** LB/MMBTU)
50
55
50
52
55
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
153.37
215.6
76.
CARBON STEEL
4.4
( 325000 ACFM)
( 420 F)
( 250 FT)
( 14.5 FT)
COAL
LIGNITE
15003.
7.80
7.2-9.3
36.20
34.3-38.2
.61
0.3-1.4
.03
******
MULTICLONE
WESTERN PREC.
106.2
176.7
.4
85.7
( 6450 BTU/LB)
6200-6700
DIVISION, JOY
( E25000 ACFM)
( 350 F)
( 1. IN-H20)
VENTURI TOWER
VARIABLE-THROAT/BOTTOM-ENTRY LIQUID DISTRIBUTION
FLOODED DISC SCRUBBER
RESEARCH-COTTRELL
10.5 DIA X 27.0
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NONE
212.6
1.7
LIMESTONE
3.2
148.0
( 3374 GPM)
(13.0 GAL/1000ACF)
(13.0 IN-H20)
( 313730 ACFM)
D-38
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
MONTANA-DAKOTA UTILITIES: LEWIS & CLARK 1 (CONT.)
INLET GAS TEMPERATURE - C 215.6 ( 420 F)
ENERGY CONSUMPTION - 7. 3.6
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM 720
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING A SCHEDULED BOILER OUTAGE GENERAL SCRUBBER MAINTENANCE WAS
PERFORMED.
11/79 SYSTEM 720
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING NOVEMBER THE SCRUBBER WAS TEMPORARILY BYPASSED TO ALLOW FOR REPAIRS
NECESSITATED BY A LEAK IN THE FLOODED DISC SCRUBBER.
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER PROBLEMS OCCURRED DURING DECEMBER.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
*« PROBLEMS/SOLUTIONS/COMMENTS
DURING THE JANUARY THROUGH MARCH PERIOD THE SCRUBBER WAS AVAILABLE MORE
THAN 95X OF THE TIME.
THE EROSION PROBLEM MENTIONED DURING NOVEMBER CONTINUED. SECTIONS OF THE
EXTERIOR CARBON STEEL LINED COLUMN WALL SUPPORTING THE FLOODED DISC WERE
ERODING, FILLING THE INNER CHAMBER WITH SLURRY AND ULTIMATELY RENDERING THE
DISC MOVEMENT MECHANISM INOPERATIVE. THE UTILITY HAS MANAGED TO KEEP THE
SCRUBBER OPERATING AS A STOP-GAP MEASURE BETWEEN UNIT SHUTDOWNS BY INSERT-
ING A GARDEN HOSE IN THE COLUMN HOLES AND CONTINUALLY FLUSHING THE INNER
CHAMBER. THE UTILITY HAS HAD SOME SUCCESS IN OTHER EROSION AREAS BY
MAKING REPAIRS WITH A HASTELLOY MATERIAL. PLANS ARE BEING MADE TO JACKET
THE ENTIRE DISC SUPPORT COLUMN WITH HASTELLOY G.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUT DOWN FOR TWO WEEKS IN MAY.
CREWS INSPECTING THE SCRUBBING SYSTEM DISCOVERED THAT THE NINE FOOT SCRUB-
BER LINER SECTION AT THE BOTTOM OF THE CYCLONIC MIST ELIMINATOR WAS SEVERE-
LY ERRODED. THE LINER HAS LASTED THREE YEARS. THE UTILITY CONSIDERS THIS
A NORMAL MAINTENANCE PROBLEM. AT ONE TIME LINERS IN THIS SECTION WERE RE-
PLACED EVERY SIX MONTHS. REPLACEMENT WORK ON THE LATEST FAILURE IS EXPECT-
ED TO BEGIN BY JULY 21.
THE ENTIRE SCRUBBER COLUMN SUPPORTING THE DISC WHICH WAS ERODING AS REPORT-
ED DURING THE PREVIOUS TWO QUARTERS HAS BEEN CLAD WITH HASTELLOY G.
D-39
-------
UTILITY FGD SURVEY: OCTOBER 1933 - SEPTEMBER 1984
MONTANA-DAKOTA UTILITIES: LEWIS t CLARK 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
THE UTILITY REPORTED THAT THE SCRUBBER HAS EXPERIENCED PLUGGING AT WET/DRY
INTERFACES WITHIN THE STRUCTURE. IT APPEARS THAT THIS IS RELATED TO COAL
SULFUR CONTENT. WHEN THE SULFUR CONTENT IS RELATIVELY HIGH (0.7 TO l.OX AT
LEWIS AND CLARK) THE PLUGGING DOES NOT OCCUR. LIMESTONE IS ADDED AS RE-
QUIRED TO PREVENT THE OCCURRANCE OF LOW PH LEVELS. WHEN THE SULFUR CONTENT
FALLS TO THE 0.3X RANGE THE PH RISES AS A RESULT OF THE ALKALINE CONSTITU-
ENTS IN THE FLY ASH UNTIL SOFT SCALE PLUGGING RESULTS. THE UTILITY HAS
CONSIDERED ADDING ACID TO STABILIZE THE PH WHEN THE COAL SULFUR CONTENT
DROPS.
7/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY TWO WEEKS OF DOWN TIME WAS NECESSARY TO REPLACE THE MIST
ELIMINATOR LINER.
THE PROBLEM WITH THE FLOODED DISC BUILDUP MENTIONED EARLIER CONTINUED.
THE UTILITY PERFORMS THE NECESSARY REPAIRS IN THREE TO FOUR HOURS WHEN
THIS OCCURS.
fl/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH SCRUBBING
OPERATIONS DURING THE MONTHS OF AUGUST AND SEPTEMBER.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH THE
SCRUBBING OPERATIONS DURING THE OCTOBER THROUGH DECEMBER PERIOD.
SCRUBBING OPERATIONS WERE SHUTDOWN FOR ONE WEEK DURING THE LAST PART OF
OCTOBER FOR A SCHEDULED MAINTENANCE OVERHAUL AND NO PROBLEMS WERE FOUND.
1/81 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR SCRUBBER PROBLEMS OCCURRED DURING
JANUARY.
2/81 SYSTEM 672
** PROBLEMS/SOLUTIONS/COMMENTS
ON FEBRUARY 10 THE SCRUBBER WAS SHUT DOWN FOR FIVE HOURS DUE TO A PLUGGED
VENTURI.
ON FEBRUARY 23 A LEAK WAS DISCOVERED ON THE OUTER WALL OF THE SCRUBBER,
LOCATED BELOW THE VENTURI. THE LEAK WAS TEMPORARILY REPAIRED FROM THE
OUTSIDE WILE THE SCRUBBER REMAINED ON-LINE. THE UTILITY PUNNED TO REPAIR
THE LEAK DURING THE SCHEDULED OUTAGE IN MARCH.
3/81 SYSTEM 744
D-40
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
MONTANA-DAKOTA UTILITIES: LEWIS t CLARK 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
«* PROBLEMS/SOLUTIONS/COMMENTS
THE SCHEDULED OUTAGE PERIOD WAS HELD FROM MARCH 3 TO 15. DURING THIS TIME
THE VENTURI AND SUMP WERE INSPECTED. THE LEAK DISCOVERED EARLIER IN FEB-
RUARY WAS REPAIRED CORRECTLY.
D-41
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY H/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BCILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RAN3E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** PARTICLE SCRUBBER
HUM3ER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
502 REMOVAL EFFICENCY - 7.
PARTICLE REMOVAL EFFICIENCY - 7.
ENERGY CONSUMPTION - 7.
PACIFIC POWER & LIGHT
DAVE JOHNSTON
4
GLENROCK
WYOMING
C
90. ( .210 LB/MMBTU)
215. ( .500 LB/MMBTU)
****** (****** LB/MMBTU)
*****
330
327
330
330
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
707.85 (1500000 ACFM)
132.2 ( 270 F)
76. ( 250 FT)
NR
******* (***** FT)
( 7430 BTU/LB)
5000-9000
COAL
SUBBITUMINOUS
17282.
12.00
******
26.00
******
.50
******
.04
******
3
4/72
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
GE ENVIRONMENTAL SERVICES
CARBON STEEL
AISI 1110
ORGANIC
POLYESTER
N/A
409.5
1.7
( 6500 6PM)
(13.0 GAL/1000ACF)
LIME/ALKALINE FLYASH
2.5
327.5
135.0
40.0
99.7
.9
(10.0 IN-H20)
( 694000 ACFM)
( 275 F)
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PACIFIC POWER & LIGHT: DAVE JOHNSTON 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/72 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN APRIL 1972, THE SCRUBBING UNIT HAS EXPERIENCED MAJOR
SCALING PROBLEMS. HARD GYPSUM SCALE ACCUMULATES IN THE SCRUBBER VESSELS
AND PIPING. THE USE OF LIME FOR PH CONTROL AND LIGNO SULFONATE TO ALTER
THE HARDNESS OF DEPOSITS IMPROVED THE SCALE PROBLEM. FRESH WATER WASHING
HAS BEEN REQUIRED TO FLUSH ASH AND SCALE DEPOSITS FROM THE SCRUBBER
VESSELS.
SOLIDS BUILDUP HAS OCCURRED AT THE WET-DRY INTERFACE AND IN THE BLEED AND
RECYCLE LINES. THE UTILITY IS USING AN ADDITIVE (HEXAMATA PHOSPHATE) IN
WHICH THE EFFECTS HAVE YET TO BE DETERMINED.
ADDITIONAL OPERATING PROBLEMS EXPERIENCED SINCE STARTUP INCLUDE ERROSION
IN THE RECYCLE PUMP AND "SILTING" DURING SHUTDOWN.
THE UTILITY CHARACTERIZED THE AVAILABILITY AS BEING DEPENDENT ON THE
AMOUNT OF SLOWDOWN AND FRESH WATER IRRIGATION THAT ARE EMPLOYED.
10/79 SYSTEM 7*4
11/79 SYSTEM 720
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION MAS AVAILABLE FOR THE FOURTH QUARTER 1979.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FIRST QUARTER OF 1980.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS OCCURRED DURING THE SECOND
QUARTER OF 1960.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE THIRD QUARTER OF 1980.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
D-43
-------
UTILITY FGD SURVEY: OCTOBER 1933 - SEPTEMBER 198*
PACIFIC POWER & LIGHT: DAVE JOHNSTON 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOS PART. HOURS HOURS HOURS FACTOR
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH THE
SCRUBBING OPERATIONS DURING THE OCTOBER THROUGH DECEMBER PERIOD.
1/81 SYSTEM 744
2/61 SYSTEM 672
3/81 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FIRST QUARTER 1981.
D-44
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
»* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
«* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
«* ESP
TYPE
»* PARTICLE SCRUBBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
POTOMAC ELECTRIC POWER
DICKERSON
DICKERSON
MARYLAND
******
******
******
******
1348
190
183
*****
190
(«***** LB/MMBTU)
(****** LB/MMBTU)
(****»* LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
******
******** (******* ACFM)
******* (**** F)
213. ( 700 FT)
CONCRETE
******* (***** FT)
( 11700 BTU/LB)
******
COAL
******
27214.
14.00
******
********
6.0-7.0
2.00
******
********
******
COLD SIDE
0/78
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
CARBON STEEL
AISI 1110
NR
NR
NONE
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
100.0
96.0
100.0
83.6
80.1
87.4
744 622 622
720 601 577
744 650 650
D-45
-------
UTILITY FGD SURVEYS OCTOBER 1983 - SEPTEMBER 1984
POTOMAC ELECTRIC POWER: DICKERSON 1 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION '/. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THIS PERIOD ONLY ONE SCRUBBER RELATED OUTAGE OCCURRED. THE OUTAGE
WAS FOR AN ID FAN INSPECTION WHICH LASTED ONE DAY.
1/80 SYSTEM 100.0 100.0 100.0 744 744 744
2/80 SYSTEM 94.3 95.8 94.3 696 685 656
3/80 SYSTEM 100.0 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980 ONLY ONE SCRUBBER OUTAGE OCCURRED. IN
FEBRUARY OUTAGE TIME WAS NECESSARY TO REPAIR A SLURRY RECYCLE LINE LEAK.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
DICKERSON 1 SCRUBBER DEPENDABILITY FACTORS WERE UNAVAILABLE FOR THE APRIL-
JUNE PERIOD. THESE FIGURES SHOULD BE AVAILABLE BY THE THIRD QUARTER
REPORT. THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED THE ENTIRE
SECOND QUARTER WITH ESSENTIALLY 100X AVAILABILITY. NO SCRUBBER-RELATED
PROBLEMS WERE REPORTED.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
JULY-SEPTEMBER PERIOD.
THE BOILER CAPACITY WAS REDUCED DURING PART OF THE PERIOD DUE TO A LINING
FAILURE IN THE SCRUBBING SYSTEM PIPING.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE BOILER WAS OPERATED AT A
60X (110 MW) CAPACITY DUE TO A LINING FAILURE IN THE SCRUBBING SYSTEM
PIPING.
1/81 SYSTEM 97.0 88.1 91.9 82.1 744 694 611
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY APPROXIMATELY 53 HOURS OF OUTAGE TIME WAS CAUSED BY PROBLEMS
WITH THE RECYCLE LINE REDUCER AND THE BLEED LINE SPOOL.
2/81 SYSTEM .0 .0 672 0 0
D-46
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
POTOMAC ELECTRIC POWER: DICKERSON 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/81 SYSTEM .0 .0 744 0 0
** PROBLEMS/SOLUTIONS/COMMENTS
DICKERSON UNITS 1, 2 AND 3 WERE SHUT DOWN SO THAT THE STACK AND THE COMMON
DUCT LEADING TO THE STACK COULD BE RELINED WITH PLASITE. UNIT 1 WAS SHUT
DOWN ON JANUARY 31 AND REMAINED DOWN THROUGHOUT FEBRUARY AND MARCH DUE TO
THESE REPAIRS.
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
TYPE
** PARTICLE SCRUBBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRACE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
POTOMAC ELECTRIC POWER
DICKERSON
DICKERSON
MARYLAND
******
******
******
******
1348
190
183
*****
190
(****** LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
******
******** (******* ACFM)
******* (**** F )
213. ( 700 FT)
CONCRETE
******* (***** FT)
( 11700 BTU/LB)
******
COAL
******
27214.
14.00
******
********
6.0-7.0
2.00
******
********
******
COLD SIDE
0/78
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
CARBON STEEL
AISI 1110
NR
NR
NONE
2
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
100.0
96.4
100.0
97.0
88.9
100.0
744 722 722
720 664 640
744 744 744
0-48
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
POTOMAC ELECTRIC POWER: DICKERSON 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
A ONE DAY OUTAGE OCCURRED, DUE TO A FAN LINING PROBLEM. NO OTHER
SCRUBBER UNIT PROBLEMS MERE ENCOUNTERED DURING THE PERIOD.
1/80 SYSTEM 95.* 96. 4 95.4 744 736 710
** PROBLEMS/SOLUTIONS/COMMENTS
IN JANUARY THE SCRUBBER WAS DOWN FOR THREE HOURS TO REPAIR A SLURRY
RECYCLE LINE LEAK.
31 HOURS OF THE OUTAGE TIME IN JANUARY WAS NECESSARY TO REPAIR A RECYCLE
PUMP.
2/80 SYSTEM 100.0 100.0 100.0 696 696 696
3/80 SYSTEM 96.9 96.9 96.9 744 7** 721
** PROBLEMS/SOLUTIONS/COMMENTS
IN MARCH THE SCRUBBER WAS DOWN FOR A SCRUBBER LINING WARRANTY INSPECTION.
NO REPAIR WORK WAS NECESSARY.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
*» PROBLEMS/SOLUTIONS/COMMENTS
DICKERSON 2 SCRUBBER DEPENDABILITY FACTORS WERE UNAVAILABLE FOR THE APRIL-
JUNE PERIOD. THESE FIGURES SHOULD BE AVAILABLE BY THE THIRD QUARTER
REPORT. THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED THE ENTIRE
SECOND QUARTER WITH ESSENTIALLY 100X AVAILABILITY. NO SCRUBBER-RELATED
PROBLEMS WERE REPORTED.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY HAS NOT FIGURED OUT THE DEPENDABILITY FIGURES AS YET.
THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
JULY-SEPTEMBER PERIOD.
THE BOILER CAPACITY WAS REDUCED DURING PART OF THE PERIOD DUE TO A LINING
FAILURE IN THE SCRUBBING SYSTEM PIPING.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
D-49
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
POTOMAC ELECTRIC POWER: DICKERSON 2 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE BOILER WAS OPERATED AT A
60X (110 MW) CAPACITY DUE TO A LINING FAILURE IN THE SCRUBBING SYSTEM
PIPING.
1/81 SYSTEM 96.9 92.8 100.0 81.9 744 654 607
2/81 SYSTEM .0 .0 672 0 0
3/81 SYSTEM .0 .0 744 0 0
** PROBLEMS/SOLUTIONS/COMMENTS
OICKERSON UNITS 1, 2 AND 3 WERE SHUT DOWN SO THAT THE STACK AND THE COMMON
DUCT LEADING TO THE STACK COULD BE RELINED WITH PLASITE. UNIT 2 WAS SHUT
DOWN ON JANUARY 31 AND REMAINED DOWN THROUGHOUT FEBRUARY AND MARCH DUE TO
THESE REPAIRS.
D-50
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 198*
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
POTOMAC ELECTRIC POWER
DICKERSON
3
DICKERSON
MARYLAND
******
****** (******
668. ( 1.600
****** ( ******
548
190
178
182
95
LB/MMBTU)
LB/MMBTU )
LB/MMBTU)
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICIENCY - 7.
ENERGY CONSUMPTION - 7.
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
278.42 ( 590000 ACFM)
126.1 ( 259 F)
213. ( 700 FT)
CONCRETE
******* (***** FT)
COAL
BITUMINOUS
27214.
14.00
******
********
6.0-7.0
2.00
******
********
( 11700 BTU/LB)
******
0
NONE
0
NONE
1
9/75
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
GE ENVIRONMENTAL SERVICES
CARBON STEEL
AISI 1110
ORGANIC
FIBER-REINFORCED POLYESTER
NONE
2.7 (20.0 GAL/1000ACF)
2.7 (11.0 IN-H20)
139.2 ( 295000 ACFM)
126.1 ( 259 F)
99.0
2.1
D-51
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/73 SYSTEM 720
10/73 SYSTEM 744
11/73 SYSTEM 720
12/73 SYSTEM 744
1/74 SYSTEM 744
** PROSLEMS/SOLUTIONS/COMMENTS
PROBLEMS DURING THIS PERIOD RANGED FROM CORROSION LEAKS IN EXPANSION JOINTS
TO PROBLEMS IN MATERIAL HANDLING EQUIPMENT, FEEDING AND SLAKING OF MGO,
PLUGGING IN THE MGO MIX TANK AND SUCTION LINES TO THE MGO MAKE-UP PUMPS.
2/74 SYSTEM 672
3/74 SYSTEM 744
4/74 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
MAINTENANCE AND MODIFICATIONS WERE PERFORMED ON THE SYSTEM. THE MAJOR
SYSTEM REVISION MADE DURING THIS PERIOD WAS THE ADDITION OF A PRE-MIX TANK
IN THE MGO SYSTEM.
5/74 SYSTEM 744
6/74 SYSTEM 720
7/74 SYSTEM 744
»* PROBLEMS/SOLUTIONS/COMMENTS
LIMITED OPERATION OCCURRED BECAUSE THE UTILITY DID NOT HAVE ACCESS TO THE
EPA CALCINING FACILITY AT THE ESSEX CHEMICAL COMPANY SULFURIC ACID PLANT.
BY THE END OF JUNE 1974, ALL THE MGO AT DICKERSON HAD BEEN USED AND A SILO
PLUS THREE CARS WERE FULL OF MGS03.
8/74 SYSTEM 744 a7
9/74 SYSTEM 720
10/74 SYSTEM 744
11/74 SYSTEM 720
12/74 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THIS PERIOD THE SYSTEM GENERALLY OPERATED AT 75 PERCENT OF THE
DESIGN GAS FLOW.
1/75 SYSTEM 7^
** PROBLEMS/SOLUTIONS/COMMENTS
PROBLEMS DEVELOPED IN THE BUCKET ELEVATOR TRANSPORTING THE MGS03 FROM THE
DRYER TO THE STORAGE SILO.
2/75 SYSTEM 672
D-52
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/75 SYSTEM 744
4/75 SYSTEM 720
5/75 SYSTEM 744
6/75 SYSTEM . 720
7/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT NO. 3 WAS TAKEN OUT OF SERVICE FOR AN 8 TO 12 WEEK TURBINE OVERHAUL.
THE SCRUBBER WAS INSPECTED, MAINTENANCE AND MODIFICATIONS WERE MADE.
8/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGO SYSTEM CONSISTS OF A SINGLE, TWO-STAGE SCRUBBER/ABSORBER, WHICH
INCORPORATES AN ADJUSTABLE-THROAT VENTURI SCRUBBER FOR PARTICULATE REMOVAL
AND A SECOND STAGE ABSORBER WITH A FIXED VENTURI TO REMOVE S02. THE LIQUOR
STREAMS FOR BOTH STAGES ARE SEPARATE AND OPERATE IN A CLOSED-LOOP MODE.
UNTIL MID-1975 THE MAGNESIUM SULFITE GENERATED WAS TRANSFERRED TO AN EPA
FINANCED FACILITY AT THE ESSEX CHEMICAL COMPANY SULFURIC ACID MANUFACTURING
PLANT IN RUMFORD, RHODE ISLAND WHERE MAGNESIUM OXIDE WAS REGENERATED AND
S02 FROM THE REGENERATION PROCESS WAS CONVERTED TO SULFURIC ACID. THE
RUMFORD FACILITY HAS SINCE BEEN CLOSED DOWN.
CONSTRUCTION WAS COMPLETED IN AUGUST AND THE SYSTEM STARTED UP IN SEPTEMBER
1973. DURING INTERMITTENT OPERATIONS FOR SHAKEDOWN THROUGH JANUARY 1974,
THE SYSTEM'S LONGEST CONTINUOUS RUN WAS 271 HOURS. THE SYSTEM HAS RE-
STARTED FROM JULY THROUGH DECEMBER 1974, AND AGAIN ON AUGUST 11, 1975, FOR
APPROXIMATELY 87 HOURS.
FGD UNIT OUTAGES WERE CAUSED PRIMARILY BY PIPE AND PUMP CORROSION AND
MAJOR TURBINE OVERHAUL OF THE BOILER. PARTICULATE AND S02 REMOVAL
EFFICIENCY GUARANTEES WERE CORROBORATED DURING OPERATIONAL PHASES.
THE FGD SYSTEM WAS RESTARTED IN AUGUST. STEAM WAS LOST TO THE MGO MIX
TANK, RESULTING IN A VERY MOIST PRODUCT FROM THE CENTRIFUGE. CAKING IN THE
DRYER OCCURRED. AT THIS POINT, THE UTILITY DECIDED TO TEST ONLY THE FIRST-
STAGE OF THE SCRUBBING SYSTEM, TAKING GAS AHEAD OF THE PRECIPITATOR. FGD
OPERATION AT DICKERSON TERMINATED AT THIS POINT.
THE REMAINING SUPPLY OF MAGNESIUM OXIDE, ABOUT 100 TONS (10 DAYS), HAS
BEEN DEPLETED, AND THE DICKERSON UNIT HAS BEEN TERMINATED AS A FGD SYSTEM.
9/75 SYSTEM 720
10/75 SYSTEM 744
11/75 SYSTEM 720
12/75 SYSTEM 744
1/76 SYSTEM 744
2/76 SYSTEM 696
3/76 SYSTEM 744
4/76 SYSTEM 720
0-53
-------
UTILITY FGO SURVEY: OCTOBER 1933 - SEPTEMBER 1984
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/76 SYSTEM 744
6/76 SYSTEM 720
7/76 SYSTEM 744
8/76 SYSTEM 744
9/76 SYSTEM 720
10/76 SYSTEM 744
11/76 SYSTEM 720
12/76 SYSTEM 744
1/77 SYSTEM 744
2/77 SYSTEM 672
3/77 SYSTEM 744
4/77 SYSTEM 720
5/77 SYSTEM 744
6/77 SYSTEM 720
7/77 SYSTEM 744
8/77 SYSTEM 744
9/77 SYSTEM 720
10/77 SYSTEM 744
11/77 SYSTEM 720
12/77 SYSTEM 744
1/78 SYSTEM 744
2/78 SYSTEM 38.0 38.0 38.0 672 672 252
** PROBLEMS/SOLUTIONS/COMMENTS
THERE HAVE BEEN MANY MAINTENANCE PROBLEMS AND PROBLEMS WITH LINER FAILURES.
SINCE SHIFTING FROM S02 TO PARTICULATE SCRUBBING ONLY, PLUGGING PROBLEMS
HAVE NOT OCCURRED. LOW PH HAS CAUSED CORROSION WHICH WAS AGGRAVATED BY
PARTICULATE ERROSION. THE UTILITY WILL PROBABLY RELINE WITH A FLAKE GLASS
TYPE LINER. NO CHEMICALS (E.G. LIME) ARE ADDED TO THE CIRCULATING LIQUOR
FOR FH BALANCE.
OUTAGE TIME WAS CAUSED BY LEAK REPAIRS IN SLURRY PIPING.
3/78 SYSTEM 21.0 22.0 21.0 744 717 156
»* PROBLEMS/SOLUTIONS/COMMENTS
OUTAGE TIME WAS DUE TO RUBBER LINING FAILURE IN THE RECYCLE PUMP DISCHARGE
LINE.
4/78 SYSTEM 80.7 79.8 76.4 720 689 550
D-54
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
26 HOURS OF OUTAGE TIME MERE DUE TO SMALL LEAKS IN PIPING.
5/78 SYSTEM 8*.5 82.7 74.0 744 666 551
»* PROBLEMS/SOLUTIONS/COMMENTS
A LEAK OCCURRED IN A MIST ELIMINATOR DRAIN.
THERE MAS A LEAK IN A BLEED LINE FOR THE SCRUBBER RECYCLE CIRCUIT.
OUTAGE TIME MAS REQUIRED FOR BLEED LINE REPLACEMENT.
6/78 SYSTEM 100.0 90.1 68.7 720 549 495
7/78 SYSTEM 100.0 .0 .0 744 16 0
»» PROBLEMS/SOLUTIONS/COMMENTS
THE VENTURI SCRUBBER HAD AN AVAILABILITY OF 100X FOR JUNE AND JULY. THE
ONLY VENTURI OUTAGE TIME WAS IN JUNE. THE OUTAGE TIME WAS REQUIRED TO
TIE IN EQUIPMENT COMMON TO THE NEW UNIT AND UNIT 3.
THE BOILER WAS DOWN IN JULY FOR AN OVERHAUL.
THE REASON VENTURI HOURS CAN BE LOWER THAN BOILER HOURS WHEN THE VENTURI
HAS A 100X AVAILABILITY IS BECAUSE THE VENTURI IS NOT OPERATED UNDER LOW
LOAD CONDITIONS.
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
4/79 SYSTEM 720
5/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
SCRUBBER OUTAGE HOURS SINCE SEPTEMBER 1978 (I.E. SEPTEMBER 19V8 THROUGH
MAY 30, 1979) TOTAL 140. THE UTILITY INDICATED THAT IT IS NO LONGER ALLOW-
ABLE TO BYPASS THE SCRUBBER WHEN PROBLEMS OCCUR, CLEANING THE PARTICULATE
MATTER SOLELY WITH THE ESP. THE UTILITY MUST DROP THE BOILER LOAD SO THE
UNIT REMAINS IN COMPLIANCE.
THERE HAVE BEEN HO PROBLEMS REPORTED FOR THE LAST FEW MOUTHS. THE UTILITY
IS KEEPING AHEAD OF PROBLEMS WITH A CONSCIENTIOUS INSPECTION AND MAINTEN-
ANCE PROGRAM.
6/79 SYSTEM 720
7/79 SYSTEM 744
D-55
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 98.6 95.4 744 720 710
#* PROBLEMS/SOLUTIONS/COMMENTS
A TEN HOUR OUTAGE OCCURRED FOR REPAIRS OF A LEAD LINE LEAK.
11/79 SYSTEM 95.2 88.8 720 672 640
*» PROBLEMS/SOLUTIONS/COMMENTS
IN NOVEMBER, 8 HOURS OUTAGE TIME WAS REQUIRED TO REPAIR A LEAK IN A
RECYCLE LINE.
12/79 SYSTEM 96.1 93.5 744 724 696
»* PROBLEMS/SOLUTIONS/COMMENTS
AN OUTAGE FOR GENERAL INSPECTION TOOK PLACE DURING DECEMBER.
1/80 SYSTEM 78.7 88.2 78.7 744 664 586
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE SCRUBBER WAS DOWN TO REPAIR THE FLAKEGLASS LINING.
2/80 SYSTEM 100.0 100.0 100.0 696 696 696
3/80 SYSTEM 100.0 100.0 100.0 744 744 744
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY AND MARCH THE SCRUBBER OPERATED WITH NO MAJOR PROBLEMS.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT 3 SCRUBBER EXPERIENCED SOME DOWN TIME DURING THE APRIL-JUNE PERIOD
AS A RESULT OF THE CONTINUING DETERIORATION OF THE SCRUBBER FLAKEGLASS
LINIIJG. THE UTILITY REPORTED THAT MAINTENANCE CREWS ARE PATCHING OLD
PATCHES. A STUDY WILL BEGIN IN LATE JULY TO ESTABLISH THE OPTIMUM LINER
MATERIAL AND APPLICATION STRATEGY FOR THE UNIT 3 SCRUBBING SYSTEM.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
** PR03LEMS/SOLUTIONS/COMMENTS
THE UTILITY HAS NOT FIGURED OUT THE DEPENDABILITY FIGURES AS YET.
THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
JULY-SEPTEMBER PERIOD.
D-56
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
THE BOILER CAPACITY WAS REDUCED TO 1/2 LOAD DURING PART OF THE PERIOD DUE
TO THE NECESSARY PATCHING OF THE SCRUBBER LINING. THE UTILITY IS PRESENTLY
STUDYING THE POSSIBILITY OF REPLACING THE FLAKEGUSS LINER WITH A RUBBER
LINER.
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
720
744
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE BOILER WAS OPERATED AT A
60X (110 MW) CAPACITY DUE TO A LINING FAILURE IN THE SCRUBBING SYSTEM
PIPING.
UNIT 3 WILL BE SHUTDOWN ON FEBRUARY 2, 1981 TO REPLACE THE FLAKEGLASS
LINING.
1/81 SYSTEM
2/81 SYSTEM
3/81 SYSTEM
96.8
.0
.0
96.9
97.5
94.2
.0
.0
744
672
744
723
0
0
701
0
0
*« FROBLEMS/SOLUTIONS/COMMENTS
DICKERSON UNITS 1, 2 AND 3 WERE SHUT DOWN SO THAT THE STACK AND THE COMMON
DUCT LEADING TO THE STACK COULD BE RELINED WITH PLASITE. UNIT 3 WAS SHUT
DOWN ON JANUARY 30 AND REMAINED DOWN THROUGHOUT FEBRUARY AND MARCH DUE TO
THESE REPAIRS.
D-57
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
PUBLIC SERVICE OF COLORADO
ARAPAHOE
4
DENVER
COLORADO
D
43.
******
******
*****
112
109
*****
112
( .100
(******
(******
LB/MMBTU)
LB/MMBTU )
LB/MMBTU )
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - '/.
. AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
******
PULVERIZED COAL
******
245.39
148.9
******
NR
*******
( 520000 ACFM)
(300 F)
(**** FT)
(***** FT)
COAL 1 [50X]
SUBBITUNINOUS; BITUMINOU
23609.
( 10150 BTU/LB)
******
10.90
******
12.45
******
.80
0.6-1.0; NR
.01
******
0
NONE
1
9/73
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
NATURAL RUBBER
STAINLESS STEEL
3
7.5 (56.0 GAL/1000ACF)
ALKALINE FLYASH
3.0 (12.0 IN-H20)
3.4 ( 11.0 FT/S)
245.4 ( 520000 ACFM)
D-58
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
PUBLIC SERVICE OF COLORADO: ARAPAHOE * (COST.)
INLET GAS TEMPERATURE - C 151.7 ( 305 F)
S02 REMOVAL EFFICENCY - X 30.0
PARTICLE REMOVAL EFFICIENCY - X 93.0
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/77 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN SEPTEMBER 1977 SCALING AND PLUGGING AT THE WET/DRY ZONE,
ON THE FIRST STAGE GRIDS, AND IN THE REHEATERS HAVE BEEN THE MOST PROMINENT
PROBLEM AREAS CHARACTERIZED BY THIS SYSTEM. VARIOUS CHEMICAL ADDITIVES
HAVE BEEN TESTED FOR CONTROL OF SCALING, INCLUDING PHOSPHATED ESTERS, BUT
WITHOUT SIGNIFICANT IMPROVEMENT. SLOWDOWN IS MAINTAINED AT A HIGH LEVEL
TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FOR TESTING PURPOSES, NO
CHEMICAL CONTROL METHOD HAS BEEN USED TO CONTROL SCALE ACCUMULATION.
OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT OF THE
MOBILE BALLS, EROSION OF LINING AND CORROSIVE FAILURE OF REHEATERS. THE
EROSION AND LINING FAILURE HAVE NOT BEEN A SERIOUS PROBLEM EXCEPT IN THE
RECIRCULATING PUMPS.
10/79 SYSTEM 74*
11/79 SYSTEM 720
12/79 SYSTEM 7*4
*» PROBLEMS/SOLUTIONS/COMMENTS
DURING" THE FOURTH QUARTER REHEATER FAILURES OCCURRED.
LEAKAGE IN THE INLINE STEAM TUBES HAS BEEN ENCOUNTERED. CORROSION
IS KNOWN TO OCCUR AFTER LEAKS ARE EXPERIENCED.
THE PRIMARY PROBLEM WITH THE SYSTEM IS THE INABILITY TO ISOLATE MODULES.
IF A PROBLEM OCCURS NO MODULE MAINTENANCE CAN BE PERFORMED UNLESS THE
UNIT LOAD IS CUT BACK OR THE UNIT IS SHUT DOWN.
1/80 SYSTEM 74*
2/80 SYSTEM 696
3/80 SYSTEM 7*4
** PROBLEMS/SOLUTIONS/COMMENTS
THE MODULE ISOLATION PROBLEMS CONTINUED THROUGH THE FIRST QUARTER OF 1980.
USE OF THE CARBON STEEL DAMPERS HAS BEEN ABANDONED. THE PROGRAM FOR RE-
PLACING THE DAMPERS HAS BEEN SUSPENDED INDEFINITELY. THE UNIT IS SHUTDOWN
WHEN MAJOR SCRUBBER PROBLEMS OCCUR.
REHEATER STEAM TUBE LEAKS ARE STILL CAUSING PROBLEMS. THE SIX STEAM COILS
ON THIS IN-LINE REHEAT SYSTEM, TWO OF WHICH ARE 316SS AND FOUR OF WHICH
ARE CARBON STEEL, ARE EXPERIENCING CORROSION PROBLEMS. A SOLUTION TO THE
PROBLEM HAS NOT YET BEEN DETERMINED.
IN FEBRUARY THE UTILITY REPLACED THE SCRUBBER BALLS AND GRIDS. THE OLD
BALLS WERE REPLACED WITH THE NEW HOLLOW HARD PLASTIC-WALLED BALLS WITH
NOTCHED SEAMS. THE GRIDS WERE ORIGINALLY 316L SS, CERAMIC, POLYPROPYLENE,
AND RUBBER LINED CARBON STEEL, BUT HAVE BEEN REPLACED WITH 317L SS GRIDS.
THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE QUARTER EXCEPT FOR THE
BALL AND GRID REPLACEMENT DOWNTIME.
4/80 SYSTEM 100.0 100.0 720 720 720
D-59
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PUBLIC SERVICE OF COLORADO: ARAPAHOE 4 ICONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM 100.0 100.0 744 744 744
6/80 SYSTEM 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
BOTH BOILER AND SCRUBBERS OPERATED THE ENTIRE APRIL-JUNE PERIOD.
THE ISOLATION DAMPERS ARE STILL EFFECTIVELY INOPERABLE AND A REPLACEMENT
PLAN AS YET HAS NOT BEEN REESTABLISHED.
THE UTILITY REPORTED THAT THE REHEATER TUBE LEAK PROBLEM CONTINUED THROUGH
THE SECOND QUARTER. THE TUBES WILL BE ENTIRELY REPLACED WITH NEW 316L SS
BUNDLES DURING THE NEXT SCHEDULED OUTAGE IN NOVEMBER AND DECEMBER. DURING
THE SECOND QUARTER MORE TUBES WERE BUNKED OFF AFTER STEAM LEAKS OCCURRED.
TO DATE ROUGHLY SOX OF THE TUBES ARE SEALED OFF AND ARE OUT OF SERVICE
BECAUSE OF LEAKS THAT OCCURRED OVER THE PAST MONTHS.
7/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
8/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
9/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND SCRUBBERS OPERATED ACCEPTABLY DURING THE JULY-SEPTEMBER PER-
IOD. NO PLANS HAVE BEEN MADE TO REPAIR THE ISOLATION DAMPERS. THE FAULTY
REHEATER TUBES WILL BE REPLACED DURING THE SCHEDULED OUTAGE NOW SET FOR THE
FIRST THREE WEEKS OF DECEMBER.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE REHEATER TUBES WERE NOT RE-
PLACED AND THE UNIT IS OPERATING WITHOUT REHEAT UNTIL THE NEXT SCHEDULED
OUTAGE PERIOD IN FEBRUARY 1981.
NO MAJOR SCRUBBER RELATED PROBLEMS WERE ENCOUNTERED, EXCEPT THE REPLACE-
MENT OF THE DISCHARGE VALVE ON THE RECIRCULATION PUMP.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE SCHEDULED FOUR WEEK OUTAGE STARTING JANUARY 30 AND ENDING FEBRU-
ARY 24, TWO NEW A-SIDE REHEATER BUNDLES WERE INSTALLED. THE UNIT WAS THEN
RESTARTED.
THE UNIT HOWEVER HAD TO BE SHUT DOWN ON FEBRUARY 24 ONLY AFTER OPERATING 3
HOURS DUE TO OPERATOR ERROR. THE BOOSTER FAN WAS RESTARTED WITHOUT ITS OIL
BEARING COOLING SYSTEM. CONSEQUENTLY, THE FAN BEARINGS WERE DAMAGE AND THE
BOOSTER FAN HAD TO BE SHUT DOWN. THE UTILITY HAS SINCE REPAIRED THE FAN
SHAFT BUT STILL AWAITS FOR THE REPAIRED FAN BEARINGS BEFORE THE UNIT CAN BE
D-60
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PUBLIC SERVICE OF COLORADO: ARAPAHOE 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOS PART. HOURS HOURS HOURS FACTOR
RESTARTED.
D-61
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
«* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
( .100 LB/MMBTU)
(**#*** LB/MMBTU)
(****** LB/MMBTU)
PUBLIC SERVICE OF COLORADO
CHEROKEE
1
DENVER
COLORADO
D
43.
******
******
710
115
100
105
102
BABCOCK * WILCOX
PULVERIZED COAL
******
245.39 ( 520000 ACFM)
146.1 ( 295 F)
******
NR
*******
(**** FT)
(***** FT)
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - V.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUNcER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
COAL
BITUMINOUS
23493.
12.50
9.4-12.5
11.30
******
.65
******
.01
******
( 10100 BTU/LB)
******
0
NONE
1
6/73
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
NATURAL RUBBER
STAINLESS STEEL
3
7.5 (56.0 GAL/1000ACF)
ALKALINE FLYASH
3.2 (13.0 IN-H20)
3.4 (
164.4
11.0 FT/S)
( 348400 ACFM)
D-62
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PUBLIC SERVICE OF COLORADO: CHEROKEE 1 (CONT.)
INLET GAS TEMPERATURE - C 146.1 ( 295 F)
S02 REMOVAL EFFICEHCY - X 16.0
PARTICLE REMOVAL EFFICIENCY - X 97.0
ENERGY CONSUMPTION - X 4.3
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/73 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JUNE 1973 SCALING AND PLUGGING AT THE MET/DRY ZONE,
ON THE FIRST STAGE GRIDS, AND IN THE REHEATERS HAVE BEEN THE MOST PROMINENT
PROBLEM AREAS CHARACTERIZED BY THIS SYSTEM. VARIOUS CHEMICAL ADDITIVES
HAVE BEEN TESTED FOR CONTROL OF SCALING, INCLUDING PHOSPHATED ESTERS, BUT
WITHOUT SIGNIFICANT IMPROVEMENT. SLOWDOWN IS MAINTAINED AT A HIGH LEVEL
TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FOR TESTING PURPOSES NO
CHEMICAL CONTROL METHOD HAS BEEN USED TO CONTROL SCALE ACCUMULATION.
OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT OF THE
MOBILE BALLS, EROSION OF LINING AND CORROSIVE FAILURE OF REHEATERS. THE
EROSION AND LINING FAILURE HAVE NOT BEEN A SERIOUS PROBLEM EXCEPT IN THE
RECIRCULATING PUMPS.
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE PERIOD ID FAN FAILURES HAVE OCCURRED DUE TO EROSION FROM THE
FLYASH.
THE ISOLATION DAMPER HAS BEEN A PROBLEM DUE TO FREEZE UPS MAKING IT
INOPERATIVE.
REHEATER FAILURES HAVE OCCURRED DUE TO PLUGGING OF THE HOT AIR INJECTION
STEAM COILS.
THE SCRUBBER EXIT DUCTWORK WILL BE REPAIRED TEMPORARILY WITH A SPRAY ON
FIBERGLASS-LIKE MATERIAL.
1/80 SYSTEM 100.0 100.0 744 744 744
2/80 SYSTEM 100.0 100.0 696 696 696
3/80 SYSTEM 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE FIRST QUARTER OF 1980.
THE ISOLATION DAMPERS HAVE NOT CAUSED ANY PROBLEMS BECAUSE MODULE
ISOLATION WAS NOT REQUIRED DURING THE PERIOD.
THE FANS ARE STILL EXPERIENCING EROSION PROBLEMS.
IN MARCH A BOILER/SCRUBBER OVERHAUL BEGAN. DURING THIS TIME THE CARBON
STEEL ISOLATION DAMPERS WILL BE REPLACED WITH 316 SS. THE NEU FANS
WILL BE INSTALLED IN THE OLD HOUSINGS. THE NEW HIGH STRENGTH CAREON STEEL
FANS WILL BE EQUIPPED WITH REPLACABLE CHROMIUM ALLOY WEAR PLATE BLADE
TIPS.
4/80 SYSTEM 720
5/80 SYSTEM 744
D-63
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
*» MECHANICAL COLLECTOR
NUMBER
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
»* PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NU113ER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
PRESSURE DROP - KPA -
SUPERFICIAL GAS VELOCITY - M/S
S02 REMOVAL EFFICENCY - 7.
( .100 LB/MMBTU)
(****** LB/MMBTU)
(«***** LB/MMBTU)
PUBLIC SERVICE OF COLORADO
CHEROKEE
4
DENVER
COLORADO
D
43.
******
******
710
375
350
375
356
COMBUSTION ENGINEERING
PULVERIZED COAL
******
717.29 (1520000 ACFM)
( 275 F)
(**** FT)
135.0
******
NR
*******
COAL
BITUMINOUS
23*93.
12.50
9.4-12.5
11.30
******
.65
******
.01
******
(***** FT)
( 10100 BTU/LB)
******
0
NONE
4
7/74
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
NATURAL RUBBER
STAINLESS STEEL
3
7.5 (56.0 GAL/1000ACF)
ALKALINE FLYASH
3.2 (13.0 IN-H20)
3.4 ( 11.0 FT/S)
16.0
D-65
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
PUBLIC SERVICE OF COLORADO: CHEROKEE 4 (CONT.)
PARTICLE REMOVAL EFFICIENCY - '/. 97.0
ENERGY CONSUMPTION - X 6.7
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/7* SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JULY 197* SCALING AND PLUGGING AT THE WET/DRY ZONE,
ON THE FIRST STAGE GRIDS, AND IN THE REHEATERS HAVE BEEN THE MOST PROMINENT
PROBLEM AREAS CHARACTERIZED BY THIS SYSTEM. VARIOUS CHEMICAL ADDITIVES
HAVE BEEN TESTED FOR CONTROL OF SCALING, INCLUDING PHOSPHATED ESTERS, BUT
WITHOUT SIGNIFICANT IMPROVEMENT. SLOWDOWN IS MAINTAINED AT A HIGH LEVEL
TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FOR TESTING PURPOSES NO
CHEMICAL CONTROL METHOD HAS BEEN USED TO CONTROL SCALE ACCUMULATION.
OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT OF THE
MOBILE BALLS, EROSION OF LINING AND CORROSIVE FAILURE OF REHEATERS. THE
EROSION AND LINING FAILURE HAVE NOT BEEN A SERIOUS PROBLEM EXCEPT IN THE
RECIRCULATING PUMPS.
10/79 SYSTEM 7**
11/79 SYSTEM . 720
12/79 SYSTEM 7**
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE PERIOD ID FAN FAILURES HAVE OCCURRED DUE TO EROSION FROM THE
FLYASH.
THE ISOLATION DAMPER HAS BEEN A PROBLEM DUE TO FREEZE UPS MAKING IT
INOPERATIVE.
REHEATER FAILURES HAVE OCCURRED DUE TO PLUGGING OF THE HOT AIR INJECTION
STEAM COILS.
THE SCRUBBER EXIT DUCTWORK WILL BE REPAIRED TEMPORARILY WITH A SPRAY ON
FIBERGLASS LIKE MATERIAL.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE OUTLET DUCT WORK IS BEING REBUILT INTERNALLY WITH FIBERGLASS FOR
STRUCTURAL SUPPORT AND ACID RESISTANCE. WITH REGULAR MAINTENANCE THE
UTILITY EXPECTS THIS TO PROVE TO BE A PERMANENT SOLUTION TO THE EROSION/
CORROSION PROBLEM.
THE OLD FANS ARE BEING REPLACED WITH HIGH STRENGTH CARBON STEEL FANS HAVING
REPLACABLE CHROMIUM ALLOY WEAR PLATE BLADE TIPS.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
D-66
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
PUBLIC SERVICE OF COLORADO: CHEROKEE 4 ICONT.)
------------------------------------------ PERFORMANCE DATA ------------------------------------------
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE NEW FANS DESCRIBED DURING THE LAST REPORT PERIOD WERE INSTALLED IN ONE
OF THE FOUR MODULES. NEW FANS WILL BE INSTALLED IN THE OTHER THREE MODULES
DURING A SCHEDULED LATE SEPTEMBER OUTAGE UNLESS THE UTILITY HAS AN OPPOR-
TUNITY TO MAKE THE REPLACEMENTS SOONER.
7/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER RETURNED TO SERVICE IN MID JULY AFTER A TWO WEEK OUTAGE.
DURING THIS TIME, THE FIBERGLASS INSIDE THE DUCTWORK WAS REPLACED, AND A
VERTICAL GRID WAS INSTALLED ON THE SECOND LEVEL OF THE MOBILE BED TOWER TO
IMPROVE SYSTEM PERFORMANCE.
8/80 SYSTEM
9/80 SYSTEM 720
»* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND FGD SYSTEM WENT DOWN ON SEPTEMBER 15, 1980 FOR A SCHEDULED
OVERHAUL. DURING THIS TIME, FANS WERE INSTALLED ON MODULES A, C, AND 0.
THE UTILITY IS CURRENTLY EVALUATING THE VERTICAL GRID ON THE SECOND LAYER.
IF THE GRID IMPROVES SYSTEM PERFORMANCE, THEY MILL INSTALL ANOTHER ONE
ON THE THIRD LEVEL.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 4 EXPERIENCED SOME MINOR REHEATER LEAKAGE PROBLEMS DURING THE PERIOD.
DURING THE FOURTH QUARTER OF 1980 THE UTILITY REPORTED THAT PROBLEMS WERE
ENCOUNTERED WHEN VERITICAL GRIDS WERE INSTALLED ON THE SCRUBBER BED. THIS
WAS INTENDED TO SOLVE THE PROBLEM OF KEEPING THE SCRUBBER BALLS FROM MOVING
HORIZONTALLY, RESULTING IN PILES OF SCRUBBER BALLS IN LOCALIZED AREAS, BUT
CORROSION AND SYSTEM PERFORMANCE DID NOT IMPROVE.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
THROUGHOUT THE JANUARY-MARCH PERIOD THE UTILITY INTERMITTENTLY SHUT DOWN
THE SCRUBBER MODULES (ONE MODULE AT A TIME) TO REPLACE SCRUBBER BALLS AND
REPAIR SCRUBBER BALL PARTITIONS.
THE UTILITY REPORTED EXPERIENCING CORROSION PROBLEMS WITH THE FOUR SCRUBBER
BOOSTER FANS.
0-67
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
302 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
INLET FLUE GAS CAPACITY - CU.M/S
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
INLET FLUE GAS CAPACITY - CU.M/S
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
PUBLIC SERVICE OF COLORADO
VALMONT
5
VALMONT
COLORADO
E
43. ( .100 LB/MMBTU)
****** (****** LB/MMBTU)
****** (****** LB/MMBTU)
274
166
157
163
166
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
436.93 ( 926000 ACFM)
126.7 ( 260 F)
****** (**** FT)
NR
******* (***** FT)
COAL
SUBBITUMINOUS
25121.
6.00
5.4-7.0
15.00
12.7-18.3
.70
0.6-0.7
********
******
218.5
0
NONE
COLD SIDE
218.5
( 10800 BTU/LB)
******
( 463000 ACFM)
( 463000 ACFM)
2
11/71
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
NATURAL RUBBER
STAINLESS STEEL
3
7.8 (58.3 GAL/1000ACF)
LIMESTONE/ALKALINE FLYASH
0-68
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
PRESSURE DROP - KPA 3.7
SUPERFICIAL GAS VELOCITY - M/S 3.4
INLET GAS FLOW RATE - CU.M/S 109.2
INLET GAS TEMPERATURE - C 132.8
S02 REMOVAL EFFICEMCY - X .45.0
PARTICLE REMOVAL EFFICIENCY - X 96.0
ENERGY CONSUMPTION - X 3.6
(15.0 IN-H20)
( 11.0 FT/S)
( 231500 ACFM)
( 271 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/71 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
THE FIRST PARTICLE MATTER SCRUBBER COMMENCED OPERATION IN NOVEMBER 1971.
THE SCRUBBER WAS ORIGINALLY INSTALLED FOR PARTICLE MATTER REMOVAL SINCE THE
PLANT BURNS LOW SULFUR COAL; HOWEVER, 45X OF THE S02 IS REMOVED AS WELL
BECAUSE OF THE ALKALINITY OF THE FLYASH.
DURING THE FIRST YEAR OF OPERATION PROBLEMS INCLUDED DIFFICULTIES WITH THE
MODULE PACKING GRID SUPPORT, GENERAL VESSEL SCALE FORMATION, FLOW DISTRI-
BUTION PROBLEMS, BALL BREAKAGE, SCALING IN THE MIST ELIMINATOR SECTION,
AND PLUGGING OF THE REHEATER. SCALE FORMATION WAS THE MOST PREDOMINANT
CONTINUING MAJOR CAUSE OF DOWNTIME IN THE SCRUBBER. SCALE ACCUMULATION
WAS NOTED ON THE WET-DRY INTERFACE IMMEDIATELY DOWNSTREAM OF THE PRESATU-
RATION NOZZLES. SCALE ALSO ACCUMULATED HEAVILY ON THE UNDERSIDE OF THE
FIRST LAYER OF GRID BARS.
SCALE ON THE UPPER GRID BARS WAS LESS PREVALENT AS THE ACTION OF THE "PING
PONS" BALLS TENDED TO KEEP THE SCALE OFF OF THESE SECTIONS. SCALE ALSO
COLLECTED ON THE WALLS OF THE VESSEL AND INTERMITTENTLY SLOUGHED OFF AND
FELL INTO THE SUMP IN LARGE PIECES CAUSING BLOCKAGE OF THE RECIRCULATION
PUMP SUCTION SCREENS. SCALING OF THE MIST ELIMINATOR ABATED SOMEWHAT WITH
THE INTRODUCTION OF A CLEAR RINSE WATER WASH. SCALE FORMATION IN THE RE-
HEAT SECTION SOMETIMES REQUIRED SUPPLEMENTAL CLEANING OF THE REHEATER IN
ADDITION TO THE CLEANING OBTAINED BY THE USE OF THE SOOTBLOWERS WHICH WERE
INSTALLED AS A PART OF THE REHEATER EQUIPMENT. UNDER NORMAL OPERATION,
THE SOOTBLOWERS LOCATED IN THIS REHEAT SECTION WERE FAIRLY SUCCESSFUL IN
REMOVING THE ACCUMULATION OF THE SCALE IN THE REHEATER.
ALTHOUGH MANY OF THE INITIAL START-UP PROBLEMS WERE SOLVED OVER A PERIOD
OF TIME, THE CALCIUM SULFATE-FLYASH SCALING CONTINUED TO BE A SIGNIFICANT
OPERATING PROBLEM AT THE VALMONT INSTALLATION. IN ADDITION TO THESE
SCALING RELIABILITY PROBLEMS, A WATER QUALITY CONCERN ALSO SURFACED THAT
WAS A DIRECT RESULT OF THE PARTICLE SCRUBBER OPERATION. THE RELATIVELY
HIGH CAO CONCENTRATION IN THE VALMONT FLYASH RESULTED IN FAIRLY HIGH S02
REMOVAL RATES (45-50 PERCENT) WITHIN THE UNITS. SINCE NO PH CONTROL CAPA-
BILITY FOR EITHER THE RECIRCULATING SLURRY OR THE SYSTEM SLOWDOWN SLURRY
WAS DESIGNED INTO THE SYSTEM, AN ACID CONDITION WAS CREATED IN THE SLURRY
AND THE SLOWDOWN STREAM. PH LEVELS OF THE SLOWDOWN NORMALLY RANGED BETWEEN
1.7 AND 2.0. ALTHOUGH THE STREAM WAS NEUTRALIZED TO A DEGREE BY ALKALINE
FLYASH, PSCC FELT THAT IT WAS IMPORTANT TO INVESTIGATE VARIOUS CONTROL
MEASURES WHICH COULD BE APPLIED TO THIS STREAM. THE CALCIUM SULFATE
SCALING PROBLEM WAS THOUGHT TO BE THE RESULT OF A SUPER-SATURATED CALCIUM
SULFATE CONDITION IN THE RECIRCULATING SLURRY. BECAUSE OF THIS IT WAS FELT
THAT CONTINUOUS PH CONTROL OF THE RECIRCULATING SLURRY, CONVERSION OF THE
SYSTEM TO CLOSED LOOP OPERATION AND ESTABLISHING A HIGHER CONCENTRATION OF
SEEDING SOLIDS IN THE RECIRCULATION SLURRY (THEREBY CONTROLLING THE SCALING
PROBLEMS WITHOUT CHEMICAL ADDITIVES) WOULD BE NECESSARY MEASURES.
FOR PH CONTROL, LIMESTONE WAS TESTED INITIALLY, THEN LIME WAS UTILIZED FOR
THE ALKALI REAGENT. IN THE FIRST TEST, SINCE LIMESTONE UTILIZATION WAS A
MAJOR CONCERN, A SPECIAL EFFORT WAS MADE TO REDUCE THE POTENTIAL FOR THE
SH03T CIRCUITING OF THE ADDED LIMESTONE AND TO PROVIDE SUFFICIENT RESIDENCE
TIME IN THE REACTOR SECTION OF THE SYSTEM. BY UTILIZING FOUR REACTION MIX
TANKS IN SERIES, PLUG FLOW WAS EXPECTED TO BE MORE CLOSELY SIMULATED. TO
MAINTAIN A CLOSED LOOP SYSTEM WHERE THE QUANTITY OF WATER REMOVED FROM THE
SYSTEM WAS HELD TO A MINIMUM, FOUR SYSTEM DESIGN FEATURES WERE UTILIZED.
1. UTILIZATION OF A COMBINATION OF POND SUPERNATANT AND MAKE-UP WATER
D-69
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
, PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
FOR RECYCLE WATER.
2. PRESATURATION OF THE INCOMING FLUE GAS WITH RECIRCULATIN6 SLURRY.
3. INTERMITTENT MIST ELIMINATOR WASH.
ft. PROPER SELECTION OF MATERIALS OF CONSTRUCTION TO PROTECT AGAINST
ATTACK CAUSED BY HIGH CHLORIDE CONCENTRATIONS.
THE SCRUBBERS R & 0 FACILITY WAS NOT EQUIPPED WITH A MECHANICAL THICKENER
FOR CONTROL OF THE SUSPENDED SOLIDS CONCENTRATION OF THE RECIRCULATING
SLURRY (ALL PURGED MATERIAL WAS SENT TO THE SLUDGE POND). WITH A 500 PPM
SOS CONCENTRATION IN THE FLUE GAS, IT IS EXPECTED THAT THE RECIRCULATING
SLURRY SOLIDS COULD BE REALLY CONTROLLED IN THE 5 TO 7 PERCENT RANGE. DUE
TO THE MIXED FUEL FIRED AT THE UNIT DURING THE TEST PERIOD, HOWEVER, THE
S02 CONCENTRATIONS EMITTED FROM THE BOILER AND HENCE PRESENT IN THE FLUE
GAS STREAM VARIED SIGNIFICANTLY AND FINALLY FELL TO SUCH LOW LEVELS (OFTEN
100-200 PPM) THAT SUSPENDED SOLIDS CONCENTRATIONS IN THE SLURRY COULD NOT
BE MAINTAINED. IT IS ALMOST CERTAIN THAT A THICKENER, WITH THE SUBSE-
QUENT RETURN OF SOLIDS TO THE SCRUBBER LIQUOR, COULD HAVE BEEN USED TO
GOOD ADVANTAGE DURING THIS TIME PERIOD. GENERALLY SPEAKING, THE SEVERE
SCALING CONDITIONS PLAGUING THE TEST MODULE WERE INTENSIFIED DURING THESE
PERIODS OF LOW INLET S02 CONDITION.
11/74 SYSTEM 720
12/74 SYSTEM 744
1/75 SYSTEM 744
2/75 SYSTEM 672
3/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SCRUBBING SYSTEM WAS OPERATED FOR A TOTAL OF FOUR AND ONE-HALF
MONTHS, FROM MID-OCTOBER 1974 TO MARCH 1975. THE OVERALL RELIABILITY OF
THE SYSTEM WAS APPROXIMATELY 75X.
4/75 SYSTEM 720
5/75 SYSTEM 744
6/75 SYSTEM 720
7/75 SYSTEM 744
8/75 SYSTEM 744
9/75 SYSTEM 720
10/75 SYSTEM 744
11/75 SYSTEM 720
12/75 SYSTEM 744
1/76 SYSTEM 744
2/76 SYSTEM 696
3/76 SYSTEM 744
4/76 SYSTEM 720
5/76 SYSTEM
6/76 SYSTEM 720
D-70
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/76 SYSTEM 7*4
8/76 SYSTEM 744
9/76 SYSTEM 720
10/76 SYSTEM 74*
11/76 SYSTEM 720
12/76 SYSTEM 744
1/77 SYSTEM 744
2/77 SYSTEM 672
3/77 SYSTEM 744
4/77 SYSTEM 720
5/77 SYSTEM 744
6/77 SYSTEM 720
7/77 SYSTEM 744
8/77 SYSTEM 744
9/77 SYSTEM 720
10/77 SYSTEM 744
11/77 SYSTEM 720
12/77 SYSTEM 744
1/78 SYSTEM 744
2/78 SYSTEM 672
3/78 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THERE HAVE BEEN RECURRING PROBLEMS ASSOCIATED WITH BALL MIGRATION IN THE
BALL COMPARTMENT AS WELL AS RECIRCULATION PUMP MOTOR BEARING FAILURE, AND
WEAR AND FAILURE IN THE BALL COMPARTMENT LINING. THERE HAVE BEEN CONTINUAL
PROBLEMS WITH REHEATER PLUGGING. THERE ALSO HAVE BEEN EXPANSION JOINT
FAILURES AT BOTH THE INLET AND OUTLET OF THE SCRUBBER.
MOPE RECENTLY THERE WAS A PINCH BELT FAILURE.
THE SCRUBBING SYSTEM HAS HAD AN AVAILABILITY RANGE OF 50 TO 78X WITH AN
AVERAGE OF 66X.
4/78 SYSTEM 720
5/78 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO SIGNIFICANT PROBLEMS WERE ENCOUNTERED.
6/78 SYSTEM 720
7/78 SYSTEM 744
D-71
-------
UTILITY FGD SURVEY: OCTOBER 1933 - SEPTEMBER 1984
PUBLIC SERVICE OF COLORADO: VALflONT 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
8/78 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY HAD NO COMMENTS FOR THIS PERIOD.
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
Z/79 SYSTEM 672
3/79 SYSTEM 744
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
AVERAGE SCRUBBER AVAILABILITY FROM START UP THROUGH APRIL 1979 WAS 64.42X.
AVERAGE SCRUBBER AVAILABILITY FOR 1978 WAS 66.85X.
AVERAGE SCRUBBER AVAILABILITY FROM JANUARY 1, 1979 THROUGH MAY, 1979 WAS
APPROXIMATELY SOX.
BALL MIGRATION, ALTHOUGH NOT SERIOUS, IS A CHRONIC PROBLEM FOR VALMONT 5.
EROSION AND CORROSION HAVE OCCURRED ON THE SCRUBBER GRID BAR AREA (PACKING
SUPPORT).
EROSION/CORROSION IS EVIDENT IN THE MIST ELIMINATOR SECTION.
EROSION/CORROSION OCCURRS IN THE REHEATER AREA AND SOOT BLOWER.
THE UTILITY HAD TO REPLACE INLET AND OUTLET EXPANSION JOINTS.
REHEATER PLUGGING HAS BEEN A PROBLEM.
RECYCLE PUMP BEARING FAILURES OCCURRED.
THE JACK SCREW DRIVE HAS BEEN MALFUNCTIONING ON INLET AND OUTLET ISOLATION
DAMPERS.
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE ANNUAL SHUTDOWN IN SEPTEMBER THE OLD SCRUBBER BALLS WERE
REPLACED WITH A NEW BRAND. DUE TO BALL MOTION THE RUBBER LINER ERODED.
IN THE MIST ELIMINATOR SECTION EROSION AND CORROSION OCCURRED.
D-72
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
100.0
92.3
98.1
720
1/80
2/80
3/80
4/80
5/80
6/80
PROBLEMS/SOLUTIONS/COMMENTS
A
B
SYSTEM
A
B
SYSTEM
A
B
SYSTEM
98.5
98.5
98.5
84.4
94.9
89.7
90.8
87.7
89.0
ONE OF THE MAJOR SCRUBBING SYSTEM PROBLEMS IS THE SCRUBBER WALL WEAR WHICH
HAS TO BE PATCHED DURING THE SPRING AND FALL.
REHEATER PLUGGING HAS BEEN A CHRONIC PROBLEM.
THE UTILITY HAS REPORTED THE FOLLOWING ANNUAL AVAILABILITIES FOR THE UNIT.
1972 - 1978: 64.3X
1972 - 1979: 65.9X
1978: 66.8X
1979: 80.5X
744
696
744 615
*« PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980, NO MAJOR PROBLEMS WERE ENCOUNTERED WITH
THE SCRUBBER.
A
B
SYSTEM
88.1
88.1
88.1
720 716
*« PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER WAS SHUT DOWN ON APRIL 14 FOR A WEEK TO MAKE REPAIRS TO A HOLE
IN THE SCRUBBER RUBBER LINING, RECYCLE PUMP LININGS AND A STEAM REGULATOR
ON ONE OF THE REHEATERS.
A
B
SYSTEM
96.8
100.0
98.4
744 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE REPORTED FOR MAY.
A
B
SYSTEM
8.0
8.0
8.0
720 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE SCRUBBER WAS FORCED OUT OF SERVICE WHEN AN INBOARD FAN
PEDISTLE BEARING FAILED. THE BEARING SECTION WAS REBUILT.
0-73
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
WHILE FAN REPAIRS WERE IN PROGRESS EXTENSIVE MAINTENANCE WAS PERFORMED ON
THE SCRUBBER. MAINTENANCE WORK INCLUDED COMPLETE BALL REPLACEMENT, ADDI-
TIONAL REPAIR WORK ON THE SCRUBBER LINER, REPAIR OF HOLES IN THE TOWER
SHELL AND OF A RUPTURED MIST ELIMINATOR WASH LINE AND THE REHEATER WAS
CLEANED.
DAMPER JAMMING AT VALMONT HAS OCCURRED PERIODICALLY. SOMETIMES DAMPERS DO
NOT READILY CLOSE. THE OPERATOR MUST MOVE THE DAMPER UP AND DOWN UNTIL THE
GUILLOTINE SEATS. BECAUSE OF CONTINUOUS FLY ASH ACCUMULATION IT APPEARS
THAT THE DAMPERS MUST BE EXERCISED FREQUENTLY TO PREVENT JAMMING.
7/80 5A 48.3 46.6
SB 48.3 46.6
SYSTEM 48.3 46.6 744 719 347
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER SYSTEM WAS SHUT DOWN BECAUSE OF SCRUBBER BOOSTER FAN
BEARING FAILURE.
8/80 5A 87.5 84.8
5B 95.6 92.6
SYSTEM 91.5 87.7 744 721 660
** FROBLEMS/SOLUTIONS/COMMENTS
THE RECIRCULATION PUMP MOTOR BEARING FAILED CAUSING SOME MINOR OUTAGE
TIME IN AUGUST.
9/80 SYSTEM .0 720 0 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND SCRUBBER WERE SHUT DOWN DURING SEPTEMBER FOR SCHEDULED
MAINTENANCE.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
»* PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER REMAINED OUT OF SERVICE THROUGHOUT THE OCTOBER-DECEMBER PERIOD
AND IS EXPECTED TO START UP AT THE END OF JANUARY. LATE START UP OF THE
SCRUBBER IS DUE TO A MANPOWER SHORTAGE. THE BOILER AND TURBINE RETURNED TO
SERVICE IN MID-DECEMBER.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SCRUBBER CAME BACK ON-LINE AT THE END OF JANUARY AND OPERATED THROUGHOUT
THE MONTHS OF FEBRUARY AND MARCH WITHOUT ANY MAJOR SCRUBBER RELATED PROB-
LEMS.
D-74
-------
UTILITY F60 SURVEY: OCTOBER 1983 - SEPTEMBER
APPENDIX D
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NS/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFL'R CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
**» PARTICLE CONTROL
** ESP
'NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUM3ER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
( .100 LB/MMBTU)
( 1.200 LB/MMBTU)
(*»**»* LB/MMBTU)
SOUTHWESTERN PUBLIC SERVICE
HARRINGTON
1
AMARILLO
TEXAS
D
43.
516.
******
350
350
320
*****
350
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
778.63 (1650000 ACFM)
176.7 ( 350 F)
76. ( 250 FT)
CONCRETE
8.2 ( 27.0 FT)
( 8700 BTU/LB)
8400-8700
COAL
SUBBITUMINOUS
20236.
5.00
5.0-5.5
27.10
25.0-30.0
.31
0.3-0.5
********
******
COLD SIDE
RESEARCH-COTTRELL
778.6 (1650000 ACFM)
168.3 ( 335 F)
.1 ( 1. IN-H20)
95.0
6
1
PACKED TOWER
STATIC BED PACKING
MARBLE-BED SCRUBBER
COMBUSTION ENGINEERING
24.0 X 25.0
CARBON STEEL
AISI 1110
ORGANIC
NR
GLASS MARBLES
1
444.1
3.1
( 7050 GPM)
(23.0 GAL/1000ACF)
SLUDGE FROM WATER TREATMENT
2.4 ( 8.0 FT/S)
141.6 ( 300000 ACFM)
0-75
-------
UTILITY FGD SURVEY'- OCTOBER 1983 - SEPTEMBER 1984
SOUTHWESTERN PUBLIC SERVICE: HARRINGTON 1 (CONT.)
INLET GAS TEMPERATURE - C 60.0 ( 140 F)
PARTICLE REMOVAL EFFICIENCY - X 50.0
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THROUGH DECEMBER, TWO SPRAY PUMP MOTORS FAILED.
THE FRP FLUSH PIPING HAS FAILED CAUSING SOME LEAKING.
PLUGGING IN ONE MARBLE BED WAS ENCOUNTERED WHEN THE CHEMISTRY CONTROL MAS
TEMPORARILY LOST.
THE CONE SHAPED EXPANDED METAL (316L SS) SCREENS COVERING THE BED DRAIN
PIPES HAVE ERODED AWAY FROM BALL MOVEMENT. THE MARBLE BALLS HAVE BEEN
DROPPING INTO THE RECYCLE TANK. WHERE THE UTILITY HAS REPLACED THE METAL
SCREEN WITH EXPANDED PLASTIC SCREEN, EROSION HAS NOT OCCURRED.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980 THE MIST ELIMINATOR WASH PIPING RUPTURED
CAUSING PLUGGING IN SCRUBBERS 4 AND 5. THE UTILITY PLANS TO REPLACE
ALL FRP PIPING WITH STEEL. THE RUPTURE ON NO. 5 ALSO DAMAGED THE WATER
SUPPLY HEADER.
THE MARBLE BED PLUGGING REPORTED DURING THE LAST QUARTER IS NOT YET
COMPLETELY CLEARED. THE SOFT SCALE IS GRADUALLY GOING BACK INTO THE
SOLUTION. THE PLATE AREA IS CLEAN.
THE DUCT BENEATH THE REHEATER TUBING ON ONE OF THE MODULES HAS CORRODED TO
THE POINT THAT HOLES HAVE FORMED. SCALE AW MOISTURE WERE FOUND ON THE
PLATE WHERE THE CORROSION FORMED. THE PLATE WAS REMOVED AND A NEW CARBON
STEEL PLATE WAS WELDED IN. NO OTHER REHEATER DUCTS HAVE EXPERIENCED ANY
SCALE OR MOISTURE ACCUMULATION.
4/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
A PUMP LINER FAILURE OCCURRED IN APRIL. THE IMPELLER SHAFT LINER WAS RE-
PAIRED AND REPLACED.
5/80 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUT DOWN A FEW DAYS IN LATE APRIL AND 12 TO 14 DAYS IN
EARLY MAY FOR AIR PREHEATER REPAIRS.
DURING APRIL AND MAY THE SCRUBBING SYSTEM EXPERIENCED AGITATOR PROBLEMS.
THE RECENT PROBLEMS HAVE BEEN RELATED TO BEARING FAILURE, HOWEVER, THE
SEALS HAVE BEEN LEAKING AS WELL. THE AGITATORS AT THIS FACILITY ARE SIDE
MOUNTED. THE AGITATOR SHAFT ENTERS THE TANK AT ROUGHLY 12 FT BELOW THE
D-76
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SOUTHWESTERN PUBLIC SERVICE: HARRINGTON 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
FLUID SURFACE. IT APPEARS THAT THE SEAL LEAKING MAY BE ATTRIBUTABLE TO
FAULTY INSTALLATION.
6/80 SYSTEM 92.1 720 696 79.3
*» PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE SCRUBBER EXHIBITED AN AVAILABILITY OF 92.IX. THERE WAS
GREATER SCRUBBER CAPACITY AVAILABLE THAN REQUIRED BY THE BOILER. NO
PROBLEMS WERE REPORTED FOR JUNE.
DAMPER PROBLEMS REPORTED PREVIOUSLY HAVE BEEN ELIMINATED. THE OLD OPERATOR
MECHANISMS WERE REPLACED WITH OPERATORS SUPPLIED BY ANOTHER MANUFACTURER.
ONE OF THE MARBLE BEDS IS STILL PARTIALLY PLUGGED. THE MATERIAL SEEMS TO
BE HARD CALCIUM SULFATE SCALE. THE SCALE WILL PROBABLY NOT CLEAR FURTHER
THROUGH DISSOLUTION DURING NORMAL SCRUBBER OPERATIONS AS HAD BEEN HOPED.
ALTHOUGH THE MODULE MUST OPERATE AT LOWER THAN DESIGN GAS FLOW SCRUBBER
OPERATIONS ARE NOT HAMPERED OVERALL BECAUSE THE SYSTEM HAS SOME DESIGN
SPARE CAPACITY.
THE REHEATER PROBLEM REPORTED PREVIOUSLY HAS OCCURRED ON THREE REHEATERS
NOW. THE FAILURE OF THE REHEATER DUCT BOTTOM PANELS MAY BE A RESULT OF AN
UNDERSIZED DEFLECTION SHIELD BENEATH THE TUBE BANKS. IT IS ALSO POSSIBLE
THAT THE DUCTING WAS IMPROPERLY WELDED.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR SCRUBBING SYSTEM PROBLEMS OCCURRED
DURING THE THIRD QUARTER 1980.
THE PROBLEM REPORTED EARLIER WITH THE MIST ELIMINATOR WASH PIPING IS
PRESENTLY BEING SOLVED BY REPLACING THE PIPING WITH CARBON STEEL.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
'** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD REPLACEMENT OF THE MIST ELIMI-
NATOR WASH PIPING WITH CARBON STEEL CONTINUED; AS THE OLD PIPING WEARS OUT
AND MAINTENANCE TIME PERMITS.
DURING LATE DECEMBER, THE SLURRY SPRAY PUMP HOUSING CRACKED DURING A BACK
FLUSH. THIS WAS THE SECOND TIME IN TWO YEARS THAT THIS PROBLEM HAD
OCCURRED.
1/81 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT AT THE BEGINNING OF THE YEAR THE SCRUBBER SYSTEM
BE-GAN TO SEE VOLUMES OF FLUE GAS GREATER THAN THAT PRODUCED BY THE BOILER.
IT WAS LATER DISCOVERED THAT THE EXPANSION JOINTS LOCATED AT THE ESP HAD
CRACKED AND WERE ALLOWING AMBIENT AIR TO ENTER THE SYSTEM. THE UTILITY
D-77
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SOUTHWESTERN PUBLIC SERVICE: HARRINGTON 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
REPORTED THEY HAD ORIGINALLY ORDERED VITRON EXPANSION JOINTS BUT INSTEAD
RECEIVED CHLOROBUTYL JOINTS WHICH SUBSEQUENTLY FAILED. DUE TO THE IN-
CREASED GAS LOAD THE UTILITY HAS HAD TO RUN MORE MODULES THAN NORMALLY
NECESSARY FOR A GIVEN BOILER LOAD. THE UTILITY PLANS TO REPLACE THE
EXPANSION JOINTS DURING THE NEXT SCHEDULED OUTAGE IN MAY.
2/81 SYSTEM 672
3/81 SYSTEM , 744
*# PROBLEMS/SOLUTIONS/COMMENTS
MODULE 3 WAS SHUT DOWN FOR 24 HOURS TO REPLACE A RUBBER PUMP LINER WHICH
HAD BEEN WORN AWAY BY THE PUMP IMPELLERS.
EXCEPT FOR THE PUMP LINER AND EXPANSION JOINT FAILURES THE SCRUBBER SYSTEM
OPERATED WELL THROUGHOUT THE JANUARY-MARCH PERIOD.
D-78
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX E
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - HG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER ANO STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - '/.
RANGE ASH CONTENT - V.
AVERAGE MOISTURE CONTENT - 7.
RAN3E MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
»* MECHANICAL COLLECTOR
TYPE
SUPPLIER
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
CHUGOKU ELECTRIC
SHIMONOSEKI
1
SHIMONOSEKI
JAPAN
******
******
219.
******
575
175
*****
*****
175
MITSUBISHI
PULVERIZED COAL
BASE
266.27
130.0
200.
CONCRETE
3.0
<****** LB/MMBTU)
( .510 LB/MMBTU)
<****** LB/MMBTU)
564255 ACFM)
266 F)
656 FT)
( 9.7 FT)
( 10768 BTU/LB)
******
COAL
******
25046.
24.60
******
2.30
******
.59
******
.04
0.01-0.11
MULTICLONE
MITSUBISHI
0
NONE
COLD SIDE
MITSUBISHI HEAVY INDUSTRIES
246.1 ( 521589 ACFM)
140.0 ( 284 F)
.8 (3. IN-H20)
SPRAY TOWER
NR
NR
MITSUBISHI
CARBON STEEL
AISI 1110
ORGANIC
SYNTHETIC RUBBER
NONE
1
E-l
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
CHUGOKU ELECTRIC: SHIMONOSEKI i (CONT.)
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
*** FGO SYSTEM
«# GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEU/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
NUMSER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - 7.
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUMBER OF STAGES
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
WASH RATE - L/S
«» REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
544.3
3.0
13.1
203.7
( 8640 GPM)
(22.5 GAL/1000ACF)
( 43.0 FT/S)
( 431725 ACFM)
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
NONE
MITSUBISHI HEAVY INDUSTRIES
MITSUBISHI
FULL SCALE
RETROFIT
85.00
1
7/79
5/79
5/77
NR
NR
1
0
COMBINATION TOWER
NR
N/A
MITSUBISHI
CARBON STEEL
AISI 1110
N/A
ORGANIC
NR
NR
4
2722.
1.0
3.0
203.73
50.0
89.0
90.0
(43200 GPM)
( 3.9 IN-H20)
( 9.8 FT/S)
( 431725 ACFM)
( 122 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
2
.1
NR
NR
FRESH
200.0
( .6 IN-H20)
( 3170 GAL/MIN)
WASTE HEAT RECOVERY
NR
NR
157.8 ( 284 F)
203.73 ( 431725 ACFM)
105.0 ( 221 F)
NR
NR
E-2
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
CHUGOKU ELECTRIC: SHIMONOSEKI i (CONT.)
** FANS
DESIGN
SUPPLIER
FUNCTION
APPLICATION
SERVICE
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** TANKS
SERVICE
NR
** PUMPS
SERVICE
NR
** SOLIDS COHCENTRATIHG/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
DIMENSIONS - FT
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
*** SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
QUALITY - X
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
NR
MITSUBISHI HEAVY INDUSTRIES
NR
'NR
NR
294.04 ( 623108 ACFM)
140.0 ( 284 F)
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
NR
NR
NUMBER
***«
NUMBER
****
CENTRIFUGE
5
0
25X SOLIDS
90X SOLIDS
THICKENER
1
0
33.0 DIA X 10.0
5X SOLIDS
25X SOLIDS
GYPSUM
6.98
99.0
NR
NR
NR
NR
NR
NR
t 7.70 TPH)
E-3
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
CHUGOKU ELECTRIC: SHIMONOSEKI i
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
CHUGOKU ELECTRIC: SHIMONOSEKI i CCONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE F60 SYSTEM OPERATED CONTINOUSLY WITH NO PROBLEMS DURING JUNE.
7/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 98.9
*» PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED DURING JULY WITH NO PROBLEMS.
8/80 SYSTEM 88.7 88.7 88.7 88.7 744 744 660 99.5
** PROBLEMS/SOLUTIONS/COMMENTS
DURING AUGUST THE FGD SYSTEM WAS SHUT DOWN FOR 84 HOURS DUE TO SOME PLUG-
GING IN THE REHEATER. DURING THIS TIME THE REHEATER WAS WATER WASHED AND
THE SOOT BLOWER SYSTEM WAS IMPROVED.
9/80 SYSTEM 89.0 89.0 89.0 89.0 720 720 641 97.3
** PROBLEMS/SOLUTIONS/COMMENTS
DURING SEPTEMBER PROBLEMS WITH PLUGGING IN THE REHEATER RECURRED. THE
TROUBLE WAS CAUSED BY ESP PROBLEMS, BY WHICH A LARGE AMOUNT OF FLYASH
WENT INTO THE REHEATER.
10/80 SYSTEM 100.0 97.4 100.0 88.0 744 673 655 88.5
** PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THE BOILER WAS TAKEN OFF LINE FOR THREE DAYS FOR AN
INSPECTION OF THE NOX REMOVAL SYSTEM.
11/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720 99.4
12/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 99.6
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING THE MONTHS OF NOVEMBER AND DECEMBER.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
«* PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME; HOWEVER THE
DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
E-5
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX E
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - V.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTUPE CONTENT - V.
AVERAGE SULFUR CONTENT - V.
RANGE SULFUR CONTENT - V.
AVERAGE CHLORIDE CONTENT - V.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
ELECTRIC POWER DEVELOPMENT
ISOGO
YOKOHAMA
JAPAN
******
20.
58.
******
238
265
238
*****
265
( .046 LB/MMBTU)
( .135 LB/MMBTU)
<****** LB/MMBTU)
IHI
PULVERIZED COAL
BASE
405.36
170.0
122.
CARBON STEEL
3.7
859000 ACFM)
338 F)
400 FT)
( 12.0 FT)
COAL
******
25958.
16.00
15.0-17.0
7.00
6.0-8.0
.60
0.2-0.6
********
******
( 11160 BTU/LB)
11160-11520
** MECHANICAL COLLECTOR
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
0
NONE
COLD SIDE
TOYO ENGINEERING
353.2 ( 748362 ACFM)
150.0 ( 302 F)
98.0
1
0
VENTURI TOWER
NR
NR
IHI-CHEMICO
43.6 DIA X 101.4
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NONE
1
2194.1 (34827 GPM)
9.4 (70.0 GAL/1000ACF)
E-6
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
ELECTRIC POWER DEVELOPMENT: IS060 1 (CONT.)
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
*»* FGO SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
«* DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* ABSCP.BER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID PECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
PRESSURE DROP - KPA
SUPEPFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH FREQUENCY
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
1.5
3.0
170.0
( 5.9 IN-H20)
( 10.0 FT/S)
( 899864 ACFM)
( 338 F)
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
IHI-CHEMICO
FULL SCALE
RETROFIT
X 97.00
95.00
1
3/76
12/75
NR
NR
1
0
VENTURI TOWER
NR
NR
IHI/CHEMICO
43.5 DIA X 76.8
CARBON STEEL
NR
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NR
NONE
1
2194.
9.4
1.5
3.0
566.28
55.0
96.7
(34827 GPM)
( 70.0 GAL/1000 ACF)
( 5.9 IN-H20)
( 10.0 FT/S)
(1200000 ACFM)
( 131 F)
( 2.0 IN-H20)
( 9.8 FT/S)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
HORIZONTAL
4
4
.5
3.0
ORGANIC
NR
INTERMITTENT
DIRECT COMBUSTION
NR
OIL
83.9 ( 151 F)
120.0 ( 248 F)
NR
E-7
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: ISOGO 1 (CONT.)
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
NUMBER OF SPARES
DESIGN
FUNCTION
APPLICATION
SERVICE
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** TANKS
SERVICE
WASTE SLURRY BLEED
ABSORBER RECYCLE
REAGENT PREP PRODUCT
THICKENER OVERFLOW
VACUUM FILTER FILTRATE
SPARGER/OXIDIZER
** PUMPS
SERVICE
SLURRY MAKEUP
ABSORBER RECIRCULATION
OXIDATION TOWER SUPPLY TRANSFER
FILTRATE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
DIMENSIONS - FT
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
*** SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
DISPOSITION
*** SLUDGE
NR
2
0
NR
BOOSTER
NR
NR
362.14
170.0
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
NR
NR
NUMBER
( 767400 ACFM)
( 338 F)
1
****
1
1
1
1
NUMBER
3
8
2
2
CENTRIFUGE
18. 57. SOLIDS
90X SOLIDS
THICKENER
1
0
20.0 DIA X 10.0
8.5X SOLIDS
18.6X SOLIDS
GYPSUM
4.53
MARKETED
( 5.00 TPH)
E-8
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: ISOGO 1 (CONT.)
** TREATMENT
METHOD FORCED OXIDATION
DEVICE OXIDATION TANK
PROPRIETARY PROCESS N/A
** DISPOSAL
NATURE NR
TYPE NR
SITE TREATMENT NR
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS PH
PROCESS CONTROL MANNER AUTOMATIC
PROCESS CHEMISTRY MODE FEEDBACK
«» WATER BALANCE
WATER LOOP TYPE OPEN
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S 40
MAKEUP WATER ADDITION - LITERS/S 22.3 ( 354 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/78 SYSTEM 720
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 744
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
100X AVAILABILITY FOR THE FGD SYSTEM WAS REPORTED DURING THE PERIOD APRIL
1978 THROUGH MARCH 1979. THE SYSTEM S02 REMOVAL EFFICIENCY WAS REPORTEDLY
AVERAGING 952.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
E-9
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
ELECTRIC POWER DEVELOPMENT: ISOGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION MAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER FOR THE ENTIRE MONTH OF
APRIL.
5/80 SYSTEM 100.0 100.0 100.0 52.8 744 393 393
6/80 SYSTEM 100.0 100.0 100.0 10.0 720 72 72
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUT DOWN FROM MAY 17 TO JUNE 27 FOR ANNUAL MAINTEN-
ANCE. THE FGD SYSTEM WAS OPERATED DURING ALL OF THE BOILER OPERATION
IN MAY AND JUNE.
744 744 744 90.9
744 744 744 91.9
720 718 718 90.4
** PROBLEMS/SOLUTIONS/COMMENTS
DURING SEPTEMBER THE BOILER WAS OUT OF SERVICE FOR APPROXIMATELY TWO HOURS
TO CHANGE THE TAP ON THE MAIN TRANSFORMER.
744 680 680 84.5
720 720 720 91.7
744 744 744 93.2
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY THROUGH DECEMBER THE FGD SYSTEM EXPERIENCED NO OPERATIONAL
PROBLEMS.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
7/80 SYSTEM
8/80 SYSTEM
9/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
99.8
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
91.4
100.0
100.0
E-10
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: ISOGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME; HOWEVER THE
DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
E-ll
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
APPENDIX E
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - V.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RAtJGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** ESP
NUMBER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATICN RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
{ .046 LB/MMBTU1
( .135 LB/MMBTU)
(****** LB/MMBTU)
ELECTRIC POWER DEVELOPMENT
ISOGO
2
YOKOHAMA
JAPAN
******
20.
58.
******
238
265
238
246
265
IHI
PULVERIZED COAL
BASE
405.36 (
170.0 (
140. (
CARBON STEEL
3.7 ( 12.0 FT)
859000 ACFM)
338 F)
460 FT)
COAL
******
25958.
16.00
15.0-17.0
7.00
6.0-8.0
.60
0.2-0.6
********
******
0
NONE
356.6
150.0
98.0
( 11160 BTU/LB)
11160-11520
( 755654 ACFM)
( 302 F)
1
0
VENTURI TOWER
NR
NR
IHI-CHEMICO
43.6 DIA X 101.4
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NONE
1
2194.1 (34827 GPM)
9.4 (70.0 GAL/1000ACF)
1.5 ( 5.9 IN-H20)
3.0 ( 10.0 FT/S)
E-12
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: ISOGO 2 (CONT.)
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
»«* FGD SYSTEM
»* GENERAL DATA
SALEABLE PRODUCT/THROWAUAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
»* DESIGN AND OPERATING PARAMETERS
** QUENCHER/FRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMSER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUFERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH FREQUENCY
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
424.6
170.0
( 699864 ACFM)
( 338 F)
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
IHI-CHEMICO
FULL SCALE
RETROFIT
X 97.00
95.00
3.0
1
5/76
3/76
NR
NR
1
0
VENTURI TOWER
NR
NR
IHI/CHEMICO
43.5 DIA X 76.8
CARBON STEEL
NR
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NR
NONE
1
2194.
9.4
1.5
3.0
566.28
55.0
96.7
(34827 GPM)
( 70.0 GAL/1000 ACF)
(5.9 IN-H20)
(10.0 FT/S)
(1200000 ACFM)
( 131 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
HORIZONTAL
4
4
.5 (
3.0 (
ORGANIC
NR
INTERMITTENT
2.0 IN-H20)
9.8 FT/S)
DIRECT COMBUSTION
NR
OIL
83.9
132.50
120.0
NR
( 151 F)
( 280783 ACFM)
( 248 F)
E-13
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: ISOGO 2 (CONT.)
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
NUMBER OF SPARES
DESIGN
FUNCTION
APPLICATION
SERVICE
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** TANKS
SERVICE
WASTE SLUP.PY BLEED
REAGENT PREP PRODUCT
THICKENER OVERFLOW
VACUUM FILTER FILTRATE
SPARGER/OXIDIZER
** PUMPS
SERVICE
SLURRY MAKEUP
ABSORBER RECIRCULATION
OXIDATION TOWER SUPPLY TRANSFER
FILTRATE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
*» SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
DIMENSIONS - FT
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
*** SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
DISPOSITION
**# SLUDGE
NR
Z
0
NR
BOOSTER
NR
NR
362.1
170.0
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
NR
NR
NUMBER
( 767400 ACFM)
( 338 F)
NUMBER
2
8
2
2
CENTRIFUGE
4
0
18.57. SOLIDS
90X SOLIDS
THICKENER
1
0
20.0 DIA X 10.0
8.SX SOLIDS
18.6X SOLIDS
GYPSUM
4.53
MARKETED
( 5.00 TPH)
E-14
-------
UTILITY FSD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: ISOGO Z (CONT.)
** TREATMENT
METHOD FORCED OXIDATION
DEVICE OXIDATION TANK
PROPRIETARY PROCESS N/A
»* DISPOSAL
NATURE NR
TYPE NR
SITE TREATMENT NR
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS PH
PROCESS CONTROL MANNER AUTOMATIC
PROCESS CHEMISTRY MODE FEEDBACK
** WATER BALANCE
MATER LOOP TYPE OPEN
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S 40
MAKEUP WATER ADDITION - LITERS/S 22.3 ( 354 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/78 SYSTEM 720
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 744
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
1002 AVAILABILITY FOR THE FGD SYSTEM WAS REPORTED DURING THE PERIOD APRIL
1978 THROUGH MARCH 1979. THE FGD SYSTEM LOGGED A TOTAL OF 1,689 HOURS OF
OPERATION.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
E-15
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: ISOGO 2 (COKT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 31.3 720 225 225
** PROBLEMS/SOLUTIONS/COMMENTS
ON MARCH 30 THE BOILER WAS SHUTDOWN FOR ANNUAL MAINTENANCE. THE UNIT
REMAINED DOWN THROUGH APRIL 20. WHEN OPERATIONS COMMENCED THE FGD SYSTEM
OPERATED WITH THE BOILER FOR THE REST OF THE MONTH.
5/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
6/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY AND JUNE THE FGD SYSTEM OPERATED WITH NO REPORTED PROBLEMS.
7/80 SYSTEM 100.0 100.0 100.0 88.2 744 656 656 82.0
»» PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY THE BOILER WAS OFF LINE APPROXIMATELY 88 HOURS FOR MAINTEN-
ANCE.
8/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 91.9
9/80 SYSTEM 100.0 100.0 100.0 99.8 720 718 718 92.1
** PROBLEMS/SOLUTIONS/COMMENTS
APPROXIMATELY TWO HOURS OF BOILER OUTAGE TIME WAS NECESSARY TO CHANGE
THE TAP OF THE MAIN TRANSFORMER.
744 744 744 92.2
720 720 720 92.7
744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY THROUGH DECEMBER THE FGD SYSTEM OPERATED WITH NO PROBLEMS.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
E-16
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: ISOGO Z (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
»* PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME; HOWEVER THE
DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
E-17
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX E
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - '/.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - Y.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
ELECTRIC POWER DEVELOPMENT
TAKASAGO
TAKASAGO
JAPAN
******
37.
ISO.
******
230
250
230
238
250
( .086 LB/MMBTU)
( .350 LB/MMBTU)
(****** LB/MMBTU)
774000 ACFM)
310 F)
( 590 FT)
( 11.9 FT)
( 11160 BTU/LB)
11160-11520
MITSUBISHI
******
BASE
365.25
154.4
180.
CARBON STEEL
3.6
COAL
******
25958.
22.00
******
7.00
******
1.80
******
********
******
0
NONE
COLD SIDE
MITSUBISHI HEAVY INDUSTRIES
344.3 ( 729507 ACFM)
154.4 ( 310 F)
99.5
1
0
VENTURI TOWER
NR
NR
MITSUI-CHEMICO
37.7 DIA X 62.3
CARBON STEEL
AISI 1110
ORGANIC
NR
NONE
1
1228.8 (19505 GPM)
6.5 (48.6 GAL/1000ACF)
E-1C
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
«** FGD SYSTEM
** GENERAL DATA
SALEABLE FRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
»* QUENCHER/FRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
INLET GAS TEMPERATURE - C
50Z REMOVAL EFFICIENCY - X
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
«* ABSORBER
NUMBER
GENERIC TYPE
1.5
260.5
154.4
56.0
50.0
(5.9 IN-H20)
( 552000 ACFM)
( 310 F)
SALEABLE PRODUCT
MET SCRUBBING
LIMESTONE
MITSUI-CHEMICO
FULL SCALE
RETROFIT
93.00
3.2
1
2/75
NR
NR
1
0
VENTURI TOWER
NR
NR
MITSUI/CHEMICO
45.9 DIA X 78.7
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
2566.
6.5
1.5
55.0
85.0
(40727 GPM)
( 48.6 GAL/1000 ACF)
( 5.9 IN-H20)
( 131 F)
VENTURI TOWER
NR
NR
MITSUI/CHEMICO
26.2 DIA X 82.3
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
610.
69.37
154.4
63.0
SPRAY TOWER
( 9689 GPM)
( 147000 ACFM)
( 310 F)
E-19
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
»* TANKS
SERVICE
CENTRIFUGE
REAGENT PREP PRODUCT
ABSORBER RECYCLE
** PUMPS
SERVICE
NR
NR
MITSUI/CHEMICO
19.7 DIA X 65.0
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
9986.
18.26
(»**»* 6PM)
( 38686 ACFM)
( 310 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
4
4
NR
NR
BLENDED
DIRECT COMBUSTION
NR
OIL
120.0 ( 248 F)
NR
NR
NR
BOOSTER
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
NR
NR
NUMBER
CIRCULATION
PH ADJUSTER CIRCULATION
REACTOR CIRCULATION
NUMBER
5
3
3
E-20
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
«* SOLIDS CONCENTRATING/DEWATERING
DEVICE CENTRIFUGE
NUMBER 7
OUTLET STREAM CHARACTERISTICS 90X SOLIDS
»* SOLIDS CONCENTRATING/DEWATERING
DEVICE THICKENER
OUTLET STREAM CHARACTERISTICS 20X SOLIDS
**» SALEABLE BYPRODUCTS
NATURE GYPSUM
FULL LOAD QUANTITY - M T/H 8.63 ( 9.50 TPH)
»»* SLUDGE
«» TREATMENT
METHOD FORCED OXIDATION
DEVICE OXIDATION TANK
PROPRIETARY PROCESS N/A
** DISPOSAL
NATURE NR
TYPE NR
SITE TREATMENT NR
»* PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS FLUE GAS VOLUME t 502 CONCENTRATION
** HATER BALANCE
WATER LOOP TYPE OPEN
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S 40
MAKEUP WATER ADDITION - LITERS/S 13.1 ( 208 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/75 SYSTEM 96.9 88.8 672 616 597
*» PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS DOWN ONCE DUE TO A PIPING FLANGE LEAK.
3/75 SYSTEM 100.0 48.4 744 360 360
4/75 SYSTEM 100.0 44.1 720 318 318
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS TAKEN OFF-LINE FOR ANNUAL MAINTENANCE DURING MARCH AND
APRIL.
5/75 SYSTEM 100.0 96.4 744 717 717
6/75 SYSTEM 97.9 97.9 720 720 705
7/75 SYSTEM 98.0 97.8 744 743 728
8/75 SYSTEM 98.0 98.0 744 744 729
9/75 SYSTEM 95.7 91.7 720 690 660
E-21
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SQZ PART. HOURS HOURS HOURS FACTOR
«* PROBLEMS/SOLUTIONS/COMMENTS
SYSTEM DOWN TIME FROM JUNE THROUGH SEPTEMBER WAS DUE TO MIST ELIMINATOR
SCALING.
10/75 SYSTEM 95.2 95.2 744 744 708
** PROBLEMS/SOLUTIONS/COMMENTS
FAN VIBRATIONS CAUSED A SYSTEM OUTAGE DURING THE MONTH.
11/75 SYSTEM 98.5 98.5 720 720 709
** PROBLEMS/SOLUTIONS/COMMENTS
MIST ELIMINATOR SCALING WAS ENCOUNTERED IN NOVEMBER.
12/75 SYSTEM 95.9 92.2 744 715 686
1/76 SYSTEM 100.0 100.0 744 744 744
2/76 SYSTEM 95.2 90.8 696 664 632
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY, THE SYSTEM AGAIN ENCOUNTERED MIST ELIMINATOR SCALING.
3/76 SYSTEM 100.0 92.3 744 687 687
4/76 SYSTEM 100.0 30.4 720 219 219
5/76 SYSTEM 100.0 100.0 744 744 744
6/76 SYSTEM 100.0 100.0 720 720 720
7/76 SYSTEM 100.0 100.0 744 744 744
8/76 SYSTEM 744 744
9/76 SYSTEM 100.0 100.0 720 720 720
10/76 SYSTEM 91.7 91.7 744 744 682
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS TAKEN OFF-LINE FOR CLEANING OF THE FIRST STAGE SCRUBBER.
11/76 SYSTEM 99.3 99.3 720 720 715
#» PROBLEMS/SOLUTIONS/COMMENTS
REPAIR OF A DUCT FORCED ONE SYSTEM OUTAGE DURING THE MONTH.
12/76 SYSTEM 98.9 98.9 744 744 736
** PROBLEMS/SOLUTIONS/COMMENTS
A DECEMBER OUTAGE WAS DUE TO THE REPAIR OF A SPRAY PIPE.
1/77 SYSTEM 99.3 99.3 744 744 739
E-22
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 198*
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS TAKEN OFF-LINE ONCE FOR CLEANING OF THE FIRST STAGE
SCRUBBER.
2/77 SYSTEM 100.0 100.0 672 672 672
3/77 SYSTEM .0 744 0 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS OFF DURING MARCH FOR ANNUAL BOILER MAINTENANCE.
4/77 SYSTEM 100.0 71.3 720 513 513
5/77 SYSTEM 98.7 98.7 744 744 734
** PROBLEMS/SOLUTIONS/COMMENTS
FAN VIBRATIONS CAUSED ONE SYSTEM OUTAGE DURING MAY.
6/77 SYSTEM 100.0 100.0 720 720 720
7/77 SYSTEM 100.0 96.4 744 717 717
** PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST STAGE ABSORBER WAS CLEANED DURING JULY.
8/77 SYSTEM 100.0 100.0 744 744 744
9/77 SYSTEM 100.0 100.0 720 720 720
10/77 SYSTEM 94.2 94.2 744 744 701
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS OFF LINE PART OF THIS MONTH FOR CLEANING OF THE SCRUBBERS
AMD REACTORS.
11/77 SYSTEM 100.0 100.0 720 720 720
12/77 SYSTEM 100.0 100.0 744 744 744
1/78 SYSTEM 100.0 100.0 744 744 744
»* PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST REACTOR WAS CLEANED THIS MONTH.
4/78 SYSTEM 720
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 744
8/78 SYSTEM 744
9/78 SYSTEM - 720
10/78 SYSTEM 744
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/78 SYSTEM 720
12/78 SYSTEM 74*
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL 1978 THROUGH MARCH 1979 NO FORCED OUTAGES OCCURRED. THE FGD
SYSTEM AVAILABILITY WAS 99.9X, AND LOGGED A TOTAL OF 7823.4 HOURS OF
OPERATION WITH 6.1 HOURS OF SCHEDULED OUTAGE TIME.
4/79 SYSTEM 720
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 31.1 720 224 224
*» PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUTDOWN ON MARCH 29 FOR ANNUAL MAINTENANCE. THE UNIT
REMAINED OFF LINE THROUGH APRIL 21. WHEN OPERATIONS COMMENCED THE FGD
SYSTEM OPERATED WITH THE BOILER FOR THE REST OF THE MONTH.
5/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
6/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
»* PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM EXPERIENCED NO PROBLEMS DURING THE MAY-JUNE PERIOD.
7/80 SYSTEM 100.0 100.0 100.0 100.0 744 74* 744 33.4
8/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 83.6
9/60 SYSTEM 100.0 100.0 100.0 100.0 720 720 720 83.3
E-24
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
«* PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING THE THIRD QUARTER 1980.
10/80 SYSTEM 99.5 99.5 99.5 99.5 7** 7** 7*0 85.3
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM UAS SHUT DOWN FOR APPROXIMATELY FOUR HOURS IN OCTOBER FOR
AH INSPECTION OF THE SECOND SCRUBBER OUTLET DUCT AND THE MIST ELIMINATOR.
THE INSPECTION REVEALED THAT NO PROBLEM EXISTED.
11/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720 85.0
12/80 SYSTEM 100.0 100.0 100.0 100.0 7** 7** 7** 89.9
»* PROBLEMS/SOLUTIOHS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING NOVEMBER AND DECEMBER.
1/81 SYSTEM 7**
2/81 SYSTEM 672
3/81 SYSTEM 7**
** PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME; HOWEVER THE
DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
E-25
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX E
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RAN3E HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
( .086 LB/MMBTU)
( .350 LB/MMBTU)
(****** LB/MMBTU)
ELECTRIC POWER DEVELOPMENT
TAKASAGO
2
TAKASAGO
JAPAN
******
37.
150.
******
230
250
238
250
MITSUBISHI
******
BASE
365.25
154.4
180.
CARBON STEEL
3.6
774000 ACFM)
310 F)
590 FT)
( 11.9 FT)
( 11160 BTU/LB)
11160-11520
COAL
******
25958.
22.00
******
7.00
******
1.80
******
********
******
0
NONE
COLD SIDE
MITSUBISHI HEAVY INDUSTRIES
344.3 ( 729507 ACFM)
154.4 ( 310 F)
99.5
1
0
VENTURI TOWER
NR
NR
MITSUI-CHEMICO
37.7 DIA X 62.3
CARBON STEEL
AISI 1110
ORGANIC
NR
NONE
1
1542.2 (24480 GPM)
6.5 (48.6 GAL/1000ACF)
E-26
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
ELECTRIC POWER DEVELOPMENT: TAKASAGO 2 (CONT.)
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
«»* FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROMAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
1.5
260.5
154.4
56.0
50.0
(5.9 IN-H20)
( 552000 ACFM)
( 310 F)
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
MITSUI-CHEMICO
FULL SCALE
RETROFIT
93.00
3.2
1
3/76
NR
NR
1
0
VENTURI TOWER
NR
NR
MITSUI/CHEMICO
45.9 DIA X 78.7
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
2066.
6.5
1.5
280.24
55.0
85.0
(32801 GPM)
( 48.6 GAL/1000 ACF)
( 5.9 IN-H20)
( 593855 ACFM)
( 131 F)
VENTURI TOWER
NR
NR
MITSUI/CHEMICO
26.2 DIA X 82.3
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
743.
69.37
154.4
63.0
(11799 GPM)
( 147000 ACFM)
( 310 F)
E-27
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
ELECTRIC POWER DEVELOPMENT: TAKASAGO 2 (CONT.)
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
*# DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
»* TANKS
SERVICE
SPRAY TOWER
NR
NR
MITSUI/CHEMICO
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
19639.
36.51
(»***# GPM)
( 77372 ACFM)
( 310 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
4
4
NR
NR
BLENDED
DIRECT COMBUSTION
NR
OIL
120.0 ( 248 F)
NR
NR
NR
BOOSTER
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
NR
NR
NUMBER
CENTRIFUGE
REAGENT PREP PRODUCT
ABSORBER RECYCLE
E-28
-------
ELECTRIC POWER DEVELOPMENT: TAKASAGO 2 (CONT.)
UTILITY F60 SURVEY: OCTOBER 1983 - SEPTEMBER 198*
#* PUMPS
SERVICE
NUMBER
CIRCULATION 5
PH ADJUSTER CIRCULATION 2
REACTOR CIRCULATION 1
»* SOLIDS CONCENTRATING/DEWATERING
DEVICE CENTRIFUGE
NUMBER 7
OUTLET STREAM CHARACTERISTICS 90X SOLIDS
«* SOLIDS CONCENTRATING/DEWATERING
DEVICE THICKENER
OUTLET STREAM CHARACTERISTICS 20X SOLIDS
«»» SALEABLE BYPRODUCTS
NATURE GYPSUM
FULL LOAD QUANTITY - M T/H 8.62
*** SLUDGE
«* TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
»* DISPOSAL
NATURE
TYPE
SITE TREATMENT
»* PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
*» WATER BALANCE
WATER LOOP TYPE
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S 40
MAKEUP WATER ADDITION - LITERS/S 13.1
( 9.50 TPH)
FORCED OXIDATION
OXIDATION TANK
N/A
NR
NR
NR
FLUE GAS VOLUME ft S02 CONCENTRATION
OPEN
( 208 GPM)
PERFORMANCE DATA T
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/76 SYSTEM
4/76 SYSTEM
5/76 SYSTEM
6/76 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
29.0
87.8
744 744 720
720 720 720
744 216 216
720 632 632
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS DOWN FOR PART OF MAY AND JUNE FOR ANNUAL BOILER MAINTENANCE.
7/76 SYSTEM 100.0 100.0 744 744 744
8/76 SYSTEM 100.0 100.0 744 744 744
9/76 SYSTEM 100.0 100.0 720 720 720
10/76 SYSTEM 94.2 94.2 744 744 701
E-29
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
ELECTRIC POWER DEVELOPMENT: TAKASAGO 2 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
OUTAGE TIME DURING OCTOBER WAS NECESSARY FOR DUCT CLEANING.
11/76 SYSTEM 100.0 100.0 720 720 720
12/76 SYSTEM 99.3 99.3 744 744 739
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS DOWN BRIEFLY FOR REPAIR OF A GYPSUM CONVEYOR.
1/77 SYSTEM 100.0 100.0 744 744 744
2/77 SYSTEM 88.2 88.2 672 672 593
3/77 SYSTEM 98.7 98.7 744 744 734
»» PROBLEMS/SOLUTIONS/COMMENTS
OUTAGE TIME IN FEBRUARY & MARCH WAS NEEDED FOR CLEANING OF A PH CONTROLLER.
4/77 SYSTEM 100.0 100.0 720 720 720
5/77 SYSTEM 100.0 51.6 744 384 384
6/77 SYSTEM 100.0 3.3 720 240 240
7/77 SYSTEM 100.0 100.0 744 744 744
8/77 SYSTEM 100.0 100.0 744 744 744
9/77 SYSTEM 100.0 100.0 720 720 720
10/77 SYSTEM 100.0 100.0 744 744 744
11/77 SYSTEM 89.2 89.2 720 720 642
«* PROBLEMS/SOLUTIONS/COMI1ENTS
CLEANING OF THE PH CONTROLLER CAUSED ONE OUTAGE DURING NOVEMBER.
A REACTOR WAS ALSO CLEANED THIS MONTH.
12/77 SYSTEM 100.0 100.0 744 744 744
1/78 SYSTEM 744 744
2/78 SYSTEM 672
3/78 SYSTEM 720
4/78 SYSTEM 720
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 744
8/78 SYSTEM 744
9/78 SYSTEM 720
E-30
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: TAKASAGO 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 71*
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE PERIOD FROM APRIL 1978 THROUGH MARCH 1979 THE FGD SYSTEM
OPERATED WITH 99.SX AVAILABILITY. THERE WERE NO FORCED OUTAGES DURING THIS
TIME. A TOTAL OF 8147.4 HOURS OF FGO SYSTEM OPERATION WERE LOGGED WITH
19.5 HOURS OF SCHEDULED OUTAGE TIME.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
B/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
»* PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
5/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
*» PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL AND MAY THE UTILITY EXPERIENCED NO PROBLEMS WITH THE FGO
SYSTEM.
6/80 SYSTEM 100.0 100.0 100.0 24.6 720 177 177
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUTDOWN FROM JUNE 3 TO JUNE 24 FOR ANNUAL MAINTENANCE.
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER THE REMAINDER OF THE TIME.
7/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 83.0
E-31
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMEKT: TAKASAGO 2 (CONT.)
PERIOD
8/80
9/80
10/80
11/80
12/80
MODULE AVAILABILITY
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100.0
100.0
OPERABILITY
100.0
100.0
100.0
100.0
100.0
HtKi-UKnAr
RELIABILITY
100
100
100
100
100
.0
.0
.0
.0
.0
UTILIZATION X REMOVAL PER BOILER
S02 PART. HOURS HOURS
100
100
100
100
87
.0
.0
.0
.0
.3
744
720
744
720
744
744
720
744
720
649
FGD
HOURS
744
720
744
720
649
CAP.
FACTOR
83.3
83.4
85.1
84.8
78.4
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY THROUGH DECEMBER NO FGD-RELATED PROBLEMS WERE EXPERIENCED.
IN DECEMBER THE BOILER WAS OUT OF SERVICE APPROXIMATELY FOUR DAYS FOR
GENERAL MAINTENANCE.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME; HOWEVER THE
DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
E-32
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX E
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RAN3E ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RAN3E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
«** PARTICLE CONTROL
*# MECHANICAL COLLECTOR
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLCM RATE - CU.M/S
( .130 LB/MMBTU)
( .630 LB/MMBTU)
(*«**** LB/MMBTU)
ELECTRIC POMER DEVELOPMENT
TAKEHARA
1
MIHARA
JAPAN
******
56.
271.
******
231
250
231
239
250
BABCOCK-HITACHI
PULVERIZED COAL
BASE
577.13
140.0
201.
CARBON STEEL
3.6
(1223000 ACFM)
( 284 F)
( 660 FT)
( 11.9 FT)
( 10804 BTU/LB)
10804-11520
COAL
******
25130.
23.00
******
9.05
******
2.00
******
.05
******
0
NONE
COLD SIDE
SUMITOMO HEAVY INDUSTRIES
333.2 ( 706000 ACFM)
140.0 ( 284 F)
98.0
VENTURI TOMER
NR
NR
HITACHI
NR
NR
ORGANIC
NR
NONE
1
533.7 ( 8471 GPM)
2.5 (18.7 GAL/1000ACF)
2.3 ( 9.1 IN-H20)
168.0 ( 356000 ACFM)
E-33
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: TAKEHARA 1 (CONT.)
INLET GAS TEMPERATURE - C 140.0
*** FGD SYSTEM
( 284 F)
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
WASH FREQUENCY
WASH RATE - L/S
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
NONE
BABCOCK-HITACHI
FULL SCALE
RETROFIT
X 91.70
94.20
3.2
1
2/79
2/77
NR
NR
TRAY TOWER
NR
NR
BABCOCK-HITACHI
CARBON STEEL
NR
N/A
ORGANIC
POLYESTER
NR
5
721. (11448 GPM)
7.0 ( 52.4 GAL/1000 ACF)
3.8 (15.2 IN-H20)
164.76 ( 349142 ACFM)
52.2 ( 126 F)
PRIMARY COLLECTOR
2
IMPINGEMENT
TUBE BANK
VERTICAL PARALLEL TUBES
HORIZONTAL
.1
NR
NR
FRESH
CONTINUOUS
( .4 IN-H20)
1.3
20 GAL/MIN)
DIRECT COMBUSTION
NR
OIL
120.0 ( 248 F)
NR
NR
2
NR
BOOSTER
INDUCED DRAFT
E-34
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
ELECTRIC POWER DEVELOPMENT: TAKEHARA 1 (CONT.)
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»* REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
«« TANKS
SERVICE
PR E SATURATOR/QUENCHER
ABSOR3ER RECYCLE
VACUUM FILTER FILTRATE
SPARGER/OXIDIZER
»* PUMPS
SERVICE
COOLER RECYCLE
ABSORBER RECIRCULATION
«* SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUM5ER
NUMBER OF SPARES
CAPACITY
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUM3ER
CONFIGURATION
DIMENSIONS - FT
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
*** SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
QUALITY - •/.
DISPOSITION
»** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
MET
NR
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
NR
NR
NUMBER
2
****
****
2
NUMBER
Z
4
CENTRIFUGE
9
1
4 GPM
20X SOLIDS
88X SOLIDS
THICKENER
1
HORIZONTAL
45.0 OIA X 10.0
12X SOLIDS
20X SOLIDS
GYPSUM
9.89
95.0
MARKETED
( 10.90 TPH)
FORCED OXIDATION
OXIDATION TANK
N/A
NR
NR
NR
E-35
-------
UTILITY F60 SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: TAKEHARA 1 (CONT.>
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS PH, GAS FLOW
CONTROL LEVELS PH 5.0-6.0
PROCESS CONTROL MANNER AUTOMATIC
** WATER BALANCE
WATER LOOP TYPE OPEN
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S 60
MAKEUP WATER ADDITION - LITERS/S 14.9 ( 237 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILEF! FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/78 SYSTEM 720
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 744
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
99.95X AVAILABILITY WAS REPORTED FOR THE PERIOD FROM APRIL 1978 THROUGH
MARCH 1979.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
E-36
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ELECTRIC POWER DEVELOPMENT: TAKEHARA 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*» PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
5/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
6/80 SYSTEM 87.9 100.0 100.0 87.9 720 633 633 82.4
«* PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS OUT OF SERVICE FOR APPROXIMATELY 3 DAYS IN JUNE TO
REMOVE THE SCALE ACCUMULATION IN THE FGD OUTLET DUCT.
744 744 744 95.5
744 744 744 95.3
720 720 720 95.3
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING THE THIRD QUARTER 1980.
10/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 94.5
11/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720 95.2
12/80 SYSTEM 100.0 100.0 100.0 27.7 744 206 206 22.4
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS OUT OF SERVICE FROM DECEMBER 1 THROUGH DECEMBER 25 FOR
SCHEDULED MAINTENANCE.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME; HOWEVER THE
DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
7/80 SYSTEM
8/80 SYSTEM
9/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
E-37
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX E
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
»* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANSE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
*»» FGD SYSTEM
«* GENERAL DATA
SALEABLE PRODUCT/THROMAWAY PRODUCT
S02 REMOVAL MODE
HOKKAIDO ELECTRIC POWER
TOMATOATSUMA THERMAL POM
1
TOMAKOMAI
JAPAN
******
******
******
350
350
175
175
350
BABCOCK-HITACHI
PULVERIZED COAL
BASE
508.21
121.1
170.
CARBON STEEL
4.5
(****** LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
(1076939 ACFM)
( 250 F)
( 558 FT)
( 14.6 FT)
COAL
BITUMINOUS
25121.
20.50
******
7.00
******
.30
******
********
******
HOT SIDE
HITACHI
828.8
363.9
.2
99.8
( 10800 BTU/LB)
******
(1756252 ACFM)
( 687 F)
( 1. IN-H20)
VENTURI TOMER
NR
NR
BABCOCK-HITACHI
NR
NR
NR
NR
NONE
198.7
47.2
( 421036 ACFM)
( 117 F)
SALEABLE PRODUCT
MET SCRUBBING
E-38
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
HOKKAIDO ELECTRIC POWER: TOMATOATSUMA THERMAL POM 1 (CONT.)
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN 302 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
«* QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
»» MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*» REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
DESIGN
SUPPLIER
FUNCTION
APPLICATION
SERVICE
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LIMESTONE
BABCOCK-HITACHI
FULL SCALE
RETROFIT
90.00
.0
1
10/80
7/80
NR
NR
1
NR
NR
NR
BABCOCK-HITACHI
NR
NR
NR
NR
NR
NR
198.69
47. Z
90.0
( 421036 ACFM)
( 117 F)
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
NR
VERTICAL
NR
NR
WASTE HEAT RECOVERY
GAS-GAS
WHEEL TYPE
14.3
65.6
199.17
NR
NR
( 118 F)
( 422057 ACFM)
CENTRIFUGAL
HITACHI,LOT.
BOOSTER
NR
NR
254.47
137.2
NR
NR
NR
NR
NR
NR
NR
( 539247 ACFM)
( 279 F)
E-39
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
HOKKAIDO ELECTRIC POWER: TOflATOATSUMA THERMAL POW 1 (CONT. )
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
PRODUCT QUALITY - X SOLIDS
** PUMPS
SERVICE
NR
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
*** SALEABLE BYPRODUCTS
NATURE
QUALITY - X
DISPOSITION
*»* SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
«* DISPOSAL
NATURE
TYPE
SITE TREATMENT
** WATER BALANCE
WATER LOOP TYPE
MAKEUP WATER ADDITION - LITERS/S
NR
WET BALL MILL
NR
NR
1
92.0
NUMBER
THICKENER
Z
CENTRIFUGE
3
1
GYPSUM
45.0
MARKETED
NR
NR
NR
NR
NR
NR
CLOSED
4.0
63 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOS PART. HOURS HOURS HOURS FACTOR
10/80 SYSTEM 100.0 100.0 100.0 70.3 94.40 744 523 523 46.0
** PROBLEMS/SOLUTIONS/COMMENTS
OPERATIONS AT THE TOMATOATSUMA STATION COMMENCED IN OCTOBER 1980.
11/80 SYSTEM 100.0 100.0 100.0 85.1 720 613 613 61.1
12/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 94.7
** PROBLEMS/SOLUTIONS/COMMENTS
DURING DECEMBER SCALE FORMATION WAS OBSERVED IN THE PIPING AND IN A PUMP OF
THE WASTE WATER TREATMENT FACILITY. A WATER WASH LINE WAS INSTALLED FOR
THE PIPING AND A PUMP WAS ADDED TO ELIMINATE SCALE. THE FGO SYSTEM
OPERATION WAS NOT AFFECTED DURING THIS TIME.
E-40
3BRKPT PRINTS
-------
UTILITY F6D SURVEY: OCTOBER 1963 - SEPTEMBER
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY MO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
«* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - Y.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RAN3E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
«** PARTICLE CONTROL
»* MECHANICAL COLLECTOR
NUM3ER
TYPE
** ESP
«* PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
»** FGD SYSTEM
*» GENERAL DATA
SALEABLE PRODUCT/THROMAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
CURRENT STATUS
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5A
FARMINGTON
NEM MEXICO
C
21.
258.
******
2089
755
*****
*****
755
******
PULVERIZED COAL
BASE
( .050 LB/MMBTU)
( .600 LB/MMBTU)
(****** LB/MMBTU)
(******* ACFM)
(**** F)
(**** FT)
(****» FT)
( 9700 BTU/LB)
******
********
*******
******
NR
*******
COAL
SUBBITUMINOUS
22562.
24.00
******
11.00
******
.81
******
********
******
0
NONE
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
THROMAWAY PRODUCT
MET SCRUBBING
LIME
SOUTHERN CALIFORNIA EDISON
BECHTEL
EXPERIMENTAL
RETROFIT
8
F-l
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
ARIZONA PUBLIC SERVICE: FOUR CORNERS 5A (CONT.)
TERMINATION
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTIN3 DEVICE TYPE
NUMBER OF CONTACTING ZONES
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«« REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
12/76
2/76
1/74
NR
NR
SPRAY TOWER
OPEN CROSSCURRENT SPRAY
HORIZONTAL SPRAY CHAMBER
60.0 X 28.0 X 17.0
CARBON STEEL
AISI 1110
N/A
ORGANIC
NATURAL RUBBER; GLASS FLAKE-FILLED POLYESTER
BLACK NATURAL RUBBER; NR
NONE
5
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
CLOSED VANE
STAINLESS STEEL; CARBON STEEL
NR
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLE
NR
NR
CENTRIFUGAL
BOOSTER
FORCED DRAFT
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
SLAKER
DETENTION
N/A
1
F-2
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
ARIZONA PUBLIC SERVICE: FOUR CORNERS 5A (CONT.)
** PUMPS
SERVICE NUMBER
SLURRY RECIRCULATION 12
** SOLIDS CONCENTRATIN6/DEMATERING
DEVICE THICKENER
NUMBER 1
DIMENSIONS - FT 60.0 DIA
SHELL GENERIC MATERIAL TYPE CARBON STEEL
OUTLET STREAM CHARACTERISTICS 30X SOLIDS
*** SLUDGE
»« TREATMENT
METHOD NR
DEVICE NR
PROPRIETARY PROCESS NR
** DISPOSAL
NATURE NR
TYPE NR
SITE TREATMENT NR
F-3
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
BOSTON EDISON
MYSTIC
6
EVERETT
MASSACHUSETTS
******
******
******
******
*****
150
*****
*****
150
COMBUSTION ENGINEERING
OIL FIRED
******
273.70
148.9
99.
NR
*******
(****** LB/MMBTU)
(****** LB/MMBTU)
I****** LB/MMBTU)
( 580000 ACFM)
( 300 F)
( 325 FT)
(«**** FT)
OIL
NO. 6
(****** BTU/LB)
******
.07
******
1.00
******
2.00
******
********
******
0
NONE
0
NONE
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
SALEABLE PRODUCT
WET SCRUBBING
MAGNESIUM OXIDE
GE ENVIRONMENTAL SERVICES
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
BOSTON EDISON: MYSTIC 6 (CONT.)
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
«* DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUMBER OF PASSES PER STAGE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
»* REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
DEMONSTRATION
RETROFIT
X 55.00
90.00
8
7/7*
4/72
4/72
0/70
NR
NR
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
CARBON STEEL
NR
N/A
ORGANIC
EPOXY
FLAKELINE E
N/A
1
9*5. (15000 GPM)
*.* ( 33.0 GAL/1000 ACF)
200.56 ( 425000 ACFH)
1*8.9 ( 300 F)
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
CLOSED VANE
6
NR
NR
FRESH
0
NONE
N/A
N/A
NONE
N/A
2
NR
NR
INDUCED DRAFT
NR
NR
NR
NR
NR
NR
NR
NR
NR
F-5
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
BOSTON EDISON: MYSTIC 6 (CONT.)
** DUCTWORK
SHELL GENERIC MATERIAL TYPE NR
SHELL SPECIFIC MATERIAL TYPE NR
LINER GENERIC MATERIAL TYPE NR
LINER SPECIFIC MATERIAL TYPE NR
** REAGENT PREPARATION EQUIPMENT
FUNCTION SLAKER
DEVICE NR
DEVICE TYPE NR
** SOLIDS CONCENTRATING/DEWATERING
DEVICE CENTRIFUGE
NUMBER 1
SHELL GENERIC MATERIAL TYPE CARBON STEEL
FEED STREAM CHARACTERISTICS 10X SOLIDS
*** SLUDGE
«* TREATMENT
METHOD NR
DEVICE NR
PROPRIETARY PROCESS NR
** DISPOSAL
NATURE N/A
TYPE NONE
SITE TREATMENT NR
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS PH, FLUE GAS INLET TEMP., SCRUBBER OUTLET TEMP.
COtlTROL LEVELS PH 6.8
MONITOR LOCATION PH - BLEED LINE FROM ABSORBER TO CENTRIFUGE
PROCESS CONTROL MANNER MANUAL
PROCESS CHEMISTRY MODE FEEDBACK
** WATER BALANCE
WATER LOOP TYPE CLOSED
F-6
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
502 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RAN3E HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
RANGE MOISTUPE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
«* FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE-TYPE
COMMONWEALTH EDISON
POWERTON
51
PEKIN
ILLINOIS
E
43. (
774. (
******
1700
450
400
425
450
BABCOCK i MILCOX
CYCLONE
BASE
722.18
157.2
137.
CONCRETE
6.4
100 LB/MMBTU)
800 LB/MMBTU)
I****** LB/MKBTU)
(1530370 ACFM)
( 315 F)
( 450 FT)
( 21.0 FT)
COAL
******
24516.
( 10540 BTU/LB)
******
9.16
16.34
******
3.53
******
.20
******
0
NONE
0
NONE
COLD SIDE
RESEARCH-COTTRELL
722.2 (1530370 ACFM)
157.2 ( 315 F)
98.7
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
F-7
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
COMMONWEALTH EDISON: POWERTON 51 (CONT.)
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*« ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
502 REMOVAL EFFICIENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMSER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
SUPERFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REKEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
SARGENT & LUNDY
FULL SCALE
RETROFIT
75.50
5.6
8
5/82
6/81
4/80
5/76
NR
NR
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
55.0 X 30.0 X 18.0
CARBON STEEL
AISI 1110
N/A
ORGANIC
SYNTHETIC RUBBER
NEOPRENE LS-576
PLASTIC/RUBBER MOBILE BALLS
3
1575.
6.6
3.0
3.8
240.73
157.2
75.5
(25000 GPM)
( 49.0 GAL/1000 ACF)
(12.0 IN-H20)
( 12.5 FT/S)
( 510123 ACFM)
( 315 F)
PRIMARY COLLECTOR
2
IMPINGEMENT
BAFFLE
CLOSED VANE
HORIZONTAL
2.7 (9.0 FT/S)
ORGANIC
FIBER-REINFORCED POLYESTER
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLE
13.9 ( 25 F)
583.28 (1236021 ACFM)
54.4 ( 130 F)
NR
NR
F-8
-------
COMMONWEALTH EDISON: POWERTON 51 (CONT.)
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
»* FANS
DESIGN
SUPPLIER
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
»* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWCPK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LIHER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
MANUFACTURER
NUMBER
FULL LOAD DRY FEED CAPACITY - M.TONS/HR
*« TANKS
SERVICE
ABSORBER RECYCLE
REAGENT PREP PRODUCT
MIST ELIMINATOR WASH
WASTE SLURRY BLEED
THICKENER OVERFLOW
** PUMPS
SERVICE
RECLAIMED WATER TRANSFER
WASTE SLURRY TRANSFER
FILTRATE TRANSFER
COMDEK'SATE RETURN
SERVICE WATER BOOSTER
FILTERED WATER BOOSTER
SURGE PONO RECOVERY
SLURRY RECIRCULATION
REACTANT FEED
DEMISTER WASH
WASTE SLURRY
SLURRY TRANSFER
»« SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUKSER OF SPARES
SHELL GENERIC MATERIAL TYPE
OUTLET STREAM CHARACTERISTICS
*» SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
DIMENSIONS - FT
SHELL GENERIC MATERIAL TYPE
OUTLET STREAM CHARACTERISTICS
CENTRIFUGAL
GREEN FAN
BOOSTER
FORCED DRAFT
DRY
CARBON STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
COMPARTMENTED
NR
KOPPERS
2
ZO.O (
NUMBER
22 TPH)
NUMBER
2
2
3
2
2
2
3
9
2
2
2
VACUUM FILTER
3
1
CARBON STEEL
55X SOLIDS
THICKENER
1
170.0 DIA X 10.0
CARBON STEEL
35X SOLIDS
F-9
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: POWERTON 51 (CONT.)
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
INLET QUALITY - X
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
** DISPOSAL
NATURE
TYPE
LOCATION
SITE TREATMENT
SITE CAPACITY - CU.M
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
PROCESS CONTROL MANNER
PROCESS CHEMISTRY MODE
** WATER BALANCE
WATER LOOP TYPE
MAKEUP WATER ADDITION - LITERS/S
FIXATION
PUG MILL
CONVERSION SYSTEMS [POZ-0-TECI
35.0
FINAL
POND
NONE
INTERIM
PONO
ON-SITE
CLAY LINING
122300
100.0 ACRE-FT)
S02, GAS FLOW, PH
AUTOMATIC
FEEDBACK/FEED FORWARD
CLOSED
35.3
( 560 GPM)
F-10
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
COMMONWEALTH
WILL COUNTY
1A
ROMEOVILLE
ILLINOIS
E
86.
77*.
******
11*7
167
137
1**
167
EDISON
( .200 LB/MMBTU)
( 1.800 LB/MMBTU)
I****** LB/MMBTU)
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RAUSE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
RAUSE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RAH3E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
»* FABRIC FILTER
NUMBER
TYPE
«* ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUM2ER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
BABCOCK *
CYCLONE
CYCLING
363.36
179.*
107.
NR
3.8
WILCOX
( 770000 ACFM)
( 355 F)
( 350 FT)
( 12.* FT)
COAL
******
22260. ( 9570 BTU/LB)
9100-10500
7.*0
3.0-16.0
********
******
1.50
0.3-*.5
********
******
0
NONE
0
NONE
COLD SIDE
WESTERN PREC. DIVISION, JOY
179.* ( 355 F)
90.0
2
*/72
VENTURI TOWER
VARIABLE-THROAT/SIDE-MOVABLE BLADES
N/A
BABCOCK I WILCOX
8.0 X 26.0 X 16.0
CARBON STEEL
AISI 1110
ORGANIC; INORGANIC
INERT FLAKE-FILLED VINYL ESTER; HYDRAULICALLY-BO
NONE
F-ll
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1A (CONT.)
LIQUID RECIRCULATIOH RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET. GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICIENCY - X
*»* FGD SYSTEM
365.4
2.4
2.2
36.6
181.7
179.4
98.0
( 5800 GPM)
(18.0 GAL/1000ACF)
( 9.0 IN-H20)
( 120.0 FT/S)
( 385000 ACFM)
( 355 F)
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
BABCOCK t WILCOX
BECHTEL
FULL SCALE
RETROFIT
X 98.00
76.00
4.2
8
7/77
2/73
2/72
2/71
*# DESIGN AND OPERATING PARAMETERS
*« QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUFERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
FREEBOARD DISTANCE - M
DISTANCE BETWEEN VANES - CM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
NR
NR
TRAY TOWER
SIEVE TRAY
N/A
BABCOCK 4 WILCOX
16.0 X 24.0 X 60.0
CARBON STEEL
HIGH STRENGTH LOW ALLOY IHSU1
COR-TEN
ORGANIC
NATURAL RUBBER
BLACK NATURAL RUBBER
PERFORATED TRAYS
2
693. (11000 GPM)
4.7 (35.0 GAL/1000 ACF )
2.5 (10.0 IN-H20)
3.0 ( 10.0 FT/S)
181.68 ( 385000 ACFM)
179.4 ( 355 F)
76.0
PRIMARY COLLECTOR
2
IMPINGEMENT
BAFFLE
CLOSED VANE
HORIZONTAL
2
05
3.8
(10.0 FT)
( 1.50 IN)
45
.2 (1.0 IN-H20)
ORGANIC
FIBER-REINFORCED POLYESTER
F-12
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
COMMONWEALTH EDISON: WILL COUNTY 1A CCONT.)
WASH WATER SOURCE
WASH FREQUENCY
WASH RATE - L/S
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*« FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
»» DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«* DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
FULL LOAD DRY FEED CAPACITY - M.TONS/HR
PRODUCT QUALITY - X SOLIDS
«* TANKS
SERVICE
SCRUBBER RECYCLE
** PUMPS
SERVICE
VENTURI RECIRCULATION
ABSORBER RECIRCULATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
CONFIGURATION
DIMENSIONS - FT
»* SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUM3ER
CAPACITY
BLENDED
UNDERSPRAY-CONTINUOUS; OVERSPRAY-INTERMITTENT
71.0 ( 1125 GAL/MIN)
2
IN-LINE
STEAM
NR
28.9 ( 52 F)
179.32 ( 380000 ACFM)
53.3 ( 128 F)
STAINLESS STEEL
AUSTENITIC
CENTRIFUGAL
BOOSTER
INDUCED DRAFT
DRY
82.2 ( 180 F)
CARBON STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
COMPARTMENTED
NR
2
10.9 ( 12 TPH)
27.5
NUMBER
2
NUMBER
THICKENER
1
CIRCULAR, SLOPED BOTTOM
65.0 OIA X 15.0
VACUUM FILTER
1
90TON/DAY
F-13
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
COMMONWEALTH EDISON: WILL COUNTY 1A (CONT. )
*»» SLUDGE
«* TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
LOCATION
SITE TREATMENT
** DISPOSAL
NATURE
TYPE
LOCATION
SITE TRANSPORTATION METHOD
*# PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
PROCESS CONTROL MANNER
** WATER BALANCE
WATER LOOP TYPE
FIXATION
PUG MILL
CHICAGO ADMIXTURES
INTERIM
POND
ON-SITE
CLAY LINING
FINAL
LANDFILL
OFF-SITE
TRUCK
PRESSURE, LIMESTONE FEED, PH
AUTOMATIC
CLOSED
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
»* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAC-E HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
• RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
»* ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
»** FGD SYSTEM
*» GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
DAIRYLAND POWER
ALMA
5
ALMA
WISCONSIN
******
******
******
******
210
80
*****
*****
80
******
******
******
********
*******
******
NR
*******
(*****« LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
COAL
******
******
********
12.0-20.0
********
3.0-3.S
********
******
********
******
(******* ACFM)
<**** F)
(**** FT)
(***** FT)
(****** BTU/LB)
10500-11000
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
THROWAWAY PRODUCT
WET SCRUBBING
LIME
FOSTER WHEELER
EXPERIMENTAL
RETROFIT
32.50
8
8/74
6/71
6/71
F-15
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
DAIRYLAND POWER: ALMA 5 (CONT.)
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NR
«* ABSORBER
GENERIC TYPE NR
SPECIFIC TYPE NR
TRADE NAME/COMMON TYPE NR
SHELL GENERIC MATERIAL NR
SHELL SPECIFIC MATERIAL NR
SHELL MATERIAL TRADE NAME/COMMON TYPE NR
LINER GENERIC MATERIAL NR
LINER SPECIFIC MATERIAL NR
LINER MATERIAL TRADE NAME/COMMON TYPE NR
*« MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR NR
GENERIC TYPE NR
SPECIFIC TYPE NR
TRADE NAME/COMMON TYPE NR
CONSTRUCTION MATERIAL GENERIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NR
** REHEATER
GENERIC TYPE NR
SPECIFIC TYPE NR
TRADE NAME/COMMON TYPE NR
CONSTRUCTION MATERIAL GENERIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NR
*« FANS
DESIGN NR
FUNCTION NR
APPLICATION NR
SERVICE NR
CONSTRUCTION MATERIAL GENERIC TYPE NR
** DAMPERS
FUNCTION NR
GENERIC TYPE NR
SPECIFIC TYPE NR
CONSTRUCTION MATERIAL GENERIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NR
LINER GENERIC MATERIAL TYPE NR
LINER SPECIFIC MATERIAL TYPE NR
»* DUCTWORK
SHELL GENERIC MATERIAL TYPE NR
SHELL SPECIFIC MATERIAL TYPE NR
LINER GENERIC MATERIAL TYPE NR
LINER SPECIFIC MATERIAL TYPE NR
** REAGENT PREPARATION EQUIPMENT
FUNCTION SLAKER
DEVICE NR
DEVICE TYPE NR
#* TANKS
SERVICE NUMBER
NR
** PUMPS
SERVICE
NR
****
NUMBER
F-16
-------
UTILITY FED SURVEY: OCTOBER 1983 - SEPTEMBER 1984
OAIRYUND POWER: ALMA 5 (CONT.)
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
*«* SLUDGE
«* TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
*« DISPOSAL
NATURE
TYPE
NA
NA
NA
NA
NR
NR
F-17
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F60 SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
DETROIT EDISON
ST. CLAIR
6A
BELLE RIVER
MICHIGAN
A
86.
1376.
******
1798
325
( .200 LB/MMBTU)
( 3.200 LB/MMBTU)
(****** LB/MMBTU)
163
163
COMBUSTION ENGINEERING
******
PEAK
465.77
132.2
130.
NR
*******
( 987000 ACFM)
( 270 F)
( 425 FT)
(****« FT)
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RAN3E HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RAN3E MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
COAL
SUBBITUMINOUS
22330. ( 9600 BTU/LB)
9500-9600
4.00
3.0-4.0
22.60
22.0-24.0
.35
0.3-0.4
********
******
0
NONE
0
NONE
WHEELABRATOR-FRYE
90.0
2
9/75
VENTURI TOWER
VARIABLE-THROAT/ADJUSTABLE DRUM
RADIAL FLOW VENTURI
PEABODY-LURGI
STAINLESS STEEL
AUSTENITIC
ORGANIC
NATURAL RUBBER
NONE
278.5 ( 4420 GPM)
2.7 (20.0 GAL/1000ACF)
3.5 (14.0 IN-H20)
F-18
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
DETROIT EDISON: ST. CLAIR 6A (CONT.)
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
«** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
»« MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
FREEBOARD DISTANCE - M
DISTANCE BETWEEN VANES - CM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
SUFERFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*« REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
28.3
116.6
132.2
( 93.0 FT/S)
( 247000 ACFM)
( 270 F)
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
BECHTEL
DEMONSTRATION
RETROFIT
X 99.70
90.00
2.8
8
12/76
9/75
6/75
0/71
NR
NR
SPRAY TOWER
OPEN COUNTERCURRENT SPRAY
N/A
PEABODY PROCESS SYSTEMS
STAINLESS STEEL
AUSTENITIC
TYPE 316L
NOME
N/A
N/A
NONE
10.7 (80.0 GAL/1000 ACF)
2.5 (10.0 IN-H20)
2.9 ( 9.5 FT/S)
101.46 ( 215000 ACFM)
47.8 ( 118 F)
90.0
PRIMARY COLLECTOR
2
CENTRIFUGAL
RADIAL VANE
RADIAL BAFFLE
HORIZONTAL
1.37 ( 4.5 FT)
20.3 ( 8.00 IN)
45
.0 ( .2 IN-H20)
3.0 ( 10.0 FT/S)
STAINLESS STEEL
AUSTENITIC
DIRECT COMBUSTION
EXTERNAL COMBUSTION CHAMBER
OIL
.0
27.8 ( 50 F)
F-19
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
DETROIT EDISON: ST. CLAIR 6A (CONT.)
INLET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
SUPPLIER
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»* DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«* REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
PRODUCT QUALITY - X SOLIDS
** PUMPS
SERVICE
VENTURI RECIRCULATION
SPRAY TOWER RECIRCULATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUM3ER
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TRANSPORTATION METHOD
SITE TREATMENT
SITE SERVICE LIFE - YRS
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
CONTROL LEVELS
MONITOR LOCATION
PROCESS CONTROL MANNER
PROCESS CHEMISTRY MODE
** WATER BALANCE
WATER LOOP TYPE
187.20
50.0
( 396700 ACFM)
( 122 F)
NR
NR
PEABOOY PROCESS SYSTEMS
BOOSTER
INDUCED DRAFT
WET
STAINLESS STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NONE
N/A
N/A
1
35.0
NUMBER
3
6
NONE
0
BLEED
N/A
N/A
FINAL
POND
PIPELINE
NONE
1
PH, SOLIDS
PH 5.8-6.0; SOLIDS 15X
RECYCLE TANK
AUTOMATIC
FEEDBACK
OPEN
F-20
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
GULF POWER
SCHOL2
1
SNEADS
FLORIDA
E
******
******
******
80
20
*****
*****
20
( ******
( ******
( ******
LB/MMBTU )
LB/MMBTU )
LB/MMBTU )
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - Y.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTUPE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
BABCOCK « WILCOX
PULVERIZED COAL
BASE
50.02 ( 106000 ACFM)
******* (**** F)
****** (**** FT)
NR
******* (***** FT)
COAL
******
30005.
********
******
********
******
3.25
3.0-3.5
********
******
( 12900 BTU/LB)
******
** ESP
NUMBER
*« PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
NR
NR
NR
NR
NR
NR
NR
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
CURRENT STATUS
TERMINATION
INITIAL START-UP
THROWAWAY PRODUCT
WET SCRUBBING
DUAL ALKALI/LIMESTONE
THYSSEN/CEA
A.D. LITTLE
DEMONSTRATION
RETROFIT
8
5/81
8/80
F-21
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
GULF POWER: SCHOLZ 1 (CONT. )
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* ABSORBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
»* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTU'CRK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** PUMPS
SERVICE
NR
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
NR
NR
TRAY TOWER
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
INDIRECT HOT AIR
NR
NR
zz.z
40 F)
NR
NR
CENTRIFUGAL
BOOSTER
INDUCED DRAFT
WET
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NUMBER
*«**
THICKENER
1
CARBON STEEL; ORGANIC ILININGI
AISI 1110; NR
F-22
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
GULF POWER: SCHOLZ 1 (CONT.)
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
SHELL SPECIFIC MATERIAL TYPE
FEED STREAM CHARACTERISTICS
«** SLUDGE
»* TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
«* DISPOSAL
NATURE
TYPE
SITE TREATMENT
** MATER BALANCE
WATER LOOP TYPE
VACUUM FILTER
1
FIBERGLASS
20X SOLIDS
DEWATERED
N/A
N/A
FINAL
POND
CLAY LINING
CLOSED
F-23
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
«* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - Y.
RAN3E ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUM3ER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
»** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
GULF POWER
SCHOLZ
1A
SNEADS
FLORIDA
A
******
516.
******
80
48
40
*****
48
BABCOCK £ WILCOX
PULVERIZED COAL
BASE
(****** LB/MMBTU)
( 1.200 LB/MMBTU)
(****** LB/MMBTU)
(******* ACFM)
( 295 F)
(**** FT)
(***** FT)
(****** BTU/LB)
******
********
146.1
******
NR
*******
COAL
******
******
********
******
********
******
5.00
******
********
******
COLD SIDE
BUELL DIVISION, ENVIROTECH
99.5
1
2/75
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
THYSSEN/CEA
CARBON STEEL
AISI 1110
INORGANIC
HYDRAULICALLY-BONDED MORTAR
NONE
THROWAWAY PRODUCT
WET SCRUBBING
DUAL ALKALI
THYSSEN/CEA
PROTOTYPE
RETROFIT
F-24
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
GULF POWER: SCHOL2 1A (CONT.)
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY - X 99.70
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*« ABSORBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
*» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
95.00
8
7/76
2/75
Z/75
NR
NR
VENTURI TOWER
NR
NR
THYSSEN/CEA
CARBON STEEL
AISI 1110
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NR
NONE
NR
NR
NR
NR
NR
NR
1
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
5.0
F-25
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
GULF POWER: SCHOLZ 1A (CONT.)
** PUMPS
SERVICE NUMBER
NR ****
#* SOLIDS CONCENTRATING/DEWATERING
DEVICE VACUUM .FILTER
NUMBER 1
CONFIGURATION ROTARY DRUM
SHELL GENERIC MATERIAL TYPE INORGANIC
SHELL SPECIFIC MATERIAL TYPE NR
*** SLUDGE
** TREATMENT
METHOD DEWATERED
DEVICE N/A
PROPRIETARY PROCESS N/A
*# DISPOSAL
NATURE FINAL
TYPE POND
LOCATION ON-SITE
SITE TREATMENT CLAY LINING
** WATER BALANCE
WATER LOOP TYPE CLOSED
F-26
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - '/.
RANGE ASH CONTENT - 7.
. AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
«** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
(****** LB/MMBTU)
( 1.200 LB/MMBTU)
(*****« LB/MMBTU)
GULF POWER
SCHOLZ
1B.2B
SNEADS
FLORIDA
A
******
516.
******
80
48
40
*****
48
BABCOCK t WILCOX
PULVERIZED COAL
BASE
******** (******* ACFM)
146.1 ( 295 F)
23. ( 76 FT)
FIBER-REINFORCED POLYESTER
******* (***** FT)
(*»**** BTU/LB)
******
COAL
******
*****-*
********
******
********
******
5.00
******
********
******
COLD SIDE
BUELL DIVISION, ENVIROTECH
99.5
1
2/75
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
CHIYODA INTERNATIONAL
CARBON STEEL
AISI 1110
INORGANIC
HYDRAULICALLY-BONDED MORTAR
NONE
THROWAWAY PRODUCT
WET SCRUBBING
THOROUGHBRED 101
CHIYODA INTERNATIONAL
PROTOTYPE
RETROFIT
F-27
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
GULF POWER: SCHOLZ 1B.2B (CONT.)
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*» ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
X 99.70
90.00
8
3/77
2/75
2/75
NR
NR
PACKED TOWER
NR
NR
CHIYODA INTERNATIONAL
STAINLESS STEEL
AUSTENITIC
TYPE 316L
NONE
N/A
N/A
PRIMARY COLLECTOR
2
IMPINGEMENT
BAFFLE
CLOSED VANE
NR
NR
NR-
NR
NR
5.0
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
MIX TANK
N/A
AGITATED TANK
F-28
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
GULF POWER: SCHOLZ 1B.2B (CONT.)
** SOLIDS CONCENTRATING/OEWATERING
DEVICE
NUMBER
CONFIGURATION
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
»* WATER BALANCE
WATER LOOP TYPE
CENTRIFUGE
1
CONTINUOUS SCREW-DECANTER/SOLID BOWL
DEMATERED
N/A
N/A
FINAL
POND
CLAY LINING
OPEN
F-29
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
PAUSE ASH CONTENT - V.
AVERAGE MOISTURE CONTENT - 7.
RAN3E MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RAN3E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
(***#** LB/MMBTU)
(****** LB/MMBTU)
(*****» LB/MMBTU)
GULF POWER
SCHOLZ
1,2
SNEADS
FLORIDA
A
******
******
******
80
23
23
*****
23
BABCOCK A WILCOX
PULVERIZED COAL
BASE
******** (**#**** ACFM)
******* (**** F)
23. ( 76 FT)
FIBER-REINFORCED POLYESTER
******* (***** FT)
( 12500 BTU/LB)
******
COAL
BITUMINOUS
29075.
11.00
******
5.00
******
2.50
2.5-5.0
********
******
COLD SIDE
BUELL DIVISION, ENVIROTECH
151.7 ( 305 F)
99.5
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRCDUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE/THOROUGHBRED 121
NONE
CHIYODA INTERNATIONAL
CHIYODA CHEMICAL ENG'R & CONSTION
PROTOTYPE
F-30
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER
GULF POWER: SCHOLZ l,Z (CONT.)
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - 7.
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
»* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
RETROFIT
X 99.50
90.00
8
6/79
8/78
NR
NR
MECHANICALLY-AIDED TOWER
GAS SPARGER
JET BUBBLER REACTOR
CHIYCDA INTERNATIONAL
34.0 DIA
STAINLESS STEEL
AUSTENITIC
NR
ORGANIC
FIBER-REINFORCED POLYESTER
NR
N/A
1
37.75 ( 80000 ACFM)
148.9 ( 300 F)
95.0
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
CLOSED VANE
VERTICAL
Z
Z
.2 ( 1.0 IN-H20)
NR
NR
NONE
N/A
N/A
NONE
N/A
CENTRIFUGAL
BOOSTER
FORCED DRAFT
DRY
25.01
148.9
CARBON STEEL
( 53000 ACFM)
( 300 F)
NR
NR
NR
NR
NR
NR
NR
F-31
-------
UTILITY FGD SURVEY: OCTOBER 1933 - SEPTEMBER 1984
GULF POWER: SCHOLZ 1,2 (COMT.)
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** PUMPS
SERVICE
NR
** SOLIDS CONCENTRATING/DEMATERING
DEVICE
*** SALEABLE BYPRODUCTS
NATURE
DISPOSITION
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
** PROCESS CONTROL AND INSTRUMENTATION
PROCESS CONTROL MANNER
** WATER BALANCE
WATER LOOP TYPE
NR
NR
NR
NR
WET BALL MILL
COMPARTMENTED
NR
NUMBER
****
NONE
GYPSUM
STACKED IN POND
FORCED OXIDATION
JET BUBBLER
N/A
FINAL
POND
CLAY LINING
MANUAL
CLOSED
F-32
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
APPEMDIX F
DESIGN ANO PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
GULF POWER
SCHOLZ
2A
SNEADS
FLORIDA
A
*K****
******
******
80
48
40
*****
48
(****** LB/MMBTU)
(«***** LB/MMBTU)
(****** LB/MMBTU)
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
RANSE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
RANSE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*«* FGD SYSTEM
«* GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
BABCOCK & WILCOX
PULVERIZED COAL
BASE
(******* ACFM)
( 295 F)
(**** FT)
(***** FT)
(****** BTU/LB)
******
********
146.1
******
NR
*******
COAL
BITUMINOUS
******
********
******
********
******
3.50
******
********
******
0
NONE
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
SALEABLE PRODUCT
SPRAY DRYING
ACTIVATED CARBON
FOSTER WHEELER/BERGBAU
DEMONSTRATION
RETROFIT
7. 99.70
F-33
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
GULF POWER: SCHOLZ 2A (CONT.)
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
*« QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
74.50
8
5/76
2/76
8/75
1/73
NR
NR
PACKED TOWER
NR
NR
FOSTER WHEELER/BERGBAU
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
0
NONE
N/A
N/A
NONE
N/A
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
N/A
N/A
N/A
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
GULF POWER: SCHOLZ 2A (CONT.)
** PUMPS
SERVICE
NR
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
»** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
»* DISPOSAL
NATURE
TYPE
SITE TREATMENT
NUMBER
****
NONE
N/A
N/A
N/A
FINAL
POND
CLAY LINING
F-35
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
SOS REMOVAL MODE
ILLINOIS POWER COMPANY
WOOD RIVER
EAST ALTON
ILLINOIS
C
*«*K**
774.
******
651
110
103
*****
110
(****** LB/MMBTU)
( 1.800 LB/MMBTU)
(****** LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
******** (******* ACFM)
154.4 ( 310 F)
76. ( 250 FT)
NR
******* (***** FT)
COAL
******
25121.
10.00
******
4.30
******
3.10
******
********
******
( 10800 BTU/LB)
******
0
NONE
RESEARCH-COTTRELL
99.6
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
SALEABLE PRODUCT
WET SCRUBBING
F-36
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
NR
NR
PACKED TOWER
NR
NR
30.0 DIA X 65.0
CARBON STEEL
AISI 1110
N/A
NR
NR
NR
8
30,
1.
454
12.0IN)
4.0 IN-H20)
850 F)
ILLINOIS POWER COMPANY: WOOD RIVER 4 (CONT.)
PROCESS TYPE CATALYTIC OXIDATION
SYSTEM SUPPLIER MONSANTO ENVIRO CHEM SYSTEMS
DEVELOPMENT LEVEL DEMONSTRATION
NEW/RETROFIT RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -7, 99.90
UNIT DESIGN S02 REMOVAL EFFICIENCY - '/. 85.00
CURRENT STATUS 8
TERMINATION 0/74
COMMERCIAL START-UP 10/72
INITIAL START-UP 9/72
CONTRACT AWARDED 6/70
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATCR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
DISTANCE BETWEEN GAS CONTACTING ZONES - CM
GAS-SIDE PRESSURE DROP - KPA
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - '/.
»* ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH FREQUENCY
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL-GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
85.0
PACKED TOWER
NR
NR
CARBON STEEL
AISI 1110
N/A
INORGANIC
PREFIRED BRICK/SHAPES
ACID-RESISTANT BRICK [LOW H20 ABSORPTION]
121.1 ( 250 F)
PRIMARY COLLECTOR
1
IMPINGEMENT
MESH
KNITTED WIRE MESH
4.5
HIGH ALLOY
NR
INTERMITTENT
PAD
(18.0 IN-H20)
IN-LINE
NR
NR
14.5
247.8
176.7
NR
NR
446 F)
350 F)
F-37
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
ILLINOIS POWER COMPANY: WOOD RIVER 4 (CONT.)
«* FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** TANKS
SERVICE
SALEABLE BYPRODUCT
#* PUMPS
SERVICE
ACID RECIRCULATION
PRODUCT ACID
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
«* DISPOSAL
NATURE
TYPE
SITE TREATMENT
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
CENTRIFUGAL
NR
INDUCED DRAFT
NR
STAINLESS STEEL
NR
NR
NR
NR
NR
NR
NR
STAINLESS STEEL
NR
NONE
N/A
N/A
N/A
N/A
NUMBER
2
NUMBER
**#*
***»
NR
0
N/A
N/A
N/A
N/A
NOME
NR
TEMPERATURE, ASH LOADINGS, ACID CONCENTRATION
F-38
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
*» FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
• RAN3E MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*»* PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
»* PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
KANSAS CITY POWER t LIGHT
HAWTHORN
KANSAS CITY
MISSOURI
E
64.
«***«*
******
836
90
85
fl7
90
( .150 LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
CYCLING
335.95
148.9
61.
CARBON STEEL
5.5
( 500000 ACFM)
( 300 F)
( 200 FT)
( 18.0 FT)
COAL 1 (25X1
BITUMINOUS; BITUMINOUS
26388.
( 11345 BTU/LB)
9500-10800; 10500-13000
11.75
6-15; 9-12
7.28
9-17; 1.5-12
2.78
0.2-1.2! 0.6-4.6
.15
0.01-0.06; 0.01-0.40
0
NONE
0
NONE
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
THROWAWAY PRODUCT
WET SCRUBBING
LIME
NONE
COMBUSTION ENGINEERING
BLACK & VEATCH
F-39
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
KANSAS CITY POWER « LIGHT: HAWTHORN 3 (CONT.)
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
DESIGN COAL SULFER CONTENT - X
DESIGN COAL HEAT CONTENT - J/G
DESIGN COAL ASH CONTENT - X
DESIGN MOISTURE CONTENT - X
DESIGN CHLORIDE CONTENT - X
SPACE REQUIREMENTS - SQ M
OPER. i MAINT. REQUIREMENT - MANHR/DAY
** QUENCHER/PRESATURATOR
NUMBER
** ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOU - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
NUMBER OF SPARES PER SYSTEM
NUMBER PER MODULE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
MANUFACTURER
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
FREEBOARD DISTANCE - M
DISTANCE BETWEEN STAGES - CM
DISTANCE BETWEEN VANES - CM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
SUPERFICAL G4S VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
WASH FREQUENCY
WASH RATE - L/S
FULL SCALE
RETROFIT
X 99.00
70.00
2.2
8
10/82
11/72
11/72
0/71
2.80
26400.1
11.80
7.30
.15
688.4
136.0
( 11350 BTU/LB)
7410 SO FT)
2
0
PACKED TOWER
STATIC BED PACKING
MARBLE-BED SCRUBBER
COMBUSTION ENGINEERING
18.0 X 26.0 X 56.0
CARBON STEEL
AISI 1110
N/A
STAINLESS STEEL
AUSTENITIC
TYPE 316L
GLASS MARBLES
1
321.
2.7
2.7
1.8
117.97
148.9
50.0
99.5
( 5090 GPM)
( 20.4 GAL/1000 ACF)
(11.0 IN-H20)
( 6.0 FT/S)
( 250000 ACFM)
( 300 F)
PRIMARY COLLECTOR
2
0
1
IMPINGEMENT
BAFFLE
CLOSED VANE
COMBUSTION ENGINEERING
HORIZONTAL
2
2
3.05 (10.0 FT)
15.24 ( 6.0 IN)
7.6 ( 3.00 IN)
45
.3 ( 1.2 IN-H20)
1.8 ( 6.0 FT/S)
ORGANIC
FIBER-REINFORCED POLYESTER
FRESH
EVERY 48 HOURS
63.1 ( 1000 GAL/MIN)
F-40
-------
KANSAS CITY POWER & LIGHT: HAWTHORN 3 (CONT.)
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
** REHEATER
NUMBER
NUMBER OF SPARES
NUMBER PER MODULE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
LOCATION
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
OUTLET FLUE GAS TEMPERATURE - C
NUMBER OF HEAT EXCHANGER BANKS
NUMBER OF BUNDLES PER BANK
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
NUMBER OF SPARES
DESIGN
SUPPLIER
FUNCTION
APPLICATION
SERVICE
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
»* DAMPERS
NUMBER
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
MANUFACTURER
MODULATION
SEAL AIR FLOW - CU. M/S
SERVICE CONDITIONS
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DAMPERS
NUMBER
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
MANUFACTURER
MODULATION
SEAL AIR FLOW - CU. M/S
SERVICE CONDITIONS
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DAMPERS
NUMBER
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
MANUFACTURER
MODULATION
SEAL AIR FLOW - CU. M/S
SERVICE CONDITIONS
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
4
0
1
IN-LINE
HOT WATER
BARE TUBE
TOP OF ABSORBER VESSEL
.0
33.3 ( 60 F)
48.9 ( 120 F)
82.Z ( 180 F)
6
1
STAINLESS STEEL
AUSTENITIC
Z
0
CENTRIFUGAL
HOUDEN, CANADA
BOOSTER
INDUCED DRAFT
DRY
79.4 ( 175 F)
CARBON STEEL
SHUT-OFF
LOUVER
PARALLEL BLADE MULTILOUVER
COMBUSTION ENGINEERING .
OPEN/CLOSED
.00 ( 0 ACFM)
330
CARBON STEEL
HIGH STRENGTH LOW ALLOY CHSLA1
NONE
N/A
SHUT-OFF
LOUVER
PARALLEL BLADE MULTILOUVER
COMBUSTION ENGINEERING
OPEN/CLOSED
.00 ( 0 ACFM)
330
CARBON STEEL
HIGH STRENGTH LOW ALLOY (HSLA1
NONE
N/A
SHUT-OFF
GUILLOTINE
TOP-ENTRY GUILLOTINE
SELF-DESIGNED t INSTALLED BY KCP *
OPEN/CLOSED
.00 ( 0 ACFM)
330
CARBON STEEL
HIGH STRENGTH LOW ALLOY WSLA1
NONE
N/A
F-41
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
KANSAS CITY POWER & LIGHT: HAWTHORN 3 CCONT.)
»* DUCTWORK
LOCATION
CONFIGURATION
DIMENSIONS
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
LOCATION
CONFIGURATION
DIMENSIONS
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
LOCATION
CONFIGURATION
DIMENSIONS
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
MANUFACTURER
NUMBER
NUMBER OF SPARES
FULL LOAD DRY FEED CAPACITY - M.TOHS/HR
PRODUCT QUALITY - X SOLIDS
** TANKS
SERVICE
ABSCPBER RECYCLE
LIME SLURRY
CLEARWELL
«* PUMPS
SERVICE
RECYCLE
CLEAR WATER SUPPLY
SLUDGE
BLOUOOWN
REHEATER FEED
MIST ELIMINATOR WASH
LIME SLURRY
SCRUBSER MAKEUP
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUrEER
NUMBER OF SPARES
DIMENSIONS - FT
CAPACITY
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
FEED STREAM SOURCE
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
OVERFLOW STREAM CHARACTERISTICS
SCRUBBER INLET
RECTANGULAR
ft.5 FT X 26 FT
CARBON STEEL
HIGH STRENGTH LOW ALLOY tHSLAJ
INORGANIC
HYDRAULICALLY-BONDED MORTAR
SCRUBBER OUTLET
RECTANGULAR
3 FT X 26 FT
CARBON STEEL
HIGH STRENGTH LOW ALLOY tHSLA]
INORGANIC
HYDRAULICALLY-BONDED MORTAR
BYPASS
RECTANGULAR
3 FT X 26 FT
CARBON STEEL
HIGH STRENGTH LOW ALLOY [HSLAJ
NONE
N/A
SLAKER
NR
NR
COFFMAN INDUSTRIES
1
0
51.7 (57 TPH)
25.0
NUMBER
2
1
1
NUMBER
2
2
2
2
4
4
1
2
THICKENER
1
0
115.0 DIA X 10.0
75000
CARBON STEEL [WALLS); INORGANIC [BOTTOM]
AISI 1110; HYDRAULICALLY-BONDED CONCRETE
ORGANIC
NR
ABSORBER BLEED
12X SOLIDS
30X SOLIDS
13900 GFM
F-42
-------
KANSAS CITY POWER * LIGHT: HAUTHORN 3 (CONT.)
OUTLET STREAM DISPOSITION
OVERFLOW STREAM DISPOSITION
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
LOCATION
SITE TRANSPORTATION METHOD
SITE TREATMENT
SITE DIMENSIONS
SITE CAPACITY - CU.M
SITE SERVICE LIFE - YRS
** PROCESS CONTROL AND INSTRUMENTATION
PROCESS STREAM
CHEMICAL PARAMETERS
PHYSICAL VARIABLES
CONTROL LEVELS
MONITOR LOCATION
PROCESS CONTROL MANNER
PROCESS CHEMISTRY MODE
*» MATER BALANCE
WATER LOOP TYPE
RECEIVING WATER STREAM
SOURCE OF MAKEUP WATER
** CHEMICALS AND CONSUMPTION
FUNCTION
NAME
PRINCIPAL CONSTITUENT
SOURCE/SUPPLIER
POINT OF ADDITION
** FGD SPARE CAPACITY INDICES
ASS03BER - '/.
MIST ELIMINATOR - X
REHEATER - X
FAN - X
SLAKER - X
EFFLUENT HOLD TANK - X
RECIRCULATION PUMP - X
THICKENER - X
** FGO SPARE COMPONENT INDICES
ABSORBER
MIST ELIMINATOR
REHEATER
FAN
SLAKER
EFFLUENT HOLD TANK
RECIRCULATION PUMP
THICKENER
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
TO ASH POND
TO RECYCLE CANAL, ASH SLUICE PUMP
BLEED
N/A
N/A
FINAL
POUD
ON-SITE
PIPELINE
NONE
40 ACRES/15 FT
733800
3
( 600.0 ACRE-FT)
RECIRCUUTING SLURRY
PH
X SOLIDS
PH 5.5-6.0, 10X SOLIDS
GRAB SAMPLES TO LABORATORY
MANUAL
FEEDBACK
OPEN
MISSOURI RIVER
MISSOURI RIVER
ABSORBENT
LIME
93X CAO
ASHGROVE
LIME SLAKER
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY MO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
RANGE ASH CONTENT - '/.
AVERAGE MOISTURE CONTENT - '/.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - '/.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - '/.
*** PARTICLE CONTROL
*» MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
KANSAS CITY POMER 4 LIGHT
HAWTHORN
4
KANSAS CITY
MISSOURI
E
64. ( .150 LB/MMBTU)
****** (****** LB/MMBTU)
****** (****** LB/MMBTU)
836
90
85
87
90
COMBUSTION ENGINEERING
PULVERIZED COAL
CYCLING
235.95
148.9
61.
CARBON STEEL
5.5
( 500000 ACFM)
( 300 F)
( 200 FT)
( 18.0 FT)
COAL 1 125X1
BITUMINOUS; BITUMINOUS
26388. ( 11345 BTU/LB)
9500-108005 10500-13000
11.75
6-15; 9-12
7.28
9-17; 1.5-12
2.78
0.2-1.2! 0.6-4.6
.15
0.01-0.06; 0.01-0.40
0
NONE
0
NONE
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
THROWAWAY PRODUCT
WET SCRUBBING
LIME
NONE
COMBUSTION ENGINEERING
BLACK & VEATCH
F-44
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
KANSAS CITY POWER & LIGHT: HAWTHORN 4 (CONT. )
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY •
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
DESIGN COAL SULFER CONTENT - X
DESIGN COAL HEAT CONTENT - J/G
DESIGN COAL ASH CONTENT - X
DESIGN MOISTURE CONTENT - X
DESIGN CHLORIDE CONTENT - X
SPACE REQUIREMENTS - SQ M
OPER. 4 MAINT. REQUIREMENT - MANHR/DAY
«* QUENCHER/PRESATURATOR
NUMBER
** ABSORBER
NUMBER
NUMBEP OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
NUMBER OF SPARES PER SYSTEM
NUMBER PER MODULE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
MANUFACTURER
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
FREEBOARD DISTANCE - M
DISTANCE BETWEEN STAGES - CM
DISTANCE BETWEEN VANES - CM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
WASH FREQUENCY
WASH RATE - L/S
FULL SCALE
RETROFIT
X 99.00
70.00
2.2
8
10/82
11/72
8/72
0/71
2.80
26400.1
11.80
7.30
.15
688.4
136.0
( 11350 BTU/LB)
( 7410 SQ FT)
Z
0
PACKED TOWER
STATIC BED PACKING
MARBLE-BED SCRUBBER
COMBUSTION ENGINEERING
18.0 X 26.0 X 56.0
CARBON STEEL
AISI 1110
N/A
STAINLESS STEEL
AUSTENITIC
TYPE 316L
GLASS MARBLES
1
321.
2.7
2.7
1.8
117.97
148.9
50.0
99.5
( 5090 GPM)
( 20.4 GAL/1000 ACF)
(11.0 IN-H20)
( 6.0 FT/S)
( 250000 ACFM)
( 300 F)
PRIMARY COLLECTOR
2
0
1
IMPINGEMENT
BAFFLE
CLOSED VANE
COMBUSTION ENGINEERING
HORIZONTAL
2
2
3.05 (10.0 FT)
15.24 ( 6.0 IN)
7.6 ( 3.00 IN)
45
.3 (1.2 IN-H20)
1.8 (6.0 FT/S)
ORGANIC
FIBER-REINFORCED POLYESTER
FRESH
EVERY 48 HOURS
63.1 ( 1000 GAL/MIN)
F-45
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
KANSAS CITY POWER & LIGHT: HAWTHORN 4 (CONT. )
** REHEATER
NUMBER
NUMBER OF SPARES
NUMBER PER MODULE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
LOCATION
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
OUTLET FLUE GAS TEMPERATURE - C
NUMBER OF HEAT EXCHANGER BANKS
NUMBER OF BUNDLES PER BANK
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
NUMBER OF SPARES
DESIGN
SUPPLIER
FUNCTION
APPLICATION
SERVICE
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
NUMBER
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
MANUFACTURER
MODULATICN
SEAL AIR FLOW - CU. M/S
SERVICE CONDITIONS
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»* DAMPERS
NUMBER
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
MANUFACTURER
MODULATION
SEAL AIR FLOW - CU. M/S
SERVICE CONDITIONS
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DAMPERS
NUMBER
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
MANUFACTURER
MODULATION
SEAL AIR FLOW - CU. M/S
SERVICE CONDITIONS
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
4
0
1
IN-LINE
HOT WATER
BARE TUBE
TOP OF ABSORBER VESSEL
.0
33.3 ( 60 F)
48.9 ( 120 F)
82.2 ( 180 F)
6
1
STAINLESS STEEL
AUSTENITIC
2
0
CENTRIFUGAL
HOUDEN, CANADA
BOOSTER
INDUCED DRAFT
DRY
79.4 ( 175 F)
CARBON STEEL
SHUT-OFF
LOUVER
PARALLEL BLADE MULTILOUVER
COMBUSTION ENGINEERING
OPEN/CLOSED
.00 ( 0 ACFM)
330
CARBON STEEL
HIGH STRENGTH LOW ALLOY [HSLAJ
NONE
N/A
SHUT-OFF
LOUVER
PARALLEL BLADE MULTILOUVER
COMBUSTION ENGINEERING
OPEN/CLOSED
.00 ( 0 ACFM)
330
CARBON STEEL
HIGH STRENGTH LOW ALLOY IHSLAI
NONE
N/A
SHUT-OFF
GUILLOTINE
TOP-ENTRY GUILLOTINE
SELF-DESIGNED & INSTALLED BY KCP S
OPEN/CLOSED
.00 ( 0 ACFM)
330
CARBON STEEL
HIGH STRENGTH LOW ALLOY IHSLAJ
NONE
N/A
F-46
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
KANSAS CITY POWER t LIGHT: HAWTHORN 4 (CONT.)
** DUCTWORK
LOCATION
CONFIGURATION
DIMENSIONS
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
LOCATION
CONFIGURATION
DIMENSIONS
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»* DUCTWORK
LOCATION
CONFIGURATION
DIMENSIONS
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
MANUFACTURER
NUMBER
NUMBER OF SPARES
FULL LOAD DRY FEED CAPACITY - M.TONS/HR
PRODUCT QUALITY - X SOLIDS
** TANKS
SERVICE
ABSORBER RECYCLE
LIME SLURRY
CLEARWELL
** PUMPS
SERVICE
RECYCLE
CLEAR WATER SUPPLY
SLUDGE
SLOWDOWN
REHEATER FEED
MIST ELIMINATOR WASH
LIME SLURRY
SCRUBBER MAKEUP
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
DIMENSIONS - FT
CAPACITY
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
FEED STREAM SOURCE
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
OVERFLOW STREAM CHARACTERISTICS
SCRUBBER INLET
RECTANGULAR
4.5 FT X 26 FT
CARBON STEEL
HIGH STRENGTH LOW ALLOY IHSLA1
INORGANIC
HYDRAULICALLY-BONDED MORTAR
SCRUBBER OUTLET
RECTANGULAR
3 FT X 26 FT
CARBON STEEL
HIGH STRENGTH LOW ALLOY IHSLAJ
INORGANIC
HYDRAULICALLY-BONDED MORTAR
BYPASS
RECTANGULAR
3 FT X 26 FT
CARBON STEEL
HIGH STRENGTH
NONE
N/A
LOW ALLOY IHSLAI
SLAKER
NR
NR
COFFMAN INDUSTRIES
1
0
51.7 ( 57 TPH)
25.0
NUMBER
2
1
1
NUMBER
2
2
2
2
THICKENER
1
0
115.0 DIA X 10.0
75000
CARBON STEEL [WALLS!; INORGANIC tBOTTOM]
AISI 1110} HYDRAULICALLY-BONDED CONCRETE
ORGANIC
NR
ABSORBER BLEED
12X SOLIDS
30X SOLIDS
13900 GPM
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
KANSAS CITY POWER & LIGHT: HAWTHORN 4 (CONT.)
OUTLET STREAM DISPOSITION
OVERFLOW STREAM DISPOSITION
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
LOCATION
SITE TRANSPORTATION METHOD
SITE TREATMENT
SITE DIMENSIONS
SITE CAPACITY - CU.M
SITE SERVICE LIFE - YRS
*» PROCESS CONTROL AND INSTRUMENTATION
PROCESS STREAM
CHEMICAL PARAMETERS
PHYSICAL VARIABLES
CONTROL LEVELS
MONITOR LOCATION
PROCESS CONTROL MANNER
PROCESS CHEMISTRY MODE
** WATER BALANCE
WATER LOOP TYPE
RECEIVING WATER STREAM
SOURCE OF MAKEUP WATER
** CHEMICALS AND CONSUMPTION
FUNCTION
NAME
PRINCIPAL CONSTITUENT
SOURCE/SUPPLIER
POINT OF ADDITION
** FGD SPARE CAPACITY INDICES
ABSORBER - X
MIST ELIMINATOR - X
REHEATER - X
FAN - X
SLAKER - X
EFFLUENT HOLD TANK - X
RECIRCULATION PUMP - X
THICKENER - X
«« FGD SPARE COMPONENT INDICES
ABSORBER
MIST ELIMINATOR
REHEATER
FAN
SLAKER
EFFLUENT HOLD TANK
RECIRCULATION PUMP
THICKENER
TO ASH POND
TO RECYCLE CANAL, ASH SLUICE PUMP
BLEED
N/A
N/A
FINAL
POND
ON-SITE
PIPELINE
NONE
40 ACRES/15 FT
733800
3
600.0 ACRE-FT)
RECIRCULATING SLURRY
PH
X SOLIDS
PH 5.5-6.0, 10X SOLIDS
GRAB SAMPLES TO LABORATORY
MANUAL
FEEDBACK
OPEN
MISSOURI RIVER
MISSOURI RIVER
ABSORBENT
LIME
93X CAO
ASHGROVE
LIME SLAKER
F-48
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY MO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - '/.
RANGE ASH CONTENT - Y.
AVERAGE MOISTUPE CONTENT - 7.
RAN3E MOISTURE CONTENT - Y.
AVERAGE SULFUR CONTENT - Y.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - Y.
RANGE CHLORIDE CONTENT - Y.
KEY MEST UTILITY BOARD
STOCK ISLAND
1
KEY MEST
FLORIDA
E
******
473.
******
42
42
37
*****
37
ERIE CITY
OIL FIRED
BASE
********
*******
34.
NR
*******
OIL
NO. 6
******
.04
******
********
******
2.01
2.0-3.0
********
******
(****** LB/MMBTU)
( 1.100 LB/MMBTU)
(****** LB/MMBTU)
(******* ACFM)
(**** F)
( 110 FT)
(***** FT)
(****** BTU/LB)
******
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
PRESSURE DROP - KPA
** FABRIC FILTER
NUM3ER
TYPE
** ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
NUM3ER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROMAWAY PRODUCT
S02 REMOVAL MODE
.6
( 3. IN-H20)
0
NONE
0
NONE
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
THROHAMAY PRODUCT
MET SCRUBBING
F-49
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
KEY WEST UTILITY BOARD: STOCK ISLAND 1 (CONT.)
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY - X
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
TERMINATION
INITIAL START-UP
CONTRACT AWARDED
«* DESIGN AND OPERATING PARAMETERS
»* QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
LIQUID RECIRCULATION RATE - LITER/S
GAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
*» DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
*# DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LIMESTONE
ZURN AIR SYSTEM
DEMONSTRATION
NEW
90.00
85.00
8
1/75
10/72
0/70
NR
NR
VENTURI TOWER
NR
NR
ZURN AIR SYSTEMS
STAINLESS STEEL
AUSTENITIC
TYPE 304L
NONE
N/A
N/A
SCRUBBING TUBE
25. (
1.5 (
58.04 (
62.8 (
400 GPM)
6.0 IN-H20)
123000 ACFM)
145 F)
PRIMARY COLLECTOR
IMPINGEMENT
CURVED DEFLECTOR PLATE
GULL WING
ORGANIC
FIBER-REINFORCED POLYESTER
0
NONE
N/A
N/A
NONE
N/A
1
NR
NR
INDUCED DRAFT
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
F-50
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
KEY WEST UTILITY BOARD: STOCK ISLAND 1 (CONT.)
LINER GENERIC MATERIAL TYPE NR
LINER SPECIFIC MATERIAL TYPE NR
»* REAGENT PREPARATION EQUIPMENT
FUNCTION WET BALL MILL
DEVICE NR
DEVICE TYPE NR
** PUMPS
SERVICE NUMBER
NR «***
*» SOLIDS CONCENTRATING/DEWATERING
DEVICE NA
*** SLUDGE
»* TREATMENT
METHOD BLEED
DEVICE N/A
PROPRIETARY PROCESS N/A
** DISPOSAL
NATURE FINAL
TYPE POND
SITE TREATMENT NONE
»* PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS TEMPERATURE, PARTICLE LOADING, PH
»* WATER BALANCE
WATER LOOP TYPE OPEN
F-51
-------
UTILITY FSD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PUNT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
»* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - V.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
SUPPLIER
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
INLET GAS TEMPERATURE - C
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
( .100 LB/MMBTU)
( 1.200 LB/MMBTU)
(****** LB/MMBTU)
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
GARY
INDIANA
E
43.
516.
******
505
116
9*
108
115
BABCOCK & WILCOX
PULVERIZED COAL
BASE
198.20
142.2
51.
FRP
( 420000 ACFM)
( 288 F)
( 168 FT)
(***** FT)
( 11000 BTU/LB)
******
*******
COAL
******
25586.
********
******
11.00
******
3.50
3.2-3.5
********
******
COLD SIDE
AMERICAN STANDARD
1
7/76
VENTURI TOWER
VARIABLE-THROAT/BOTTOM-ENTRY PLUMB BOB
N/A
CARBON STEEL
AISI 1110
NR
NR
NONE
1
142.2 ( 288 F)
SALEABLE PRODUCT
WET SCRUBBING
WELLMAN LORD
DAVY MCKEE
DAVY MCKEE
DEMONSTRATION
F-52
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
NORTHERN INDIANA PUB SERVICE: DEAN H. MITCHELL 11 (CONT.)
NEW/RETROFIT RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY - X 98.50
UNIT DESIGN S02 REMOVAL EFFICIENCY - X 90.00
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
IZ.
8
3/82
6/77
7/76
6/72
»* DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
GAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOW - CU. M/S
S02 REMOVAL EFFICIENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
** FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
NR
NR
TRAY TOWER
VALVE TRAY
BUBBLE CAP TRAY TOWER
DAVY MCKEE
CARBON STEEL
AISI 1110
N/A
INORGANIC
PREFIRED BRICK/SHAPES
ACID-RESISTANT BRICK [LOW H20 ABSORPTION]
VALVE TRAYS
3.0
198.20
91.0
(12.0 IN-H20)
( 420000 ACFM)
NR
NR
NR
NR
NR
NR
DIRECT COMBUSTION
NR
NATURAL GAS
27.8
54.4
NR
NR
CENTRIFUGAL
BOOSTER
FORCED DRAFT
DRY
198.20
142.2
CARBON STEEL
( 50 F)
( 130 F)
( 420000 ACFM)
( 288 F)
CENTRIFUGAL
UNIT
FORCED DRAFT
DRY
CARBON STEEL; HIGH ALLOY
F-53
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
NORTHERN INDIANA PUB SERVICE: DEAN H. MITCHELL 11 (CONT.)
** DAMPERS
FUNCTION NR
GENERIC TYPE NR
SPECIFIC TYPE NR
CONSTRUCTION MATERIAL GENERIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NR
LINER GENERIC MATERIAL TYPE NR
LINER SPECIFIC MATERIAL TYPE NR
** DUCTWOPK
LOCATION SCRUBBER INLET
SHELL GENERIC MATERIAL TYPE CARBON STEEL
SHELL SPECIFIC MATERIAL TYPE AISI 1110
LINER GENERIC MATERIAL TYPE NONE
LINER SPECIFIC MATERIAL TYPE N/A
** REAGENT PREPARATION EQUIPMENT
FUNCTION MIX TANK
DEVICE N/A
DEVICE TYPE AGITATED TANK
MANUFACTURER AGITATED TANK
** TANKS
SERVICE NUMBER
REAGENT PREP PRODUCT ****
ABSORBER RECYCLE ****
»* PUMPS
SERVICE NUMBER
DISSOLVING TANK TO ABSORBER FEED TAN ***»
FLYASH PURGE TO POND TRANSFER «***
ABSORBER RECIRCULATION 3
EVAPORATCR-CRYSTALLIZER FEED ****
SLURRY FEED ****
** SOLIDS CONCENTRATING/DEWATERING
DEVICE CENTRIFUGE
NUMBER 1
»** SALEABLE BYPRODUCTS
NATURE ELEMENTAL SULFUR
QUALITY - 7. 99.9
*** SLUDGE
** TREATMENT
METHOD N/A
DEVICE N/A
PROPRIETARY PROCESS N/A
** DISPOSAL
NATURE N/A
TYPE NONE
** WATER BALANCE
WATER LOOP TYPE CLOSED
** FGD SPARE CAPACITY INDICES
ABSORBER - '/. .0
** FGD SPARE COMPONENT INDICES
ABSORBER .0
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
*» UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
*» FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANSE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEU/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
TERMINATION
INITIAL START-UP
CONTRACT AUARDED
<****** LB/MMBTU)
( .300 LB/MMBTU)
(«***** LB/MMBTU)
PACIFIC POWER * LIGHT
JIM BRIDGER
2A
ROCK SPRINGS
WYOMING
B
******
129.
******
*****
550
*****
509
100
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
1283.57 (2720000 ACFM)
******* (**** p)
152. ( 500 FT)
******
******* (***** FT)
COAL
SU3BITUMINOUS
22330.
11.00
5.0-16.0
17.00
12.0-2*.0
.56
0.2-0.9
********
******
( 9600 BTU/LB)
******
0
NONE
N/A
N/A
THROWAWAY PRODUCT
SPRAY DRYING
LIME/SODIUM CARBONATE
FLAKT
FLAKT t PACIFIC POWER t LIGHT
DEMONSTRATION
RETROFIT
7. 99.30
86.00
8
1/83
1/82
12/80
F-55
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
PACIFIC POWER & LIGHT: JIM BRIDGER 2A (CONT.)
** DESIGN AND OPERATING PARAMETERS
*» QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
INLET GAS TEMPERATURE - C
SOZ REMOVAL EFFICIENCY - X
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
#* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
*» DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
*** SLUDGE
»* TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
»* DISPOSAL
NATURE
TYPE
NA
NA
SPRAY DRYER
NA
HYDRAULIC PRESSURE NOZZLE
36 FT DIAMETER
NA
NA
NA
NA
NA
NA
121
86
( 250 F)
99.3
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NONE
NA
NA
NA
FINAL
LANDFILL
F-56
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PACIFIC POWER £ LIGHT: JIM BRIDGER 2A (CONT.)
** MATER BALANCE
WATER LOOP TYPE CLOSED
F-57
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - V.
AVERAGE MOISTURE CONTENT - V.
RANGE MOISTURE CONTENT - V.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
PHILADELPHIA ELECTRIC
EDDYSTONE
1A
EDDYSTONE
PENNSYLVANIA
C
****** (****** LB/MMBTU)
****** (****** LB/MMBTU)
****** (****** LB/MMBTU)
1395
120
120
*****
120
COMBUSTION ENGINEERING
******
BASE
437.45 ( 927000 ACFM)
157.2 ( 315 F)
76. ( 249 FT)
CONCRETE
5.6 ( 18.5 FT)
COAL
BITUMINOUS
31634.
9.40
******
5.90
******
2.60
******
********
******
( 13600 BTU/LB)
******
2
9/75
VENTURI TOWER
VARIABLE-THROAT/VERTICALLY-ADJUSTABLE ROD DECKS
ROD SCRUBBER
ENVIRONEERING
14.0 X 25.0 X 53.0
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
1
.6 (
.0 (
145.8 (
157.2 (
4.8 GAL/1000ACF)
.1 IN-H20)
309000 ACFM)
315 F)
1
9/75
F-58
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
PHILADELPHIA ELECTRIC: EDDYSTONE 1A CCONT.)
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
»** FGD SYSTEM
«* GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
302 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEH/RETPOFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN 502 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CO.MTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
»* GUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
FREEBOARD DISTANCE - M
VENTURI TOWER
VARIABLE-THROAT/ADJUSTABLE DRUM
RADIAL FLOW VENTURI
PEABODY-LURGI
14.0 X 25.0 X 53.0
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
.6
.0
145.8
157.2
( 4.8 GAL/1000ACF)
( .1 IN-H20)
( 309000 ACFM)
( 315 F)
SALEABLE PRODUCT
WET SCRUBBING
MAGNESIUM OXIDE
NONE
UNITED ENGINEERS
UNITED ENGINEERS t CONSTRUCTORS
DEMONSTRATION
RETROFIT
X 99.00
90.00
8
12/79
9/75
9/75
0/73
NR
NR
PACKED TOWER
GRID PACKING
N/A
ENVIRONEERING, RILEY STOKER
14.0 X 25.0 53.0
CARBON STEEL
HIGH STRENGTH LOW ALLOY tHSLAl
COR-TEN
ORGANIC
EPOXY
FLAKELINE E
ROD DECKS
2
843. (13384 GPM)
6.5 ( 48.5 GAL/1000 ACF)
2.5 (10.0 IN-H20)
126.47 ( 266000 ACFM)
51.7 ( 125 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
VERTICAL
2
2
2.44 t 8.0 FT)
F-59
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (CONT.)
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
WASH FREQUENCY
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
#* FANS
NUMBER
DESIGN
SUPPLIER
FUNCTION
APPLICATION
SERVICE
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
*# DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
LOCATION
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
LOCATION
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** PUMPS
SERVICE
ABSORBER RECIRCULATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
DIMENSIONS - FT
OUTLET STREAM CHARACTERISTICS
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUM3ER
ORGANIC
FIBER-REINFORCED POLYESTER
FRESH
INTERMITTENT
DIRECT COMBUSTION
IN-LINE BURNER
OIL
57.Z ( 103 F)
51.7 ( 125 F)
NR
NR
CENTRIFUGAL
BUFFALO FORGE
UNIT
INDUCED DRAFT
DRY
126.47 ( 268000 ACFM)
107.2 ( 225 F)
NR
NR
NR
NR
NR
NR
NR
NR
SCRUBBER INLET
STAINLESS STEEL
AUSTENITIC
NONE
N/A
SCRUBBER OUTLET
STAINLESS STEEL
AUSTENITIC
NONE
N/A
SLAKER
NR
NR
NUMBER
2
THICKENER
1
40.0 DIA
25X SOLIDS
CENTRIFUGE
1
F-60
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (CONT. )
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
»* DISPOSAL
NATURE
TYPE
SITE TREATMENT
** WATER BALANCE
MATER LOOP TYPE
MAKEUP WATER ADDITION - LITERS/S
»* FGD SPARE CAPACITY INDICES
ABSORBER - X
#* FGD SPARE COMPONENT INDICES
ABSORBER
DEWATERED
N/A
N/A
N/A
NONE
N/A
OPEN
8.3
.0
.0
( 132 GPM)
F-61
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
»« FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
(****** LB/MMBTU)
( 1.600 LB/MMBTU)
(****** LB/MMBTU)
POTOMAC ELECTRIC POWER
DICKERSON
3A
DICKERSON
MARYLAND
E
******
688.
******
548
190
178
182
95
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
278.42 ( 590000 ACFM)
126.1 ( 259 F)
122. ( 400 FT)
CONCRETE
******* (***** FT )
( 11700 BTU/LB)
******
COAL
BITUMINOUS
27214.
14.00
******
********
6.0-7.0
2.00
******
********
******
0
NONE
0
NONE
RESEARCH-COTTRELL
97.5
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
CARBON STEEL
AISI 1110
ORGANIC
FIBER-REINFORCED POLYESTER
NONE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
SALEABLE PRODUCT
WET SCRUBBING
F-6£
-------
UTILITY F60 SURVEY: OCTOBER 1983 - SEPTEMBER 1984
POTOMAC ELECTRIC POWER: DICKERSON 3A (CONT.)
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
L/G RATIO - L/CU.M
" GAS-SIDE PRESSURE DROP - KPA
S02 REMOVAL EFFICIENCY - X
»» MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
DISTANCE BETWEEN VANES - CM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*« REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
MAGNESIUM OXIDE
NONE
GE ENVIRONMENTAL SERVICES
GE ENVIRONMENTAL SERVICES
DEMONSTRATION
RETROFIT
X 99.30
90.00
2.1
8
8/75
7/74
9/73
7/71
NR
NR
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
GE ENVIRONMENTAL SERVICES
CARBON STEEL
AISI 1110
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NR
NONE
5.3
2.2
90.0
( 40.0 GAL/1000 ACF)
( 9.0 IN-H20)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
3
2
5.1
45
.2
3.0
ORGANIC
( 2.00 IN)
( 1.0 IN-H20)
(10.0 FT/S)
FIBER-REINFORCED POLYESTER
0
NONE
N/A
N/A
NONE
N/A
CENTRIFUGAL
UNIT
INDUCED DRAFT
WET
HIGH ALLOY
F-63
-------
UTILITY FGD SURVEY! OCTOBER 1983 - SEPTEMBER
POTOMAC ELECTRIC POWER: DICKERSON 3A (CONT.)
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»« DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** TANKS
SERVICE
REAGENT PREP PRODUCT
** PUMPS
SERVICE
NR
»» SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
*«* SLUDGE
*» TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
*» PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
CONTROL LEVELS
MONITOR LOCATION
PROCESS CONTROL MANNER
PROCESS CHEMISTRY MODE
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NUMBER
1
NUMBER
**##
THICKENER
2
THICKENED
N/A
N/A
N/A
NONE
N/A
PH, PRESSURE DROP
PH 7
IN SECOND STAGE SYSTEM
AUTOMATIC
FEEDBACK
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RAN3E MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RAK3E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
INLET FLUE GAS CAPACITY - CU.M/S
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
INLET FLUE GAS CAPACITY - CU.M/S
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LIN^R SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
( .100 LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
PUBLIC SERVICE OF COLORADO
VALMONT
5A
VALMONT
COLORADO
D
43.
******
******
274
166
157
163
166
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
436.98 ( 926000 ACFM)
126.7 ( 260 F)
****** (**** FT)
NR
******* (***** FT)
COAL
SUBBITUMINOUS
25121.
6.00
5.4-7.0
15.00
12.7-18.3
.70
0.6-0.7
********
******
218.5
0
NONE
COLD SIDE
218.5
( 10800 BTU/LB)
******
( 463000 ACFM)
( 463000 ACFM)
1
11/71
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
NATURAL RUBBER
STAINLESS STEEL
3
7.8 (58.3 GAL/1000ACF)
3.7 (15.0 IN-H20)
F-65
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PUBLIC SERVICE OF COLORADO: VALMONT 5A (CONT.)
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
»* QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
S02 REMOVAL EFFICIENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* FANS
DESIGN
FUNCTION
3.4
109.2
132.8
45.0
96.0
( 11.0 FT/S)
( 231500 ACFM)
( 271 F)
THROWAMAY PRODUCT
WET SCRUBBING
LIMESTONE/ALKALINE FLYASH
NONE
UOP/PUBLIC SERVICE OF COLORADO
STEARNS-ROGER
EXPERIMENTAL
RETROFIT
X 95.00
85.00
3.6
8
3/75
10/74
0/72
NR
NR
1
0
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
N/A
ORGANIC
SYNTHETIC RUBBER
NEOPRENE LS-576
77.5
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
HORIZONTAL
2
7
.1 ( .5 IN-H20)
STAINLESS STEEL
NR
SUPERNATANT
1
IN-LINE
STEAM
NR
36.1 ( 65 F)
NR
NR
CENTRIFUGAL
BOOSTER
F-66
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
PUBLIC SERVICE OF COLORADO'- VALMONT 5A (CONT.)
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
LOCATION
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
«* TANKS
SERVICE
THICKENER OVERFLOW
*» PUMPS
SERVICE
NR
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATUSE
TYPE
SITE TREATMENT
** WATER BALANCE
WATER LOOP TYPE
EVAPORATION WATER LOSS - LITER/S
FORCED DRAFT
DRY
CARBON STEEL
NR
NR
NR
NR
NR
NR
NR
OUTLET
CARBON STEEL
AISI 1110
NONE
N/A
WET BALL MILL
NR
NR
NUMBER
1
NUMBER
***«
THICKENER
BLEED
N/A
N/A
FINAL
POND
NONE
CLOSED
5.5
( 88 GPM)
F-67
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
RANGE ASH CONTENT - V.
AVERAGE MOISTURE CONTENT - '/.
RANGE MOISTURE CONTENT - V.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - V.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUttSER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*#» FGD SYSTEM
( .064 LB/MMBTU)
( .150 LB/MMBTU)
(****** LB/MMBTU)
SOUTHERN CALIFORNIA EDISON
MOHAVE
1A
LAUGHLIN
NEVADA
D
28.
64.
******
1560
790
790
790
170
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
******** (******* ACFM)
132.2 ( 270 F)
152. ( 500 FT)
NR
******* (***** FT)
COAL
******
26749.
10.00
******
********
******
.40
******
********
******
0
NONE
0
NONE
RESEARCH-COTTRELL
97.2
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
( 11500 BTU/LB)
11000-12000
F-68
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
SOUTHERN CALIFORNIA EDISON: MOHAVE 1A (CONT.)
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - L/CU.M
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOU - CU. M/S
S02 REMOVAL EFFICIENCY - X
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH FREQUENCY
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
THROWAMAY PRODUCT
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
PROTOTYPE
RETROFIT
X 97.20
.0
8
7/75
1/74
1/74
NR
NR
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
18.0 X 40.0 X 90.0
CARBON STEEL
AISI 1110
N/A
ORGANIC
NATURAL RUBBER
BLACK NATURAL RUBBER
PLASTIC/RUBBER MOBILE BALLS
4
11.1 ( 83.0 GAL/1000 ACF)
3.8 ( 12.6 FT/S)
212.35 ( 450000 ACFM)
95.0
93.0
PRIMARY COLLECTOR
NR
NR
NR
NR
NR
CONTINUOUS
1
IN-LINE
STEAM
NR
30.6 ( 55 F)
51.7 ( 125 F)
NR
NR
CENTRIFUGAL
BOOSTER
NR
NR
NR
F-69
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SOUTHERN CALIFORNIA EDISON: MOHAVE 1A (CONT.)
«* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
** PUMPS
SERVICE
NR
«* SOLIDS CONCENTRATING/DEWATERING
DEVICE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
**# SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
«* DISPOSAL
NATURE
TYPE
LOCATION
SITE TRANSPORTATION METHOD
SITE TREATMENT
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
COMPARTMENTED
NR
1
NUMBER
****
CENTRIFUGE
THICKENER
VACUUM FILTER
FIXATION
PUG MILL
CONVERSION SYSTEMS
FINAL
POND
ON-SITE
TRUCK
NR
IPOZ-O-TEC]
F-70
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
»» FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RAN3E HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
*«* PARTICLE CONTROL
«* MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
**» FGD SYSTEM
( .064 LB/MMBTU)
( .150 LB/MMBTU)
(****** LB/MMBTU)
SOUTHERN CALIFORNIA EDISON
MOHAVE
2A
LAUGHLIN
NEVADA
D
28.
64.
******
1560
790
790
790
160
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
******** (******* ACFM)
132.2 ( 270 F)
152. ( 500 FT)
NR
******* (**»** FT)
COAL
******
26749.
10.00
******
********
******
.40
******
********
******
0
NONE
0
NONE
RESEARCH-COTTRELL
97.2
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
( 11500 BTU/LB)
11000-12000
F-71
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
SOUTHERN CALIFORNIA EDISON: MOHAVE 2A (CONT.)
«* GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
ENERGY CONSUMPTION - 7.
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
#* QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - L/CU.M
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
SOS REMOVAL EFFICIENCY - 7.
PARTICLE REMOVAL EFFICENCY - X
*« MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
THROWAWAY PRODUCT
WET SCRUBBING
LIME
SO. CALIFORNIA EDISON/STEARNS-
STEARNS-ROGER
PROTOTYPE
RETROFIT
X 97.20
.0
8
2/75
11/73
11/73
NR
NR
SPRAY TOWER
OPEN CROSSCURRENT SPRAY
HORIZONTAL SPRAY CHAMBER
SO. CALIFORNIA EDISON/STEARNS-ROGER
15.0 X 30.0 X 60.0
CARBON STEEL
AISI 1110
N/A
NR
NR
NR
NONE
4
4.0 (
6.6 (
212.35 (
95.0
93.0
30.0 GAL/1000 ACF)
21.6 FT/S)
450000 ACFM)
PRIMARY COLLECTOR
NR
NR
NR
VERTICAL
1
NR
NR
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLE
30.6 ( 55 F)
48.9 ( 120 F)
NR
NR
CENTRIFUGAL
BOOSTER
NR
NR
NR
F-72
-------
SOUTHERN CALIFORNIA EDISON: MOHAVE 2A (CONT.)
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
#* PUMPS
SERVICE
NR
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
*** SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
»* DISPOSAL
NATURE
TYPE
SITE TREATMENT
*» WATER BALANCE
WATER LOOP TYPE
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
SLAKER
NR
NR
NUMBER
NR
FIXATION
MIX TANK
DRAVO CCALCILOX1
FINAL
POND
CLAY LINING
CLOSED
F-73
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RAN3E ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANSE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
*» ESP
NUMBER
TYPE
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
»** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
ST. JOE ZINC
G.F. WEATON
1
MONACA
PENNSYLVANIA
D
43.
516.
******
120
60
*****
*****
60
COMBUSTION ENGINEERING
PULVERIZED COAL
******
75.03 (
148.9 (
23. (
FIBERGLASS
3.2
( .100 LB/MMBTU)
( 1.200 LB/MMBTU)
(****** LB/MMBTU)
159000 ACFM)
300 F)
75 FT)
( 10.5 FT)
COAL
BITUMINOUS
29075.
11.50
******
********
******
2.00
2.0-4.5
.20
******
COLD SIDE
148.9
99.6
0
NONE
N/A
N/A
N/A
N/A
N/A
N/A
N/A
SALEABLE PRODUCT
KET SCRUBBING
CITRATE
MORRISON ft
MORRISON &
PROTOTYPE
RETROFIT
7. 99.60
( 12500 BTU/LB)
******
( 300 F)
KNUDSEN/U.S.B.M.
KNUDSEN
F-74
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 196*
ST. JOE ZINC: 6.F. MEATON 1 (CONT.)
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
*» QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*» FANS
NUMBER
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
90.00
8
9/82
1/80
11/79
0/77
NR
NR
PACKED TOWER
FIXED BED PACKING
N/A
26.0 DIA X 85.0
CARBON STEEL
AISI 1110
N/A
ORGANIC
VINLY ESTER
NR
INTALOX SADDLE
1
283.
73.62
48.9
90.0
( 4500 GPM)
( 156000 ACFM)
( 120 F)
PRIMARY COLLECTOR
2
IMPINGEMENT
BAFFLE
CLOSED VANE
ORGANIC
POLYVINYL CHLORIDE
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLE
NR
NR
CENTRIFUGAL
BOOSTER
FORCED DRAFT
DRY
CARBON STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
F-75
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 198*
ST. JOE ZINC: G.F. WEATON 1 (CONT.)
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** TANKS
SERVICE
SALEABLE BYPRODUCT
REAGENT PREP PRODUCT
MAKEUP WATER
** PUMPS
SERVICE
SULFUR SLURRY
LEAN SOLUTION
******
SULFUR TRANSFER
SCRUBBER RECIRCULATION
SULFUR LOADINS
RICH CITRATE SOLUTION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
*** SALEABLE BYPRODUCTS
NATURE
QUALITY - X
«** SLUDGE
«* TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
** WATER BALANCE
WATER LOOP TYPE
** FGD SPARE CAPACITY INDICES
ABSORBER - X
** FGD SPARE COMPONENT INDICES
ABSORBER
MIX TANK
N/A
AGITATED TANK
NUMBER
NUMBER
2
Z
I
I
4
1
2
NONE
ELEMENTAL SULFUR
99.5
N/A
N/A.
N/A
N/A
NONE
N/A
CLOSED
.0
.0
F-76
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RAN3E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*** FGD SYSTEM
.100 LB/MMBTU)
1.200 LB/MMBTU)
(****** LB/MMBTU)
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10A
PADUCAH
KENTUCKY
E
43.
516.
******
1750
10
10
*****
10
******
******
******
********
*******
******
NR
*******
(******* ACFM)
(**** F)
(**** FT)
(***** FT)
(****** BTU/LB)
******
COAL
BITUMINOUS
******
********
******
********
******
2.90
******
********
******
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
NR
NR
NR
NR
PLASTIC SPHERES
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
TERMINATION
INITIAL START-UP
THROWAWAY PRODUCT
WET SCRUBBING
LIME/LIMESTONE
VARIABLE - TEST FACILITY
AIR CORRECTION DIVISION, UOP
BECHTEL
PROTOTYPE
RETROFIT
90.00
8
7/82
4/72
F-77
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
TENNESSEE VALLEY AUTHORITY: SHAWNEE 10A (CONT.)
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER Of CONTACTING ZONES
DISTANCE BETWEEN GAS CONTACTING ZONES
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
WASH FREQUENCY
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
MR
NR
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
NR
NR
NR
NR
NR
NR
PLASTIC/RUBBER MOBILE BALLS
3
- CM 12.7 ( 5.0IN)
16.52 ( 35000 ACFM)
148.9 ( 300 F)
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
CLOSED VANE
NR
NR
SUPERNATANT .
INTERMITTENT
DIRECT COMBUSTION
NR
OIL
NR
NR
CENTRIFUGAL
BOOSTER
INDUCED DRAFT
DRY
CARBON STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
F-78
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER
TENNESSEE VALLEY AUTHORITY: SHAWNEE IDA (CONT.)
** TANKS
SERVICE
ABSORBER RECYCLE
»« PUMPS
SERVICE
NR
*» SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
** SOLIDS CONCENTRATING/OEWATERING
DEVICE
NUMBER
*** SLUDGE
*» TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
** MATER BALANCE
WATER LOOP TYPE
tut FGD SPARE CAPACITY INDICES
ABSORBER - X
** FGD SPARE COMPONENT INDICES
ABSORBER
NUMBER
****
NUMBER
«**«
CENTRIFUGE
1
THICKENER
1
DEWATERED
N/A
N/A
FINAL
LANDFILL
NONE
CLOSED
.0
.0
F-79
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - '/.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - V.
RANGE MOISTURE CONTENT - '/.
AVERAGE SULFUR CONTENT - V.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - V.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** PARTICLE SCRUBBER
NUM3ER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
INLET GAS FLON RATE - CU.M/S
INLET GAS TEMPERATURE - C
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
SOS REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
.100 LB/MMBTU)
1.200 LB/MMBTU)
(****** LB/MMBTU)
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10B
PADUCAH
KENTUCKY
E
43.
516.
******
1750
10
10
*****
10
******
******
******
********
*******
******
NR
*******
(******* ACFM)
(**** F)
(**** FT)
(***** FT)
(****** BTU/LB)
******
COAL
BITUMINOUS
******
********
******
********
******
2.90
******
********
******
1
4/72
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
GE ENVIRONMENTAL SERVICES
NR
NR
NR
NR
NONE
1.7 ( 3500 ACFM)
148.9 ( 300 F)
THROWAWAY PRODUCT
WET SCRUBBING
LIME/LIMESTONE
VARIABLE - TEST FACILITY
GE ENVIRONMENTAL SERVICES
BECHTEL
PROTOTYPE
RETROFIT
90.00
8
F-80
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
TENNESSEE VALLEY AUTHORITY: SHAWNEE 10B (CONT.)
TERMINATION
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
»* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
7/82
4/7E
NR
NR
SPRAY TOWER
OPEN COUNTERCURRENT SPRAY
N/A
GE ENVIRONMENTAL SERVICES
NR
NR
NR
NR
NR
NR
NONE
16.52
148.9
( 35000 ACFM)
( 300 F)
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
CLOSED VANE
NR
NR
DIRECT COMBUSTION
NR
OIL
NR
NR
CENTRIFUGAL
BOOSTER
INDUCED DRAFT
DRY
CARBON STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
F-81
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
TENNESSEE VALLEY AUTHORITY: SHAWNEE 10B (CONT.)
** TANKS
SERVICE NUMBER
ABSORBER RECYCLE ****
SPARGER/OXIDIZER ****
NR ****
** PUMPS
SERVICE NUMBER
NR #***
** SOLIDS CONCENTRATING/DEWATERING
DEVICE NR
*** SLUDGE
#* TREATMENT
METHOD DEWATERED
DEVICE N/A
PROPRIETARY PROCESS N/A
** DISPOSAL
NATURE FINAL
TYPE LANDFILL
SITE TREATMENT NONE
** WATER BALANCE
WATER LOOP TYPE CLOSED
** FGD SPARE CAPACITY INDICES
ABSORBER -7. .0
»* FGD SPARE COMPONENT INDICES
ABSORBER .0
F-82
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANSE ASH CONTENT - '/.
AVERAGE MOISTURE CONTENT - 7.
RANSE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RAK3E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
SOZ REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
CURRENT STATUS
TERMINATION
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
TENNESSEE VALLEY AUTHORITY
SHAKNEE
IOC
PADUCAH
KENTUCKY
D
43. ( .100 LB/MMBTU)
516. ( 1.200 LB/MMBTU)
****** <****«* LB/MMBTU)
1750
10
*****
*****
10
BABCOCK & WILCOX
PULVERIZED COAL
BASE
(******* ACFM)
(**** F)
( 800 FT)
(***** FT)
(****** BTU/LB)
******
********
*******
244.
NR
*******
COAL
BITUMINOUS
******
********
******
********
******
2.90
******
********
******
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
NR
NR
NR
NR
PLASTIC SPHERES
THROWAWAY PRODUCT
WET SCRUBBING
LIME/LIMESTONE
COMBUSTION ENGINEERING
BECHTEL
PROTOTYPE
RETROFIT
8
7/73
4/72
F-63
-------
UTILITY F6D SURVEY: OCTOBER 1983 - SEPTEMBER 1984
TENNESSEE VALLEY AUTHORITY: SHAKNEE IOC (COMT.)
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
INLET GAS FLOW - CU. M/S
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
#* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** PUMPS
SERVICE
NR
NR
NR
PACKED TOWER
STATIC BED PACKING
MARBLE-BED SCRUBBER
NR
NR
NR
NR
NR
NR
GLASS MARBLES
14.16 ( 30000 ACFM)
NR
NR
NR
NR
NR
NR
DIRECT COMBUSTION
NR
OIL
NR
NR
CENTRIFUGAL
BOOSTER
INDUCED DRAFT
DRY
CARBON STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NUMBER
*«**
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
VACUUM FILTER
*** SLUDGE
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
TENNESSEE VALLEY AUTHORITY: SHAWNEE IOC (CONT.)
** TREATMENT
METHOD DEWATERED
DEVICE N/A
PROPRIETARY PROCESS N/A
*» DISPOSAL
NATURE FINAL
TYPE LANDFILL
SITE TREATMENT NONE
F-85
-------
UTILITY FGO SURVEY: OCTOBER 1983 - SEPTEMBER 1984
APPENDIX F
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - V.
AVERAGE "SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PROOUCT/THROWAWAY PRODUCT
502 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
TERMINATION
INITIAL START-UP
CONTRACT AWARDED
UNION ELECTRIC
MEREMAC
2
N/A
MISSOURI
******
******
******
******
4135
140
125
***
140
(****** LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
******
PULVERIZED
BASE
********
*******
******
NR
*******
COAL
(******* ACFM)
(**** F)
(**** FT)
(***** FT)
(****** BTU/LB)
******
COAL
******
******
********
******
********
******
3.40
******
********
******
PACKED TOWER
STATIC BED PACKING
MARBLE-BED SCRUBBER
NR
NR
NR
NR
PLASTIC SPHERES
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
FULL SCALE
RETROFIT
7. 99.00
83.00
8
0/69
3/68
0/67
F-86
-------
UNION ELECTRIC: MEREMAC 2 CCONT.)
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 1984
** DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»* DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** PUMPS
SERVICE
NR
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
*** SLUDGE
NR
NR
PACKED TOWER
STATIC BED PACKING
MARBLE-BED SCRUBBER
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
NR
NR
NUMBER
*#**
NR
F-87
-------
UTILITY FGD SURVEY: OCTOBER 1983 - SEPTEMBER 198*
UNION ELECTRIC: MEREMAC 2 CCONT.)
** TREATMENT
METHOD NR
DEVICE NR
PROPRIETARY PROCESS NR
** DISPOSAL
NATURE FINAL
TYPE NR
SITE TREATMENT NR
** WATER BALANCE
WATER LOOP TYPE CLOSED
F-88
-------
TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
1.
4.
7.
9.
REPORT NO.
EPA 340/1-85-01%
TITLE AND SUBTITLE
Utility FGD Survey
October 1983 - September
Volume 1
2.
1984
AUTHOR(S)
M.T. Melia, R.S. McKibben, B.W. Pelsor
PERFORMING ORGANIZATION NAME At«
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, OH 45246-010
12. SPONSORING AGENCY NAME AND ADC
U.S. Environmental Protec
Stationary Source Complia
401 M Street, S.W.
Washington, B.C. 20460
JO ADDRESS
0
1RESS
tion Agency
ince Division (EN-341)
3. RECIPIENT'S ACCESSION NO.
5. REPORT DATE
October 1984
6. PERFORMING ORGANIZATION CODE
8. PERFORMING ORGANIZATION REPORT NO.
10. PROGRAM ELEMENT NO.
11. CONTRACT/GRANT NO.
68-02-3963, Task No. 46
13. TYPE OF REPORT AND PERIOD COVERED
Final, Oct. 1983-Sept. 1984
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
Sunmarized in EPA 340/1-85-014 - Utility FGD Survey Sunnary
EPA Task Manager - Sonva Stelmack (202) 382-2851
16. ABSTRACT
This report, which is generated by a computerized data base system,
represents a survey of operational and planned domestic utility flue gas
desulfurization (FGD) system. The three volume set summarizes information
contributed by the utility industry, system and equipment suppliers, system
designers, research organizations, and regulatory agencies. The data cover system
design, fuel characteristics, operating history, and actual system performance.
Also included is a unit-by-unit discussion of problems and solutions associated
with the boilers, scrubbers, and FGD systems.
The development status (operational, under construction, or in the planning
stages) , system supplier, process, waste disposal practice, and regulatory class
are tabulated alphabetically by utility company. Simplified process flow diagrams
of FGD systems, definitions, and a glossary of terms are attached to the report.
Current data for domestic FGD systems show 124 systems in operation, 25 systems
under construction, and 68 systems planned. The current FGD-con trolled capacity
in the United States is 47,255 W.
17
a.
DESCRIPTORS
KEY WORDS AND DOCUMENT ANALYSIS
b.lDENTIFIERS/OPEN ENDED TERMS
18
. DISTRIBUTION STATEMENT
Release unlimited
19. SECURITY CLASS (This Report)
unclassified
20. SECURITY CLASS (This page)
unclassified
c. COSATI Field/Group
21. NO. OF PAGES
22. PRICE
EPA Form 2220-1 (Rev. 4-77) PREVIOUS EDITION is OBSOLETE
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