oEPA
United States
Environmental Protection
Agency
Industrial Environmental Research
Laboratory
Research Triangle Park NC 27711
EPA-600/7-80-029b
May 1980
EPA Utility FGD Survey:
January-March 1980
Interagency
Energy/Environment
R&D Program Report
-------
RESEARCH REPORTING SERIES
Research reports of the Office of Research and Development, U.S. Environmental
Protection Agency, have been grouped into nine series. These nine broad cate-
gories were established to facilitate further development and application of en-
vironmental technology. Elimination of traditional grouping was consciously
planned to foster technology transfer and a maximum interface in related fields.
The nine series are:
1. Environmental Health Effects Research
2. Environmental Protection Technology
3. Ecological Research
4. Environmental Monitoring
5. Socioeconomic Environmental Studies
6. Scientific and Technical Assessment Reports (STAR)
7. Interagency Energy-Environment Research and Development
8. "Special" Reports
9. Miscellaneous Reports
This report has been assigned to the INTERAGENCY ENERGY-ENVIRONMENT
RESEARCH AND DEVELOPMENT series Reports in this series result from the
effort funded under the 17-agency Federal Energy/Environment Research and
Development Program. These studies relate to EPA's mission to protect the public
health and welfare from adverse effects of pollutants associated with energy sys-
tems. The goal of the Program is to assure the rapid development of domestic
energy supplies in an environmentally-compatible manner by providing the nec-
essary environmental data and control technology. Investigations include analy-
ses of the transport of energy-related pollutants and their health and ecological
effects; assessments of, and development of, control technologies for energy
systems; and integrated assessments of a wide range of energy-related environ-
mental issues.
EPA REVIEW NOTICE
This report has been reviewed by the participating Federal Agencies, and approved
for publication. Approval does not signify that the contents necessarily reflect
the views and policies of the Government, nor does mention of trade names or
commercial products constitute endorsement or recommendation for use.
This document is available to the public through the National Technical Informa-
tion Service, Springfield, Virginia 22161.
-------
EPA-600/7-80-029b
May 1980
EPA Utility FGD Survey:
January-March 1980
by
M. Smith, M. Melia, and N. Gregory
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
Contract No 68-01-4147
Task No. 143
Program Element No. INE828
EPA Project Officer: Norman Kaplan
Industrial Environmental Research Laboratory
Office of Environmental Engineering and Technology
Research Triangle Park, NC 27711
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY and U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Research and Development Office of Enforcement
Washington, DC 20460 Washington, DC 20460
-------
NOTICE
This report (prepared by PEDCo Environmental, Inc., Cincin-
nati, Ohio under EPA Contract No. 68-01-4147, Task No. 143) is
provided as an information transfer document. Data in this re-
port are supplied voluntarily by utility representatives; flue
gas desulfurization (FGD) system designers and suppliers; regula-
tory personnel; and others. Neither EPA nor the designated
contractor warrants the accuracy or completeness of information
contained in this report.
Initial distribution of the report (generally one copy per
company) is limited to organizations and individuals indicating
a specific interest in the field of FGD technology. Additional
copies of this report and succeeding issues can be purchased from
National Technical Information Service, Springfield, Virginia
22151.
-------
USE OF THIS REPORT
This report is the first of three supplementary issues to
the October-December 1979 report. Supplementary issues are
cumulative, so that it is necessary to retain only the latest
issue and the October-December 1979 report (EPA-600/7-80-029a).
It should be noted that along with the design and perform-
ance data for operational FGD systems contained in Section 3,
this report also contains a number of tables presenting tabula-
tions of some of the key data. The Executive Summary contains
the number and capacity of FGD systems as of the end of March
1980, future projections (January 1990) of controlled and uncon-
trolled generating capacity, and unit by unit summaries of status
changes and performance during the period.
Recent additions to this report include a section containing
design and performance data for U.S. operational particle scrub-
bers (Section 14) and a section containing design and performance
data for coal-fired operational Japanese FGD systems (Section 15).
The regulatory classifications were recently modified to accomodate
the revised New Source Performance Standards (6/79) and, as a
result, the categories will differ slightly from those of pre-
vious issues.
Appended to this report is a section containing reported and
adjusted cost data for U.S. FGD systems in which operational sys-
tems are stressed (Appendix A). Also included in the appendices
are definitions and a glossary of units.
111
-------
ABSTRACT
This report is the first of three supplements updating the
October - December 1979 report (EPA-600/7-80-029a) and should be
used in conjunction with it. The report, which is generated by a
computerized data base system, presents a survey of operational
and planned domestic utility flue gas desulfurization (FGD) sys-
tems, operational domestic particle scrubbers, and Japanese
coal-fired utility boiler FGD installations. It summarizes
information contributed by the utility industry, process suppliers,
regulatory agencies, and consulting engineering firms. It pre-
sents data on system design, fuel characteristics, operating
history and actual performance. Unit by unit dependability
parameters are included and problems and solutions associated
with the boilers, scrubbers, and FGD systems are discussed.
The domestic FGD systems are tabulated alphabetically by
development status (operational, under construction, or in the
planning states), utility company, system supplier, process,
waste disposal practice, and regulatory class. FGD system
economic data, definitions, and a glossary of terms are appended
to the report. Current data for operational domestic FGD systems
show 65 systems in operation, 42 systems under construction, and
74 planned systems. Projected 1990 FGD controlled capacity in
the U.S. is 85,671 MW.
IV
-------
CONTENTS
Notice
Use of This Report
Abstract
Tables
Executive Summary and Highlights
Section 1
Section 2
Section 3
Summary List of FGD Systems 1
Status of FGD Systems 7
Design and Performance Data for Operational
FGD Systems 38
Alabama Electric
Tombigbee 2 38
Tombigbee 3 40
Allegheny Power System
Pleasants 1 41
Arizona Electric Power
Apache 2 42
Apache 3 43
Arizona Public Service
Cholla 1 44
Cholla 2 45
Four Corners 1 46
Four Corners 2 47
Four Corners 3 48
Big Rivers Electric
Green 1 49
Central Illinois Light
Duck Creek 1 50
Central Illinois Public Service
Newton 1 52
Colorado Ute Electric Assn.
Craig 2 54
Columbus & Southern Ohio Electric
Conesville 5 55
Conesville 6 57
Cooperative Power Association
Coal Creek 1 59
v
-------
CONTENTS (continued)
Duquesne Light
Elrama 1-4 61
Phillips 1-6 63
Indianapolis Power & Light
Petersburg 3 65
Kansas City Power & Light
Hawthorn 3 66
Hawthorn 4 68
LaCygne 1 69
Kansas Power & Light
Jeffrey 1 70
Lawrence 4 71
Lawrence 5 72
Kentucky Utilities
Green River 1-3 73
Louisville Gas & Electric
Cane Run 4 74
Cane Run 5 75
Cane Run 6 76
Mill Creek 3 77
Paddy's Run 6 78
Minnkota Power Cooperative
Milton R. Young 2 79
Montana Power
Colstrip 1 81
Colstrip 2 82
Nevada Power
Reid Gardner 1 83
Reid Gardner 2 84
Reid Gardner 3 86
Northern Indiana Public Service
Dean H. Mitchell 11 87
Northern States Power
Sherburne 1 88
Sherburne 2 89
Pacific Power & Light
Jim Bridger 4 90
Pennsylvania Power
Bruce Mansfield 1 91
Bruce Mansfield 2 92
Philadelphia Electric
Eddystone 1A 93
Public Service Company of New Mexico
San Juan 1 94
San Juan 2 95
San Juan 3 96
VI
-------
CONTENTS (continued)
Section 4
Section 5
Section 6
Section 7
Section 8
Section 9
Section 10
Section 11
Section 12
Page
Salt River Project
Coronado 1 97
South Carolina Public Service Authority
Winyah 2 98
South Mississippi Electric
R.D. Morrow 1 99
R.D. Morrow 2 100
Southern Illinois Power Coop
Marion 4 101
Southern Indiana Gas & Electric
A.B. Brown 1 103
Springfield City Utilities
Southwest 1 105
St. Joe Zinc
G.F. Weaton 1 107
Tennessee Valley Authority
Shawnee 10A 108
Shawnee 10B 109
Widows Creek 8 111
Texas Utilities
Martin Lake 1 113
Martin Lake 2 114
Martin Lake 3 115
Monticello 3 116
Utah Power & Light
Hunter 1 117
Huntington 1 118
Summary of FGD Systems by Company 119
Summary of FGD Systems by System Supplier 121
Summary of FGD Systems by Process 123
Summary of Operating FGD Systems by
Process and Unit 124
Summary of End-Product Disposal
Practices for Operational FGD Systems 126
Summary of FGD Systems in Operation 128
Summary of FGD Systems Under Construction 131
Summary of Contract Awarded FGD Systems 133
Summary of Planned FGD Systems 134
-------
CONTENTS (continued)
Section 13
Section 14
Section 15
Total FGD Units and Capacity (MW)
Installed by Year
Design and Performance Data for
Operational Particle Scrubbers
Commonwealth Edison
Will County 1
Detroit Edison
St. Clair 6
Minnesota Power and Light
Aurora 1
Aurora 2
Clay Boswell 3
Montana-Dakota Utilities
Lewis & Clark 1
Pacific Power and Light
Dave Johnston 4
Potomac Electric Power
Dickerson 1
Dickerson 2
Dickerson 3
Public Service of Colorado
Arapahoe 4
Cherokee 1
Cherokee 4
Valmont 5
Southwestern Public Service
Harrington 1
Design and Performance Data for
Operational Foreign FGD Systems
Chugoku Electric
Shimonoseki 1
Electric Power Development Company
Isogo 1
Isogo 2
Takasago 1
Takasago 2
Takehara 1
138
151
157
159
161
163
165
167
168
170
175
177
179
181
186
188
188
190
192
194
196
198
viii
-------
CONTENTS (continued)
Appendix A FGD System Cost Data: Operational
and Nonoperational Systems A-l
A-l Major FGD System Equipment Summary A-8
A-2 Cost Element Factors A-13
A-3 Description of Cost A-16
A-4 Categorical Results of Reported and
Adjusted Capital and Annual Costs for
Operational FGD Systems A-19
A-5 Costs for Operational FGD Systems A-20
A-6 Costs for Nonoperational FGD Systems A-25
Appendix B Definitions B-l
Appendix C Glossary of Units C-l
IX
-------
TABLES
No. Page
I Number and Total Capacity of FGD Systems xi
II Summary of Changes, January - March 1980 xiii
III Performance of Operational Units,
January - March 1980 xiv
FIGURE
No. Page
1 computerized data base structure diagram xii
-------
EXECUTIVE SUMMARY
This report is prepared quarterly (every three months) by
PEDCo Environmental, Inc., under contract to the Industrial
Environmental Research Laboratory/Research Triangle Park and the
Division of Stationary Source Enforcement of the U.S. Environmen-
tal Protection Agency. It is generated by a computerized data
base system, the structure of which is illustrated in Figure 1.
Table 1 summarizes the status of FGD systems in the United
States at the end of March 1980. Table II lists the units that
have changed status during the first quarter 1980, and Table III
shows the performance of operating units during this period.
TABLE 1. NUMBER AND TOTAL CAPACITY OF FGD SYSTEMS
Status
Operational
Under construction
Planned:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only
FGD systems
TOTAL
No. of
units
65
42
23
2
15
34
181
Total
Controlled
Capacity, MW*
23,887
19,583
11,532
842
10,255
19,572
85,671
Equivalent
Scrubbed
Capacity, MW"1"
22,100
18,454
10,519
842
10,221
19,432
81,568
* Total Controlled Capacity (TCC) is the summation of the gross unit
capacities (MW) brought into compliance with FGD systems regardless
of the percent of the flue gas scrubbed by the FGD system(s).
Equivalent Scrubbed Capacity (ESC) is the summation of the effective
scrubbed flue gas in equivalent MW based on the percent of flue gas
scrubbed by the FGD system(s).
t
XI
-------
H-
H-
Figure 1. Computerized data base structure diagram.
-------
TABLE II. SUMMARY OF CHANGES
JANUARY - MARCH 1980
FGD status report
12/31/79
Arizona Electric Power Coop
Four Corners 1
Four Corners 2
Four Corners 3
Basin Electric Power Coop
Laramie River 3
Cincinnati Gas & Electric
East Bend 1
Deseret Generation & Trans. Coop
Moon Lake 1
Moon Lake 2
Grand Haven Brd. of Light & Pwr.
J.B. Sims 3
Michigan So. Central Pwr. Agency
Project 1
Muscatine Power & Water
Muscatine 9
Nevada Power
Reid Gardner 4
New York State Elec. & Gas
Somerset 1
Philadelphia Electric
Eddys tone IB
Eddystone 2
Seminole Electric
Seminole 1
Seminole 2
Tennessee Valley Authority
Johnsonville 1-10
Paradise 1
Paradise 2
Texas Municipal Power Agency
Gibbons Creek 1
United Power Association
Stanton 2
Wisconsin Power S Light
Columbia 2
TOTAL
Operational
No.
62
+ 1
+ 1
+ 1
65
MW*
21.5218
175
175
229
22.100
Under
construction
No.
39
-1
-1
-1
+1
+1
+ 1
+1
+1
+1
42
MW*
16,051
175
175
229
600
240
334
704
704
400
18,454
Contract
awarded
No.
23
-1
+ 1
+1
+1
-1
-1
+1
+1
+1
-1
-1
-1
+1
-1
23
MU*
11.631a
600
81
55
160
240
334
620
620
600
704
704
400
50
316
10.519
Letter
of Intent
No.
2
2
MU*
842
842
Requesting/
eval. bids
No.
15
+1
+1
-1
+1
+1
-1
-1
-1
15
MU*
10.281
410
410
160
250
870
620
620
600
10,221
Considering
FGD
No.
35
+1
-1
-1
34
MW*
19,902
650
250
870
19.432
Total
No.
176
+1
+1
+1
+1
+1
+1
-1
181
MW*
80,228a
650
410
410
81
55
50
316
81.568
• Equivalent scrubbed capacity.
1 This value was «od1fied slightly due to « MW correction.
Xlll
-------
TABLE III. PERFORMANCE OF OPERATIONAL UNITS
JANUARY - MARCH 1980
Plant
Toribigbee 2
Toabigbee 3
Pleasant* 1
Apache 2
Apache 3
Choi la 1
Cholla 2
Four Corners 1
Four Corners 2
Four Corners 3
Green 1
Duck Creek 1
Newton 1
Craig 2
Conesville 5
Conesville 6
Coal Creek 1
Elraaa 1-4
Phillips 1-6
Petersburg 3
Hawthorn 3
Hawthorn 4
La Cygne 1
Jeffrey 1
Lawrence 4
Lawrence 5
Green River 1-3
Cane Run 4
Cane Run 5
Cane Run 6
Hill Creek 3
Paddy's Run 6
FGO syste*
capacity,
179
179
519
195
195
119
350
175
175
229
242
378
617
447
411
411
327
510
410
532
90
90
874
540
125
420
64
188
200
299
44?
72
Flue gas
X scrubbed
70
70
83
100
100
100
100
100
100
100
100
90
100
100
100
100
60
100
100
100
100
100
100
75
100
100
100
100
100
100
100
100
FGD capacity
on line
during
PMW^'
179
179
195
195
119
175
175
229
378
617
447
411
411
327
510
410
532
90
540
125
420
188
200
299
442
Mo information
for this
period, MW3
519
350
242
874
Shut dour
through-
out
period,
90
64
72
January 1980
Jependabi 1 ity X '
vt
90
00
90
92
32
52
27
89
100
73
1DO
100
100
OPR
62
98
58
92
97
35
46
44
76
100
100
89
100
100
100
100
92
49
REL
89
92
38
54
52
76
100
74
UTL
48
43
57
92
97
32
45
15
76
%
98
72
93
0
100
100
0
96
72
14
0
0
February 1980
Dependability X '
AVI
99
100
93
95
49
53
92
90
100
71
100
100
100
OPR
99
100
97
74
100
49
39
66
78
100
100
79
100
100
100
100
72
85
36
REL
93
96
52
40
81
82
100
71
UTL
99
3
93
71
100
49
39
33
72
100
92
70
100
0
100
52
0
67
50
47
27
0
March 1980
Dependability * '
AVI
100
100
99
91
36
66
94
100
100
100
OPR
98
99
91
96
34
82
73
100
100
100
100
81
45
70
37
REL
99
91
37
82
73
UTL
90
0
99
91
96
34
82
16
96
100
0
100
55
0
74
27
65
31
0
(continued)
-------
TABLE III (continued)
Plant
Hilton R. Young 2
Colstrip 1
Colstrip 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Dean H. Mitchell 11
Sherburne 1
Sherburne 2
Jim Bridger 4
Bruce Mansfield 1
Bruce Mansfield 2
Eddystone 1A
San Juan 1
San Juan 2
San Juan 3
Coronado 1
Winyah 2
R.O. Morrow 1
R.D. Morrow 2
Marion 4
A.B. Brown 1
Southwest 1
G. F. Weaton 1
Snawnee IDA
Shawnee 10B
Widows Creek 8
Martin Lake 1
Martin Lake 2
FGO system
capacity,
405
360
360
125
125
125
115
740
740
550
917
917
120
361
350
534
280
140
124
124
184
265
194
60
10
10
550
595
595
Flue gas
X scrubbed
92
100
100
100
100
100
100
100
100
100
100
100
N/Ad
100
100
100
80
50
62
62
100
100
100
N/Ad
N/Ad
N/Ad
100
75
75
FGD capacity
on line
duri ng
•>$?!!•
405
125
125
125
740
740
550
917
917
361
350
534
280
140
124
124
184
265
194
60
10
10
550
595
595
No information
for this
period, tor
360
360
115
Shut down
through-
out
period,
MW*
120
Ja
)epe
TO.
7
100
97
100
97
97
98
97
87
31
0
0
99
61
70
luary
idabi 1
WIT
11
100
97
100
100
100
57
21
100
98
56
90
980
ty XC
-an-
ii
100
97
100
0
0
98
62
e
-oTT-
7
100
82
91
90
91
47
21
0
0
10
98
52
45
February 1980
Dependability Xc'e
~AVl
0
100
97
78
97
96
98
94
67
40
99
55
85
OPR
0
100
97
98
100
100
65
23
100
70
50
94
REL
100
97
78
70
50
UTL
0
100
97
78
94
100
59
26
31
69
50
77
March 1980
Dependability X •
AVL
29
66
98
60
98
98
98
98
93
57
45
43
87
OPR
29
84
98
100
100
100
73
31
100
65
35
79
REL
29
85
98
100
68
35
UTL
29
34
98
60
84
84
26
20
48
27
35
77
(continued)
-------
TABLE III (continued)
Plant
Hart in Lake 3
Honticello 3
Hunter 1
Huntington 1
TOTAL
FGO systen
capacity .
595
800
360
366
Flue gas
X scrubbed
75
100
90
85
FGO capacity
on line
during
P$°g>
S95
800
18.208
No information
for this
period, HWa
360
366
3,546
Shut down
through-
out
period.
346
January 1980
pependability X '
Wl
OPR
REL
UTL
February 1980
Dependability X '
Wl
OPR
REL
UTL
March 1980
Dependability X 'e
AVL
OPR
REL
UIL
. Equivalent scrubbed capacity.
This category includes the flue gas capacity being handled by the FGD system at least part of the time during the report period.
. The percent figures listed are average values for all system scrubbing trains during the period.
Flue gas X scrubbed for prototype and demonstration units is not applicable unless the system is designed to bring a unit into compliance
with SO2 Mission standard.
Availability, operability, reliability, and utilization as defined in Appendix C of this report.
-------
As indicated in Table 1, 65 power generating units (all coal-
fired) are now equipped with operating FGD systems. These units
represent a total controlled capacity of 23,887 MW. Current
projections indicate that the total power generating capacity of
the U.S. electric utility industry will be approximately 931 GW
by 1990.a (This value reflects the annual loss resulting from
the retirement of older units, which is considered to be 0.4
percent of the average generating capacity at the end of each
year.b) Approximately 382 GW or 41 percent of the 1990 total
will come from coal-fired units. The distribution of power
generation sources, both present (April 1979) and future (January
1990) is as follows:3
Coal Nuclear Oil Hydro Gas Other GW (total)
April 1979 39% 9% 26% 12% 13% 1% 588
January 1990 41% 22% 18% 10% 8% 1% 931
Based on the known commitments to FGD by utilities as presented
in Table 1, the percentage of electrical generating capacity
controlled by FGD for both the present (March 1980) and the
future (January 1990) is as follows:
% of coal-fired % of total
generating capacity generating capacity
March 1980* 10.4 4.1
January 1990 22.4 9.2
In light of the revised New Source Performance Standards, actual
FGD control is expected to be greater than what is reflected by
the figures above. For example, about 55 to 60 systems repre-
senting approximately 36,000 to 41,000 MW of generating capacity
presently fall into the uncommitted category. These are systems
that cannot be included in the committed group at this time
because information regarding their status is not ready for
public release.
In an effort to show general FGD usage and projected usage trends,
the table below gives a current (March 1980) and a projected
(January 1990) breakdown of throwaway product systems versus
saleable product systems as a percent of the total known committ-
ments to FGD as of the end of the first quarter 1980:
The number of committed FGD systems is as of March 1980; however,
the figure used for the total generating capacity and coal fired
generating capacity is based on the available April 1979 figures.
xvn
-------
Throwaway product process Saleable product process Process undecided Total
% of total % of total % of total
Line Limestone Other Sulfur H-SO, Gypsum N/A*
March 1980 28.1 39.4 25.5 4.0 3.0 Ioo
January 1990 16.4 36.4 20.5 1.1 2.4 0.2 3.0 20.0 loo
*
N/A - not available (these systems will utilize a saleable product process but the byproduct is unknown at
this time).
HIGHLIGHTS: JANUARY - MARCH 1980
The following paragraphs highlight FGD system developments during
the first quarter, 1980.
Tombigbee 2 of Alabama Electric Cooperative achieved availabili-
ties of 90%, 99%, and 100% for the months of January, February,
and March, respectively. The FGD system was unavailable only 69
hours in January due to a ruptured waste slurry line and an
abraded expansion joint. No major FGD related problems were
reported for February or March. The Tombigbee 3 FGD system had
availabilities of 100% for both January and February; however,
the Unit 3 boiler only operated for 24 hours in February. Unit 3
did not operate at all during March.
Arizona Electric Power Cooperative reported availabilities of
90%, 92%, and 99% for the Apache 2 FGD system during January,
February, and March, respectively. The Apache 3 availabilities
were 91%, 95%, and 91% for the same period. Most of the FGD
system outage time reported was due to the malfunction of pumps.
The Cholla 1 FGD system of Arizona Public Service had operabili-
ties of 97%, 100%, and 96% for the months of January, February,
and March, respectively. No major FGD related problems were re-
ported for the three month period although some outage time was
required for repair of reheater ductwork.
Arizona Public Service announced during the period that modifica-
tions to the particle scrubbers at the Four Corners 1, 2, and 3
units were completed and the systems have begun operation in an
SC>2 removal mode. Initially, the two Chemico venturi scrubbers
designed for primary particle control at each unit were also
removing approximately 30% of the SC>2 due to the alkalinity of
the fly ash. These systems were modified to accommodate addi-
tional SC-2 removal (67.5%) by converting the scrubbers to lime/
alkaline fly ash systems. Actual conversion of each system was
completed in November 1979.
XVI11
-------
Basin Electric Power Coop announced that construction of the
Laramie River 3 FGD system began during February 1980. Particle
and S02 emissions at this 600 MW (gross) unit will be controlled
by four lime/spray drying towers followed by a common ESP. The
system is designed to remove 85 percent of the S02 before the
flue gas exits through a 600 foot acid brick lined stack.
Initial start up of the system is expected in July 1981.
Cincinnati Gas and Electric announced plans during the period for
the installation of a second 650 MW (gross) generator at the East
Bend power plant. The boiler will be identified as Unit 1 and
will be required to meet an SC>2 emission standard of 0.84 Ib/MMBtu,
Currently, the utility is considering only FGD as a means of
controlling the S02 emissions. The process type has not been
selected and the projected start-up date of the unit has not been
finalized.
No major FGD related problems were encountered during the first
quarter, 1980 with the Conesville 6 FGD system of Columbus and
Southern Ohio Electric. As a result, the unit had availabilities
of 89%, 90%, and 94% for January, February, and March, respec-
tively. The system utilization was only 16% in March due to an
annual boiler/turbine inspection that began on March 9.
Cooperative Power Association reported FGD system utilization
parameters of 96%, 100%, and 96% for January, February, and
March, respectively. Some minor FGD outage time was reportedly
caused by nozzle plugging and cracking which resulted in the unit
operating at a reduced load for a short time in January. No
major FGD related problems were reported for February or March.
Deseret Generation and Transmission Coop announced plans during
the period for two new 410 MW (gross) units to be located in
Vernal, Utah. The units will be designated as Moon Lake 1 and 2,
and will burn coal with an average sulfur content of 0.5%.
Currently, the utility is requesting/evaluating bids for lime-
stone FGD systems to control S02 emissions from these two units.
Baghouses will be used for primary particle removal. The FGD
systems will operate in a closed water loop and the sludge
generated will be disposed of in an on-site landfill. The ex-
pected start up of Unit 1 is December 1984. The start up date of
Unit 2 is not finalized but is expected between 1987 and 1989.
Grand Haven Board of Light and Power announced that a contract
has been awarded to Babcock and Wilcox for the installation of a
lime FGD system at the new 81 MW (gross) J.B. Sims 3 unit. The
boiler, which will be located in Grand Haven, Michigan, will fire
coal with an average sulfur content of 2.75%. The FGD system
will include two 100% capacity spray towers preceded by a cold
side ESP for primary particle removal. Each spray tower will be
xix
-------
equipped with a chevron mist eliminator and an in-line hot water
reheater to boost the temperature of the flue gas before it exits
through a 360 foot stack. Initial start up of this unit is
expected in June 1983.
Michigan South Central Power Agency reported during the period
that a contract has been awarded to Babcock and Wilcox for a
limestone wet scrubbing system to control SO? emissions from the
new Project 1 unit. The 55 MW (gross) boiler, which will be
located in Litchfield, Michigan, will burn coal with an average
sulfur content of 2.25%. The SC>2 removal equipment will consist
of a spray tower system preceded by a hot side ESP for primary
particle removal. Initial start up of the system is expected in
July 1982.
A contract was awarded during the first quarter, 1980, to Re-
search Cottrell by Muscatine Power and Water for the installation
of a limestone FGD system at the new 166 MW (gross) Muscatine 9
unit. The Combustion Engineering boiler will burn coal with an
average sulfur content of 3.17%. The FGD system will consist of
three double loop combination towers, each with a spray tower
lower stage and a "wetted film contactor" grid type upper stage
(Research Cottrell design). Upstream of the FGD system will be
a cold side ESP for primary particle removal. The system will
operate in a closed water loop and the sludge will be disposed of
in a landfill. The expected start up date is September 1982.
Nevada Power reported that the Reid Gardner 2 FGD system had an
availability of 98% for all three months of the first quarter,
1980. Minor outages were reportedly caused by problems with the
emergency spray system and the malfunctioning of ID fan controls.
Nevada Power began requesting/evaluating bids during the period
for a system to control SO2 emissions from the new unit scheduled
for installation at the Reid Gardner station. The boiler will be
identified as Unit 4 and will burn coal with an average sulfur
content of 0.75%. Construction of the unit is expected to begin
sometime in 1980 and initial start up is scheduled for April
1983.
New York State Electric and Gas began requesting/evaluating bids
in February, 1980 for a limestone FGD system to be installed at
the new 870 MW (gross) Somerset 1 unit. The boiler will fire a
bituminous coal with an average sulfur content of 2.4%. The
limestone absorber will be designed for a 90% SC>2 removal effi-
ciency and will be preceded by a cold side ESP for particle
removal. The sludge generated will be dewatered and stabilized
before being landfilled. Expected start up of the system is June
1984.
xx
-------
At Sherburne 1 of Northern States Power the FGD system had
availabilities of 97%, 97%, and 98% for the months of January,
February, and March, respectively. The Sherburne 2 FGD system
had availabilities of 97%, 96%, and 98% for the same period. No
major FGD related problems were reported for either unit during
the first quarter and both boilers achieved the highest gross
generation to date in January.
Pennsylvania Power reported that the Bruce Mansfield 1 FGD system
had availabilities of 98% for all three months of the first
quarter, 1980. The Bruce Mansfield 2 availabilities were 97%,
94%, and 98% for January, February, and March, respectively. No
FGD related problems were reported for the three month period.
Philadelphia Electric announced during the period that construc-
tion has begun on the new magnesium oxide FGD system that is
being installed at the Eddystone 1 unit. Operation of the
prototype magnesium oxide system which treated one-third of the
flue gas from the coal fired boiler has been terminated. The SO-
removal equipment is being replaced with a similar magnesium
oxide system designed to treat 100% of the boiler flue gas. The
expected start up of the new system is December 1982. Current
regulations do not require the utility to control SC>2 emissions
from the Unit 1 boiler until the new FGD system is available for
operation.
Construction is also underway on the FGD system being installed
to control S02 emissions from the 334 MW (gross) Eddystone 2
boiler. This system will also be magnesium oxide and is being
supplied by United Engineers. Expected start up is scheduled for
December 1982.
Seminole Electric announced that contracts were awarded during
February, 1980 to Peabody Process Systems for the installation of
limestone FGD systems on the two new 620 MW (gross) Seminole 1
and Seminole 2 units located in Palatka, Florida. Each unit will
be a pulverized coal boiler firing coal with an average sulfur
content of 2.75%. Each FGD system will consist of five spray
towers preceded by two ESP's for primary particle removal. One
of the five modules for each system will be a spare. The ex-
pected start up dates for Units 1 and 2 are June 1983, and June
1985, respectively.
Tennessee Valley Authority announced that a contract has been
awarded to Riley Stoker/Environeering for the installation of a
magnesium oxide FGD system at the 1450 MW (gross) Johnsonville
power station located in New Johnsonville, Tennessee. The system
will consist of four venturi scrubber/absorber trains (one spare)
and sulfuric acid will be produced as a byproduct. The equiva-
lent of 600 MW of flue gas will be treated by the FGD system,
with the remaining 60% of the gas being bypassed for reheat.
Expected start up of this system is December 1981.
xx i
-------
Tennessee Valley Authority also announced during the period that
construction has begun on the FGD systems being installed on the
Paradise 1 and 2 boilers. Each FGD system will consist of six
trains, each train consisting of two Venturis in series, the
first for primary particle control and the second for primary SO2
removal. Inlet flue gas will be used to heat water, which in
turn will be used to reheat the outlet flue gas. The systems are
being supplied by Chemico and are expected to start up in March
1982, and June 1982, for Units 1 and 2, respectively.
Texas Municipal Power Agency announced that construction began
during the first quarter, 1980 on the FGD system being stalled at
the Gibbons Creek station. The system is being installed on
Unit 1, a new 400 MW (gross) boiler that will fire lignite with
an average sulfur content of 1.06%. The emission control system
will consist of a cold side ESP followed by three 50% capacity
limestone spray towers. Also included will be a chevron mist
eliminator and a steam coil reheat system downstream of each
spray tower. The unit is expected to begin operation in January
1982.
United Power Association announced during the period that a con-
tract has been awarded to Komline and Sanderson for the installa-
tion of a lime/spray drying FGD system at the new Stanton 2 unit.
The boiler, which will be located in Stanton, North Dakota, will
fire lignite with an average sulfur content of 0.77%. The FGD
system will consist of a spray dryer tower followed by a fabric
filter for the removal of the spent reagent and particulate
matter. The cleaned flue gas will exit to the atmosphere through
a 254 foot concrete stack. Expected start up of this unit is
January 1982.
Wisconsin Power and Light announced that plans for the installa-
tion of an FGD system at the Columbia 2 unit have been dropped.
The utility will be utilizing a low sulfur coal at this unit in
order to comply with the applicable SO- emission standard.
REFERENCE
a. U.S. Department of Energy. Energy Information Administra-
tion. Office of Energy Data Interpretation. Division of
Coal Power Statistics. Inventory of Power Plants in the
United States, April 1979. Pub. No. DOE/EIA-0095.
b. Rittenhouse, R.C. New Generating Capacity: When, Where,
and By Whom. Power Engineering 82(4):57. April 1978.
xxn
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
ALABAMA ELECTRIC COOP
TOMBIGBEE
TOMBIGBEE
ARIZONA ELECTRIC POWER COOP
APACHE
APACHE
ARIZONA PUBLIC SERVICE
CHOLLA
CHOLLA
CHOLLA
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
ASSOCIATED ELECTRIC COOP
THOMAS HILL
ATLANTIC CITY ELECTRIC
CUMBERLAND
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
ANTELOPE VALLEY
LARANIE RIVER
LARAMIE RIVER
LARA1IE RIVER
BIG RIVERS ELECTRIC
D.B. UILSOM
D.B. WILSON
SREEM
GREEN
CAJUN ELECTRIC POWER COOP
SIS CAJUN III
CENTRAL ILLINOIS LIGHT
DUCK CREEK
DUCK CREEK
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
CENTRAL ILLINOIS PUBLIC SERVIC
NEWTON
CENTRAL MAINE POWER
SEARS ISLAND
CENTRAL POWER S LIGHT
COLETO CREEK
CINCINNATI GAS ( ELECTRIC
EAST BEND
EAST BEND
UNIT
2
3
2
3
1
Z
t
1
2
3
4
5
3
1
1
2
1
2
3
1
2
1
2
1
1
2
1
2
1
2
1
2
NO. UNIT LOCATION
LEROY
LEROV
COCHISE
COCHISE
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARMIN6TON
FARHINGTON
FARMINGTON
FARHINGTON
FARMINGTON
MOBERLY
MILLVILLE
BEULAH
BEDLAM
WHEATLAND
WHEATLAND
WHEATLAND
SEBREE
SEBREE
DE SOTO PARISH
CANTON
CANTON
NEUTON
NEWTON
PENOBSCOT BAY
FANNIN
RABBITHASH
RABBITHASH
ALABAMA
ALABAMA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
MISSOURI
NEW JERSEY
NORTH DAKOTA
NORTH DAKOTA
WYOMING
UYOHING
WYOMING
KENTUCKY
KENTUCKY
LOUISIANA
ILLINOIS
ILLINOIS
ILLINOIS
ILLINOIS
MAINE
TEXAS
KENTUCKY
KENTUCKY
START-UP
DATE
9/78
6/79
8/78
6/79
10/73
4/78
6/81
11/79
11/79
11/79
0/82
0/82
1/82
1/88
4/83
10/8$
7/80
6/81
4/82
7/84
1/86
12/79
11/80
0/85
7/76
1/86
9/79
12/82
1/89
9/86
10/87
12/80
STATUS
1
1
t
1
1
1
2
1
1
1
3
3
2
6
2
5
1
2
2
3
3
1
2
6
1
5
1
7
6
6
6
2
REG
CLASS
B
B
t
D
C
C
C
C
C
C
C
C
A
C
D
C
C
C
C
A
A
B
B
A
B
A
B
A
A
A
B
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD. SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPSC6/79)
B. FEDERAL NSPSH2/71)
C. STAMDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARO(S) MORE STRINGENT THAN NSPSM2/71) BUT NOT MORE STRINGENT THAN NSPS<6/79>
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS(12/71>
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 198C
SECTION 1
LIST OF F&D SYSTEMS
COMPANY NAME/
UNIT NAME
COLUMBUS & SOUTHERN OHIO ELEC.
POSTON
POSTON
COMMONWEALTH EDISON
POWERTON
COOPERATIVE POWER ASSOCIATION
COAL CREEK
COAL CREEK
OELMARVA POWER K LIGHT
DELAWARE CITY
VIENNA
DESERET GENERATION g TRANS COO
MOON LAKE
MOON LAKE
DUOUESNE LIGHT
ELRAMA
PHILLIPS
EAST KENTUCKY POWER COOP
J. K. SMITH
J. K. SMITH
SPURLOCK
GENERAL PUBLIC UTILITIES
COHO
GILBERT
SCOTTSVILLE
SEWARD
WEHRUn
GRAND HAVEN BRD OF LIGHT K PUR
J. B. SIMS
HOOSIER ENERGY
MEROH
MEROM
HOUSTON LIGHTING g POWER co.
M.A. PARISH
INDIANAPOLIS POWER K LIGHT
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
KANSAS CITY POWER B LIGHT
HAWTHORN
HAWTHORN
LA CVGNE
KANSAS POWER K LIGHT
JEFFREY
JEFFREY
LAWRENCE
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
A. FEDERAL NSPS(£/79)
B. FEDERAL NSPSM2/71)
C. STANDARDCS) MORE STRINGENT
D. STANDARD**) MORE STRINGENT
UNIT NO. UNIT LOCATION
5
6
51
1
2
1-3
9
1
2
1-4
1-6
1
2
2
1
1
1
7
1
3
1
2
8
1
2
3
3
4
3
4
1
1
2
4
4.
5.
6.
7.
THAN
THAN
NELSONVILLE
NELSONVILL?
PERKIN
UNDERWOOD
UNDERWOOD
DELAWARE CITY
VIENNA
VERNAL
VERNAL
ELSAMA
SOUTH HEIGHT
MAYSV1LLE
GIRARD TWP.
MILFORD
SCOTTSVILLE
OHIO
OHIO
ILLINOIS
NORTH DAKOTA
NORTH DAKOTA
DELAWARE
MARYLAND
UTAH
UTAH
PENNSYLVANIA
PENNSYLVANIA
KENTUCKY
PENNSYLVANIA
NEW JERSEY
PENNSYLVANIA
E. WHEATFIELD TPENNS YLVANI A
WEHHUM
GRAND HAVEN
SULLIVAN
SULLIVAN
BOOTH
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
KANSAS CITY
KANSAS CITY
LA CYGNE
WAMEGO
WAMEGO
LAURENCE
PLANNED - LETTER OF
PENNSYLVANIA
MICHIGAN
INDIANA
INDIANA
TEXAS
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
MISSOURI
MISSOURI
KANSAS
KANSAS
KANSAS
KANSAS
START-UP
DATE
8/86
0/bO
4/8?
8/79
7/8D
4/60
6/87
12/84
0/88
10/75
7/73
1/85
1/87
1/81
12/88
0/91
0/91
5/87
0/95
6/81
5/82
7/81
11/82
0/87
0/87
0/87
12/77
10/84
11/72
8/72
2/73
8/78
4/85
1/76
STATUS
6
6
2
1
2
2
6
5
5
1
1
6
6
2
6
6
6
6
6
3
3
2
3
6
6
6
1
2
1
1
1
1
2
1
HEG
CLASS
D
D
E
B
B
E
A
A
A
D
D
A
A
B
A
A
A
A
A
A
B
B
A
C
C
C
B
B
D
D
E
D
D
D
INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING FGD SYSTEMS;
NSPS<6/79)
NSPS(13/71) BUT NOT
MORE STRINGENT
ALSO ALTERNATIVE
THAN NSPS
•6/79)
METHODS
E. STANDARD(S) EguAL TO OR LESS STRINGENT THAN NSPSC12/71)
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY
UNIT
NAME/
NA*t
UNIT NO. UNIT LOCATION
START-UP REG
DAT^ STATUS CLASS
KANSAS POWER t. LIGHT
LAWRENCE
KENTUCKY UTILITIES
GREEN RIVER
LAKELAND UTILITIES
MCINTOSH
LAWfc EMCE
KANSAS
LOUISVILLE G«S
CANE RUN
CANE RUN
CANE RUN
MILL CREEK
WILL CREEK
HILL CREEK
MILL CREEK
PADDY'S RUN
& ELECTRIC
TS1»BLE
TR li»3LE
C PUNT*
COUNTY
"1CHIGAN SO.
PROJECT
CENTRAL PWR
"I1DDLE SOUTH UTILITIES
ARKANSAS COAL
ARKANSAS COAL
LOUISIANA COAL
LOUISIANA COAL
MISSISSIPPI COAL
MISSISSIPPI COAL
MINNESOTA POWER *• LIGHT
CLAY B OS * ELL
KI1NNKOTA POWER COOPERATIVE
MILTON R. YPUNG
MONTANA POWER
COLSTR1P
COLSTR1P
COLSTRIP
COLSTR1P
"IUSCATINE POWER * WATER
MUSCATINE
NEVADA POWER
HARRY ALLEN
HARRY ALLEN
HARRY ALLFN
HARRY ALLEN
REID GARDNER
REID GARDNER
REID GARDNER
REID GARDNER
WARNER VALLEY
VALLEY
CENTSAL CITY KENTUCKY
LAKELAND
LCUISVILLf
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
BEDfCKD
B t 0 F 0 h D
LITCHFIELO
COHA'SET
CENTf
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
MUSCMINE
FLORIDA
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUC KY
KENTUCKY
KENTUCKY
KENTUC KY
MICHIGAN
MISNE SOTA
NORTH DAKOTA
MONTANA
MONTANA
MONTANA
MONTANA
IOWA
N.F. LAS VEGAS NEVADA
N.F. LAS VEGAS NEVADA
N.f. LAS VEGAS NEVADA
N.c. LAS VEGAS NEVADA
MOAPA NEVADA
MOAPA NEVADA
MOAPA NEVADA
MOAPA NEVADA
ST. GEORGE UTAH
ST. GEORGE UTAH
11/71
9/75
1C/c1
8/76
zn~>
4/79
4/ei
4/e?
8/7?
7/E1
4/73
7/64
7/tf
1
1
1
2
t.
1
2
1
6
6
D
D
D
E
E
D
B
E
A
A
7/c'
ARKANSAS
ARK AN; «s
LOUIS I ANA
LOUIS I *NA
MISSISSIPPI
MISSISSIPPI
1/bf
1/£q
r/f-6
0/6B
C/£?
C'/c7
5
C
C
t
5
5
4/fcC
9/77
9/75
5/76
1/64
C/84
6/c6
6/8?
6/8?
t/89
4/74
4/74
6/76
4/e3
6/a5
1. OPERATIONAL UNITS
?. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTFNT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/7?)
B. FEDERAL NSPSCI2/71)
C. STINDARD(S) "ORE STRINGENT THAN NSPS<6/79)
D. STANDARDS) MORE STRINGENT THAN NSPS<1?/71) BUT NOT MORE STRINGENT THAN NSPS<6/79)
E. STANDARD(S) ?OUAL TO OR LESS STRINGENT THAN NSPSM2/71)
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 1
SUMMARY LIST Of Ft,D SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP
DATE
SEfc
STATUS CLASS
NEW YORK STATE ELEC 8 GAS
SOMERSET 1
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
SCHAHFER 17
SCHAHFE" 18
NORTHERN STATES POWER
RIVERSIDE 6,7
SHERBURNE 1
SHERBURNE 2
SHERBURNE 3
OTTER TAIL POWER
COYOTE 1
PACIFIC GAS * ELECTRIC
MONTEZUMA 1
MONTEZUMA 2
PACIFIC POWER R LIGHT
JIM BRIDGES 4
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
BRUCE MANSFIELD 2
BRUCE MANSFIELD 3
PHILADELPHIA ELECTRIC
CROMBY
EDDYSTONE 1A
EDDYSTONE IB
EDDYSTONE 2
POTOMAC ELECTRIC POWER
DICKERSON 4
PUBLIC SERVICE INDIANA
GIBSON 5
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
SAN JUAN 4
PWR AUTHORITY OF STATE OF NY
FOSSIL
SALT RIVER PROJECT
CORONADO 1
CORONADO 2
CORONADO 3
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SOMERSET
BUFFALO
GARY
WHEATFIELD
WHEATfIELD
MINNEAPOLIS
BECKER
BECKER
BECKER
BEULAH
COLLINSVILLE
COLLINSVILLE
ROCK SPRINGS
SHIPPINGPORT
SHIPPINGPORT
SHIPPINGPORT
PHOENIXVILLE
EDDYSTONE
ECDYSTONE
EDDYSTONE
DICKERSON
PRINCETON
WATERFLOW
WATERFLOW
yATERFLOU
WATERFLOW
NEW YORK
ST. JOHNS
ST. JOHNS
ST. JOHNS
SAN MIGUEL
NEW YORK
NEW YORK
INDIANA
INDIANA
INDIANA
MINNESOTA
MINNESOTA
MINNESOTA
MINNESOTA
NORTH DAKOTA
CALIFORNIA
CALIFORNIA
WYOMING
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
MARYLAND
INDIANA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW M5XICO
NEW YORK
ARIZONA
ARIZONA
ARIZONA
TEXAS
6/84
7/76
6/83
6/65
7/80
3/76
4/77
5/84
3/61
6/67
6/68
1
4
4
2
1
1
5
2
6
e
E
A
A
E
D
D
C
E
C
C
9/79
12/75
7/77
10/8?
9/75
12/82
12/fc2
5/87
0/82
4/78
8/7P
12/79
6/62
11/87
11/79
7/80
6/87
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REOUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSM2/71)
C. STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARD(S) WORE STRINGENT THAN NSPSC12/71) BUT NOT MORE STRINGENT THAN NSPS(6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS(1?/71)
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
SE11NOLE ELECTRIC
SEM1NOLE
SEMINOLE
UNIT
1
2
NO. UNIT LOCATION
PALATKA FLORIDA
PALATKA FLORIDA
START-UP
DATE
3/83
3/85
REG
STATUS CLASS
3 A
3 A
SIKESTON BOARD OF MUNIC. UTIL.
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 2
WINYAH 3
WINYAH 4
SIKESTON MISSOURI 1/81
GEORGETOWN SOUTH CAROLINA 7/77
GEORGETOWN SOUTH CAROLINA 5/80
GEORGETOWN SOUTH CAROLINA 7/81
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW 1
R.D. MORROW 2
HATTISBURG
NATTISBURG
MISSISSIPPI
MISSISSIPPI
8/78
6/79
SOUTHERN ILLINOIS POWER COOP
MARION
MARION
SOUTHERN INDIANA GAS & ELEC
A.B. BROUN
MARION
MARION
ILLINOIS
ILLINOIS
WEST FRANKLIN INDIANA
5/79
0/66
4/79
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEV 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
HALLSVILLE
TEXAS
SPRINGFIELD MISSOURI
12/84
4/77
SPRINGFIELD WATER, LIGHT & PWR
DALLMAN 3
ST. JOE ZINC
G.F. WEATON 1
SPRINGFIELD ILLINOIS
MONACA
11/80
PENNSYLVANIA 11/79
TAMPA ELECTRIC
BIG BEND 4
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE 1-10
PARADISE 1
PARADISE 2
SHAWNEE 10A
SHAWNEE 106
WIDOWS CREEK 7
WIDOWS CREEK 8
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
TEXAS POWER t LIGHT
SANDOy 4
TWIN OAKS 1
TWIN OAKS 2
TEXAS UTILITIES
FOREST GROVE 1
MARTIN LAKE 1
MARTIN LAKE 2
MARTIN LAKE 3
MARTIN LAKE 4
1. OPERATIONAL UNITS 4.
2. UNITS UNDER CONSTRUCTION 5.
3. PLANNED - CONTRACT AWARDED 6.
7.
TAMPA
FLORIDA
NEW JOHNSONVILLTENNESSEE
PARADISE
PARADISE
PADUCAH
PADUCAH
BRIDGEPORT
BRIDGEPORT
CARLOS
ROCKDALE
BREMOND
BREMOND
ATHENS
TATUM
TATUM
TATUM
TATUN
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
ALABAMA
ALABAMA
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
3/85
12/81
3/82
6/82
4/72
4/72
9/81
5/77
1/82
7/80
8/84
8/85
0/81
4/77
5/78
2/79
0/85
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING F6D SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPSC6/79)
B. FEDERAL NSPSH2/71)
C. STANDARDS) MORE STRINGENT THAN NSPSC6/79)
D. STANDARDS) MORE STRINGENT THAN NSPS<12/71> BUT NOT MORE STRINGENT THAN NSPSJ6/79)
E. STANDARDS) EQUAL TO OR LESS STRINGENT THAN NSPS<12/71>
-------
EPA UTILITY F60 SURVEY: JANUARY - MARCH 198C
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP
DATE
REG
STATUS CLASS
TEXAS UTILITIES
MILL CREEK
MILL CREEK
MONTICELLO
TUCSON ELECTRIC POWER
SPRINGERVILLE
SPRINGERVILLE
UNITED POWER ASSOCIATION
STANTON
UTAH POWER K LIGHT
HUNTER
HUNTER
HUNTER
HUNTER
HUNT1NGTON
HENDERSON
HENDERSON
MT. PLEASANT
SPRINGERVILLE
SPRINGERVILLE
STANTON
CASTLE DALE
CASTLE DALE
CASTLE DALE
CASTLE DALE
PRICE
TEXAS
TEXAS
TEXAS
ARIZONA
ARIZONA
NORTH DAKOTA
UTAH
UTAH
UTAH
UTAH
UTAH
C/85
0/86
5/78
6/65
1/87
1/62
5/79
6/8P
0/83
0/85
5/78
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SI6NED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY F6D SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSC12/71)
C. STANDARDS) MORE STRINGENT THAN NSPS<6/79>
D. STANDARDS) MORE STRINGENT THAN NSPS<12/71> BUT NOT MORE STRINGENT THAN NSPS<6/79>
E. STANOARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS<12/71>
-------
EPA UTILITY fGO SURVEY: JANUARY - MARCH 1980
SECTION 2
STATUS Of FGO SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
ALABAMA ELECTRIC COOP
TOMBIGBEE
2
HEW 255.0 MU (GROSS)
179.0 MU (ESC)
COAL
1.15 US BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3. IX
STATUS 1 STARTUP 9/78
TOMBIGBEE 2 OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA. THE BOILER GENERATES A MAXIMUM FLUE GAS FLOW OF 953.OCO
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.ZX AND
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB. THE UNIT SO? EMMISSION LIMITA-
TION VALUE IS 1.2 LB/HMBTU. PRIMARY PARTKULATE MATTER CONTROL JS PROVID-
ED BY A HOT SIDE ESP. THE S02 REMOVAL EOUIPMENT CONSISTS OF TWO SPRAY
TOWERS SUPPLIED BY PEABODV PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REA-
GENT. A CHEVRON MIST ELIMINATOR IS INCLUDED FOR EACH TOWER AND THE FLUE
GAS is REHEATED WITH BYPASSED GAS BEFORE BEING VENTED TO A too FOOT ACID-
BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE AND
SPENT ABSORBENT IS DISPOSED OF IN AN ON-SITE LINED POND.
ALABAMA ELECTRIC COOP
TOMBIGBEE
3
MEW 255.0 MU (GROSS)
179.P MU (ESC)
COAL
1.15 ZS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3. IX
STATUS 1 STARTUP 6/79
TCMBI66EE 3 OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA. THE BOILER GENERATES A MAXIMUM FLUE GAS FLOW OF 953,OCO
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.2X AND
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB . THE UNIT SO? EMISSION LIMITATION
VALUE IS 1.2 LB/MMBTU. PRIMARY PARTICULATE CONTROL IS PROVIDED BY A HOT
SIDE ESP. THE S02 REMOVAL EQUIPMENT CONSISTS OF TWO SPRAY TOWERS SUPPLIED
BY PEABODY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REAGENT. A CHEVRON
MIST ELIMINATOR IS INCLUDED IN EACH TOWER, AND THE FLUE GAS IS REHEATED
WITH BYPASSED GAS BEFORE BEING VENTED TO A 400 FOOT ACID BRICK LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE, AND SPENT ABSORBENT
IS DISPOSED IN AN ON-SITE LINED POND.
ALLEGHENY POWER SYSTEM
1ITCHELL
33
RETROFIT 300.0 MU (GROSS)
300.0 MU (ESC)
COAL
2.80 XS BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: 1.U
STATUS 3 STARTUP 8/82
UNIT 33 AT ALLEGHENY POWER SYSTEM'S MITCHELL POWER STATION IN COURTNEY,
PENNSYLVANIA IS A 2.8X SULFUR COAL FIRED BOILER. A CONTRACT WAS
AWARDED TO CHE*!C0 FOR A LIME SCRUBBING PROCESS. S02 REMOVAL
EFFICIENCY WILL BE 9SX. START UP IS PLANNED FOR AUGUST OF 1982.
ALLEGHENY POWER SYSTEM
PLEASANTS
1
NEW 625.0 MU (GROSS)
519.P MU (ESC)
COAL
3.70 XS BITUMINOUS
LIME
BABCOCK S WILCOX
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 3/79
ALLEGHENY POUER SYSTEM'S PLEASANTS 1 IS A BITUMINOUS COAL (3.7CZ S. 12.150
BTU/LB) FIRED BOILER IN BELMONT, WEST VIRGINIA. BABCOCK ANO UlLCOK SUP-
PLIED A LIME FGD SYSTEM DESIGNED TO REMOVE 90* OF THE FLUE GAS SO? FROM
THIS UNIT. THE EMISSION CONTROL SYSTEM INCLUDES AN ESP UPSTREAM OF FOUR
SPRAY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM PROVIDES REHEAT OF THE
CLEANED GAS BEFORE IT IS DISCHARGES THROUGH A 1?00 FOOT PLAC1TE LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGD SYSTEM ON THIS
UNIT HAS BEEN OPERATIONAL SINCE MARCH OF 1979.
ALLEGHENY POUER SYSTEM
PLEASANTS
2
KEU 625.0 MU (GROSS)
519.0 MU (ESC)
COAL
4.50 XS BITUMINOUS
LIME
aABcOcK ( WILCOX
ENERGY CONSUMPTION: *•**»
STATUS I STARTUP 9/80
ALLEGHENY POUER SYSTEM'S PLEASANTS 2 IS A BITUMINOUS COAL (3.7X S, 12,150
BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN BELMONT, WEST VIRGINIA. BABCOCK
AND UILCOX IS SUPPLYING A LIME FGD SYSTEM DESIGNED TO REMOVE 9OX OF THE
BOILER FLUE GAS S02. THE EMISSION CONTROL SYSTEM ON THIS UNIT WILL INCLUDE
AN ESP UPSTREAM OF FOUR SPRAY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM
WILL PROVIDE REHEAT OF THE CLEANED GAS BEFORE IT IS DISCHARGED THROUGH A
1200 FOOT PLACITE LINED STACK. THE SYSTEM UILL OPERATE IN AN OPEN WATER
LOOP. FGD SYSTEM START UP IS EXPECTED IN SEPTEMBER, 1980.
ARIZONA ELECTRIC POUER COOP
APACHE
2
MEW 195.0 MU (GROSS)
195.0 MU (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 4.11
STATUS 1 STARTUP 8/78
APACHE 2 OF ARIZONA ELECTRIC POUER COOP IS LOCATED IN COCH1SE. ARIZONA AND
IS A DRV BOTTOM PULVERIZED COAL FIRED UNIT WITH A FLUE GAS FLOW OF 735,000
ACFN. BITUMINOUS COAL UITH A HEATING VALUE OF 10.000 BTU/LB, A SULFUR CON-
TENT Of 0.7X AND AN ASH CONTENT OF 15* IS THE FUEL USED (OR THIS UNIT.
PARTICULATE CONTROL IS EFFECTED BY A HOT SIDE ESP. THE UNIT IS CURRENTLY
IN OPERATION UITH STARTUP IN AUGUST 1978. TUO PACKED TOWERS EMPLOYING
LIMESTONE ABSORBENT AND HAVING A DESIGN S02 REMOVAL OF 85* WERE SUPPLIED
Bt RESEARCH COTTRELL. MIST ELIMINATION IS PROVIDED BY CHEVRON TYPE ELIMI-
NATORS. NO REHEAT is EMPLOYED. A too FT COLE BRAND CXL2000 LINED STACK is
IN USE. THE SYSTEM OPERATES IN AN OPEN UATER LOOP MODE AND WASTE MATERIAL
IS DISPOSED OF IN OFF-SITE SLUDGE PONDS.
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 1980
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZONA ELECTRIC POWER COOP
APACHE
3
HEW 195.0 MW (CROSS)
195.0 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 4.11
STATUS 1 STARTUP 6/79
ARIZONA PUBLIC SERVICE
CHOLLA
1
RETROFIT 119.0 MW (GROSS)
119.C MU (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 3.4X
STATUS 1 STARTUP 10/73
APACHE 3 OF ARIZONA ELECTRIC POWER COOP IS A DRY BOTTOM, PULVERIZED COAL
FIRED UNIT IN COCHISE. ARIZONA. LOW (0.72) SULFUR BITUMINOUS COAL WITH AN
AVERAGE HEATING VALUE OF 10,000 BTU/L.B PRODUCES A MAXIMUM FLUE GAS FLOW OF
735,000 ACFM. THE FLUE GAS PASSES THROUGH A HOT SIDE ESP TO TWO RESEARCH
COTTRELL PACKED TOWERS, WHERE LIMESTONE IS USED TO REMOVE B5X (DESIGN) Or
THE S02. THE GAS EXITS A HORIZONTAL CHEVRON MIST ELIMINATOR INTO ITS OWN
CEILCOTE LINED FLUE IN THE 400 FOOT STACK IT SHARES WITH UNIT 2. THE f&O
WHICH HAS BEEN OPERATIONAL SINCE JUNE. OF 1979, USES NO REHEAT. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP AND SLUDGE IS DISPOSED OF IN TWO OFF SITE
LINED PONDS WITH 20 YEARS' EXPECTED LIFESPAN. TWO ADDITIONAL PONDS ARE
PLANNED, WHICH WOULD ADD ANOTHER ?0 YEARS* CAPACITY.
ARIZONA PUBLIC SERVICE'S CHOLLA 1 IS LOCATED IN JOScPH CITY, ARIZONA AND
IS A TAN6ENTIALLV FIRED, W£T BOTTOM PULVERIZED COAL UNIT. IT IS FUELED BY
BITUMINOUS COAL THAT HAS A SULFUR CONTENT OF C.5X AND A HEATING VALUE OF
10,150 BTU/LB. PARTICULATE MATTER IS CONTROLLED BY TWO FLOODED DISC SCRUB-
BERS. THE FGD SYSTEM BEGAN IN OCTOBER, 1973 AND IS NOW OPERATIONAL. 502 js
CONTROLLED BY ONE TOWER WITH MUNTERS PACKING EMPLOYING A LIMESTONE
ABSORBENT. THE UNIT WAS SUPPLIED BY RESEARCH COTTRELL AN 0 HAS A DESIGN
REMOVAL OF 921. CHEVRON MIST ELIMINATORS ARE LOCATED PRIOR TO AN IN-LINE
STEAM REHEAT SYSTEM. THE TREATED FLUE GAS IS VENTED TO A 256 FT ACID BRICK
LINED STACK. THE FGD SYSTEM OPERATES IN AN OPEN WATER LOOP MODE AND THE
UNTREATED WASTE IS DISPOSED OF IN AN ON-SITE UNLINED POND.
ARIZONA PUBLIC SERVICE
CHOLLA
2
NEW 350.0 «W (GROSS)
350-0 Mw (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: •**.»
STATUS 1 STARTUP 4/78
CHOLLA ? OF ARIZONA PUBLIC SERVICE IS LOCATED IN JOSEPH CITY, ARIZONA. THE
BOILER BURNS PULVERIZED BITUMINOUS COAL (0.5X S, 10,150 BTU/LB). MECHANI-
CAL COLLECTORS PROVIDE PRIMARY PARTICULATE CONTROL. FOUR PARALLEL
FLOODED DISC AND PACKED TOWER S02 ABSORBER TRAINS (THREE ARE REQUIRED FOR
FULL LOAD) REMOVE THE FLUE GAS SO?. THE DESIGN SO? REMOVAL FOR THE
SYSTEM, WHICH BEGAN OPERATIONS IN APRIL, 1978, IS 75X. THE CLEANED GAS
PASSES THROUGH AN IN-LINE STEAM REHEATER INTO AN ACID BRICK LINED STACK.
THE OPEN WATER LOOP SYSTEM DEPOSITS ITS SLUDGE INTO A FLY ASH POMC.
ARIZONA PUBLIC SERVICE
CHOLLA
t
NEW 3SO.O MW (GROSS)
126.0 MW (ESC)
COAL
.50 XS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: »**«X
STATUS 2 STARTUP 6/80
CHOLLA 4 OF ARIZONA PUBLIC SERVICE IS PRESENTLY UNDER CONSTRUCTION IN
JOSEPH CITY, ARIZONA. START UP IS SCHEDULED FOR JUNE, 1960. THE PULVERIZFA
COAL (0.5X S, 10,150 BTU/LB) FIRED BOILER WILL EXHAUST FLUE GAS THROUGH AN
ESP TO A PACKED TOWER WHICH WILL TREAT 36X OF THE GAS WITH LIMESTONE.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT 175.0 MW (GROSS)
175.0 MW (ESC)
COAL
.75 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
CHEMICO
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1. 2. AND 3 IN FARHIN6TON, NEW MEXICO TO HANDLE ADDITIONAL
SO? REMOVAL. INITIALLY, THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 9650 BTU/LB) UNITS 1 AND 2 SUPPLY 814,000 ACFM EACH
INTO 2 CHENICO VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICULATE CONTROL
AND APPROXIMATELY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN SO?
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67.5X. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
RETROFIT 175.0 MW (GROSS)
175.0 MU (ESC)
COAL
.75 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
CHEMICO
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1,2, AND 3 IN FARMIN6TON, NEW MEXICO TO HANDLE ADDITIONAL
SO? REMOVAL. INITIALLY, THE FRONT FIRED, DRV BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 8650 BTU/LB) UNITS 1 AND 2 SUPPLY 814,000 ACFM EACH
INTO ? CHEMICO VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICULATE CONTROL
AND APPROXIMATELY 301 S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN SO?
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67.SX. OPERATIONS COMMENCED IN NOVEMBER, 1979.
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION i
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZONA PUBLIC SERVICE
FOUR CORNERS
J
RETROFIT 229." MU (GROSS)
229.0 MW (ESC)
COAL
.75 ZS SUBBITUMINOUS
LIME/ALKALINE FLYASM
CHEMICO
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PART1CULATE SCRUBBERS
AT FOUR CORNERS 1,2. AND * IN FARMIN6TON, NEW MEXICO TO HANDLE ADDITIONAL
S02 REMOVAL. INITIALLY, THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUE-
BITUMINOUS, 0.75X S, 8650 BTU/LB) UNIT 3 SUPPLIES 1,030,0*0. ACfM INTO 2
CHEMICO VfNTURl SCRUBBERS FOR PRIMARY PARTICIPATE CONTROL AND APPROXIMATE-
LY 301 502 REMOVAL USING ALKALINE FLY ASH. THE DESIGN SO^ REMOVAL EFFICI-
ENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH SCRUBBING IS 6?.5Z.
OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
4
RETROFIT 7SS.O MW (GROSS)
755.0 MW
COAL
.75 XS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 0/82
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO UNITED ENGINEERS FOR A LIME
FGD SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND 5 AT ITS FOUR CORNERS STA-
TION IN FARMIN6TON, NEW MEXICO. BASED ON THE PROTOTYPE HORIZONTAL SCRUB-
BING PROGRAM CONDUCTED BY THE UTILITY, A HORIZONTAL SYSTEM WAS CHOSEN TO
CONTROL THE EMISSIONS FROM THESE COAL (0.75X S, 6650 BTU/LB) FIRED UNITS.
THE PARTKULATE EMISSIONS ARE HANDLED BY AN ESP. START UP IS EXPECTED IN
1982.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5
RETROFIT 755.0 MW (GROSS)
755.0 MW (ESC>
COAL
.75 XS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 0/82
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO UNjTED ENGINEERS FOR A LIME
FGD SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND 5 AT ITS FOUR CORNERS STA-
TION IN FARM1NGTON, NEy MEXICO. BASED ON THE PROTOTYPE HORIZONTAL SCRUB-
BING PROGRAM CONDUCTED BY THE UTILITY, A HORIZONTAL SYSTEM WAS CHOSEN TO
CONTROL THE EMISSIONS FROM THESE COAL (0.75* S, 8650 BTU/LB) FIRED UNITS.
THE PARTICULATE EMISSIONS ARE HANDLED BY AN ESp. START UP IS EXPECTED IN
1982.
ASSOCIATED ELECTRIC COOP
THOMAS HILL
3
NEW 730.C MW (GROSS)
670.0 MW (ESC)
COAL
4.80 ZS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 1/82
THOMAS HILL 3 OF ASSOCIATED ELECTRIC COOP IS A PULVERIZED COAL (A.8Z S,
9,700 BTU/LB) FIRED UNIT LOCATED IN MOBERLY, MISSOURI. TWO COLD SIDE fSP'S
WILL PRECEDE THE FOUR 91.51 EFFICIENT PULLMAN KELLOGG HORIZONTAL WEIR FGD
MODULES USING MAGNESIUM-PROMOTED LIMESTONE AS THE ABSORBENT. THE CLEANED
GAS WILL PASS THROUGH A VERTICAL CHEVRON MIST ELIMINATOR TO A 620 FOOT
BRICK LINED STACK. REHEAT WILL BE ACCOMPLISHED BY BYPASS. DRY FIXATED
SLUDGE WILL BE TRUCKED TO AN ACTIVE STRIP MINE. THE SYSTEM WILL USE A
CLOSED WATER LOOP. THE FGO SYSTEM IS UNDER CONSTRUCTION AND START UP IS
EXPECTED IN JANUARY, 1982.
9ASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
1
NEW 440.C MW (GROSS)
440.0 MW (ESC)
COAL
.68 XS LIGNITF
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 4/82
UNIT 1 Of BASIN ELECTRIC POWER COOP'S ANTELOPE VALLEY PLANT IS PRESENTLY
UNDER CONSTRUCTION IN BEULAH, NORTH DAKOTA. THIS UNIT WILL BURN PULVERIZED
COAL (0.68X S, 6600 BTU/LB LIGNITE) AND SUPPLY 2,055,000 ACFH TO A DRY
LIME FGD SYSTEM SUPPLIED BY WESTERN PRECIPITATION. THE 62X EFFICIENT
SYSTEM WILL CONSIST OF 5 NIRO ATOMIZER SPRAY DRYERS AND TWO BAGHOUSES.
THE CLEANED GAS, ALONG WITH A 4X BYPASS REHEAT, WILL EXIT A 600 FOOT
PVC LINED STACK. THE SYSTEM WILL USE A CLOSED WATER LOOP AND THE DRY
POWDER WILL BE USED FOR LANDFILL IN A COAL MINE. START UP IS EXPECTED
IN APRIL, 1982.
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
2
NEW 440.0 MW (GROSS)
440.0 MW
COAL
.68 XS LIGNITE
LIME/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: .OX
STATUS 5 STARTUP 4/84
ANTELOPE VALLEY 2 OF BASIN ELECTRIC POWER COOP WILL BE LOCATED IN BEULAH,
NORTH DAKOTA. THE UTILITY IS PRESENTLY CONSIDERING VARIOUS FGD PROCESSES
FOR THIS LIGNITE (0.68X S, 6600 BTU/LB) FIRED UNIT. THE UNIT WILL BE
REQUIRED TO COMPLY WITH STATE EMISSIONS STANDARDS VIA BEST AVAILABLE
CONTROL TECHNOLOGY. START UP IS SCHEDULED FOR APRIL, 1964.
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION Z
STATUS OF fGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
BASIN ELECTRIC POWER COOP
LARANIE RIVER
1
NEW 570.C MW (GROSS)
600.0 MW (ESC)
COAL
.81 2S SUBBITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 4/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 1 IS PRESENTLY UNDER CONSTRUC-
TION IN WHEATLANO, WYOMING. THE PULVERIZED CO»L (0.81t S, 8139 BTU/LB)
FIRED BOILER HILL FEED 2,300.000 ACFM OF FLUE GAS THROUGH A COLD 5IDE
ESP TO FIVE RESEARCH COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH WILL
REMOVE 90X Of THE S02. THE CLEANED GAS WILL EXIT FROM A VERTICAL CHEVRON
DEMISTER INTO A 600 FOOT ACID BRICK LINED STACK. NO REHEAT WILL BE USED.
THE FLYASH FIXATED SLUDGE WILL BE DEwATERED TO "3X SOLIDS BEFORE PE1NG
LANDFILLED, AND THE SYSTEM WILL EMPLOY A CLOSED WATER LOOP. START UP IS
SCHEDULED FOR APRIL, 198C.
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
2
NEW 570.0 MW
600.0 MW USO
COAL
.81 IS SUBBITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 11/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 2 IS PRESENTLY UNDER CONSTRUC-
TION IN WHEATLAND, WYOMING. THE PULVERIZED COAL (D.81X S, 8139 BTU/LB)
FIRED BOILER WILL FEED 2,300,000 ACFN OF FLUE GAS THROUGH A OLD SIDE
ESP TO FIVE RESEARCH COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH WILL
REMOVE 90X Of THE S02. THE CLEANED GAS WILL EXIT FROM A VERTICAL CHEVRON
DEMISTER INTO A 600 FOOT ACID BRICK LINED STACK. NO REHEAT WILL BE USED.
THE FLYASH FIXATED SLUDGE WILL BE DEWATERED TO P3X SOLIDS BEFORE BEING
LANDFILLED, AND THE SYSTEM WILL EMPLOY A CLOSED WATER LOOP. START UP IS
SCHEDULED FOR NOVEMBERt 1980.
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
3
NEW 570.C MW
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH I960
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
BIG DIVERS ELECTRIC
SREEN
2
NEW 242.0 MW (GROSS)
242.C MU (ESC)
COAL
3.75 XS BITUMINOUS
LIKE
AMERICAN AIR FILTER
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 11/80
UNIT 2 OF BIG RIVERS ELECTRlC'S GREEN STATION IS BEING CONSTRUCTED IN
SEBREE, KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75X S, 9750 BTU/LB)
FIRED BOILER WILL SUPPLY 1,000.000 ACFM TO A COLO SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH WILL REMOVE 90* Of THE
S02. THE CLEANED GAS WILL PASS THROUGH A CHEVRON MIST ELIMINATOR AND
WILL EXIT A SAUERISEN 72 LINED STACK AfTER IT IS HEATED BY STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM U1LL BE POZ-0-TEC
STABILIZED. START UP IS SCHEDULED FOR NOVEMBER, 19fa0.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
NEW 416.0 MH (GROSS)
378.0 MU (ESC)
COAL
3.30 IS BITUMINOUS
LIMESTONE
RILEY STOKER/ENVIRONEERING
ENERGY CONSUMPTION: 2.9*
STATUS 1 STARTUP 7/76
DUCK CREEK 1 OF CENTRAL ILLINOIS LIGHT IS LOCATED IN CANTON, ILLINOIS. THE
BALANCED DRAFT, FRONT FIRED, DRY BOTTOM UNIT BURNS PULVERIZED BITUMINOUS
COAL (3.3* S. 10,500 BTU/LB) AND SUPPLIES 2,415,000 ACFM OF FLUE GAS TO
TWO COLO SIDE ESP'S FOLLOWED BY FOUR RILEY STOKER/ENVIRONEERING ROD DECK
SPRAY TOwER MODULES. THE FGD SYSTEM HAS BEEN OPERATIONAL (ONE MODULE)
SINCE JULY, 1976, AND IS DESIGNED TO REMOVE 85X OF THE SO?. HORIZONTAL
CHEVRON MIST ELIMINATORS FOLLOW THE ABSORBERS, AND THE CLEANED GAS EXITS
TO A 500 FOOT CEILCOTE LINED STACK WITHOUT REHEAT. THE SYSTEM OPERATES IN
A CLOSED WATER LOOP. AND THE SLUDGE IS DISPOSED OF IN AN ON SITE CLAY
LINED POND.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
2
NEW 450.0 MW (GROSS)
416.0 MU (ESC)
COAL
3.3? ZS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTIONr *••*»
STATUS 5 STARTUP 1/86
CENTRAL ILLINOIS LIGHT IS CURRENTLY EVALUATING BIDS ON A LIMESTONE OR DUAL
ALKALI FGD SYSTEM FOR UNIT 2 OF ITS DUCK CREEK STATION. THE BITUMINOUS
COAL FIRED BOILER WILL FEED ITS FLUE GAS THROUGH A COLD SIDE ESP. THE
SYSTEM WILL OPERATE IN A CLOSED WATER LOOP AND IS SCHEDULED TO BEGIN
OPERATIONS IN JANUARY, 1986.
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
NEW 617.0 MU (GROSS)
617.0 MU (ESC)
COAL
2.25 XS BITUMINOUS
DJAL ALKALI
3UELL/ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 9/79
NEWTON 1 OF CENTRAL ILLINOIS PUBLIC SfRVICE 1$ A TANGENTlALLY FIRED, DRV
BOTTOM, PULVERIZED BITUMINOUS COAL U* S, 10,900 RTU/Lb) FIRED UNIT
LOCATED IN NEWTON, ILLINOIS. A COLD SIDE ESP RECEIVES 2,163,480 ACFM
OF FLUE GAS AND FEEDS IT TO FOUR BUELL ENV1ROTECH POLYSPHERE PACKED
TRAY TOWERS FOLLOWED BY TWO VERTICAL MJST ELIMINATORS PER MODULE. THE
CLEANED 6AS IS BOOSTED 25 OEG F BY A COMBINATION OF TWO DIFFERENT TYPES
OF IN-LINE REHEATERS PLUS BYPASS REHEAT, AND THFN EXITS A 53C FOOT
PRECRETE LINED STACK. THE WATER LOOP IS CLOSED, AND THE SLUDGE IS
POZ-0-TEC TREATED.
CENTRAL MAINE POUER
SEARS ISLAND
1
NEtf 600.0 MU (GROSS)
600.0 MU (ESC)
COAL
• •*•* X S
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: • •**«
STATUS 6 STARTUP 1/89
SEARS ISLAND 1 IS A PLANNED UNIT TO BE BUILT ON PENOBSCOT BAY BY CENTRAL
MAINE POUER. BECAUSE OF THE DISCOVERY OF A GEOLOGICAL FAULT ON SEARS
ISLAND, PLANS FOR A 1150 MU NUCLEAR POWER PLANT HAVE BEEN REPLACED WITH
PLANS FOR A 600 MU COAL FIRED PLANT. LIME AND LIMESTONE SCRUBBING ARE
THE PRIMARY METHODS BEING CONSIDERED FOR COMPLIANCE WITH THE NSPS. IT
WILL BE TUO YEARS BEFORE ALL PERMITS REQUIRED HAVE BEEN RECEIVED. START
UP IS SCHEDULED FOR JANUARY, 1989.
CINCINNATI GAS & ELECTRIC
EAST BENO
1
NEW 650*0 MU (CROSS)
650.0 MW (ESC)
COAL
**•** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.9X
STATUS 6 STARTUP O/ 0
CINCINNATI GAS AND ELECTRIC HAS PLANS FOR A NEW UNIT, EAST BEND 1, TO
BE LOCATED ADJACENT TO EAST BENT 2 AT THE RABB1THASH, KENTUCKY SITE. THE
COAL FIRED BOILER WILL HAVE A GENERATING CAPACITY OF 650MW. THE UNIT'S
EXPECTED START UP HAS NOT BEEN OETERHINE6.
11
-------
EPA UTILITY FGC SURVEY: JANUARY - MARCH 1980
SECTION i
STATUS OF FGD SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
CINCINNATI GAS & ELECTRIC
EAST BEND
2
MEW 650.0 wy (GROSS)
650.0 MU (ESC)
COAL
5.CO XS
LIME
BABCOCK K UILCOX
ENERGY CONSUMPTION: 2.9*
STATUS 2 STARTUP 9/80
E«ST BEND 2 OF CINCINNATI GAS AND ELECTRIC IS A PULVERIZED COAL <5][ S)
FIRED BOILER UNDER CONSTRUCTION IN RABBITHASH, KENTUCKY. THE EMISSION
CONTROL SYSTEM CONSISTS OF A HOT SIDE ESP FOLLOWED BY THREE BABCOCK AND
WILCOX LIME fGD MODULES. THE 87X CLEANED GAS WILL PASS THROUGH A CHEVON
MIST ELIMINATOR BEFORE BEING HARMED BY AN INDIRECT HOT AIR REHEMER AND
EXITING THROUGH A BRICK LINED 65C FOOT STACK. THE SLUDGE FROM THIS CLOSED
WATER LOOP SYSTEM WILL BE POZ-0-TEC STABILIZED BEFORE DISPOSAL IN AN ON
SITE LANDFILL. START UP IS EXPECTED IN SEPTEMBER, 198C.
COLORADO UTE ELECTRIC ASSN.
CRAIG
1
NEW 447." MU (GROSS)
447.0 MU (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
PEABOCY PROCESS SYSTEMS
ENERGY CONSUMPTION: 5.4X
STATUS 2 STARTUP 4/80
THE COLORADO UTE ELECTRIC ASSN IS PRESENTLY CONSTRUCTING TWO IDENTICAL
UNITS IN CRAIG, COLORADO, CRAIG 1 AND 2. BOTH UNITS WILL FIRE PULVERIZED
SUBBITUMINOUS COAL (0.45S S, 13,000 8TU/LB). EACH UNIT'S HOT SIDE ESP AND
FOUR MAGNESIUM PROMOTED LIMESTONE SPRAY TOWERS WILL REMOVE 85X Of THE SOJ.
THE SCRUBBER CXHAUST WILL BE WARMED BY AN IN-LINE STE»M COIL REHEATER AND
WILL PASS THROUGH A 600 FOOT TALL ACID BRICK LINED STACK. THE SYSTEW WILL
OPERATE IN A CLOSED WATER LOOP, AND THE STABILIZED SLUDGE WILL BE DISPOSED
OF IN AN OFF SITE M1NEFILI. UNIT 1 START UP IS EXPECTED IN APRIL, 1981?.
COLORADO UTE ELECTRIC ASSN.
CRAIG
2
NEW 447.0 MW (GROSS)
447.0 MW (ESC)
COAL
.41 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 5.4X
STATUS 1 STARTUP 8/79
THE CRAIG 2 UNIT OF THE COLORADO UTE ELECTRIC ASSN IS LOCATED
IN CRAIG, COLORADO. THE CRAIG 2 UNIT FIRES PULVERIZED
SUB8ITUM1NOUS COAL (0.45X S, 13,000 BTU/LP). THE UNIT'S HOT SIDE ESP AND
FOUR MAGNESIUM PROMOTED LIMESTONE SPRAY TOWERS WILL REMOVE 85X OF THE S02.
THE SCRUBBER EXHAUST IS WARMED BY AN IN-LINE STEAM COIL REHEATER AND
PASSES THROUGH A 600 FOOT TALL ACID BRICK LINED STACK. THE SYSTEM
OPERATES IN A CLOSED WATER LOOP, AND THE STABILIZED SLUDGE IS DISPOSED
OF IN AN OFF SITE MINEFILl. START UP OF UNIT 2 WAS IN AUGUST, 1979.
COLORADO UTE ELECTRIC ASSN.
CRAIG
3
NEW 447.0 MW (GROSS)
447.^ MM (ESC)
COAL
.45 XS SUBBITUMINOUS
LIME/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/82
COLORADO UTE ELECTRIC ASSN. HAS PLANS FOR A NEW UNIT, CRAIG 3, TO BE
LOCATED IN CRAIG, COLORADO ALONG WITH UNITS 1 AND 2. THE UNIT WILL FIRE
PULVERIZED SUBBITUMINOUS COAL (0.451 S, 10,000 BTU/LB). THE SYSTEM WILL
UTILIZE A DRY SCRUBBER WITH LIMESTONE INJECTION FOR EMISSION CONTROL.
THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN 1982.
COLUMBUS t SOUTHERN OHIO ELEC.
CONESVILLE
5
NEW 411.0 MW (GROSS)
411.0 MW (ESC)
COAL
4.67 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 3.9X
STATUS 1 STARTUP 1/77
CONESVILLE 5 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.67X S, 10,850 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TWO THIOSORBIC LIME TCA MODULES SUPPLIED BY UOP.
THE S02 REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH BEGAN INITIAL
OPERATION IN JANUARY, 1977, IS 89.5X (DESIGN). EACH MODULE HAS ONf
BULK ENTRAINMENT SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 800 FOOT TALL ACID BRICK LINED STACK.
THE POZ-O-TEC STABILIZED SLUDGE is PUMPED INTO AN ON SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN WATER LOOP.
COLUMBUS ( SOUTHERN OHIO ELEC.
CONESVILLE
6
NEW 411.0 MW (GROSS)
411.0 MU (ESC)
COAL
4.67 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 3.91
STATUS 1 STARTUP 6/78
CONESVILLE 6 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.67X 5, 10,850 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TWO THIOSORBIC LIME TCA MODULES SUPPLIED BY UOP.
THE S02 REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH BEGAN INITIAL
OPERATION IN JUNE, 1978, IS 89.5X (DESIGN). EACH MODULE HAS ONE
BULK ENTRAINMENT SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 800 FOOT TALL ACID BRICK LINED STACK.
THE POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN WATER LOOP.
12
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 196C
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COLUMBUS
POSTON
5
NEW
t SOUTHERN OHIO ELEC. COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TuO NEW UNITS, POSTON 5
AND 6, TO BE LOCATED IN ATHENS, OHIO. THE COAL (2 . 5X S, 11,000
425.0 MW (GROSS)
375.0 MU (ESc>
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 4.7X
STATUS 6 STARTUP 8/86
FIRED UNITS WILL UTILIZE EITHER A LIME, LIMESTONE, OR DUAL ALKALI FGD
SYSTEM. START UP OF UNIT 5 IS EXPECTED IN 1986.
COLUMBUS £ SOUTHERN OHIO ELEC. COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TWO NEW UNITS, POSTON 5
POSTON AND 6, TO BE LOCATED IN ATHENS, OHIO. THE COAL <2.5X S, 11,000 BTU/LB)
6 FIRED UNITS WILL UTILIZE EITHER A LIME, LIMESTONE, OR DUAL ALKALI FGD
NEW 425.0 MW (GROSS) SYSTEM. START UP OF UNIT 6 IS EXPECTED IN 1989.
425.0 MW (GROSS)
375.P MW (ESC)
COAL
2.50 US
PROCESS NOT SELECTFD
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 4.7*
STATUS 6 STARTUP 0/89
COMMONWEALTH EDISON
POWERTON
51
RETROFIT 450.0 MU (GROSS)
450.0 MU (ESC)
COAL
3.53 XS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 5.6X
STATUS 2 STARTUP 4/80
COMMONWEALTH EDISON IS PRESENTLY RETROFITTING BOILER NUMBER 51 AT ITS
POUERTON STATION WITH A UOP LIMESTONE F6D SYSTEM. UNIT 51 IS ONE OF TWO
IDENTICAL BOILERS SUPPLYING STEAM TO AN 850 M« TURBINE. THE PULVERIZED
COAL (3.6* s, ic,500 BTU/LB) FIRED BOILER FEEDS FLUE GAS THROUGH AN ESP
TO 3 TCA MODULES WHICH ARE DESIGNED TO REMOVE 74X OF THE soz. A STEAH
INDIRECT HOT AIR REHEATER WILL BOOST THE TEMPERATURE BEFORE THE 6A$ EXITS
AN ACID BRICK LINED STACK. THE SYSTEM WILL UTILIZE A CLOSED WATER LOOP,
AND THE SLUDGE WILL BE POZ-0-TEC STABILIZED AND DISPOSED OF IN A LANDFILL.
THE FGD SYSTEM IS UNDER CONSTRUCTION, AND THE START UP IS EXPECTED IN
APRIL, 1980.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
1
NEW 545.0 MU (GROSS)
327.0 MU (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 8/79
COAL CREEK 1 AND 2 ARE TWO PULVERIZED LIGNITE (9.63X S, 6?58 BTU/IB) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AND UNITED POWER. A COLD SIDE
ESP RECEIVES ?,POO,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FOUR COUNTER-
CURRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED BY A BULK ENTRAlNMfNT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40* BYPASS REHEAT
WILL BE PROVIDED BEFORE THE CLEANED 6AS EXITS THE 650 FOOT ACID BRICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 9CX. THE SYSTEM
WILL OPERATE IN AN OPEN WATER LOOP, AND THE FLYASH STABILIZED SLUDGE WILL
BE DISPOSED IN A CLAY LINED POND. UNIT 1 OPERATIONS BEGAN IN AUGUST 1979.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
2
MEW 545.0 MU (GROSS)
327.0 MW (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 7/80
COAL CREEK 1 AND 2 ARE TWO PULVERIZED LIGNITE (Q.63X S, 6258 BTU/LB) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AND UNITED POUER. A COLD SIDE
ESP RECEIVES 2,200,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FOUR COUNTER-
CURRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED BY A BULK ENTRAINNENT
SEPARATOR AND TUO CHEVRON MIST ELIMINATORS. A MINIMUM OF 4QX BYPASS REHEAT
WILL BE PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT AClB B&U*
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
WILL OPERATE IN AN OPEN WATER LOOP, AND THE FLYASH STABILIZED SLUDGE WILL
BE DISPOSED OF IN A CLAY LINED POND. UNIT 2 IS PRESENTLY UNDER CONSTRUC-
TION AND SHOULD INITIALLY START OPERATIONS IN JULY, 1980.
DELMARVA POWER & LIGHT
DELAWARE CITY
1-3
RETROFIT 180.0 MU (GROSS)
180.0 MU (ESC)
COKE
7.00 XS FLUID PETROLEUM COKE
dELLMAN LORD
DAVY NCKEE
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 4/80
DELMARVA POWER 8 LIGHT'S DELAWARE CITY PLANT HAS FOUR BOILERS, THREE OF
WHICH HAVE STEAM CAPACITIES OF 5OPK LB/HR EACH. THE BOILERS GENERATE STEAM
AS WELL AS ELECTRICITY FOR GETTY "REFINING AND MARKETING. LOU SULFUR CRUDE
OIL UILL BE REPLACED UITH COKE (7-8X S) IN THE BOILER WHEN THE FGD SYSTEM
IS COMPLETE, IN APRIL, 1980. A VENTURI PARTICULAR SCRUE6ER AND A UELLMAN-
LORD FGD SYSTEM (90X DESIGN EFFICIENCY) SUPPLIED BY DAVY POUERGAS ARE
PRESENTLY UNDER CONSTRUCTION. AN INDIRECT GAS REHEATER UILL BE USED.
THE SYSTEM WILL OPERATE IN AN OPEN WATER LOOP.
13
-------
EP» UTILITY fGD SU&VEY: JANUARY - MARCH 1980
SECTION 2
STATUS OF FGD SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
DELMARVA POWER K LIGHT
VIENNA
9
NEW 55P.O MW (GROSS)
550.C MW (ESC)
COAL
2.70 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***«X
STATUS 6 STARTUP A/87
DELMARVA POWER AND LIGHT IS PLANNING A NEW UNIT. VIENNA 9, TO
BE CONSTRUCTED IN VIENNA, MARYLAND. THE UTILITY IS PRESENTLY CONSIDERING
A LIMESTONE FGD UNIT FOR EMISSION CONTROL. THE PULVERIZED COAL FIRED UNIT
IS EXPECTED TO COMMENCE OPERATIONS IN JUNE 19?7.
DESERET GENERATION K TRANS
100N LAKE
1
NEW 410.0 My (GROSS)
410.0 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 12/84
COO MOON LAKE 1 IS A PULVERIZED COAL (0.5X S, 10,500 BTU/LB) FIRED UNIT
PLANNED BY DESERET GENERATION AND TRANSMISSION COOP. TO BE LOCATED IN
VERNAL, UTAH. THE UTILITY IS PRESENTLY REQUESTING BIDS FOR A yET LIME-
STONE SCRUBBING SYSTEM HAVING A so? REMOVAL EFFICIENCY OF 95*. THE SYSTEM
WILL FEATURE * BAGHOUSE DESIGNED TO REMOVE 99.6* OF THE PARTICULATE. THE
UNIT WILL OPERATE IN » CLOSED WATER LOOP WITH SLUDGE DISPOSAL ON SITE
IN A LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1P84.
DESEOET GENERATION 8 TRANS
MOON LAKE
2
NEW 410.0 MW (GROSS)
410.0 RW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGI CONSUMPTION: *»*«X
STATUS 5 STARTUP 0/88
COO MOON LAKE 2 IS A PULVERIZED COAL (0.5X S, 10,500 BTU/LB) FIRED UNIT
PLANNED BY DESERtT GENERATION AND TRANSMISSION COOP. TO fc£ LOCATED IN
VERNAL, UTAH. THE UTILITY IS PRESENTLY REQUESTING BIDS FOR A WET LIME-
STONE SCRUBBING SYSTEM HAVING A S02 REMOVAL EFFICIENCY OF 95X. THE SYSTEM
WILL FEATURE A BAGHOUSE DESIGNED TO REMOVE 99.6* OF THE PARTICULATE. THE
UNIT WILL OPERATE IN 4 CLOSED WATER LOOP WITH SLUDGE DISPOSAL ON S]T£
IN A LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1<»88.
OUQUESNE LIGHT
ELRAMA
1-4
RETROFIT 510.0 MW (GROSS)
510.0 MW (ESC)
COAL
2.20 XS
LIME
CHEMICO
ENERGY CONSUMPTION: 3.5X
STATUS 1 STARTUP 10/75
ELRAMA 1-4 OF DUQUESNE LIGHT CONSISTS OF FOUR PULVERIZED COAL (2.2X S,
11,350 PTU/LB) FIRED UNITS LOCATED IN ELRAMA, PENNSYLVANIA. THE EMISSION
CONTROL SYSTEM ON THIS SITE CONSISTS OF AN ESP FOLLOWED BY A MECHANICAL
COLLECTOR AND FIVE VARIABLE THROAT VENTURI LIME ABSORBER MODULES SUPPLIED
BY CHENICO, WHICH ARE DESIGNED TO REMOVE 83* OF THE S02 FROM THE FLUE GAS
THE CLEANED GAS PASSES THROUGH A DIRECT OIL FIRED REHEATER BEFORE EXITING
A 400 fOOT ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER
LOOP, AND THE POI-0-TEC STABILIZED SLUDGE IS HAULED TO AN OFF SITE LAND-
FILL. THE SYSTEM HAS BEEN OPERATIONAL SINCE OCTOBER, 1975.
DUOUFSNE LIGHT
PHILLIPS
1-6
RETROFIT 408.0 "W (GROSS)
410.0 MW (ESC)
COAL
1.92 XS BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: J.4X
STATUS 1 STARTUP 7/73
EAST KENTUCKY POWER COOP
J. K. SMITH
1
NEW 650.0 *W (GROSS)
650.0 MW (ESC)
COAL
•*•** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *•*•*
STATUS 6 STARTUP 1/85
THE PHILLIPS POWER STATION Of DUOUESNE LIGHT CONSISTS OF SIX DRY POTTOM
PULVERIZED CO*L (2.2X S, 11,350 BTU/LB) FIRED UNITS LOCATED IN SOUTH
HEIGHT, PENNSYLVANIA. PARTICULATE CONTROL IS ACCOMPLISHED BY SIX ESP/
MECHANICAL COLLECTOR COMBINATIONS (ONE/BOILER). ONE TWO STAGE AND THREE
SINGLE STAGE VARIABLE THROAT VENTURI LIME FGD MODULES SUPPLIED BY CHEMICO
ARE DESIGNED TO REMOVE 83X OF THE S02 FROM THE FLUE GAS. TWO CHEVPON MIST
ELIMINATORS/MODULE ARE FOLLOWED BY A DIRECT OIL FIRED REHEATER WHICH RAIS-
ES THE GAS TEMPERATURE BY 20 DEC F BEFORE IT LEAVES VIA A 34(j FOOT TALL
ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND
THE POZ-0-TEC STABILIZED SLUDGE IS TRUCKED TO AN OFF SITE LANDFILL. THE
SYSTEM HAS BEEN OPERATIONAL SINCE JULY, 1973.
THE EAST KENTUCKY POWER COOP HAS PLANS TO FIRE TWO NEU UNITS. THE J.K.
SWITH 1 AND 2 WILL UTILIZE EITHER A DRY PROCESS OR A WET LINE PROCESS
FOR EMISSION CONTROL. UNIT 1 IS EXPECTED TO START UP IN JANUARY, 1985.
14
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 1960
SECTION 2
STATUS OF FGO SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
EAST KENTUCKY POWE" COOP
J. K. SMITH
2
NEW 650.0 MW (GROSS)
650.0 My (ESc)
COAL
.**•* »S
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«*•»
STATUS 6 STARTUP 1/87
THE EAST KENTUCKY POWER COOP HAS PLANS TO FIRE TyO NEW UNITS. THE J.K.
SMITH 1 AND 2 WILL UTILIZE EITHER A DRY PROCESS OR A W£T LjMt PROCESS
FOR EMISSION CONTROL. UNIT 2 IS EXPECTED TO START UP IN JANUARY, 19£7.
EAST KENTUCKY POWER COOP
SPURLOCK
2
SEW 500.C MW (GROSS)
500.0 MW (ESC)
COAL
3.5T XS
LIME
ADL/COMBUSTION EOUIP ASSOCIATE
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 1/81
SPURLOCK 2 Of EAST KENTUCKY POWER COOPERATIVE IS A BALANCED DRAFT PULVER-
I7ED COAL (3.5J S, 11,000 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN M*YS-
VILLE, KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN E?P FOL-
LOWED BY AN ADL/COMBUSTION EQUIPMENT ASSOCIATES LIME FGD SYSTEM (90X
DESIGN S02 REMOVAL EFFICIENCY). FLUE GAS FROM UNIT ONE WILL BE USED TO
REHEAT THE CLEANED GAS. THE SYSTE", SLATED FOR START UP IN JANUARY, 1981,
WILL EMPLOY A CLOSED WATER LOOP AND POZ-0-TEC SLUDGE STABILIZATION.
GENERAL PUBLIC UTILITIES
COHO
1
NEW 690.0 MW (GROSS)
800.0 MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 9.<.X
STATUS 6 STARTUP 12/88
COHO 1 IS A 3.5X S COAL FIRED UNIT PLANNED BY GENERAL PUBLIC UTILITIES TO
BE LOCATED IN ERIE, PENNSYLVANIA. PRIMARY CONSIDERATION IS BEING GIVEN TO
LIME AND LIMESTONE NON-SLURRY TYPE FGD SYSTEMS. THE UNIT »ND FGD SYSTEM
ABE SCHEDULED TO START UP IN DECEMBER, 1988.
GENERAL PUBLIC UTILITIES
GILBERT
1
NEW 625.0 MW (GROSS)
625.0 MW (ESO
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«**X
STATUS 6 STARTUP 0/90
GENERAL PUBLIC UTILITIES HAS PLANS FOR A NEW UNIT, GILBERT 9, TO PE
LOCATED IN M1LFORD, NEW JERSEY. THE UTILITY IS CONSIDERING FGO »S AN
EMISSION CONTROL STRATEGY. THE EXPECTED START UP DATE IS IN 1990.
GENERAL PUBLIC UTILITIES
SCOTTSVILLE
1
NEW 625.n MW (GROSS)
625.C MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «**«X
STATUS 6 STARTUP
GENERAL PUBLIC UTILITIES IS PLANNING « NEW UNIT TO BE LOCATED IN
StOTTSVILLE, PENNSYLVANIA. THE SCOTTSVILLE 1 UNIT IS EXPECTED TO START
UP IN 1991. THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS A EMISSION
CONTROL STRATEGY.
GENERAL PUBLIC UTILITIES
SEWARD
7
NEW 690.0 MW (GROSS)
800.0 MW (ESC)
COAL
•**** zs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 9.4*
STATUS 6 STARTUP 5/87
GENERAL PUBLIC UTILITIES IS PLANNING A NEW UNIT, StWARD 7, TO BE BUILT IN
SEWARD, PENNSYLVANIA. THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS THE
EMISSION CONTROL STRATEGY, WITH NON-SLURRY TYPE LIKE AND LIMESTONE SYSTEflS
LOOKING THE MOST PROMISING. START UP IS EXPECTED IN HAY, 1987.
15
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SECTION I
STATUS OF FGD SYSTEMS
JMT IDENTIFICATION
ABSTRACT
GENERAL PUBLIC UTILITIES
WEHRUM
1
NEW 625.C MW (GROSS)
625.P *U
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/95
THE WEHRUM 1 UNIT PLANNED BY GENERAL PUBLIC UTILITIES IS TO BE LOCATED
IN WEHRUH, PENNSYLVANIA. THE UTILITY is PRESENTLY CONSIDERING FGD AS AN
EMISSION CONTROL STRATEGY. THE UNIT IS EXPECTED TO COMMENCE OPERATIONS
IN 1995.
GRAND HAVEN BRD OF LIGHT &
i. B. SIMS
3
MEW 81.0 MW (GROSS)
81.0 MU (ESC)
COAL
2.75 XS BITUMINOUS
LIME
BABCOCK g UILCOX
ENERGY CONSUMPTION: **•**
STATUS 3 STARTUP 6/B3
PUR THE GRAND HAVEN BOARD OF LIGHT AND POWER'S J.P. SIMS 3 IS A PLANNFD
BITUMINOUS COAL (2.75X St H»COC BTU/Lb) FIRED UNIT TO BE LOCATED IN
GRAND HAVEN, MICHIGAN. A CONTRACT HAS BEEN AWARDED TO BABCOCK AND ULCOX
TO 5UPPL> TWO SPRAY TOuERS TO CONTROL EMISSIONS. EACH SCRUBBER SYSTEM
WILL UTILIZE A CHEVRON MIST ELIMINATOR AND AN IN-LINE CEHEATER. THE
SLUDGE IS TO Bt DISPOSED IN AN OFF SITE LANDFILL. OPERATIONS ARE TC
COMMENCE IN JUNE, 19E3.
HOOSIER ENERGY
HEROM
1
NEW 490.0 MW (GROSS)
441.0 MU (ESC)
COAL
3.50 XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 5/82
MEROM 1 AND 2 ARE TWO NEW UNITS BUNG BUILT BY HOOSIER EfcFRGY IN SULLIVAN
INDIANA. THESE PULVERIZED COAL (3.5X S) FIRED UNITS WITH PRODUCE 1,732,000
ACFM OF FLUE GAS WHICH UILL BE CLEANED BY A COLD SIDE ESP UPSTREAM OF A
MITSUBISHI LIMESTONE GRID TOWER ABSORBER «90X DESIGN S02 REMOVAL). THE
SYSTEM WILL UTILIZE BYPASS REHEAT AND A 700 FOOT STACK. THE SLUDG? WILL
BE STABILIZED AND LANDFILLED, AND THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP OF UNIT 1 IS SCHEDULED FOR MAY, 1982.
HOOSIER ENERGY
2
NEW 490.0 MU (GROSS)
441.0 MU (ESC)
COAL
3.50 XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 7/81
MEROM 1 AND 2 ARE TWO NEW UNITS BEING BUILT BY HOOSIER ENERGY IN SULLIVAN
INDIANA. THESE PULVERIZED COAL (3.5X S) FIRED UNITS WITH PRODUCE 1,732,OCO
ACFM OF FLUE GAS WHICH WILL BE CLEANED BY A COLD SIDE ESP UPSTREAM OF A
MITSUBISHI LIMESTONE GRID TOWER ABSORBER (90X DESIGN SO? REMOVAL). THE
SYSTEM WILL UTILIZE BYPASS REHEAT AND A 700 FOOT STACK. THE SLUOGf WILL
BE STABILIZED AND LANDFILLED, AND THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP OF UNIT 2 IS SCHEDULED FOR JULY, 1981.
HOUSTON LIGHTING t POWER CO.
ri.A. PARISH
8
NEW 600.0 MU (GROSS)
492.P MU (ESC)
COAL
.60 XS SUBBITUMINOUS
LIMESTONE
CHEMICO
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 11/82
U.A. PARISH £ IS A PULVERIZED COAL (0.6X S, 8?00 BTU/LB) FIRED UNIT PLAN-
NED BY HOUSTON LIGHTING AND POWER CO TO BE LOCATED IN THOMPSONS, nXAS.
THE UTILITY HAS AWARDED A CONTRACT TO CHEMICO FOR A LIMESTONE
FGO SYSTEM WHICH WILL REMOVE 82X OF THE FLUE GAS 502. REHEAT
WILL BE PROVIDED BY BYPASSING 18X OF THE PARTICULATE CLEANED FLUE GAS.
SLUDGE WILL BE DEWATERED, BLENDED UITH FLYASH, AND DISPOSED IN AN ON
SITE LANDFILL. START UP IS EXPECTED IN NOVEMBER, 1982.
INDIANAPOLIS POWER S LIGHT
PATRIOT
1
NEU 650.0 MU (GROSS)
650.0 MU (ESC)
COAL
3.50 tS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/87
INDIANAPOLIS POWER AND LI6HT HAS PLANS FOR THREE NEW UNITS, PATRIOT 1, 2
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
16
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 19gn
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIfICATION
ABSTRACT
INDIANAPOLIS POWER g LIGHT
PATRIOT
2
NEW 650.0 fW (GROSS)
650.C MW (ESC)
COAL
3.50 XS
LIMESTONE
t/ENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/87
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UMTS. PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON U
A LIMESTONE fGD PROCESS fOR EMISSION CONTROL.
INDIANAPOLIS POUER 8 LIGHT
PATRIOT
3
NEW 650.0 *W (GROSS)
650.0 MU (ESC)
COAL
3.50 XS
LIMESTONE
YENDOH NOT SELECTED
ENERGY CONSUMPTION: ****x
STATUS 6 STARTUP 0/87
INDIANAPOLIS POUER AND LIGHT HAS PLANS FOR TH*EE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE fGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POWER 8 LIGHT
PETERSBURG
3
MEW 532.0 "« (GROSS)
532.0 MW (ESC)
COAL
3.25 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 12/77
PETERSBURG 3 OF INDIANAPOLIS POWER AND LIGHT IS LOCATED IN PETERSBURG,
INDIANA, AND BURNS 4.5X S BITUMINOUS COAL (11,COO BTU/LB). TWO COLD SIDE
ESP'S ARE LOCATED UPSTREAM OF 4 85X EFFICIENT UOP LIMESTONE TCA MODULES.
A HORIZONTAL MIST ELIMINATOR PRECEDES AN INDIRECT HOT AIR REHEATEP THAT
BOOSTS THE GAS TEMPERATURE BY 30 DEC F BEFORE IT EXITS THE 616 FOOT RIGI-
FLAKE 4S50 LINED STACK. STABILIZED SLUDGE IS DISPOSED IN AN ON SITE POND,
AND THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE. THIS UNIT HAS BEEN
OPERATIONAL SINCE DECEMBER, 1977.
INDIANAPOLIS POWER K LIGHT
PETERSBURG
4
NEW 530.0 MW (GROSS)
530.0 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 2.1X
STATUS 2 STARTUP 10/84
PETERSBURG 4 OF INDIANAPOLIS POWER AND LIGHT IS A BITUMINOUS COAL (5.5CX S
11,000 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN PETERSBURG, INDIANA. THE
LIMESTONE FGD SYSTEM FOR THIS UNIT WJLL BE SUPPLIED BY RESEARCH COTTRELL.
THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP, AND SLUDGE WILL B* P07-0-
TEC STABILIZED BEFORE PONDING. START UP IS SLATED FOR OCTOBER Of 1984.
KANSAS CITY POUER 8 LIGHT
HAWTHORN
3
RETROFIT 90.0 MW (GROSS)
90.0 MW (ESC)
COAL
.60 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY COMSUMPTIONt 2.2*
STATUS 1 STARTUP 11/72
HAWTHORN 3 OF KANSAS CITY POWER A«D LIGHT IS A DRY BOTTOM PULVERISED
BITUMINOUS COAL (0.6* S, 98CC BTU/LB) FIRED UNIT LOCATED IN KANSAS
MISSOURI, WHICH WAS CONVERTED FROM LIMESTONE FURNACE INJECTION AND TAIL
END SCRUBBING TO A LIME SLURRY SYSTEM. TWO COMBUSTION ENGINEERING MARBLE
BED ABSORBERS, WHICH WERE DESIGNED TO REMOVE 70* OF THE FLUE GAS S02,
BEGAN OPERATION IN JANUARY, 1977. ONE HORIZONTAL CHEVRON MIST ELIMINATOR
PER MODULE IS UPSTREAM OF AN IN-LINE FINNED TUBE REHEATER, WHICH RAISES
THE TEMPERATURE OF THE CLEANED GAS BEFORE IT EXITS THROUGH A GUNITE LINED
200 FOOT STACK. THE FLVASH STABILIZED SLUDGE IS DEPOSITED IN AN UNL1NEO
SLUDGE POND. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.
KANSAS CITY POUER 8 LIGHT
HAWTHORN
4
RETROFIT 90.0 MW (GROSS)
90. C1 MW (ESC)
COAL
.60 XS BITUMINOUS
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.2Z
STATUS 1 STARTUP 8/72
HAWTHORN 4 OF KANSAS CITY POWER AND LIGHT IS A DRY BOTTOM PULVERIZED
BITUMINOUS COAL C0.6X S, 9800 BTU/LB) FIRED UNIT LOCATED IN KANSAS CITY,
MISSOURI, WHICH WAS CONVERTED FROM LIMESTONE FURNACE INJECTION AND TAIL
END SCRUBBING TO A LIME SLURRY SYSTEM. TWO COMBUSTION ENGINEERING MARBLE
BED ABSORBERS, WHICH WERE DESIGNED TO REMOVE 701 OF THE FLUE GAS $02,
BEGAN OPERATION IN JANUARY, 1977. ONE HORIZONTAL CHEVRON MIST ELIMINATOR
PER MODULE IS UPSTREAM OF AN IN-LINE FINNED TUBE REHEATER, WHICH RAISES
THE TEMPERATURE OF THE CLEANED GAS BEFORE IT EXITS THROUGH A GUNITE LINED
200 FOOT STACK. THE FLYASH STABILIZED SLUDGE IS DEPOSITED IN AN UNLINED
SLUDGE POND. THE SYSTEM OPERATES IN * CLOSED WATER LOOP MODE.
17
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198C
SECTION 2
STATUS Of FGD SYSTEMS
JNIT IDENTIFICATION
APSTRACT
KANSAS CITY POWER K LIGHT
LA CYGNE
1
NEW 874.C MW (GROSS)
874.P »W (ESC>
COAL
5.39 XS SUBBITUMINOUS
LIMESTONE
BABCOCK R WILCOX
ENERGY CONSUMPTION: 2.7*
STATUS 1 STARTUP 2/73
LA CYGNE 1 IS A WET BOTTOM, CYCLONE FIRED PULVERIZED SUBfa ITUMINOUS COAL
(5.39X S, 9421 BTU/LB) FIRED UNIT OF KANSAS CITY POWER AND LIGHT, LOCATED
IN LA CYGNE, KANSAS. THE EMISSION CONTROL SYSTE"! CONSISTS OF EIGHT VARIA-
BLE THROAT VENTURI/LIMESTONE SIEVE TRAY TOWER TPAINS SUPPLIED EY FABCOCK
AND WILCOX. EACH 8CX (S02 REMOVAL, DESIGN) EFFICIENT TRAIN IS FOLLOWED BY
A COMBINATION SIEVE TRAY AND CHEVRON MIST ELIMINATOR, FOLLOWED B1 AN INDI
RECT REHEATER. THE CLEANED GAS E»JTS THROUGH A ?C'0 FOOT STEEL LINED STACK.
THE SYSTEM OPERATES IN A CLOSED kATFR LOOP, AND THE SCRUBBER SLUDGE IS
DISPOSED IN AN UNLINED POND. INITIAL OPERATIONS OF THE FGD SYSTEM BEGAN 1N
FEBRUARY, 1977.
KANSAS POWER & LIGHT
JEFFREY
1
NEW 720.0 MW (GROSS)
540.0 MW (ESC)
COAL
.32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP P/7B
KANSAS CITY POWER AND LIGHT'S JEFFREY 1 IS A TANGENTIAL FIRED PULVERIZED
COAL (G.32X S, 8125 BTU/LP) UNIT IN WAMPGO, KANSAS. THE EMISSION CONTROL
SYSTEM FOR THIS UNIT CONSISTS OF • COLD SIDE ?SP FOLLOWED BY SIX (ONE
SPARE) LIMESTONE SPRAY TOWER MODULES SUPPLIED BY COMBUSTION ENGINEERING.
THE DESIGN SO? REMOVAL EFFICIENCY IS 5C* (INCLUDING A 30X BYPASS R£HEAT>.
THE UNIT HAS BEEN OPERATIONAL SINCE AUGUST, 1978.
KANSAS POWER & LIGHT
JEFFREY
2
NEW 700.0 MW (GROSS)
490.0 MW (ESC)
COAL
.30 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 4/80
UNIT 2, PRESENTLY UNDER CONSTRUCTION AT KANSAS POWER AND LIGHT'S JEFFREY
ENERGY CENTER IN JEFFREY, KANSAS, WILL BURN 0.3X S PULVERIZED COAl (81CO
BTU/LB). THIS UNIT'S EMISSION CONTROL SYSTEM WILL CONSIST OF A COLD SIDE
ESP AND COMBUSTION ENGINEERING LIMESTONE SPRAY TOWERS. A 70X FLUE GAS
BYPASS WILL PROVIDE REHEAT OF THE CLEANED GAS BEFOhE IT EKITS THROUGH A
6TO FOOT STACK. THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP MODE, AND
THE SLUDGE WILL BE STABILIZED WITH BOTTOM ASH AND PIPED TO AN ON-SITE
CLAY LINED POND. SCHEDULED START UP OF THE SYSTEM IS APRIL, 196C.
KANSAS POWER & LIGHT
LAWRENCE
4
RETROFIT 125.0 MW (GROSS)
125.0 MW (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 1/76
LAWRENCE 4 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 1C,COT BTU/LB) UNIT LOCATED IN LAWRENCE, KANSAS.
A NEW COMBUSTION ENGINEERING LIMESTONE ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MARBLE BED TAIL END SCRUBBER IN JANUARY, 1977. THE
SYSTEM TREATS 403,000 ACFM OF FLUE GAS. WITH A DESIGN S02 REMOVAL OF
73*. MJST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS AND ONE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DEG F BEFORE
IT IS EXHAUSTED THROUGH A 120 FOOT STACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP.
KANSAS POWER & LIGHT
LAWRENCE
5
RETROFIT 420.0 MW (GROSS)
420.0 MW (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: **«*X
STATUS 1 STARTUP 11/71
LAWRENCE 5 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 10,000 RTU/LB) UNIT LOCATED IN LAWRENCE, KANSAS
A NEW COMBUSTION ENGINEERING LIMESTONE ROD DECK/SPRAY TOWER SYSTEM *
REPLACED THE EXISTING MARBLE BFD TAIL END SCRUBBER IN APfclL. 1978. THE
SYSTEM TREATS 403,000 ACFM OF FLUE GAS, WITH A DESIGN S02 REMOVAL OF
73*. MIST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS AND ONE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DEG F BEFORE
IT IS EXHAUSTED THROUGH A 120 FOOT STACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP.
KENTUCKY UTILITIES
GREEN RIVER
1-3
RETROFIT 64.0 MM (GROSS)
64.C MW (ESC)
COAL
4.00 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 3.IX
STATUS 1 STARTUP 9/75
GREEN RIVER 1-3 OF KENTUCKY UTILITIES ARE THREE DRV BOTTOM PULVERIZED
BITUMINOUS COAL (4X S, 11,000 BTU/LB) FIRED UNITS LOCATED IN CENTRAL
CITY, KENTUCKY. EACH BOILER SUPPLIES 360,000 ACFM OF FLUE GAS TO A
VARIABLE THROAT VENTURI FOLLOWED BY AN AMERICAN AIR FILTER LIME MOBILE
BED CONTACTOR (SOX DESIGN S02 REMOVAL EFFICIENCY). A RADIAL VANE MIST
ELIMINATOR IS FOLLOWED BY A STEAM TUBE REHEATFR AND A 165 FOOT STACK.
SLUDGE IS DISPOSED IN AN ON-SITE UNLINED POND, AND THE SYSTEM OPERATES
IN A CLOSED WATER LOOP. THE SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER,
1975.
18
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198n
SECTION 2
STATUS OF FGO SYSTEMS
IDENTIFICATION
ABSTRACT
LAKELAND UTILITIES
>IC INTOSH
J
NEW 364.C MW (GROSS)
364.C I»W (ESC)
COAL
2.56 XS BITUMINOUS
LIMESTONE
BABCOCK X WILCOX
ENERGY CONSUMPTION: ****X
STATUS I STARTUP 10/81
MCINTOSH 7 Of LAKELAND UTILITIES IS BEING CONSTRUCTED IN LAKELAND,
FLORIDA. PABCOCK AND WILCOX HAS 6F.EN AWARDED A CONTRACT TO SUPPLY AN
85X EFFICIENT FIRED UNIT.
COMBUSTION ENGINEERING IS SUPPLYING THE LIME/LIME STONE FGD SYSTEM WHICH
WILL COMPLY WITH LOCAL EMISSION STANDARDS BY ApRIL OF 1982.
19
-------
EPA UTILITY FGD SU"VEY: JANUARY - MARCH 1980
SECTION 2
STATUS Of FGD SYSTEMS
JNIT IDENTIFICATION
APSTRACT
LOUISVILLE GAS « ELECTRIC
tlLL CREEK
J
NEW 44?.0 MW (GROSS)
44?.C MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.62
STATUS 1 STARTUP 8/78
LOUISVILLE GAS »N|> ELECTRIC'S MILL CREEK 3 IS A 3.75X S COAL (11,FOG BTU/
LB) FIRED UNIT LOCATED IN LOUISVILLE* KENTUCKY. AMERICAN AIR FILTER SUP-
PLIED A CARBIDE LIME FGD SYSTEM FOR THIS UNIT WHICH WAS DESIGNED T0 REMOVE
85X OF TH? SO? FROM THE FLUE GAS. AN ESP IS FOLLOWED BY FOUR MOBILE B*D
SPRAY TOWERS AND A STEAM TUBE REHFAUR. THE WATER LOOP IS OPEN, A*D TH£
FLYASH AND LI»E STABILIZED SLUDGE is PONDED. THIS UNIT HAS BEEN OPERATION-
AL SINCE AUGUST, 1978.
LOUISVILLE GAS & ELECTRIC
flLL CREEK
4
NEW 495.0 !"W (GROSS)
495.P MW (ESC)
COAL
3.75 XS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 7/81
MILL CREEK 4 OF LOUISVILLE GAS AND ELECTRIC 1$ A PULVERIZED BITUMINOUS
COAL (3.75X S, 11,500 bTU/LB) FIRED UNIT UNDE" CONSTRUCTION IN LOUISVILLE,
KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP AND FOUR
MOBILE BED SPRAY TOWERS. THE SYSTEM'S WATER LOOP WILL BE CLOSED, »ND
THE SLUDGE WILL BE STABILIZED WITH L»*E AND FLYASH. STEAM TUBES WILL
PROVIDE REHEAT OF THE CLEANED GASES. THE SYSTEM IS SCHEDULED TO S'APT
UP JN JULY OF 1961.
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN
5
RETROFIT 7?.c MU (GROSS)
7?.0 WW (ESC)
COAL
2.50 SS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.8X
STATUS 1 STARTUP 4/73
UNIT 6 AT LOUISVILLE GAS AND ELECTRIc'S PADDY'S RUM STATION IS A DRY BOT-
TOM PULVERIZED COAL (?.5X S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. A RETROFIT CARBIDE LIME FGD SYSTEM BY COMBUSTION ENGINEERING TREATS
400.000 ACFM OF FLUE GAS FROM THE BOILER. AN ESP is FOLLOWED BY TWO MARBLE
BSD ABSORBERS, A DIRECT COMBUSTION RBHEATER, AND A 250 FOOT STACK. WIST
ELIMINATION IS PROVIDED BY ONE CHEVRON/MODULE- THE LIME FIXATED SLUDGE IS
TRUCKED TO AN UNL1NED POND, AND THE WATER LOOP IS CLOSED. THE FGD SYST[N
BEGAN INITIAL OPERATIONS IN APRIL, 1973.
LOUISVILLE GAS & ELECTRIC
TRIMBLE COUNTY
1
NEW 575.0 MU (GROSS)
575.0 WW (ESC)
COAL
4.00 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 7/84
LOUISVILLE GAS AND ELECTRIC WILL 8E INSTALLING FGO SYSTEMS ON TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED *» S (IF NO COAL WASH IS INCLUDED) COAL FIPED
UNITS' FLUE 6AS KILL BE CLEANED BY ESP'S AND WET SCRUBBING (9QX REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 1 IS SCHEDULED
FOR START UP IN JULY OF 1984.
LOUISVILLE GAS t ELECTRIC
TRIMBLE COUNTY
2
HEW 575.0 MW (GROSS)
575.0 MW (ESC)
COAL
4.00 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTIONS ****X
STATUS 6 STARTUP 7/86
LOUISVILLE GAS AND ELECTRIC WILL BE INSTALLING FGD SYSTEMS ON TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 42 S (IF NO COAL WASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS WILL Bt CLEANED BY ESP'S AND WET SCRUBBING (90X REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 2 IS SCHEDULED
FOR START UP IN 19S6.
MICHIGAN SO. CENTRAL PWfi AGENC THE PROJECT 1 UNIT OF MICHIGAN SOUTH CENTRAL POWER AGENCY IS TO BE CON-
PROJECT
1
NEW
S5.0 MU (GROSS)
55.0 MU (ESC)
COAL
2.25 XS
LIMESTONE
BABCOCK K U1LCOX
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 7/82
STRICTED IN LITCHFIELD, MICHIGAN, AND WILL UTILIZE A WET LIMESTONE FGD
PROCESS. THE PULVERIZED COAL FIRED BOILER WILL FEED ITS FLUE GAS THROUGH
A HOT SIDE ESP FOLLOWED BY A BABCOCK AND WILCOX LIMESTONE SPRAY TOWER.
THE CLEANED GAS WILL PASS THROUGH A HIST ELIMINATOR BEFORE PEING WARMED
BY AN IN-LINE REHEATER AND EXITING A 25P FOOT STACK. THE SLUDGE IS TO
BE DISPOSED OFF SITE. START UP IS SCHEDULED FOR JULY, 1982.
20
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198n
SECTION I
STATUS OF FGD SYSTEMS
JSIT IDENTIFICATION
ABSTRACT
H1DDLE SOUTH UTILITIES
ARKANSAS COAL
5
NEU 890.0 MU (GROSS)
89D.O MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: •*•*!{
STATUS 5 STARTUP 1/86
MIDDLE SOUTH UTILITIES HAS AWARDED CONTRACTS ON SIX NEW LOU SULFUR
COAL FIRED UNITS. THE UTILITY IS CURRENTLY REQUESTING/EVALUATING BIDS FOR
THE FGO SYSTEMS, ALTHOUGH THE TYPE OF SYSTEM HAS NOT BEEN DECIDED. MISSIS-
SIPPI COAL 1 WILL START UP IN 1985.
DIDDLE SOUTH UTILITIES
MISSISSIPPI COAL
2
NEU 890.0 MU (GROSS)
890.0 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***«J
STATUS 5 STARTUP 0/87
MIDDLE SOUTH UTILITIES HAS AWARDED CONTRACTS ON SIX NEW LOW SULFUR (Q.5X)
COAL FIRED UNITS. THE UTILITY is CURRENTLY REQUESTING/EVALUATING BIDS fOR
THE FGD SYSTEMS, ALTHOUGH THE TYP-F OF SYSTEM HAS NOT BEEN DECIDED. MISSIS-
SIPPI COAL 2 WILL START UP IN 1987.
21
-------
EPA UTILITY FGD SU»VEY: JANUARY - MARCH 1980
SECTION i
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
1INNESOTA POWER 8 LIGHT
CLAY BOSUELL
4
NEW 554.C MW (GROSS)
475.P «U
COAL
.94 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
PEABOOY PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.3X
STATUS 2 STARTUP 4/80
CLAY BOSNELL 4 OF MINNESOTA POyER AND LIGHT IS A SUBBITUMINOUS COAL O.54X
S, 8896 bTU/LB) FIRED UNIT UNDER CONSTRUCTION IN COHASSfT, MINNESOTA.
PEABODY PROCESS SYSTEMS WILL SUPPLY A LI ME/ALKALINE FLYASH SYSTEM HHICH
IS DESIGNED TO REMOVE 69X OF THE S02 IN THE FLUE GAS. TWO HOT SIDf ESP'S
WILL BE FOLLOWED BY VENTURI/SPRAY TOWER TRAINS. MIST ELIMINATION WILL BE
PROVIDED BY A SIEVE TRAY FOLLOWED BY A SPIN VASE CHEVRON, AND REHfAT WILL
BE PROVIDED BY BYPASSING 5X OF THE FLUE GAS. THE SYSTEM WILL OPcRME IN A
CLOSED WATER LOOP MODE, AND THE SLUDGE WILL BE DISPOSED IN A LINED POND.
OPERATIONS ARE SCHEDULED TO COMMENCE IN APRIL, 1980.
"UNNKOTA POWER COOPERATIVE
PULTON R. YOUNG
Z
nw 440.0 MM (GROSS)
405.0 MU (ESC)
COAL
.70 XS LIGNITE
LIME/ALKALINE FLYASH
ADI/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 9/77
MINNKOTA POWER COOPERATIVE'S MILTON R. YOUNG 2 IS A CYCLONE FIRE& LIGNITE
(0.70XS, 6500 BTU/LB) BOILER LOCATED IN CENTER, NORTH DAKOTA. TH£ BOILER
PRODUCES ?,021,4QO ACFM OF FLUE GAS, WHICH IS CLEANED BY TWO ESP'? AND TWO
ADL/COMBUSTION EQUIPMENT ASSOCIATES LIME/ALKALINE FLYASH SPPAV TOWERS (75X
DESIGN SO? REMOVAL EFFICIENCY). THE CLEANED GAS PASSES THROUGH A CHEVRON
MIST ELIMINATOR BEFORE IT JOINS A 15X BYPASS ȣHEAT AND EXITS A 550 FOOT
STACK. THE WATER LOOP IS OPEN, AND THE SLUDGE IS TRUCKED TO AN OFf-SlTE
MINEFILL. THIS SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER, 1977.
MONTANA POUER
COLSTRIP
1
1EW 360.0 MU (GROSS)
360.0 MU (ESC)
COAL
.77 XS SUBBITUHINOUS
LIME/ALKALINE FLVASH
ADL/COMBUSTION EOUIP ASSOCIATE
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 9/75
COLSTRIP 1 OF MONTANA POUER IS A SUBBITUMINOUS COAL (0.77X ;, 884? PTU/LB)
FIRED UNIT LOCATED IN COLSTRIP, MONT/SNA. AOL/COMB USTION EQUIPMENT ASSOCI-
ATES SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOUER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOUED
BY HORIZONTAL CHEVRON MIST ELIMINATORS, A STEAM TUBE REHEATER, AND A SCO
FOOT STACK. THE UNSTABILI7ED SLUDGE IS DISPOSED IN AN ON-S1TE LINED POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN SEPTEMBER OF 1975.
10NTANA POUER
COLSTRIP
2
MEW 360.0 MU (GROSS)
360.0 MU (ESC)
COAL
.77 XS SUBBITUMINOUS
LINE/ALKALINE FLYASN
ADL/COMBUSTION EOUIP ASSOCIATE
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 5/76
COLSTRJP 1 OF MONTANA POWER IS A SUBBITUMINOUS COAL (0.77* S, 8843 6TU/LB)
FIRED UNIT LOCATED IN COLSTRIP, MONTANA. ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOUER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON MIST ELIMINATORS, A STEAM TUBE REHEATER, AND A 5'0
FOOT STACK. THE UNSTABILIZED SLUDGE IS DISPOSED IN AN ON-SlTE LINED POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN MAY OF 1976.
MONTANA POUER
COLSTRIP
3
NEW 700.0 MU (GROSS)
700.0 MH (ESC)
COAL
.70 XS
LIME/ALKALINE FLVASH
ADL/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: ****!
STATUS 2 STARTUP 1/84
MONTANA POUER'S COLSTRIP 3 IS A LOU SULFUR COAL (0.7X S, 8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A CONTRACT HAS BEEN
AWARDED TO ADL/COMBUSTION EQUIPMENT ASSOCIATES FOR A LIME/ALKALINE FLYASH
FGD SYSTEM ON THIS UNIT. START UP IS SCHEDULED FOR JANUARY, 1984.
HONTANA POWER
COLSTRIP
4
NEW 700.0 MU (GROSS)
700.0 MU (ESC)
COAL
.70 XS
LIME/ALKALINE FLVASH
AOL/COMBUSTION EQUIP ASSOCIATE
ENER6V CONSUMPTION: ****X
STATUS 2 STARTUP 0/8*
MONTANA POUER'S COLSTRIP 4 IS A LOU SULFUR COAL (0.7X S, 8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A CONTRACT HAS BEEN
AWARDED TO ADL/COMBUSTION EQUIPMENT ASSOCIATES FOR A LIME/ALKALINE FLVASH
FGD SYSTEM ON THIS UNIT. START UP IS SCHEDULED FOR 1984.
22
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH I960
SECTION 2
STATUS Of FGD SYSTEMS
JSIT IDENTIFICATION
ABSTRACT
•USCAT1NE POWER 8 WATER
1JSCATJNE
9
MEW 166.0 "W (GROSS)
160.0 »W (ESC>
COAL
J.17 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION:
STATUS 3
MUSCAT1NE 9 IS A PULVERIZED BITUMINOUS COAL OX S. 11,230 6TU/L6) fIREO
UNIT PLANNED B» MUSCATINE PONER AND WATER TO PE LOCATED IN MUSCATISE,
IOWA. A CONTRACT WAS AtiAROEO TO RESEARCH COTTRELL FOR « LIMESTONE UNIT FOR
EMISSION CONT1QL. THE FGO SYSTEM WILL FEATURE AN ESP, TWO 1CCX CAPACITY
TOWERS, STEAf CC1L REHEAT, A CLOSED WATER LOOP. AND FOSCfcD OXIDATION OF
THE SLUDGE BEFORE LANDFILL. THE DESIGN 502 REMOVAL WILL BE 94X. START UP
WILL TAKE PLACE IN 1982.
4.82
STARTUP 9/82
NEVADA POWER
HARRY ALLEN
1
Ntw 500.C rw (GROSS)
500.C *w (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****%
STATUS 6 STARTUP 6/86
NEVADA POWER'S HARRY ALLEN 1 IS A PLANNED COAL FIRED UMT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGO SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE, 1986.
NEVADA POWER
HARRY ALIEN
2
NEW 500.0 MU (GROSS)
500.0 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 6/87
NEVADA POWER'S HARRY ALLEN 2 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FtD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED fOR JUNE, 1967.
NEVADA POWER
HARRY ALLEN
3
NEW 500.0 MU (GROSS)
500.0 MU (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 6/88
NEVADA POWER'S HARRY ALLEN 3 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE, 1988.
NEVADA POWER
HARRY ALLEN
4
NEW 500.0 »W (GROSS)
500.0 MM (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION.- ****X
STATUS 6 STARTUP 6/89
NEVADA POWER'S HARRY ALLEN * IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT VET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE, 1989.
NEVADA POWER
REID GARDNER
1
RETROFIT 125.0 flU (GROSS)
125.0 MU (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
AOL/COMBUSTION ECUIP ASSOCIATE
ENER6Y CONSUMPTION: *••*)[
STATUS 1 STARTUP 4/74
REID GARDNER 1 IS A MET BOTTOM LOW SULFUR COAL 10.51 S, 12,450 BTU/LB)
FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA. A SODIUM CAR-
BONATE-BASED (TRONA) SCRUBBING SYSTEM BY AOL/COMBUSTION ECUIPHENT ASSOCI-
ATES CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH \ SINGLE STAGE PEFORATED PLATE WASH
TOWER. PRIMARY PARTICULATE CONTROL IS PROVIOEC BY UPSTREAM MULTICLONES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM HOT AIR REHEATED
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAV LINED SOLAR EVAPORATION POND. THE
DESIGN SO? REMOVAL EFFICIENCY IS 9Qt. THE SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL, 1974.
23
-------
EPA UTILITY FGB SURVEY: JANUARY - MARCH 1980
SECTION t
STATUS OF F6D SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
NEVADA POWER
REID GARDNER
2
RETROFIT 125.0 MW (GROSS)
135.0 MW
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 19E'
SECTION 2
STATUS Of FGD SYSTEMS
JMT IDENTIFICATION
ABSTRACT
NIAGARA MOHAWK POWFR COOP
CHARLES R. HUNTLFY
66
HETfiOflT 100.0 "U (GROSS)
100.0 "W (ESC)
COAL
1.60 *S
ABUEOUS CARBONATF
ROCKWELL INTERNATIONAL
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 4/?2
CHARLES R. HUNTL
12,530 PTU/LB) F
AWARDED TO ATOMI
F.FF HUNT ReTSOF
TAL SULFU" AS AN
THE EMPIRE STATE
FOLLOWED BY TWO
STACK. THE WATEP
1082.
EY 6t OF NIA&ARA POWER COOP is A PULVERIZED COAL (i.sx s,
JRED UNIT LOCATED IN BUFFALO, MEW >ORK. A CONTRACT W IS
CS INTERNATIONAL FOR THE DESIGN AND INSTALLATION OF A 9^*
IT AGUEOUS CARBONAT? FG6 SYST?* WHICH WILL PRODUC? EL^.EN-
END PRODUCT. FUNDS ARE BEING PROVIDED BY THE U.S.EPA AND
ELECTRIC ENERGY RESEARCH CORP. A SPR»Y DRYER WILL EE
bANKS OF FIGHT CYCLONES AN ESP, AND A ?"C FOOT STfEL LINED
LOOP WILL BE OPEN. START UP OF THE FGD SYSTEM WILL BE IN
INDIANA PUB SERVICE
DEAN H. MITCHELL
RETROFIT 115.C MW (GROSS)
115." "W (ESC)
COAL
3.5C IS
JeLLMAN LORD
0»VY POWERGAS
E!»CRGY CONSUMPTION: 27.8*
STATUS 1 STARTUP 7/76
NORTHERN INDIANA PUBLIC SERVICE'S DEAN H. MITCHELL 11 IS A COAL (?.5X S,
11,000 PTU/LB) FIRED UNIT LOCATED IN GARY, INDIANA. A RETROFIT WELLMAN
LORD FGD SYSTrK BY DAVY POWERGAS HAS BEEN OPERATING ON THIS UNIT SINCC
JULY, 197«. AN ESP IS FOLLOWED PY A VARIABLE THROAT VENTURI SCSUBPER
AND A TRAY TOWER ABSORBER (90* DESIGN S02 REMOVAL EFFICIENCY). A DIRECT
COMEUSTION RAISES THE CLEANED GAS TEMPERATURE 5-" DEC F BEFORE THE GAS
IS DISCHARGED THROUGH A 168 FOOT STAINLESS STEEL AND FRP LINED STACK.
ELEMENTAL SULFUR AND SULFATE IS PRODUCED PY THE PROCESS DEVELOPED faY
ALLIED CHEMICAL. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.
NORTHERN INDIANA PUB SERVICE SCHAHFtP 17 OF NORTHERN INDIANA PUBLIC SfRVICc IS A 3.2X SULFUR COAL FIRED
SCHAHFER UNIT PLANNED FOR CONSTRUCTION IN WHEATFIELD, INDIANA. THE UTILITY H»S
? SIGNED A LETTER OF INTENT WITH F MC FOR THE INSTALLATION OF A DUAL ALKALI
F6D SYSTEM AT THIS UNIT. PART1CULATE MATTER WILL BE COLLECTED BY AN ESP
AND THE SYSTE" WILL INCLUDE A REHFATEfi. START UP OF THIS UNIT IS
SCHEDULED FOR JUNE OF 1983.
421.0 MU (GROSS)
421.0 MW (ESC>
.,F-
C()AL
3.Zr
OJAL ALKALI
[NERGY CONSUMPTION: *****
STATUS * STARTUP 6/85
INDIANA PUB SERVICE
SCHAHFER
1E
421.0 MW (GROSS)
421 .C MW (ESC)
COAL
3.2" US BITUMINOUS
OJAL ALKALI
ENERGY CONSUMPTION: *****
STATUS * STARTUP 6/85
SCHAHFER 18 OF NORTHERN INDIANA PUBLIC SERVICE IS A 3.2X SULFUR COAL FIRED
UNIT PLANNED FOR CONSTRUCTION IN WHEATFIELD, INDIANA. THE UTILITY HAS
SIGNED A LETTER OF INTENT WITH FWC FOR THE INSTALLATION OF A DUAL ALKALI
FGD SYSTEM AT THIS UNIT. PARTICULATE MATTER WILL BE COLLECTED BY AN ESP
AND THE SYSTE" WILL INCLUDE A REHfATER. START UP OF THIS UNIT IS
SCHEDULED FOR JUNE OF 1985.
STATES POWER
RIVERSIDE
110.0 MU (GROSS)
110.0 MW (ESC)
COAL
1.5
DRYING
JOY MFG/N1RO ATOMI7ER
ewERGY CONSUMPTION: *****
TTATUS 2
RIVERSIDE 6 AND 7 ARE TWO COAL FIRED BOILERS OWNF.D BY NORTHERN STATES
POWER AND LOCATED IN MINNEAPOLIS, MINNESOTA. EACH BOILER GENERATES A FLUE
GAS FLOW OF 320,000 ACFM AT 350 F. CURRENTLY, A DEMONSTRATION LIME/SPRAY
DRYING FGD SYSTEM IS UNDER CONSTRUCTION THAT WILL BE CAPABLE OF TREATING
THE FLUE GAS FROM BOTH BOILERS. THE SYSTEM If BEING SUPPLIED BY
NIRO ATOMIZER/JOY MANUFACTURING AND WILL CONSIST OF A SPRAY pR»ER FOLLOWED
BY A BAGHOUSE. THE CLEAN FLUE GAS WILL EE VENTED TO TWO 3QC FT CONCRETE
STACKS WITH FIRE BRICK LINERS. SPENT ABSORBENT WILL BE DISPOSED OF IN ON
AND OFF SITE LANDFILLS. OPERATIONS ARE EXPECTED TO BEGIN IN JULY, 1V8C.
NORTHERN STATES POWER'S SHERBURNE 1 IS A BALANCED DRAFT PULVERIZED SUB6I-
TUMINOUS COAL (C.80* S, 8*00 BTU/IB) FIRED BOILER IN BECKER, MINNESOTA. A
SOX EFFICIENT (DESIGN) LIWESTONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MA">CH Of
1976. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MIST ELIHINATORS/TRAIN, AN IN-LINE HOT WATER
REMEATER, AND A 650 FOOT CORTEN LINED STACK. THE SLUDGE IS FORCIBLY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LOOP IS OPEN.
NORTHERN STATES POWER
SHERBURNE
1,u 7AO.O "W (GROSS)
'lfc" 740.0 MW (ESC)
C°*gO XS SUBBITUMINOUS
, ,-ESTONE/ALKALlNE fLlASH
COMBUSTION ENGINEERING
* CONSUMPTION: 2.7*
STATUS 1 STARTUP 3/76
25
-------
EPA UTILITY F&O SU"VEY: JANUARY - MARCH 19SC
SECTION i
STATUS OF FGD SYSTEMS
JNIT IDENTIFICATION
APSTR* CT
NORTHERN STATES POWER
SHERBURNE
2
NEW 740.T MW (GROSS)
740.? »H (ESC)
COAL
.80 XS SURBITUMINOUS
LIMESTONE/ALKALINE FL»«SH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.71
STATUS 1 STARTUP 4/77
NORTHERN STATES POWER'S SHERBURNE 2 IS A BALANCED DRAFT PULVERIZED SUPfal
TUM1NOUS COAL Sl S, 8500 BTU/LB) FIRED UNIT TO B? CON-
STRUCTED IN BECKER, MINNESOTA. DUE TO THE LATEST TECHNOLOGY THAT HAS BEEN
DEVELOPED BIDS HAVE AGAIN BEEN OPENED. THE UTILITY IS PRESENTLY EVALUAT-
ING THREE DIFFERENT TYPES OF FGD SYSTEMS. MAY, 1984 IS EXPECTED START UP.
OTTE" TAIL POwER
COYOTE
1
NEW 440.? MU (GROSS)
440.0 MW (ESC)
COAL
.87 XS LIGNITE
AQUEOUS CARBONATE/SPRAY DRYING
JHEELABRATOR-FRYE/R.I .
ENERGY CONSUMPTION: 1.1X
STATUS 2 STARTUP 3/81
COYOTE 1 IS A CYCLONE FIRED PULVERIZED LlGNiTE (0.875X S, 7050 BTU/LB)
BOILER UNDER CONSTRUCTION IN BEULAH, NORTH DAKOTA. THIS UNIT IS JOINTLY
OWNED BY FIVE UTILITIES, WITH OTTER TAIL POWER BEING THE MAJOR OWNER «KD
CONSTRUCTOR. AN AQUEOUS CARBONATE DRY FGD SYSTEM DESIGNED TO REMOVE 7^1
OF THE S02 IS BEING SUPPLIED BY WHEELABRATOR-FRYE AND ATOMICS INTFRNATIOK.
At. THE SPRAY OR YER/B AGHOUSE SYSTEM IS SCHEDULED TO START UP IN
PACIFIC GAS 8 ELECTRIC
10NTEZUMA
1
NEW 800.0 «W (GROSS)
800.0 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.51
STATUS 6 STARTUP 6/87
MONTEZUMA 1 OF PACIFIC GAS AND ELECTRIC IS A CO«L (O.PX S, 12fCQQ BTU/LB)
FIRED BOILER PLANNED FOR COLL IN 5VILLE, CALIFORNIA. THE EMISSION CONTROL
SYSTEM WILL CONSIST OF A PAGHOUSE AND A LIMESTONE FGD SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START UP DATE IS JUNE, 1937.
PACIFIC GAS 8 ELECTRIC
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 196C
SECTION i
STATUS Of FGO SYSTEMS
JN1T IDENTIFICATION
ABSTRACT
PENNSYLVANIA POWER
3I1UC? MANSFIELD
1
NEW 917." *W (GROSS)
917.^ »W (ESC)
COAL
3.0*1 * S BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: 6.0*
STATUS 1 STARTUP 12/75
BRUCE MANSFIELD 1 OF PENNSYLVANIA POWER
BOILER FIRING PULVERIZED COAL (3.P* S, 1
PENNSYLVANIA. A CHEMICO TH10SORBIC LIME
FLYASH AND SO? (92.1)(> FROM 3,350,000 AC
CONSISTS OF SIX VARIABLE THROAT VCNTURI
THROAT VENTURI ABSORt?RS, HORIZONTAL MIS
TION REHEATERS, AND A 95C FOOT FLAKEGLAS
THE WATER LOOP IS OPEN, AND THE CALC1LOX
AN OFF SITE LANDFILL. THIS SYSTEM HAS BE
1975 .
IS « SUPERCRITICAL, BALANCED DRAFT
1,50C BTU/LB) IN SHIPPIN&PORT,
FGD SYSTEM WAS DESIGNED TO CEMOVE
FM OF FLUE GAS. THE FGD SYSTEM
SCRUBRERS FOLLOWED BY SIX FIXED
T ELI"INATORS, TWO DIRECT COMBuS-
S STACK SHARED PY UNITS 1 AND I.
STABILIZED SLUDGE IS DISPOSED IN
EN OPERATIONAL SINCE DECE^bER,
PENNSYLVANIA POWER
3RUC f. MANSFIELD
2
MEW 917.C MW (GROSS)
917.0 MW (ESC)
COAL
3.CO X S BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: 6.C*
STATUS 1 STARTUP 7/77
BRUCE MANSFIELD i OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL H.CX S, 11.50C BTU/LB) IN WHIPPINGPOST,
PENNSYLVANIA. A CHEMICO TH10SOREIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND SO? (V2.1X) FROM 3,35C,000 ACFM OF FLUE GAS. THE FGD SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIX fIXEC
THROAT VENTUfil ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT COMPtS-
TION REHEATERS, AND A 950 fOOT FLAKEGLASS STACK SHARED BY UNITS 1 AND ;.
THE «ATER LOOP IS OPEN, AND THE CALCILOX STABILIZED SLUDGE IS DISPOSED IN
AN OFF SITE LANDFILL. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY, 1977.
PENNSYLVANIA POWER
3RUCE MANSFIELD
j
•4EW 917.0 »W (GROSS)
917.C MW (ESC)
COAL
3.or1 *s
LIME
PULLMAN KELLOGG
ENERGY CONSUMPTION: •**•»
STATUS 2 STARTUP 10/80
BRUCE MANSFIELD 3 OF PENNSYLVANIA POWER IS A SUPERCRITICAL PULVERIZED COAL
(7.03t S, 11,5r>C BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN S HIPP INGPOR T ,
PENNSYLVANIA. FOUR ESP'S WJLL TREAT 3,308,000 ACFM OF FLUE GAS, FOLLOWED
BY FIVE (ONE SPARE) PULLMAN KELLOGG THIOSORBIC LIME ABSORBERS WHICH
WILL REMOVE 92.2X OF TH£ S02. THE CLEANED GAS WILL PASS THROUGH
CHEVRON MIST ELIMINATORS AND DIRECT COMBUSTION REHEATERS BEFORE
DISCHARGE THROUGH A 6 <"0 FOOT 1NCONEL 625 LINED STACK. THE FLYASH STA-
BILIZED SLUDGE WILL b€ PIPED TO THE EXISTING OFF SITE LANDFILL PRESENTLY
USED BY UNITS ONE AND TWO. START UP IS EXPECTED IN OCTOBER, 198C.
PHILADELPHIA ELECTRIC
CROMBY
RETROFIT
150. H MW (GROSS)
150. C «W (ESC)
PHILADELPHIA FLECTRIC HAS PLANS FOR THE RETROFIT OF AN FGO SYSTEM ON ONE
OF THE TWO 3.nx SULFUR COAL FIRED BOILERS AT CROMBY STATION IN PHOEN1X-
VILLE, PENNSYLVANIA. A CONTRACT HAS BEEN AWARDED TO UNITED ENGINEERS
FOR A MAGNESIUM OXIDE SYSTEM. THE START UP D«TE IS SET FOR 1962.
COAL
3.C? XS
MAGNESIUM OXIDE
JNITEO ENGINEERS
ENERGY CONSUMPTION: •***«
STATUS 3 STARTUP 12/82
PHILADELPHIA
EDDYSTONE
1 A
RETROFIT
ELECTOR
120." MW (GROSS)
120.9 MW (ESC)
COAL
2.60 XS BITUMINOUS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: •*•*»
STATUS 1 STARTUP 9/75
PHILADELPHIA
EDBYSTONE
IB
RETROFIT
ELECTRIC
240.0 MU
240.0 MW
(GROSS)
(ESC)
COAL
2.60 XS
1AGNESIUM
OXIDE
UNIT 1 OF PHILADELPHIA ELECTRIC'S E&D*STONE. PENNSYLVANIA STATION IS A
BITUMINOUS COAL (2.6X S, 13,600 BTU/LB) FIRED UNIT WHICH USES ESP'S,
MECHANICAL COLLECTORS, AND THREE PARTICULATE SCRUBBERS (TWO VENTRI ROD
AND ONE VENTURI) PROVIDE PRIMARY PARTICULATE CONTROL. THE 1A FGD SYSTEM
CONSISTS OF A MAG OX OOD DECK SPRAY TOWER FOLLOWING THE VENTURI SCRUBBER.
THE 90X EFFICIENT (DESIGN) ABSORBER, A RETROFIT BY UNITED ENGINEERS, LEADS
TO A LOUVER TYPE MIST ELIMINATOR, A DIRECT COMBUSTION REMEATtR, AND A
249 FOOT STACK. THE SPENT SLURRY IS REGENERATED AT THE ESSEX SULFURIC
ACID PLANT IN NEWARK, NEW JERSEY, AND THE MAG-OX is RETURNED TO EPDY-
STONE. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND HAS BEEN OPERA-
TIONAL SINCE SEPTEMBER, 1975.
•»—•»••— ——•—••!•—•••••••«•—••••»••••—• •»•• ••«•»««••»•«•••»•*•••••••»_,»• W»W »
UNIT 1 OF PHILADELPHIA ELECTRIC'S EDDYSTONE, PENNSYLVANIA STATION IS A
BITUMINOUS COAL (2.6)1 S, 13.6CO 6TU/LB) FIRED UNIT WHICH USES ESP'S,
MECHANICAL COLLECTORS, AND THREE PARTICULATE SCRUBBERS (TWO ROD DECK
SPRAY TOWERS AND ONE VENTURI) FOR PRIMARY PARTICULATE CONTROL. THE
16 FGD WILL FOLLOW THE TWO ROD DECK SPRAY TOWERS. UNITED ENGINEERS
WILL SUPPLY A MAGNESIUM 0*I&E fGD SYSTEM FOR EMISSION CONTROL.
THE START UP DATE IS SET FOR DECEMBER, 1982.
JNITED ENGINEERS
ENERGY CONSUMPTION: ****X
STATUS 2 STASTUP 12/82
27
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198C
SECTION 2
STATUS OF fGD SYSTEMS
JNIT IDENTIFICATION
AESTR* CT
PHILADELPHIA ELECTRIC
EDDYSTONE
RETROFIT
COAL
i.50 XS
MAGNESIUM
334.?
334.T
OXIDE
MW
MW
(GROSS)
EDDYSTONE I OF PHILADELPHIA ELECTRIC IS A 2.5* SULFUR COAL F IBEb BOILER
LOCATED 1H EDDYSTONE, PENNSYLVANIA. THE PLANT'S GENERATING
CAPACITY IS 3T4 MU. UNITED ENGINEERS WILL SUPPLY A MAGNESIUM OXIDE
FCD SYSTEM FOR EMISSION CONTROL. START UP IS SET FOR DECEMBER. 19S^.
JNITED ENGINEERS
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 1?/f2
POTOMAC ELECTRIC POWER
DICKERSON
I.
HEW 650.H py (GROSS)
BOO.? My
COAL
1.9H XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 5/87
DICKERSON 4 OF POTOMAC ELECTRIC POWER IS A PULVERIZED COAL (2.0* «, 11,000
BTU/LP) FIRED UNIT PLANNED FOR LOCATION IN DICKERSON, MARYLAND. THE UTIL-
ITY IS CONSIDERING AN FGD SYSTEM FOR THIS UNIT, BUT THERt ARE NO F1&M
PLANS FOR THE INSTALLATION OF AN FGD SYSTEM. START UP OF THE BOILER IS
EXPECTED IN 1385. FGD SYSTEM ST«RT UP IS EXPECTED IN MAY, 1967.
PUBLIC SERVICE INDIANA
SIB SON
5
MEW 65P.O MW (GROSS)
650.0 My (ESC)
COAL
3.30 ZS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 0/82
GIBSON 5 OF PUBLIC SERVICE OF INDIANA IS A 3.?* SULFUR COAL FIRED UNIT
PLANNED FOR LOCATION IN PRINCETON, INDIANA. A CONTRACT MAS AWARDED TO
PULLMAN KELLOGG F0« A LIMESTONE FGD SYSTEM CONSISTING OF FOUR KELLOGG-
WEIR AbSORBER-fEACTOR MODULES. SYSTEM START UP IS EXPECTED IN 1VP2. T
SYSTEM WILL USE KELLOGG'S PROPRIETARY MAGNESIUM-PROMOTED LIMESTONE.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
1
RETROFIT 361.0 MW (GROSS)
361 .0 *H (ESC)
COAL
.fcO XS SUHB1TUMINOUS
4ELLMAN LORD
DAVY POWE&GAS
ENERGY CONSUMPTION: 4.4X
STATUS 1 STARTUP 4/78
S«N JUAN 1 OF PUBLIC SERVICE CF NEW MEXICO IN WATERfLQWi NEW MEXICO IS A
COAL (0.6* S, E1-0 PTU/LB) FIPED BOILER WHICH SUPPLIES 1,T19,CCO ACFM Of
FLUE GAS TO A RETROFIT WELLMAN LO"D FGO SYSTE* BY DAVY POWERGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE APRIL OF 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUBBER/SPR AY TOWEC ABSOR-
BER TRAINS WHICH WERE DESIGNED TO REMOVE S5X OF THE FLUE GAS S02. AN !»,-
DIRECT HOT A11 PEHEATER PPECEDE? * BRICK UNEC STACK. END PRODUCT ELE«EN-
T»L SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE WATER LOOP IS
CLOSED.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
RETROflT 350.0 MW (GROSS)
350.0 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
BELLMAN LORD
DAVY POWERGAS
ENERGY CONSUMPTION: 4.6X
STATUS 1 STABTUP 8/78
SAN JUAN 2 OF F>UBLIC SERVICE OF NEW MEXICO JN WATERFLOW, NEW MEXICO IS A
COAL (0.6* S, 81uO RTU/LB) FIRED P01LER WHICH SUPPLIES 1,319,000 ACFM Of
FLUE GAS TO A RETROFIT UELLMAN LORD FGD SYSTEM PY DAVY POWERGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE AUGUST OF 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRU6BER/SPRAY TOwEP ABSOR-
BER TRAINS WHICH WERE DESIGNED TO REMOVE P5X OF THE FLUE GAS S02. AN IK,-
DIRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END PRODUCT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL P10CESS. THE WATER LOOP IS
CLOSED.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
3
NEW 534.0 MW (GROSS)
534.0 MW (ESC)
COAL
.80 IS SUBBITUHINOUS
WELLMAN LORD
DAVY POWERGAS
ENERGY CONSUMPTIONi 3.6X
STATUS 1 STARTUP 12/79
SAN JUAN T IS A COAL (0.81 S, 8100 BTU/LB) FJRED UNIT OF THE PUfLIC
SERVICE OF NEW MEXICO AND JS LOCATED IN WATERFLOW, NEW MEXICO. THT fGD
SYSTEM, SUPPLIED BY DAW POUERGAS IS AN INTEGRATION OF THE WELLMAN
LORD SO? RECOVERY PROCESS AND ALLIED CHEMICAL'S SOZ REDUCTION TO fULfUfi
PROCESS. FIVE (ONE SPARE) VENTURI SCRUBSER/SPRAY TOWER ABSORBER <9C* DE-
SIGN S02 REMOVAL) TRAINS FOLLOW A HOT SIDE ESP. AN INDIRECT HOT AJt
REHEATER BOOSTS THE GAS TEMPERATURE 50 DEC F. THE SYSTEM OPERATES
IN A CLOSED WATER LOOP MODE. OPERATIONS COMMENCED IN DECEMBER, 19?9.
28
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 1960
SECTION 2
STATUS Of FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
4
VEU 534.0 MW (GROSS)
534.P MW (ESC)
COAL
.80 XS SUBBITUMINOUS
rfELLMAN LORD
DAVY POWERGAS
ENERGY CONSUMPTION: 3.6X
STATUS 2 STARTUP 6/82
SAN JUAN 4 IS A COAL (0.8X S, 8100 BTU/LB) FIRED UNIT OF THE PUBLIC SER-
VICE OF NEW MEXICO UNDER CONSTRUCTION IN UATERFLOW, NEW MEXICO. THE FGD
SYSTEM BEING SUPPLIED BY DAVY POWERGAS IS AN INTEGRATION OF THE yELLMAM
LORD S02 RECOVERY PROCESS AND ALLIED CHEMICAL'S S02 REDUCTION TO SULfUR
PROCESS. FIVE (ONE SPARE) VENTUR1 SCRUBBER/SPRAY TOWER ABSORBER <"C* DE-
SIGN SO? REMOVAL) TRAINS WILL FOLLOW A HOT SIDE ESP. AN INDIRECT HOT AIR
RFHEATER WILL BOOST THE GAS TEMPERATURE 50 DEG F. THE SYSTEM WILL OPERATE
IN A CLOSED WATER LOOP MODE. START UP IS EXPECTED IN JUNE, 1983.
P4R AUTHORITY OF STATE OF NY
FOSSIL
*EW
COAL
700.0 MW (GROSS)
700.0 MW (ESC)
THE POWER AUTHORITY OF NEW YORK PLANS A NEW 3.OX SULFUR COAL FIRED UNIT
WHICH WILL BE LOCATED AT THE ARTHUR KILL FACILITY ON STATEN ISLAND. THE
UTILITY IS PRESENTLY CONSIDERING FGD SYSTEMS FOR THIS UNIT. PUBLIC SERVICE
COMMISSION HEARINGS ARE CURRENTLY IN PROGRESS. START UP IS EXPECTED IN
NOVEMBER, 1987.
XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 11X87
SALT RIVER PROJECT
CORONAOO
1
NEW 350.r MW (GROSS)
280.0 MW (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: 4.3X
STATUS 1 STARTUP 11/79
SALT RIVER PROJECT'S CORONADO 1 IS A DR* BOTTOM PULVERIZED SUBBITUMINOUS
COAL (1.0X S, 83QO BTUJLB) FIRED BOILER LOCATED IN ST. JOHNS.
ARIZONA. PULLMAN KELLOttG SUPPLIED THE TWO LIMESTONE HORIZONTAL WEIR SPRAY
TOWERS WHICH WILL REMOVE P2.5X OF THE S02 FROM THE FLUE GAS PASSED THROUGH
THEM. VERTICAL HEIL MIST ELIMINATORS PRECEDE A 500 FOOT STACK. A MINIMUM
OF 201 BYPASS PROVIDES REH£AT. THE WATER LOOP IS AN OPEN "ODE. AND THE
UNSTABILI7ED SLUDGE IS DISPOSED IN AN UNLINED POND. START UP WAS
IN NOVEMBER, 1979.
SALT RIVER PROJECT
CORONADO
2
350.0 MW (GROSS)
280.0 MW (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: 4.3X
STATUS 2 STARTUP 7/80
SALT RIVER PROJECT'S CORONADO 2 IS A DRY BOTTOM PULVERIZED SUBEI TUMI NOUS
COAL (1.0X S. 83CO BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN ST. JOHNS,
ARIZONA. PULLMAN KELLOGG IS SUPPLYING TWO LIMESTONE HORIZONTAL WEIR SPRAY
TOWERS WHICH WILL REMOVE P2.5X OF THI 502 FROM THE FLUE GAS PASSED THROUGH
THEM. VERTICAL HEIL MIST ELIMINATORS PRECEDE A 500 FOOT STACK. A MINIMUM
OF 20X BYPASS WILL PROVIDE REHEAT. THE WATER LOOP WILL BE OPEN, AND THE
UNSTA8IL1ZED SLUDGE WILL EE DISPOSED IN AN UNLINED POND. START UP IS EX-
PECTED IN JULY, 1980.
SALT RIVER PROJECT
CORONADO
3
NEW 400.0 MU (GROSS)
280.C MW (ESC)
COAL
.60 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.8X
STATUS 6 STARTUP 6/87
CORONADO 3 IS A DRV BOTTOM PULVERIZED SUBBITUMINOUS COAL (1.CX S. 8300 BTU
/LB) FIRED UNIT PLANNED BY SALT RIVER PROJECT TO BE LOCATED IN ST. JOHN'S,
ARIZONA. THE UTILITY IS PRESENTLY CONSIDERING THE INSTALLATION OF TWO HOR-
IZONTAL SPRAY TOWERS UTILIZING LIMESTONE AS THE ABSORBENT. PLANS FOR AN
EMISSION CONTROL SYSTEM HAVE NOT BEEN FINALIZED. THE SYSTEM WILL HAVE A
2?X BYPASS REHEAT, AND THE SLUDGE WILL PROBABLY BE PONDED. SCHEDULED OPER-
ATION DATE IS 1987.
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL
1
NEW 400.0 MW (GROSS)
400.0 MW (ESC)
COAL
1.70 XS LIGNITE
LIMESTONE
BABCOCK S WILCOX
ENERGY CONSUMPTION: 5.OX
STATUS 2 STARTUP 9/80
SAN MIGUEL 1 OF THE SAN MIGUEL ELECTRIC COOP IS A LIGNITE (1.7X S. 5000
BTU/LB) FIRED RADIANT BOILER UNDER CONSTRUCTION IN SAN MIGUEL, TEXAS. THE
EMISSION CONTROL SYSTEM ON THIS UNIT WILL CONSIST OF A COLD SIDE ESP FOL-
LOWED BY FOUR BABCOCK AND WILCOX 96X EFFICIENT LIMESTONE TCA MODULES.
CHEVRON MIST ELIMINATORS WILL PRECEDE AN IN-LINE REHEATER AND AN ACID
BRICK LINED STACK. THE WATER LOOP WILL BE CLOSED, AND THE DEwATERED SLURRY
WILL BE MIXED WITH FLYASH BY RESEARCH COTTRELL AND DISPOSED IN AN OFF SITE
LANDFILL.
29
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SEMINOLE ELECTRIC
SEMINOLE
1
MEW 620.0 MW (GROSS)
620.P MU (ESC)
COAL
2.75 ZS SUBBITUMINOUS
LIMESTONE
PEABOOY PROCESS SYSTEMS
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 3/83
SEMINOLE 1 OF SEMINOLE ELECTRIC IS A CO*L (2.75* Si 11,700 BTU/LB) FIRED
UNIT PLANNED FOR LOCATION IN PALATKA, FLORIDA. THE EMISSION CONTROL SYSTEh.
WILL CONSIST OF ESP'S AND A LIMESTONE FGD SYSTEM. THE FGD SYSTEM WILL 6E
SUPPLIED BY PEABOOY PROCESS SYSTEM. 4TART UP TS EXPECTED IN MARCH OF
1983.
SEMINOLE ELECTRIC
SEMINOLE
2
NEW 620.0 nw (GROSS)
620.0 MW (ESC)
COAL
2.75 *S SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP ?/85
SEMINOLE 2 OF SEMINOLE ELECTRIC IS A COAL (2.75* S, 11.7CO BTU/LB) FIREO
UNIT PLANNED FOR LOCATION IN PALATKA, FLORIDA. THE EMISSION CONTROL SYSTEM
WILL CONSIST OF ESP'S AND A LIMESTONE fGD SYSTEM. THE FGD SYSTEM WILL BE
SUPPLIED BY PEABODV SYSTEMS. START UP IS EXPECTED IN MARCH OF
1985.
SIKESTON BOARD OF MUNIC. UTIL. THE SIKESTON BOARD OF MUNICIPAL UTILITIES' SiKESTON 1 IS A PULVERIZED COAL
(2 8* S, 11,3*C BTU/L8) FIRED BOILER UNDER CONSTRUCTION IN SIKESTON, MIS-
SOURI. BABCOCK AND W1LCOX IS SUPPLYING AN EMISSION CONTROL SYSTEM CONSIST-
(GROSS) ING OF TWO ESP'S AND THREE 50* CAPACITY LIMESTONE VENTURI FGD MODULES. THE
(ESC) CLEANED GAS WILL PASS THROUGH CHEVRON MIST ELIMINATORS BEFORE EXITING A
450 FOOT FRP LINED FLUE (A SECOND CARBON STEEL LINED FLUE, USED FOR EMER-
GENCY BYPASS, IS ALSO IN THE STACK). THE WATER LOOP WILL BE OPEN, AND THE
SLUDGE WILL BE PONDED. START UP IS SLATED FOR JANUARY, 19P1.
SIKESTON
1
NEW 235.0 MW
235.0 MW
COAL
2.80 *S
LIMESTONE
BABCOCK K WILCOX
ENERGY CONSUMPTION:
STATUS 2 STARTUP
1.6*
1/81
SOUTH CAROLINA PUBLIC SERVICE
iJINYAH
2
NEW 280.0 MW (GROSS)
UO.O MU (ESC)
COAL
1.70 XS BITUMINOUS
LIMESTONE
BABCOCK t WILCOX
ENERGY CONSUMPTION: 1.1*
STATUS 1 STARTUP 7/77
WINYAH 2 OF SOUTH CAROLINA PUBLIC SERVICE IS A PULVERIZED BITUMINOUS COAL
(1.70* S, 11,500 BTU/LB) FIRED UNIT LOCATED IN GEORGETOWN, SOUTH CAROLINA,
A COLD SIDE ESP AND A BABCOCK AND WILCOX VENTURI SCRUBBER/LIMESTONE TRAY
TOWER ABSORBER TRAIN DESIGNED TO REMOVE 69* OF THE S02 FROM THE BOILER
FLUE GAS MAKE UP THE EMISSION CONTROL SYSTEM ON THIS UNIT. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP, AND 'THE SLUDGE IS DISPOSED IN AN ON-SITE
UNLINEO POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY OF 1977.
SOUTH CAROLINA PUBLIC SERVICE
tflNVAH
S
1EU 280.0 MW (GROSS)
280.0 MM (ESC)
COAL
1.70 XS
LIMESTONE
BABCOCK I WILCOX
ENERGY CONSUMPTION: 2.1*
STATUS 2 STARTUP 5/80
WINVAH 3 IS A DRY BOTTOM BOILER UNDER CONSTRUCTION BY SOUTH CAROLINA PUB-
LIC SERVICE WHICH WILL BURN 1.7* SULFUR COAL (11,500 BTU/LB) IN GEORGE-
TOWN, SOUTH CAROLINA. AN ESP WILL PRECEDE A BABCOCK AND WILCOX LIMESTONE
FGD SYSTEM AND AN INDIRECT STEAM REHEATER. THE WATER LOOP WILL BE CLOSED,
EXPECTED START UP DATE IS MAY, 1980.
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
4
NEW 280.0 MU (GROSS)
280.0 MU (ESC)
COAL
1.70 *S BITUMINOUS
LIMESTONE
UNERICAN AIR FILTER
ENERGY CONSUMPTION: 2.1«
SOUTH CAROLINA PUBLIC SERVICE'S WINYAH 4 IS A PLANNED BITUMINOUS COAL
(1.7* S, 11,500 6TU/L6) FIREO UNIT TO BE LOCATED IN GEORGETOWN, SOUTH
CAROLINA. TWO AMERICAN AIR FILTER LIMESTONE SLURRY SPRAY TOWERS WILL
FOLLOU AN ESP. THE TEMPERATURE OF THE CLEANED GAS WILL BE RAISED BY AN
INDIRECT STEAM REHEATER. THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP
MODE. THE CONTRACT FOR THE FGD SYSTEH HAS BEEN AWARDED, AND START UP IS
EXPECTED IN JULY, 1981.
STATUS 3
STARTUP 7/81
30
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 2
STATUS Of FGD SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
SOUTH MISSISSIPPI FLEC PWR
R.D. MORROW
1
NEW 200.P »U (GROSS)
124.0 MW (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
RILE* STOKER/ENVIRONEERING
ENERGY CONSUMPTION: 5.5*
STATUS 1 STARTUP 8/78
R.D. MORROW 1 OF
S, 12,000 BTU/L8
TROL SYSTEM FOR
STONE VENTRI-ROD
THE CLEANED GAS
JOINED BY A 3SX
STACK SHARED BY
FLUE). THE WATER
HAULED 61 TRUCK
SINCE AUGUST OF
SOUTHERN MISSISSIPPI ELECTRIC IS A PULVERIZED COAL (1.31
) FIRED UNIT IN KATT1SSUKG, MISSISSIPPI. THE EMISSION CON-
THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LI*E-
ABSORBER SUPPLIED BY R1LEY STOKER/ENVIRONEERING. AFTER
PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT IS
BYPASS REHEAT BEFORE IT is DISCHARGED THROUGH A *r8 FOOT
UNITS 1 AND 2 (EACH UNIT HAS ITS OwM AClD BRICK LINED
LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUDGE IS
TO AN OfF SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
1978.
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW
2
NEW 200.0 l»W (GROSS)
124.f »W (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
RILEV STOKER/ENVIRONEEB1NG
ENERGY CONSUMPTION: 5.5*
STATUS 1 STARTUP 6/79
R.D. MORROW 2 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVERIZED COAL (1.3X
S, 12,000 BTU/LB) FIRED UNIT IN HATT1S6URG, MISSISSIPPI. THE EMISSION CON-
TPOL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY • LIME-
STONE VlENTRl-BOD ABSORBER SUPPLIED BY R1LEY STOK ER /E NVI R ONEER I NG . AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT is
JOINED BY A 3?* BYPASS R{H£AT BEFORE IT IS DISCHARGED THROUGH A 4r8 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OhN ACID BRICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUDGE IS
HAULED BY TRUCK TO AN OFF SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE OF 1979.
SOUTHERN ILLINOIS POWER COOP
1APJON
4
NEW 184.0 MW (GROSS)
184.f MW (ESC>
COAL/REFUS
3.50 XS
LIMESTONE
3ABCOCK 8 WILCOX
ENERGY CONSUMPTION: *«««X
STATUS 1 STARTUP 5/79
UNIT 4 AT SOUTHERN ILLINOIS POWER COOP'S FARlON STATION IN MARION, ILLI-
NOIS IS A CYCLONE FIRED COAL (3.OX S, 90CO BTU/LB) BOILER WHICH IS SERVED
BY A 89.4* EFFICIENT (DESI6N) LIMESTONE FGD SYSTEM SUPPLIED BY 8APCOCK AND
ylLCOX. TWO SPRAY TOWERS AND A BRICK LINED STACK ARE DOWNSTREAM OF AN ESP
IN THIS SYSTEM. THE WATER LOOP IS OPEN, AND THE FLYASH STABILIZED SLUDGE
IS DEWATERED AND LANDFILLED. TH£ SYSTEM BECAME OPERATIONAL DURING MAY OF
1979.
SOUTHERN ILLINOIS POWER COOP
HARION
5
NEW 300.0 MW (GROSS)
300.C MW (ESC)
COAL
3.00 *S
PROCESS NOT SELECTED
tfENOOR NOT SELECTED
ENERGY CONSUMPTION! ••***
STATUS 6 STARTUP 0/86
MARION 5 IS A COAL (3.OX S, 9000 BTU/LB) FIRED UNIT PLANNED BY SOUTHERN
ILLNOIS POWER COOP FOR LOCATION IN MARION. ILLINOIS. THE UTILITY HAS NOT
YF.T DECIDED ON AN FGD PROCESS AS IT 1$ WAITING FOR THE FINALIZATION OF
THE S02 REGULATIONS THE UNIT WILL HAVE TO MEET. START UP IS EXPECTED IN
1986.
SOUTHERN INDIANA GAS & ELEC
A.8. BROWN
1
NEW 265.0 «M (GROSS)
265.0 MU (ESC)
COAL
3.35 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: .8X
STATUS 1 STARTUP 4/79
SOUTHERN INDIANA GAS AND ELECTRIC'S A.B.BROWN 1 IS A DRY BOTTOM PULVERIZED
COAL (4.SX S. 13,010 BTU/L6) FIRED UNIT IN WEST FRANKLIN, INDIANA. FMC
SUPPLIED A DUAL ALKALI FGP SYSTEM DESIGNED TO REMOVE 85X OF THE FLUE GAS
S02. THE UNIT CONSISTS OF TWO THREE STAGE DISC CONTACTORS. A COLD SIDE ESP
PROVIDES PRIMARY PARTICULATE CONTROL, AND ONE CHEVRON MIST ELIMINATOR/MOD-
ULE PRECEDES A 498 FOOT ACID BRICK LINED STACK. THE SYSTEM PRODUCES A
FILTER CAKE WASTE PRODUCT WHICH IS DISPOSED IN AN ON SITE LANDFILL. THE
WATER LOOP CAN BE EITHER OPEN OR CLOSED. THE SYSTEM HAS BEEN OPERATIONAL
SINCE HARCH OF 1979.
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY
1
NEW 720.0 MU (GROSS)
720.0 MW (ESC)
COAL
.80 XS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 12/84
HENRY W. PERKEY 1 IS A WET BOTTOM LI6N1TE (C.PX S, 6300 eTU/LB) FIRED UNIT
PLANNED BY SOUTHWESTERN ELECTRIC POWER FOR LOCATION IN HALLSVILLE, TEXAS.
A CONTRACT HAS BEEN AWARDED TO THE AIR CORRECTION DIVISION OF UOP FOR FOUR
LIMESTONE SPRAY TOWERS (99«X EFFICIENCY). HIST ELIMINATION WILL BE PRO-
VIDED BY TWO STAGE CHEVRONS. AND THE STACK WILL BE ACID BRICK LINED. NO
REHEAT IS PLANNED. THE WATER LOOP WILL BE CLOSED, AND THE SLUDGE WILL BE
POZ-0-TEC STABILIZED. START UP IS EXPECTED BY DECEMBER, 1984.
31
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
NEW 194.0 MU (GROSS>
194.0 MW
COAL
3.50 XS BITUMINOUS
LIMESTONE
MR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 4.6X
STATUS 1 STARTUP 4/77
SPRINGFIELD CITY UTILITIES* SOUTHWEST 1 IS A PULVERIZED BITUMINOUS COAL
(?.5X S, 12.50C BTU/LP) FIRED BOILER LOCATED IN SPRINGFIELD, MISSOURI. THE
EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A COLD SIDE ESP FOLLOWED
BY TWO UOP LIMESTONE TCA MODULES WHICH WERE DESIGNED TO REMOVE 8GX OF THE
FLUE GAS S02. ONE CHEVRON/MODULE LEADS TO A 384 FOOT CEILCOTE LINED STACK.
THE DRY FLYASH STABILIZED SLUDGE IS OEWATERED BY A ROTARY DRUM VACUUM AND
TRUCKED TO A LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL SINCE APRIL, 1977.
SPRINGFIELD WATER, LIGHT &
DALLMAN
I
HEW 205.0 MU (GROSS)
205.0 MU (ESC)
COAL
3.30 XS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 5.91
STATUS 2 STARTUP 11/80
PWR DALLMAN 3 OF SPRINGFIELD WATER, LIGHT, AND POWER IS A PULVERIZED COAL
(3.3X S, lOtSOO BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN SPRINGFIELD,
ILLINOIS. RESEARCH COTTRELL IS SUPPLYING A LIMESTONE FGD SYSTEM DESIGNED
TO REMOVE 95X OF THE S02 FROM 850,000 ACFM OF BOILER FLUE G«S. A HOT SIDE
ESP WILL PRECEDE TWO PACKED TOWER ABSORBERS, ONE HORIZONTAL CHEVRON PER
MODULE, AND A 500 FOOT ACID BRICK LINED STACK. NO REHEAT WILL BE PROVIDED,
A SLUDGE DISPOSAL STRATEGY HAS NOT BCEN FINALIZED, BUT THE UTILITY IS CON-
SIDERING EITHER PONDING OR LANDFILL. FGD OPERATIONS SHOULD BEGIN IN
NOVEMBER, 198P.
ST. JOE ZINC
G.F. WEATON
1
RETROFIT 60.0 MW (GROSS)
60.0 MW (ESC)
COAL
2.00 XS BITUMINOUS
CITRATE
BUREAU OF MINES
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 11/79
G.F. WEATON 1, OWNED 61 ST. JOE ZINC, IS A COAL (3.CX S, 12,500 BTU/LB)
FIRED BOILER LOCATED IN MONACA, PENNSYLVANIA. THE BUREAU OF MINES RE-
TROFITTED A PROTOTYPE CITRATE FGD SYSTEM ON THIS UNIT, WHICH PROVIDES
POWER FOR THE LOCAL UTILITY GRID. ONE VENTURI SCRUBSER/ABSORBER TPAIN
FOLLOWS A COLD SIDE ESP. TwO CHEVRON MIST ELIMINATORS ARE FOLLOWED BY
A COMBINATION OF INDIRECT HOT AIR AND DIRECT COMBUSTION REHEATERS. AND A
102 FOOT FIBERGLASS LINED SCRUBBER STACK. THE SYSTEM SO 2 REMOVAL EFFICIEN-
CY WILL BE OVER 90X. THE WATER LOOP IS CLOSED LOOP MODE. THE FGD SYSTEM
COMMENCED OPERATION IN NOVEMBER OF 1979.
TAMPA ELECTRIC
BIG BEND
t
*EU 475.C MW (GROSS)
475.0 MU (ESC)
COAL
2.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 3/85
UNIT 4 AT TAMPA ELECTRIC'S BIG BEND STATION IS A PLANNED DRY BOTTOM PUL-
VERIZED COAL (2.5X S, 10,300 BTU/LB) FIRED UNIT TO BE LOCATED IN TAMPA,
FLORIDA. THE FGD PROCESS HAS NOT YET BEEN CHOSEN. AN ESP WILL PROVIDE
PRIMARY PARTICULATE CONTROL. THE FGD SYSTEM, WHICH WILL REMOVE 9"X OF THE
FLUE GAS S02, WILL INCLUDE AN INDIRECT HOT AIR REHEATER LEADING TO A 490
FOOT CONCRETE LINED STACK.
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE
1-10
RETROFIT 1450.0 MU (GROSS)
600.0 MU (ESC)
COAL
3.10 XS
MAGNESIUM OXIDE
RILEY ENVIRONEERING
ENERGY CONSUMPTION: ««**X
STATUS 3 STARTUP 12/81
UNITS 1 THROUGH 10 AT JOHNSONVILLE STATION OF TVA ARE COAL (2.6X 5, 10,750
BTU/LB) FIRED BOILERS LOCATED IN NEU JOHNSONVILLE, TENNESSEE. UNITED EN-
GINEERS HAS BEEN AWARDED A CONTRACT TO PROVIDE ENGINEERING ASSISTANCE TO
TVA FOR A 90Z EFFICIENT MAGNESIUM OXIDE FGD SYSTEM TO BE RETROFITTED ON
THESE UNITS. SULFURIC ACID WILL BE PRODUCED AS A BYPRODUCT FROM THIS SYS-
TEM, UHICH UILL FEATURE FOUR VENTURI SCRUBBER/ABSORBER TRAINS (ONE SPARE),
60X BYPASS REHEAT, AND A 600 FOOT STACK. START UP IS EXPECTED IN 1981.
TENNESSEE VALLEY AUTHORITY
PARADISE
1
RETROFIT 704.0 MU (GROSS)
704.0 MU (ESC)
COAL
4.20 XS
LIMESTONE
CHEHICO
ENERGY CONSUMPTION: *«**x
STATUS 2 STARTUP 3/82
PARADISE 1 OF TVA IS A 4.2X SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR AN 84.2X EFFICIENT
LIMESTONE FGD SYSTEM TO BE RETROFITT&D ON THIS BOILER. SIX VENTURI SCRUB-
BERS AND VENTURI ABSORBER TRAINS WILL FOLLOW AN ESP. INLET FLUE GAS WILL
BE USED TO HEAT WATER, UHICH IN TURN UILL BE USED TO REHEAT THE OUTLET
FLUE GAS. FORCED OXIDATION UILL BE USED IN ONE MODULE TO CONTROL SCALING
THROUGHOUT THE SYSTEM. THE UTILITY EXPECTS TO GET AN 8CX SOLIDS LANDFILL-
ABLE GRADE SLUDGE. OPERATIONS SHOULD START IN MARCH, 1982.
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION i
STATUS Of FGD SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
TENNESSEE VALLEY AUTHORITY
PARADISE
2
RETROFIT 70*.o MW (GROSS)
704.0 MW (ESC)
COAL
<..21 XS
LIMESTONE
CHEMICO
ENERGY CONSUMPTION: *»*«X
STATUS 2 STARTUP 6/82
PARADISE ? OF TVA IS A 4.2X SULFUR COAL FIRED UNIT LOCATED IN PAR*D1SE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR AN t4.2X EFFICIENT
LIMESTONE FGD SYSTEM TO BE RETROFITT6D ON THIS BOILER. SIX VENTURI SCRUB-
BERS AND VENTURI ABSORBER TRAINS WILL FOLLOW AN ESP. INLET FLUE GAS WILL
BE USED TO HEAT WATER, WHICH IN TURN WILL BE USED TO REHEAT THE OUTLET
FLUE GAS. FORCED OXIDATION HILL BE USED IN CNF MODULE TO CONTROL SCALING
THROUGHOUT THE SYSTEM. THE UTILITY EXPECTS TO GET AN PCX SOLIDS LANDFILL-
ABLE GRADE SLUDGE. OPERATIONS SHOULD START IN JUNE, 1982.
TENNESSEE VALLEY AUTHORITY
SHAWNEE
13A
RETROFIT 10.0 My (GROSS)
10.0 MW
COAL
2.90 XS BITUMINOUS
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 4/72
SHAWNEE 10 OF TVA IS A 2.9J SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
PADUCAH, KENTUCKY. MODULE 10A IS A RETROFIT PROTOTYPE LIME/LIMESTONE TCA
SYSTEM SUPPLIED BY THE AIR CORRECTION DIVISION, UOP. THE SYSTEM UTILIZES
A CHEVRON MIST ELIMINATOR AND A DIRECT COMBUSTION REHEATER, AND OPERATES
IN A CLOSED WATER LOOP. THIS TEST PROGRAM is FUNDED BY THE EPA WITH TVA AS
THE CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTEL CORP. OF SAN FOANCISCO
IS THE MAJOR CONTRACTOR, TEST DIRECTOR, AND REPORT WRITER. THE SYSTEM HAS
BEEN OPERATIONAL SINCE APRIL, 1972.
TENNESSEE VALLEY AUTHORITY
SHAWNEE
1DB
RETROFIT 10.0 MW IGROSS)
10.0 MW
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198C
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS POWER * LIGHT
SANDOW
I
NEW 545.0 My (GROSS)
382.0 MW (ESC)
COAL
1.60 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *«**X
STATUS 2 STARTUP 7/80
SANDOW t IS A PULVERIZED 1.6X SULFUR LIGNITE FJPEO BOILER OF TEXA? POWER
AND LIGHT UNDFR CONSTRUCTION IN ROCKOALE, TEX«S. COMBUSTION ENGINFEMNG IS
SUPPLYING THREE LIMESTONE SPRAY TOWERS FOF THIS UNIT. A COLO SIDE ESP WILL
PROVIDE PRIMARY PARTICULATE CONTROL. A 3 OX BYPASS REHEAT WILL 6E USED, AND
THE OVERALL S02 REMOVAL EFFICIENCY WILL BE 75?. THE SYSTEM WILL OPIRATE IN
A CLOSED WATER LOOP, AND THE SLUDGE WILL BE PONDED. START UP IS EXPECTED
IN JULY, 198C.
TEXAS POWER 8 LIGHT
TrflN OAKS
1
MEW 750.0 MW (GROSS)
750.C MW (ESC)
COAL
.7H XS LIGNITE
LIMESTONE
CHEMICO
ENERGY CONSUMPTION:
TWIN OAKS 1 IS A 0.75* SULFUR LIGNITE FlRED BOlLE' PLANNED BY 1EX«S POWER
AND LIGHT AND ALCOA FOR LOCATION IN BREMOND, TEXAS. A CONTRACT HA? pEEN
AWARDED TO CHEMICO FOP A LIMESTON? FGO SYSTEM ON THIS UNIT. START UP IS
EXPECTED IN AUGUST OF 1984.
STATUS 3
*** *X
STARTUP 9/84
TEXAS POWER £ LIGHT
TuIN OAKS
2
NEW 75C.n *W (GROSS)
750.P MW (ESC)
COAL
.7" XS LIGNITE
LIMESTONE
CHEMICO
ENERGY CONSUMPTION: ***«X
STATUS 3 STARTUP 8>85
TWIN OAKS 2 IS A D.75X SULFUR LIGNITt flRfD BOILER PLANNED BY TEXAS POhER
AND LIGHT AND ALCOA FOR LOCATION IN BREMONO, TEXAS. A CONTRACT HAS REEN
AWARDED TO CHEMICO FOR A LIMESTONE FGD SYSTEM ON THIS UNIT. START UP IS
EXPECTED IN AUGUST OF 1985.
TEXAS UTILITIES
FOREST GROVE
1
NEW 750.0 "W (GROSS)
750.C MW (ESC)
COAL
.80 XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTlONr ***«X
STATUS 5 STARTUP 0/81
TEXAS UTILITIES IS PLANNING A LIGNITt (C.8X S, 7000 BTU/LB) FIRED BOILER,
FOREST GROVE 1, WHICH WILL BE LOCATED IN ATHENS, TEXAS. THE UTILITY IS
PRESENTLY REOUEST1NG BIDS ON AN FGD SYSTEM FOR THIS UNIT. TWO ESP'S WILL
PROVIDE PRIMARY PARTICULATE CONTROL, AND NO STACK GAS REHEAT IS PLANNED.
START UP IS EXPECTED IN LATE 1981.
TEXAS UTILITIES
1ARTIN LAKE
1
NEW 793.0 MW (GROSS)
595.0 *W (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 4/77
TEXAS UTILITIES' MARTIN LAKE 1 IS A LIGNITE (n.9X S, 7380 BTU/LB) FIRED
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGD SYSTEM CONSISTS OF SIX PACKED SPRAY
TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02 REMOVAL EFFICI-
ENCY IS 7C.5X. TbO CHEVRONS/HODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP. INITIAL SYSTEM OPERATIONS TOOK
PLACE IN APRIL, 1977.
TEXAS UTILITIES
HARTIN LAKE
2
NEW 793.0 MW (GROSS)
595.0 MW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1.3X
STATUS 1
STARTUP 5/78
TEXAS UTILITIES* MARTIN LAKE 2 IS A LIGNITE (0.9X S, 738C BTU/LB) FIRED
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THf FGD SYSTEM CONSISTS OF SIX PACKED SPRAY
TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL POILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED F0» REHEAT. THE TOTAL DESIGN 502 REMOVAL EFFICI-
ENCY IS 70.5X. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP. INITIAL SYSTEM OPERATIONS TOOK
PLACE IN MAY, 1978.
34
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRA CT
TEXAS UTILITIES
1ARTIN L'K E
3
NEW 793.r *W (GROSS)
595.T MW (ESC>
COAL
.9" *S LIGNITE
LIMESTONE
RESEARCH COTTRELI
ENERGY CONSUMPTION
STATUS 1
1.3X
STARTUP 2/79
TEXAS UTILITIES' MARTIN LAKE 3 IS A LIGNITE (^.91 S, 738C BTU/LB) FIRED
BOILER IN TATUM, TEXAS. THIS UNIT IS EOUIPPED WITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLO SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGO SYSTEM CONSISTS OF SIX PACKED SPRAY
TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TQTAL DESIGN SOi REMOVAL EFFICI-
ENCY IS 70.51. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP. INITIAL SYSTEM OPERATIONS TOOK
PLACE IN FEBRUARY, 19?9.
TEXAS UTILITIES
1ARTIN LAKE
4
NEW 750.C1 MW (GROSS)
750.0 MU IESC)
COAL
.9" IS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: ***«X
STATUS 3 STARTUP 0/85
MARTIN LAKE 4 OF TEXAS UTILITIES IS A LIGNITE < ? • 9* Si 7380 BTU'LP> FIRED
BOILER UNDER CONSTRUCTION IN TATUM, TEXAS. A CONTRACT FOR A LIMESTONE FGD
SYSTEM FOR THIS UNIT HAS BEEN AWARDED TO RESEARCH COTTRELL. CONSTRUCTION
HAS NOT YET BEGUN ON THE FGD SYSTEM. FCD START UP IS EXPECTED IN 1985 OR
1986.
TEXAS UTILITIES
«IILL CREEK
1
NEW 750.C MW (GROSS)
750.0 MW (ESC)
COAL
..... XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«**X
STATUS 6 STARTUP 0/85
MILL CREEK 1 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TC PE
LOCATED IN HENDERSON, TEXAS. THE UTILITY HILL INCLUDE AN FGD SYSTEM ON
THIS UNIT. BUT NO DECISIONS HAVE PEEN MADE AS TO THE PROCESS TYPE OR
VENDOR. ESp's WILL PROVIDE PRIMARY PARTICULATE CONTROL. START UP IS
EXPECTED IN 1965.
TEXAS UTILITIES
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TUCSON ELECTRIC POWER
SPRINGERVILLE
2
NEW 370.0 MW <6ROSSJ
370.0 MW (ESC)
COAL
•**«* XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS I STARTUP 1/87
TUCSON GAS AND ELECTRIC WILL BE BUILDING TWO NEW UNITS IN SPRINGE"vILLE,
COLORADO. SPRINGERVILLE 1 AND 2. TH£ UNITS WILL F1BE PULVERIZED SUB8ITU-
MINOUS COAL (CI.53-0.69X S AND 85CO-89CC ETU/LB). A CONTRACT HAS BEEN
AWARDED TO JOY MANUfACTUR1NG/MIR0 ATOMIZER FOR A LIME/SPRAY DRYING FGD
SYSTEM TO CONTROL PARTICIPATE MATTER AND S02 EMISSIONS. THE SYSTEM WILL
BE DESIGNED TO ACCOMOOATE A REHEATER (SHOULD ONE BE REQUIRED) AND WILL
OPERATE IN A CLOSED WATER LOOP. CLEANED FLUE GAS WILL EXIT THf SYSTEM
VIA A 500 FOOT CONCRETE STACK. OPERATIONS ARE SCHEDULED TO BEGIN IN 1987
JNITEO POWER ASSOCIATION
STANTON
2
MEW SO.O MW (GROSS)
50.C1 MW (ESC)
COAL
.77 XS LIGNITE
LIME/SPRAY DRYING
KOMLINE 8 SANDERSON
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 1/82
THE UNITED POWER ASSOCIATION HAS PLANS FOR A PULVERIZED COAL (C.77» 5,
7000 BTU/LB) FIRED UNIT, STANTON 2, TO BE LOCATED IN STANTON, NORTH
DAKOTA. A CONTRACT HAS BEEN AWARDED TO KOMLINE AND SANDERSON FOR A
LIME SPRAY TOWER. A FABRIC FILTER SUPPLIED BY RESEARCH COTTRELL WILL bf.
DESIGNED TO REMOVE 99X OF THE PARTICULATE. THE SYSTEM WILL OPERATE IN
AN OPEN LOOP MODE WITH SLUDGE DISPOSAL TO BE IN A CLAY LINED SETTLING
POND. OPERATIONS ARE SCHEDULED TO COMMENCE IN JANUARY, 1982.
UTAH POWER & LIGHT
HUNTER
1
NEW 400.0 MW (GROSS)
360.f MW (ESC)
COAL
.55 XS BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: ***»X
STATUS 1 STARTUP S/79
HUNTER 1 OF UTAH POWER AND LIGHT IS A COAL (0.55X S, 12.JCO BTU/LP) FIKEO
UNIT IN CASTLEDALE, UTAH. CHEMICO SUPPLIED A PEBBLE LIME WET ScRUFBlNG
SYSTEM WHICH BECAME OPERATIONAL IN "AY, 1979. THE SCRUBBING SYSTE" IS DE-
SIGNED TO OPERATE IN AN OPEN WATER LOOP WITH AN SO? REMOVAL EFFICIENCY OF
8PX. PRIMARY PARTICULATE CONTROL is PROVIDED BY AN UPSTREAM ESP, «ND STACK
GAS REHEAT IS PROVIDED BY BYPASS. THE SLUDGE IS FL»ASH STABILIZED AND DIS-
POSED ON-SITE.
UTAH POWER 1 LIGHT
HUNTER
2
NEW 400.0 MW (GROSS)
360.0 MW (ESC)
COAL
.55 XS
LIME
CHEMICO
ENERGY CONSUMPTION:
STATUS 2
*** *X
STARTUP 6/80
UTAH POWER AND LIGHT'S HUNTER 2 IS A COAL <0.55* S, 12,50? BTU/LB) FIRED
UNIT UNDER CONSTRUCTION IN CASTLEDALE, UTAH. CHEMICO IS SUPPLYING A PEBBLE
LIME WET SCRUBBING SYSTEM DESIGNED TO OPERATE IN AN OPEN WATER LOOP WITH
AN S02 REMOVAL EFFICIENCY OF BOX. AN UPSTREAM ESP PROVIDES PRIMARY PARTIC-
ULATE CONTROL, AND A BYPASS SYSTEM PROVIDES STACK GAS REHEAT. THE SLUDGE
WILL BE FLYASH STABILIZED AND DISPOSED ON-SITF. START UP OF BOTH THE BOIL-
ER AND FGD SYSTEM IS EXPECTED IN JUNE, 19EO.
UTAH POWER t LIGHT
HUNTER
3
NEW 400.0 1W (GROSS)
400.0 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
CHEMICO
ENERGY CONSUMPTION: **««x
STATUS 3 STARTUP 0/83
UTAH POWER AND LIGHT HAS PLANS FOR TyO NEW UNITS, HUNTER 3 AND 4, TO BE
CONSTRUCTED IN CASTLEDALE, UTAH. A CONTRACT HAS BEEN AWARDED TO CHEMICO
FOR A LIME, NONREGENERABLE FGD UNIT FOR EMISSION CONTROL. THE PULVERIZED
COAL FIRED UNITS (0.55X S, 12,500 BTu/LB) ARE TO BEGIN OPERATIONS IN 1983
AND 1985, RESPECTIVELY.
JTAH POWER
HUNTER
4
NEW
t LIGHT
400.0 MU (GROSS)
400.0 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
CHEMICO
ENERGY CONSUMPTION:
STATUS 3 STARTUP
>*•»%
0/85
UTAH POWER AND LIGHT HAS PLANS FOR TyO NEW UNITS, HUNTER 3 AND 4, TO BE
CONSTRUCTED IN CASTLEOALE, UTAH. A CONTRACT HAS BEEN AWARDED TO CHEMICO
FOR A LIMF, NONREGENERABLE FGD UNIT FOR EMISSION CONTROL. THE PULVERIZED
COAL FIRED UNITS (0.55X S, 12,500 BTU/LB) ARE TO BEGIN OPERATIONS IN 1983
AND 1985, RESPECTIVELY.
36
-------
EPA UTILITY FGO S U & V E Y : JANUARY - P A (, C H
S ? C T I c r, i
STATUS CF F G D S Y S T £. |» $
1 DENT I F 1C « T! ON A P S T K* C T
JTAH POkFR R LIGHT hl'ST INbTC*.1 1 " F UTAH POED ]S A T J H.G E KT I * L L Y F I P E D PULVFR12EO COAL ( 9 . 5 5 X
HJNTINGTCN b, 1i,5": RTU/Lr) P C I L t K IN FSICt, UTAH. A COLD SlEE F£P TfifATS 1 , 7 <. 2 , C C C
1 AfFI-OF FLUEfA^AND ISFOLLCbEt)OiACHE''ICOLIF'EFGDS»STEMCCNcISTI\G
NEW 41":.? WW (GROSS) Of FOUfc SPRAY TC»ERS (cOX DESIGN EFFICIENCY). ONE FOUC PASS C H E V R "K /« PC U L E
36*." VH (ESC) F»OVlCiS "JST ELIVINA~]ON, AND A CC*eiN«TICN CF A STEAr TUBE ANt '•'.-Z~'l
COAL n^PASS ttHEATJPS HOOST THr GAS TcwpcfijTucf 45-5" DEG F. THE SYSTE* CP^f-
.55 *S BITUMINOUS ATES IN A CLCCED wATES LOOP, AND THF FLYASH STABILIZED SLUDGE IS T';UCKcD
Li»t TC A^ ON-?ITE L«NDF;LL. THE SYSTE* INCLUDES A t~c FOOT ACIC BOICK LI^EC
CHfMICO ST'CK, »SD HAS PtEN CPcfiATiONAL SINCE «»«Y OF 1 9 ? 6 .
ENERGY CONSUMPTION: 1.6*
STATUS 1 STARTUP 5/78
-------
EP« UTILITY F&D SURVEY: JANUARY - MARCH 198C
SECTION 7
DF.STGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD 5TSTFMS
COMPANY NAM?
PLANT NAME
UNIT NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING C'PACITY W/FGD - Mb
EQUIVALENT SCRUPBFD CAPACITY - »W
•• FUEL DATA
FUEL TYPE
FUEL GR«DE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - x
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 5!
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPF
SYSTEM SUPPLIER
NEW/RETRQFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN 8E»OVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
APSORBER SPAR* CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
ALAMMA ELECTRIC COOP
TOMfclGBEE
2
LER&Y
ALA(- OMA
255.:
2?;.3
1 7C.O
( 115CC PTU/LP)
COAL
BITUMINOUS
26749.
14.DC
7.?C
1.15
WET <:CRUPbING
LIMESTONE
PEAe-ODY PROCESS SYSTEMS
NEW
'.1
9/7°
9/7S
.0
.0
CLOSED
fl.
UC GPI«)
•* DISPOSAL
TYPE
LINED POND
PEPfORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPU1TY RELIABILITY UTILIZATION I REMOVAL PE» BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80
A
6
SYSTEM
35.8
5*. 7
61.5
90.7
*• PHOBLEMS/SOLUTIONS/COMMENTS
21.1
33.5
4P.1
744
357
DURING JANUARY UNIT 2 «AS UNAVAILABLE 6« HOURS DUE TO REPAIRS NFEOED ON
AN ABRADED EXPANSION JOINT AND A RUPTURF.D WASTE SLURRY LINE.
2/8"
A
B
SYSTEM
84.3
74.7
99.3
99.3
PROBLEMS/SOLUTIONS/COMMENTS
84.3
74.7
99.3
696
69£
691
THE UNIT 2 FGD SYSTEM OPERATED ALL BUT 5 HOURS CURING FEBRUARY, IN WHICH
TIME THE BOILER WAS PF1NG MOU&HT ON-LINE.
3/8C
A
b
SYSTEM
100.0
81. t
79.4
97.8
75.0
73.0
8P.9
744
6?4
669
-------
EPA UTILITY F6D SURVEY: JANUARY - PAHCH 1
-------
EP« UTILITY FGD SU»VEY: JANUARY - MARCH 198C
SFCT1CN
DrSIGN AND PERFORMANCE DATA FOR
DOMESTIC F&D SYSTff?
C OMPANY NAME
PLANT NAME
JNIT NUMBER
C ITY
STATE
GROSS UNIT GENEOAMN& CAPACITY - Ww
NET UNIT GENERATING CAPACITY W/FGD - *w
EOUIVALF.NT SCPUPFFD CAPACITY - Mu
• * FUEL DATA
FUEL TYPE
FUEL GRAD?
AVcRAGE HEAT CONTENT - J/G
AVERAGE AJM CONTENT - X
AVc»AGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - *
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYpr
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - *
INITIAL STAPT-UP DATE
COMMfRfjAL START-UP DATE
S02 BESI&N REMOVAL EFFICIENCY - X
PARTICULAR DFSIGM REMOVAL EFFICIENCY
ABSORBER SPASt CAPACITY INDEX - X
A9SORBER SPARE COMPONENTS INDE»
»• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* DISPOSAL
TYPE
«LAt-AMA CLECTRIC COOP
TOMfl&BEE
7
LEKCY
ALAbAWA
179.:.
COAL
26749. ( 1150C
lll5
WET SCRUPBING
LIMESTONE
PEAbODY PROCESS SYSTEMS
NEW
'.1
6/7"
6/79
fcS.^C
99.30
CLOSED
«.? C HC r-P»«)
LINED PO^fD
.. .__ . PE'f 0«MAMCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RFLIAPILITY UTILIZATION 1 REMOVAL PER SsOILfcG FGD C«F.
502 PART. HOURS HOURS HOURS FACTOR
1/80
A
B
SYSTEM 1CO.O
69.2
45.4
97.9
3". 5
20. C
47.1 744 3?t *<1
2/6'
3/BC
•* PROBLtMS/SOLUTIONS/COMMENTS
DURING JANUARY UNIT 3 HAS AVAILABLE THE ENTIRE MONTH.
33.3 1.1
1CC.C 7.4
'00.C 10C.C 7.4 e°6 ?4 24
•• PHOBLEWS/SOLUT10NS/COMMENTS
DURING FEBRUARY THE UNIT 3 BOILER AND FGD SYSTEM OPFB4TED ONLY ?4 HOURS.
A
b
SYSTEM
A
e
SYSTEM
.0
.3
.C
744
100.0
*• PROBLEMS/SOLUTIONS/CONMENTS
DURING MARCH THF UNIT 3 GENERATOR WAS KEPT OUT OF SFRVICt.
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH I9t'
SECTION 3
DESIGN AND PERFORMANCE DA^A fOK OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
&SOSS UNIT GENERATING CAPACITY - MW
\ET UNIT GENERATING CAPACITY W/FGD - l"w
EQUIVALENT SCRUPBC0 CAPACITY - «y
• * FUEL DATA
FUEL TYPE
FUEL GRAO?
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - t
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - I
IMT1AL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATt DESIGN REMOVAL EFFICIENCY - 3t
ABSORBER SPARf COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP UATEH - LITER/S
ALLEGHENY PObEB SYSTEM
PLE A*ANTS
1
BEL^ONT
WEST VIRGINIA
625.C
625.C
510.:
COAL
BITUMINOUS
c irccc
11. CC
WET SCRUFB INC-
LINE
BAECOCK ft yiLCCX
NEW
J/7'
**/•«
97. OC
59.55
CLOSED
(*»**• 6PM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEHAPHITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGO C»P.
SO? PART. HOURS HOURS HOURS FACTOR
1/8^ SYSTEM
2/80 SYSTEM
3/8? SYSTEM
** PROBLEMS/SOLUTIONS/COMHENTS
69C
744
NO INFORMATION WAS AVAILABLE ON THE OPERATIONS AT PLEASANTS 1 FOR THE
FIRST QUARTER 1980.
41
-------
EPA UTILITY FGP SURVEY: JANUARY - PARCH 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
NAMf
PLANT NAME
JV]f NUMBER
C MY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NiET UNIT GENERATING CAPACITY W/FGD - "W
EQUIVALENT SCFUPBFO CAPACITY - fu
API20NA ELECTRIC POKER COOP
APACHt
2
COCHISE
ARIZONA
1 95.0
1 75.0
195.0
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
** FGC SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NFy/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COM"ERCJ*L START-UP DATE
SOi DESIGN REMOVAL EFFICIENCY - X
COAL
BITbllNOUS
2326U. < 1*000 ETU/LP)
15.00
9. 30
.55
WFT SCRUBBING
LI" £ STONE
RESEARCH COTTHELL
NE\-
4. 1
P/ ?«
I/ 7?
25 .CO
PAKT1CULATE DESIGN REMOVAL EFFICIENCY - X S9.5C
APSORBER SPARE CAPACITY INDEX - X
AHSORBE" SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP yATER - LITER/S
•* DISPOSAL
TYPE
PERIOD MODULE AVAILABILITY OPERAB1LITY
• w1
• -'
OPEN
115.9 ( 1»4C GP^)
PONt
RELIABILITY UTILIZATION * ȣMOVAL PER BOILER FGD C*P.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 90.9 5P.3 8
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 15fc:
SECTION 5
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - MU
EQUIVALENT SC&UBBFD CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/&
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL STAPT-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PART1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - L1TER/S
** DISPOSAL
TYPE
- X
ARIZONA ELECTRIC POfcER COOP
APACHE
i
COCMISE
ARIZONA
195.0
1 75.C
195.0
COAL
BITUMINOUS
2326C.
15.00
9.00
.55
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
4.1
6/79
4/79
65.00
99.50
.0
.0
( 1TOCC 6TU/LB)
OPEN
340.2
POND
< 5400 6PM)
— — PERFORMANCE DATA— —
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UT1LI7ATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 91.7 91.7 91.7 91.7 97.40 744 744 682
•* PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY SOME OUTAGE TIME WAS DUE TO A PUMP MALFUNCTION.
OUTAGE TIME WAS ALSO CAUSED 8» A BROKEN FEED BELT TO THE LIMESTONE BALL
MILL.
Z/60 SYSTEM 95.6 74.1 96.0 71.4 97.40 696 671 497
•• PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY OUTAGE TIME MAS DUE TO A PRECIPITATOR FAILURE.
FORCED OUTAGE TIME WAS ALSO CAUSED BY A PUMP MALFUNCTION.
3/80 SYSTEM 91.0 91.C 91.0 91.0 744 744 677
** PROBLEMS/SOLUTIONS/COMMENTS
SOME OF THE OUTAGE TIME DURING MARCH OCCURRED BECAUSE OF PU«IP FAILURE.
OTHER OUTAGE TIME WAS CAUSED BY STICKING VALVES AND LIMESTONE FEED-BELT
PROBLEMS.
43
-------
EPA UTILITY FGD SU»VEY: JANUARY - WAPCH 198C
SECTION J
AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC fGD SYSTEMS
COMPANY MANE
PLANT NAME
UNIT NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - PI*
NET UNIT GENERATING CAPACITY W/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - MW
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - S
AVERAGE MOISTURE CONTENT - T
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - ?
*• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - *
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
302 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBED SPARF CAPACITY INDEX - X
ABSORBER SPARF COMPONENTS INDEX
•* HATEC LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
ARIZONA PUBLIC SERVICE
CHOLLA
1
JOSEPH CITY
ARIZONA
11<3.C
115.0
1 19.0
COAL
BITUMINOUS
23699.
13.50
15.00
.50
.D2
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
RETROFIT
3.4
10/7?
12/73
92.00
80.00
.0
< 10150 BTU/LFJJ
OPEN
7.6
I 120 GPM)
POND
...... ____..... —PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
PROBLEMS/SOLUTIONS/COMMENTS
X REMOVAL PER BOILER FGD ClP.
S02 PART. HOURS HOURS HOURS FACTOR
11/79
12/79
1/60
2/80
3/80
A
b
SYSTEM
A
B
SYSTEM
A
b
SYSTEM
A
e
SYSTEM
A
e
SYSTEM
77.0
9P.O
87.5
91. C
87.0
9C.5
95. C
99.0
97. C
100.0
99. Q
99.5
99.0
93. C
94.0
77.0
98.0
87.5
94.0
87.0
90. 5
9?.0
99.0
97.Q
ior.o
99.0
99.5
99.0
93.0
96.0
720 720 632
744 744 672
744 744 724
696 696 694
744 744 715
NO FORCFD OUTAGES UfRE REPORTED BY THE UTILITY FOR THE FIVE MONTH PER10P.
SOME SCHEDULED OUTAGE TIME HAS REQUIRED FOR REPAIR OF THE REHEATED DUCT-
WORK.
-------
EPA UTILITY fee SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC f6D SYSTEMS
NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/FGD - Mw
EQUIVALENT SCRUPBED CAPACITY - MW
«« FUEL OATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
»* FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEK/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP D»TE
S02 DESIGN REMOVAL EFFICIENCY - X
PAHT1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPAR? COMPONENTS INDEX
«* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* DISPOSAL
TYPE
ARIZONA PUBLIC SERVICE
CHOLLA
2
JOSEPH CITY
ARIZONA
357.0
25".0
150.0
COAL
PITUMINOUS
13.50
15.00
.50
.02
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
( 1?150 BTU/LB)
4/78
*•/ «»
75.00
X 99.70
33.0
1.0
OPEN
7.6
( 120 GPM>
POND
— —-—PERFORMANCE DATA-------
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD (. tP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
a/80 SYSTEM
3/80 SYSTEM
*» PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
NO INFORMATION IS AVAILABLE AS OF YET WITH RESPECT TO THE CHOLLA ? FGD
OPERATIONS.
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
C 1TY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY H/FGD - Mw
EOUIVALENT SCRUFBFD CAPACITY - I»W
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFU" CONTENT - Z
AVERAGE CHLORIDE CONTENT - *
** FGD SYSTEM
GENERAL PPOCE«S TYPE
PROCESS TYPt
SYSTEM SUPPLICR
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - *
PARTICULAU DESIGN REMOVAL EFFICIENCY - *
ABSORBER 5P«RE COMPONENTS INDEX
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
FARKINGTON
NEW MEXICO
1 75.0
175.0
1 75. C
COAL
SUBblTUMlNOUS
20CC<..
'2.nO
1?.30
.75
.07
WET SCRUBBING
LIME/ALKALINE FLYASH
( "600 BTU/LP)
RETROFIT
11/70
+ * / * *
59.00
1 .C-
------------------------------------------ PERFORMANCE DATA
PE»10D MODULE AVAILA9ILITY OPERABILITY RELIABILITY UTILIZATION
REMOVAL
? PART.
PER
HOURS
BOILER
HOURS
FGD CAP.
HOURS FACTOR
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS STARTED IN NOVEMBER 1979.
1/8? SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
•* PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT IS PRESENTLY IN THE S HAK E D OWN /DEBUGGI NG PHASE OF OPERATION.
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH
SECTION 3
DESIGN AND PERFORMANCE DAT* (OS OPERATIONAL DOMESTIC FGD SYSTEMS
C OWPAN* NAME
PLANT N * M E
JN1T NUMBER
C ITY
STftTE
GROSS UNIT GENERATING CAPACITY - MM
YET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
*• FUEL DAT»
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFU" CONTENT - *
AVERAGE CHLORIDE CONTENT - *
** FGD SYSTFM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL ST»RT-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PAHTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
FARM1NGTON
NEW MEXICO
1 75.5
1 75.0
1 75.0
COAL
SUBBITUMINOUS
23C04.
22.00
12.30
.75
.07
tiET SCRUBBING
LIME/ALKALINE FLVASH
CMEMICO
RETROFIT
( ?6CC BTU/Lp)
11/79
** / * *
99.00
1.0
PERFORMANCE DAT*
PERIOD MODULE *V«ILABILITY OPERAPILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FED CAP.
<02 PART. HOURS HOURS HOURS FACTOR
11/70 SYSTEM 720
12/79 SYSTEM 744
** PROBLEWS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS STARTED IN NOVEMBER 19?9.
1/8P SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
•* PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT IS PRESENTLY IN THE SHAKEDOWN/DEBUGGING PHASE OF OPERATION.
47
-------
EP» UTILITY FGD SURVEY: JANUARY - MARCH 198C
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC fGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
C JTY
STATE
GROSS UNIT GENERATING CAPACITY - M*
NET UNIT GENERATING CAPACITY W/fGD - *W
EQUIVALENT SCRUBBED CAPACITY - Mw
•• FUEL DATA
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - T
*• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPF
SYSTEM SUPPLIER
NEW/RETROF IT
ENERGY CONSUMPTION - X
INITIAL STAPT-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PART1CULATE DESIGN RtMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
ABIZON* PUBLIC SfRVjCE
FOUR CORNERS
3
FARKINGTON
NEW MEXICO
229.0
COAL
SUBBITUMINOUS
2CCG4.
23.10
12.30
.75
.07
WET SCRUBBING
LIME/ALKALINE FLYASH
CHEMCO
RETROFIT
( P60C BTU/Lp)
11/79
* * I * *
99.00
1.0
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
11/79 SYSTEM 720
12/79 SYSTEM 7*4
*• PBOBLEHS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS STARTED IN NOVEMBER 1979.
1/80 SYSTEM 744
2/80 SYSTEM C>96
3/80 SYSTEM 744
•• PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT IS PRESENTLY IN THE SHAKEDOWN/DEBUGGING PHASE OF OPERATION.
48
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1°l'
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F&D SYSTEMS
COMPANY NAME
PtANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGO - MU
EQUIVALENT SCRUBBED CAPACITY - "V
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PART1CULATE OFSIGN REMOVAL EFFICIENCY -
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
BIG "IVE"S ELECTRIC
GREEN
1
KENTUCKY
24?.0
2: -r. c
COAL
BITUMINOUS
2267s.
2T. 00
11.00
?.75
WET SCRUBBING
LJNE
AMERICAN AIR FILTER
NEW
( 975C EiTU/LP)
12/79
12/79
9?.00
99.00
1.0
CLOSED
POZ-0-TEC
(*****
_ ._._. — PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 744
2/8T SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FIRST QUARTER, 1980.
49
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 2
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Ntf
NET UNIT GENERATING CAPACITY W/FGD - "W
EQUIVALENT SCRUBBED CAPACITY - MW
CENTSAL ILLINOIS LIGHT
DUCK CREEK
1
CANTON
ILLINOIS
4 14.0
378.0
378.C
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - I
FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SU°PLIFR
NEy/RETROFIT
ENERGY CONSUMPTION - *
INITIAL STABT-UP DATE
COMMERCIAL START-UP DftTE
S02 DESIGN REMOVAL EFFICIENCY - X
PAHTICULATE DFSIGN REMOVAL EFFICIENCY
ABSORBER SPAR? COMPONENTS INDEX
WATER LOOP
TYPE
FRESH MAKF-UP WATER - LITER/S
COAL
BITUMINOUS
24423. < 1C5CC BTU/LP)
9.12
1«.OC
3.30
.03
WET SCRUPBING
LIM ESTONE
RILEY STOKER/ENVIRONEERING
NEW
2.9
7/76
8/7°
•5.00
CLOSED
7,7. a
600 GP!»)
•• DISPOSAL
TYPE
LINED POND
..—.. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPtRAPILITY RELIABILITY UTILIZATION
* REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 A
B
C
D
SYSTEM
21. P
58.5
17.1
29.2
32.4
27. C
67.6
1C. 6
31.9
35.2
29.8
65.9
2?. 3
35.4
38.3
24.8
5».5
17.1
29.3
32.4
744 684 241
*• PROBLtMS/SOLUTIONS/COMMENTS
2/80 A
B
C
D
SYSTEM
11.8
72.7
70.7
70.2
49.7
OUTAGE TIME WAS REGUIRED DURING JANUARY FOR RECYCLE TANK COVERING WORK.
THE MIST ELIMINATOR SECTION PLUGGED ALONG WITH THE NOZZLES HINDERING
SYSTEM OPERATIONS. THE MIST ELIMINATOR DRAIN LINE WAS MODIFIED ALSO
CAUSING OUTAGE TIME.
OTHER PROBLEMS ENCOUNTERED DURING THE MONTH INCLUDED: A PLUGGED LIMESTONE
FEEDER, INLET DAMPER PROBLEMS, SLURRY SUPPLY HEADER LEAKS AND STORAGE
PUMP DISCHARGE VALVE REPAIRS.
11.8
72.7
70.7
41.2
49.1
12.5
73.5
71.5
47.8
51.9
11.8
72.7
70.7
41.2
49.1
696 696
342
50
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 196"
CENTRAL ILLINOIS LIGHT: DUCK CREEK 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIAPILITY UTILIZATION * REMOVAL PE" BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS fACTOR
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY SOME OUTAGE TIME MAS DUE TO MODULE CLEANING AND THE
CLEANING OF THE MIST ELIMINATOR SECTION.
THE INLET DAMPER DRIVE WAS REPLACED DURING THF MONTH.
REPAIR OF THE FIBERGLASS ON THE SLURRY RECYCLE LINE HINDERED OPER-
ATIONS DURING THIS MONTH.
THE RECYCLE DISCHARGE VALVE WAS REPLACED CAUSING SOME DOWN
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONSKOMMENTS
NO INFORMATION WAS AVAILABLE FOR THE MONTw OF MARCH.
51
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGO - I" W
EQUIVALENT SCRUBBED CAPACITY - MM
•• FUEL DATA
FUEL TYPE
FUEL GRADF
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - ?
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEb/RETROFIT
ENERGY CONSUMPTION - X
INITIAL STAPT-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - L1TER/S
•* TREATMENT
TYPE
- X
CENTRAL ILLINOIS PUBLIC SERV
NEW TON
1
NEW TON
ILLINOIS
617.C
575.0
617.0
COAL
BITUMINOUS
25353.
4.00
2.25
.20
WET SCRUBBING
DUAL ALKALI
BUELL/ENVIROTECH
NEW
( 1T9CC BTU/LP)
9/79
12/79
95.00
99.50
1.0
CLOSED
POZ-0-TEC
(•**** GPM)
. ._.... . -PERFORMANCE DATA-----
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
2/8?
* REMOVAL PER BOILER FGD c*p.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 A
B
C
D
SYSTEM
68.7
66.4
52.2
21. C
52. r
57.1
60.6
48. S
19.1
4t.4
63.5
64.9
6H.5
26.3
57.8
55.5
5?. 9
47.4
1?.5
45.1
744 723 336
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY TESTS WERE CONDUCTED TO CERTIFY THE GAS EMISSIONS MONITOP
AT NEWTON.
A
ti
C
D
SYSTEM
61.1
74.4
78.2
f*
• v
53.4
42.4
55.7
5«.5
.0
30.2
45.0
57.7
59.1
42.4
55.7
5?.5
.0
39.2
696 696
:73
PROBLEMS/SOLUTIONS/COMMENTS
J/80
53.4
47.0
44.5
DURING FEBRUARY THE D MODULE WAS UNAVAILABLE DUE TO THE COLLAPSE OF THE
PRECOOLfR MIST ELIMINATORS CAUSED BY A TEMPERATURE EXCURSION.
52.6
42.3
41.1
53.1
4P.C
46.5
52.3
42.1
41.0
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 196?
CENTRAL ILLINOIS PUBLIC SERW: NEWTON 1
-------
EPA UTILITY FGD SU"»ET: JANUARY - MARCH 198C
SFCTJON 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEM?
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/fGD - My
EQUIVALENT SCRUBBED CAPACITY - MW
*• FUEL DAT*
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - x
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
•* HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
COLORADO UTE ELECTPIC «SSN.
CRAIG
2
C"AIG
COLORADO
1,1.7.0
4:,;. o
447.0
< 10000 E-TU/Lp)
COAL
SUBBITUMINOUS
23260.
S.OO
16.00
.45
.00
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
NEW
5.4
8/79
6/80
85.00
99.80
1.0
CLOSED
19.9
MINEflLL
( 316 6PM)
. . ._.—.............. PEP fORM AN CE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD C»P.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
6<>6
744
THE BOILER WAS DOWN AT THE END OF THE PERIOD DUE TO TURBINE RELATED
PROBLEMS.
WHEN FULL LOAD OPERATIONS HERE ATTEMPTED CONTROL PROBLEMS WERE ENCOUNTERED
WITH THE SCRUBBER.
PROBLEMS WITH OPENING/CLOSING THE BYPASS DAMPER HAVE BEEN ENCOUNTERED.
LARGER OPERATORS ARE BEING LOOKED AT TO SOLVE THE PROBLEM.
54
-------
EPA UTILITY fGD SURVEY; JANUARY - MARCH 198P
SECTION ?
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGC SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY -MM
NET UNIT GENERATING CAPACITY U/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DAT*
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
COLU1&US & SOUTHERN OHIO ELEC.
CONESVILLE
5
CONESVILLE
OHIO
411. C
375.0
411.0
COAL
BITUMINOUS
?5i?7.
15.1C
7.50
4.67
( 10850 6TU/LP)
•* FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL ST«RT-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE OPEN
FRESH MAKE-UP WATER - LITER/S 31.5
** TREATMENT
TYPE POZ-0-TEC
•* DISPOSAL
TYPE POND
WET SCRUF8ING
LIME
AIR CORRECTION DIVISION, UOP
NEW
*.9
1/77
2/77
89.50
.?C
.0
.0
< 500 GPM)
..—... _—..__.._pEBfORBAN£E
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGC C«P-
S02 PART. HOURS HOURS HOURS FACTOR
1/80 A 25.0 38.0 45.0 13.0
B 29.0 50.0 59.0 17.0
SYSTEM 27.0 44.0 52.0 15.0
744 255 112
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY A BOILER OUTAGE OCCURRED FROM THE FIRST OF THE MONTH TO THE
TWENTIETH, DURING WHICH TIME MAINTENANCE WAS PERFORMED ON THE FGD SYSTEM.
2/80
A
B
SYSTEM
90.0
93.0
92.0
6J.O
69.0
66.0
77.C
84.C
81.0
31.0
34.0
33.0
696 348
230
** PROBLEMS/SOLUTIONS/COMMENTS
A BOILER OUTAGE LASTING APPROXIMATELY 17 DAYS ALSO OCCURRED DURING
FEBRUARY.
5/80
A
B
SYSTEM
88.0
88.0
88.0
82.0
81.0
82.0
82.C
81.0
82.C
82.0
81.0
82.0
744 744
610
55
-------
EP» UTILITY FGD SURVEY: JANUARY - MARCH 198C
COLUMBUS 6 SOUTHFRM OHIO ELEC.: CONESV1LLE 5 KONT.J
pEBfCRMANCF DATA
PERIOD MODULE AVAILABILITY OPE R AE> I L IT Y RELIABILITY UTILIZATION X REMOVAL PER BOllE" FGO C»P.
«02 PAST. HOURS HOURS HOURS fACIOR
•* PROBLIWS/SOLUTIONS/COMWENTS
DURING MARCH PROBLEMS NERE EXPERIENCED WITH THE IUC? SLUDGE STABILIZATION
PROCESS AND SOMF OUTAGE TIKE RESULTED. ALSO DURING MARCH SOME GRlt RODS
EC REPL'CING «ND SOME RUBBER LINER FAILURES OCCURRED.
56
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 19£r
SECTION 2
DE57GN AND PERFORMANCE CA^A FOR OPERATIONAL DOMESTIC f&D
COMPANY NAME
PLANT NAME
JNIT NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - M*
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - Mtt
COLU»bUS & SOUTHERN OHIO ELEC.
CONESVILLE
6
CONcSVlLLE
OHIO
01. j
375.:
411. j
«• fUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HfAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
•« FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYP?
SYSTEM SUPPLIER
NEn/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SOe DESIGN REMOVAL EFFICIENCY - X
PARTICULAR DESIGN REMOVAL EFFICIENCY
APSORBER SPAR? CAPACITY INDEX - X
ABSORBER SPARF COMPONENTS INDEX
»« yATEB LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
** DISPOSAL
TYPE
COAL
PITU"INOUS
25Z37. ( 1085C PTU/LP)
15.10
7. 50
4.67
.01
hET SCRUF>6INC
LIME
AIR CORRECTION DIVISION, OOP
NEW
3.9
6/7?
* * / * *
89.5C
* ."0
OPEN
21.5
POZ-0-TEC
POND
GPM)
. ...... . . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEPAPILITY RELIABILITY UTILIZATION X REMOVAL PE" BOILER FGD C*P«
SO? PART. HOURS HOURS HOURS FACTOR
1/60 A
e
SYSTEM
88.0
89.C
*• PROBLEMS/SOLUT10NS/COMHENTS
74.0
78.0
76.0
74.0
7?.C
76.?
74.0
7S.O
76.0
744
743
565
NO MAJOR FGD RELATED PROBLEMS WERE REPORTED FOR JANUARY.
2/80
A
B
SYSTEM
87.C
92.0
90.0
75.0
81.0
78.0
78.0
85.0
82.0
69.0
75.0
72.0
6<>6 642
501
PROBLEHS/SOUUTIONS/COHHENTS
3/80
A
B
STSTE"
93.0
94.0
94.0
IN FEBRUARY, MIST ELIMINATOR N072LE PLUGGING OCCURRED CAUSING SOME OUTAGE
TIME.
69.0
76.0
73.0
69.0
76.0
73.0
15.0
16.0
16.0
744
163
119
57
-------
EP* UTILITY F6C SURVEY: JANUARY - MARCH 198C
COLUMBUS 8 SOUTHERN OHIO ELEC.: CONESVILLE 6 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPHITY RELIABILITY UTILI?ATION * REMOVAL PcR &OJLEP FGD C«F.
SO? F««T. HOURS HOUCS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMWENTS
THE BOILER WENT DOWN ON MAPCH 9TH FOR A BOILEP/TURBIN£ INSPECTION AND
REMAINED DOWN THROUGH THE END OF THE MONTH.
58
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1 9 fc '
SFCTION ;
DESIGN AND PERFORMANCE DATA F1R OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JM T NUMBER
i ITT
STATE
&COSS UNIT GENERATING CAPACITY - Mi,
SET UNIT GENERATING CAPACITY Y/FGD - »b
tOu!VAL?NT SCRUBBED CAPACITY - MM
• < fUE L DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVE'A&E SULFU" CONTENT - X
AVERAGE CHLORIDE CONTENT - *
* * FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NE./RETROFIT
ENERGY CONSUMPTION - J
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - 1
PAKTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
LOOP
TYPE
fRESH MAKE-UP WATER - LITER/S
• TREATMENT
TYPE
• DISPOSAL
TYPE
COOPERATIVE POUE" ASSOCIATION
COAL CREEK
1
UND £ SfcOOD
NORTH DAKOTA
5*5.:
4^5.:
327.:
COAL
LIGNITE
14^6.
7.u
30.8!
. i-
ETU/LP)
yET SCRUPB1NG
LIMP/ALKALINE
COMLUSTION ENGINEERING
NEW
8/7"
t, * / * *
?'.3C
9-5.50
OPEN
FLYASH STASILIJATION
LINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABJL1T1 RELIAPILITY UTILIZATION * REMOVAL PE» BOILER FGD C«P.
SO? PART. HOURS HOURS HOURS FACTOR
1/S? SYSTEM 1CP.O
** PROBLE»S/SOLUTIONSyCOMMENTS
96.1
715
715
DURING JANUARY TWO MODULES AT A TIME WERE TAKEN OFF-LINE FOR INSPECTION
AND CLEANING. SOME CRACKED NOZZLES AND PLUGGAGE WERE FOUND DURING THE
INSPECTION.
SOME OUTAGE TIME DURING THE MONTH WAS CAUSED BY BOILER RELATED PROBLEMS.
A BOILER TRIP WAS CAUSED BY THE TURBINE.
AN HOUR OUTAGE TIME WAS NECESSARY DUE TO A LOSS OF POWER TO THE CONTROL
SYSTEM. ABNORMAL DRUM LEVEL WAS ALSO ENCOUNTERED.
A THREE TO FOUR HOUR OUTAGE WAS SCHEDULED TO MAKE REPAIRS ON THE EOUIPMFNT.
2/80 SYSTEM 100.0 99.9 696 695 695
** PROBLEMS/SOLUTIONS/COMMENTS
WHILE THE BOILER WAS OFF-LINE DUE TO ID FAN TROUBLE CAUSED BY ELECTRICAL
GROUNDING, TWO MODULES WERE TAKEN OFF LINE SO CALIBRATIONS COULD BE DONE.
3/60 SYSTEM
100.0
96.1
74*
715
715
59
-------
EPA UTILITY FGD SU»VEY: JANUARY - MARCH 1980
COOPFRATIVE POWER »SSOC1ATION: COAL CREEK 1 tCONT.)
p£RfORWANC?
PERIOD MODULE AVAILABILITY OPE&APIL1TY RELIABILITY UTU17AUON * REMOVAL PE» BOILER fGD C«P.
<02 PART. HOURS HOUBS HOURS FACTOR
** PROBLEWS/SOLUTIONS/COM^ENTS
THE BOILER TRIPPED THREE TIMES DURING THE MONTH. ONE TRIP WAS DUE TO THE
CUT DOWN OF TRANSMISSION POWER.
THE UNIT WAS DOWN WITH THE BOILER FOR FOUR HOURS TO CLEAN THE FILTER ON
THE STATOR COOLING PUMPS.
DURING MARCH STACK EMISSION TESTS HERE RUN. THE SYSTEM OPERATtD WITH ONE
MODULE DOWN DURING TESTING.
60
-------
UTILITY FGD SURVEY: JANUARY - MlfcCH
SfCTlON I
DESIGN AND PERFORMANCE DATA f Of OPERATIONAL DOMESTIC F&D SYSTEM?
COMPANY NAME
PLANT N«ME
JM T NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - W*
NET UNIT GENERATING CAPACITY W/FGD -
EQUIVALENT SC"UPB?C CAPACITY - MW
DUCUESNE LIGHT
ELK fcMA
1-4
ELR «"A
PENNSYLVANIA
ST'.C
475.0
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
•« F&D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO? DESIGN REMOVAL EFFICIENCY - X
P«RT1CULATE DESIGN REMOVAL EFFICIENCY -
ABSORBER SPAR? CAPACITY INDEX - X
APSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*« TREATMENT
TYPE
•• DISPOSAL
TYPE
COAL
244".;.
tl.CC
MET SCRUPbING
LIME
CHEM1CO
RETROFIT
3.5
10/75
1C/75
£7.30
•59.:o
35.C
1.?
OPEN
( 11J5C ErTU/LP)
POZ-0-TEC
LANDFILL
<««.««
... PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILISATION x REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
12/79
101
ZD1
301
401
5CM
SYSTEM
1CO.O
100.0
100. ?
P8.1
100.0
100.0
51.6
9C.9
10P.O
tf.t
100.0
1CO.C
1CO.C
100.0
96.1
8A.4
100.0
100.0
*?.5
85.5
10C.O
61.5
100.0
98.7
744 700 587
PROBLEMS/SOLUTIONS/COMMENTS
101
2C1
301
95.8
87.1
84.6
THERE HAVE BEEN NO SCRUBBER-RELATED OUTAGES OVER THE SEPTEMBER THRU
DECEWBE* PERIOD.
THE SLUDGE IS NOW BEING TRUCKED TO A REMOTE SITE 10 MILES *WAY CAUSING
OPERATING COSTS TO INCREASE.
THE NEW S02 WONITOfi HAS PLUGGED ONLY ONCE SINCE OCTOBEd AHD HAS REOU1REC
ONLY 4 HOURS OF MAINTENANCE PER WEEK.
91.2
100.0
100.0
94.8
84.6
75.2
87.1
84.6
61
-------
EPA UTILITY FGD SU'VEt: JANUARY - MARCH 198C
DJQUfSNE LIGHT: FLRAMA 1-4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAI LAB I LIT» OPERAEILITY RELIABILITY UTILIZATION
TI PEMOVAL PER BOILER FGD c»p.
SO? PART. HOURS HOURS HOURS FACTOR
401
501
SYSTEM
86. 4
100.0
100. C
55.6 7?.1 45.?
100.0 ic:>.o 1CO.C
100. C 1C".C 9?. 2
744 613 528
101
201
301
401
501
SYSTEM
100.0
100.0
100.0
100. n
77.6
100.0
85.4
100.0
10C.C
1CO.C
56.8
10P.C
100.0
100.C
1Cn.C
1CC.C
64.0
100.C
96.6
100.0
7^.7
4C.Z
9?.0
493
427
** PR06LEWS/SOLUTIONS/COMPENTS
3/80 SYSTEM
THE S02 MONITOR IS STILL OPERATING WELL AND HAS LOGGED SIX MONTHS OF
OPERATION. THE TWO RUBBER LINED WORMEN RECYCLE PUMPS HAVE NOW LOGGED
14,000 HOURS AS OF FEBRUARY 198C AND ARE STILL OPERATING WITHOUT ANY
PROBLEMS. THE HIGH AVAILAPILITIES ARE DUE TO THE 5TH MODULE BEING A TRUE
SPARE.
THE S02 MONITOR IS STILL OPERATING WELL AND HAS LOGGED SIX MONTHS OF
744
•* PROBLtlS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE MONTH OF MARCH,
-------
EPA UTILITY FGD SURVEY: JANUARY - PARCH 19fa:
SECTION 3
DESIGN «ND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT SAME
JNl T NU*B E P.
CITY
STATE
GROSS UNIT GENERATING CAPACITY - I" W
SET UNIT GENERATING CAPACITY W/FGD
EQUIVALENT SCRUBBED CAPACITY - MW
DUGUESNE LIGHT
PHILLIPS
1-6
SOUTH HEIGHT
PENNSYLVANIA
4 . o. . 0
37T.CI
4 1 :. 0
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - »
AVERAGE CHLORIDE CONTENT - *
COAL
BITUMINOUS
Ztfc'j.
16. 27
<.D2
1 .92
BTU/Lp)
>* FGD SYSTEM
GENERAL PBOCE5S TYPE '
PROCESS TYPE
SYSTEM SUPPLIER
NEw/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTUULATE DESIGN REMOVAL EFFICIENCY - X
ABSORBER SPAR? CAPACITY INDEX - X
ABSORBER SPARC COMPONENTS INDEX
•« WATER LOOP
TYPE
FRESH MAKE-UP MATES - LITES/S
WET SCfiUP&INt
LIME
CHEMICO
RETROFIT
?.*
7/7'
* * / * *
b7.CC
99.00
1?.0
.6
OPEN
<*•*«•
•* TREATMENT
TY PE
POZ-0-TEC
DISPOSAL
TYPE
LANDFILL
... PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAEILITY RELIABILITY UTILHATION t REMOVAL °E» BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
12/70
101
201
3C1
401
SYSTE"
99
90
77
67
.0
.9
.7
.7
.1
10?
ior
100
7;
.c
.c
.c
.0
.c
1CC.
9°.
61.
6B.
^
0
6
?
r
•
10C.
90.
77.
67.
0
0
o
0
0
744 567 494
PROBLEMS/SOLUTIONS/COMMENTS
101
201
331
401
SYSTEM
98.1
100.0
97.6
73.9
PRESENTLY THE UTILITY HAS BEEN ADDING SOBIUM ThlCSULFATE TO THE LIME TO
PREVENT SCALE FORMATION. THIS PROCESS HAS IMPROVED SO? COLLECTION AS
MELL.
THE SCRUBEER FAN HOUSING LINERS ARE BEING REPLACED.
THE MECHANICAL COLLECTORS A9E BEING UPGRADED TO IMPROVE THE QUALITY OF
THE MET SLUDGE.
.0
IjC.O
100.C
10?.0
89. C
98.0
10C.D
9'.5
73.9
.0
93.3
99.0
9*.0
73.0
744
6"4
536
63
-------
EPA UTILITY FGC SURVEY: JANUARY - MARCH 198C
OJQUESME LIGHT: PHILLIPS 1-6 (CONT.)
PERIOD MODULE AVAILABILITY
i/60 1P1
2C1
301
401
SYSTEM
13.7
91.6,
8ft.?
94.?
71.4
OPERABIL ITY
17.3
1GP.C
1CO.O
1 j ? . C
79.3
RFLI AP1L ITY
17.7
91.7
S6.C1
94 . "•
71.4
UTILIZATION * REMOVAL PE° BCILER FGD C»P.
?o?
1T.7
91.7
84.6
9". 5
7".1
PART. HOURS HOURS HOURS FACTOR
t°6 551 488
** PROBLE-S/SOLUTIONS/COMMENTS
SODIUM THIOSULFATE ADDITION CONTINUED THROUGH THE FIRST GiUARTER AND THE
MIST ELIMINATOR SCALING HAS bEE >' SIGNIFICANTLY REDUCED. ?07C-500C HOURS
OF OPERATION HAVE BEEN LOGGED WITHOUT MIST ELIMINATOR SCALE UP. THE
UTILITY REPORTS THAT $02 REMOVAL EFFICIENCY HAS IMPROVED ?X DUE TO THIS
AS WELL. THt UTILITY IS LOOKINC INTO THE ADDITION OF SODIUM THIOSULFATF
AT ELRAMA.
THE FAN RUBBfcR LINE'S HAVE BEEN A CONT1NUAL PROELEM. TWO WILL BE REPLACED
WITH INCONEL THF NEXT TIME THE RUBBER LINERS FAIL.
THE PHILLIPS F&D SYSTFM HAD A SYSTEM AVAILABILITY OF 71.&Jr FOR THE YEAR
1979.
3/8n SYSTEM 744
*• PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE MONTH OF MARCH.
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 19tr
SECTION ?
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEM*
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - M«
NET UNIT GENERATING CAPACITY W/FGO - »W
EQUIVALENT SCRUBBED CAPACITY - Mw
INDIANAPOLIS POWFR & LIGHT
PETERSBURG
r
PETERSBU»G
INDI ANA
512.?
515.C
532. 3
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - If
AVERAGE SULFU" CONTENT - X
AVERAGE CHLORIDE CONTENT - I
COAL
BITUMINOUS
25C3*.
( 1"75C PTU/LP)
F&6 SYSTEM
GENERAL PROCESS TYPE
PROCESS TYP*
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
WET SCRUPBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEW
2.4
12/77
12/77
tc.OC
95.3C
.6
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
•• TREATMENT
TYPE
•« DISPOSAL
TYPE
POZ-O-TEC
LANDFILL
PERFORMANCF BATA
PcRlOO MODULE AVAILABILITY OPE«AP1L1TY RELIABILITY UTILIZATION
t RfcHOVAL PER BOILER
S02 PART. HOURS HOURS
FGD CAP.
HOURS FACTOR
1/bO SYSTEM
i/80 SYSTEM
3/6" SYSTEM
744
694
744
PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER 1980, THE ENTIRE SCRUBBER PACKING BED WAS LOST
DUE TO EXCESSIVE WEAR OF THE NEOPRENE FOAM PACKING PALLS. THESE ARE TO
BE REPLACED IN APRIL, AT WHICH TINE THE UNIT WILL BE TAKEN OFF LINE TO
ACCOMODATE THE REPAIR.
BYPASS DAMPER FAILURES ALSO OCCURRED AND ARE REPORTED TO BE A CONTINUAL
PROBLEM. MODIFICATIONS WERE MADE TO THE GULLOTINE TYPE DAMPERS DURING
THE PERIOD.
65
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SFCTION ?
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTFMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - «y
EQUIVALENT SCPUPBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEy/RETBOfIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN HE"OVAL EFFICIENCY - I
PARTKULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
KANSAS CITY
HAW THORN
1
KANS9S CITY
MISSOURI
9?.0
J5.T
91.9
COOL
BITUMINOUS
227Q5.
11 .CO
POWER K LIGHT
( 9600 BTU/IP)
.60
yET SCRUPbING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
11/7?
* * / * *
70.00
59.00
CLOSED
<**.»« GFP)
FLYASH STABILIZATION
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPIL1TY RELIABILITY UTILIZATION T &Ef>OVAL PE« BOILER FGD C»P.
SO? PART. HOURS HOURS HOURS FACTOR
13/79
11
12
IT)
/79
SYSTEM
SYSTEM
SYSTEM
100
100
100
.0
.0
.0
10C.
100.
100.
0
0
0
91
38
9?
.0
.0
.3
744
720
744
677
274
6?4
677
274
684
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE VIRTUALLY 100Z Of THE TIME THE BOILER
OPERATED. THE LOW NOVEMBER FIGURES ARE BUE TO A 406 HOUR BOILER OUTAGE
CAUSED PY SUPERHEAT TUBE LEAKS AND A 4? HOUR OUTAGE CAUSED PY ECONOMIZE'
LEAKS.
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
97.0
100.0
100.0
744
696
744
696
744
S92
696
744
66
-------
EPA UTILITY FGO SUfcVEl: JANUARY - PARCH 196"
KANSAS CITT POWtR X LIGHT: HAWTHORN 3 KONT.)
-PERFORMANCE DATA
PERIOD MODULE »VA]LAaiLITl OPERAFILITH RFLIAP1LITV UT1L17AT10N t B£l«OV*L P£" bOILER FGO C*P.
SO' PART. HOUPS HOURS HOURS FACTOR
** PROBIEWS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE 1O^X OF THE TIME THE BOILER OPERATED. NO
PROBLEMS WERE ENCOUNTERED.
-------
EPA UTILITY FGt> SURVEY: JANUARY - MARCH 19?C
SFCTION 3
DESIGN AND PERFORMANCE DAT* FOR OPERATIONAL DOMESTIC FtD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HFAT CONTENT - J/G
AVERAGE ASH CONTENT - x
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFU" CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITJAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARF COMPONENTS INDEX
«• WATER LOOP
TYPF
FRESH hAKF-UP WATER - LITER/S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
- X
KANSAS CITY POWER K LIGHT
HAWTHORN
4
KANSAS CITY
MISSOURI
90.?
9C.O
COAL
BITUMINOUS
22795.
11.Co
.6C
( 9800 6TU/LB)
WET SC
LIME
COMbUSTION ENGINEERING
RETROFIT
2.2
8/72
* * / * *
7T.OC
99.OC
.6
CLOSED
(***** 6PM)
FLYA'H STABILIZATION
POND
... .—.- ...—- — .. PERFORMANCE DATA--
PERIOD MODULE AVAILABILITY OPERAPHIM RELIABILITY UTILIZATION t REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOUPS HOURS FACTOR
ID/79
11 /79
1Z/79
SYSTEM
SYSTEM
SYSTEM
100
100
too
.0
.0
.0
100.
100.
0
0
89
4C
.0
.0
.0
744
72C
744
662
2P8
r*
662
268
:
•• PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT WENT DOWN ON NOVEMBER 26TH FOR A TURBINE GENERATOR OVERHAUL.
1/8? SYSTEM 100.0 .0 744 C 0
H/60 SYSTEM 10C.O ,C 696 C 0
3/60 SYSTEM 100.0 .0 744 C 0
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT REMAINED OFF LINE THROUGH THE FIRST OUARTED 198C BECAUSE OF THE
TURBINE GENERATOR OVERHAUL.
68
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 198?
SECTION 3
DESTGN *ND PERFORMANCE DAT/) FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UMT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
•* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIES
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP D»TE
S02 DESIGN »E"OVAL EFFICIENCY - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKF-UP WATER - LITER/S
•• DISPOSAL
TYPE
- X
KANSAS CITY POWE"
LA CYGNE
1
LA OGNE
KANSAS
S74.0
823.0
874.0
LIGHT
COAL
SUBBITUMINOUS
21913.
24.36
S.60
5.39
.0?
yET SCRUBBING
LIMESTONE
BABCOCK f UILCOX
NEW
2.7
2/7?
6/7?
S-.30
99.50
.6
CLOSED
72.3
UNLINED POND
( 9421 BTU/Lp)
iue
.—. . PERFORMANCE DATA —
PERIOD MODULE IVAILABIL1TY OPERABILITY RCLIARIL1TY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8C SYSTEM 744
2/8? SYSTEM 606
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FIRST QUARTER 19SO>
69
-------
EPA UTILITY FGO SU»VEYt JANUARY - MARCH 198C
SECTION I
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT N»«E
JN1T NUMBER
C ITY
STATE
SROSS UNIT GENERATING CAPACITY - M W
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 1
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - T
KANSAS POyER & LIGHT
JEF FREY
1
WAMEGO
KANSAS
720.0
6a:.o
54D.O
COAL
18899.
5.80
2«.00
.52
.01
E-TU/LB)
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - x
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARC CAPACITY INDEX - X
ABSORBER SPARF COMPONENTS INDEX
- X
WET SCRUBBING
LIMESTONE
COKeUSTION ENGINEERING
NEW
8/7?
* * / * *
to.co
59.OC
2C.O
1.0
•* WATER LOOP
TYPE
FRESH MAKE-UP WATE8 - L1TER/S
•* DISPOSAL
TY PF.
CLCSFD
35.1
POND
( 557 GFI")
. . — PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD C«P.
502 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/8" SYSTEM
3/E
SYSTEM
• • PROBL£MS/SOLUTIONS/COM!»ENTS
744
606
744
NO MAJO» PROBLEMS WERE ENCOUNTERED DURING THE FIRST QUARTER
INTAKE MIXER MODIFICATIONS WERE PERFORMED.
SOME
70
-------
EPA UTILITY fGO SURVEY: JANUARY - HARCH 1060
SECTION !
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JMT NUMBER
CITY
STATE
S50SS UNIT GENERATJMG CAPACITY - M«
SET UNIT GENERATING CAPACITY W/FGD - Mt,
EQUIVALENT SC»UPBED CAPACITY - My
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - J
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - t
** FGD SYSTE1
GENERAL PROCESS TYPE
PROCESS TYPF
S»STEM SUPPLIER
NEW/RETROFIT
ENE"G1 CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
APSORBER SPARF CAPACITY 1NDFX - X
ABSORBER SPARF CO"PONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
«• TREATMENT
TYPE
•* DISPOSAL
TYPE
KANSAS POWER & LIGHT
LAWRENCE
4
LAWRENCE
KANSAS
1 35.0
1 15.0
1 i5.0
COAL
23Z6J.
0.80
12.::.
.?5
.03
WET SCKUPbING
LIMESTONE
COMtUSTION ENGINEERING
RETROFIT
1rOCC PTU/LP)
1/76
* * / * *
73.00
X 95.90
.->
.0
CLOSED
<<•«.. GPM)
FORCED OXIDATION
POND
— PERFORMANCE DATA — • —
PERIOD MODULE AVAILABILITY OPERABILIT1 RELIABILITY UTILIZATION * REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 100.0
2/8" SYSTEM 100.0
3/8P SYSTE* 100.0
** PROBLEMS/SOLUTIONS/COn«ENTS
NO MAJOR PROBLEMS
1CT.3
10C.3
1CT.O
744
744
744
696
744
744
696
744
REPORTED TO HAVE BEEN EXPERIENCED WITH THE
LAWRENCE 4 SCRUBBER DURING THE FIRST QUARTER 19?:.
71
-------
EP* UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 3
OESTGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFU» CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FGB SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPAR? CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* TREATMENT
TYPE
•* DISPOSAL
TYPE
KANSAS POWER i. LIGHT
LAURENCE
5
LAURENCE
KANS*S
420.0
400.0
420.0
COAL
23260. < 1^000
9.80
12.DO
.55
.03
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
11/71
* * / * *
52.00
X 98.90
.0
.0
CLOSED
*** »•••
(**»»* GPM)
FORCED OXIDATION
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
2/80
3/en
SYSTEM
SYSTEM
SYSTE*
IOC
100
100
.0
.0
.0
100
51
54
.0
.7
.8
744
606
744
744
340
4?E
744
360
4C8
•• PROBLEMS/SOLUTIONS/COMMENTS
THE LAWRENCE 5 SCRUBBER OPERATED WITHOUT ANY MAJOR PROBLEMS DURING THE
FIRST QUARTER 1980. THE BOILER WAS DOWN FROM THE MIDDLE OF FEBRUARY TO
THE MIDDLE OF MARCH FOR TURBINE REPAIRS, DURING WHICH TIME SCRUBBER
MAINTENANCE WAS PERFORMED.
72
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 5
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JN]T NU"3ER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - M«
MET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - I»W
KENTUCKY UTILITIES
GREEN RIVER
1-3
CENTRAL CITY
KENTUCKY
64.0
63.0
t4.0
•« FUEL DAT«
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - J
AVERAGE CHLORIDE CONTENT - T
COAL
BITUMINOUS
13. AC
17.10
4. CO
< 11000 BTU/LH)
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEb/RETPOF IT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL ST»RT-UP DATE
502 DESIGN REMOVAL EFFICIENCY - X
PARTICULATt DESIGN REMOVAL EFFICIENCY - I
ABSORBER SPARE CAPACITY INDEX - J;
ABSORBER SPAR? COMPONENTS INDEX
•* WATER LOOP
TYPE CLOSED
FRESH MAKE-UP WATER - LITER/S 4.7
** DISPOSAL
TYPE LINED POND
WET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
9/75*
6/76
99*. 50
.0
.0
< 75 GPM)
... — _ . ...—.—PERFORMANCE DATA--"—
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UT1L1?AT10N I REMOVAL PER BOILER FGD c«P.
SO? PART. HOURS HOURS HOURS FACTOR
1/60 SYSTEM
8/81 SYSTEM
3/80 SYSTEM
100.0
100.0
100.0
.0
.0
.0
744
696
744
C
r\
w
C
PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINED OUT OF SERVICE DUE TO BOILER REPAIRS.
EXPECTED TO BE OPERATING IN ANOTHER MONTH.
THE UNIT IS
73
-------
EPA UTILITY FGD SUPVEY: JAVUAR1 - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPAN1 NAME
PLANT NAME
UNIT NUM3ER
C ITY
STATE
SROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY y/FGD -
EQUIVALENT SCRUBBED CAPACITY - MW
LOUISVILLE GAS 8 ELECTPK
CANE RUN
4
LOUISVILLE
KENTUCKY
1 6 « . • j
1 75.0
1&R.D
** FUEL DATA
FUEL TUPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVtKAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFU" CONTENT - ?
AVERAGE CHLORIDE CONTENT - *
** F&D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPF
SYSTEM SUPPLIER
NEn/flETROFIT
ENERGY CONSUMPTION - *
INJT]AL START-UP DATE
COMMERCIAL START-UP DATE
soi DESI&N REMOVAL EFFICIENCY - ~i
PARTICULATE OFSIGN REMOVAL EFFICIENCY
APSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FKESH MAKE-UP WATER - LITER/S
•• DISPOSAL
TYPE
COAL
BITUMINOUS
26749.
1*.1"
9.00
( 115PC 6TU/L")
WET SCRUPbING
LJ^E
AME KUAN AIR F 1 LTE R
RETRPFIT
1.«
S/ 76
5/77
t 5.CO
99.-C
OPEN
6.3
LINED POND
< 100 CPI")
. PERFORMANCE DATA .
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOU15 HOURS HOURS FACTOR
1/60 SYSTEM
2/8^ SYSTE*
J/fcn SYSTEM
10P.O
99.8
8T.5
95.6
66.7
74.3
744
744
711
6»7
711
464
553
** PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR OPERATIONAL PROBLEMS WERE REPORTED fOD THE FIRST QUARTER 1987
xITH EITHER THE BOILER OR THE FGD SYSTEM.
74
-------
EPA UTILITY fGO SURVEY: JANUARY - MARCH 196"
SECTION 3
OFSIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTFMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
iROSS UNIT GENERATING CAPACITY - MW
MET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•« FUEL DATA
FUEL TYPE
FUEL GRADF
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TIP?
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COM»ERCIAL START-UP DATE
SOc DESIGN RE»OVAL EFFICIENCY - i
PARTICULATE DFSIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - J
ABSORBER SPARF COMPONENTS INDEX
•• WATER LOOP
TYPF
FRESH MAKF-UP WATER - LITER/5
•« TREATMENT
TYPE
•* DISPOSAL
TYPE
LOUISVILLE G*S R ELECTRIC
CANE RUN
5
LOUISVILLE
KENTUCKY
2C".0
192.0
2CO.O
t 1150C 6TU/LP)
COAL
BITUMINOUS
26749.
17.10
9.00
*.75
.04
WET SCRUPbING
LlM£
COMBUSTION ENGINEERING
BETROF IT
1.5
12/77
7/7S
&5.JC
.0
OPEN
(**•** GPM)
POZ-0-TEC
LINED POND
PERFORMANCE DATA-— —
PERIOD MODULE AVAUAB1L1T1 OPERABU1TK RF.LIAPUITY UTU17AT10N X REMOVAL PER BOILER FGD C«P.
SO? PART. HOURS HOURS HOURS FACTOR
1/6C SYSTEM 92.1 72.2 744 5S3 537
•• PROBIEMS/SOLUTIONS/COMMENTS
DURIN6 JANUARY NO OPERATIONAL PROBLEMS WERE ENCOUNTERED.
Z/fcC SYSTEM 71.9 49.7 696 4?1 346
3/60 SYSTEM 44.5 27.2 744 454 202
«* PROELEWS/SOLUTIOXS/COHMENTS
IM FEBRUARY THE UTILITY RAN OUT OF CARBIDE LIME CAUSING INTERRUPTION OF
THE FGD SYSTEM OPERATION. THE UNAVAILABILITY OF LIME WAS CAUSED PV FREF2E
UPS ENCOUNTERED BY AIRCO, THE LIME SUPPLIER.
REHEATER TUBE PROBLEMS WERE ALSO ENCOUNTERED IN FEBRUARY AND CONTINUED
THROUGH MARCH. THE UTILITY HOPES TO REPLACE THE TUPE BUNDLES IN THE
SUMMER.
-------
EP» UTILITY fGD SURVEY: JANUARY - MARCH 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC fGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY hl/FGD - >"W
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - *
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TVPF
SYSTEM SUPPLHR
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL ST«RT-UP DATE
so? DESIGN RE»OVAL EFFICIENCY - x
PARTICULATE OfSIGN REMOVAL EFFICIENCY
ABSORBER SPARF CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER'S
*• DISPOSAL
TYPE
- X
LOUISVILLE GAS 8 ELECTRIC
CANE RUN
6
LOUISVILLE
KENTUCKY
299.0
277.9
299.C
COAL
BITUMINOUS
25596. < 11000
9.0C
4.8C
.C4
UET SCRUPLING
DUAL ALKALI
AOL/CO«*BUST10N EQUIP ASSOCIATE
RETROFIT
1.0
1.1 79
* • / * *
55. :o
99. "0
2:.o
CLOSED
LANDFILL
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION I REMOVAL PE" BOILER FGD C'P.
SO? PART. HOURS HOURS HOURS FACTO*.
1/80 SYSTEM 49.0
•• PROBLE^S/SOLUTIONS/COM^ENTS
17.8
744
21C
FGD SYSTEM OUTAGE TIME IN JANUARY WAS CAUSED BY THE LOSS OF THE
THE RAKE WOULDN'T TURN AND THE THICKENER HAD TO BE CLEANED OUT.
J/8? SYSTEM 64.7
3/80 SYSTEM 70.0
•• PROBIEMS/SOLUTIONS/COMMENTS
47.0
64. 5
696
744
3P6
6?6
103
127
480
IN FEBRUARY AND MARCH OUTAGE TI»l WAS CAUSED PY PROBLEMS WITH THE RECYCLE
PUMPS.
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUO CONTENT - X
AVERAGE CHLORIDE CONTENT - »
•* FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
.« WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* TREATMENT
TYPE
•« DISPOSAL
TYPE
- X
LOUISVILLE GAS & ELECTRIC
MILL CREEK
3
LOUISVILLE
KENTUCKY
44?. 0
420.0
442.0
COAL
BITUMINOUS
26749.
11.50
3.75
.04
WET SCRUBBING
LIME
AMERICAN AIR FILTER
NEW
1.6
8/78
3/79
£5.00
99.00
.3
< 115CC f-TU/LP)
OPEN
9.4
( 15C GPf)
FLYASM/LIME STABILIZATION
POND
....... .. ... ...... — ....—.....P£pf ORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILED FGD C'P.
SO? PART. HOURS MOU"S HOURS FACTCB
1/80 SYSTEM
2/80 SYSTEM 36.1
3/80 SYSTEM 36.9
*• PROBLEMS/SOLUTIONS/CONMENTS
.0
26.6
3C.6
744
744
THE UNIT CAME BACK ON LINE ON FEBRUARY 1QTH AFTER THE TURBINE OVE"HAUL
UORK UAS COMPLETED.
PROBLEMS ENCOUNTERED DURING FEBRUARY AND MARCH k]TH THE FGO S>STt*
OPERATION INCLUDED FROZEN WATER LINES AND yORN GASKETS "LOWING 1% THE
REHEATER FLANGES.
77
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198C
SECTION 5
DESIGN AND PERFORMANCE DATA FOB OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT N«ME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - M*
'JET UNIT GENERATING CAPACITY W/FGD
EQUIVALENT SCRUBBED CAPACITY - *W
** FUEL DAT*
FUtL TYPE
FUEL GR»DE
AVERAGE HEAT CONTENT - J/6
AVE°AGE ASM CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - f.
LOUISVILLE GAS S. ELECTRIC
PADDY'S "UN
6
LOUISVILLE
KENTUCKY
7?.0
67.0
7?.0
COAL
BlTUWjNOUS
36749.
11.50
2.50
< 11500 PTU/LP)
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEW/RETROF]T
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL ST«RT-UP DATE
SO? DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN RtlOVAL EFFICIENCY
ABSORBER SPARF CAPACITY INDEX - X
Af-SORBER SPAR* COMPONENTS INDEX
- X
y£T SCRUPBING
LIME
COMBUSTION ENGINEERING
RETROFIT
3.9
4/75
* * / * *
Sti.OO
99.10
.3
.0
WATER LOOP
TYPE
FRESH MAKE-UP WATER
CLOSED
3.1
< 50 GPM)
•• TREATMENT
TYPE
LIME STABILIZATION
•* DISPOSAL
TYPE
POND
... .—---. .......... -.PERFORMANCE DATA .-.—..-...—...._..._. ....—_ __
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/6^ SYSTEM
3/60 SYSTEM
3/BC SYSTEM
.0
.0
.0
744
696
744
0
0
0
0
0
«« PROBLEMS/SOLUTIONS/COnMENTS
THIS UNIT DID NOT OPERATE DURING THE FIRST BUARTER 1980 DUE TO A LACK OF
DEMAND. THIS UNIT IS USED AS A PEAKING UNIT AND WILL BE RETIRED SOMETIME
IN 1987.
78
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 19t'
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - My
N?T UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASM CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFU" CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL ST«RT-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULAR DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKF-UP WATER - LITER/S
•* DISPOSAL
TYPE
POWER COOPERATIVE
YOUNG
I 65CC PTU/Lp)
MINSKOTA
MILTON R
2
CENTER
NORTH DAKOTA
44?. 0
4C2.0
4C5.?
COAL
LIGNITE
15119.
6.5Q
3?.00
.70
.01
WET SCRUBBING
LIME/ALKALINE FLYASH
AOL/COMBUSTION EQUIP ASSOCIATE
NEW
1.6
9/77
6/7R
o5.:o
99.tC
CLOSED
44.1
MINEFILL
700 GPK)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY DURABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
1 /80 A
B
SYSTEM
67.7
67.7
7.1
10.5
.0
10.5 10.5
7.1
.0
7.1
7*4 504 27
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE COLD WEATHER CAUSED SOME FROZEN LINES AND THE BOOSTE"
FAN TO FREEZE.
A HIGH PERCENTAGE OF COARSE SOLIDS IN THE THICKENER CAUSED SOME OUTAGE
TIME. THE WARM GEAR ON THE THICKENER ALSO BROKE CAUSING PROBLEMS.
A
B
SYSTEM
.0
.0
.0
.0
.0
.C
.0
696
696
** PROBLEMS/SOLUTIONS/COMMENTS
THE PROBLEMS RELATED TO THE COLD WEATHER CONTINUED THROUGH FEBRUARY.
ICE ON THE BOOSTER FAN HAD TO BE MELTED.
THE
THE SHAFT SLEEVES ON SEVERAL SPRAY RECYCLE PUMPS WERE REPLACED.
THE GEAR REDUCER FAILED ON THE B-SIDE ABSORBER AGITATOR CAUSING PROBLEMS.
79
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
1INNKOTA POWER COOPERATIVE: HILTON R. TOUNG ? (CONT.)
. _ . . — PERFORMANCE DAT*
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILE" FGD CAp.
S02 PART. HOURS HOURS HOURS FACTOR
THE ISOLATION DAMPEP CHAINS BROKE DURING THE MONTH.
3/8? A 28.9 22.t 22.6
B 28.9 6.2 #.2
SYSTEM 28.9 28.8 28.? 2?.8 744 743 107
•* PROBLEMS/SOLUTIONS/COMMENTS
DURING "ARCH COLD WEATHER CONTINUED TO PE A PROBLEM.
THE TOROUE SWITCHES ON THE ISOLATION DAMPERS WERE REPLACED. THE OAMPEK
PROBLEMS CAUSED THE BOOSTER FAN TO TRIP.
AN EXCESSIVE AMOUNT OF COARSE PARTICLES IN THE THICKENER CONTINUED TO BF
A PROBLEM. PLUGGED BLEED LINES FROM THE ABSORBER TO THE THICKENER WERE
ALSO ENCOUNTERED.
THE A-SIDE ABSORBER AGITATOR EXPERIENCED A PROBLEM WITH THE ANCHOR BOLTS
SHEARING.
THE SHAFT SLEEVES ON THE SPRAY RECYCLE PUMPS WOULD NOT HOLD THE PACKING
SO THEY HAD TO BE REPLACED IN MARCH.
80
-------
EPA UTILITY FSD SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOB OPERATIONAL DOMESTIC FGC SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY U/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MU
• • FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARF COMPONENTS INDEX
• * WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
- X
( 1843 BTU/L6)
MONTANA POWER
COLSTRIP
1
COLSTRiP
MONTANA
360.0
332.0
360.0
COAL
SUB6ITUMJNOUS
20569.
S.60
23.90
.77
.01
WET SCRUBBING
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
NEW
3.3
9/75
11/75
60.00
99.50
2D.O
.5
CLOSED
23.3
POND
< 370 GPi")
.... .....—.....................—PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL P£R BOILER FGD C»F«
S02 PART. HOU"S HOURS HOURS FACTOt
12/79 SYSTEM
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
74A
711,
696
744
NO INFORMATION WAS AVAILABLE FOP THE PE»lOD OF DECE'BEC 197" THROUGH
MARCH 1980.
81
-------
EPA UTILITY FGD SUDVET: JANUARY - MARCH i9»c
DESIGN AND PERFORMANCE DATA
SECTION 3
FOP OPERATIONAL
DOMESTIC FGD SYSTEMS
COMPANY NAI»F
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MX
NET UNIT GENERATING CAPACITY U/FGD -
EQUIVALENT SCRURB^D CAPACITY - I»W
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT
AVERAGE
AVEMGE
AVERAGE
AVERAGE
CONTENT - J/G
ASH CONTENT - X
MOISTURE CONTENT - *
SULFU" CONTENT - X
CHLORIDE CONTENT - 5!
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYpr
SYSTEM SUPPLICR
NE w/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S0£ DESIGN REMOVAL EFFICIENCY - X
P«STlCULATt DESIGN REMOVAL EFFICIENCY
A5SCR9ED SP«RC CAPACITY INDEX - X
AHSCRPER 5P«Rr CO"PONENTS INDEX
1 * WATER LOOP
TYPf
FRESH MAKF-UP WATER - L I T£K/S
'• DISPOSAL
TYPE
MONTANA POWER
COLSTHIP
2
COLSTRIP
MON TANA
36?. 0
332.0
3tO.O
CO«L
SUBfclTUMjNOUS
255«9.
?.6C
i3.90
.77
."1
WET SCRUPBING
BTU/L?)
ADL/COMBUSTION
NEW
'.3
5/76
10/76
d^.OC
99.50
2C.O
.5
EOUIP ASSOCIATE
CLOSED
23.3
POND
( 370 GPU)
. ....... .....—-PERFORMANCE DATA — ----- — — -.-_. .
MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
SC2 PART. HOUBS HOURS HOURS FACTOR
12/79 SYSTEM
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
•• PROBLEMS/SOLUTIONS/COMrENTS
744
744
696
744
NO INFORMATION HAS AVAILABLE FOR THE PERIOD FROM DECEMBER 1979 THROUGH
MARCH 198C.
82
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT N«ME
JN1T NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - "to
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DAT*
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
*« FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL ST«RT-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKf-UP yATER - LITER/S
«• DISPOSAL
TYRE
NEVADA POWER
REID GARDNER
1
MOAPA
NEVADA
125.0
11?.0
125.0
COAL
BITUMINOUS
28959.
9.30
5.50
.50
.05
WET SCRUBBING
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
RETROFIT
< 12450 BTU/LB)
4/74
* * / * *
9".00
X 97.00
CLOSED
9.8
LINED POND
( 155 6PM)
... . ...... . .....—.-PEPF OHMANCE DATA — —
PERIOD MODULE AVAILABILITY OP£RABIL1T» RELIABILITY UT1LI7AT10N X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
i/eo SYSTEM 100.0 100.0 100.0 100.0 7** 744 7*4
•* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND FGD SYSTEM OPERATED THE ENTIRE MONTH WITH NO OUTAGES.
2/8" SYSTEM 100.0 100.0 100.0 100.0 696 696 696
•* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY, NO OUTAGES OCCURRED*
3/80 SYSTEM 66.2 83.7 84.7 33.8 744 30C 251
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST OF MARCH THE FGo SYSTEM WAS OFF LINE FOR A SCHEDULED
OVERHAUL.
THE FGD UNIT HAS FORCED DOWN ONCE TO REPAIR THE VENTURI PUMP AND SIX OTHER
TIMES DUE TO LOW VENTURI FLOW.
83
-------
EP» UTILITY fGO SURVEY: JANUARY - MARCH 1980
SECTION 3
OFSIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUMBER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATIVE CAPACITY W/FGD - MW
EQUIVALENT SCRUPBEO CAPACITY - My
NEVADA POWER
REID GARDNER
2
MOAPA
NEVADA
125.0
110.0
125.0
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - t
COAL
BITUMINOUS
28959.
9.00
5.50
.50
.05
( 12450 6TU/LB)
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPF
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE OFSIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-OP WATER - LITER/S
WET SCRUBBING
SODIUM CARBONATE
AOL/COMBUSTION EQUIP ASSOCIATE
RETROFIT
4/74
**/ •»
90.00
X 97.00
.0
r\
CLOSED
9.8
< 155 GPM)
•* DISPOSAL
TYPE
LINED POND
..... — ... PERFORMANCE DATA — ———— — —— ——.... ... _„_
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 97.3 96.9
** PROBLEMS/SOLUTIONS/COMMENTS
96.9
81.6
744
637
607
DURING JANUARY THE SCRUBBER WENT OFF LINE WITH THE BOILER TO REPLACE THE
REBUILT NO. 2 HIGH PRESSURE HEATER. THIS OUTAGE LASTED APPROXIMATELY
112 HOURS.
REPAIRS WERE NEEDED ON THE LEFT HAND INTERCEPT VALVE ON THE TURBINE CAUSING
THE SCRUBBER TO COME OFF LINE WITH THE BOILER.
THE CLEANING OF THE VENTURI RACE TRACK NOZZLES CAUSED TWO SCRUBBER OUTAGES.
THE SCRUBBER WENT OFF LINE SO MAINTENANCE COULD BE DONE ON THE ID FAN
DAMPER CONTROLS.
2/80 SYSTEM 97.P 97.0
** PROBLEMS/SOLUTIONS/COMMENTS
97.0
97.0
696
696
675
THE SCRUBBER WAS TAKEN OFF-LINE TWICE DURING FEBRUARY DUE TO A MALFUNCTION
OF THE ID FAN CONTROLS. THE PRESSURE SENSING LINES WERE ALSO CLEANED
DURING THE OUTAGE.
THE SCRUBBER RACE TRACK NOZZLES HAD TO BE CLEANED TWICE, CAUSING APPROX-
84
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198?
NEVADA POWER: REID GARDNER 2 (CONT.)
.. ..—. ..—-PERFORMANCE DATA— ——
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD C«P
502 PART. HOURS HOURS HOURS
IRATELY 4 HOURS OUTAGE TIME.
THE DISCHARGE VALUE ON THE VENTUR1 RECYCLE PUMP WAS REPLACED DURING
FEBRUARY.
REPAIRS WERE HADE ON THE SCHURBER EMERGENCY SPRAY LINE CAUSING ABOUT 4
HOURS OUTAGE TIME.
THE SCRUBBER HAD TO BE SHUT DOWN SO REPAIRS ON THE ID FAN DAMPER CONTROLS
COULD BE MADE.
3/80 SYSTEM 97.5 97.5 97.5 97.5 74* 744 725
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THE SCRUBBER bAS TAKEN OFF LINE DUE TO NO EMERGENCY SPRAY.
DURING THIS TIME MAINTENANCE WAS DONE ON THE A AND P ASH SLUICE PUMPS.
LATER IN THE MONTH AN OUTAGE WAS CAUSED BY A LEAK IN THE EMERGENCY SPRAY
LINE.
LOU VENTURI FLOW ALSO WAS A PROBLEM DURING MARCH.
85
-------
EPA UTILITY FGD SU"VEY: JANUARY -MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC fGO
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
SET UNIT GENERATING CAPACITY W/FGD - Mw
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL T»PE
FUEL GR«OF
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPF
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• DISPOSAL
TYPE
NEVADA POyER
REID GARDNER
3
MOAPA
NEVADA
125. 0
II"1.G
1c5.9
COAL
BITUMINOUS
28959.
S.3C
9.0C
.50
.05
WET SCRUBBING
SODIUM CARBONATE
AOL/COMBUSTION EQUIP ASSOCIATE
NEW
< 1245C BTU/LR)
6/76
7/76
85.00
Z 99.00
.0
.0
CLOSED
9.8
LINED POND
( 155 GPM)
......—.................—-—.-. ————PERFORMANCE DATA ——— — .......—
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 100.0 99.7
*• PROBUKS/SOLUTIONS/COMMENTS
100.0
91.3
744
681
679
DURING JANUARY THE SCRUBBER AND BOILER WERE OFF LINE FOR APPROXIMATELY
64 HOURS TO REPAIR AND BALANCE THE BOILER ID FAN.
696
552
542
2/80 SYSTEM 78.8 9S.2 77.9 77.9
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY TWO OUTAGES WERE NECESSARY SO THE ID FAN COULD BE BALANCED.
THE SCRUBBER AND BOILER WENT OFF LINE SO THAT THE COAL LEAKS ON THE
BURNER LINES COULD BE REPAIRED.
HIGH FURNACE PRESSURE CAUSED THE SCRUBBER AND BOILER TO TRIP OFF.
3/80 SYSTEM
60.3
99.7
«9.7
60.2
744
450
448
«• PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT AND SCRUBBER WENT DOWN TWICE DURING MARCH. THE FIRST OUTAGE WAS
TO BALANCE THE ID IAN. LATER IN THE MONTH THE ID FANS AND THE
PRECIPITATORS HAD TO BE REPAIRED.
86
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 1980
SECTjON 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/FGD - Mw
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASM CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - X
** FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO? DESIGN REMOVAL EFFICIENCY - X
P«RTICULAT£ DfSIGN REMOVAL EFFICIENCY
ABSORBER SPAR* CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
fRESH MAKE-UP WATER - LITER/S
•* BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
GARY
INDIANA
115.0
78.0
115.0
COAL
*** * * *
25586.
11.00
3.50
WET SCRUBBING
WELLMAN LORD
DAVY POWERGAS
RETROFIT
27.8
7/76
6/77
93.00
9S.5C
.0
.0
CLOSED
( 11000 BTU/LB)
<*.*•* GPM)
ELEMENTAL SULFUR
. _—. —..—.—. PERFORMANCE DATA -—
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
•• PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE IRON DECEMBER 1979 THROUGH MARCH 1980.
87
-------
EPA UTILITY r&t> SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITT
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MU
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
- X
NORTHERN STATES POWER
SHERBURNE
1
BECKER
MINNESOTA
743.0
700.0
740.0
< 8500 BTU/LB)
COAL
SU8BITUMINOUS
19771.
9.00
25.00
.80
.03
WET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
2.7
3/76
5/76
SO.00
99.00
8.0
.9
CLOSED
*******
(***** 6PM)
'• TREATMENT
TYPE
'* DISPOSAL
TYPE
FORCED OXIDATION
LINED POND
————————————— —PERFORMANCE DATA———— — ———.....
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
97.0
97.0
98.0
74* 793
696 687
744 688
** PROBLEMS/SOLUTIONS/COMHENTS
DURING THE FIRST QUARTER, 1960 NO MAJOR PROBLEMS HERE ENCOUNTERED WITH
THE F6D UNIT.
FROM MID-SEPTEMBER TO MID-OCTOBER THE UTILITY HAS SCHEDULED A BOILER
OUTAGE IN WHICH TIME THE MARBLE BEDS WILL BE INSPECTED.
88
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIEN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTFHS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
»• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* TREATMENT
TYPE
•• DISPOSAL
TYPE
- X
NORTHERN STATES POWER
SHERBURNE
2
BECKER
MINNESOTA
740.0
700.0
70.0
< 8500 BTU/LB)
COAL
SUBBITUMINOUS
19771.
9.00
25.00
.80
.03
UET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
2.7
4/77
4/77
53.00
99.00
8.0
.9
OPEN
(***»* 6PM)
FORCED OXIDATION
LINED POND
.. _ . —PERFORMANCE DATA—
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
97.0
96.0
98.0
744 744
696 696
744 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER, 1980 THE FGD SYSTEM EXPERIENCED NO MAJOR
PROBLEMS.
A FOUR MEEK BOILER OUTAGE IS SCHEDULED FOR MAY IN WHICH TIME THE MARBLE
BEDS HILL BE REMOVED FROM THE FGD UNIT.
89
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD
COMPANY NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - »U
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
*• WATER LOOP
TYPE
FRESH MAKE-UP WATER - L1TER/S
•• DISPOSAL
TYPE
- X
PACIFIC POKER 8 LIGHT
JIM BRIDGER
4
ROCK SPRINGS
WYOMING
550.0
507.8
550.0
( 9300 BTU/LB)
COAL
SUBBITUMlNOUS
21632.
'.00
18.00
.56
.01
MET SCRUBBING
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
NEU
.2
9/79
2/80
91.00
99.00
.9
CLOSED
*******
POND
<***•* GPM)
........ ... ... . -.PERFORMANCE DAT*
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
•• PROBLEMS/SOLUTIONS/COHMENTS
744
696
744
THE UNIT IS STILL IN THE SHAKEDOWN PHASE. A NUMBER OF MECHANICAL PR08LFMS
AND SOME CONTROL PROBLEMS HAVE BEEN ENCOUNTERED.
90
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 1980
SECTION 2
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC fGo SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - HW
NET UNIT GENERATING CAPACITY W/FGD - Mb
EQUIVALENT SCRUBBED CAPACITY - MH
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
SHIPP1NGPORT
PENNSYLVANIA
917.0
825.0
917.D
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
» u c o 4 r c ruinpTnc rnuTcuT — v
A V t N A u C LMLv/nlUt 1 DN 1 C N 1 ~ A
• * FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP BATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
COAL
BITUMINOUS
26749. 1 11500 BTU/LB)
12.90
7.00
3.00
UET SCRUBBING
LIME
CHEMICO
NEW
6.0
12/75
6/76
92.10
PARTICULAR DESIGN REMOVAL EFFICIENCY - X 99.80
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
«» WATER LOOP
TYPE
FRESH MAKF-UP HATER - LITER/S
•• TREATMENT
TYPE
** DISPOSAL
TYPE
PERIOD MODULE AVAILABILITY OPERABILITv
1/8C SYSTEM 98.6 100.0
2/80 SYSTEM 98.1 100.0
.0
.0
OPEN
******* (***** GPM)
CALCILOX
LANDFILL
RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
90.* 74* 672 672
93.7 696 652 652
** PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR FGD RELATED PROBLEMS OCCURRED DURING JANUARY AND FEBRUARY.
3/80 SYSTEM 98.8 100.0 83.7 7** 623 623
•* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER HAS OUT ONE WEEK IN MARCH DUE TO A PLUGGED AIR PREHEATER. NO
MAJOR FGD RELATED PROBLEMS WERE REPORTED FOR MARCH.
91
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT 6ENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - Mw
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PAftTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
- X
PENNSYLVANIA POhER
BRUCE MANSFIELD
2
SHIPPINGPORT
PENNSYLVANIA
917.0
835.0
917.0
COAL
BITUMINOUS
26719.
1?.90
7.00
3.00
WET SCRUBBING
LIME
CHEMICO
NEU
6.0
7/77
• */ »•
92.10
99.80
.0
OPEN
•***«**
CALCILOX
LANDFILL
( 11500 BTU/LB)
****** GPM)
. . ............. -PERFORMANCE DATA — — _
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 97.1 100.0 90.6 744 674 674
3/80 SYSTEM 94.7 100.0 99.8 696 694 694
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM EXPERIENCED NO MAJOR PROBLEMS DURING JANUARY AND FEBRUARY.
3/80 SYSTEM 98.4 100.0 83.7 744 380 380
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER HAS OUT 16 DAYS IN MARCH FOR A SCHEDULED BOILER INSPECTION.
NO MAJOR FGD RELATED PROBLEMS HERE REPORTED.
92
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - WW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
PHILADELPHIA
EDDHSTONE
1A
EDDYSTONE
PENNSYLVANIA
130.0
1 20.0
120.0
COAL
BITUMINOUS
31634.
9.40
5.90
Z.60
ELECTRIC
( 13600 BTU/LR)
WET SCRUBBING
MAGNESIUM OXIDE
UNITED ENGINEERS
RETROFIT
9/75
9/75
93.00
99.00
.0
.0
OPEN
8.3
SULFURIC ACID
GPM)
... . ... .. ....... — __.._.-. —.-PER f ORM AN CE DATA—
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
* REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
THE BOILER AND TURBINE WERE DOWN DURING THE FIRST QUARTER 1980 FOR TURBINE
MAINTENANCE.
OPERATION OF THIS PROTOTYPE MAGNESIUM OXIDE SYSTEM, WHICH TREATED ONE
THIRD OF THE FLUE GAS FROM THE EDDVSTONE 1 BOILER, HAS BEEN TERMINATED*
THE S02 REMOVAL EQUIPMENT IS PRESENTLY BEING REPLACED WITH A SIMILAR
NAG-OX SYSTEM DESIGNED TO TREAT 100X OF THE BOILER FLUE GAS. THE EXPECTED
START DATE OF THIS SYSTEM IS DECEMBER 1982. CURRENT REGULATIONS DO NOT
REQUIRE CONTROL OF SO? EMISSIONS UNTIL THE NEW SCRUBBER IS AVAILABLE
FOR OPERATION.
93
-------
EPA UTILITY FGD SU»VEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT MME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
- X
PUBLIC SERVICE OF N£W MEXICO
SAN JUAN
1
WAT£»FLOW
NEW MEXICO
361.0
314.0
361.0
COAL
SUBBITUMINOUS
22795.
1S.30
U.82
.80
.03
WET SCRUBBING
WELLMAN LORD
DAVY POWERGAS
RETROFIT
4.4
4/73
** / * *
90.00
99.80
35.0
1.0
CLOSED
30.2
< 9800 BTU/LP)
( 480 GPM)
ELEMENTAL SULFUR
MARKETED
... . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
x REMOVAL PER BOILER FGD CIP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
2/80
3/80
A
B
C
D
SYSTEM
A
B
C
D
SYSTEM
A
B
C
D
SYSTEM
81.0
96.0
.P
83.0
87.C
.0
99.0
3.0
99.0
67.0
.0
100.0
83.0
97.0
93.0
51.0
42.0
,C
79.0
57.0
.0
94.0
3.0
98.C
65.0
.0
50.0
83.0
85.0
73.0
.« PROBLEMS/SOLUT10NS/COHMENTS
42.0
35.0
.0
65.0
47.0
.0
86.0
2.0
8".0
59.0
.0
18.0
29.0
30.0
26.0
744 610
696 634
74*
262
351
411
191
SCRUBBER OPERATIONS AT UNIT ONE ARE STILL LIMITED TO TWO MODULES BECAUSE
OF A LACK OF REHEAT.
94
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 3
DFSIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNlT NUMBER
C ITY
STATE
5ROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - Mw
EQUIVALENT SCRUBBED CAPACITY - MW
*« FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*« FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPF
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO? DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DFSIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - L1TER/S
•* BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
- X
WAT CR
NEW MEXICO
35'.0
3:6.:
351.0
COAL
SUBblTUMTNOUS
2279i.
ip.no
14.82
.80
.03
WET SCRUPBING
WELLMAN LORI>
DAVY POWF.RGAS
RETROFIT
4.6
8/78
* * / * *
91.00
99.50
33.0
1.0
CLOSED
30.2
< 9800 BTU/LO)
< 48C GPIO
ELEMENTAL SULFUR
MARKETED
_. _ - ... .... _ — .. — PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION
2/80
3/80
E
F
G
H
SYSTEM
E
f
G
H
SYSTEM
97.0
22.0
.0
.0
40.0
87.0
85.0
.0
.0
57.0
66.0
2.0
.0
.0
23.0
.0
94.0
.0
.0
31.C
** PROBLEMS/SOLUTIONS/COMMENTS
X REMOVAL PE» BOILER FGD C«P.
SO? PART. HOURS HOURS HOURS FACTOR
„ E
F
G
H
SYSTEM
92.0
.C
.0
.0
31.0
63.0
.0
.0
.0
21. C
62.0
.0
.0
.0
21.0
744 737 155
65.3
12.0
.0
.0
26.0
.0
59.0
.0
.0
20.0
696 6»3 17?
744 472 147
DURING THE FIRST QUARTER ONLY ONE ABSORBER COULD PE OPERATED DUE TO AN
ELECTRICAL PROBLEM. CURRENTLY, OPERATIONS ARE LIMITED TO TWO ABSORBERS
UNTIL REHEAT IS INSTALLED, WHICH IS EXPECTED TO PE COMPLETED IN APRIL.
95
-------
EPA UTILITY FGD SURVEY: JANUARY - "ARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FO& OPERATIONAL DOMESTIC FGD SYSTFMS
COMPANY NAMf
PLANT NAME
JNJT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mu
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - Mw
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASM CONTENT - *
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
PUBLIC SERVICE OF
SAN JuAN
3
WATERfLOW
NEW MEXICO
534.C
463.0
534.0
NEW
COAL
SUBfalTUMjNOUS
15S41.
2?.45
14.ea
.8C
.37
< MOC BTU/tp)
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPF
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - *
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDFX - X
ABSORBER SPARF COMPONENTS INDEX
•* BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
WET SCRUPbING
WELLIAN LORD
DAVY POWFHGAS
12/79
* * y
.6
99. 5C
2.5
1.3
SULFUR1C ACID
MARKETED
. -PERFORMANCE DATA-- — — _.»,
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP
S02 PART. HOURS HOURS HOURS FACTOR
1/80
2/80
3/80
M 86. P
SYSTEM
M 98.0
SYSTEM
M
SYSTEM
54.0
H.O
80. 0
43.0
1.0
63.0
744
696
744
366
44
547
.« PflOBLtMS/SOLUTIONS/COMMENTS
THE ONE MODULE CURRENTLY OPERATIONAL AT SAM JUAN 3 OPERATED WITHOUT AN*
MAJOR PROBLEMS DURING THE FIRST QUARTER. THE BOILER WAS OFF LINE FOR
3-4 WEEKS IN FEBRUARY DUE TO AN ELECTRICAL PROBLEM.
96
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 108'
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC fGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
C ITV
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
• * FUEL DAT*
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - t
INITIAL START-UP DATE
COMMERCIAL ST«RT-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATt DESIGN REMOVAL EFFICIENCY
ABSORBED SPARE CAPACITY INDEX - X
ABSORBER SPARF COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
SALT RIVER PROJECT
CORONADO
1
ST. JOHNS
ARIZONA
350.0
350.0
280.0
COAL
SUBBITUM1NOUS
19306.
25.00
16.00
1.00
< P3CO 6TU/LEO
WET SCRUBBING
LIMESTONE
PULLMAN KELLOGG
NEW
*.3
11/70
12/79
82.50
X '9.87
.0
.0
OPEN
LINED POND
( 270 GPM)
.---«------------ — — PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RFLIAP1LITY UTILIZATION X REMOVAL P£R BOILER FGD CAP-
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
DURING THE PERIOD THE STACK EMISSION TESTS HERE COMPLETED. NO OPERATIONAL
INFORMATION WAS AVAILABLE.
97
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SECTION *
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - "W
EQUIVALENT SCRUBBED CAPACITY - *U
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
•* FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL STABT-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTUULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPAR? CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• DISPOSAL
TYPE
- X
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
2
GEORGETOWN
SOUTH CAROLINA
28C.O
25«.C
uo.o
COAL
BITUMINOUS
26749.
13.50
1.70
< 115CO ETU/LP)
WET SCRUPBING
LIMESTONE
BABCOCK * WILCOX
NEW
1.1
7/77
**/ **
69.00
59.40
.3
.c
OPEN
6.3
( 100 6PM)
PONC
. .___._....-— -PERFORMANCE DATA————————--—......... .
PERIOD MODULE AVAILABILITY OPERAE'lLITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP?"
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER 19SO THE UNIT OPERATED WITH NO MAJOR PROBLEMS.
98
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 108T
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - My
EOUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFU" CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROF IT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO? DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKF-UP WATER - LITER/S
•• TREATMENT
TYPE
•* DISPOSAL
TYPE
- X
SOUTH MISSISSIPPI EtEC PWR
R.D. MORROW
1
HATTISBURG
MISSISSIPPI
Z C -i. D
180.0
124.0
< 1200C BTU/L8)
COAL
BITUMINOUS
27?1i.
15.00
6.5C
1.30
.01
WET SCRUBBING
LIMESTONE
RILEY STOKER/ENVIRONEERING
NEW
c c
8/73*
8/7?
85.00
99.60
.T
.0
CLOSED
FHASH STABILIZATION
LANDFILL
......———- — ........... — .........——PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILI7ATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM .0
** PROBLEMS/SOLUTIONS/COMMENTS
740
THE UNIT REMAINED OFF LINE DURING JANUAH1 DUE TO THE FAILURE OF THE
LININGS.
2/6? SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FO" FEBRUARY AND MARCH.
696
744
99
-------
EP» UTILITY FGD SURVEY: JANUARY - MARCH 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOP OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNJT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - x
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PART1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
- X
** WATER LOOP
TYPE
FRESH MAKE-UP WATER
*• TREATMENT
TYPE
•• DISPOSAL
TYPE
LITER/S
SOUTH MISSISSIPPI fLEC PWR
R.D. MORROW
3
HATTISBUPG
MISSISSIPPI
200.0
180.0
124.0
< 12000 BTU/LB)
COAL
BITUMINOUS
27912.
15.00
6.50
1.30
.01
WET SCRUBBING
LIMESTONE
RILEY STOKER/ENVIRONEEPING
NEW
5.5
6/79
6/79
85.00
99.60
.0
CLOSED
<****«
FLYASH STABILIZATION
LANDFILL
....—.—..—-—— .. — -PERFORMANCE DATA --. ————.-—..— ... .___
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM .0
** PROBLEMS/SOLUTIONS/COMMENTS
.0
.0
744
698
THE UNIT REMAINED OFF LINE DURING JANUARY DUE TO THE FAILURE OF THE
LININGS.
2/80 SYSTEM
3/60 SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR FEBRUARY AND MARCH.
696
744
100
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 1960
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• • FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - *
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
• • HATER LOO'
TYPE
FRESH MAKE-UP WATER - LITER/S
•* TREATMENT
TYPE
•• DISPOSAL
TYPE
- X
SOUTHERN ILLINOIS POWER COOP
MARION
4
MARION
ILLINOIS
184.0
160.0
184.0
COAL/REFUSE
***»*•
30934.
16.00
10.00
3.50
.10
WET SCRUBBING
LIMESTONE
BAB COCK ( UILCOX
NEW
< 9000 BTU/LB)
5/79
5/79
89.40
99.60
OPEN
*** **» *
(***•• GPM)
FLYASH STABILIZATION
LANDFILL
— — — — -PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD C»P.
S02 PART. HOURS HOURS HOURS FACTOR
13/79
11/79
12/79
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
.0
26.7
71.0
744
720
744
0
192
528
0
192
528
** PROBLEMS/SOLUT10NS/COMHENTS
THE UNIT WAS DOWN FROM OCTOBER 1 THROUGH NOVEMBER 17 FOR A BOILER/TURBINE
INSPECTION. NO MAJOR FGD RELATED PROBLEMS WERE ENCOUNTERED DURING THE
FOURTH QUARTER 1979 OTHER THAN SOME FREEZE-UPS CAUSED BY THE U1NTER
WEATHER.
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
100.0
100.0
100.0
10.0
31.0
48.4
744 72
696 216
744 360
72
216
360
101
-------
EPA UTILITY fGD SU»VEY: JANUARY - MARCH 1980
SOUTHERN ILLINOIS POWER COOP: MARION 4 (CONT.)
...... ... .................... .....PERfORM»NCE DATA — — ———. - ———.«__.
PERIOD MODULE AVAILABILITY OPERABILIT» RELIABILITY UTILIZATION X REMOVAL PE» BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS fACTOR
•* PROBLEMS/SOLUTIONS/COHMENTS
DURING JANUARY THE LOW BOILER AND SCRUBBER HOURS WERE A RESULT OF AN
EIGHTEEN DAY BOILER OUTAGE NEEDED FOR CORRECTION OF TUBE PROBLEMS. BOILER
OUTAGES DUE TO TUBE PROBLEMS WERE ALSO EXPERIENCED IN FEBRUARY AND MARCH.
THE ONLY REPORTED FGD DELATED PROBLEM DURING THE FIRST QUARTER 1980 WAS
KEEPING THE BELT IN THE SLUDGE DISPOSAL SYSTEM PROPERLY ALIGNED.
102
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198?
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FED SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
SOUTHERN INDIANA GAS t ELEC
A.B. BROUN
1
WEST FRANKLIN
INDIANA
265.0
250.0
265.0
COAL
BITUMINOUS
25819.
9.40
13.3C
3.35
.05
< 11100 BTU/LB)
** F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - i
PARTKULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
*• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* TREATMENT
TYPE
• • DISPOSAL
TYPE
UET SCRUBBING
DUAL ALKALI
FMC
NEU
.8
4/79
4/79
85.00
- X 99.50
20.0
.3
CLOSED
*»*****
NONE
LANDFILL
(•**** GPM)
—. —— ——PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP*
SO? PART. HOURS HOURS HOURS FACTOR
1/80
A
B
SYSTEM
99.0
99.0
99.0
96.5
99.0
98.0
98.0
96.5
99.0
99.0
744
744
727
•* PROBLEMS/SOLUTIONS/COMMENTS
THE 7 HOURS OF FORCED OUTAGE TIME DURING JANUARY WERE DUE TO A THICKENER
RAKE STALL.
2/80
A
B
SYSTEM
99.1
98.4
99.0
70.3
70.0
7C.O
70.0
69.4
68.7
69.0
696 6?7
481
PROBLEMS/SOLUTIONS/COMMENTS
3/80 A
B
SYSTEM
43.8
38.4
45.0
SOME OUTAGE TIME IS FEBRUARY WAS DUE TO A WET SLUDGE PRODUCT CAUSED BY
A CHEMICAL IMBALANCE.
44.4
35.4
65.0
68.0
26.5
21.1
27.0
744 304
177
103
-------
EPA UTILITY FG6 SURVEY: JANUARY - MARCH 1980
SOUTHERN INDIANA GAS « ELEC: A.B. BROWN 1 (CONT.)
„.___.—. _._...—.._._—__—_ .. PERFORMANCE DATA— —— -——_.._
PERIOD MODULE AVAILABILITY OPERABIL1T1 RELIABILITY UTILIZATION » REMOVAL PER BOILER FGD CAp""~
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMHENTS
DURING MARCH, DOWN TJME WAS DUE TO A SCHEDULED UNIT OUTAGE, DURING UHICH
TIME MAINTENANCE UAS PERFORMED ON THE SCRUaBER.
104
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 196n
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F60 SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - NW
• * FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
«* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
• * DISPOSAL
TYPE
CITY UTILITIES
- X
( 12500 BTU/LB)
SPR JNGF1ELD
SOUTHWEST
1
SPRINGFIELD
MISSOURI
194.D
173.0
194.0
COAL
BITUMINOUS
29075.
13.00
3.50
.30
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION. UOP
NEW
4.6
4/77
• */ • *
83.00
99.70
.0
.0
CLOSED
19.8
LANDFILL
I 315 GPM)
— — PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
t REMOVAL PE» BOILER FGD CAP-
SO? PART. HOURS HOURS HOURS FACTOR
1/80
S-1
S-2
SYSTEM
24.4
68.7
61.5
38.6
72.5
55.6
*7.9
73.0
61.5
36.3
68.0
52.2
744 698 388
PROBLEMS/SOLUTIONS/COMMENTS
2/80
S-1
S-2
SYSTEM
36.6
73.9
55.3
AT THE BEGINNING OF JANUARY THE ID FAN EXPANSION JOINT BROKE FOLLOWED BY
THE UNIT COMING OFF LINE.
DURING THE LATER PART OF THIS PERIOD THE DEMISTER AND TRAP OUT TRAY HEADER
FROZE. AFTER REPAIRS WERE MADE BOTH MODULES WERE PUT ON LINE. BOTH WERE
KEPT RUNNING UNTIL THE 20TH WHEN A FLANGE BROKE LOOSE ON THE DEMISTER
HEADER.
AFTER THE REPAIRS WERE COMPLETED TH£ MODULE OPERATED UNTIL THE 27TH WHEN
FREEZING AIR LINES TO THE BALL MILLS PREVENTED THE USE OF BOTH MODULES
DUE TO THE LACK OF SLURRY.
THE UNIT WAS ON LINE AT THE BEGINNING OF THE MONTH PUT DEVELOPED pRESAlURA-
TOR SPRAY NOZZLE PROBLEMS. bHILE THIS WAS BEING REPAIRED THE UNIT WAS
TAKEN OFF LINE. APART FROM THIS TIME THE NODULE WAS ON LINE.
29.1
71.7
50.4
29.0
71.6
SO.4
29.0
71.6
50.3
6'6 695
350
105
-------
EP» UTILITY FGD SURVEY: JANUARY - MARCH 1980
SPRINGFIELD CITY UTILITIES: SOUTHWEST 1 (CONT.)
PERFORMANCE DATA--
PERIOD MODULE »V»ILABIL1T» OPERAB1LITY RELIABILITY UTILIZATION * REMOVAL P£R BOILER FGD C»p7~
S02 PART. HOURS HOURS HOURS FACTOR
•* PROBLEMS/SOLUTIONS/CONMENTS
THE S-1 MODULE WAS OUT OF SERVICE IN THE FIRST PART OF FEBRUARY DUE TO
FROZEN AND BROKEN LINES. THE SUPERNATE LINE BROKE IN SEVERAL PLACES TAKING
BOTH MODULES OUT OF SERVICE FOR SEVERAL DAYS. ONCE THIS UAS REPAIRED BOTH
MODULES WERE IN SERVICE AS REQUIRED BY LOAD EXCEPT FOR A FEW MINOR TRIPS.
THE S-2 MODULE WAS EITHER IN SERVICE OR AVAILABLE FOR HOST OF THE MONTH.
3/80 S-1 64.5 64.1 64.1 64.1
S-2 22.C 5.8 5.8 5.8
SYSTEM 43.3 34.9 34.9 34.9 744 744 240
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THF S-1 MODULE WAS OUT FOR 11 DAYS TO CLEAN THE ABSORBER
SECTION.
THE S-2 MODULE UAS OUT OF SERVICE FOR CLEANING THE ABSORBER SECTIONS AND
DEMISTERS FOR NEARLY ALL THE PERIOD BUT WAS AVAILABLE OH THE 25TH.
IT UAS NOT RUN, HOWEVER, DUE TO LOU UNIT LOADS.
106
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 198C1
SECTION 2
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - MW
EOUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ST. JOE 7INC
G.F. toEATON
1
MONACA
PENNSYLVANIA
6r'.0
60.0
6C.O
COAL
BITUMINOUS
29C75.
11.50
< 1?500 BTU/LB)
3.00
.20
WET SCRUBBING
CITRATE
BUREAU OF MINES
RETROFIT
*******
11/79
1/80
90.00
X 99.60
.0
.0
CLOSED
(***** GPM)
ELEMENTAL SULFUR
............. .......—.—. — _ ..—. — PERFORMANCE DATA •
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
x REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
THE SYSTEM IS STILL GOING THROU6H THE DEBUGGING PHASE OF OPERATION. SOME
EQUIPMENT PROBLEMS HAVE OCCURRED, ESPECIALLY WITH THE HYDROGEN SULFITE
GENERATOR EQUIPMENT. ANOTHER MAJOR PROBLEM AREA HAS BEEN THE HEAT EX-
CHANGERS, ONE OF WHICH HAD TO BE REMOVED AND SENT BACK. 120 HOURS OF
OPERATION WERE LOGGED DURING THE FIRST QUARTER 198Q BRINGING THE TOTAL
SYSTEM HOURS OF OPERATION TO 164.
107
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGO - MW
EOUIVALENT SCRUBBED CAPACITY - HW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEy/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO? DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
- X
TENNESSEE VALLE* AUTHORITY
SHAWNfcE
10A
PADUCAH
KENTUCKY
10.0
10.0
10.0
COAL
BITUMINOUS
?.90
<*•**•* BTU/LBJ
WET SCRUBBING
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
RETROFIT
4/72
** / **
********
.0
CLOSED
*******
(*****
. —... .. ——-PERFORMANCE DATA—--
PERIOD MODULE AVAILABILITY OPERABUITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGO CAP ~
S02 PART. HOURS HOURS HOURS FACTOR
3/80 SYSTEM
«* PROBLEMS/SOLUTIONS/COMMENTS
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR SHAWNEE 10B.
108
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU
•* FUEL DATA
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - J
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - I
• * FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY - *
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
TENNESSEE VALLEY AUTHORITY
SHAUNEE
10B
PADUCAH
KENTUCKY
10.0
10.0
10.0
COAL
BITUMINOUS
BTU/LB)
2.90
WET SCRUBBING
LIME/LIMESTONE
RETROFIT
*** •«**
4/72
** / »*
CLOSED
• ** ****
(**•**
.._————- —————-—..........PERFORMANCE DATA——
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
SO? PART.
PER BOILED FGD CAP.
HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
74*
696
744
DURING THE FIRST BUAf)T£R OF 1980, ONLY THE VENTUR1 /SPRAY TOWER SYSTEM WAS
OPERATED. THE TCA SYSTEM CONTINUED TO OPERATE DURING THE QUARTER ON DOW*
BASIC ALUMINUM SULFATE PROCESS UNDER EPRI/UOP/TVA SPONSORSHIP.
THE LIHESTONE/ADIPIC ACID TEST SERIES ON THE VENTURI/SPRAY TOWER SYSTEM,
WHICH HAD BEEN INITIATED IN MID-DECEMBER TO INVESTIGATE THE RELATIONSHIP
BETWEEN THE SLURRY PH AND THE ADIPIC ACID CONSUMPTION (DEGRADATION) RATE,
WAS COMPLETED IN MID-FEBRUARY. THE TESTS WERE CONDUCTED WITHOUT FORCED
OXIDATION AND WITH A SINGLE HOLD TANK. AT THE SCRUBBER INLET PH OF 4.6
TO 5.0, ESSENTIALLY ALL OF THE ADIPIC ACID ADDED WAS ACCOUNTED FOR IN
THE LIQUID PHASE OF THE WASTE SLUDGE DISCHARGED FROM THE SYSTEM. AT THE
SCRUBBER INLET PH 5.25 AND 5.5, THE ADIPIC ACID UNACCOUNTED FOR WERE
6 PERCENT AND 26 PERCENT, RESPECTIVELY. THEREFORE, IT APPEARS THAT THE
ADIPIC ACID (OR CARBOXYLIC ACID) DEGRADATION TAKES PLACE AT SCRUBBER INLET
PH ABOVE ABOUT 5.1 UNDER CONDITIONS ASKED.
A SERIES OF IINESTONE/ADIP1C ACID TESTS WERE CONDUCTED FROM MID-FEBRUARY
TO EARLY MARCH USING THE VENTURI SCRUBBER ONLY WITH A SINGLE TANK AND
WITHOUT FORCED OXIDATION TO INVESTIGATE THE S02 REMOVAL CAPABILITY OF THE
VENTURI AT 5.1 INLET PH AND HIGH ADIPIC ACID CONCENTRATION. AT 4000 PPP
ADIPIC ACID, L/G OF 21 GAL/MCF, AND 8.3 INCHES H20 PRESSURE DROP, S02
REMOVAL WAS 65 PERCENT WITH 2200 PPM INLET SO? CONCENTRATION.
FORCED OXIDATION USING A SINGLE TANK WITH UIMESTONE/AOIP1C ACID SLURRY ON
109
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198C
TENNESSEE VALLEY AUTHORITY: SHAUNEE IOB
-------
EPA UTILITY FGD SURVEY: JANUARY - PUfiCH
SECTION J
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL OONESTjC FGD
COMPANY NAME
PLANT NAHE
JNIT NUMBER
CITT
GROSS UNIT GENERATING CAPACITY - WH
uFT UNIT GENERATING CAPACITY W/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - MW
• » FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - 1
AVERAGE SULFUR CONTENT - »
AVERAGE CHLORIDE CONTENT - *
.* FGO StSTEN
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - t
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PHRT1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
** DlSPOS»t
T»PE
- Z
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
B»IDGEPORT
ALA&AM*
5 5 :. 0
516.0
559.3
COAL
23260.
25.30
10.00
3.70
< 1"OOC BTU/LP)
WET SCRUBBING
LIMESTONE
TENNESSEE VALLEY AUTHORITY
RETROFIT
4.7
5/77
1/78
6".00
99.50
.3
.0
POND
•PERFORMANCE DATA-
" PIQD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER
PE S02 PART. HOURS HOURS
FGO CAP.
HOURS FACTOR
1/BO
A
B
C
D
SYSTEM
70.4
83.5
100.0
28.3
70.6
79.8
100.0
100.0
54.6
9C.4
39.2
S6.3
55.5
ze.9
44.5
83.60
744
366
331
PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE UNIT 8 BOILER EXPERIENCED LOW AVAILABILITY, CAUSING THF
FORCED OXIDATION TESTS TO BE DISCONTINUED UNTIL AFTER THE SCHEDULED
MAINTENANCE OUTAGE WHICH WILL BEGIN IN SEPTEMBER 19RO. THE FORCED OXIDA-
TION TESTS ARE EXPECTED TO RESUME IN JANUARY 1981.
2/80
A
B
C
SYSTEM
80.0
86.1
90.7
87.2
85.9
88.6
90.2
97.5
98.2
93.7
7?. f
74.0
80.0
80.6
76.5
84.00
696 571
535
*«
PROBLEMS/SOLUT1 ON S/COMENTS
BY FEBRUARY 27. 1980. THE DIFFERENTIAL PRESSURE ACROSS TRAIN "C" ABSORBER
HAD REACHED 19 INCHES WATER GA6E. THE HIGH ABSORBER DIFFERENTIAL PRESSURE
WAS CAUSED BY PLUG6A6E OF TURBULENT CONTACT ABSORBER (TtA) SPHERES WHICH
WERE INSTALLED DURING SCRUBBER OPTIMIZATION TESTS. THE TCA SPHERES WILL
BE REMOVED IN MARCH.
3/80
93.5
88.0
85.3
111
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
TENNESSEE VALLEY AUTHORITY: WIDOWS CREEK 8 (CONT.)
. —.__.__._.._..—..—___—_ .—PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
B
C
D
SYSTEM
93.0
71.9
93.3
87.9
90.6
73.3
63.9
78.9
87.9
71.1
61.9
76.6
8?. 60
744
722
570
** PROBIEMS/SOLUTIONS/COMNENTS
ON MARCH 3 THE TCA SPHERES INSTALLED IN TRAIN C AS PART OF THE OPTIMIZA-
TION TESTS HERE REMOVED. THE SPHERES HAD BECOME PLUGGED, RESULTING IN AN
ABSORBER DIFFERENTIAL PRESSURE OF 20 INCHES WATER GAGE. THE SPHERES HAD
BEEN IN USE SINCE NOVEMBER 17, 1979.
11Z
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 198?
SECTION 3
DESIGN ANP PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - HW
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
.. HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• TREATMENT
TYPE
** DISPOSAL
TYPE
- X
TEXAS UTILITIES
MARTIN LAKE
1
TATUH
TEXAS
793.0
7SO.O
595.0
COAL
LIGNITE
17166.
8.QO
33.00
.90
*»*****«
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
1.3
4/77
10/78
71.00
99.40
.0
.0
< 7380 6TU/LB)
CLOSED
34.6
< 550 6PH)
FLYASH STABILIZATION
LANDFILL
.........—..... ......—... ——PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 StSTEM
Z/80 SYSTEM
3/80 SYSTEM
•* PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
PLUGGING PROBLEMS CONTINUED IN THE FIRST QUARTER 1980, PARTICULARLY IN
THE WETTED FILM CONTACT AREA AND THE MIST ELIMINATOR SECTION. THE
MIST ELIMINATOR PLUGGING HAS RECENTLY SOLVED BY SWITCHING BACK TO LAKE
WATER FOR HIST ELIMINATOR WASH FROM AN ASH POND WATER WASH THEY HAD BEEN
TESTING.
THE FPP STRUCTURAL WORK IS BECOMING A PROBLEM.
WORK WAS REPLACED WITH STAINLESS STEEL.
MUCH OF THE FRP SUPPORT
THE UTILITY HAS PLANS TO INSTALL A NEW MODULE IN EARLY 198Z, THE NEW
MODULE HAS BECOME NECESSARY DUE TO THE INCREASE IN THE SULFUR CONTENT OF
THE LIGNITE.
113
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/FGD - My
EQUIVALENT SCRUBBED CAPACITY - My
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
*• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE OESI6N REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* HATER LOOP
TYPE
FSESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
** DISPOSAL
TYPE
- X
TEXAS UTILITIES
MARTIN LAKE
2
TATUM
TEXAS
793.0
750.0
595.0
COAL
LIGNITE
17166.
8.00
31.00
.90
********
UET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEU
1.3
5/78
**/ •*
71.00
99.40
.0
.0
( 7380 6TU/LR)
CLOSED
34.6
< 550 GPM)
FLVASH STABILIZATION
LANDFILL
......................... PERFORMANCE DATA-—-
PERIOD MODULE AVAILABILITY OPERA8UITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
Z/80 SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
PLUGGING PROBLEMS CONTINUED IN THE FIRST QUARTER 1980* PARTICULARLY IN
THE WETTED FILM CONTACT AREA AND THE MIST ELIMINATOR SECTION. THE
HIST ELIMINATOR PLUGGING WAS DECENTLY SOLVED BY SWITCHING BACK TO LAKE
WATER FOR HIST ELIMINATOR HASH FROM AN ASH POND WATER WASH THEY HAD BEEN
TESTING.
THE FRP STRUCTURAL WORK IS BECOMING A PROBLEM.
WORK WAS REPLACED WITH STAINLESS STEEL.
MUCH OF THE FRP SUPPORT
THE UTILITY HAS PLANS TO INSTALL A NEW MODULE IN THE FALL 1982. THE NEU
MODULE HAS BECOME NECESSARY DUE TO THE INCREASE IN THE SULFUR CONTENT OF
THE LIGNITE.
114
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGp SYSTrMS
COMPANY NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGO - ttu
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
.* TREATMENT
TYPE
• * DISPOSAL
TTPE
TEXAS UTILITIES
MARTIN LAKE
3
TATUW
TEXAS
793.C
750.0
595.0
COAL
LIGNITE
17166.
8.00
33.00
.90
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELl
NEW
1.3
2/79
** / * *
71.00
- X 99.40
.0
.0
FLYASH STABILIZATION
LANDFILL
( 7380 BTU/LB)
......—— PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILIT1 RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD C«P.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
•* PROBLEflS/SOLUTIONS/COMMENTS
696
744
PLUGGING PROBLEMS CONTINUED IN THE FIRST QUARTER 1980t PARTICULARLY IN
THE WETTED FILM CONTACT AREA AND THE MIST ELIMINATOR SECTION. THE
HIST ELIMINATOR PLUGGING WAS RECENTLY SOLVCD BY SWITCHING BACK TO LAKE
WATER FOR MIST ELIMINATOR WASH FROM AN ASH POND WATER WASH THEY HAD BEEN
TESTING.
THE FRP STRUCTURAL WORK IS BECOMING A PROBLEM* MUCH OF THE FRP SUPPORT
WORK WAS REPLACED WITH STAINLESS STEEL.
THE UTILITY HAS PLANS TO INSTALL A NEW MODULE IN EARLY 1983. THE NEW
MODULE HAS BECOME NECESSARY DUE TO THE INCREASE IN THE SULFUR CONTENT OF
THE LIGNITE.
115
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FCD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - M«
NET UNIT GENERATIN6 CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
** TREATMENT
TYPE
*• DISPOSAL
TYPE
TEXAS UTILITIES
MONTICELLO
3
MT. PLEASANT
TEXAS
800.0
750.0
800.0
COAL
LIGNITE
• * *****
18.90
31.90
1.50
.04
WET SCRUBBING
LIMESTONE
CHEMICO
NEW
(****»* BTU/lB>
5/78
10/78
74.00
X 99.50
.0
.0
CLOSED
( 546 CPM)
FLYASH STABILIZATION
LANDFILL
.. ............................,..—-__.PER FORM AN CE DATA——————————————._..
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
MO PROBLEMS VEftE ENCOUNTERED DURING THE FIRST QUARTER OF 1980.
116
-------
EPA UTILITY F60 SURVEY: JANUARY - MARCH 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGo SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/fGD - MU
EQUIVALENT SCRUBBED CAPACITY - HU
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - »
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - J
•* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
** TREATMENT
TYPE
«* DISPOSAL
TYPE
UTAH POUER l LIGHT
HUNTER
1
CASTLE DALE
UTAH
400.0
400.0
360.0
COAL
BITUMINOUS
29075.
10.00
6.50
.55
*«******
WET SCRUBBING
LIME
( 12500 BTU/Lf))
NEU
5/79
**/ * *
80.00
* 99.50
.0
OPEN
*******
(***** GPM)
FLYASH STABILIZATION
POND
.. ..... . ... —. —PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 7*4
2/80 SYSTEM 69«
J/80 SYSTEM 744
•* PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FIRST QUARTER 1980.
117
-------
EP» UTILITY FGD SURVEY: JANUARY - MARCH i960
SECTION 3
DESIGN AND PERFORMANCE 6ATA FOP OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - My
EOUIVALENT SCRUBBED CAPACITY - MU
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-OP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - x
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
«• TREATMENT
TYPE
•• DISPOSAL
TYPE
- X
UTAH POWER 8 LIGHT
HUN71NGTON
1
PR! CE
UTAH
43:.o
iCD.O
366.0
COAL
BITUMINOUS
29075.
10.00
6.50
.55
********
WET SCRUBBING
LlM£
CHEMICO
NEW
1.6
5/78
*•/ •*
80.00
99.50
2.5
.0
CLOSED
18.9
( 125CO BTU/LB)
< 300 GPM)
FLYASM STABILIZATION
LANDFILL
— ———————————————PERFORMANCE DATA — ——————....____..__
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD c**~"
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FIRST QUARTER 1980.
118
-------
EPA UTILITY FGD SURVEY: JANUARY - HARCH 1960
SECTION 4
SUMMARY OF FGD SYSTEMS BY COMPANY
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
PLANNED
COMPANY NAME
ALABAMA ELECTRIC COOP
ALLEGHENY POWER SYSTEM
AR^ONA ELECTRIC POWER COOP
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC COOP
BASIN ELECTRIC POWER COOP
BIG RIVERS ELECTRIC
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CINCINNATI GAS It ELECTRIC
COLORADO UTE ELECTRIC ASSN.
COLUMBUS K SOUTHERN OHIO ELEC.
COMMONWEALTH EDISON
COOPERATIVE POWER ASSOCIATION
DELMARVA POWER K LIGHT
DESERET GENERATION K TRANS COO
DUQUESNE LIGHT
EAST KENTUCKY POWER COOP
GENERAL PUBLIC UTILITIES
GRAND HAVEN BRD OF LIGHT K PWR
HOOSIER ENERGY
HOUSTON LIGHTING S POWER CO.
INDIANAPOLIS POWER t LIGHT
KANSAS CITY POWER g LIGHT
KANSAS POWER t LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LOUISVILLE GAS 1 ELECTRIC
MICHIGAN SO. CENTRAL PWR AGENC
MIDDLE SOUTH UTILITIES
MINNESOTA POWER t LIGHT
MINNKOTA POWER COOPERATIVE
MONTANA POWER
MUSCATINE POWER t WATER
NEVADA POWER
NEW YORK STATE ELEC & GAS
NIAGARA MOHAWK POWER COOP
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
OTTER TAIL POWER
PACIFIC GAS t ELECTRIC
PACIFIC POWER t LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
POTOMAC ELECTRIC POWER
PUBLIC SERVICE INDIANA
PUBLIC SERVICE OF NEW MEXICO
PWR AUTHORITY OF STATE Or NY
SALT RIVER PROJECT
SAN MIGUEL ELECTRIC COOP
SERINOLE ELECTRIC
SIKESTON BOARD OF HUNIC. UTIL.
SOUTH CAROLINA PUBLIC SERVICE
SOUTH MISSISSIPPI ELEC PWR
SOUTHERN ILLINOIS POWER COOP
SOUTHERN INDIANA GAS t ELEC
SOUTHWESTERN ELECTRIC POWER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER. LIGHT t PWR
ST. JOE ZINC
TAMPA ELECTRIC
TENNESSEE VALLEY AUTHORITT
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER K LIGHT
NO.
2
3
2
8
1
5
4
2
1
1
2
3
4
1
2
2
2
2
3
5
1
2
1
5
3
4
1
1
10
1
6
1
1
4
1
10
1
1
3
4
1
2
1
3
4
1
1
4
1
3
1
2
1
3
2
2
1
1
1
1
1
1
7
1
3
ix W
358.
1738.
790.
2684.
670.
2680.
1764.
794.
617.
600.
1700.
1341.
1572.
450.
654.
730.
820.
920.
1800.
3475.
81.
882.
492.
3012.
1054.
1575.
64.
364.
3554.
55.
534Q.
475.
405.
2120.
160.
3125.
870.
100.
957.
2450.
440.
1600.
550.
2751.
844.
800.
650.
1779.
700*
840.
400.
1240.
235.
700.
248.
484.
265.
720.
194.
205.
60.
*75.
3153.
(00.
1882.
NO.
2
1
2
5
0
0
1
1
1
0
0
1
2
0
1
0
0
2
0
0
0
c
0
1
3
3
1
0
5
0
0
0
1
2
0
3
0
0
1
2
0
0
1
2
1
0
0
3
0
1
0
0
0
1
2
1
1
0
1
0
1
0
3
0
0
MM
358.
519.
390.
1348.
0.
0.
242.
378.
617.
C.
0.
447.
822.
0.
327.
0.
0.
920.
0.
0.
0.
0.
0.
532.
1054.
1085.
64.
0.
1201.
0.
0.
0.
405.
720.
0.
375.
0.
0.
115.
1480.
0.
0.
550.
1834.
120.
0.
0.
1245.
0.
280.
0.
0.
0.
140.
248.
184.
265.
0.
194.
0.
60.
0.
570.
0.
0.
NO.
n
1
n
1
1
4
1
0
0
c
1
1
0
1
1
1
0
n
1
0
n
1
0
1
0
1
0
1
3
C
0
1
0
2
0
0
0
1
0
1
1
0
0
1
2
0
0
1
0
1
1
0
1
1
0
0
0
0
0
1
0
0
3
1
1
»n
C-
519.
C.
126.
670.
2J40.
242.
I. •
0.
C.
650.
447.
C.
450.
327.
180.
0.
0.
500.
C.
C.
441.
C.
530.
C.
490.
C.
364.
1203.
C.
0.
475.
0.
1400.
c.
0.
0.
100.
0.
110.
440.
0.
0.
917.
574.
C.
c.
534.
0.
280.
400.
0.
235.
280.
0.
0.
0.
0.
0.
205.
0.
0.
1983.
400.
382.
NO*
0
1
r.
2
0
0
0
c
c
0
0
0
0
c
c
0
0
c
0
c
1
1
1
0
c
0
0
0
0
1
0
c
0
0
1
0
c
0
0
0
0
0
0
0
1
0
1
0
0
0
0
2
0
1
0
0
0
1
0
0
0
0
1
0
2
MW
c.
300.
w •
1510.
0.
c.
0.
C..
c.
c.
c.
0.
0.
w •
1. •
w«
u •
c.
*s •
0.
81.
441 .
492.
w •
0.
0.
J.
r\
u •
C.
55.
0.
0.
c.
w .
160.
0.
0.
G.
u *
0.
0.
0.
0.
0.
150.
C.
650.
0.
0.
0.
0.
1240.
0.
280.
0.
0.
0.
72C.
0.
0.
0.
0.
600.
0.
1500.
NO.
0
n
f\
r\
n
1
2
1
n
1
1
1
2
^
'
i
2
f\
2
5
0
0
n
3
0
^
0
0
2
n
6
n
r\
n
n
7
1
r
2
1
n
2
0
0
0
1
0
a
i
i
D
0
n
0
0
1
c
c
0
0
0
1
0
0
0
MW
V. •
0.
c.
£.
0.
44?.
88 C.
416.
0.
603.
«s:.
447.
75C;.
U •
w •
55T.
ez:.
r.
. •
13CO.
3475.
C.
C.
c.
195C.
r, t
0 .
C.
" .
1150.
C .
534C.
C.
C.
:.
0.
2750.
87C.
0.
842.
86C.
0.
1600.
0.
c.
0.
800.
C.
P.
7CC.
280.
C *
o.
0.
0«
c.
3QQ.
0-
0.
0.
0.
0.
475.
0.
c.
0.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT S1G
AND CONSIDERING ONLY FGD SYSTEMS
NED* REAUESTING/EVALUTING BIDS,
119
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 1980
SECTION «
SUMMARY OF FCO SYSTEMS BY COMPANY
TOTAL
OPERATIONAL
CONSTRUCTION CONTRACT
PLANNED
AWARDED
COMPANY NAME
TEXAS UTILITIES
TUCSON ELECTRIC POWER
UNITED POWER ASSOCIATION
UTAH POWER C LIGHT
NO.
8
2
1
5
MW
5585.
740.
50.
1886.
NO.
4
0
0
2
MW
2585.
0.
0.
726.
NO.
0
0
0
1
MW
0*
0.
0.
360.
NO*
1
z
1
2
MW
750.
740.
50.
800.
NO.
3
0
0
C
My
2250.
0.
0.
C.
TOTALS 181 81568. 65 22100. 42 18*54. 23 10519. 51 3Q495.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIC NED, RE-OOESTINC/EVALUTIN6 BIDS,
AND CONSIDERING ONLY FtO SYSTEMS
120
-------
EPA UTILITY (GO SURVEY: JANUARY - MARCH 1980
SECTION 5
SUMMARY OF F60 SYSTEMS BY SYSTEM SUPPLIER
TOTAL
STATUS
OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
SYSTEM SUPPLIER
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 1980
SECTION <
SUMMARY OF FGO SYSTEMS PY SYSTEM SUPPLIER
TOTAL
SYSTEM SUPPLIER/PROCESS
KOMLINE K SANDERSON
LIME/SPRAY DRYING
TOTAL -
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
TOTAL -
PEABODY PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
PULLMAN KELLOGG
LIME
LIMESTONE
TOTAL -
RESEARCH COTTSELL
LIMESTONE
TOTAL -
RILEY ENVIRONEERING
MAGNESIUM OXIDE
TOTAL -
RILEY STOKER/ENVIRONEERIN6
LIMESTONE
TOTAL -
ROCKWELL INTERNATIONAL
AOUEOUS CARBONATE
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
LIME
MAGNESIUM OXIDE
TOTAL -
WHEELABRATOR-FRYE/R.I.
AOUEOUS CARBONATE/SPRAY DRYING
TOTAL -
NO.
1
1
2
2
6
1
7
1
4
5
14
U
1
1
3
3
1
1
1
1
2
4
6
1
1
My
50.
50.
682.
882.
2492.
475.
2967.
917.
1880.
2797.
5615.
5615.
600.
600.
626.
626.
100.
100.
550.
550.
1510.
844.
2354.
440.
440.
OPERATIONAL
NO.
0
C
r
C
3
r
3
C
1
1
7
7
0
n
3
3
0
0
1
1
0
1
1
0
0
MU
^
-' •
0.
C.
C.
805.
0.
805 .
0.
280.
280.
2644.
2644.
0.
0.
626.
626.
0.
0.
550.
550.
0.
120.
120.
0.
0.
CONSTRUCTION
NO.
0
0
1
1
1
1
2
1
2
3
5
5
0
0
0
0
1
1
0
0
0
2
2
1
1
MW
0.
0.
441.
441.
447.
475.
922.
917.
950.
1867.
2061.
2061.
0.
0.
0.
0.
100.
100.
0.
0.
0.
574.
574.
440.
440.
CONTRACT
AWARDED
NO.
1
1
1
1
2
0
2
0
1
1
2
2
1
1
C
0
0
0
0
0
2
1
3
0
0
iy
5n.
50.
441.
441.
1240.
0.
1240.
0.
650.
650.
91p.
910.
600.
600.
?.
0.
0.
C.
C.
0.
1510.
15D.
1660.
0.
0.
TOTAL -
130 51073.
65 22100.
42 18454.
23 10519.
122
-------
EPA UTILITY fGO SURVEY: JANUARY - MARCH 19fcO
SECTION 6
SUMMARY OF FGD SYSTEMS R» PROCESS
TflTAt
STATUS
OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
PLANNED
PROCESS
NO.
MW
NO.
MU
NO.
Mta
NO.
MW
NO.
MW
AQUEOUS CARBONATE
CITRATE
LIMESTONE
MAGNESIUM OXIDE
WELLMAN LORD
1
1
3
5
6
100.
60.
1760.
1444.
2C74.
0
1
0
1
4
0.
60.
0.
120.
1360.
1
0
0
2
2
100.
0.
fi.
574.
714.
0
0
1
2
C
j »
o •
160.
75:.
j.
*
n
2
rt
n
^.
? m
16CC.
w •
? •
SUBTOTAL - SALEABLE PRODUCT
5(38.
154C.
1T88.
910.
1600.
UEOUS CARPONATE/SPRAY DRYING
AL ALKALI
ME
MESTONE
MESTONE/ALKALINE
FLVASH
ME;ALKALINE FLVASH
ME/LIMESTONE
ME/SPRAY CRYING
OCESS NOT SELECTED
ID1UM CARBONATE
SUBTOTAL - THROWAUAt PRODUCT
1
5
34
66
2
11
2
8
31
5
165
440.
2^23.
13P71.
29721.
1480.
4233.
20.
2P27.
20340.
1175.
76130.
0
3
17
24
2
7
2
n
0
*
59
0.
11S1 .
6209.
£714 .
148C.
2^31.
20.
C.
ri
925.
20560.
1
g
9
2C
0
4
*
3
D
r
37
440.
0.
4791.
8»83.
C.
220?.
r .
115T.
C.
C.
17066.
r
0
4
13
0
o
r
w
3
\_
0
20
;,
0.
1891 .
6928.
J.
j.
0.
793.
j.
^ •
9609.
7
2
4
9
n
C
j
2
i1
1
49
C .
842.
1 3 8 1 • .
5196.
3.
0.
c.
887.
20340.
25:.
28895.
TOTALS
SALEABLE X OF TOTAL MW
181 S1568.
7
65 22100.
7
42 18454.
8
23 11519.
9
51 3C495.
5
123
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SECTION 7
SUMMARY OF OPERATIONAL fGD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
CITRATE
6.F. yEATON
DUAL ALKALI
A.B. BROUN
CANE RUN
NEWTON
UNIT NO.
1
1
(
1
CAPACITY
MW
60.
60.
265.
299.
617.
INITIAL
STARTUP
11/79
4/79
4/79
9/79
COMMERCIAL
ST»RTUP
1/80
4/79
o/ c
12/79
1181.
L1*E
BRUCE MANSFIELD
BRUCE MANSFIELD
CANE RUN
CANE RUN
CONESVILLE
CONESVILLE
FL"AMA
GREEN
GREEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTINGTON
MILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS
LIMESTONE
AP«CHE
APACHE
CHOLLA
CHOLLA
CORONADO
CRAIG
DUCK CREEK
JEFFREY
LA CY6NE
LAWRENCE
LAWRENCE
MARION
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MONTICELLO
PETERSBURG
R.D. MORROW
R.D. MORROW
SOUTHWEST
TOMBIGBEE
TO"B1GBEE
WIDOWS CREEK
WINYAH
4
5
5
6
1-4
1
1-3
3
4
1
1
3
«
1-6
1
2
3
1
?
1
2
1
1
1
4
5
4
1
2
3
3
3
1
2
1
2
3
t
2
917.
917.
186.
200.
411.
411.
510.
242.
64.
90.
90.
360.
366.
442.
72.
410.
519.
6209.
LIMESTONE/ALKALINE FLVASH
SHERBURNE 1
SHERBURNE 2
87U.
740.
740.
1480.
12/75
7/77
8/76
12/77
1/77
6/78
10/75
12/79
9/75
11/72
8/72
5/79
5/78
8/78
4/73
7/73
3/79
6/76
!>/ 0
»/77
7/78
2/77
O/ 0
10/75
12/79
6/76
C/ 0
C/ 0
C/ 0
P/ 0
3/79
C1/ 0
o/ c
O/ 0
195.
195.
119.
350.
280.
447.
378.
540.
874.
125.
420.
184.
595.
595.
595.
800.
532.
124.
124.
194.
179.
179.
550.
140.
8/78
6/79
10/73
4/78
11/79
8/79
7/76
8/78
2/73
1/76
11/71
5/79
4/77
5/78
2/79
5/78
12/77
8/78
6/79
4/77
9/78
6/79
5/77
7/77
1/79
4/79
12/73
r*/ o
12/79
6/80
»/78
O/ 0
6/73
O/ 0
O/ 0
5/79
10/78
O/ 0
O/ 0
10/78
12/77
8/78
6/79
P/ 0
9/78
6/79
1/78
O/ 0
3/76
4/77
5/76
4/77
124
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1"8'
SECTION 7
SUMMARY OF OPERATIONAL FGO SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
UNIT NO.
CAPACITY
MW
INITIAL
STARTUP
COMMERCIAL
STARTUP
LIME/ALKALINE FLYASH
COAL CREEK
COLSTRIP
COLSTRIP
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
MILTON R. YOUNG
LIME/LINE STONE
SHAWNEE
SHAWNEE
MAGNESIUM OXIDE
EDDYSTONE
SODIUM CARBONATE
JIM BRIDGES
REID GARDNER
REID GARDNER
REID GARDNER
WELLMAN LORD
DEAN H. MITCHELL
SAN JUAN
SAN JUAN
SAN JUAN
TOTAL
10B
1A
327.
11
1
175.
175.
229.
10.
10.
20.
120.
120.
550.
125.
12sl
925.
115.
361.
350.
534.
136Q.
22100.
8 /79
9/75
5/76
11/79
11/79
11/79
9/77
4/72
4/72
9/75
9/79
4/74
4/7*
6/76
7/76
4/78
8/7?
12/79
-I 0
11/75
10/76
r/ o
?/ o
?/ 0
6/78
:>/ c
'/ c
9/75
2/?0
->/ C
"/ C
7/76
6/77
n/ p
?/ 0
«/ 0
125
-------
EPA UTILITY FGD SU»VEY: JANUARY - MARCH 1980
SECTION 8
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
PROCESS/
UNIT NAME
CITRATE
G.F. WEATON
DJAL ALKALI
A. St BROWN
CANE RUN
MEWTON
L11E
3RUCE MANSFIELD
3RUCF MANSFIELD
CANE RUN
CANE RUN
CONESVILLE
CONESVILLE
ELAAMA
GREEN
GREEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HJWTINGTON
MILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS
LIMESTONE
APACHE
APACHE
CHOLLA
CHOLLA
CORONADO
CRAIG
DUCK CREEK
JEFFREY
LA CVGNE
LAWRENCE
LAWRENCE
MARION
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MONTICELLO
PETERSBURG
R.D. NORROU
R.D. MORROW
SOUTHUEST
TOMBIGBEE
TOWBIG8EE
WIDOWS CREEK
WINY AH
UNIT
1
1
6
1
1
2
4
5
5
6
1-4
1
1-3
3
4
1
1
3
6
1-6
1
2
3
1
2
1
2
1
1
1
4
5
4
1
2
3
3
3
1
2
1
2
3
8
2
NO STABILIZED UNSTABILI/ED TYPE DISPOSITION
ELEMENTAL SULFUR
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LINED POND
LINED POND
POND
POND
LANDFILL
LINED POND
POND
POND
POND
LANDFILL
POND
POND
LANDFILL
POND
POND
POND
POND
LINED POND
HINEFILL TO WASTE
LINED POND
POND
UNLINED POND
POND
POND
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LINED POND CAS03-CAS04 POND
LINED POND CAS03-CAS04 POND
POND
POND
LIMESTONE/ALKALINE FLYASH
SHERBURNE
SHERBURNE
LIME/ALKALINE FLtASH
COAL CREEK
COLSTSIP
COLSTRJP
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
MILTON R. YOUNG
1
2
1
1
2
1
2
3
2
LINED POND
LINED POND
LINED POND
POND
POND
flNEFILL
126
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH
SECTION f
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGO SYSTEMS
PROCESS;
JNIT NAME
THROWAWAY
UNIT NO STABILIZED UNSTABILIZED
-BYPRODUCT-
TYPE
01SPOSITION
LIME/LIMESTONE
SHAKNEE
SHAfcNEE
MAGNESIUM OXIDE
EODYSTONE
S3D1UM CARBONATE
JIM PRIUGES
REID GARDNER
REID GARDNER
REID GARDNER
LORD
DEAN H. "ITCHEll
SAN JUAN
SAN JUAN
SAN JUAN
1CB
1A
<•
1
2
3
11
1
2
3
SULFURK ACID
POND
LINED POND
LINED POND
LINED POND
ELEMENTAL SULFUR
ELEMENTAL SULFUR
ELEMENTAL SULFUR
SULFU"IC ACID
MARKETED
MARKETED
MARKETED
127
-------
EP* UTILITY FGD SU"VEY: JANUARY - MARCH 198C
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
ALABAMA ELECTRIC COOP
TOMB16BF.E 2
•LABAMA ELECTRIC COOP
TOMBIGBEE 3
ALLEGHENY POWER SYSTEM
PLEASANTS i
ARIZONA ELECTRIC POWER COOP
APACHE 2
ARIZONA ELECTRIC POWER COOP
APACHE 3
ARIZONA PUBLIC SERVICE
CHOLL* t
ARIZONA PUBLIC SERVICE
CHOLLA 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZONA PUPLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
BIG RIVERS ELECTRIC
GREEN 1
CENTRAL ILLINOIS LI6HT
DUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
COLORADO UT£ ELECTRIC ASSN.
CRAJ6 Z
COLUMBUS t SOUTHERN OHIO ELEC.
CONESV1LLE 5
COLUMBUS t SOUTHERN OHIO ELEC.
CONESVILLE 6
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
OUOUESNE LIGHT
ELRAM* 1-4
DUQUESNE LIGHT
PHILLIPS 1-6
INDIANAPOLIS POWER t LIGHT
PETERSBURG 3
KANSAS CITY POWER « LIGHT
HAWTHORN 3
KANSAS CITY POWER * LIGHT
HAWTHORN *
KANSAS CITY POWER « L16HT
LA CY6NE 1
KANSAS POWFfi t LIGHT
• c r c n r « 1
NEta OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROf IT
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
CAPAC ITY
MW
179.:
179.0
519.1
195 .1
195.?
119. ?
350.?
175.0
175.0
229.0
242."
378. C
617.?
447.0
411.0
411.0
327.0
510.0
410.0
532.0
90.0
90.0
874.3
540.0
PROCESS/
SYSTEM SUPPLIER
IJMESTOM*
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
PA8COCK * WILCOX
LIMESTONE
RESEARCH COTTBELL
LIMESTONE
OESEARCH COTTBELL
LIMESTONE
RESEARCH COTT&F.LL
LIMESTONE
RESEARCH COTTRELL
LJME/AIKALINE FlYASH
CHEMICO
IJME/ALKALIWE FLYASH
CHEMJCO
LIME/ALKALINE FLYASH
CHEMICO
LIME
AMERICAN AIR FILTER
LIMESTONE
RILEY STOKER/ENVIRONEERING
DUAL ALKALI
BUELL/ENVISOTECH
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
AIR CORRECTION DIVISION, UOP
LJME
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME
CHEMICO
LIME
CHEMICO
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK 8 UILCOX
LIMESTONF
COMRUSTION ENGINEERING
STAPT-UP
DATE
9/78
6/79
3/79
3/78
6/79
10/7!
4/78
11/79
11/79
11/79
12/79
7/76
9/ 79
8/79
1/77
6/78
8/79
10/75
7/73
12/77
11/72
8/72
2/73
8/78
128
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
KANSAS POWER t LIGHT
LAWRENCE 4
KANSAS POWER ( LIGHT
LAWRENCE 5
KENTUCKY UTILITIES
GREEN RIVER 1-3
LOUISVILLE GAS ( ELECTRIC
CANE RUN t
LOUISVILLE GAS t ELECTRIC
CANE RUN 5
LOUISVILLE 6AS t ELECTRIC
CANE RUN 6
LOUISVILLE GAS ( ELECTRIC
MILL CREEK 3
LOUISVILLE GAS t ELECTRIC
PADDY'S RUN 6
M1NNKOTA POWER COOPERATIVE
MILTON R. YOUNG 2
MONTANA POWER
COLSTRIP 1
MONTANA POWER
COLSTRIP Z
NEVADA POWFR
REID GARDNER 1
NEVADA POWER
OEID GARDNER 2
NEVADA POWER
REID GARDNER 3
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
NORTHERN STATES POWER
SHERBURNE 1
NORTHERN STATES POWER
SHERBURNE 2
PACIFIC POWER 8 LIGHT
JIB BRIDGER 4
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
PHILADELPHIA ELECTRIC
EDDVSTONE 1A
PUBLIC SERVICE Of NEW MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 2
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
NEW OR C
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
:APACIT»
nw
125.0
420.0
64. 0
188.0
200.0
299.0
442.0
72.0
405.0
360.0
360.0
125.0
125.0
125.0
115.0
740.0
740.0
550.0
917.0
917.0
120.0
361.0
350.0
534.0
PROCESS/ S
SYSTEM SUPPLIER
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
DUAL ALKALI
AOL/COMBUSTION EOUIP ASSOCIATE
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
LIME/ALKALINE FLYASH
ADL/COMBUST10N EOUIP ASSOCIATE
LIME/ALKALINE FLYASH
AOL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALINE FLYASH
AOL/COMBUSTION EOUIP ASSOCIATE
SODIUM CARBONATE
AOL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
AOL/COMBUSTION EOUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EOUIP ASSOCIATE
WELLMAN LORD
DAVY POWER6AS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
SODIUM CARBONATE
AIR CORRECTION DIVISION. UOP
LIME
CHEHICO
LIME
CHEMICO
MAGNESIUM OJUDE
UNITED ENGINEERS
WELLMAN LORD
DAVY POWERGAS
WELLMAN LORD
DAW POWERGAS
WELLMAN LORD
DAVY POWERGAS
START-UP
DATE
1/76
11/71
9/75
8/76
12/77
4/79
8/78
4/73
9/77
9/75
5/76
4/74
4/74
6/76
7/76
3/76
4/77
9/79
12/75
7/77
9/75
4/78
8/78
12/79
129
-------
EPA UTILITY FGD SUPVEY: JANUARY - MARCH 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
SALT RIVER PROJECT
CORONADO 1
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 2
SOUTH MISSISSIPPI ELEC PWR
R.O. MORPOW 1
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW 2
SOUTHERN ILLINOIS POWER COOP
MARION 4
SOUTHERN INDIANA GAS & ELEC
A.B. BROUN 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
ST. JOE ZINC
G.F. UEATON 1
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10A
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10B
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 8
TEXAS UTILITIES
MARTIN LAKE 1
TEXAS UTILITIES
MARTIN LAKE 2
TEXAS UTILITIES
MARTIN LAKE 3
TEXAS UTILITIES
MONTICELLO 3
UTAH POWER t, LIGHT
HUNTER 1
UTAH POWER & LIGHT
HUNTIN6TON 1
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW
280.0
UO.O
124.0
124.3
184.0
265.0
194.0
60.0
10.0
10.0
550.0
595.0
595.0
595.0
800.0
360.0
366.0
PROCESSy
SYSTEM SUPPLIER
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BAB COCK I WILCOX
LIMESTONE
RILEY STOKER/ENVIRONEERING
LIMESTONE
RILEY STOKER/ENVIRONEERING
LIMESTONE
BAB COCK K WILCOX
DUAL ALKALI
FMC
LIMESTONE
AIR CORRECTION DIVISION. UOP
CITRATE
BUREAU OF MINES
LIME/LIMESTONE
*IR CORRECTION DIVISION, UOP
LIME/LIMESTONE
CHEMICO
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
CHEMICO
LIME
CHEMICO
LIME
CHEMICO
START-UP
DATE
11/79
7/77
a/78
6/79
S/79
4/79
4/77
11/79
4/72
4/72
5/77
4/77
5/78
2/79
5/78
5/79
5/78
130
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 198C
SECTION 10
SUMMARY Of FGO SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
ALLEGHENY POWEP SYSTEM
PLEASANTS 2
ARIZONA PUBLIC SERVICE
CHOLLA 4
ASSOCIATED ELECTRIC COOP
THOMAS HILL 3
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 1
BASIN ELECTRIC POUER COOP
LARAniE RIVER 1
BASIN ELECTRIC POWER COOP
LARAMIE RlvER 2
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 3
BIG RIVERS ELECTRIC
6REEN 2
CINCINNATI GAS t ELECTRIC
EAST BEND 2
COLORADO UTE ELECTRIC ASSN.
CRAIG 1
COMMONWEALTH EDISON
POWERTON 51
COOPERATIVE POWER ASSOCIATION
COAL CREEK 2
DELMARVA POWER t LIGHT
DELAWARE CITY 1-3
EAST KENTUCKY POUER COOP
SPURLOCK 2
HOOSIER ENERGY
HERON 2
INDIANAPOLIS POUER I LIGHT
PETERSBURG 4
KANSAS POWER K LIGHT
JEFFREY 2
LAKELAND UTILITIES
MCINTOSH 3
LOUISVILLE GAS t ELECTRIC
MILL CREEK 1
LOUISVILLE GAS S ELECTRIC
HILL CREEK 2
LOUISVILLE GAS 1 ELECTRIC
MILL CREEK 4
MINNESOTA POWER & LIGHT
CLAY BOSUELL 4
MONTANA POWEP
COLSTRIP 3
MONTANA POWER
COLSTRIP 4
NEU OR CAPACITY
RETROFIT nu
NEW
NEW
NEU
NtW
NEW
NEW
NEW
N£W
NEW
NEW
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEU
NEU
NEW
NEU
519.0
126.0
670.0
440.0
600.0
603.0
600.0
242.0
653.0
447.0
45D.O
327.0
180.0
500.0
441 .0
530.0
490.0
364.0
358.0
350.0
495.3
475.0
700.0
700.0
PROCESS/ START-UP
SYSTEM SUPPLIER BATE
LIME
BABCOCK K UILCOX
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
PULLMAN KELLOGG
LIME/SPRAY DRYING
JOY MF6/NIRO ATOHI7ER
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIME/SPRAY DRYING
BABCOCK 8 WILCOX
LIME
AMERICAN AIR FILTER
LIME
BABCOCK * WILCOx
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AID CORRECTION DIVISION. UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
UELLMAN LORD
DAVY MCKEE
LINE
AOL/COMBUSTION EQUIP ASSOCIATE
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK t WILCOX
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME/ALKALINE FLVASH
PEABODY PROCESS SYSTEMS
LIME/ALKALINE FLVASH
ADL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALIME FLYASH
ADL'COMBUSTION EQUIP ASSOCIATE
9/80
6/80
1/82
4/82
4/80
11/80
4/82
11/80
9/80
4/8C
4/80
7/80
4/80
1/81
7/81
10/84
4/80
10/81
4/81
4/82
7/81
4/80
1/84
0/84
131
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
NORTHERN STATES POWER
RIVERSIDE 6,7
OTTER TAIL POWER
COYOTE 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 3
PHILADELPHIA ELECTRIC
EDDYSTONE 1B
PHILADELPHIA ELECTRIC
EODVSTONE 2
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 4
SALT RIVER PROJECT
CORONADO 2
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SIKESTON BOARD OF MUNIC. UTIL.
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
WINVAH 3
SPRINGFIELD WATER, LIGHT « PWR
DALLMAN 3
TENNESSEE VALLEY AUTHORITY
PARADISE 1
TENNESSEE VALLEY AUTHORITY
PARADISE 2
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
TEXAS POWER i LIGHT
SANDOW 4
UTAH POWER & LIGHT
HUNTER 2
NEW OR
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
CAPACITY
MW
100.0
110.0
440.3
917.0
240.0
334.0
534.0
230.3
400.0
235.0
280.0
205.0
704.0
704.0
575.0
400.0
382.0
360.0
PROCESS/
SYSTEM SUPPLIER
AQUEOUS CARBONATE
ROCKWELL INTERNATIONAL
LIME/SPRAY DRYING
JOY MF6/NIRO ATOMIZER
AQUEOUS CARBONATE/SPRAY
WHEELABRATOR-FRYE/R.I .
LIME
PULLMAN KELLOGG
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
WELLMAN LORD
DAVY POWERGAS
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BAB COCK K WILCOX
LIMESTONE
BAB COCK K WILCOX
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
CHEKICO
LIMESTONE
CHEMICO
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
CHEMICO
START-UP
DATE
4/82
7/80
DRYING 3/81
10/80
12/82
12/82
6/82
7/80
9/flO
1/81
5/80
11/80
3/82
6/82
9/81
1/82
7/80
6/80
132
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 11
SUMMARY Of CONTRACT AWARDED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
ALLEGHENY POWE« SYSTEM
MITCHELL 33
•R110NA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
GRAND HAVEN BOD OF LIGHT I PVR
J. B. SIMS 3
HOOSIER ENERGY
MEROM 1
HOUSTON LIGHTING & POWER CO.
V.A. PARISH 8
MICHIGAN so. CENTRAL PUR AGENC
PROJECT 1
MUSCATINE POWER t WATER
MUSCATINE 9
PHILADELPHIA ELECTRIC
CROMBV
PUBLIC SERVICE INDIANA
GIBSON 5
SEMINOLE ELECTRIC
SEMINOLE 1
SEMINOLE ELECTRIC
SEMINOLE 2
SOUTH CAROLINA PUBLIC SERVICE
UINYAH 4
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY 1
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE 1-10
TEXAS POWER t LIGHT
TWIN OAKS 1
TEXAS POWER t LIGHT
TWIN OAKS 2
TEXAS UTILITIES
MARTIN LAKE 4
TUCSON ELECTRIC POWER
SPRIN6ERVILLE 1
TUCSON ELECTRIC POWER
SPR1NGERVILLE 2
UNITED POWER ASSOCIATION
STANTON 2
UTAH POWER t LIGHT
HUNTER 3
UTAH POWER t LIGHT
HUNTER *
NEW OR I
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROf IT
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NiW
NEW
NEW
NEW
NEW
NEW
CAPAC ITY
MU
300.0
755.0
755.3
81.9
4*1.0
492.0
55.0
160.0
150.0
650.0
620.0
620.0
280.0
720.0
600.0
750.0
750.0
750.0
370.0
370.0
50.0
400.0
400.0
PROCESS/
SYSTEM SUPPLIER
LIME
CHEMICO
LIME
UNITED ENGINEERS
LIME
UNITED ENGINEERS
LIME
PABCOCK t WILCOX
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
CHEMICO
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
RESEARCH COTTRELL
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
AIR CORRECTION DIVISION. UOP
MAGNESIUM OBIDE
RILEY ENVIRONEERING
LIMESTONE
CHEMICO
LIMESTONE
CHEMICO
LIMESTONE
RESEARCH COTTRELL
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LINE/SPRAY DRYING
KOMLINE 8 SANDERSON
LIMESTONE
CHEMICO
LIMESTONE
CHEMICO
START-UP
DATE
8/82
0/82
0/82
6/83
5/82
11/82
7/82
9/82
12/82
C/82
3/83
3/85
7/81
12/84
12/81
e/84
8/85
0/85
6/85
1/87
1/82
0/83
0/85
133
-------
EPA UTILITY FGD SURVEYr JANUARY - MARCH 1980
SECTION 12
SUMMARY OF PLANNED FGO SYSTEMS
COMPANY NAME/
UNIT NAME
NEU OR CAPACITY PROCESS;
UNIT NO. RETROFIT NW SYSTEM SUPPLIER
START-UP
DATE
LETTER OF INTENT SIGNED
NEW
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
NORTHERN INDIANA PUB SERVICE
SCHAHFER 18
NEU
421 .0 DUAL ALKALI
FMC
421 .0 DUAL ALKALI
FMC
REQUESTING/EVALUATING BIDS
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
DESERET GENERATION & TRANS COO
MOON LAKE 1
DESERET GENERATION fc TRANS COO
MOON LAKE 2
MIDDLE SOUTH UTILITIES
ARKANSAS COAL 5
MIDDLE SOUTH UTILITIES
ARKANSAS COAL 6
MIDDLE SOUTH UTILITIES
LOUISIANA COAL 1
MIDDLE SOUTH UTILITIES
LOUISIANA COAL 2
MIDDLE SOUTH UTILITIES
MISSISSIPPI COAL 1
MIDDLE SOUTH UTILITIES
MISSISSIPPI COAL 2
NEVADA POWER
REID GARDNER 4
NEW YORK STATE ELEC t GAS
SOMERSET 1
NORTHERN STATES POWER
SHERBURNE 3
TAMPA ELECTRIC
BIG BEND 4
TEXAS UTILITIES
FOREST GROVE 1
CONSIDERING FGD SYSTEMS
BIG RIVERS ELECTRIC
0. B. WILSON 1
BIG RIVERS ELECTRIC
D. B. WILSON 2
CENTRAL MAINE POWER
SEARS ISLAND 1
CINCINNATI G*S t ELECTRIC
EAST BEND 1
COLORADO UTE ELECTRIC ASSN.
CRAIG 3
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
IS
NEW
NEW
NEW
NEW
NEW
440.0
416.0
410.0
410.0
890.0
890.0
890.0
890.0
890.3
890.0
250. C
870.0
860.0
475.0
?50.0
440.0
440."
600.0
650.0
447.0
LIME/SPRAY DRYING
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
COMBUSTION ENGINEERING
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME/SPRAY DRYING
VENDOR NOT SELECTED
6/83
6/85
4/84
1/86
12/84
0/88
1/86
1/88
0/86
0/88
C/85
0/87
4/83
6/84
5/84
3/85
0/81
0/84
0/8S
1/89
O/ 0
0/82
134
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
COLUMBUS 8 SOUTHERN OHIO ELEC.
POSTON 5
COLUMBUS K SOUTHERN OHIO ELEC.
POSTON 6
DELMARVA POWER t LIGHT
VIENNA 9
EAST KENTUCKY POWER COOP
J. K. SMITH 1
EAST KENTUCKY POYE» COOP
J. K. SMITH 2
GENERAL PUBLIC UTILITIES
COHO 1
GENERAL PUBLIC UTILITIES
GILBERT 1
GENERAL PUBLIC UTILITIES
SCOTTSVILLE 1
GENERAL PUBLIC UTILITIES
SEWARO 7
GENERAL PUBLIC UTILITIES
WEHBUM 1
INDIANAPOLIS POWER g LIGHT
PATRIOT 1
INDIANAPOLIS POWER & LIGHT
PATRIOT 2
INDIANAPOLIS POWER & LIGHT
PATRIOT 3
LOUISVILLE GAS 8 ELECTRIC
TRIMBLE COUNTY 1
LOUISVILLE GAS t ELECTRIC
TRIMBLE COUNTY 2
NEVADA POWER
HARRY ALLEN 1
NEVADA POWER
HARRY ALLEN 2
NEVADA POWER
HARRY ALLEN 3
NEVADA POWER
HARRY ALLEN 4
NEVADA POWER
UARNER VALLEY 1
NEVADA POWER
UARNER VALLEY 2
PACIFIC GAS C ELECTRIC
MONTEZUMA 1
PACIFIC GAS t ELECTRIC
MONTEZUMA 2
POTOMAC ELECTRIC POWER
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPAC IT1
MM
375 .0
375.0
550. a
650.0
650.0
800.0
625.0
625.0
800. D
625.0
650.0
65D.O
65C.C
575.0
575. T
500. 0
500.0
500.0
500.0
25C. 0
250.0
800.0
800.0
800.0
PROCESS/
SYSTEM SUPPLIER
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
START-UP
DATE
8/86
C/89
6/87
1/85
1/87
12/St
"/9G
0/91
5/87
0/95
0/87
C/87
0/87
7/84
7/86
6/86
6/87
6/88
6/89
6/85
6/86
6/87
6/88
5/87
VENDOR NOT SELECTED
135
-------
EPA OTILITT F60 SURVEY: JANUARY - MARCH 1980
SECTION 12
SUMMARY OF PLANNED fGD SYSTEMS
COMPANY NAME/
UNIT NAME
NEW OR CAPACITY PROCESS/
UNJT NO. RETROFIT MW SISTEW SUPPLIER
START-UP
DATE
PUR AUTHORITY OF STATE OF NY
FOSSIL
SALT RIVER PROJECT
CORONADO 3
SOUTHERN ILLINOIS POWER COOP
MARION 5
TEXAS UTILITIES
MILL CREEK
TEXAS UTILITIES
MILL CREEK
NEW
NEW
NEW
NEW
NEW
700.0 PROCESS NOT SELECTED
VENDOR NOT SELECTED
ZS0.9 LIMESTONE
VENDOR NOT SELECTED
300.0 PROCESS NOT SELECTED
VENDOR NOT SELECTED
751.0 PROCESS NOT SELECTED
VENDOR NOT SELECTED
750.0 PROCESS NOT SELECTED
VENDOR NOT SELECTED
11/87
6/87
C/86
0/8S
0/86
136
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1960
SECTION 1J
TOTAL F6D UNITS AND CAPACITY INSTALLED
YEAR
1968
1969
1971
1972
1973
197*
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1995
UNDEFINED
NEW 01
NO.
1
0
4
8
8
3
6
8
11
13
20
20
11
22
5
11
12
9
13
6
3
1
1
1
12
* LINE
«W
140.
0.
702.
518.
1938.
606.
2018.
2786.
4684.
4736.
6356.
8040.
5038.
9331.
1772.
6995.
6766.
4946.
8290.
4390.
1*75.
t25.
625.
625.
2612.
TERMINATED
NO. NW
C 0.
1 140.
C 0.
C 0.
1 175.
3 340.
3 1637.
3 850.
1 47.
C 0.
1 23.
C 0.
C 0.
0 0.
0 0.
0 C.
0 0.
C 0.
C 0.
0 0.
0 0.
C 0.
C 0.
0 0.
TOTAL
NO.
1
0
4
12
19
19
22
27
37
50
69
89
100
122
127
138
150
15"
172
1T8
iei
182
183
184
ON LINE
«W
140.
0.
7C2.
122C.
29?3.
3250.
3631.
5567.
10204.
1494Q.
21273.
29313.
34351.
43682.
45454.
52449.
59215.
64161 .
72451.
76741.
78216.
78841.
79466.
80091.
137
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
C ITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY W/F60 - "W
NET UNIT GENERATING CAPACITY UO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MW
•* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - Z
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
RANGE MOISTURE CONTENT - X
AVERAGE SULFU" CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
•* ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FLUE GAS TEMPERATURE - C
•* PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
TYPE OF NOZZLES
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LIQUID RECl«CUL»TION RATE - LlTER/s
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PAOTICULATE INLET LOAD - G/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
- t
COMMONWEALTH EDISON
UILL COUNTY
1
ROMEOVlLLE
ILLINOIS
******
86.
774.
1U7.0
167.0
137.0
< .200
< 1.800 LB/MMPTU)
BABCOCK g UILCOX
CYCLONE
CYCLIC
0/55
3£3.36
179.4
107.
3.S
< 7700CO ACFM)
< 355 F)
< 350 FT1
< 12.4 FT)
< 9570 BTU/Lfi)
9.100 - 10.500
COAL
22260.
7.40
3-16
******
1.50
0.3 - 4.5
COLD SIDE
WESTERN PRECIPITATION
79.0
179.4 < 355 F)
VENTURI
BABCOCK R UILCOX
CARBON STEEL
PLASITE AND KAOCRETE
STAINLESS STEEL
181.7 < 3S5000 ACFM)
179.4 ( 355 F)
3(5.4 ( 5800 GPM)
?.* <1S.O GAL/1000ACF>
******* (»***• jN-H20)
36.6 ( 120.0 FT/S)
.4 ( .16 GR/SCF)
X 98.0
-——————---———-— --——-PERFORMANCE DATA——
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP
S02 PART. HOURS HOURS HOURS FACTOU
3/75
A
B
SYSTEM
94.0
.0
99.2
.0
81.2
.0
744 609
138
-------
EPA UTILITY fGO SURVEY: JANUARY - MARCH I960
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE OAT A.
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION T OfMOVAL P£" BOILER fGO OP.
SO? PART. HOURS HOURS HOURS FACTOR
*• PROBLEMS/SOLUTIONS/COMMENTS
A VENTURI HOSE LEAK FORCED MODULE A OUT ONCE.
MODULE B WAS OUT OF SERVICE TWICE FOR NO DEMAND AND ONCE AS A RESULT OF
ACCIDENTAL 50 MINUTE TRIP.
COAL BURNED THIS MONTH AVERAGED LESS THAN ONE PERCENT SULFUR.
4/75
A
B
SYSTE"
37.0
39.5
.0
35.0
.0
72C
6*5
*« PROBIEMS/SOLUTIONS/COMMENTS
CHICAGO FLU ASM IS TREATING MATERIAL FROM THE SCRUBPf WITH LIME AND
ASH AND DUMPING IT INTO THE HOLDING BASIN.
A BOILER OUTAGE FORCED MODULE A OUT OF SERVICE ONCE THIS MONTH (MODULE
WAS ALREADY OUT OF SERVICE).
FLY
COAL BURNED THIS MONTH WAS RECLAIM COAL AND VARIED IN SULFUR CONTENT.
5/75
A
e
SYSTEM
64.5
37.1
84.5
37.1
84.5
37.1
744
744
** PROBLEMS/SOLUTIONS/COMMENTS
NODULE P WAS IN SERVICE ON "AY 20 FOR THE FIRST TIME SINCE APRIL 13t 197J.
REC1RCULAT10N TANK MIXERS.
NODULE A (WHICH WAS THE ONLY ONE OPERATING) WAS FORCED OUT TWICE IN APRIL
TO AVOID POND OVERBOARDING INTO THE DES PLAINES RIVER. THE SECONO OUTAG?
LASTED UNTIL MAY 5. DURING THE PAST SEVERAL MONTHS Of GENERALLY CONTINUOUS
OPERATION OF MODULE ». IT HAS BECOME APPARENT THAT THE PRESENT LIQUID
CIRCULATING SYSTEM CANNOT BE OPERATED IN A CONTINUOUSLY CLOSED CYCLE. THE
WATER IMBALANCE POSES A HIGH RISK Of OVERBOARDING FROM THE SLUDGE POND
DURING LONG PERIODS OF SUSTAINED OPERATON. THE FOLLOWING REVISIONS HAVE
BEEN MADE TO REDUCE THE WATER IMBALANCE:
1. THE PUMP GLAND WATER FLOWS HAVE BEEN CUT FROM 10 GPM TO 5 GPM.
2. THE SCRUBBER HOUSE SERVICE WATER FILTER BACKWASH HAS BEEN ROUTED
OUT OF THE SYSTEM.
3. THE CONTINUOUS UNDERSPRAY HAS BEEN CHANGED TO AN INTERMITTENT
SPRAY 5 MINUTES ON, 5 MINUTES OFF.
THE THICKENER HAS BEEN DOWN SINCE APRIL 21 DUE TO A BROKEN GEAR AND A STUCK
SWEEP ARM. THE THICKENER HAS BEEN BYPASSED AND THE SLUDGE IS GOING TO THE
POND.
DURING MAY, MODULE A WAS OUT FOR 45 MINUTES DUE TO A DAMPER TRIP.
NODULE A WAS OUT ONCE FOR SPRAY NOZZLE CLEANING.
NODULE B WAS OUT TWICE AFTER START UP, ONCE FOR A VENTURI PUMP TRIP AND
ONCE FOR A RECIRCULATION TANK LEVEL TRIP.
CHICAGO FLY ASH IS TREATING THE MATERIAL FROM THE SCRUBBER WITH LIME AND
FLY ASH AND DUMPING IT INTO THE HOLDING BASIN. A MIXER HAS BEEN INSTALLED
AT THE THICKENER, WHICH ENABLES THEM TO SUBSTITUTE SEALED DUMP TRUCKS FOR
THE CEMENT TRUCKS WHICH WERE USED IN THE PAST FOR MIXING AND TRANSPORTING
THE WASTE MATERIAL TO THE HOLDING BASIN.
COAL BURNED THIS MONTH VARIED GREATLY IN SULFUR CONTENT, RANGING FROM LOW
SULFUR WESTERN COAL TO HIGH SULFUR ILLINOIS COAL.
6/75
A
B
SYSTEM
64.1
85.5
60.6
84.6
54.1
75.4
720 642
** PROBLEMS/SOLUTIONS/COMMENTS
A REHEATER PLUGGAGE INSPECTION FORCED ONE NODULE A OUTAGE.
A LOW LEVEL TRIP CAUSED A 35 MINUTE OUTAGE, AND NO DEMAND ACCOUNTED FOR TWO
MORE MODULE A OUTAGES.
NODULE B WAS OUT FOR 95 HOURS TO CLEAN THE BOOSTER FAN AND DEMISTER.
HIGH BOOSTER FAN VIBRATIONS CAUSED MODULE B> TO SHUT DOWN ON JUNE 30.
DURING THIS MONTH HIGH SULFUR COAL WAS BURNED IN A TwO WEEK TEST, AND LOW
SULFUR COAL WAS BURNED THE REST OF THE MONTH.
7/75 A
B
SYSTEM
.0
79.2
.0
79.4
.0
73.5
744
689
139
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
COMMONWEALTH EDISON: WILL COUNTY 1 6
140
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
......—....— —— —-——PERFORMANCE DATA-- ....... --
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION T REMOVAL PER BOILER f6D C«P.
S02 PART. HOURS HOURS HOURS FACTOR
B 8.8 20.4 8.5
SYSTEM 744 309
•* PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 WAS DOWN FROM OCTOBER 11 THROUGH MARCH 19 FOR ITS BOILER TURBINE
AND SCRUBBER OVERHAUL. THE MAJOR ITEMS TO BE ACCOMPLISHED DURING THE
OUTAGE WERE:
1. SIMPLIFICATION OF THE MILLING SYSTEM CONTROL.
2. PULLING AND CLEANING OF THE MODULE B REHEATER AND RETURNING IT
REPLACED WITH MARGINAL BUNDLES LEFT OVER FROM MODULE A.
3. CLEANING OF THE POND PUMP BAY.
4. REMOVAL OF THE VENTUHI AND ABSORBER PUMP CHECK VALVES tONE OF THEM
FAILED LAST SPRING AND DESTROYED A PUMP LINSR AND IMPELLER).
5. CLEANING AND REPAIR OF THE VENTURI NOZZLES AND SUPPORTS.
6. REPAIR OF CORRODED REHEATER SUPPORTS.
7. RESETTING AND ADJUSTMENT OF ALL DAMPERS.
8. REVISION OF SCRUBBER CONTROLS BY REMOVING THE CONTROLS NO LONGE"
USED OR NEEDED.
9. INSPECTION AND CLEANING OF THE ENTIRE SCRUBBER AND RELATED
EQUIPMENT.
NODULE A WAS PUT INTO THE GAS PATH ON MARCH 22 AND REMAINED AVAILABLE FOR
SERVICE THE REST OF THE MONTH.
NODULE B HAD TO REMAIN OUT OF SERVICE UNTIL MARCH 29 WHILE ITS REPAIRED
REHEATER WAS INSTALLED.
A/76 A 23.0 20.0 19.2
B 49.3 47.3
SYSTEM 720 691
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 RETURNED TO SERVICE APRIL 2 AFTER A SHORT TURBINE CONTROL OUTAGE.
BOTH MODULES CAME ON LINE JUST BEFORE THE BOILER.
A FIVE DAY OUTAGE OF MODULE B WAS DUE TO REHEATER TUBE BUNDLE LEAKS.
SEVERAL MODULE B OUTAGES WERE DUE TO PLUGGED ABSORBER TANK SCREENS CAUSED
BY MILL AND CLASSIFIER FAILURES WHICH ALLOWED ROCK TO GET INTO THE SYSTEM.
NODULE B WAS THOROUGHLY CLEANED.
ONLY ONE ABSORBER PUMP IS BEING USED IN MODULE B, SINCE THE 1B2 PUMP LINER
FAILED AS A RESULT OF A BROKEN DISCHARGE VALVE. A REPLACEMENT LINER IS
BEING INSTALLED.
A SCRUBBER TESTING AND EVALUATING PROGRAM WAS STARTED THIS MONTH. MUCH OF
THE LATTER TWO WEEKS OF THE MONTH WERE SPENT TRAINING THE TESTING PERSON- .
NEL. THE PROGRAM WILL PROVIDE CHEMISTRY DATA AND OPERATING CHARACTERISTICS
5/76 A .0 .0 .0
SYSTEM 744 665
** PROBLEMS/SOLUTIONS/COMMENTS
A VENTRUI HOSE LEAK FORCED MODULE B OFF ONCE THIS MONTH.
MODULE 6 WAS TAKEN OUT OF SERVICE ONCE BECAUSE OF A PLUGGED ABSORBER TANK
SCREEN.
NODULE 6 WAS OFF ONCE DUE TO A FOULED I.D. FAN.
NODULE B WAS OUT OF THE GAS PATH ONCE DUE TO NO DEMAND.
6/76 A 52.0 44.2 37.6
B 86.2 84.5 71.9
SYSTEM 720 612
** PROBLEMS/SOLUTIONS/COMMENTS
NODULE A SUFFERED VENTURI PUMP LINER FAILURES ON APRIL 78 WHEN AN INLET 16
INCH BUTTERFLY ISOLATION VALVE BROKE APART AND FELL INTO THE VENTURI PUPP.
BOTH THE A AND BACKUP AB VENTURI PUMP LINERS WERE DESTROYED. MODULE A
REMAINED OUT SERVICE UNITL JUNE 9, WHEN THE LINERS WERE REPLACED.
NODULE A WAS OFF ONCE FOR SHEARED BYPASS DAMPER PINS.
I.D. BOOSTER FAN FOULING FORCED MODULE A OFF ONCE THIS MONTH FOR ABOUT
164 HOURS.
BOTH MODULES WERE OFF TWICE DUE TO NO DEMAND. DURING THESE OUTAGES, THE
DEHISTERS WERE WASHED AND ABSORBER TRAY SCALE* IF ANY, WAS KNOCKED OFF.
NODULE B WAS OUT OF THE GAS PATH FOR SEVERAL SHORT VENTURI LOW FLOW TRIP
OUTAGES DUE TO A PLUGGED, SCALED VENTURI TANK SCREEN. AT THE END OF THE
MONTH, THE MODULE WAS TAKEN OUT TO CLEAN THE SCREEN.
141
-------
EPA UTILITY FGD SU»VEY: JANUARY - MARCH 1980
COMMONWEALTH EDISON: yiLL COUNTY 1 (CONT.)
-- ..... . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILlTY RELIABILITY UTILIZATION
x REMOVAL PER BOILER FGD c*p
S02 PART. HOURS HOURS HOURS FACTOR
THE MODULE B I.D. BOOSTER FAN REOUIRED CLEANING DURING THE MONTH.
THE REHEATER TUBES ARE SCALING, WHICH RESULTS IN A LOWER HEAT TRANSFER RATE
RATE, AND THEREFORE INCREASES I.D. BOOSTER FAN FOULING. THE ONLY WAY Tn
THE ONLY WAY TO
CLEAN THE REHEATERS EFFECTIVELY IS TO REMOVE THEM, WHICH DEMANDS A
TIAL OUTAGE.
7/76
A
B
SYSTEM
19.9
86.?
.0
90.0
.0
72.3
7*4
598
PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OFF THE FIRST PART OF THE MONTH DURING REPAIRS TO THE ABSORBrn
THE LATTER PART OF THE MONTH THE MODULE WAS READY FOR SERVICE BUT WAS
OPERATED BECAUSE OF THICKENER-POND SLUDGE OVERLOADING.
MODULE B HAS FORCED OFF ONCE TO BALANCE THB I.D. BOOSTER FAN. AND ONtF
WASH THE FAN.
MODULE B WAS OUT OF THE GAS PATH TWICE DUE TO NO DEMAND.
8/76
A
B
SYSTEM
98.2
65.4
57.6
61.4
3?.3
4P.9
744
495
PROBLEMS/SOLUTIONS/COMMENTS
HOOULE A WAS OUT OF THE GAS PATH THE FIRST HALF OF THE MONTH T AVOID
THICKENER-POND OVERLOADING.
DURING THE LATTER HALF OF THE MONTH, MODULE A WAS USED WITH THREE MIMflB
FORCED OUTAGES AND ONE FOUR DAY NO DEMAND OUTAGE.
NODULE B WAS OUT OF THE GAS PATH THREE TIMES DUE TO NO DEMAND.
LOSS OF CHEMICAL CONTROL CAUSED TWO MODULE A OUTAGES.
MODULE B WAS OFF FOR NINE DAYS DUE TO FOULING.
SPENT SLURRY VALVE REPAIRS FORCED A MODULE B OUTAGE.
ON AUGUST 12 THE OPERATING PH CONTROL SET POINT WAS REDUCED FROM 5 4 TO
5.1. IT is BELIEVED THAT THIS LOWER PH is THE CAUSE OF THE FOULING"OUTAI-«:
OF MODULE B ON AUGUST 21. MODULE A WAS ALSO OPERATED FOR THREE DAYS AMn
IT, TOO, EXPERIENCED INCREASED SACLE FOULING. THE PH SET POINT WAS THE*
INCREASED BACK TO 5.4.
9/76
A
B
SYSTEM
42.3
79.4
28.7
22.6
59.9
720 566
PROBLEMS/SOLUTIONS/COMMENTS
NODULE A WENT OFF ONCE DUE TO A LOW FLOW TRIP.
NODULE A WAS TAKEN OFF ONCE FOR CLEANING OF THE RECIRCULAT ION TANK AND
PUMPS, AND.INSPECTION OF PUMP ISOLATION VALVES.
A LINER LEAK IN 1A2 ABOSOHBER PUMP ALSO FORCED MODULE A OFF.
NODULE A WAS OUT OF TH GAS PATH TWICE DUE TO NO DEMAND.
NODULE A WAS TAKEN OFF ONCE TO AVOID THICKENER-POND OVERLOADING.
SPENT SLURRY VALVE TROUBLE CAUSED TWO MODULE B OUTAGES.
10/76
A
B
SYSTEM
27.9
76.4
28.9
56.2
37.9
54.8
744
726
*• PROBLEMS/SOLUTIONS/COMMENTS
HIGH SULFUR ILLINOIS COAL WAS BURNED IN THE BOILER FROM MARCH THROUGH
OCTOBER.
THE SCRUBBER HASTE MATERIAL HAS TREATED HITH LIME AND FLY ASH AND HAULER tn
AN OFF SITE DISPOSAL AREA. tv T°
NODULE A OPERATED ON ONE ABSORBER PUNP, ALLOWING TESTING ON A LOWER
ABSORBER FAN.
HOOULE A HAS OUT OF THE GAS PATH ONCE FOR AN I.D. BOeOOSTEH FAN TRIP.
WORK ON RECIRCULATION TANK LEVEL CONTROLS CAUSED A MODULE A OUTAGE.
NODULE B HAS FORCED OFF ONCE TO REPAIR A REHEATER HEADER LEAK.
ONE MODULE B OUTAGE HAS FOR VENTURI N027LE CLEANING.
NODULE B WENT OFF FOR A VENTURI LOU FLOW TRIP.
NODULE B REMAINED OUT OF SERVICE WHILE NODULE A HAS BEING TESTED TO AVOID
THICKENER-POND OVERLOADING.
A VACUUM FILTER WAS TIED IN AT THE THICKENER.
142
-------
EPA UTILITY fGO SURVEY: JANUARY - MURcH
COMMONWEALTH EDISON: WILL COUNTY 1 UONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERARILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD C«P.
$02 PART. HOURS HOURS HOURS FACTOR
11/76
A
B
SYSTEM
20.1 25.6
72.2 69.6
20.1
4.7
7?0 566
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A OPERATED ON ONE ABSORBER PUMP DURING MODULE B OUTAGE.
MODULE B WAS FORCED OUT OF THE GAS PATH ONCE FOR A MILLING SYSTEM FAILURE.
MODULE f ENCOUNTERED A VENTURI HEADER LEAK.
THE VENTURI NOZZLES REQUIRED CLEANING DURING THE MONTH.
REPLACEMENT Of THE SPENT SLURRY VALVE NECESSITATED A »OOULE OUTAGE.
MODULE f WAS OFF ONCE DUE TO A CHEMICAL SYSTEM UPSET.
MODULE B WAS OUT Of THE GAS PATH TWICE DUE TO NO DEMAND (MODULE A taAS NOT
IN SERVICE AT THE TIME OF THE OUTAGE).
12/76 A 44.0 4B.3 44.9
B 53.4 51.7 48.0
SYSTEM 744 692
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE LAST WEEK OF NOVEMBER, THE 1«2 ABSORBER PUMP HAS TAKEN OUT OF
SERVICE FOR OVERHAUL. THE REPAIRS WERE COMPLETED ON DECEMBER 6, yHEN THF
MODULE ASSUMED A ONE ABSORBER PU«P STANDBY CAPABILITY UNTIL THE 1A1 ABSOR-
BER PUMP CAN BE REPAIRED.
DURING THE LAST HALF OF THE MONTH, MOOUELE A OPERATED WHILE MODULE B WA<
BEING REPAIRED.
MODULE P PERFORMED SAT1SFACT10RILY DURING THE FIRST HALF OF THE MONTH,
EXPERIENCING ONLY ONE NO DEMAND OUTAGE. ON THE 17TH, HOWEVER, THE SPENT
SLURRY VALVE FAILED AND THE MODULE HAS REMAINED OUT or SERVICE.
1/77 A 98.? 98.7 95.8
8 13.5 1.1 1.1
SYSTEM 744 722
*• PROBLEMS/SOLUTIONS/COMMENTS
THE 1A1 ABSORBER PUMP KENT OUT IN LATE SEPTEMBER WITH BURNED OUT BEARINC-S
AND REMAINED OUT THROUGH JANUARY WAITING FOR PARTS.
LOU SULFUR COAL WAS BURNED IN THE BOILER FROM NOVEMBER THROUGH JANUARY.
DUE TO THE LOU VOLUME OF SLUDGE PRODUCED WHILE BURNING LOU SULFUR COAL,
MUCH OF THE SLUDGE HANDLING TIME WAS SPENT DIGGING OUT THE ACCUMULATED
SLUDGE IN THE REC IRCULAT ION PONDS. THIS MATERIAL, ALONG WITH SCRUBBER
WASTE MATERIAL, WAS TREATED WITH LIME AND FL1ASH AND HAULED TO AN OFF
SITE DISPOSAL AREA.
MODULE A WAS FORCED OUT ONCE BY A FAILED SPENT SLURRY VALVE.
PLUGGED DEMISTED UNDERSPRAYS CAUSED ANOTHER MODULE A OUTAGE.
MODULE A WENT OUT ONCE BECAUSE OF NO DEMAND AND ONCE DUE TO A BOILER OUTAGE
(MODULE B WAS ALREADY OUT OF SERVICE FOR REPAIRS).
MODULE B BECAME AVAILABLE FOR SERVICE ON JANUARY 27. AFTER REPAIRS TO THE
SPENT SLURRY VALVE WERE COMPLETED. DUE TO SEVERE HEATHER CONDITIONS! THf
MODULE WAS PLACED IN THE GAS PATH JANUARY 31.
2/77 A 38.8 42.6 38.8
B 72.0 45.7 41.7
SYSTEM 672 613
«* PROBLEMS/SOLUTIONS/COMMENTS
THERE WAS VERY LITTLE DIGGING IN THE RECIRCULATION PONDS. CHICAGO FLYASH
SPENT MOST OF THEIR TIME ON CLEANING AND MAINTENANCE.
,/77 A 96.9 6«.7 6«.2
B 80.9 75.5 73.9
SYSTEM 744 728
** PROBLEMS/SOLUTIONS/COMMENTS
AN ERT S02 ANALYZER WAS INSTALLED ON THE DISCHARGE SIDE OF MODULE B I.D.
BOOSTER FAN. THIS IS AN "IN SITU" ON-DISPERSIVE ANALYZER THAT CONTINUALLY
MEASURES AND READS OUT CONCENTRATIONS OF S02, CO, C02, AND NO.
AN ABSORBER SUCTION HEADER LEAK FORCED MODULE 6 FROM THE 6AS PATH.
MODULE FJ UAS FORCED OUT DUE TO A SLURRY VALVE GASKET LEAK.
143
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.I
.. . . ... ...—-PERFORMANCE DATA-- —
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
* REMOVAL PER BOILER FGD CAP
SO? PART. HOURS HOURS HOURS FACTOR
A PLUGGED FEED SLURRY RECIRCULAT1ON LINE WAS ENCOUNTERED IN MODULE B
HIGH SULFUR COAL WAS BURNED FOR SEVEN DAYS THIS MONTH TO PROVIDE HIGH
SULFUR SLUDGE FOR THE UOP SLUDGE TEST.
CHICAGO FLYASH SPENT 75* OF THEIS TINE DIGGING IN THE POND. THE REST U*S
SPENT ON THE THICKENER AND VACUUM FILTER IPERATION. THE SCRUBBER WASTE
MATERIAL WAS TREATED WITH LIME FLYASH AND HAULED OFF SITE.
DISPOSAL AREA.
4/77 A
B
SYSTEM
86. 1
45.5
67.7
3P.2
61.?
27.3
720 65C
** PROBLEMS/SOLUTIONS/COMMENTS
THE PERFORMANCE OF THF ERT SG2 ANALYZER TO DATE HAS BEEN, AT BEST UNREII.
BLE AND INCONSISTENT. THE EOT TECHNICIANS ARE OUT TO SERVICE THE ANALYZES
ALMOST EVERY OTHER DAY. THE PROPLEM, ACCORDING TO ERT TECHNICIANS, is or •
"THERMAL NATURE". WHEN THE ANALYZES REACHES A CERTAIN TEMPERATURE A CMTD
SHORTS OUT. THEY HAVE NOT BEEN ABLE TO LOCATE THE FAULTY INTEGRATED
YET.
A BOILER TUBE LEAK REPAIR FORCED MODULE A OUT OF THE GAS PATH ONCE THIS
MONTH (MODULE 6 WAS ALREADY DOWN FOR REPAIRS).
MODULE B WAS FORCED OUT OF THE GAS PATH TWICE FOR AN ABSORBER SUCTION
HEADER LEAK REPAIR.
MODULE P WAS OUT OF SERVICE ONCE TO WASH THE I. D. BOOSTER FAN.
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME DIGGING IN THE SMALL POND
GETTING PEADY FOR THE MGO ADDITION AND FORCED OXIDATION TEST. THE SC
WASTE MATERIAL WAS TREATED WITH LIME AND FLYASH AND HAULED TO AN OFF
DISPOSAL AREA.
5/77 A
B
SYSTEM
89.*
98.0
2.2
5C.9
2.0
47.3
744 691
*• PROBLEMS/SOLUTIONS/COMMENTS
THE ERT S02 ANALYZER HAS BEEN REMOVED FROM SERVICE DUE TO A POOR PERFORM
ANCE RECORD OVER THE LAST THREE MONTHS. EOT IS IN THE PROCESS OF RE-
ENGINEERING THEIR ANALYZER.
THE MGO ADDITION TEST WENT WELL. ALTHOUGH THE MGO INCREASED S02 RENOVA1
EFFICIENCY ABOUT 10X, IT DID PRACTICALLY NOTHING FOR THE TWO MORE SERIOnc
PROBLEMS, SINCE THICKENER AND SLUDGE PRODUCTION AND LIMESTONE CONSUMDTT«^
HATE WERE ABOUT THE SAME. «™»«ncTION
NODULE A WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH WHEN THE INLET
VALVE ON 1A? ABSORBER PUMP FAILED.
MODULE B WAS TAKEN OFF TO CLEAN AND INSPECT THE REHEATER TUBES.
BOTH MODULES HERE FORCED OFF FOR THE FIRST FIFTEEN DAYS OF THE MONTH Due T
A FAILED 120V CONTROL TRANSFORMER FOR THE POND RETURN PUMPS. THE TRANSFORM
ER HAD TO BE ORDERED FROM WESTINGHOUSE.
HIGH SULFUR COAL HAS BURNED FOR ELEVEN DAYS DURING THE MONTH.
6/77
A
B
SYSTEM
31. f
93.2
13.3
93.*
10.5
73.5
720 566
•* PROBLEMS/SOLUTIONS/COMMENTS
THE 1»1 ABSORBER PUMP IS STILL OUT OF SERVICE WAITING FOR PARTS 1AJ
ABSORBER PUMP'S ISOLATION VALVES FORCED MODULE A OFF FOR MOST OF T(E MONTH
NODULE A HAD ONE NO DEMAND AND ONE BOILER OUTAGE THIS MONTH. '
NODULE B UAS ALSO FORCED OFF TO CLEAN THE I.D. BOOSTER FAN.
NO HIGH SULFUR COAL WAS BURNED THIS MONTH.
7/77
B
SYSTEM
70.3
41.4
21.0
744
377
•* PROBLEMS/SOLUTIONS/COMMENTS
HIGH SULFUR COAL HAS BURNED FOR EIGHT CAYS THIS MONTH. LIMESTONE OPERATION
WAS NORMAL FOR HIGH SULFUR OPERATION.
NODULE B HAS FORCED OUT OF THE GAS PATH ONCE TO REMOVE A PLUGGED DIFFUSED
THE FINAL TEST, FORCED OXIDATION SEEMDD TO BE THE MOST SUCCESSFUL OF ALL
USING LIQUID OXYGEN, UP TO 12,000 CFM OF GASEOUS 02 UAS FED INTO EACH *
VENTUftI DOUNCOMEff, OXIDATION OF SULFITE TO SULFATE WAS INCREASED FROM
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 19»C
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA--
PERIOD NODULE AVAILABILITY OPERAE1LIT1 RELIABILITY UTIL17AT10N
Tt REMOVAL PEP BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
35 TO 90 X
NODULE B WAS ALSO FORCEO OFF DUE TO A LOW LEVEL IN THE SLURRY STORAGE
NODULE B WAS ALSO FORCEO OfF DUE TO REHEAT6R TUBE BUNDLE LEAKS.
TANK.
9/77
A
B
SYSTEM
99.8
9.7
99.6
12.0
8C.8
9.7
PROBLEMS/SOLUTIONS/COMMENTS
NODULE » WAS AVAILABLE THE ENTIRE MONTH WITH JUST THE VENTURI PUMP OPERAT-
ING.
9/77
A
B
SYSTEM
61.0
52.3
77.8
75.4
54.0
5?.3
720 499
«• PROBLEMS/SOLUTIONS/CONNENTS
MODULE B ENCOUNTERED HIGH VIBERATIONS IN ITS BOOSTER FAN DURING THE FIRST
WEEK Of THE MONTH. AFTER THE FAN WAS BALANCED, THE MODULE OPERATED INT1L
THE UNIT OUTAGE ON SEPTEMBER 21.
13/77 A .0
B .0
SYSTEM
11/77 A .0
B 8.8
STSTEM
50.1
.
.0
.0
744
720 126
PROBLEMS /SOLUTIONS/COMMENTS
UNIT ONE CAME UP ON NOVEMBER 25 AFTER A SIXTY-THREE DAY OUTAGE.
MODULE B IS IN THE GAS PATH FATED EXPERIENCING SOME OIFICULTT IN BALANCING
ITS BOOSTER FAN.
12/77
A
B
STSTEM
42.5
84.1
42.5
84.1
47.8
94.6
42.5
84.1
744
661
PROBLEMS/SOLUTIONS/COMMENTS
PLUGGAGE WAS ENCOUNTERED IN TH EMOOULE e REHEATEK. PECAUSE NO SPARE REHRAT
COILS WERE AVAILABLE, THE UTILITY TRIED TAKING SOME COILS fROM MODULE A
MODULE B APPEARED TO BE MORE ORE SEVERELY PLUGGED THAN ORIGINALLY THOUGHT.
MODULE » UAS DOWN HALF THE MONTH BECAUSE 01 A MAIN STEAM LEAK WHICH COULD
NOT BE ISOLATED.
MODULE A OPERATED UNTIL SEPTEMBER 19, WH E A COMBINATION OF MUD AND SCALE
BUILD-UP ON THE SUMP FLOOR STRUCTURALLY DAMAGED THE MODULE. REPAIRS PUT
THE MODULE OUT OF SERVICE UNTIL HID DECEMBER.
1/78
A
B
STSTEM
69.0
22.0
89.9
29.6
66.3
22.0
744
549
** PROBLEMS/SOLUTIONS/COMMENTS
ON JANU1RT 7, THE MODULE B I.D. BOOSTER FAN DISCHARGE DUCT STARTED VIBRAT-
ING WILDLY. THIS FORCED THE BOILER OFF WHILE THE SHOP MADE REPAIRS TO THE
DUCTWORK AND BALANCED THE FAN WITH AN I.fl.D. MACHINE.
WHEN THE UTILITY ATTEMPTED TO POT MODULE B BACK IN THE GAS PATH. A LEAK IN
THE SLURRY LINE FORCED IT BACK OFF.
A PLUGGED VENTURI POMP FORCED MODULE B OFF THE REST OF THE MONTH.
DURING THE OUTAGE, THE REHEATER COILS HERE CLEANED WITH A HIGH PRESSURE
(5000 LB) SPRAYER.
NODULE A UAS FORCED OFF WHEN A STEAM REGULATING VALVE BLEU ITS PACKING.
ON THE 23RD, BOTH MODULES WERE TAKEN OFF AND DRAINED TO ALLOW THE SHOP TO
INSTALL NEW ISOLATION VALVES IN THE ABSORBER AND VENTURI PUMPS.
TOWARD THE END OF THE MONTH, SOME PROBLEMS WERE ENCOUNTERED WITH THE POND
RETORN PUMPS FREEZING.
2/78 A
B
STSTEM
40.9
69.5
56.5
92.9
34.4
56.5
672 409
145
-------
EP« UTILITY FGD SU»VEY: JANUARY - MARCH 198C
COMMONWEALTH EDISON: WILL COUNT* 1 .
MODULE B OPERATED VERY WELL AND AN INSPECTION SHOWED THE MODULE TO BE VERY
CLEAN.
3/78 A 93.5 100.0 90.6
B 88.5 84.7 76.0 26.2
SYSTEM 744 230
** PROBLEMS/SOLUTIONS/COMMENTS
THIS MONTH, DUE TO COAL CONSERVATION, UNIT 1 WAS ON THE SYSTEM VERY LITTIt
MODULE B HAD DIFFICULTY FOR SEVERAL DAYS BECAUSE OF A CRACKED SHEAVE ON TM
VENTURI PUMP. E
HIGH PRESSURE CLEANING ON BOTH MODULES DURING THE COAL CONSERVATION ALONG
WITH REMOVING THE VENTURI THROAT RESTRICTOH BLOCKS PROVED BENEFICIAL IN
MAINTAINING BETTER CONTROL OF THE DRAFT CONDITIONS IN THE SCRUBBER.
4/78 A 99.9 99.7 92.0
B 100.0 99.9 92.2
SYSTEM 720 665
** PROBLEMS/SOLUTIONS/COMMENTS
THE PRESSURE DIFFERENTIAL ACROSS THE VENTURIS HAS BEEN REDUCED BY APPRO*!
MATELY 40X AT 140 MW BY REMOVING THE VENTURI RESTRICTOR BLOCKS. PARTICULAR
REMOVAL AND SOLIDS CARRYOVER COULD BE ADVERSELY AFFECTED BY THIS ACTION
SINCE PARTICULATE REMOVAL AT THE VENTURI IS A FUNCTION OF WATER DROPLET*
SIZE, WHICH IN TURN IS A FUNCTION OF PRESSURE DROP. INCREASED SOLIDS CAPRv
OVER COULD POSSIBLY COMPUNO REHEATER PLUGGING PROBLEMS. THE UTILITY IS
KEEPING A CLOSE MATCH FOR PLUGGING, BUT HAS NOT YET FOUND ANYTHING UNUSim
MODULE A WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH FOR A VENTURI PTcc
LEAK. 4PE
5/78 A 9.5 99.4 55.2
B 89.? 100.0 56.1
SYSTEM 744 413
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE LAST PART OF THE MONTH BOTH MODULES WERE FORCED OUT OF THE GAS
PATH DUE TO REHEATER LEAKS. IT REQUIRED A TWO DAY OUTAGE TO REMOVE THE
LEAKING REHEATER BUNDLES. ADDITIONAL REHATERS ARE ON ORDER AND ARE EXPECT
ED TO ARRIVE IN JUNE.
6/78 A 87.1 94.5 25.7
B 85.6 100.0 25.1
SYSTEM 720 181
** PROBLEMS/SOLUTIONS/COMMENTS
DURING A SCRUBBER INSPECTION. 25X DIEMISTER AND 75X ABSORBER SPRAY PLUGGAGF
WAS DISCOVERED IN MODULE A. MODULE B WAS NOT AS BAD.
HIGH VIBRATION WAS ENCOUNTERED IN THE TURBINE BEARINGS DURING BOILER STABT
UP, CAUSING THE BOILER TO SHUT BACK DOWN.
THE PUG MILL FOR CHICAGO ADMIXTURES HAS BEEN APPROVED, AND THE NEW SLUDGE
TREATMENT SYSTEM SHOULD BE OPERATING BY FALL.
THE SCRUBBER WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH WHEN THE 161
ABSORBER DISCHARGE VALVE FAILED TO OPEN.
THE BOILER WAS FORCED OFF THE LAST FOUR DAYS OF THE MONTH FOR CYCLONE
LEAKS. DURING THIS OUTAGE. THE A AND B MODULE SPENT SLURRY VALVES
WERE REPLACED.
7/78 A 97.0 100.0 11.6
B 99.? 100.0 11.6
SYSTEM 744 77
146
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH
COMMONWEALTH EDISON; WILL COUNTY 1
-------
EP» UT1LJTH FGO SURVEY: JANUARY -MARCH 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
. -—-----PERFORMANCE DATA — ... _
PERIOD MODULE AVAILABILITY OPERABILITY RELIAB1L1TT UTILISATION * REMOVAL PER BOILER F6D "cAp~~
502 PART. HOURS HOURS HOURS FACTOR
e
SYSTEM
85.2
100.0
48.3
720 348
*• PROBLEMS/SOLUTIONS/COMM6NT5
THE UNIT HAS DOWN THREE TIMES THIS MONTH DUE TO A VENTURI PUMP AND
BOOSTER FAN OUTAGES.
12/78 A
e
65.3
64.5
100.0
100.0
64.5
64.5
744 4*0
PROBLEMS/SOLUTIONS/COMMENTS
REHEATER TUBE LEAKS CAUSED TwO OUTAGES.
THE MODULE B SPENT SLURRY DRAIN WAS REPAIRED,
1/79
A
B
SYSTEM
83.5
62.2
100.0
87.1
61.3
5!.4
744
456
PROBLEMS/SOLUTIONS/COMMENTS
THE S02 PLANT WAS FORCED OFF TWICE THIS MONTH DUE TO REHEATER TUBE
TWO TUBES ON MODULE A AND FOUR TUBES ON MODULE B WERE REPLACED.
THE I.D. BOOSTER FAN ON MODULE B WAS FOULED AND HAD TO BE REPLACED
TWO SPECIAL SECTIONS Of VENTURI PIPING, A SIXTEEN TO EIGHT INCH ECCEKTBir
REDUCER AND AN OFFSET TEE WERE PREPARED BY LOCKPORT FABRICATING AND INST.
LEO THIS MONTH. THE ORIGINAL REDUCER AND TBE HAD BEEN PATCHED AND WELDED 5
MANY TIMES THAT THEY WERE BEYOND REPAIR.
2/79
A
B
SYSTEM
93.0
93.0
91.3
91.3
54.2
54.2
672 399
•* PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT WAS FORCED OFF ONCE FOR A MAIN STEAM HEADER LEAK.
J/79
A
B
SYSTEM
100.0
68.6
100.0
100.0
46.0
46.0
744 343
PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS FORCED OUT TWICE IN FEBRUARY AND FOUR TIMES IN MARCH DUE
TO A VENTURI HEADER LEAK. A TEN FOOT SECTION OF PIPE WILL HAVE TO BE
REPLACED DUE TO EXTENSIVE CORROSION.
THE SYSTEM WAS DOWN ONCE FOR A SPRAY HEADER LEAK.
NODULE B EXPERIENCED A LEAK IN THE VENTURI DOWNCOMER. A FIVE FOOT SECTin
OF THE PIPE HILL HAVE TO BE REPLACED. 1ON
4/79 A
SYSTEM
5/79
A
e
SYSTEM
720
744
*• PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 WAS OUT OF SERVICE THE ENTIRE MONTH DUE TO A BOILER OVERHAUL
CHICAGO ADMIXTURES WILL STOCKPILE THE FIXED SLUDGE ON STATION PROPERTY
6/79 SYSTEM
7/79 SYSTEM
8/79 SYSTEM
720
744
744
0
c
PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 WAS OUT OF SERVICE TO REPLACE THE AIR HEATER TUBES, TUBE SHEET ANh
HOPPERS. DURING THIS OUTAGE. THE WORN VENTURI SPRAY NOZZLES AND DEMISTEBC
WERE REPLACED. WELDING LEAKS AND GENERAL CLEANING OF THE S02 INTERNALS
WAS ALSO DONE AT THIS TIME.
148
-------
EPA UTILITY F60 SURVEY: JANUARY - MARCH 196C
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
„„__„......—. . -PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPtRABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
THE BOILER AND THE SCRUBBER ARE SCHEDULED TO RETURN TO SERVICE OCTOBER 1.
1979.
9/79 SYSTEM
10/79 SYSTEM
11/79 A
B
SYSTEM
53.3
53.3
53.3
100.0
100.0
100.0
85. *
85.4
720
744
720
0
c
336
PROBLEMS/SOLUTIONS/COMMENTS
ON NOVEMBER 5, UNIT 1 RETURNED TO SERVICE AFTER A SIX MONTH OUTAGE TO
REPLACE THE AIR HEATER TUBES, TUBE SHEET AND HOPPERS.
DURING THE OUTAGE, SEVERAL LENGTHS OF VENTURI PIPING HAD TO BE REPLACED
UITH NEW RUBBER LINED PIPE.
THE UNIT DID NOT FORCE THE BOILER OFF AT AMY TIME DURING NOVEMBER.
12/79 A 77.0 99.5
B 84.9 100.0
SYSTEM 77.0 99.5
57.5
57.8
57.5
744 431
428
PROBLEMS/SOLUTIONS/COMMENTS
ON DECEMBER 4, UNIT 1 CAME OFF LINE SO THAT THE AIR HEATER HOPPERS AND
PRECIPITATOR HOPPERS COULD BE EMPTIED Of CARBON CARRY-OVER AND DEBRIS.
DURING THIS OUTAGE THE SHOP REPAIRED A LEAK IN THE POND RETURN LINE.
ON DECEMBER 10, THE A MODULE DEVELOPED A SE.R10US STEAM LEAK <25,000 MAKE-
UP) IN A LOWER REHEAT BUNDLE. THE LEAKING BUNDLE HAD TO BE REMOVED AND
REPLACED. THIS RESULTED IN A TWO DAY FORCED OUTAGE. LATTER IN THE MONTH
THE A MODULE BLEU ANOTHER REHEATER TUBE FORCING THE BOILER OFF FOR AN
ADDITIONAL 25 HOURS AND 12 MINUTES.
THE A NODULE WAS REMOVED FROM THE GAS PATH ON DECEMBER 29, FOR THREE HOURS
TO ALLOW THE MAINTENANCE SHOP TO WELD A LEAKING REHEATER FLANGE.
THE S02 PLANT FORCED THE BOILER OFF TWICE THIS MONTH. TOTAL FORCED OUTAGE
TIME ATTRIBUTED TO THE SCRUBBER WAS 54 HOURS AND 39 MINUTES.
1/80
A
B
SYSTEM
91.0
88.6
88.6
87.5
84.1
84.1
63.0
60.6
60.6
744 536
451
«« PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST SIX DAYS OF JANUARY, UNIT 1 BOILER WAS OFF THE SYSTEM BECAUSE
OF A SLAG SCREEN TUBE LEAK. THE UNIT RETURNED TO SERVICE ON JANUARY 7.
ON JANUARY 16, THE UTILITY HAD TO DERATE UNIT 1 TO 50 HW BECAUSE THE RE-
HEATER SECTIONS ON A AND B MODULES WERE PLUGGING. ON JANUARY 17, THE
MODULES WERE TAKEN OUT OF THE GAS PATH TO BEGIN REMOVING AND CLEANING THE
REHEATER SECTIONS WITH A HIGH PRESSURE (4CQO PSI> WATER SPRAY. UNIT 1
BOILER WAS LEFT ON TO PROVIDE STABILITY FOR THE 138 KV SYSTEM.
IN THE PAST, ALL FORTY-TWO BUNDLES CONSISTING OF SEVEN TUBES PER BUNDLE,
HAD TO BE TAKEN OUTSIDE TO BE CLEANED ON A CONCRETE SLAB. IN THIS CASE
SINCE TIME WAS THE MOST IMPORTANT FACTOR, A, DIFFERENT APPROACH WAS USED.
ONLY THE MIDDLE SIX BUNDLES ON EACH MODULE WAS REMOVED. THIS PROVIDED A
LARGE ENOUGH SPACE SO THAT A LANCE WITH AN EXTENSION ON IT COULD BE USED
TO CLEAN THE BOTTOM OF THE TWO TOP BUNDLES AND THE TOP OF THE TWO BOTTO"
BUNDLES. THERE ARE DOORS THAT ALLOW EASY ACCESS TO THE TOP AND BOTTOM
OF THE REHEATER. USING THIS METHOD, ONLY TWELVE OF THE FORTY-TWO BUNDLES
WERE REMOVED. IN THE PAST, THIS JOB HAS TAKEN AS LONG AS TWO WEEKS TO
COMPLETE. USING THE NEW METHOD, ALL THE REHEATER BUNDLES WERE CLEANED IN
TWENTY HOURS.
THE B NODULE WAS FORCED OFF LINE ON TWO OTHER OCCASIONS IN JANUARY. BOTH
THESE OUTAGES WERE CAUSED BY THE REHEATER
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA .._...
PERIOD MODULE AVAILABILITY OPERABlLlTY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAR
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLENS/SOLUT10NS/COMMENTS
NO INFORMATION FOR THE WILL COUNTY UNIT WAS AVAILABLE FOR FEBRUARY AND
MARCH.
150
-------
EPA UTILITY fGO SURVEY: JANUARY - MARCH 1980
SECTION U
DESIGN AND PERFORMANCE DMA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG>J
NET PLANT GENERATING CAPACITY - Mg
GROSS UNIT GENERATING CAPACITY - M«
NET UNIT GENERATING CAPACITY W/FGD - Mw
NET UNIT GENERATING CAPACITY WO/fGD - MU
EQUIVALENT SCRUBBED CAPACITY - MW
• * BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
*« FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J^G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 1
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
• • ESP
** MECHANICAL COLLECTOR
** PARTICULATE SCRUBBER
NUMBER
TYPE
DETROIT FDISON
ST. CLA1P
6
BELLE RIVER
MICHIGAN
C
******
1376.
1775.0
ZcD.O
(****** LP/KMPTU)
< 3.ZOO LP/WMBTU)
COMBUSTION ENGINEERING
BASE
0/61
465.77
132.3
******
*******
COAL
SUBblTUMINOUS
4.00
« 98700C
( 270 F)
<•*** FT)
(***** FT)
(****«* BTU/LB)
0,500 - 9,600
Zl - H.
.35
0.3 - C.4
VENTURI
______.... -----PERFORMANCE DATA --
PERIOD MODULE AVAILABILITY OPERABlLITt RELIABILITY UTILIZATION X REMOVAL
SO?
PER BOILER FGD CAP.
PART. HOURS HOURS HOURS FACTOR
SYSTEM
tz/74 SYSTEM
1/75 SYSTEM
730
744
744
2/75
3/75
4/75
*« PROBLEMS/SOLUTIONS/COMMENTS
INSTALLATION OF THE FGD SYSTEM WAS ESSENTIALLY COMPLETED BY THE NOVEMBER,
1974 THROUGH JANUARY 1975 PERIOD.
A FAULTY INSTRUMENT PANEL WHICH HAS INCORRECTLY WIRED HAS BEEN RETURNED TO
THE MANUFACTURER FOR REPAIR.
TO DATE, THE UTILITY HAS WATER TESTED ALL THE AUXILIARY EQUIPMENT. THE 10
FAN HAS BEEN TESTED AND AIR BALANCE HAS BEEN CHECKED.
SYSTEM 6?2
SYSTEM 744
SYSTEM 7?0
151
-------
EP» UTILITY FGO SURVEY: JANUARY - MARCH 1980
DETROIT EDISON: ST. CLAIR 6 (CONT.)
.... ...... ... .. PERFORMANCE DATA .....
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION * REMOVAL PER BOILER F6D CAP
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
A COLD FLUE GAS RUN WAS SUCCESSFULLY CONDUCTED MARCH 22 AND 23. DURING
THIS PERIOD THE RUBBER-LINED PUMPS WERE REPAIRED AND THE LIMESTONE PREAR*-
TION SYSTEM yAS CALIBRATED.
5/75 SYSTEM 744
5/75 SYSTEM 720
7/75 SYSTEM 744
*• PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST HOT FLUE GAS RUN WAS CONDUCTED ON JUNE 22, 1975. THE RUN LASTED
FOR A PERIOD OF 22 HOURS. DURING THIS RUN, THE SCRUBBER WAS PURPOSELY
TRIPPED OFF AT LOADS OF 40 AND 80 PERCENT. THIS WAS PERFORMED TO OBSERVE
IF ANY DETRIMENTAL EFFECTS TO THE STEAM GENERATION OPERATIONS RESULTED.
NONE WERE DETECTED. THE SYSTEM WAS TAKEN OUT OF SERVICE FOLLOWING THIS
GAS RUN TO CORRECT THE FOLLOWING MAJOR OPERATION AREAS:
GAS CIRCUIT: LUGI THROAT POSITIONAL FAILURE; DETERIORATION OF THE
DAMPER SEALS; SEVERE VIBRATIONS; S02 ANALYZERS INOPERATIVE.
LIQUID CIRCUIT: FAILURE OF PH CONTROL SYSTEM; TARGET FLOW METER
TARGETS H»VE BEEN BROKEN OFF; PUMP SEAL WATER LOW FLOW ALARM TRIPS.
8/75 SYSTEM 744
9/75 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
A SECOND HOT FLUE GAS RUN WAS INITIATED ON AUGUST 6 AND LASTED 27 HOURS
THE RUN WAS TERMINATED BECAUSE OF A REHEATER THERMOCOUPLE FAILURE. A *
SUBSEQUENT INSPECTION OF THE SCRUBBING SYSTEM REVEALED NO APPARENT
ABNORMALITIES OR MALFUNCTIONS.
A THIRD HOT FLUE GAS RUN OF 41 HOURS DURATION WAS COMPLETED OCTOBER 9 Tut
MAIN OBJECTIVE Of THIS RUN WAS TO EVALUATE VARIOUS COMPONENTS OF THE FBFtu
WATER SPRAY SYSTEM AND EFFECTS ON SYSTEM OPERATION. THE TEST RUN WAS
PREMATURELY TERMINATED BECAUSE OF A BOILER FEED PUHP MALFUNCTION, RESULTl*r
IN A REDUCED BOILER LOAD CAUSING SUBSEQUENT WEEPING OF THE WASH TRAY.
ID/75 SYSTEM 744
11/75 SYSTEM 720
12/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
A FOURTH FLUE GAS RUN OF 23 DAYS DURATION WAS TERMINATED DUE TO EXCESSIVE
VIBRATION IN THE I.D. t BOOSTER FAN. ONE OTHER SCRUBBER-RELATED OUTAGE
OCCURRED WHEN THE PACKING OF ONE OF THE SCRUBBER RECIRCULATION PUMPS NEFDFh
MAINTENANCE. S02 REMOVAL DURING THIS PERIOD WAS 90 PERCENT AND PARTICULAR
OUTLET LOADING WAS 0.1 LB/1900 LBS OF FLUE GAS FOR 1-3 PERCENT SULFUR COAL.
1/76 SYSTEM 744
2/76 SYSTEM 696
3/76 SYSTEM 744
*/76 SYSTEM 100.0 100.0 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE 30-DAY VENDOR QUALIFICATION RUN AND FINAL ACCEPTANCE TEST WERE
COMPLETED BY MAY 29. THE QUALIFICATION RUN WAS CONDUCTED ON A "HANDS OFF-
BASIS USING PLANT PERSONNEL EXCLUSIVELY. THE SYSTEM WAS IN SERVICE 100
PERCENT OF THE TIME THE BOILER WAS OPERATIONAL. THE FINAL ACCEPTANCE TEST
CONSISTED OF SIX 4-HR. TEST RUNS CONDUCTED IN THE SPACE OF ONE WEEK. THE
S02 REMOVAL EFFICIENCY FOR HIGH SULFUR COAL WAS 90.9 PERCENT. PARTICULAR
REMOVAL ALSO EXCEEDED DESIGN LEVELS. NO MAJOR CHEMICAL OR MECHANICAL-
RELATED PROBLEMS WERE ENCOUNTERED.
5/76 SYSTEM 744
152
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 198?
DETROIT EDISON: ST. CLA1H 6 (CONT.)
____ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILllATION * REMOVAL PEP BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
6/76 SYSTEM 720
7/76 SYSTEM 744
B/76 SYSTEM 7*4
*• PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY IS NOW PREPARING TO CONDUCT A 2 MONTH MINIMUM INTERNAL SCRUBBER
DEMONSTRATION PROGRAM TO ACQUIRE OPERATING DATA AND INFORMATION. FOLLOWING
THE COMPLETION OF THIS PROGRAM THE BOILERS WILL FIRE LOW SULFUR DECKER
COAL (0.1 TO 4.0 PERCENT) TO MEET S02 EMISSION REGULATIONS. THE SCRUBBERS
WILL CONTINUE TO OPERATE IN THE PARTICULATE REMOVAL NODE.
9/76 SYSTEM 720
•10/76 SYSTEM 7*4
• • PROBLEMS/SOLUTIONS/COMMENTS
THE INTERNAL 502 SCRUBBING DEMONSTRATION PROGRAM COMMENCED ON OCTOBER 14.
THE SCRUBBERS OPERATES CONTINUOUSLY FOR 10 DAYS.
OPERATION ON THE DEMONSTRATION PROGRAM WAS INTERRUPTED BY A FORCED SCRUBBER
OUTAGE RESULTING FROM SCALE AND SOLIDS CARRYOVER FROM THE WASH TRAY AND
MIST ELIMINATOR TO THE SCRUBBER 1.0. BOOSTER FAN ASSEMBLY. CAUSING VIBRA-
TION AND BALANCE PROBLEMS. IT WAS DECIDED TO SANDBLAST THE fAN TO REMOVE
SOLIDS BUILDUP ON THE FAN ASSEMBLY.
THE UTILITY PLANS TO MODIFY THE COMPONENT'S HASH SYSTEM FOR GREATER FLOW
CAPABILITY AFTER COMPLETION OF THE SO? SCRUBBING PROGRAM. DECO ALSO PLANS
TO CONTINUE PARTICULATE SCRUBBING FOLLOWING THE TERMINATION OF THE S02
PROGRAM 6V UNCOUPLING THE SPRAY TOWERS AND MAINTAINING THE PEABODY-LUR6I
VENTURI SCRUBBERS IN THE FLUE GAS STREAM. SOME LIMESTONE NAY HAVE TO BE
ADDED TO THE PARTICULATE SCRUBBING SOLUTION IN ORDER TO PREVENT LOW PH
SWINGS AND MINIMIZE THE POSSIBILITY OF ACID CORROSION DAMAGE TO THE
INTERNAL COMPONENTS.
11/7« STSTEM 80.0 720
*• PROBLEMS/SOLUTIONS/COMMENTS
FOLLOWING THE COMPLETION OF SAND BLASTING OPERATIONS TO SCRUBBER'S I.D.
BOOSTER FAN FOR REMOVAL OF SOLIDS BUILD UP, OPERATIONS RESUMED ON NOVEMBER
7 AND CONTINUED THROUGHOUT THE MONTH. THE SYSTEM'S AVAILABILITY INDEX FOR
THE MONTH WAS 80 PERCENT. THE MAJORITY OF THE OUTAGE TIME WAS CONSUMED
PROCURING SAND BLASTING SERVICES. THE OPERATION ITSELF REQUIRED ONLY 8
HOURS.
12/76 SYSTEM 51.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
THE S02 DEMONSTRATION PROGRAM CONTINUED THROUGHOUT DECEMBER. THE SYSTEM'SS
AVAILABILITY INDEX FOR THE PERIOD WAS 51 PERCENT.
SCRUBBER OUTAGES RESULTED FROM LIMESTONE FEEDER PROBLEMS.
SCRUBBER OUTAGES RESULTED FROM DENSE SLURRY TRAVERSE PUMP PROBLEMS.
SCRUBBER OUTAGES RESULTED FROM DENSE SLURRY TANK AGITATOR MALFUNCTIONS.
PH SAMPLING LINE PLUGGING RESULTED IN SOME OUTAGE TIME.
1/77 STSTEM .0 744
SYSTEM .0 672
** PROBLEMS/SOLUTIONS/COMMENTS
THE S02 DEMONSTRATION PROGRAM WAS OFFICIALLY TERMINATED ON DEC. 31, 1976.
THE SCRUBBER PLANT WAS SHUT DOWN AT THIS POINT AND FLUE GAS WAS BY-PASSED
AROUND THE SYSTEM.
SYSTEM .0 744
153
-------
EPA UTILITY FGD SU»VEY: JANUARY - MARCH 1980
DETROIT EDISON: ST. CLAIR 6 (CONT.)
PERFORMANCE DATA—--•
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINS IN SERVICE, FIRING LOW SULFUR (0.3*) WESTERN COAL.
CURRENT PLANS CALL FOR THE SCRUBBER PLANT TO REMAIN OUT OF SERVICE UNTIL
MID-JUNE FOR DESIGN AND OPERATING MODIFICATIONS. RESUMPTION OF SCRUBBER
OPERATIONS WILL OCCUR IN THE PRIMARY PARTICULATE-REMQVAL MODE. THE
PEABODY-LURGI VENTUR1 SCRUBBERS AND SPRAY TOWER ABSORBERS WILL REMAIN IN
THE GAS STREAM. SOLUTION WILL BE CIRCULATED THROUGH THE VENTURI'S WASH
TRAYS, AND MIST ELIMINATORS. NO SOLUTION KILL BE CIRCULATED THROUGH TH?
SPRAY ZONE OF THE ABSORBER TOWERS. LIMESTONE REAGENT WILL BE ADDED TO THE
SCRUBBING SOLUTION IN ORDER TO PREVENT LOW PH SWINGS AND SUBSEQUENT
MATERIALS DAMAGE TO THE SCRUBBER'S INTERNALS. SO? REMOVAL SHOULD RESIDE
IN THE 35 TO 5CX RANGE IN THIS MODE OF OPERATION BECAUSE OF THE SOLUTION'S
ALKALINITY DUE TO THE FLY ASH AND LIMESTONE. ALSO DECO PLANS TO MAINTAIN
A HIGHER L/G RATIO IN THE SCRUBBER MODULES. THIS MODE OF OPERATION IS
PROJECTED TO CONTINUE FOR A ONE TO THREE YEAR PERIOD FOLLOWING THE
MID-JUNE RESTART.
4/77 SYSTEM
5/77 SYSTEM
6/77 SYSTEM
7/77 SYSTEM
8/77 SYSTEM
9/77 SYSTEM
ID/77 SYSTEM
.0
.0
.0
.0
.0
.0
7?0
744
720
744
744
720
744
** PROBLEMS/SOLUTIONS/COHMENTS
THE UNIT WAS PULLED OFF LINE IN DECEMBER 1976 AND DID NOT RESTART UNTIL
OCTOBER 1977. WHILE THE UNIT HAS DOWN THE UTILITY INSTALLED BUILDINGS
AROUND PUMPS THAT WERE EXPOSED TO SEVERE WEATHER CONDITIONS.
11/77 SYSTEM
12/77 SYSTEM
1/78 SYSTEM
2/78 SYSTEM 96.0
J/78 SYSTEM 85.6
4/78 SYSTEM 90.0
5/78 SYSTEM 74.6
720
744
744
672
744
720
744
PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT EXPERIENCED SPRAY HEADER PROBLEMS IN THE ABSORBER TOWER. SOME
BROKEN N022LES WERE DISCOVERED.
THERE WERE SOME I.D. BOOSTER FAN PROBLEMS. THE UTILITY MUST SAND BLAST THS
FAN EVERY 4 TO 5 WEEKS WHEN THE MAGNITUDE OF VIBRATION OF THE FAN BECOMES
EXCESSIVE FROM SCALE FORMATION; HOWEVER, IN THIS INSTANCE THE PROBLEM WAS
A RESULT OF A LOW FAN OIL LEVEL.
THE UTILITY NOW OPERATES 3 RECYCLE TANK AGITATORS. PREVIOUSLY ONLY 2 WFRP
OPERATED. IT WAS FELT THAT PART OF THE TANK PLUGGING WAS A RESULT OF
INSUFFICIENT AGITATION.
THE SLURRY SPRAY SURGE TANK ENCOUNTERED CONTINUAL OVERFLOW PROBLEMS WHEN
THE ABSORBER SUMP PUMP WAS OPERATING. THIS HAS BELIEVED TO BE A RESULT or
A BROKEN SECTION IN THE SPRAY NOZZLE LINES. SPRAT WAS BEING DIRECTED
UPWARD TO THE BOTTOM OF A TRAY INSTEAD OF DOWN, COUNTERCURRENT TO THE
6AS FLOW AS INTENDED.
REHEATER PROBLEMS OCCURRED WITH THE FORMATION OF OIL CLINKERS IN THE
BURNER AREA. IT WAS DISCOVERED THAT THE AIR SUPPLY TO THE BURNER WAS
INSUFFICIENT.
154
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH
DETROIT EDISON: ST. CLAIR 6 (CONT.)
PERFORMANCE CATA
PERIOD MODULE »V»UAB111TY OPERAB1L1TY RELIABILITY UT1LI7ATION
T REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
SOME SPRAY HEADER PROBLEMS WERE ENCOUNTERED. THE FRP PIPING WAS RUPTURING.
IT WAS SUSPECTED THAT THE RUPTURES HERE A RESULT OF "HATER HAMMER" I.E.
THE SURGE THAT OCCURRS IN THE PIPE WITH A SUDDEN FLOW R»TE CHANGE.
THE SPRAY HEADERS WERE PLUGGING. WHEN THE HEADERS ARE DRAINED (E.G.
SYSTEMS SHUTDOWN) SOME SLURRY SETTLES IN THE HEADER LINES ETC. RINSE LINES
ARE NOW BEING INSTALLED TO FLUSH OUT HEADERS DURING FUTURE SHUTDOWNS.
S/7« SYSTEM
87.
7?0
«• PROBLEMS/SOLUTIONS/COMMENTS
ONE OF THE BLADES CAME LOOSE FROM AN I.0. BOOSTER FAN AND PASSED THROUGH
THE HOUSING. REPAIRS WERE MADE WITHOUT SERIOUS COMPLICATIONS.
7/78 SYSTEM
96.C
744
** PROBIEMS/SOLUMOHS/COMMENTS
THE INSTALLATION Of RINSE LINES MAS NOT YET BEEN COMPLETED.
PROBLEMS WITH RUPTURED SPRAY HEADER PIPING CONTINUED. IT HAS BEEN POSSIBLE
TO OPERATE THE SCRUBBER WITH THE RUPTURED LINES WITHOUT SERIOUS
CONSEQUENCES. IT IS NOT CRUCIAL THAT REPAIRS BE MADE IMMEDIATELY.
744
72C
744
720
744
744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THIS PERIOD RECYCLE TANK AGITATORS HERE BREAKING LOOSE AND SIMILAR
PROBLEMS WERE ENCOUNTERED WITH THE SLURRY STORAGE TANK AGITATORS. THE
SCRUBBING SYSTEM WAS REMOVED FROM SERVICE FROM SEPTEMBER THROUGH JANUARY.
STEADY BEARINGS HERE INSTALLED AT THE BOTTOM OF THE RECYCLE TANK SOLVING
THE RECYCLE TANK AGITATOR PROBLEM. THE SLURRY STORAGE TANK SYSTEM ALREADY
HAD STEADY BEARINGS. THESE WERE REWORKED TO IMPROVE OPERATIONS.
B/78
9/78
10/78
11/78
12/78
1/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
90.4
69.0
.0
.0
.0
2/79
3/79
SYSTEM
SYSTEM
PROBLEMS/SOLUTIONS/COMMENTS
SOME REHEATER PROBLEMS OCCURRED.
4/79 SYSTEM
5/79 SYSTEM
6/79 SYSTEM
7/79 SYSTEM
8/79 SYSTEM
9/79 SYSTEM
tO/79 SYSTEM
672
744
720
744
720
744
744
720
744
PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM IS CURRENTLY DOWN BUT IS EXPECTED TO BE BACK ON LINE SOON. THE
SCRUBBING SYSTEM HAS OPERATED ONLY 1 WEEK SINCE MAY 18, 1979 BECAUSE OF
SUMP PROBLEMS.
THE AGITATOR BEARING SYSTEM WAS POORLY DESIGNED. THE BEARING SYSTE!J MAS
NOW BEEN COMPLETELY REDESIGNED. THE AGITATORS HAVE NOW OPERATED 2000 HOURS
ON THE NEW BEARINGS. THE UTILITY WILL PROBABLY DRAIN THE TANK AFTER ABOUT
500 MORE HOURS TO INSPECT AND READJUST THE BEARINGS. THE NEW BEARING
155
-------
EPA UTILITY FGD SURVEY; JANUARY - MARCH T980
DETROIT EDISONr ST. CLAIR 6
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NU«BER
CITY
STATE
RE6ULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MU
*ET UNIT GENERATING CAPACITY W/FGC - MH
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
MINNESOTA POWER
CLAY BOSUELL
3
COHASSET
MINNESOTA
E
25?.
1720.
J5C.O
364.0
347.1
350.0
359.0
K LIGHT
( .600 LB/MMBTU)
( 4.000 LB/MMBTU)
«» BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 1
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
»* MECHANICAL COLLECTOR
NUMBER
*• PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
TYPE OF NOZ7LES
BOILER LOAD/SCRUBBER - X
fLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - c
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD - NG/J
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
COMBUSTION ENGINEERING
PULVERI7ED COAL
BASE
5/73
613.47
123.3
213.
7.9
COAL
SUBBITUMINOUS
19538.
9.00
4.81-16.0
26.00
24.C-28.C1
.92
0.5-1.5
.01
0.0-0.07
0
NONE
(1300000 ACFM>
( 254 F)
( 700 FT)
( 26.0 FT)
( 8400 BTU/LEO
7JOO-9900
- X
SPRAY IMPINGEMENT TOUER
KREBS ENGINEERS
1
316LC SS
NONE
316L SS
SPRAY NOZZLES WITH CERAMIC INSERTS
110.0
(130QOOO ACfM)
( ?S4 F)
(11340 6PM)
8.3 6AL/1000ACM
(*«•** IN-H20)
8.0 FT/S)
3.00 GR/SCF)
.078 LB/MMBTU)
613.5
123.3
714.4
1.1
•****«*
2.4
6.9
34.
98.7
800.000
.0
157
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
MINNESOTA POWER R LIGHT: CLAY BOSWELL 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION X REMOVAL P£R BOILE" FGD CAP
SO? PART. HOURS HOURS HOURS FACTOR
13/79 SYSTEM 744
11/79 SYSTEM 72G
12/79 SYSTEM 74*
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOP THE FOURTH QUARTER 1979.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
•• PBOBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER 1980.
158
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SECTION H
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAHE
JN1T NUMBER
CITV
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - N6/J
$02 EMISSION LIMITATION - NGVJ
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGO - Mw
^ET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
.* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE tlATE
MAXIMUM BOILER FLUE GAS (LOU - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
.* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVEDAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - T
RANGE CHLORIDE CONTENT - X
.* FABRIC FILTER
NUMBER
TYPE
MINNESOTA POWER * LIGHT
SYL LASKIN
( .600 LB/MMPTU)
( 4.000 LB/MWPTU)
AURORA
MINNESOTA
E
25B.
1721.
116.0
62.0
57.3
58.0
5«.0
COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
0/53
141.57 ( 3CQOOO ACFM)
171.1 < 340 F)
91. < 300 FT)
3.2 < 10.5 FT)
COAL
SUBB1TUMINOUS
23469.
9.00
4.81-16.r
26.70
24.C-28.0
1.00
.5-1.5
.01
0.00-0.07
0
NONE
( 8800 BTU/LP)
7509-9923
«* ESP
NUMBER
TYPE
.* MECHANICAL COLLECTOR
NUMBER
TYPE
.. PART1CULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
TYPE OF N027LES
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
fLUE GAS TEMPERATURE - C
LIQUID RECIPCULAT10N RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD - NG/J
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
- X
0
NONE
0
NONE
SPRAY IMPINGEMENT TOWER
KREBS ENGINEERS
1
316 ELC SS
NONE
316 ELC SS
SPRAY NOI2LES WITH CERAMIC INSERTS
100.0
1 37.4 < 291160 ACFM)
171.1 < 34C F)
151.2 < 2400 GPIO
1.1 C 8.3 6AL/1COHACF)
(•**»* IN-H30)
2.1
4.7
34.
97.8
SCO.000
SCO.000
.3
( 7.0 FT/S)
< 2.06 GR/SCF)
( .078 LB/MMPTU)
159
-------
EPA UTILITY F6D SURVEY: JANUARY - MARCH 198D
MINNESOTA POWER g LIGHT: SYL LASKIN 1 ICONT.)
.. .—.__ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION * REMOVAL P£R BOILER FGD "~CAP
SO? PART. HOURS HOURS HOURS FACTOR
13/79 SYSTEM 744
11/79 SYSTEM 7?0
12/79 STSTEM 744
*• PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FOURTH QUARTER 1979.
1/80 SYSTEM 744
2/80 SYSTEM 696
J/80 SYSTEM 744
• * PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURINr TL,
1ST OUARTER 1980. ™E
160
-------
EPA UTILITY FGD SURVEY: JANUARY - MA&CH 19b?
SECTION U
PES1GN AND PERFORMANCE DAT* fOR OPERATIONAL PARTICLE SCRUBBERS
NAM?
PLANT NAME
NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
$02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACIT1 - Hv
&POSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/F&D - My
~FT UNIT GENERATING CAPACITY yO/FGD - MW
EQUIVALENT SCRUPBFD CAPACITY - MU
*• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SE"V1CE DATE
MAXIMUM SORE" FLUE GAS FLOW - Cu.M/S
FLUE GAS TEMPERATURE - c
STACK HEIGHT - M
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - »
RANGE M01STUR' CONTENT - *
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - *
RANGE CHLORIDE CONTENT - X
,. FABRIC FILTER
NUMBER
TYPE
MINNESOTA POWER * LIGHT
SYL LASKIN
2
AURORA
MINNESOTA
E
25?. < .600 LB/MMBTU)
172?. ( 4.00C L8/MMPTU)
1U.O
t?.0
57.3
5 ° • ^
5»!5
COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
0/55
141.57 < 3COOCP ACFM)
171.1 < 34C F)
91. ( 300 FT)
?.2 < 10.5 FT)
COAL
SUBblTUMINOUS
JD469.
9.00
4.81-16.0
2i.70
24.0-i8.C
1.00
.5-1.5
.01
C.GC-0.07
0
NONE
FTU/L">
7509-9923
ESP
NUMBER
TYPE
MECHANICAL COLLECTOR
NUM9ER
TYPE
PARTICULATE SC9UBBER
NUMBER
TYPf
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
TYPE OF N027LFS
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
FLUf GAS T^P'RATURE - C
LlUUID RECIRCULATION HATE -LITER/S
L/G RATIO - LITER/CU.^
PRESSURE CROP - KPA
SUPERFICIAL G'S VELOCITY - «/S
p»RTICULAT£ INLET LOAD - G/CU.M
PART1CULATE OUTLET LOAD - NG/J
PHRTICUIATE DESIGN REMOVAL EFFICIENCY
502 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
502 DESIGN REMOVAL EFFICIENCY - X
- X
0
NONE
0
NONE
SPRAY IMPINGEMENT TOWER
KREES ENGINEERS
1
316 ELC SS
NOSE
316 ELC SS
SPRAY NOZZLES WITH CERAMIC INSERTS
1CO.O
1 37.4 ( 291160 ACfM)
171.1 < 340 F)
151.2 < 2400 GPM)
1.1 ( 8.3 GAL/10COACF)
•**•*•* ««*«•* IN-H20)
7.C FT/S)
?.06 GR/SCF)
.078 LB/MME>TU)
4.7
34.
97.8
SCO.000
5 CO.000
.0
161
-------
EPA UTILITY FGP SURVEY: JANUARY - MARCH 1980
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 196?
SECTION H
DESIGN AND PERFORMANCE DAT* fOR OPERATIONAL PARTICLE
SCRUBBERS
COMPANY NAME
PLAMT NAME
JN1T NUMBER
CITY
STATE
REGULATOR! CLASSIFICATION
pARTICULATE E«ISSION LIMITATION - NG/J
SOi EMISSION LIMITATION - NG/J
WET PLANT GENERATING CAPACITY - Mb
GROSS UNIT GENERATING CAPACITY - My
SET UNIT GENERATING CAPACITY y/FGO - * *
MET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCBUPBEO CAPACITY - My
** BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM 30UE = FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP 0!A«ETEP - N
.. FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE MFAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/Lfc
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 1
RANGE MOISTURE CONTENT - X
AVE"AGE SULFU" CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - T
RANGE CHLORIDE CONTENT - x
.* MECHANICAL COLLECTOR
NUMBER
TYPE
SUPPLlER
PARTICIPATE CFSIGN RE10VAL EFFICIENCY - t
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICULATE OUTLET LOAD - C/CU.I"
,. pARTICULATE SCRUBBER
TYPE
SUPPLIER
NUMBER OF STAfiES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
NUMBER OF NOZZLES
BOILER LOAD/SCRUBBER - X
fLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LIGUID RECI"CULATION RATE - LITEH/S
L/G RATIO - LlTER/CU.1*
PRESSURE DftOP - Kt>A
PARTICULATE I«JLET LOAD - G/CU.M
pARTICULATt OUTLET LOAD - G/CU.M
SOi INLFT CONCENTRATION - NG/J
MONTANA-DAKOTA UTILITIES CO.
LEWIS & CLARK
1
SIDNEY
MON TANA
< .ZCC LE./MMBTU)
< 1.000 Lt/MMPTU)
£6.
43".
5?. 3
51.5
CO*!faUSTICN ENGINEERING
PULVERIZED COAL
EAS E
10/5?
153.37 ( 325CCC
215.6 ( 4?C F)
76. • 25u FT)
4.4 ( 14.5 FT)
COAL
LIGNITE
15 '.03.
7. SO
34. 25-38.16
.61
. 32-1.43
< 645C FTU/LP)
t200-6
1
MULTICLONE
WESTERN PRECIPITATION
£5.7
1C6.2 ( ?25CC^ ACFf)
176.7 ( ?5C F)
**«*•** (**•»» ]K-H?0)
?.93 < 1.26 GC/SCF)
VESTURI
RESEARCH COTTRFLL
1
CAftbON STEEL
CEILCOTE FLAKELINE 1C3
CARBON STEEL WITH 1" NORTON CA-3'fc
14".0
215.6
212.6
1.7
327.2
.1
? S 1 3 4 .
( 31373T ACFM)
( 42C F)
< 3374 GPf)
03.0 GAL/1CCCACF)
(..«.. IK-H2C)
(143 .CC GF/SCF)
( .0?C tfi/SCF)
<......
163
-------
EPA UTILITY FGD SU"VEY: JANUARY - MARCH 198C
10NTANA-OAKOTA UTILITIES CO.: LEWIS 8 CLARK 1 (CONT.)
.... .. .. — PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPE»ABIL1T» RELIAP1LITY UTILIZATION * REMOVAL PE» B01LE' FGD C*P.
SO? PART. HOURS HOURS HOURS FACTCS
li/79 StSTEM 7?C
•• PROBLEMS/SOLUTIONS/COMMENTS
DURING A SCHEDULED BOILER OUTAGE GENEBAL SC"UBPER MAINTENANCE „«S
PERfORMED.
11/79 SYSTEM 7 ? C
•• PROBltMS/SOLUTIONS/COMPENTS
DURING NOVEMBER THE SCRUBBER HAS T EI»POI< AR I L Y BYPASSED TO ALLOW FOB R E P A I (, S
NECESSITATED PY A LEAK IN THE FLOODED DISC SCRUBBER.
U/7P SYSTEM 74*
•• PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SC"UBBER PROPLEHS OCCURRED DURING DECEMBER.
1/6? SYSTEM 7tl>
?/bO SYSTEM 6"6
J/80 SYSTEM 744
•• PROBLEMS/SOLUTIONS/CONMENTS
DURING THE JANUARY THROUGH MARCH PERIOD THE SCRUBBER WAS AVAILABLE MORE
THAN 95T OF THE TIM?.
THE EROSION PROPLEM MENTIONED DURING NOVEMBER CONTINUED. SECTIONS OF THE
LINED CAREON ST'EL COLUMN WILL SUPPORTING THE FLOODED DISC uE»E HUPTURIIVG
FILLING THE INNER CHAMBER blTH SLURRY AND ULTIMATELY RENDERING THE DISC '
MOVEMENT MECHANIST INOPERATIVE. THE UTILITY HAS MANAGED TO KEEP THE
SCRUbBER OPERATING AS A STOP-GAP MEASURE BETWEEN UNIT SHUTDOWNS BY INSERT-
ING A GARDEN HOSE IN THE COLUMN HOLES AND CONTINUALLY FLUSHING THE INNEC
CHAMBER. THE UTILITY HAS H»D SOME SUCCESS IN OTHER EROSION AREAS BY
MAKING REPAIRS WITH A HASTELLOY MATERIAL. PLANS ARE BEING !"ADE TO JACKET
THE ENTIRE DISC SUPPORT COLUMN WITH HASTELLOY G.
164
-------
EPA UTILITY fGC SURVEY: JANUARY - MARCH
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
NAME
PLANT NAME
NUMBER
STATE
•CtULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
CQ2 EMISSION LIMITATION - NG/J
PLANT GENERATING CAPACITY - MW
UNIT GENERATING CAPACITY - MM
UNIT GENERATING CAPACITY W/FGD - MW
UNIT GENERATING CAPACITY WO/FGD - MW
"oUlVALENT SCRUBBED CAPACITY - MW
BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
fLUE GAS TE"PE«ATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE MEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORID? CONTENT - X
PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L1TER/CU.M
PRESSURE DROP - KPA
PARTICULATE INLET LOAD - G/tU.M
PARTICULATE OUTLET LOAD - G/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
S02 BESIGN REMOVAL EFFICIENCY - X
PACIFIC POWER s LIGHT
DAVE JOHNSTON
4
GLENROCK
WYOMING
- X
90.
.210 LE/MMPTU)
.5CC LB/MMBTU)
330.0
326. 5
33r.O
37.0
COMBUSTION ENGINEERING
PULVERIZED COAL
»* / »«
707.85
1 J2.2
76.
COAL
SUBblTUMINOUS
17252.
13.00
******
16.00
******
.50
nsooooc ACFM)
i 270 »>
( 250 FT)
(***** FT)
< 74,30 BTU/LB)
5,000-9,COO
.04
VENTURI
CHEMCO
CARBON STEEL, 3/?" AT VENTURI THROAT
POLYESTER-LINED STEEL
33.3
327.5 < 694COP ACFM)
135.0 « 275 F)
409.5 ( 6500 GPM)
1.7 (13.0 6AL/1000ACF)
******* (***** IN-H20)
< *.TC GR/SCF)
( .040 Gfi/SCF)
9.Z
.1
99.7
SCO.000
40.0
___ - ----------------------------------- PERFORMANCE DATA
MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
so? PART. HOURS HOURS HOURS FACTOR
SYSTEM
,,/79 SYSTEM
12/7C SYSTEM
744
744
165
-------
EP» UTILITY FGD SURVEY: JANUARY - MARCH 19SO
PACIFIC POME" R LIGHT: DAVE JOHNSTON 4 (CONT.)
p£B fORWANCF DATA
PERIOD MOOULf AVAILABILITY OPERAPUITY RFLlAPUlTir UTILIZATION 1 REMOVAL Pt» BOH.ER Ftt> C»P?~
SO? PART. HOURS HOURS HOURS FACTOR
•• PROBLfel"S/SOLUTION S/COMMENTS
NO INFORMATION WAS AVAILABLE FOB THE FOUBTH (JUABTfR 1079.
1/63 SYSTE" 744
Z/8n SYSTE" 696
5/8? SYSTEM 744
•• PROBlf'SfSOLUTIONS/COMWENTS
NO INFORMATION WAS AVAILABLE FOR TH£ FIRST OOARTER T980.
166
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 19fc
SECTION 14
DESIGN AND PERFORMANCE DAT* FOR OPERATIONAL PARTICLE SCRUBPE»S
COMPANY NAME POTOMAC ELEC™U POWER
PLANT NAME DICKERSON
jialT «,U"BER 1
rjTY DICKERSON
cTATE MARYLAND
RetUL»TORY C L» SS I F I C AT I ON *««**.
PARTICULATE EMISSION LIMITATION - NG/J ...... (...... LP/KM?TU)
EMISSION LIMITATION - NG/J *«..*• («*••*• LP/MMPTU)
PLANT GENERATING CAPACITY - Mw 1345.0
SS UNIT GENERATING CAPACITY - MW 191. 0
VCT UNIT GENERATING CAPACITY w/fGo - *W 1?3.C
NCT UNIT GENERATING CAPACITY yO/FGO - MW .......
£OUIV*LENT SC&UP.BFD CAPACITY - MU .......
.. POILFR DATA
SUPPLIER ......
Typc PULVERIZED COAL
SERVICE LOAD ......
CO^'ERCIAL ?E»VICF DATE «./«.
«»»1MU"I B01LE" FLUE GAS FLOW - CU.M/S ........ (**..*.. ACFM)
FLUE GAS TE»P'RATUNE - C ....... <*«*• F)
STACK HEIGHT - M ...... (..*. FT)
STACK TOP DIA"ETEB - N ....... (*..«. ft)
.. FUEL DATA
FUEL TYPE COAL
FUEL GRADE ......
AVERAGE HEAT CONTENT - J/G 272K.. < 117CC E-TU
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198C
SECTION U
DESIGN AND PERFORMANCE OAT* FOR OPERATIONAL PAPTICLE SCRUBPEBS
COMPANY NAME POTOMAC ELECTRIC PO^E"
PLANT NAME DICKERSON
JNIT NUMBER 2
CITY DUKERSON
STATE MARYLAND
REGULATORY CLASSIFICATION .*«.••
PART1CULATE EMISSION LIMITATION - NG/J •*«..* (•*.**. LB/MMPTU)
SOi EMISSION LIMITATION - NG/J »..*«» <«..... LB/MMPTU)
NET PLANT GENERATING CAPACITY - MW 134?.Q
GROSS UNIT GENERATING CAPACITY - My 19?.0
NET UNIT GENERATING CAPACITY y/FGD ~ My 133.0
NET UNIT GENERATING CAPACITY WO/FGD - «W ••*•••*
EQUIVALENT SCRUPBFD CAPACITY - My .......
•* ROILFR DATA
SUPPLIER *»».»*
TYPE PULVERIZED COAL
SERVICE LOAD ......
COMMERCIAL SERVICE BATE **/**
MAXIMUM BORE" FLUE GAS FLOW - CU.M/S ..***..* («*..... «CFM>
FLUE GAS TEMPERATURE - c ....... <**** n
STACK HEIGHT - M ...... (.... fT)
STACK TOP 01A«ETER - M ....... (*..*. FT)
•• FUEL DATA
FUEL TYPE COAL
FUEL GRAOF ......
AVERAGE HEAT CONTENT - J/G ?72U. ( 11 7&0 PTU/LP)
RANGE HEAT CONTENT - 9TU/LB ......
AVERAGE ASH CONTENT - 2 14.00
MANGE ASH CONTENT - I ......
AVERAGE MOISTURE CONTENT - * ........
RANGE MOISTURE CONTENT - » ......
AVERAGE SULFUR CONTENT - X ?.00
RANGE SULFUR CONTENT - X ......
AVERAGE CHLORIDE CONTENT - * ........
RANGE CHLORIDE CONTENT - * ......
•• PARTICULATE SCRUBBER
TYPE VENTURI
NUMBER OF STAGES 2
.. .— . . PERFORMANCE DATA __
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD c«p
SO? PART. HOURS HOURS HOURS FACTC
ID/79 SYSTEM
11/79 SYSTEM
12/70 SYSTEM
3/69
100.0
96.A
icr.o
97.0
88.9
10T.O
744
730
744
722
664
744
722
64?
744
•• PROBLEMS/SOLUTIONS/COMMENTS
A OWE 0«Y OUTAGE OCCURREDt DUE TO A FAN LIMNG PROBLEM. NO OTH?R
UNIT PROBLEMS hE»E ENCOUNTERED DURING THE PERIOD.
1/80 SYSTEM
95.4
96.4
95.4
744
736
71C
*» PROBLEMS/SOLUTIONS/COMMENTS
IN JANUARY THF SCRUP6ER yAS DOWN FOR J HOURS TO RfP«I» A SLURRY RECYCLE
LINE LEAK.
31 HOURS OF THE OUTAGE TIME IN JANUARY UAS NECESSARY TO REPAIR A RECYCLE
SYSTEM
SYSTEM
PUMP.
100.0
96.9
100.0
96.9
100.0
96.9
696
744
696
744
6V6
168
-------
EPA UTILITY fGO SURVEY: JANUARY - MARCH 19B?
ELECTRIC POWER: D1CKERSON 2
•PERFORMANCE DATA-
t>foiot> MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER reo C«P.
S02 PART. HOURS HOURS HOURS FACTOR
.* PROBLEHS/SOLUTIONS/COMWENTS
IN MARCH THE SCRUBBER WAS DOWN FOR A SCRUBBED LINING WARRANTY INSPECTION.
NO REPAIR WORK WAS NECESSARY.
169
-------
EPA UTILITY FGD SUPVEY: JANUARY - MARCH 198C
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBPERS
COMPANY NAME
PLANT NAKE
UNIT NUMBER
CITY
S TATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SO? EMISSION LIMITATION - NG/J
SET PLANT GENERATING CAPACITY - My
GROSS UNIT GENERATING CAPACITY - Mw
MET UNIT GENERATING CAPACITY y/FGD - *H
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MM
POTO«AC ELECTRIC POyEC
DICKERSON
3
MARYLAND
******
668.
548.0
19?.0
1S3.Q
<****««
< 1.6CC LB/MMBTU)
** BOILER DATA
SUPPLJ ES
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILED FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPFRATURE - C
STACK HEIGHT - M
STACK TOP OIA^E TER - M
ENGINEE»ING
PULVERIZED COAL
BASE
0/62
27P.42 ( 5POOCC ACFM)
126.1 ( 259 F)
12?. < 400 FT)
....... <***.. fT)
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HFAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 5!
RANGE MOISTURE CONTENT - *
AVERAGE SULFU" CONTENT - X
RANGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - 2
RANGE CHLORIDE CONTENT - *
COAL
******
27214.
14.00
******
******
2.0C
* * * * * *
< 117CC BTU/LB)
******
ESP
NUMBER
SUPPLIER
PARTICULATE DESIGN REMOVAL EfflCJFNCr
PARTICULAR SCRUBBER
NUMBER
TYPE
SUPPLIER
BOILER LOAD/SCRUBBER - t
FLUE GAS CAPACITY - CU.1/S
FLUE GAS TE^PFBATURE - c
l/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
RESEARCH COTTRELL
VENTURI
CHEMICO
50.C
139.2
126.1
2.7
( 2957CO ACFM)
< 259 F)
-------
EPA UTILITY fGO SURVEY: JANUARY - MARCH 1<58C
POTOMAC ELECTRIC POWER: D1CKERSON 3
-------
EPA UTILITY F&D SURVEY: JANUARY - MARCH 19gC
POTOMAC ELECTRIC POWER: D1CKERSON 3 (CONT.)
PEOFORMAM C? DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILI7ATION
r REMOVAL
so? PART.
PER
HOURS
bOlLER
HOURS
FGD
HOURS
csp.
FACTOR
9/75 SYSTEM
13/75
11/75
12/75
1/76
2/76
3/76
4/76
5/76
6/76
7/76
3/76
9/76
11/76
12/7t
1 m
im
3/77
4/77
5/77
6/77
7/7'
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTE"
SYSTE"
•* PROBLEMS /SOLUTIONS/COMMENTS
THE f&O SYSTEM CONSISTS OF A SINGLE, TwO-STAGF S CRUPbFR / AbS o* R E t , WHICH
INCORPORATES AN AD JUST ABLE -THROAT VENTu"! SCRUBBER FOP PARTICULATE REfOVjL
AND A SECOND STAGE ABSORBER WITH A FIXED VENTURI TO REMOVE $02. THE LICijOR
STREAMS FOR BOTH STAGES ARE SEPARATE AND OPERATE IN A CLOSED-LOOP MO&c.
UNTIL NID-1975 THE MAGNESIUM SULflTE GENERATED UAS TRANSFERRED TO AN £P«
FINANCED FACILITY AT ThE ESSEX CHEMICAL COMPANY SULFU"IC ACID I"! AN I! F A C T U c I N G
PLANT IN RUMFORD, RHODE ISLAND WHERE MAGNESIUM OXIDE WAS REGENERATED A M>
soz FROM THE REGENERATION PROCESS WAS CONVERTED TO SULFURIC ACID. THE
RUMFORD FACILITY HAS SINCE BEEN CLOSED DOWN.
CONSTRUCTION UAS COMPLETED IN AUGUST AND THE SYSTEM STARTED U" IN SEPT;»EEP
1973. DURING INTERMITTENT OPERATIONS FOR SHAKEDOWN THROUGH JANUARY 1 ? 7 <,
THE SYSTEM'S LONGEST CONTINUOUS RUN WAS 2? 1 HOURS. THE SYSTEM HAS Rt- '
STARTED FRQM JULY THROUGH DECEMPER 1974, AND AGAIN ON AUGUST 11, 1975
APPROXIMATELY 87 HOURS. ''
fGO UNIT OUTAGES HERE CAUSED PRIMARILt PY PIPE AND PU"P CORRCSlON AND
MAJOR TURBINE OVERHAUL OF THE BOILER. PARTICULATE AND SO? REMOVAL
EFFICIENCY GUARANTEES WERE CORROBORATED DURING OPERATIONAL PHASES.
THE FGD SYSTEM WAS RESTARTED IN AUGUST. STEAM WAS LOST TO THE "GO Mix
TANK, RFSULTING IN A VERY MOIST PRODUCT FROM THE CENTPIFuGE. CAKING
D»tER OCCURRED. AT THIS POINT, THE UTILITY DECIDED TO TEST ONLY THE
STAGE OF THE SCRUBBING SYSTrM, TAKING GAS AHEAC OF »hF PRECIPMATOR.
OPERATION AT D1CKERSON TERMINATED AT THIS POINT.
THE REMAINING SUPPLY OF MAGNESIUM OXIDE, ABOUT IOC TONS (12 DAYS), HAS
BEEN DEPLETEOt AND THE DICKERSON UNIT MAS BEEN TERMINATED AS A FGD S>STc,v
rot
I .N T * e
Fl'ST-
FTD
7?C
744
7?C
744
744
6°6
744
7?C
744
7?C
744
744
7?C
7?C
744
744
672
744
7?C
744
7?C
744
172
-------
EPA UTILITY FGD SURVEY: JANUARY - PARCH 19E?
P3TO"AC ELECTRIC POWER: DICKERSON 3 ALANCE«
OUTAGE TIME WAS CAUSED BY LEAK REPAIRS IN SLURRY PIPING.
3/7? SYSTE"
21.0
22.C
21.Q
744
717
156
PROBLEMS/SOLUTIONS/COMMENTS
OUTAGE TIME WAS DUE TO RUBBER LINING FAILURE IN THE RECYCLE PUMP DISCHARGE
LINE.
SYSTEM
80.7
79.8
76.4
72C
689
** PROBLEMS/SOLUTIONS/COMMENTS
26 HOURS OF OUTAGE TIME WERE DUE TO SMALL LEAKS IN PIPING.
5/78 SYSTEM
84. 5
82.7
74.0
744
666
550
551
** PROBLEMS/SOLUTIONS/COMMENTS
A LEAK OCCURRED IN A MIST ELIMINATOR DRAIN.
THERE WAS A LEAK IN A BLEED LINE FOR THE SCRUBBER RECYCLE CIRCUIT.
OUTAGE TIME WAS REQUIRED FOR BLEED LINE REPLACEMENT.
6/7»
7/78
SYSTEM
SYSTEM
100.0
100.C
9T.1
.0
6».7
.0
72C
744
549
16
495
0
• * PROBLEMS/SOLUTIONS/COMMENTS
THE VENTURI SCRUBBEP HAD AN AVAILABILITY OF 1CCX F0» JUNE AND JULY. TH«
ONLY VENTURI OUTAGE TIME WAS IN JUNE. THE OUTAGE TIME WAS REQUIRED TO
TIE IN EQUIPMENT COMMON TO THE NEW UNIT AND UNIT 3.
THE BOILER WAS DOWN IN JULY FOR AN OVERHAUL.
THE REASON VENTURI HOURS CAN BE LOWER THAN BOILER HOURS WHEN THE VENTURI
HAS A iro* AVAILABILITY is PECAUSE THE VENTURI is NOT OPERATED UNDER LOW
LOAD CONDITIONS.
9/78 SYSTEM
,/78 SYSTEM
13/78 SYSTEM
11/75 SYSTEM
U/7K SYSTEM
1/79 SYSTEM
2/79 SYSTEM
5/79 SYSTEM
744
72C
744
720
744
744
672
744
173
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198C
POTOMAC ELECTRIC POWERr D1CKERSON 3 (CONT.)
PEBfORMANCF DATA
PERIOD MODULE AVAILABILITY OPERAPILlTY RELIABILITY UTILIZATION X REMOVAL PER B01LEP FGD CAP.
SO? PACT. HQUuS HOURS HOURS FACTOR
4/79 SYSTEM 770
5/79 SYSTEM 744
•• PROBLEMS/SOLUTIONS/COMMENTS
SCRUEBER OUTAGE HOURS SINCE SEPTEMBER 1978 U.E. SEPTEMBER 1976 THROUGH
MAY 2C, 1979) TOTAL 140. THE UTILITY INDICATED THAT IT IS NO LONGfR ALLOW-
ABLE TO BYPASS THE SCRUBBER yHEN PROBLEMS OCCUP, CLEANING THE PARTICULATf
MATTER SOLELY yITH THE ESP. THE UTILITY "UST DROP THE BOILER LOAD SO THE.
UNIT REMAINS IN COMPLIANCE.
THERE HAVE BEEN NO PROBLEMS REPORTED FOR THE LAST FEw MONTHS. THE UTILITY
IS KEEPING AHEAD OF PROBLEMS WITH A CONSCIENTIOUS INSPECTION AND l"AIf,l£>v-
ANCE PROGRAM.
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 730
1D/79 SYSTEM 98.6 95.4 744 72C 710
•« PROBLE*S/SOLUTIONS/COMMENTS
A TEN HOUR OUTAGE OCCURRED FOR REPAIRS OF A LEAD LINE LEAK.
11/79 SYSTEM 95.2 88.8 7?0 67? 640
•* PROBLEMS/SOLUTIONS/COMMENTS
IN NOVEMBERt 8 HOURS OUTAGE TIME WAS "EOUIRED TO REPAIR A LEAK IN A
RECYCLE LINE.
12/79 SYSTE" 96.1 9*.5 744 724 696
«• PROBLEMS/SOLUTIONS/COMMENTS
AN OUTAGE FOR GENERAL INSPECTION TOOK PLACE DURING DECEMBER.
1/80 SYSTEM 78.7 88.2 78.7 744 664 586
•* PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE SCRUBBER WAS DObN TO REPAIR THE FLAKEGLASS LINING.
2/80 SYSTEM 100.0 10P.O 100.0 696 696 696
3/80 SYSTEM 100.C 100.0 1CC.O 744 744 744
** PR08LEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY AND MARCH THE SCRUBBER OPERATED WITH NO MAJOR PROBLEMS.
174
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH
SECTION 14
DESIGN AND PERFORMANCE DAT* FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME PUBLIC SERVICE OF COLORADO
PLANT NAME ARAPAMOE
UNIT NUMBER <•
CITV DENVER
STATE COLORADO
REGULATORY CLASSIFICATION **.»*»
PARTICULATE EMISSION LIMITATION - NG/J * 3 . < .1CC Le/MweTU)
S02 E"ISS10N LIMITATION - NG/J .*..., (...... LF/MHPTU)
NET PLANT GENERATING CAPACITY - My *»»*..*
&ROSS UNIT GENERATING CAPACITY - My 112.C
HET~UNJT GENERATING CAPACITY W/FGD - »H 1G'.8
ycl UNIT GENERATING CAPACITY yO/FGD - MW .*..«*«
EOUIVALFNT SCRUBBED CAPACITY - My 11.3
•* P01LER DATA
SUPPLIER ««•«««
TYPE PULVERIZED COAL
SERVICE LOAD •*•***
COM'ERCIAL SERVICE DATE 5/55
MAXIMUM BOUES fLUE GAS FLOW - CU.M/S 2*5.39 < 5200CC «CFK>
FLUE GAS TEMPERATURE - C 1*8.9 ( 3"0 F)
STACK HEIGHT - H *....* («*•* fT)
STACK TOP DIAWETE" - « .*•«.*. (..... FT)
.. FUEL CAT*
FUEL TYPE COAL
FUEL GRADE SUBEI TUMI NOUS
AVERAGE HEAT CONTENT - J/G 237J5. < IC^OC BTU/LP)
RANGE HEAT CONTENT - 8TU/L6 .«««**
AVERAGE ASH CONTENT - * 9.3C
RANGE ASH CONTENT - 2 ***•««
AVERAGE MOISTURE CONTENT - X T*.70
RANGE MOISTURE CONTENT - » .*...*
AVERAGE SULFU" CONTENT - X .95
RANGE SULFUR CONTEST - X 0.6-0.95
AVERAGE CHLORIDE CONTENT - X .01
RANGE CHLORIDE CONTENT - X ••«..«
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - »
RANGE CHLORIDF CONTENT - X
FABRIC FILLER
NUMBER
TYPE
COAL
BITUMINOUS
23493.
12.50
»•»•**
11.2C
t 1C1DC ETU/LP)
.65
t *
.01
0
NONE
NUMBER
,. ȣCHANICAL COLLECTOR
NUMBER
.. PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
BOILER LOAO/SCRUBPER - X
FLUE GAS CAPACITY - CU.M/S
MOBILE PACKED TOWE9
AIO CORRECTION DIVISION, UOP
3
CARBON STEEL
RUB6?H
STAINLESS STEEL GRIDS, PLASTIC SPHERES
100.0
2*5.4 < 5?OCOO ACF«)
175
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
PJPLIC SERVICE Of COLORADO: ARAPAHOfc 4 (CONT.)
HUE GAS TEMPERATURE - C 151.7 < 305 F)
L/G RATIO - LITER/cU.W 7.5 <56.0 GAL/KOOACf)
PRESSURE DROP - KPA .*..... (••••• JM-H?O>
SUPERFICIAL G»S VELOCITY - M/S 3.4 < 11.0 FT/S)
PARTICULATE INLET LOAD - G/CU.M 1.8 < .8r, GB/SCF)
PARTICULATE OUTLET LOAD - G/CU.M .0 ( .32C GP/SCF)
PARTICULATE DESIGN REMOVAL EFFICIENCY - » 93.0
S02 INLET CONCENTRATION - PPM 5C7.00T
so< OUTLET CONCENTRATION - PPM 3i?.ooo
SOZ DESIGN REMOVAL EFFICIENCY - X 20.0
. .— PERFORMANCE DATA •--
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION X REMOVAL PEP BOILER FGO C«P.
SO? PART. HOURS HQUoS HOURS FACTOR
13/7<> SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FOURTH QUARTER REHEAT£R FAILURES OCCURRED.
LEAKAGE IN THE INLINE STEAM TUBES HAS BEEN ENCOUNTERED. CORROSION
IS KNOWN TO OCCUR AFTER LEAKS ARE EXPERIENCED.
THE PRIMARY PROBLEM KITH THE SYSTEM IS THE INABILITY TO ISOLATE MODULES.
IF A PROBLEM OCCURS NO MODULE MAINTENANCE CAN EE PERFORMED UNLtSS THE
UNIT LOAD IS CUT BACK OR THE UNIT IS SHUT OOyN.
1/80 SYSTEM 744
2/60 SYSTEM 6'e
i/8? SYSTEM 744
•• PROBLfcMS/SOLUTIONS/COMMENTS
THE MODULE ISOLATION PROBLEMS CONTINUED THROUGH THE FIRST dUAPTFR 19t'.
USE OF THE CARBON STEEL DAMPERS HAS BEEN ABANDONED. THE PKOGRA" FOR RE-
PLACING THE DAMPERS HAS BEEN SUSPENDED INDEFINITELY.
REHEATEH STEAM TUBE LEAKS ARE STILL CAUSING PROBLEM. ThE C STFA^ C C i Lr 0\
THIS IN-LINE REHEAT SYSTEM, i or WHICH ARE 3Uss AND 4 OF wnich API C4s^o\
STEEL, ARE EXPERIENCING CORROSION PROBLEMS. A SOLUTION TO TbF PRPfcLfl" HA «:
NOT YET BEEN DETERMINED.
IN FEBRUARY THE UTILITY REPLACED THE SCRUBBER B»LLS AND OH 01. TutY ufc=-
REPLACEO WITH THE NE* HOLLOW HARC PLASTIC-WALLED BALLS WITH NOTCHED SEA"S
THE GRIDS WERE ORIGINALLY 316L SS, CEPAMIC, POLYPROPYLENE, «NO "UB6ER L!\f
CARBON STEEL, faUT HAVE BEEN REPLACED WITH 31?L SS GRIDS.
THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE QUARTER EXCEPT fOU
BALL AND GRID REPLACEMENT DOWNTIME.
176
-------
EPA UT1L1TT FGD SURVEY: JANUARY - MARCH 19fa?
SECTION U
DESIGN AND PERFORMANCE DAT* FOR OPERATIONAL PARTICLE SCRUBPERS
PLANT NAME
NUMBER
STATE
REGULATORY CLASSIFICATION
pARTJCULATE EMISSION LIMITATION - NG/J
S02 £«1SSION LIMITATION - NG/J
SET PLANT GENERATING CAPACITY - MH
6BOSS UNIT GENERATING CAPACITY - Mu
NET UNIT GENERATING CAPACITY U/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MV
tOUJVALENT SCRUBBED CAPACITY - MU
»* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
RANGE M01STUR? CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE Sl/LfUR CONTENT - I
AVERAGE CHLORIDE CONTENT - »
RANGE CHLORIDE CONTENT - X
.. FABRIC FILTER
NUMBER
TYPE
«• ESP
NUMBER
t, MECHANICAL COLLECTOR
NUMBER
.« PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
BOILER LOAD/SCRUBBER - 1
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
L/G RATIO - L1TER/CU.H
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD - G/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 JHLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
PUBLIC SERVICE OF COLORADO
CHEROKEE
1
DENVER
COLORADO
** * * **
MO.O
115.0
1CO.O
115.0
102.2
6ABCOCK R WILCOX
PULVERIZED COAL
< .TOO
<«..».* LB/MMPTU)
0/57
245.39
146.1
COAL
BITUMINOUS
23493.
12.50
9.4-12.5
11.30
< 5?OCOC ACFM)
< 295 f)
<**»* fT)
<**.«» FT)
< 101CC BTU/LB)
******
.65
k*
.01
0
NONE
- X
MOBILE PACKED TOWER
AIR CORRECTION DIVISION, UOP
3
CARBOH STEEL
RUBBER
STAINLESS STEELi 1.5 INCH PLASTIC SPHERES
67.0
164.4 ( 348400 Atrm
295 F)
-------
EP* UTILITY FGD SURVEY: JANUARY - MARCH 1980
PUBLIC SERVICE or COLORADO: CHEROKEE 1
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 19fc(
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOi EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - My
*ET UNIT GENERATING CAPACITY U/FGD - MU
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - I»W
** BOILER DATA
SUPPLIE"
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILE" FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DI»M£TER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - *
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
RANGE M01STURF CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - 1
RANGE CHLORIOF CONTENT - X
** FABRIC FILTER
NUMBER
TYPE
• • ESP
NUMBER
** MECHANICAL COLLECTOR
NUMBER
«* PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.N
PARTICULATE OUTLET LOAD - G/CU.W
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
PUBLIC SERVICE OF COLORADO
CHEROKEE
4
DENVER
COLORADO
43.
.1CC LB/MMBTU)
.«.*« LB/MMPTU)
71C.O
375.0
330.0
375.0
356.4
COMBUSTION ENGINEERING
PULVERIZED COAL
3/6"
717.29 (1520000 ACFM)
135.0 < 275 F)
...... (.... ff>
....... (..... FT)
COAL
BITUMINOUS
23493.
12.50
9.4-12.5
11.30
******
.65
( 101CC BTU/LP)
.01
0
NONE
MOBILE PACKED TOWER
AIR CORRECTION DIVISION, UOP
t
CARBON STEEL
RUBBER
STAINLESS STEEL, 1.5 INCH PLASTIC SPHERES
7.5
?.4
1.6
.0
97. Q
520. OOP
42C.OOO
U.O
(56. C
(*•**• IM-H20)
11.* FT/S)
.7C GMSCF)
.C20 GP/SCF)
179
-------
EP» UTILITt FGO SURVEY: JANUARY - MARCH 1980
PUBLIC SERVICE OF COLORADO: CHEROKEE 4 PECTS THIS TO PROVE TO BE A PERMANENT SOLUTION.
ALSO DURING THE OUT«6E A SECOND LAYER OF VERTICAL GRIDS IS PE1NG INSTALLS
ON THE THREE LAYER MOBLE BED TOWER. THE VERTICAL GRIDS SHOULD CHECK THE
POTENTIAL FOR SIDE TO SIDE tALL MIGSATJOK.
THE OLD FANS ARE BEING REPLACED HlTH HIGH STRENGTH CARBON STEEL FANS HAVINr
HEPLACAPLE CHROMIUM ALLOY hEAR PLATE BLADF TIPS.
180
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/4
S02 EMISSION LIMITATION - N6/J
MET PLANT GENERATING CAPACITY - MW
CROSS UNIT GENERATING CAPACITY - My
MET UNIT GENERATING CAPACITY W/FGO - Mu
MET UNIT GENERATING CAPACITY WO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MW
«* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - lit,
RANGE HEAT CONTENT - BTU/LB
AVERAGE *SH CONTENT - X
RANGE ASH CONTENT - t
AVERAGE MOISTURE CONTENT - %
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
** FABRIC FILTER
NUMBER
TYPE
PUBLIC SERVICE OF COLORADO
VALMONT
5
VALHONT
COLORADO
43.
**<***
273.8
166.0
157.0
163.0
166.0
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
0/64
436.98
126.7
( .100 LB/MNBTU)
(****** LB/MMBTU)
( 926000 ACFM)
C 260 F)
<••*» FT)
<•**** FT)
COAL
SUBBITUMINOUS
25121.
6.00
5.4-7.0
15.00
12.7-18.3
.70
0.68-.73
( 1T800 BTU/LP)
0
NONE
ESP
NUMBER
TYPE
FLUE 6AS CAPACITY - CU.M/S
COLD SIDE
218. 5
( 463000 ACFM)
MECHANICAL COLLECTOR
NUMBER
FLUE GAS CAPACITY -
PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
TYPE OF NOZ7LES
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
L/6 RATIO - LITER/CU.*
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD - G/CU.M
S02 INLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
1
218.5
c 463000 ACFM)
MOBILE PACKED TOWER
AIR CORRECTION DIVISION, UOP
3
CARBON STEEL
RUBBER
STAINLESS STEEL, 1.5 INCH PLASTIC SPHERES
25.
36.0
109.2 ( 231500 ACFM)
271 F)
158.3 GAL/1000ACF)
(•**«* IN-H20)
11.0 FT/S)
.80 6R/SCF)
.020 GR/SCF)
132.8
7.8
••*•••*
3.4
1.8
.0
500.000
40.0
181
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
PUBLIC SERVK£ Of COLORADO: VALMONT 5 <£ONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILIT1 RELIABILITY UT1LI7ATION
* REMOVAL PER BOUE* F6o c«p.
S02 PART. HOURS HOURS HOURS FACTOR
ID/7* SYSTEM
744
•• PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER WAS ORIGINALLY INSTALLED FOR PARTJCULATE REMOVAL SINCE THE
PLANT BURNS LOy SULFUR COAL; HOWEVER, 45X OF THE SO? IS REMOVED AS WELL
BECAUSE OF THE ALKALINITY OF THE FLYASH.
11/74 SYSTEM
1Z/74 SYSTEM
1/75 SYSTEM
3/75
3/75
4/75
5/75
6/75
7/75
3/75
9/75
ID/75
11/75
12/75
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
744
672
744
7?C
744
720
744
744
720
744
72C
744
•• PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST TEAR OF OPERATION PROBLEMS INCLUDED DIFFICULTIES WITH THF
MODULE PACKING GRID SUPPORT, GENERAL VESSEL SCALE FORMATION, FLOW DISTRI-
BUTION PROBLEMS, BALL BREAKAGE, SCALING IN THE MIST ELIMINATOR SECTION
AND PLUGGING Of THE REHEATER. SCALE FORMATION WAS THE MOST PREDOMINANT
CONTINUING MAJOR CAUSE OF DOWNTIME IN THE SCRUBBER. SCALE ACCUMULATION ft
WAS NOTED ON THE WET-DRY INTERFACE IMMEDIATELY DOWNSTREAM OF THE PRESATU
RATION N072LES. SCALE ALSO ACCUMULATED HEAVILY ON THE UNDERSIDE OF THE
FIRST LATER OF GRID BARS.
SCALE ON THE UPPER GRID BARS WAS LESS PREVALENT AS THE ACTION OF THE "PiMr
PONG" BALLS TENDED TO KEEP THE SCALE OFF OF THESE SECTIONS. SCALE ALSO
COLLECTED ON THE WALLS OF THE VESSEL AND INTERMITTENTLY SLOUGHED OFF AND
FELL INTO THE SUMP IN LARGE PIECES CAUSING BLOCKAGE OF THE REC1RCULATI ON
PUMP SUCTION SCREENS. SCALING OF THE MIST ELIMINATOR ABATED SOMEWHAT WITH
THE INTRODUCTION OF A CLEAR RINSE WATER WASH. SCALE FORMATION IN THE RE-
HEAT SECTION SOMETIMES REOUJREO SUPPLEMENTAL CLEANING OF THE REHEATER IN
ADDITION TO THE CLEANING OBTAINED BY THE USE OF THE SOOTBLOWERS WHICH uccr
INSTALLED AS A PART OF THE REHEATER EQUIPMENT. UNDER NORMAL OPERATION
THE SOOTBLOWERS LOCATED IN THIS REHEAT SECTION WERE FAIRLY SUCCESSFUL IN
REMOVING THE ACCUMULATION OF THE SCALE IN THE REHEATER.
ALTHOUGH MAN1 OF THE INITIAL START-UP PROBLEMS WERE SOLVED OVER A PERIOD
OF TIME, THE CALCIUM SULFATE-FLVASH SCALING CONTINUED TO BE A SIGNIFICANT
OPERATING PROBLEM AT THE VALHONT INSTALLATION. IN ADDITION TO THESE
SCALING RELIABILITY PROBLEMS, A WATER OUALIT* CONCERN ALSO SURFACED THAT
WAS A DIRECT RESULT OF THE PARTICULATE SCRUBBER OPERATION. THE RELATlVFiv
HIGH CAO CONCENTRATION IN THE VALMONT FLTASH RESULTED IN FAIRLY HIGH SO?
REMOVAL RATES C45-50 PERCENT) WITHIN THE UNITS. SINCE NO PH CONTROL CAPA
BILITT FOR EITHER THE RECIRCULATIN6 SLURRY OR THE SYSTEM BLOWOOWN SLURRY
WAS DESIGNED INTO THE SYSTEM, AN ACID CONDITION WAS CREATED IN THE SLURRY
AND THE SLOWDOWN STREAM. PH LEVELS OF THE SLOWDOWN NORMALLY RANGED BETuEFkj
1.7 AND 2.0. ALTHOUGH THE STREAM WAS NEUTRALIZED TO A DEGREE BY ALKALINE
FLTASH, PSCC FELT THAT IT WAS IMPORTANT TO INVESTIGATE VARIOUS CONTROL
MEASURES WHICH COULD BE APPLIED TO THIS STREAM. THE CALCIUM SULFATE
SCALING PROBLEM WAS THOUGHT TO BE THE RESULT OF A SUPER-SATURATED CALCIUM
182
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
PJBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
____ . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION T REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
SULFATE CONDITION IN THE REC 1RCULATING SLURRY. BECAUSE OF THIS IT WAS FELT
THAT CONTINUOUS PH CONTROL OF THE REC 1RCULATING SLURRY, CONVERSION OF THE
SYSTEM TO CLOSED LOOP OPERATION AND ESTABLISHING A HIGHER CONCENTRATION OF
SEEDING SOLIDS IN THE RECIRCULAT10N SLURRY (THEREBY CONTROLLING THE SCALING
PROBLEMS WITHOUT CHEMICAL ADDITIVES) WOULD BE NECESSARY MEASURES.
FOR PH CONTROL, LIMESTONE WAS TESTED INITIALLY, THEN LIME WAS UTILIZED FOR
THE ALKALI REAGENT. IN THE FIRST TEST, SINCE LIMESTONE UTILIZATION WAS A
MAJOR CONCERN, A SPECIAL EFFORT WAS MADE TO REDUCE THE POTENTIAL FOR THE
SHORT CIRCUITING OF THE ADDED LIMESTONE AND TO PROVIDE SUFFICIENT RESIDENCE
TIME IN THE REACTOR SECTION OF THE SYSTEM. BY UTILIZING FOUR REATION MIX
TANKS IN SERIES, PLUG FLOW WAS EXPECTED TC BE MORE CLOSELY SIMULATED. TO
MAINTAIN A CLOSED LOOP SYSTEM WHERE THE QUANTITY OF taATER REMOVED FROM THE
SYSTEM WAS HELD TO * MINIMUM, FOUR SYSTEM DESIGN FEATURES WERE UTILIZED.
1. UTILIZATION OF A COMBINATION OF POND SUPERNATANT AND MAKE-UP WATER
FOR RECYCLE WATER.
2. PRESATURATION OF THE INCOMING FLUE GAS WITH hECIRCULATING SLURRY.
3. INTERMITTENT MIST ELIMINATOR WASH.
4. PROPER SELECTION OF MATERIALS OF CONSTRUCTION TO PROTECT AGAINST
ATTACK CAUSED faY HIGH CHLORIDE CONCENTRATIONS.
THE SCRUBBERS R R D FACILITY WAS NOT EQUIPPED WITH A MECHANICAL THICKENER
FOR CONTROL OF THE SUSPENDED SOLIDS CONCENTRATION OF THE REC IRCULATING
SLURRY
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
...... _ — . . PERFORMANCE DATA-
PERIOD MODULE AVAILABILITY OPERAPIL1TY RELIABILITY UTILIZATION X REMOVAL
E* BOILER FGO CAP
S02 PART. HOURS HOURS HOURS FACTOR
8/77 SYSTEM
9/77 SYSTEM
10/77 SYSTEM
11/77 SYSTEM
1Z/77 SYSTE"
SYSTEM
SYSTEM
SYSTEM
1/78
2/78
3/7?
744
720
744
7?0
744
744
672
744
•• PROBLEMS/SOLUTIONS/COMMENTS
THERE HAVE BEEN RECURRING PROBLEMS ASSOCIATED WITH BALL MIGRATION IN Tut
BALL COMPARTMENT AS fc E LL AS RECIRCULATION PUMP MOTOR PEARING FAILURE Aiun
WEAR AND FAILURE IN THE BALL COMPARTMENT LINING. THERE HAVE BEEN CONTTiuii.
PROBLEMS WITH REHEATER PLUGGING. THERE ALSO HAVE BEEN EXPANSION JOINT
FAILURES *T BOTH THF INLET AND OUTLET OF THE SCRUBBER.
MORE RECENTLY THERE WAS A PINCH BELT FAILURE.
THE SCRUBBING SYSTEM HAS HAD AN AVAILABILITY RANGE OF 50 TO 7SX yiTu .1,
AVERAGE OF 661. H AN
4/7? SYSTEM
5/78 SYSTEM
• • PROBLEMS/SOLUTIONS/COMMENTS
NO SIGNIFICANT PROBLEMS WERE ENCOUNTERED.
6/7« SYSTEM
7/78 SYSTEM
8/78 SYSTEM
• • PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY HAD NO COMMENTS FOR THIS PERIOD.
9/78
ID/78
11/78
12/78
1/79
2/79
3/79
4/79
5/79
6/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
72C
744
744
720
744
72C
744
744
672
744
7?0
744
720
•• PROBLEMS/SOLUTIONS/COMMENTS
AVERAGE SCRUBBER AVAILABILITY FROM START UP THROUGH APRIL 1979 WAS 64 A5»
AVERAGE SCRUBBER AVAILABILITY FOR 1978 WAS 66.85*. •*«
AVERAGE SCRUBBER AVAILABILITY FBQM JANUARY 1, 1979 THROUGH MAY. 197O
APPROXIMATELY 8PJt. "5
BALL MIGRATION, ALTHOUGH NOT SERIOUS, is A CHRONIC PROBLEM FOR VALMONT 5
184
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 19gO
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
__„___- — — —-PERFORMANCE DATA — ——-—-— — ——
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION * REMOVAL PE* BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
EROSION AND CORROSION HAVE OCCURRED ON THE SCRUBBER GRID BAR AREA (PACKING
SUPPORT).
EROSION/CORROSION IS EVIDENT IN THE MIST ELIMINATOR SECTION.
EROSION/CORROSION OCCURRS IN THE REHEATER AREA AND SOOT BLOWER.
THE UTILITY HAD TO REPLACE INLET AKD OUTLET EXPANSION JOINTS.
REHEATER PLUGGING HAS BEEN A PROBLEM.
RECYCLE PUMP BEARING FAILURES OCCURRED.
THE JACK SCREW DRIVE HAS BEEN MALFUNCTIONING ON INLET AND OUTLET ISOLATION
DAMPERS.
7/70
8/79
9/79
SYSTEM
SYSTEM
STSTE"
744
744
720
PROBLEMS/SOLUTIONS/COMMENTS
DURING THE ANNUAL SHUTDOWN IN SEPTEMBER THE OLD SCRUBBER BALLS WERE
REPLACED WITH A NEW BRAND. DUE TO BALL MOTION THE RUBBER LINER ERODED*
IN THE MIST ELIMINATOR SECTION EROSION AND CORROSION OCCURRED.
13/79
11/79
12/79
SYSTEM 100.0
SYSTEM 92.3
SYSTEM 98.1
744
72C
744
PROBLEMS/SOLUTIONS/COMMENTS
ONE OF THE MAJOR SYSTEM PROBLEMS IS THE SCRUBBER WALL WEAR WHICH HAS
TO BE PATCHED DURING THE SPRING AND FALL.
REHEATER PLUGGING HAS BEEN A CHRONIC PROBLEM.
THE UTILITY HAS REPORTED THE FOLLOWING ANNUAL AVAILABILITIES FOR THE UNIT,
1972 - 1978: 64.JX
1972 - 1979: 65.9*
1978: 66.81
1979: 80.5T
1/80
2/8?
3/8?
A
B
SYSTEM
A
B
SYSTEM
A
b
SYSTEM
98.5
98.5
98.5
84.4
94.9
89.7
85.0
85.0
85.0
744
696
744
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER 1980. NO MAJOR PROBLEMS WE"E ENCOUNTERED WITH
THE SCRUBBER.
185
-------
EPA UTILITY FGD SU»VE«: JANUARY - MARCH 1980
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY * «W
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY yO/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - Mw
SOUTHWESTERN PUBLIC SERVICE
HARRINGTON
1
AMARILLO
TEXAS
* *** * *
516.
360.0
360.0
< .10C LB/MMPTU)
( 1.20C LE/MMPTU)
BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAIIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - c
STACK HEIGHT - M
STACK TOP DIAMETER - M
FUEL DATA
FUEL TYPE
FUEL GRADF
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
RANGE MOISTURE CONTENT - X
AVERAGE SULFU» CONTENT - X
RANGE SULFUR CONTENT - t
AVERAGE CHLORIDE CONTENT - t
RANGE CHLORIDE CONTENT - X
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
S/76
778.63 (1650000 ACFM)
176.7 I 350 F)
7ft. ( 250 FT)
.8 ( 2.7 FT)
COAL
SUBBITUMINOUS
1953d.
5.30
4.5-6
27.10
25-3?
.42
.39-.45
< 8400 PTU/LB)
8000-8900
• * ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICULATE OUTLET LOAD - G/CU.M
•• PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
NUMBER OF NOZZLES
TYPE Of NOZZLES
BOILER LOAD/SCRUBPER - X
fLUE GAS CAPACITY - CU.M/S
fLUE GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
SUPERFICIAL GAS VELOCITY - M>s
PARTICULATE INLET LOAD - NG/J
PARTICULATE OUTLET LOAD - NG/J
PAHTJCULATE DESIGN REMOVAL EFFICIENCY - X
502 INLET CONCENTRATION - NG/J
S02 OUTLET CONCENTRATION - NG/J
1
COLD SIDE
RESEARCH COTTRELL
95.C
77S.6 (1650PCC ACFM)
16S.3 ( 335 F)
....... (..... IN-H20)
.18 ( .C8 GR/SCF)
MOBILE PACKED TOWER
COMBUSTION ENGINEERING
1
CARBON STEEL
RIGID LINE POLYESTER
316L SS FIBERGLASS ALLOY 2C
59
OPEN PIPE
141.6
444.1
3.1
43'.
21*.
30CCCC ACFM)
140 F)
7C5C GPM)
?3.0 GAL/1POCACF)
8.0 FT/S)
.185 LP/MMPTU)
.07C LE-/MMPTU)
( 1.00C LP/MMPTU)
( .SCO LB/MMBTU)
186
-------
EPA UTILITY FGP SURVEY: JANUARY - MARCH 1980
SOUTHWESTERN PUBLIC SERVICE: HARRINGTON 1 CCONT.)
__„ PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t ȣKOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/70 SYSTEM 744
11/79 SYSTEM ?20
12/79 SYSTEM 744
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THROUGH DECEMBER, TWO SPRAY PUMP KOTORS FAILED.
THE FRP MATERIAL IN THE FLUSH PIPING HAS FAILED CAUSING SOME LEAKAGE.
PLUGGING IN ONE MARBLE BED UAS ENCOUNTERED WHEN THE CHEMISTRY CONTROL W*S
TEMPORARILY LOST.
THE CONE SHAPED EXPANDED METAL SCREEN COVERING THE BED DRAIN PIPES HAS E
ERODED AWA1 F»OP BALL MOVEMENT. THE MARBLE BALLS HAVE BEEN DROPPING INTO 1
THE CONE SHAPED EXPANDED METAL SCREEN COVERING THE PED DRAIN PIPES HAS E
ERODED AWAY FROM BALL MOVEMENT. THE MARBLE BALLS HAVE SEEN DROPPING INTO 1
THE RECYCLE TANK. WHERE THE UTILITY HAS REPLACED THE METAL SCREEN WITH ANE
THE CONE SHAPED EXPANDED METAL SCREEN COVERING THE BED DRAIN PIPES HAS E
ERODED AWAY FRO" GALL MOVEMENT. THE MARBLE BALLS H»vF REEN DROPPING INTO Y
THE RECYCLE TANK. WHERE THE UTILITY HAS REPLACED THE METAL SCREEN WITH ANE
EXPANDED PLASTIC SCREEN, EROSION HAS MOT OCCURRED.
1/60 SYSTEM 744
2/80 SYSTEM «96
3/60 SYSTEM 744
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER 19SO THE MIST ELIMINATOR WASH PIPING RUPTURED
CAUSING PLUGGING IN SCRUBBERS 4 AND S. THt UTILITY PLANS TO REPLACE
ALL FRP PIPING WITH STEEL. THE RUPTURE ON NO. 5 ALSO DAMAGED THE HATER
SUPPLY HEADER.
THE MARBLE BED PLUGGING REPORTED DURING THE LAST QUARTER jS NOT YET
COMPLETELY CLEARED. THE SOFT SCALE IS GRADUALLY GOING BACK INTO THE
SOLUTION. THE PLATE AREA IS CLEAN.
THE DUCT BENEATH THE REHEATER TUBING ON ONE OF THE MODULES HAS CORRODED TC
THE POINT THAT HOLES HAVE FORMED. SCAL? AND M01STU«e WERE FOUND ON THE
PLATE WHERE THE CORROSION FORMED. THE PLATE WAS REMOVED AND A NEW CARBON
STEEL PLATE yAS WELDED IN. NO OTHER REHEATER AREA HAS EXPERIENCED ANY ?CA
OR MOISTURE.
187
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGC SYSTEMS
COMPANY NAME CHUGOKU ELECTRIC
PLANT NAME SHIMOMOSEKI
JNIT NUMBER 1
CITY SHIMONOSEKI
STATE
GROSS UNIT GENERATING CAPACITY - MW 175.C
SET UNIT GENERATING CAPACITY W/FGD - *W 175.C
EQUIVALENT SCRUBBED CAPACITY - MW 175.0
•• FUEL DATA
FUEL TYPE COAL
FUEL GRADE *••«*•
AVERAGE HEAT CONTENT - J/G 25046. I 1C768 BTU/LP)
AVERAGE ASH CONTENT - X 24.6C
AVERAGE MOISTURE CONTENT - X 2.30
AVERAGE SULFUR CONTENT - X .59
AVERAGE CHLORIDE CONTENT - X .04
•• F60 SYSTEM
GENERAL PROCESS TYPE WET SCRUBBING
PROCESS TYPE LIMESTONE
SYSTEM SUPPLIER MITSUBISHI HEAVY INDUSTRIES
NEW/RETROFIT RETROFIT
ENERGY CONSUMPTION - X ....«•.
INITIAL START-UP DATE 5/?o
COMMERCIAL START-UP DATE 7/79
502 DESIGN RErOVAL EFFICIENCY - X 85.CO
PARTICULATE DESIGN REMOVAL EFFICIENCY - X ........
ABSORBER SPAR? COMPONENTS INDEX .0
•* PYPRODUCT
BYPRODUCT NATURE GYPSUM
DISPOSITION
....—.......—....—-—-—.--— PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION » REMOVAL PE» BOILER FGO CAP""
S02 PART. HOURS HOURS HOURS FACTOR
7/79
8/79
9/79
13/79
11/79
12/79
1/80
3/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
ioe.0
10C.O
10C.O
100.0
10".0
100.0
5*.8
100.0
100.0
744
744
72C
408
744
720
408
744
720
•• PROBLEMS/SOLUTIONS/COMMENTS
COMMERCIAL OPERATIONS BEGAN IN THE MIDDLE OF JULY 1979. THE FGD UNIT HAt
OPERATED CONTINUOUSLY THROUGH THE THIRD QUARTER WITH NO PROBLEMS.
SYSTEM
SYSTEM
SYSTEM
100.r
100.0
93.5
10C.C
10C.O
93.5
100.0
1CO.O
93.5
10P.O
100.0
93.5
744
720
744
744
72C
744
744
720
696
.. PROBLEMS/SOLUTIONS/COMMENTS
THE FGD UNIT OPERATED CONTINUOUSLY THROUGH THE FOURTH QUARTER EXCEPT Foe
2 DAY SHUTDOWN TO INSPECT THi GAS-GAS HEATER DURING DECEMBER. THE BOILFB
WAS OPERATED FIRING A LOW SULFUR OIL DURING THE TWO DAYS.
STSTEH
SYSTEM
100.0
55.2
100.0
1CO.C
100.0
55.2
100.0
55.2
744
6960
744
384
744
384
188
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
CHUGOKU ELECTRIC: SHIMONOSEKI i (CONT.)
__.....—— — PERF ORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABH1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY AND THE FIRST HALF Of FEBRUARY THE FGD UNIT OPERATED UITH
NO PROBLEMS. THE UNIT WAS TAKEN OFF-LINE IN THE MIDDLE OF FEBRUARY FOR
SCHEDULED MAINTENANCE.
189
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGC SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
G»OSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - I»W
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE AJH CONTENT - *
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
** F&D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
502 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELECTRIC POWER DEVELOPMENT CO.
ISOGO
1
YOKOHAMA
JAPAN
265.0
23?.0
265.0
COAL
******
25958.
16.CO
7.00
.60
WET SCRUBBING
LIMESTONE
IHI - CHEMICO
RETROFIT
» 11160 BTU/LP)
12/75
3/76
90.00
96.70
.0
OPEN
22.3
GYPSUM
MARKETED
< 354 GPI»>
. . __ PERFORMANCE DATA — —
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGO CAP"*
S02 PART. HOURS HOURS HOURS FACTOR
4/73 SYSTEM
5/7* SYSTEM
6/78 SYSTEM
7/78 SYSTEM
8/78 SYSTEM
9/7P SYSTEM
13/78 SYSTEM
11/7S SYSTEM
12/78 SYSTEM
1/79 SYSTEM
2/79 SYSTEM
3/79 SYSTEM
7?0
Tit,
720
744
744
7?0
744
720
744
744
672
744
190
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198T
ELECTRIC POWER DEVELOPMENT CO.: ISOGO 1
— PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION T REMOVAL P£« BOILER FGD C»P.
SO? PART. HOURS HOURS HOURS FACTOR
** PR08LEMS/SOLUT10NS/COM*ENTS
100X AVAILABILITY WAS REPORTED FOR THE PE"IOD FROM 'P"IL 1978 THROUGH
MARCH 1979.
191
-------
EPA UTILITY FGB SURVEY! JANUARY - MARCH 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTFMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL OAT*
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - x
AVERAGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - t
•• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL STAPT-UP DATE
COMMERCIAL START-UP DATE
SO? DESIGN »E"OVAL EFFICIENCY - *
PARTICULATE DFSIGN REMOVAL EFFICIENCY
ABSORBER SPARF COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELECTRIC POWER DEVELOPMENT CO.
ISOGO
2
YOKOHAMA
JAPAN
265.0
238.0
265.0
COAL
25956.
16.00
7.00
.60
MET SCRUBBING
LIMESTONE
IHI - CHEMICO
RETROFIT
3.0
3/76
5/76
9C.OO
96.70
.0
OPEN
GYPSUM
MARKETED
1116C BTU/LB)
354 GPM>
DATA— . .___
PE»IOD MODULE AVAILABILITY OPERABUITY RELIABILITY UTILIZATION * REMOVAL PEP BOILER F6D C»P
SO? PART. HOURS HOURS HOURS FACTOR
4/78
5/78
6/7«
7/78
8/78
9/78
10/78
11/78
12/78
1/79
2/79
3/79
STSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
72C
7*4
720
744
744
720
744
720
744
744
6?2
744
192
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 19gr
ELECTRIC POWER DEVELOPMENT CO.: ISOGO 2
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198C
SECTION 15
DESIGN AND PERFORMANCE DATA FOP OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT N»ME
JNIT NUMB ER
C ITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUPBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASM CONTENT - *
AVERAGE MOISTURE CONTENT - »
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 5!
•* FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPUFR
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
ABSORBER SPARE COMPONENTS INDEX
*• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELECTRIC POWER DEVELOPMENT CO,
TAICASAGO
1
TAKASA60
JAPAN
23".C
25C.O
COAL
25958.
il.OO
7.00
1.80
WET SCRUBBING
LIM ESTONE
HITSUI - CHEMICO
RETBOFIT
3.2
2/75
* * / * *
97.OC
( 1116C PTU/LR)
.0
OPEN
1J.1
GYPSUM
?OP
. . PERFORMANCE DATA _
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILI7ATION * REMOVAL PEP BOILER FGD CAp"~
$02 PART. HOURS HOURS HOURS FACTOR
W7R
5/7P
6/7R
7/7S
8/78
9/78
n/7«
11/7^
MI7P
1 /7Q
2/7
-------
EPA UT1LJTK FGD SORVEK: JANUARY - MARCH 198?
ELECTRIC POWER DEVELOPMENT CO.: TAKASAGO 1 (CONT.)
. — —PE» FORWANCE DATA —
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION * REMOVAL PE' BOILER FGO C»P.
SO? PACT. HOURS HOURS HOURS FACTOR
*• PROBIE»S/SOLUTIONS/COM*IENTS
DURING APRIL 1978 THROUGH MARCH 1Q7Q NO FORCED OUTAGES OCCURRED. THE FCD
SYSTEM »V*ILABU1T> WAS 99.9j.
195
-------
EPA UTUITY F&D SURVEY: JANUARY - MARCH 198C
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CUT
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY M/FGO - KM
EQUIVALENT SCRUBBED CAPACITY - «W
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEK/RETROFIT
ENERGY CONSUMPTION - t
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTKULATE DESIGN REMOVAL FFF1CIENCY
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELECTRIC POWER DEVELOPMENT CO.
TAKASAGO
2
TAKASAGO
JA«>AN
2SC.O
230.0
250.0
COAL
25956.
22.00
7.00
1.80
********
WET SCRUBBING
LIMESTONE
MITSUI - CHEM1CO
RETROFIT
3.2
3/76
**/ **
93.00
< 11160 BTU/LB)
.0
OPEN
13.1
GYPSUM
?08 GPM>
....—....... ... — .....-_.._pERfORMANCE DATA — - ......
PERIOD MODULE AVAILABILITY OPERARILITY RELIABILITY UTILIZATION x REMOVAL PEP BOILER FGO CAP""
P»RT. HOURS HOURS HOURS FACTOR
*/7?
5/78
6/7S
7/78
8/78
9/78
13/78
11/78
12/78
1/79
2/79
3/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
720
744
744
720
744
720
744
744
6^2
744
196
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 1980
ELECTRIC POWER DEVELOPMENT CO.: TAKASA60 2
-------
EPA UTILITY FGD SUSVEY: JANUARY - MARCH 1980
SECTION 15
DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL fOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - *y
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRAOF
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
- X
ELECTRIC POWER DEVELOPMENT CO.
TAKEHARA
1
M1HARA
JAPAN
25T.O
231.0
25D.O
COAL
MITSUI MINING
2513Q.
23.00
9.05
?.DO
.05
WET SCRUBBING
LIMESTONE
BABCOCK - HITACHI
RETROFIT
3.2
2/77
2/79
94.20
91.70
.0
OPEN
14.1
BTU/LB)
GPW)
•• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
GYPSUM
MARKETED
. .— .. . - — PERFORMANCE DATA — —— ..«
PERIOD MODULE AVAllABUITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER F6D CAP
SO? PART. HOURS HOURS HOURS FACTOR
4/78
5/78
6/78
7/78
8/78
9/78
10/78
11/78
12/78
1/70
2/79
5/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
7?0
744
744
720
744
720
744
744
672
744
198
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 198?
ELECTRIC POWER DEVELOPMENT CO.: TAKEHARA 1 (CONT.)
-PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X RE«OV»|_ PE" BOILER FGD C»P«
SO? PART. HOURS HOURS HOURS FACTOR
*« PROBLfclS/SOLUTlONS/COMWENTS
99.95X AVAILABILITY WAS REPORTED FOR THE PERIOD FROI" APRIL 1978 THROUGH
MARCH 1979.
199
-------
APPENDIX A
FGD SYSTEM COST DATA: OPERATIONAL AND NONOPERATIONAL SYSTEMS
A-l
-------
INTRODUCTION
The cost of flue gas desulfurization (FGD) systems for the
control of sulfur dioxide emissions is an area of intense inter-
est and substantial controversy. As a result, many computer
models have recently been developed to estimate capital and
annual costs. As part of an effort by the U.S. Environmental
Protection Agency to provide meaningful economic data concerning
FGD systems, reported economic data have been incorporated into
the EPA Utility FGD Survey report. This information has appeared
as a separate appendix of the report since October 1976. Until
January 1978, this cost appendix consisted entirely of data
reported by the utilities with little or no interpretation pro-
vided by PEDCo Environmental, Inc. Beginning with the May 197g
report, the format and content of the cost appendix were revised
to include reported and adjusted costs for the operational FGD
systems.
The rationale for including adjusted as well as reported
costs stems primarily from the lack of comparability of the
reported costs. Many of the reported cost figures, both capital
and operating, are largely site-sensitive values that cannot be
accurately compared because they refer to different FGD battery
limits and different years in which the expenditures were made.
As a result, an analysis of the cost data was made for the opera-
tional units since these systems offer the potential of having
complete and accurate economic data. The adjustments were made
to provide comparable, accurate cost data for the sulfur dioxide
portion of the emission control system. This, in effect, will
eliminate much of the confusion that exists concerning the re-
ported data, and it will provide a common basis for the reported
costs.
A-2
-------
In an attempt to promote further comparability of the
figures, the adjustment procedure was carried one step further
and standardized adjusted figures were developed. This was done
by modifying the fixed annual cost rates such that they would be
identical for each unit (i.e. cost of depreciation, interim re-
placement, taxes, insurance and capital costs). The newly ad-
justed total fixed annual cost rate was applied to the total ad-
justed capital cost in each case and a standardized adjusted
annual cost was obtained.
A-3
-------
APPROACH
In March 1978, each utility having at least one operational
FGD system was given a cost form containing all available cost
information then in the PEDCo files. The utility was asked to
verify the data and fill in any missing information called for
on the form. A follow-up visit by the PEDCo Environmental staff
was arranged to assist in data acquisition and to insure com-
pleteness and reliability of information. Results of the cost
analysis were forwarded to each participating utility for final
review and comment.
The cost data were treated solely to establish the accurate
costs for FGD systems, on a common basis, not to critique the
design or reasonableness of the costs reported by any utility.
Adjustments focused primarily on the following items:
0 All capital costs were adjusted to July 1, 1977, dol-
lars using the Chemical Engineering Index. All capital
costs, represented in dollars/kilowatt ($/kW), were
expressed in terms of gross megawatts (MW). Actual
costs were reported by utilities in dollar values for
years 1970 to 1980. These values are represented in
terms of the year of greatest capital expenditures.
0 Gross unit capacity was used to express all FGD capital
expenditures because the capital requirement of an FGD
system is dependent on actual boiler size before de-
rating for auxiliary and air quality control power
requirements.
0 Particulate control costs were deducted. Since the
purpose of the study was to estimate the incremental
cost for sulfur dioxide control, particulate control
costs were deducted using either data contained in the
cost breakdowns or as a percentage of the total direct
cost (capital and annual). The percentage reduction
varied depending upon system design and operation.
A-4
-------
The capital costs associated with the modification or
installation of equipment not part of the FGD system
but needed for its proper functioning, were included
(e.g. - stack lining, modification to existing ductwork
or fans, etc.).
Indirect charges were adjusted to provide adequate
funds for engineering, field expenses, legal expenses,
insurance, interest during construction, allowance for
startup, taxes, and contingency.
All annual costs, represented in mills/kilowatt-hour
(mills/kWh), were expressed in terms of net megawatts
(MW) .
Net unit capacity was used to express all FGD annual
expenditures because the annual cost requirement of an
FGD system is dependent on the actual amount of kilo-
watt-hours (kWh) produced by the unit after derating
for auxiliary and air quality control power require-
ments.
All annual costs were adjusted to a common capacity
factor (65%).
Replacement power costs were not included since only a
few utilities reported such costs and these were pre-
sented using a variety of methods.
Sludge disposal costs were adjusted to reflect the
costs of sulfur dioxide waste disposal only (i.e.,
excluding fly ash disposal) and to provide for disposal
over the anticipated lifetime of the FGD system. This
latter correction was necessary since several utilities
reported costs for sludge disposal capacity that would
last only a fraction of the FGD system life. The
adjustments were based on a land cost of $2000/acre
with a sludge depth of 50 ft in a clay-lined pond (clay
is assumed to be available at the site).
A 30-year life was assumed for all process and economic
considerations for all new systems that were installed
for the life of the unit. A 20-year life was assumed
for all process and economic considerations for retro-
A-5
-------
fit systems that were installed for the remaining por-
tion of the life of the unit.*
0 Regeneration and by-product recovery facility costs
were added for those regenerable systems not reporting
such costs.
To the extent possible, all cost adjustments were made using
the previous assumptions developed by PEDCo Environmental. When
cost data were inadequate, adjustments were made using process
design data in conjunction with the previous cost assumptions.
In some cases, no adjustments were possible because of in-
sufficient data.
The use of a 30-year service life for new units coincides with
the conclusion of the National Power Survey of the Federal
Power Commission which recognized this value as reasonable for
steam-electric plants. A 20-year service life was assumed for
all retrofit units even if the remaining life of the units is
less than this value. Thus, two different rates are used and
should be noted when making comparisons between new and retro-
fit systems.
A-6
-------
DESCRIPTION OF COST ELEMENTS
Capital costs consist of direct costs, indirect costs, con-
tingency costs, and other capital costs. Direct costs include
the "bought-out" cost of the equipment, the cost of installation,
and site development. Indirect costs include interest during
construction, contractor's fees and expenses, engineering, legal
expenses, taxes, insurance, allowance for start-up and shake-
down, and spares. Contingency costs include those costs result-
ing from malfunctions, equipment alterations, and similar un-
foreseen sources. Other capital costs include the nondepreciable
items of land and working capital.
Annual costs consist of direct costs, fixed costs, and over-
head costs. Direct costs include the cost of raw materials,
utilities, operating labor and supervision, and maintenance and
repairs. Fixed costs include those of depreciation, interim
replacement, insurance, taxes, and interest on borrowed capital.
Overhead costs include those of plant and payroll expenses. The
various capital and annual cost components are discussed and
defined in greater detail in the following paragraphs.
The direct capital costs include the following elements:
0 Equipment required for the FGD system. Table A-l
provides a summary of the major process equipment used
in regenerable and nonregenerable systems.
° Installation of equipment, including foundations; steel
work for support, buildings, piping and ducting for
effluents, slurries, sludge, and make-up water, control
panels, instrumentation, insulation of ducting, buildings,
piping, and other equipment, painting and piling.
0 Site development may include clearing and grading,
construction of access roads and walkways, establish-
ment of rail, barge, and/or truck facilities, and
parking facilities.
A-7
-------
TABLE A-l. MAJOR FGD SYSTEM EQUIPMENT SUMMARY
Category
Description
Material handling-
raw materials
Feed preparation-
raw materials
Sulfur dioxide
absorption
Flue gas reheat
Gas handling
Sludge disposal
Utilities
By-product
handling
Equipment for the handling and transfer of
raw materials includes unloading facilities,
conveyors, storage areas and silos, vibrators,
atmospheric emission control associated with
these facilities, and related accessories.
Equipment for the preparation of raw material
to produce a feed slurry consists of feed
weighers, crushers, grinders, classifiers,
ball mills, mixing tanks, pumps, agitators,
and related accessories.
Equipment for treating the flue gas includes
absorbers, mist eliminators, hold tanks,
agitators, circulating pumps, pond water re-
turn pumps, and related accessories.
Equipment required includes air, steam, or
hot water heaters, condensate tanks, pumps,
soot blowers, fans, fuel storage facilities,
gas bypass equipment, and related accessories.
Equipment to handle the boiler flue gas in-
cludes booster fans, ductwork, flue gas by-
pass system, turning vanes, supports, plat-
forms, and related accessories.
Nonregenerable FGD systems require solids/
water separation equipment such as clarifiers
vacuum filters, centrifuges, sludge fixation
equipment, and related accessories.
Equipment to supply power and water to the
FGD equipment consists of switch-gear, break-
ers, transformers, piping, and related
accessories.
Equipment for processing the by-product of
regenerable FGD systems may include a rotary
kiln, fluid bed dryer, conveyor, storage silo
vibrator, combustion equipment and oil stor-
age tanks, waste heat boilers, hammer mills,
evaporators, crystallizers, strippers, tanks,
agitators, pumps, compressors, sulfuric acid'
absorber and cooling, mist eliminator, pumps
acid coolers, tanks, etc.
(continued)
A-8
-------
TABLE A-l. (continued)
Category
Description
Regeneration
Purge treatment
Auxiliary
Equipment for regeneration of the absorbing
medium of an FGD system may consist of re-
actor vessels, material handling system,
storage, weigh feeder, conveyor, rotary kiln,
fluid bed calciner, dust collector, storage
silo, vibrator, combustion equipment and oil
storage tanks, waste heat boiler, hammer
mill, evaporators, crystallizers, strippers,
tanks, agitators, pumps, compressors, sul-
furic acid absorber and cooling, mist elimi-
nator, pumps, acid coolers, tanks, etc.
Equipment for the removal of purge material
(e.g. sodium sulfate) includes refrigeration,
pumps, tanks, crystallizer, centrifuge,
dryer, dust collector, conveyors, storage,
and related equipment.
Equipment not directly related to the
FGD system, but which may require design or
modification to accommodate an FGD system
may include such items as existing fans,
ducts, or stack. If new fans, ducts, or
stacks are added to improve boiler perfor-
mance and accommodate the FGD systen, the
costs are prorated to the boiler and FGD
system.
A-9
-------
Indirect capital costs include the following elements:
0 Interest accrued on borrowed capital during construction.
0 Contractor's fee and expenses, including costs for
field labor payroll; field office supervision; person-
nel; construction offices; temporary roadways; railroad
trackage; maintenance and welding shops; parking lot;
communications; temporary piping and electrical and
sanitary facilities; safety security (fire, material,
medical, etc.); construction tools and rental equip-
ment; unloading and storage of materials; travel ex-
penses; permits; licenses; taxes; insurance; overhead;
legal liabilities; field testing of equipment; start-
up; and labor relations.
0 Engineering costs, including administrative, process,
project, and general; design and related functions for
specifications; bid analysis; special studies; cost
analysis; accounting; reports; consultant fees; pur-
chasing; procurement; travel expenses; living expenses-
expediting; inspection; safety; communications; model-'
ing; pilot plant studies (if required because of pro-
cess design or application novelty); royalty payments
during construction; training of plant personnel; field
engineering; safety engineering; and consultant ser-
vices .
0 Legal expenses, including those for securing permits,
rights-of-way, etc.
0 Taxes, including sales, and excise taxes.
0 Insurance covering liability for equipment in transit
and at site; fire, casualty, injury, and death; damage
to property; delay; and noncompliance.
0 Allowance for start-up and shakedown includes the cost
associated with system start-up.
0 Spare parts including pumps, valves, controls, special
piping and fittings, instruments, spray nozzles, and
similar items.
Other capital costs include the following elements:
0 Land required for the FGD process, waste disposal, re-
generation facility, and storage.
0 Working capital, including the total amount of money
invested in raw materials and supplies in stock,
finished products in stock, and unfinished products
A-10
-------
in the process of being manufactured; accounts re-
ceivable; cash kept on hand for payment of operating
expenses such as salaries, wages, and raw materials
purchases; accounts payable; and taxes payable.
Annual cost of an FGD system includes the following direct,
fixed and overhead charges:
° Direct Charges
Raw materials, including those required by the FGD
process for sulfur dioxide control, absorbent regenera-
tion, sludge treatment, sludge fixation, flocculants,
etc.
Utilities, including water for slurries, cooling and
cleaning; electricity for pumps, fans, valves, lighting
controls, conveyors, and mixers; fuel for reheating of
flue gases; and stream for processing.
Operating labor, including supervisory, skilled, and
unskilled labor required to operate, monitor, and
control the FGD process.
Maintenance and repairs, consisting of both manpower
and materials to keep the unit operating efficiently.
The function of maintenance is both preventive and
corrective to keep outages to a minimum.
Byproduct Sales; credit from the sale of byproducts
regenerable FGD processes (e.g. sulfur, sulfuric acid)
is a negative charge deducted from the annual direct
cost to obtain the net annual direct cost of the FGD
system.
° Fixed Charges
Depreciation - the annual charge to recover direct and
indirect costs of physical assets over the life of the
asset.
Interim, replacement - costs expended for temporary or
provisional replacement of equipment that has failed or
malfunctioned prematurely.
Insurance, including the costs of protection from loss
by a specified contingency, peril, or unforeseen event.
Required coverage could include losses due to fire,
personal injury or death, property damage, explosion,
lightning, or other natural phenomena.
A-ll
-------
Taxes, including franchise, excise, and property taxes
levied by fe city, county, state, or Federal government.
Interest on borrowed funds.
° Overhead
Plant and administrative overhead is a business expense
that is not charged directly to a particular part of a
project, but is allocated to it. Overhead costs in-
clude administrative, safety, engineering, legal and
medical services; payroll; employee benefits; recrea-
tion; and public relations.
Table A-2 provides a summary of the means used to determine
the missing cost elements if the costs were not reported or
insufficient information prevented their actual determination.
The assumptions and cost bases for determining the capital and
annual costs of FGD systems were developed by the PEDCo staff
based upon previous economic studies conducted for the U.S. EPA
(Flue Gas Desulfurization Process Cost Assessment, May 1975;
Simplified Procedures for Estimating Flue Gas Desulfurization
System Costs, June 1976, EPA-600/2-76-150; Particulate and Sulfur
Dioxide Emission Control Costs for Large Coal-Fired Boilers,
March 1978, EPA-600/7-78-032).
A-12
-------
TABLE A-2. COST ELEMENT FACTORS
Category
Value
Indirect capital costs:
Interest during
construction
Field overhead
Contractor's fee and
expenses
Engineering
Taxes
Spares
Shakedown allowance
Other capital costs:
Contingency3
Direct annual costs:
Raw materials:
Fixation chemicals
Lime
Limestone
Magnesium oxide
Sodium carbonate
Salt cake (credit)
Sulfur (credit)
Sulfuric acid (credit)
Utilities:
Electricity
Water
Steam
Operating labor:
Direct labor
Supervision
10% of total direct capital costs
10% of total direct capital costs
5% of total direct capital costs
10% of total direct capital costs
2% of total direct capital costs
1% of total direct capital costs
5% of total direct capital costs
20% of total direct and indirect
capital costs
$2/ton
$40/ton
$10/ton
$150/ton
$80/ton
$50/ton
$65/ton
$25/ton
25 mills/kWh
$0.20/103 gal
$0.80/106 Btu
$8.50/man-hour
15% of direct labor costs
Contingency costs are used only when the cost data supplied are
incomplete (such as equipment costs or direct costs only) and a
contingency cost must be factored in to give an accurate estimate
of the total capital cost.
(continued)
A-13
-------
TABLE A-2. (continued)
Category
Value
Maintenance:
Labor and materials
Supplies
Overhead:
Plant
Payroll
Fixed annual costs:
Depreciation
Interim replacement
Taxes
Insurance
Capital costs
4% of total direct capital costs
15% of labor and materials costs
50% of operation and maintenance costs
20% of operating labor costs
3.33% or 5% (new or retrofit)
0.7% or 0.35%
4%
0.3%
9%
Some system components have life spans less than the expected
service life of the system. Interim replacement is an allow-
ance factor used in estimating annual revenue requirements to
provide for the replacement of these short-lived items. An
average allowance of 0.35% of the total investment is normally
provided and used for systems with an expected service life of
20 years or less. A higher allowance of 0.70% of the total
investment is provided and used for systems with an expected
service life of 30 years or more.
A-14
-------
DEFINITION OF COST ELEMENTS
The costs displayed in Appendix A are accompanied by a
series of alphabetic characters summarizing data presented for
each FGD system. These relate to the cost elements described
earlier in this section and identify what has been included and
excluded for reported and adjusted capital and annual costs. The
alphabetic characters, along with their titles, are briefly de-
scribed in Table A-3.
A-15
-------
TABLE A-3. DESCRIPTION OF COST
Code
Title
Description
B
c
L
M
N
0
Farticulate control (required for FGD pro-
cess) included in capital cost.
Particulate control (included in FGD
process) included in capital cost.
Total direct capital costs included.
Partial direct capital costs included.
Total indirect capital costs included.
Partial indirect costs included.
Chemical fixation of sludge included in
capital cost.
Dry sludge disposal included in capital
cost.
Off-site landfill area included in
capital cost.
Sludge pond included in capital cost.
Additional sludge disposal capacity
added for life of system.
Stack included in capital cost.
Modifications to stack, ducts, and/or
fans included in capital cost.
Total regeneration facility cost included
in capital cost.
Partial regeneration facility cost in-
cluded in capital cost.
R & D costs included in capital cost.
Particulate precollection device (ESP,
fabric filter, venturi) prior to FGD
system required for proper operation of
SO- control system.
Particulate collection equipment (venturi
scrubber) is included in the FGD system.
Complete cost of all FGD equipment, the
labor and materials required for equip-
ment installation, and interconnecting
the system is included in the total
capital cost.
One or a number of direct cost items, or
the cost associated with one or a number
of direct cost items, are excluded from
the total capital cost.
Complete cost of all the indirect cost
elements, including interest during con-
struction, contractor's fees, engineer-
ing, legal expenses, taxes, insurance,
allowance for start-up, and spares, ia
included in total capital cost.
One or a number of indirect cost items
or the cost associated with one or a '
number of indirect cost items, are ex-
cluded from the total capital cost.
The cost of a chemical fixation process
which stabilizes the flue gas cleaning
wastes prior to disposal is included in
the total capital cost.
The cost of a secondary dewatering or
treatment method, such as filtration can
trifugation, or forced oxidation, which
ultimately produces a dry sludge cake
for final disposal, is included in the
total capital cost.
The cost of an off-site area used as a
landfill for flue gas cleaning wastes ia
included in the total capital cost.
The cost of an on-site disposal area for
ponding of treated or untreated fiue gas
cleaning wastes is included in the total
capital cost.
The cost of additional SO. waste disposal
capacity required for FGD^system operation
over the anticipated service life of the
unit is included in the total capital cost
The cost of the stack is included in th«
total capital cost.
Modifications to existing equipment (stack
fans, ducts, etc.) which are required be-
cause of inclusion of an FGD system.
Complete cost of entire regeneration
facility included in total capital cost.
Part of the cost associated with the re,
generation facility included in the tot.i
capital cost. «»*»!
Bench scale or pilot plant studies to de
termine process and design characteristics
(continued)
A-16
-------
TABLE A-3. (continued)
Code
M
X
Title
losts underwritten by system supplier in-
luded in capital cost.
Excess reagent supply costs included in
capital cost.
Total direct annual costs included.
Partial direct annual costs included.
Total fixed annual costs included.
Partial fixed annual costs included.
Overhead cost included in total annual
cost.
Particulate control costs included in
direct annual cost.
Sludge disposal service costs (contract)
included in direct annual cost.
Replacement energy costs included in
total annual costs.
Description
Capital expenditures underwritten by the
system supplier for system repairs or
modifications for optimization of perfor-
mance or R t D programs.
Capital expenditures for reagent supply
exceeds the amount required for the period
of initial operation.
Complete cost of all raw materials,
utilities, operating labor and maintenance
and repairs is included in the total
annual cost.
One or a number of direct annual cost items,
or the cost associated with one or a number
of direct annual cost items, are excluded
from the total annual cost.
Complete cost of all fixed cost elements,
including depreciation, interim replace-
ment, insurance, taxes, and interest, is
included in the total annual cost.
One or a number of fixed annual cost items,
or the cost associated with one or a
number of fixed annual cost items, are ex-
cluded from the total annual cost.
Plant and payroll overhead costs are in-
cluded in the total annual cost.
The cost of operating particulate collection
equipment included in the FGD system is in-
cluded in the total annual cost.
The treatment and disposal of flue gas
cleaning wastes that are handled by an
outside firm.
The cost of additional power-generating
capacity required to compensate for power
used by the FGD system.
A-17
-------
RESULTS OF COST ANALYSIS
The results of the operational FGD system survey are summarized
in Table A-4 and Section A-l. Table A-4 produces a summary of a
categorical analysis of the reported and adjusted capital and
annual costs for the operational FGD systems addressed in the
survey. Included in this categorical analysis are the ranges,
means, and standard deviation for all the various types and
categories of FGD systems examined. Section A-l summarizes the
reported and adjusted capital and annual costs for all the oper-
ational FGD systems that were addressed in the cost study
(Section A-2 summarizes available cost data for nonoperational
FGD systems).
A-l 8
-------
TABLE A-4. CATEGORICAL RESULTS OF THE REPORTED AND ADJUSTED
CAPITAL AND ANNUAL COSTS FOR OPERATIONAL FGD SYSTEMS
CATEGORY
— REPORTED
---CAPITAL, I/KU-- ANNUAL, NILLS/KUH---
RANGE AV6 DEV RANGE AVG DEV
ADJUSTED
CAPITAL, »/KU —-ANNUAL, HILLS/KUH—
RANGE AVG DEV RANGE AVG DEV
ALL
MEU
RETROFIT
THROMAUAY PRODUCT
SALEAILE PRODUCT
LIMESTONE
LINE
•UAL ALKALI
LINE/ALKALINE rITASH
SOIIUN CARIONATE
UELLNAN LORI
LIMESTONE/ALKALINE FLYASH
HA6NE5IUN OXIDE
2V.2-189.0 80.9 40.2 .1- 14.9 4.4 4.4
31.B-IB9.0 80.4 39.6 .1- 14.3 3.3 3.9
29.2-154.9 82.0 4t.3 2.0- 14.9 4.1 4.5
29.2-189.0 75.6 37.2 .1- 14.3 4.2 4.1
127.9-156.9 142.3 14.5 2.0- 14.9 8.4 6.5
31.8-168.0 74.0 37.9 1.3- 3.3 2.1 .6
29.2-128.3 74.9 32.2 .1- 14.3 4.9 4.8
43.2-189.0 96.7 65.5 3.2- 3.2 3.2 .0
77.1- 85.9 80.0 4.1 .3- .3 .3 .0
42.9-120.0 79.8 37.0 2.1- 2.1 2.1 .0
127.9-154.9 137.6 13.7 14.9- 14.9 14.9 .0
47.9- 47.9 47.9 .0 2.0- 2.0 2.0 .0
156.7-154.7 156.7 .0 2.0- 2.0 2.0 .0
56.0-233.2 93.2 35.4 2.6- 13.0 5.7 2.7
66.4-117.6 86.1 17.8 2.8- 8.7 5.2 2.0
56.0-233.2 100.2 45.8 2.6- 13.0 6.1 3.2
56.0-140.6 86.2 21.9 2.6- 8.7 5.1 2.0
134.8-233.2 184.0 49.2 12.4- tl.O 12.7 .3
56.0-117.6 88.6 25.5 2.6- 6.6 4.6 1.6
47.5-140.6 90.8 22.2 2.7- 8.7 6.4 2.0
**«**- .0 .0 .0 »•**•- .0 .0 .0
77.2- 93.0 82.5 7.4 4.1- 5.2 4.5 .5
60.9-107.9 76.6 22.2 3.2- 4.4 3.6 .6
134.8-134.8 134.8 .0 12.4- 12.4 12.4 .0
71.2- 71.2 71.2 .0 2.8- 2.8 2.8 .0
233.2-233.2 233.2 .0 13.0- 13.0 13.0 .0
-------
EPA UTILITY FGD SURVEY: JANUARY - PARCH 198C
SECTION A-1
COSTS FO" OPERATIONAL FGD SYSTEMS
JNIT DESCRIPTION
ALABAMA ELECTRIC COOP
179.0 MW (NET)
COST DtSCPIPTION
CAPACITY FACTOR, X
COST ELFMFNTS
PEPO&TFD
* * *
C,F,J
ADJUSTED
65
STANDARDIZED
ADJUSTED
65
ALLEGHENY POWER SYSTEM
PLEASANTS
1
519.0 MW (NET)
CAPACITY FACTOR, X 65
TOTAL CAPITAL, J/KU(YEAR> 1?8.Z
TOTAL ANNUAL, KILLS / KWH(YEAR ) 2.8(197?)
COST ELEMFNTS B,C,J,S
65
C)
C)
65
******(
r)
ARIZONA ELECTRIC POWER COOP
APACHE
2
195.3 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, t/KW(YEAR)
TOTAL ANNUAL, MI LLS / KWH ( Y E AR )
COST ELEMENTS
44 65
35.9(1977) **««**(
2.1(1978) ******(
C ,F ,H,J,L,S,
U.W.Y.Z
65
C) ***«»»(
0) *.....(
•:•)
")
ARIZONA ELECTRIC POWER COOP
APACHE
3
195.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, J/KUCYEAR)
TOTAL ANNUAL, MI LLS / KWH < Y EA R )
COST ELEMENTS
44
71 .8( 1977)
2.1(1978)
C,E,H,J,L,S,
U.W.Y.Z
65
65
0) *»»**•(
G) *«*..*<
ARIZONA PUBLIC SFRVICt
CHOLLA
1
119.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, I/KW(YEAR)
TOTAL ANNUAL, « I LLS / K WH ( Y E A R )
COST ELEMENTS
»5 65 65
52.0(1973) 56.0(1977) 56.0(1977)
2.2(1976) 2.6(1977) 2.3(1977)
P,C,E,S,U,X C,£,K,S,U,b C,E,K,S,U,W
ARIZONA PUBLIC SERVICE
CHOLLA
2
350.0 MW (NET)
BIG RIVERS ELECTRIC
GREEN
1
242.0 MW (NET)
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
378.0 MW (NET)
CENTRAL ILLINOIS PUBLIC SERV
•ifcWTON
1
617. J MW (NET)
CAPACITY FACTOR, X 65 65
COST ELEMENTS B,D,T,X
CAPACITY FACTOR, X *** 65
COST ELEMENTS B,C
CAPACITY FACTOR, X *** 65
COST ELEMENTS C,F,J,K
CAPACITY FACTOR, X ••* 65
COST ELEMENTS C,F,G
65
C) »**•««( r )
C) *«•«•*< :,
65
C) ******( pj
65
C) *••«*•< r)
65
COLORADO UTE ELtCTRIC ASSN.
CRAIG
2
447.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
*** 65
73.7(1979) «***.*(
•*.*•( 0) *****•(
65
0) **»***( QJ
0) ******( Q)
INDICATES COST FIGURES NOT YET AVAILABLE
*- 2
-------
EPA UTILITY fGD SURVEY: JANUARY - MARCH 1980
SECTION A-1
COSTS F0» OPERATIONAL FGD SYSTFMS
DESCRIPTION
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
COLUMBUS & SOUTHERN OHIO ELEC.
CONESVILLE
5
411.0 MW (NET)
COLUI«BUS 8 SOUTHERN OHIO ELEC.
CONESVI LLE
6
411.0 MW (NET)
OUOUESNE LIGHT
ELlAltA
1-*
510.0 MW (NET)
DJQUESNE LIGHT
PHILLIPS
1-6
410.0 MW (NET)
CAPACITY FACTOR, x
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, I* I LLS / KWH ( Y E A R )
COST ELEMENTS
CAPACITY FACTOR, X
TO T A 1 f A D T T A 1 t^VUfVCAOt
1 U 1 ff (B IMrJIHLf '/RWlltAnJ
T fl T A 1 AUhllAI MTII C4tfLJIjfVCAD>
1 U 1 P L AnnUALt rilLLj/KWnlTtAHJ
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, J/KW(YEAR)
TOTAL ANNUAL, MI LLS / KWH ( Y E AR )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, I/KW(YFAR)
TOTAL ANNUAL, MI LLS / KWH( Y E AR )
COST ELEMENTS
48
55.5(1975)
5.8(1978)
B,C,J,M,S,U,
W.X.Y
48
cc C / 1 Q 7 Q \
3 3 • j t iv/ej
Sfl / 1 O ? fl \
.Ol 1 " f C /
B,C,JI,M,S,U,
W.X.Y
64
113.4(1976)
8.6(1977)
B.D.F.l.J.M,
T.V.X.Y
7C
1"6. 9(1972)
7.8(1977)
B.D.F.J.J.f".
T.V.X.V
65
7f5. 7(1977)
7.4(1977)
C.E.J.M.S.U,
W,Y
65
7^ 7f4f>77\
''• f \ I V t I t
******( C)
C,E,J ,M,S ,U,
W,Y
65
127.1(1977)
7.8(1977)
C.E.I.J ,M,S ,
U,Y
65
141.6(1977)
8.6(1977)
C,E,1,J,M,S ,
U,Y
65
70.7(1977)
7.4(1977)
C.E.J.M.S.U,
W,Y
65
65
127.1(1977)
7.5(1977)
C.E.I ,J ,I",S,
U,Y
65
140.6(1977)
8.2(1977)
C, E,I ,J ,*,S,
U,Y
INDIANAPOLIS POtfER 8 LIGHT
PETERSPURG
3
532.0 MW (NET)
CAPACITY FACTOR, X ***
TOTAL CAPITAL, J/KW(YEAR) 99.5(1976)
TOTAL ANNUAL, MILLS/KWH(YEAR) ***.**{ C)
COST ELEMENTS C,F,G,J,M
65 65
110.6(1977) 110.6(1977)
6.6(1977) 7.4(1977)
C,E,G,J,M,S, C,E,G,J ,l", S,
U,W,Y U,W,Y
KANSAS CITY POWER R LIGHT
HAWTHORN
90.0 MW (NET)
CAPACITY FACTOR, X 14
TOTAL CAPITAL, J/KW(YEAR) 29.12(1972)
TOTAL ANNUAL, MILLS/KWH(YEAR) 8.4(1977)
COST ELEMENTS B,D,F,T,X
65 65
87.2(1977) 87.2(1977)
4.3(1977) 4.4(1977)
B, C.E.J, K,S, B,C,E ,J ,K ,S,
U.W.X
U,W,X
KANSAS CITY POWER 8 LIGHT
HAWTHORN
4
90.0 MW (NET)
CAPACITY FACTOR, X **»
TOTAL CAPITAL. f/KW(YEAR) 29.i2(1972)
TOTAL ANNUAL, MILLS/KWH(YEAR) 8.4(1977)
COST ELEMENTS B.D.F^T.X
65 65
87.2(1977) 87.2(1977)
4.3(1977) 4.4(1977)
B.C.E.J.K.S. B.C.E.J.K.S,
U.W.X U.W.X
KANSAS CITY POWER « LIGHT
tA CYGNE
874. 0 MW (NET)
CAPACITY FACTOR, X 42
TOTAL CAPITAL, S/KW(YEAR) 53.6(1972)
TOTAL ANNUAL. MILLS/KWH(YEAR) 1.3(1978)
COST ELEMENTS T
65
68.0(1977)
3.8(1977)
65
68.0(1977)
3.9(1977)
C,E.J,K,S,U
KANSAS POWER 8 LIGHT
JEFFREY
1
540.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MI LLS/ KWH ( YE AR )
COST ELEMENTS
*** 65
56.8(1978) ***«**(
*-*****.{ 1978) •*****(
B.C
65
***•*.<
******(
0)
0)
KENTUCKY UTILITIES
6REEN RIVER
1-3
64.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL. MI LLS/KWH < YEAR)
COST ELEMENTS
16 65 65
70.3(1975) 77.5(1977) 77.5(1977)
U.3(1977) 2.7(1977) 5.2(1977)
B.C.E.J.S.U, C.E.J.S.U.W C.E.J.S.U.W
w
****** INDICATES COST FIGURES NOT VET AVAILABLE
»- 21
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH 198C
SFCT10N A-1
COSTS FOP OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION COST DESCRIPTION
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
LOUISVILLE GAS ft ELECTRIC
CANE RUN
1>
1P6.Q MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, 1/KW(Y?AR)
TOTAL ANNUAL, * ILLSIKWH(Y£AR)
COST ELEMENTS
55 65 65
66.5(1575) 6?.6(1977) SG.6(1C77)
2.7<1977> 5.8(1977) 6.2(1577)
C,F,H,J,Q,T C,E,H,JtK,0, C,E,HtJ,K,0,
S,U,W S.U.U
LOUI
CANE
203
SVILLE GAS & ELECTRIC
RUN
.n
MW (NET)
LOUISVILLE G«S & ELECTRIC
299
LOUI
3
442
.0
MW (NET)
SVILLE GAS & ELECTRIC
.0
MW (NET)
LOUISVILLE GAS t, ELECTRIC
PADDY'S RUN
6
72
.0
MW (N?T)
>UNNKOTA POWER COOPERATIVE
11LTON R. YOUNG
2
405
.0
MW (NET)
CAPAC
TOTAL
TOTAL
COST
ITY FACTOR, X
CAPITAL, $/KW( YEAR)
ANNUAL .
ELEMENTS
CAPACITY FACTOR, 3!
COST
ELEMENTS
CAPACITY FACTOR, I
TOTAL
COST
CAPAC
TOTAL
TOTAL
COST
CAPAC
TOTAL
TOTAL
COST
ANNUAL ,
ELEMENTS
MLLS/KWH(YEAP)
ITY FACTOR, X
CAPITAL, 5/KW ( YEAR )
ANNUAL ,
ELEMENTS
ITY FACTOR, X
CAPITAL, $/KW(YEAR)
ANNUAL ,
ELEMENTS
***
TfF
,HrJ
* * *
c 7 Q / 1 Q 77 %
C,E
W
.M^M.S.V,
1C
/ 2 A f 1 Q 7F )
1.3(1°78)
c,s
* * *
52.8(1973)
C,E
** *
95.9(1976)
C.f
,H,P
65
67. 5(1977)
u,w
65
65
65
76.4 (1977)
C,£,S,U,W
65
93.0(1977)
C .E.H.M.p.S ,
U.W
65
67.
5.
U.W
65
65
* * * * *
65
76.
6.
C.E.S
65
93.
5.
C.E.H
U.W
5(
6(
*(
4(
1977)
1°77)
K ^
r )
}
C )
1977)
4(T977)
.U
C(
2 (
.n
.W
1977)
1"77)
• P.S.
MONTANA POWER
COLSTRIP
1
360.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
76 65 65
77.1(1975) 77.2(1977) 77.2(1977)
.3(1977) 4.1(1977) 4.1(1977)
B,C,E,J,P,T C,E,J,K,P,S, C,E,J,K,P,s,
U.W U,W
MONTANA POWER
COLSTRIP
2
360.0 MW (NET)
CAPACITY FACTOR, X 76
TOTAL CAPITAL, S/KH(YEAR) 77.1(1975)
TOTAL ANNUAL, MILLS/KWH(YEAR ) .3(1977)
COST ELEMENTS B,C,Ei,J,P,T
65 65
77.2(1977) 77.2(1977)
4.1(1977) 4.1(1977)
C,E,J,K,P,S, C,E,J,K,p,s,
U.W U.W
NEVADA POWER
REID GARDNER
1
125.0 MH (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KU(VEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR )
COST ELEMENTS
67 65 65
42.9(1973) 60.9(1977) 60.9(1977)
2.X1P77) 3.2(1977) 3.4(1977)
B,0,E#P,S,U, B.D.E.P.S.U, B.D.E.P.S.U,
W,X W,X w,X
NEVADA POWER
REID GARDNER
2
125.0 My (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, I/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
67 65 65
42.9(1973) 60.9(1977) 60.9(1977)
2.t(1977) 3.2(1977) 3.4(1977)
B,0,E,P,S,U, B,0,E,P,S,U, B.D.E.P.S.U,
w.x u.x w,x
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 22
-------
EPA UTILITY FGO SURVEY: JANUARY - MARCH
SECTION A-1
COSTS FOR OPERATIONAL FGO SYSTEMS
jNJT DESCRIPTION
NEVADA POWER
REID GARDNER
125.0 MW FACTOR, X
TOTAL CAPITAL, S/KW(»EAR)
TOTAL ANNUAL, M I LLS / KWH ( Y E AR )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, f/KW(YEAR)
TOTAL ANNUAL, P. I LLS / KWH < Y EA R )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS /KWH (Y EA R )
COST ELEMENTS
CAPACITY FACTOR, X
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MI LLS / KWH (Y EAR )
COST ELEMENTS
REPORTED
67
113.6(1975)
2.1(1977)
B,C,?.,L,S,U,
u,x
77
156. 9( 1«76)
U. 9(1976)
P.C.E ,'L,N,S,
u,w,xrz
'3
47.9(1972)
2.0(1977)
B.C, JyS.U.X,
Z
'3
47.9(1972)
2.0(1977)
B,C,J,S,U,X,
Z
** *
C,E,J
40
120.6(1975)
14.3(1977)
B.C.E ,G,I ,L,
s.u.w.x
ADJUSTED
65
107.9(1977)
4.4(1977)
B,C,E,L,S,U,
w,x
65
134.8(1977)
12.4(1977)
C.E.L.N.S ,U,
HtZ
65
71 .2(1977)
2.8(1977)
C,E,J,K,S,U,
W
65
71 .2(1977)
2.8(1977)
C.E.J.K ,S ,U,
W
65
65
102.1(1977)
?. 7(1977)
C,E,G,I,M,S,
U.W
STANDARDIZED
ADJUSTED
65
107.9(1977)
5.0(1977)
B.C.E, L.S.U,
W,X
65
134.8(1977)
11.0(1^77)
C,E,L,N,5,U,
W,Z
65
71. 2( 1977)
3.3(1977)
C,E,J,K,S,U,
U
65
71.211977)
3.3(1977)
C,E,J,K,S,U,
W
65
65
102.1(1977)
10.8(1977)
C.E,G,I.P,S,
U.W
PENNSYLVANIA POwER
3RUCE MANSFIELD
2
917.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, J/KW(YEAR)
TOTAL ANNUAL, MI LLS/KWH(YEAR)
COST ELEMENTS
40 65 65
1?C.6(1975) 102.1(1977> 102.1(1977)
14.3(1977) ?.7(1977) 10.8(1977)
B,C,E,G,I,L, C,E,G,I,M,S, C,E,6,1,W,S,
s,u,wrx u,w u.w
PHILADELPHIA ELECTRIC
EDDYSTONE
1A
120.0 MW (NET)
CAPACITY FACTOR, X *** 65
TOTAL CAPITAL, $/KW(YEAR) 156.7(1972) 233.2(1977)
TOTAL ANNUAL, MILLS/KWh(YEAR) 2.0(1972) 13.0(1977)
COST ELEMENTS 0,F,N',P C.E.N.P
65
233.2(1977)
12.4(1977)
C.E.N.P
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
1
361 .0 MU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MI LLS /KWH (Y EAR )
COST ELEMENTS
**« 65
1?7. 9(1977) «*«***(
*.*...< C) ••**..<
».C,E ,N
C)
*«,„»«(
*•***.<
0)
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
350.0 MW (NET>
CAPACITY FACTOR, X
TOTAL CAPITAL, J/KW(YEAR)
TOTAL ANNUAL, MI LLS /KWH
-------
EP» UTILITY F&D SURVEY: JANUARY - MARCH 1980
SECTION A-1
COSTS FOR OPERATIONAL FGO SYSTEMS
U*IT DESCRIPTION
COST DESCRIPTION
REPORTED
---COST--
ADJUSTED
STANDARDIZED
ADJUSTED
SALT RIVER PROJECT
CORONADO
1
280.0 MW (NET)
CAPACITY FACTOR. X *** 65 65
TOTAL CAPITAL, */KW(YEAl> '4.Q(197fi) ***•*«( 0) *.....(
TOTAL ANNUAL, MILLS/KWH(YFAR) »*****( C) *»****( C) *****»(
COST ELEMENTS C,F
C)
f )
SOUTH CAROLINA PUBLIC SERVICE CAPACITY FACTOR, X 80 65 65
JINYAH TOTAL CAPITAL, $>KW(YEAR) 47.4(1976) 66.4(1977) 66.4(1977)
2 TOTAL ANNUAL, MlLLS/KUH(YEAR) 1.6(1975) ?.9(1977) 3.2(1977)
14Q.O MH (NET) COST ELEMENTS C,F,J,M,S,V C,E,J,K,N,S, C,E,J,K,K,S,
U,W U,W
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW
1
124.0 MW (NET)
CAPACITY FACTOR, X ***
TOTAL CAPITAL, $/KW(YEAR> 37.4(1975)
TOTAL ANNUAL, MILLS/KWH(YEAR) *•*•**( C)
COST ELEMENTS C,E
65
65
SOUTH MISSISSIPPI ELEC PHR
R.D. MORROW
2
124.0 MU (NET)
CAPACITY FACTOR, X «** 65 65
TOTAL CAPITAL, J/KW(YEAR) 37.4(1975) ••****( C) ***«»•(
TOTAL ANNUAL, MILLS/KWH(YEAR) **«***( 0> **•***( Q> ***•••{
COST ELEMENTS C,E
C)
SOUTHERN ILLINOIS POWER COOP CAPACITY FACTOR, X 65 65 65
MARION TOTAL CAPITAL, */KW(YEAR) 152.7(1978) *»***•( 0) **•*•*( P)
4 TOTAL ANNUAL, MILLS/KUH
COST ELEHENTS
"0 65 65
85.9(1978) *«•*.*( cj **«...( r)
1.4(1978) **•*..( C) ****..( Q)
*««... INDICATES COST FIGURES NOT YET AVAILABLE
A- 24
-------
tPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION A-2
COSTS FOR NON-OPERATIONAL FGD SYSTEMS
tfMJT DESCRIPTION
COST DESCRIPTION
REPORTED
-—COST—-
ADJUSTED
STANDARDIZED
ADJUSTED
BASIN ELECTRIC POWER COOP
RIVER
MW KW(YEAR) 82.5(1972) ••*•**< 0) **«•*•( C)
TOTAL ANNUAL, MILLS/KWH(YEAR) ******< C) ******( C) *«**•*< 0)
COST ELEMENTS A.C.E.M.N
POTOMAC ELECTRIC POWER
0JCKERSON
.0 MW (NET)
45
CAPACITY FACTOR, X ***
TOTAL CAPITAL, $/KW(YEAR) 68.QO978) **.*„.(
TOTAL ANNUAL, MI LLS /KWH< Y EAR ) •*****< 0)
COST ELEMENTS A,C,E,M
0)
Q)
.,
)
PUBLIC SERVICE OF COLORADO
tfALMONT
*166.0 MW (NET)
.,
CAPACITY FACTOR, X .
TOTAL CAPITAL, S/KH(YEAR) 87.0(1974) ******< 0) **•**•( D
TOTAL ANNUAL, MI LLS/KWH( YEAR ) *»****( Q) **••••< 0) *****•( 0)
COST ELEMENTS B ,C
****** INDICATES COST FIGURES NOT YET AVAILABLE
*- 25
-------
EPA UTILITY FGD SURVEY: JANUARY - MARCH 1980
SECTION A-2
COSTS FOR NON-OPERATIONAL FGD SYSTFHS
COST
UNIT DESCRIPTION COST DESCRIPTION REPORTED ADJUSTED STANDARDI2ED
ADJUSTED
SALT RIVER PROJECT CAPACITY FACTOSt X *** 65 65
CORONADO TOTAL CAPITALt J/KW(YEAR> 74.0(1978) ******( g) ******( rj)
Z TOTAL ANNUALt MILLS/KWH(YEAR) *****»( 0) **•***( C> ******( C)
280.0 HW (NET) COST ELEMENTS C,E
INDICATES COST FIGURES NOT VET AVAILABLE
A- 26
-------
APPENDIX B
DEFINITIONS
B-l
-------
DEFINITIONS
Boiler Commercial Service Date
Byproduct
Commercial Service Date
(FGD System)
Company Name
Disposal
Efficiency:
Particulate Matter
SO,
Date when boiler and auxiliary
equipment (including FGD sys-
tem for new boilers) has met
initial supplier guarantees
and begins to contribute elec-
trical power to the power
grid.
The nature (e.g. elemental
sulfur, sulfuric acid) and
disposition (e.g. stockpile on
site, marketed) of the end
product by systems that gen-
erate a saleable product.
Date when the FGD system suc-
cessfully completes compliance
testing and the utility is
satisfied that the system
meets supplier contractual
guarantees.
Name of corporation as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - as space permits.
Disposal method for throwaway
product systems producing
sludge including: stabilized
or unstabilized sludge, inter-
im and final disposal sites
and disposal type (minefill,
landfill, etc.) as well as
disposal location.
The actual percentage of par-
ticulate matter removed by the
emission control system (me-
chanical collectors, ESP, or
fabric filter and FGD) from
the untreated flue gas.
The actual percentage of SO2
removed from the flue gas by
the FGD system.
B-2
-------
FGD Viability Indexes
Availability Index
Reliability Index
Several parameters have been
developed to quantify the vi-
ability of FGD system technol-
ogy. Various terms such as
"availability," "reliability,"
"operability," and "utiliza-
tion" are used to accurately
represent the operation of any
FGD system during a given per-
iod. The above-mentioned pa-
rameters are defined below and
discussed briefly. The objec-
tives of this discussion are
to make the reader aware that
several different definitions
are being used and to select
appropriate parameters that
can be used for reporting pur-
poses so that reasonably con-
sistent comparisons can be
made.
Hours the FGD system is avail-
able for operation (whether
operated or not) divided by
hours in period, expressed as
a percentage. This parameter
tends to overestimate the vi-
ability of the FGD system be-
cause it does not penalize for
election not to operate the
system when it could have been
operated. Boiler downtime may
tend to increase the magnitude
of the parameter because FGD
failures generally cannot oc-
cur during such periods.
Hours the FGD system was oper-
ated divided by the hours the
FGD system was called upon to
operate, expressed as a per-
centage. This parameter has
been developed in order not to
penalize the FGD system for
elected outages, e.g., periods
when the FGD system could have
been run but was not run be-
cause of chemical shortages,
lack of manpower, short dura-
tion boiler operations, etc.
The main problem in using this
B-3
-------
FGD Operability Index
FGD Utilization Index
End Product
Saleable
formula is the concise determi-
nation whether or not the sys-
tem was "called upon to oper-
ate" during a given time per-
iod. In addition, an undefined
value can result when the FGD
system is not called upon to
operate for a given period
(e.g., turbine or boiler out-
age when FGD system is avail-
able) .
Hours the FGD system was oper-
ated divided by boiler operat-
ing hours in period, expressed
as a percentage. This param-
eter indicates the degree to
which the FGD system is actu-
ally used, relative to boiler
operating time. The parameter
is penalized when options are
exercised not to use the FGD
system in periods when the
system is operable. In addi-
tion, an undefined value can
result when the FGD system is
not called upon to operate for
a given period (e.g., turbine
or boiler outage when FGD sys-
tem is available).
Hours that the FGD system op-
erated divided by total hours
in period. This parameter is
a relative stress factor for
the FGD system. It is not a
complete measure of FGD system
viability because the parameter
can be strongly influenced by
conditions that are external
to the FGD system (e.g., in-
frequent boiler operation will
lower the value of the parame-
ter although the FGD system
may be highly dependable in
its particular application).
The S02 removed from the flue
gas is recovered in a usable
or marketable form (e.g., sul-
fur, sulfuric acid, gypsum,
B-4
-------
ammonium sulfate, sodium sul-
fate).
Throwaway
Energy Consumption, %
Equivalent Scrubbed Capacity
(ESC)
FGD Status:
Category 1
Category 2
Category 3
Cateogry 4
Category 5
The SC-2 removed from the flue
gas is not recovered in a us-
able or marketable form and
resulting sulfur-bearing waste
products must be disposed in
an environmentally acceptable
fashion.
The percentage of gross unit
electrical generating capacity
consumed by the FGD system, as
defined by the following equa-
tion:
[Net MW w/o FGD - Net MW w/FGD]/
Gross unit rating]
The effective scrubbed flue
gas in equivalent MW based on
the percent of flue gas scrubbed
by the FGD system.
Operational - FGD system is in
service removing SC>2.
Under construction - ground
has been broken for installa-
tion of FGD system, but FGD
system has not become opera-
tional.
Planned, Contract Awarded -
contract has been signed for
purchase of FGD system but
ground has not been broken for
installation.
Planned, Letter of Intent
Signed - letter of intent has
been signed, but legal con-
tract for purchase has not
been awarded.
Planned, Requesting/Evaluating
Bids - bid requests have been
released but no letter of in-
tent or contract has been is-
sued.
B-5
-------
Category 6
Category 7
Category 8
Fuel Firing Rate - TPH
General Process Type
Initial Start-Up (FGD System)
New
Plant Name
Process Additives
Considering only FGD Systems -
an FGD system is proposed as a
means to meet an S02 regulation,
Considering an FGD system as
well as alternative methods.
Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended in-
definite period of time.
Boiler fuel firing rate in
terms of tons per hour at max-
imum continuous load.
The manner in which the SC>2
from the flue gas is collected,
e.g., wet scrubbing, spray
drying, dry adsorption.
Date when flue gas first
passes through any component
of the FGD system (or is
scheduled to do so).
FGD unit and boiler were de-
signed at the same time or
space for addition of an FGD
unit was reserved when boiler
was constructed.
Unit identification as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities/ McGraw-Hill - Current
Edition - or as indicated by
utility representative for in-
stallations in planning stages.
A chemical compound or element
which is added to the process
or normally found with the
main process reagent in small
quantities (e.g., Mg, adipic
acid) to promote improved
process operation (e.g., scale
reduction, increased SC>2
removal efficiency).
B-6
-------
Process Type
Regulatory Class
Retrofit
Spare Capacity Index - %
Spare Component Index
System Supplier
Total Controlled Capacity
(TCC)
Company name if process is
patented. Generic name if
several companies have similar
processes (e.g., Lime, Lime-
stone, Wellman Lord, Thorough-
bred 121) .
A. New boiler constructed
subject to Federal New
Source Performance Stan-
dards (NSPS), 8/17/71.
B. Existing boiler subject
to State Standard that is
more stringent than the
NSPS, 8/17/71.
C. Existing boiler subject
to State Standard that is
equal to or less stringent
than NSPS, 8/17/71.
D. Other (unknown, undeter-
mined) .
FGD unit will be/was added to
an existing boiler not specif-
ically designed to accommodate
FGD unit.
The summation of the individ-
ual component capacities (%)
minus 100%.
The equipment spare capacity
index (%) divided by the indi-
vidual component capacity (%).
A firm that fabricates and
supplies flue gas desulfuriza-
tion systems.
The gross rating (MW) of a
unit brought into compliance
with FGD, regardless of the
percent of flue gas treated at
the facility. In the case of
prototype and demonstration
FGD systems, this figure will
be identical to the Equivalent
Scrubbed Capacity rather than
B-7
-------
Unit Rating
Gross
New w/FGD
Net w/o FGD
the gross unit rating if the
system is not meant to bring
the facility into compliance
with S02 emission standards.
Operational - Maximum contin-
uous gross generation capacity
in MW; Preoperational - maxi-
mum continuous design genera-
tion capacity in MW.
Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
inclusive of emission control
systems.
Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
exclusive of emission control
systems.
B-8
-------
APPENDIX C
TABLE OF UNIT NOTATION
C-l
-------
TABLE OF UNIT NOTATION
Classification
Area
Concentration
Flow
Heat Content
Length
L/G Ratio
Mass/Weight
Pressure
Temperature
Volume
English Unit
Acre
Square foot
Grains per standard
cubic foot
Parts per million
Pounds per million
Btu
Actual cubic feet
per minute
Gallons per minute
Pounds per minute
Ton per day
Ton per hour
Btu per pound
Foot
Inch
Mile
Gallons per
thousand actual
cubic feet
Pound
Ton
Inches of water
Degree Fahrenheit
Cubic feet
Acre-feet
Symbol
acre
ft2
gr/scf
ppm ,
lb/10 Btu
ft /mm
(actual )
gal/min
Ib/min
t/day
t/h
Btu/lb
ft
in
mi
gal/1000
ft3
(actual )
Ib
t
in. H20
"F
ft3
Acre-f t
Survey Report
Nota t ion
ACRE
SQ.FT
GR/SCF
PPM
LB/MMBTU
ACFM
GPM
LB/MIN
TPD
TPH
BTU/LB
FT
IN
MI
GAL/1000ACF
LB
T
IN. H20
F
CU.F
ACRE-FT
ASTM/SI Unit
Square meter
Square meter
Grams per cubic meter
Parts per million
Nanograms per joule
Cubic meters per
second
Liters per second
Kilogram per second
Metric ton per day
Metric ton per hour
Joules per
gram
Meter
Centimeter
Kilometer
Liters per cubic
meter
Kilogram
Meqagram
Kilopascal
Degree Celsius
Cubic meter
Cubic meter
Symbol
M2
M2
g/m3
ppm
ng/J
m3/s
liter/s
kg/s
M t/d
M t/h
J/q
m
cm
km
liter/m
kg
Mg
kPa
°C
m
rn
Survey Report
Notation
SQ.M
SQ.M
G/CU.M
PPM
NG/J
CU.M/S
LITER/S
KG/S
M T/D
M T/H
J/G
M
CM
KM
LITER/CU.M
KG
MG
KPA
C
CU.M
CU.M
n
i
to
-------
TECHNICAL REPORT DATA
(Please read Inunctions on the reverse before completing)
REPORT NO.
PA-600/7-80-029b
2.
3. RECIPIENT'S ACCESSION NO.
TITLE AND SUBTITLE
PA Utility FGD Survey: January-March 1980
. REPORT DATE
May 1980
6. PERFORMING ORGANIZATION CODE
AUTHOR(S)
M. Smith, M. Melia, and N.Gregory
8. PERFORMING ORGANIZATION REPORT NO.
PN 3570-1-Z
PERFORMING ORGANIZATION NAME AND ADDRESS
PEDCo Environmental, Inc.
.1499 Chester Road
Cincinnati, Ohio 45246
10. PROGRAM ELEMENT NO.
INE828
11. CONTRACT/GRANT NO.
68-01-4147, Task 143
2. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
Quarterly; 1-3/80
14. SPONSORING AGENCY CODE
EPA/600/13
5.SUPPLEMENTARY NOTES jERL-RTP project officer is Norman Kaplan, Mail Drop 61, 919/
541-2556. The report supplements report EPA-600/7-80-029a.
16. ABSTRACT
The report is the first of three supplements updating the October-December
1979 report (EPA-600/7-80-029a) and should be used in conjunction with it. The
report, generated by a computerized data base system, presents a survey of oper-
ational and planned domestic utility flue gas desulfurization (FGD) systems, oper-
ational domestic particle scrubbers, and Japanese coal-fired utility boiler FGD
installations. It summarizes information contributed by the utility industry, process
suppliers, regulatory agencies, and consulting engineering firms. Domestic FGD
systems are tabulated alphabetically by development status (operational, under con-
struction, or in planning stages), utility company, process supplier, process, and
waste disposal practice. It presents data on boiler design, FGD system design,
fuel characteristics , and actual performance. It includes unit by unit dependability
parameters and discusses problems and solutions associated with the boilers and
FGD systems. Process flow diagrams and FGD system economic data are appended.
7.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.IDENTIFIERS/OPEN ENDED TERMS
c. COSATi Field/Group
Pollution
Flue Gases
Desulfurization
Electric Utilities
Waste Disposal
Boilers
Maintenance
Pollution Control
Stationary Sources
Utility Boilers
13 B
2 IB
07A,07D
15E
13A
"\k. DISTRIBUTION STATEMENT
Release to Public
19. SECURITY CLASS (ThisReport}
Unclassified
21. NO. OF PAGES
258
20. SECURITY CLASS (Thispage)
Unclassified
22. PRICE
EPA Form 2220-t (9-73)
C-3
------- |