&EPA
United States
Environmental Protection
Agency
Industrial Environmental Research
Laboratory
Research Triangle Park NC 27711
EPA-600/7-79-022f
October 1979
EPA Utility FGD Survey:
July-September 1979
Interagency
Energy/Environment
R&D Program Report
-------
RESEARCH REPORTING SERIES
Research reports of the Office of Research and Development, U.S. Environmental
Protection Agency, have been grouped into nine series. These nine broad cate-
gories were established to facilitate further development and application of en-
vironmental technology. Elimination of traditional grouping was consciously
planned to foster technology transfer and a maximum interface in related fields.
The nine series are:
1. Environmental Health Effects Research
2. Environmental Protection Technology
3. Ecological Research
4. Environmental Monitoring
5. Socioeconomic Environmental Studies
6. Scientific and Technical Assessment Reports (STAR)
7. Interagency Energy-Environment Research and Development
8. "Special" Reports
9. Miscellaneous Reports
This report has been assigned to the INTERAGENCY ENERGY-ENVIRONMENT
RESEARCH AND DEVELOPMENT series. Reports in this series result from the
effort funded under the 17-agency Federal Energy/Environment Research and
Development Program. These studies relate to EPA's mission to protect the public
health and welfare from adverse effects of pollutants associated with energy sys-
tems. The goal of the Program is to assure the rapid development of domestic
energy supplies in an environmentally-compatible manner by providing the nec-
essary environmental data and control technology. Investigations include analy-
ses of the transport of energy-related pollutants and their health and ecological
effects; assessments of, and development of, control technologies for energy
systems; and integrated assessments of a wide range of energy-related environ-
mental issues.
EPA REVIEW NOTICE
This report has been reviewed by the participating Federal Agencies, and approved
for publication. Approval does not signify that the contents necessarily reflect
the views and policies of the Government, nor does mention of trade names or
commercial products constitute endorsement or recommendation for use.
This document is available to the public through the National Technical Informa-
tion Service, Springfield, Virginia 22161.
-------
EPA-600/7-79-022f
October 1979
EPA Utility FGD Survey:
July-September 1979
by
M. Smith and M. Melia
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
Contract No. 68-01-4147
Task No. 79
Program Element No. EHE624
EPA Project Officers:
N. Kaplan J.C. Herlihy
Industrial Environmental Research Laboratory Division of Stationary Source Enforcement
Office of Environmental Engineering and Technology Office of Enforcement
Research Triangle Park, NC 27711 Washington. D.C. 20460
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Research and Development
Washington, DC 20460
-------
NOTICE
The report, (prepared by PEDCo Environmental, Inc., Cincin-
nati, Ohio, under EPA Contract No. 68-01-4147, Task No. 113) 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; regu-
latory personnel; and others. Neither EPA nor the designated
contractor warrants the accuracy or completeness of information
contained in this report.
This report is the third of three supplementary issues to
the December 1978 - January 1979 report. Supplementary issues
are cumulative, so that it is necessary to retain only the latest
issue and the December 1978 - January 1979 report (EPA-600/7-79-
022c).
Initial distribution of the report (generally, one copy per
company) is limited to organizations and individuals indicating
a specific interest in the field of FGD technology. Additional
copies of this report and succeeding issues can be purchased from
National Technical Information Service, Springfield, Virginia
22151.
11
-------
CONTENTS
Notice
Tables
Executive Summary and Highlights
Section 1 Summary List of FGD Systems
Section 2
Section 3
Status of FGD Systems
Design and Performance Data for Operational
FGD Systems
Alabama Electric
Tombigbee 2
Tombigbee 3
Allegheny Power System
Pleasants 1
Arizona Electric Power
Apache 2
Apache 3
Arizona Public Service
Cholla 1
Cholla 2
Central Illinois Light
Duck Creek 1
Central Illinois Public Service
Newton 1
Columbus and Southern Ohio Electric
Conesville 5
Conesville 6
Cooperative Power Association
Coal Creek 1
Duquesne Light
Elrama 1-4
Phillips 1-6
Indianapolis Power and Light
Petersburg 3
Kansas City Power and Light
Hawthorn 3
Hawthorn 4
LaCygne 1
Page
ii
vii
viii
1
6
33
33
35
38
40
42
44
46
48
52
54
56
58
60
63
66
68
70
72
ill
-------
CONTENTS (continued)
Kansas Power and Light
Jeffrey 1 75
Lawrence 4 77
Lawrence 5 79
Kentucky Utilities
Green River 1-3 81
Louisville Gas and Electric
Cane Run 4 83
Cane Run 5 85
Cane Run 6 87
Mill Creek 3 90
Paddy's Run 6 92
Minnkota Power Cooperative
Milton R. Young 2 94
Montana Power
Colstrip 1 97
Colstrip 2 99
Nevada Power
Reid Gardner 1 101
Reid Gardner 2 103
Reid Gardner 3 106
Northern Indiana Public Service
Dean H. Mitchell 11 108
Northern States Power
Sherburne 1 110
Sherburne 2 112
Pennsylvania Power
Bruce Mansfield 1 114
Bruce Mansfield 2 116
Philadelphia Electric
Eddy stone 1A 118
Public Service Company of New Mexico
San Juan 1 120
San Juan 2 122
South Carolina Public Service Authority
Winyah 2 124
South Mississippi Electric
R.D. Morrow 1 125
R.D. Morrow 2
Southern Illinois Power Coop
Marion 4
Southern Indiana Gas and Electric
A.B. Brown 1
Springfield City Utilities
Southwest 1 ,~
Tennessee Valley Authority
Shawnee 10A
Shawnee 10B
Widows Creek 8
iv
-------
CONTENTS (continued)
Page
Texas Utilities
Martin Lake 1 144
Martin Lake 2 146
Martin Lake 3 148
Monticello 3 151
Utah Power and Light
Hunter 1 153
Huntington 1 155
Summary of FGD Systems by Company 157
Summary of FGD'Systems by System Supplier 158
Summary of FGD Systems by Process 160
Summary of Operating FGD Systems by Process
and Unit 161
Summary of End-Product Disposal Practices
for Operational FGD Systems 163
Summary of FGD Systems in Operation 165
Summary of FGD Systems Under Construction 168
Summary of Contract Awarded FGD Systems 170
Summary of Planned FGD Systems 171
Total FGD Units and Capacity (MW) Installed
by Year 173
Design and Performance Data for Operational
Particulate Scrubbers 174
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-24
Appendix B FGD Process Flow Diagrams B-l
Section 4
Section 5
Section 6
Section 7
Section 8
Section 9
Section 10
Section 11
Section 12
Section 13
Section 14
Appendix A
v
-------
CONTENTS (continued)
page
Appendix C Definitions C-l
Appendix D Glossary of Units D-l
vx
-------
TABLES
No. Page
I Number and Total Capacity of FGD Systems viii
II Summary of Changes, Third Quarter 1979 x
III Performance of Operational Units, Third Quarter 1979 xi
VII
-------
EXECUTIVE SUMMARY
This report is prepared quarterly (every three months) by PEDCo
Environmental, Inc., under contract to the Industrial Environ-
mental Research Laboratory/Research Triangle Park and the Division
of Stationary Source Enforcement of the U.S. Environmental Pro-
tection 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 September 1979. Table II lists the units that have
changed status during the third quarter 1979, 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
56
42
19
0
18
26
161
Total
Controlled
Capacity, MW*
21,104
18,485
9,713
13,033
14,000
76,335
Equivalent
Scrubbed ,
Capacity, MW
19,387
17,250
9,415
12,183
13,930
72,165
Total Controlled Capacity (TCC) is the summation of the gross
unit capacities (MW) brought into compliance with FGD systems
regardless of the percent of the flue gas scrubbed by the FGD
system(s).
Equivalent Scrubbed Capacity (ESC) is the summation of the ef
fective scrubbed flue gas in equivalent MW based on the percent
of the flue gas scrubbed by the FGD system(s).
viii
-------
r
ABSORBERS
CENTRIFUGE
REHEATER
THICKENER
WATER
LOOP
|
REAG
PREPAR
EQUIP
Figure 1. Computerized data base structure diagram.
-------
TABLE II. SUMMARY OF CHANGES: FGD SUMMARY REPORT
THIRD QUARTER 1979
FGD status report
6/30/79
Allegheny Power System
Mitchell 3
Central 'Illinois Public Serv.
Newton 1
Cooperative Power Association
Coal Creek 1
Gulf Power
Scholz 1,2
Hoosier Energy
Merom 1
Houston Lighting & Power Co.
U. A. Parish 8
Montana Power
Colstrip 3
Colstrip 4
Muscatine Power & Light
Muscatine 9
New York State Elec. & Gas
Somerset
Niagara Mohawk Power Coop.
Charles R. Huntley 66
Northern States Power
Sherburne 3
Philadelphia Electric
Cromby
Eddystone IB
Eddystone I
Tampa Electric
Big Bend 4
Tennessee Valley Authority
Cumberland
TOTAL
Operational
No.
55
+1
+1
-1
56
MW*
18,466a
617
327
23
19,387
Under
construction
No.
42
-1
-1
-1
+1
+1
+1
42
MW*
17,135
617
327
441
700
700
100
17,250
Contract
awarded
No.
16
+1
+1
+1
-1
-1
-1
+1
+1
+1
19
MW*
8,938
300
441
512
700
700
100
150
240
334
9,415
Letter
of Intent
No.
2
-1
-1
0
MW*
1,100
860
240
Requesting/
eyal. bids
No.
16
-1
+1
+1
+1
18
MW*
11,200
512
160
860
475
12,183
Considering
FGO
No.
31
-1
-1
+1
-1
-1
-1
-1
26
MW*
15,079a
300
160
870
150
334
475
600
13,930
otal
No.
162
-1
+1
-1
161
MW*
71,918a
23
870
600
72,165
* Equivalent scrubbed capacity.
a This value was modified slightly due to
an MU correction.
-------
TABLE III. PERFORMANCE OF OPERATIONAL UNITS
THIRD QUARTER 1979
Plant
Tombigbee 2
Tombigbee 3
Pleasant! 1
Apache 2
Apache 3
Cholla 1
Cholla 2
Duck Creek 1
Newton 1
Conesville 5
Conesville 6
Coal Creek 1
Elrama 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
Mill Creek 3
Paddy's Run 6
Milton 8. Young 2
Colstrip 1
Colstrip 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Dean H. Mitchell 11
Sherburne 1
Sherburne 2
Bruce Mansfield 1
Bruce Mansfield 2
Eddystone 1A
San Juan 1
San Juan 2
Winyah 2
R.D. Morrow 1
R.D. Morrow 2
Marion 4
A.B. Brown 1
Southwest 1
Shawnee 10A
Shawnee 10B
Widows Creek 8
Martin Lake 1
Martin Lake 2
Martin Lake 3
Monticello 3
Hunter 1
Huntington 1
Total
FGD system
capaci ty ,
179
179
519
195
195
119
350
378
617
411
411
327
510
410
532
90
90
874
540
125
420
64
188
190
288
442
72
405
360
360
125
125
125
115
740
740
917
917
120
361
350
140
124
124
184
265
194
10
10
550
595
595
595
800
360
366
F lue gas
I scrubbed
70
70
83
100
100
100
100
90
100
100
100
60
100
100
100
100
100
100
75
100
100
100
100
100
100
100
100
92
100
100
100
100
100
100
100
100
100
100
t>lff
100
100
50
62
62
100
100
100
N/Ad
N/A"
100
75
75
75
100
90
85
FGD capacity
on line
during
period.
179
179
519
195
195
119
350
378
617
327
510
410
90
90
874
540
125
420
64
188
190
288
442
72
405
360
360
125
125
125
115
740
740
917
917
361
350
140
124
124
265
194
10
10
550
595
595
595
800
360
366
17,729
No information
for this
period, >1W
411
411
532
120
184
1,658
Shut down
through-
out
period,
MW
0
JULY 1979
Dependabi i ty 'C.e
AVL
93
72
95
100
93
100
44
Bl
86
93
90
93
95
98
57
100
OPR
91
28
87
88
92
99
72
0
60
0
44
81
91
93
98
63
41
100
100
80
REL
91
28
96
44
81
86
93
82
98
41
UTL
72
11
61
SO
73
0
93
56
0
55
0
44
80
78
93
79
98
65
41
41
99
80
AUGUiT 1979
Oependat-i i ty c-e
AVL
99
99
13
75
100
94
100
39
96
93
87
95
96
99
84
97
OPR
92
64
17
88
9?
89
88
7
68
45
39
97
99
93
99
94
62
100
100
30
REL
92
64
23
39
97
93
68
99
62
UTL
70
42
12
BC
70
0
89
73
7
50
13
39
97
93
88
98
94
59
75
100
27
SEPTEMB
Dependabi
«VL
100
100
65
'
84
69
96
100
23
100
85
100
92
95
4
71
97
OPR
93
75
57
0
84
60
90
0
23
100
84
99
5
75
59
100
100
55
P 1579
ity '•<•
RLL
93
75
65
23
100
82
100
5
66
UTL
76
14
53
0
0
54
44
84
0
23
53
66
90
5
74
47
71
100
54
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 * scrubbed for prototype and demonstration units is not applicable unless the system is designed to bring a jnit into compliance with SO?
emission standards.
e Availability, operability, reliability, and utilization as defined in Appendix C cf this report.
XI
-------
As indicated in Table 1, 56 power generating units (all coal-
fired) are now equipped with operating FGD systems. These units
represent a total controlled capacity of 21,104 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 gen-
eration sources, both present (April 1979) and future (January
1990) is as follows:&
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 con-
trolled by FGD for both the present (September 1979) and the
future (January 1990) is as follows:
% of coal-fired % of total
generating capacity generating capacity
September 1979 9.2 3.6
January 1990 20.0 8.2
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 to 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.
HIGHLIGHTS: THIRD QUARTER 1979
The following paragraphs highlight FGD system developments
during the third quarter, 1979.
Xll
-------
Tombigbee 2 of Alabama Electric Coop achieved FGD system availa-
bilities of 93%, 99% and 100% for July, August and September,
respectively. Tombigbee 3 demonstrated FGD system availabilities
of 99% and 100% for August and September. No major problems were
reported during the period.
A contract was awarded by Allegheny Power System during the third
quarter 1979 for a lime slurry FGD system to be installed by
Chemico on Mitchell 33. Initial startup of the FGD system is
scheduled for August 1982. The Mitchell 33 unit is a 300 MW
(gross) boiler that fires bituminous coal with an average sulfur
content of 2.8%.
Duck Creek 1 of Central Illinois Light operated through July with
an FGD system availability of 95%. The unit encountered some
recycle pump failures and mist eliminator plugging.
Initial FGD operations began during the period at the Newton 1
unit of Central Illinois Public Service. Although flue gas has
been passed through the individual modules for testing purposes,
integrated operation of the FGD system is not expected to begin
until December 1979. This dual alkali system was supplied by
Buell/Envirotech and consists of four tray tower absorbers pre-
ceded by a cold-side ESP for primary particulate matter control.
Also included are two thickeners, two experimental reheat sys-
tems, and three horizontal extraction filters for sludge dewa-
tering.
Coal Creek 1 of Cooperative Power Association began shakedown/
debugging operations during the report period. Particulate mat-
ter is removed from the flue gas generated by the unit with cold
side ESP's and S02 is controlled by four parallel spray towers
circulating a lime/alkaline fly ash slurry. Approximately 40% of
the flue gas is bypassed for reheat and the sludge is disposed in
a clay-lined pond.
Chiyoda International announced that all testing of the CT-121
process at the Scholz Power Plant of Gulf Power has been com-
pleted. The EPRI studies that were being conducted were of-
ficially terminated late in June after a total of 4,448 hours of
operation had been logged. During this time, the jet bubbling
reactor was off line for 123 hours with an average six-month
availability of 99.5%.
Houston Lighting and Power announced during the period that a
contract has been awarded to Chemico for the installation of an
emission control system on the 600 MW (net) W. A. Parish 8 unit.
The system will consist of three spray drying towers utilizing
limestone as the reagent. Each tower will be designed for 85%
SO2 removal. Also included will be a chevron type mist eliminator
and reheat will be provided by an 18% bypass system.
Xlll
-------
At LaCygne 1 of Kansas City Power and Light, average FGD system
availabilities of 94% and 96% were reported for the months of
August and September, respectively. No major problems occurred
during these two months. The unit was out of service during
for a turbine overhaul.
Louisville Gas and Electric reported operabilities of 99% and 89%
during July and August, respectively for Cane Run 4. Mill Creek
3 achieved a 90% operability in September. Cane Run 4 experi-
enced some damper problems and Mill Creek 3 had reheater failures
during the report period.
Montana Power has announced that construction began during the
third quarter at the Colstrip Power Station on the lime/alkaline
fly ash FGD systems that are being installed on Boilers 3 and 4.
These units are being supplied by ADL/Combustion Equipment
Associates and are scheduled to begin commercial operation in
January 1984 and the Fall of 1984 for units 3 and 4 respectively.
Each boiler is rated at 700 MW (gross) and fires coal with an
average sulfur content of 0.7%.
Muscatine Power and Water reported that bids are being evaluated
for the FGD facility planned for Muscatine 9. The FGD system
will consist of two lime or limestone slurry S02 absorbers, an
indirect steam coil reheater and a forced oxidation system that
will produce a stable waste for landfill when dewatered. Musca-
tine 9 is expected to begin operations in September 1982.
Nevada Power reported that the FGD systems at Reid Gardner 1, 2,
and 3 were in service for most of the third quarter 1979. FGD
system availabilities for July, August and September were 81%,
96% and 100%, respectively, for Unit 1. Unit 2 availabilities
were 86%, 93%, and 85% with Unit 3 availabilities being 93%, 87%
and 100%, respectively, for July, August and September.
New York Electric and Gas announced plans to install a limestone
slurry FGD system on the utility's new 850 MW Somerset 1 steam
generator scheduled for service in 1984. Particulate matter gen-
erated by the pulverized coal furnace will be removed by a cold
side ESP. The FGD facility design will include a direct hot air
injection reheat system to boost the saturated gas temperature
before entering the 450 ft stack. FGD_waste from this closed
loop system will be dewatered and stabilized before being land-
filled.
Construction at Charles R. Huntly 66 of Niagara Mohawk Power be-
gan in September. The demonstration aqueous carbonate FGD
system to be retrofilled onto this unit will produce sulfur as an
end product. Particulate matter is removed from the flue gas by
mechanical collectors and an ESP upstream of the FGD system. The
Charles R. Huntly 66 FGD System is expected to begin operations
in April 1982.
xiv
-------
Although data were not available for the months of August and
September, Northern Indiana Public Service reported that the
availability of the Dean H. Mitchell 11 scrubber was 90% for the
month of July. FGD outage resulted from inspection of the
booster blower speed reducer and a high flow resistance in the
S02 reduction unit.
Northern States Power has announced that bids were again reopened
for the emission control system that is to be installed at Sher-
burne 3 due to developments in the latest FGD technology.
Sherburne 3 is a 860 MW (gross) unit that fires coal with an
average sulfur content of 0.8%. FGD operations are tentatively
scheduled to begin at this unit in mid-1984.
At Sherburne 1 of Northern States Power, the FGD system had
availabilities of 93%, 95%, and 92%, respectively, for July,
August and September. No major operational problems were re-
ported for the three-month period. The unit went off-line on
September 8 for an annual boiler/turbine inspection and is ex-
pected to restart during the last week of October. The Sherburne
2 FGD system availabilities were 95%, 96% and 95% for July,
August and September, respectively. No operational problems have
been reported for this unit since it restarted in June after the
annual boiler turbine inspection.
Philadelphia Electric announced during the third quarter that
contracts have been awarded to United Engineers for the installa-
tion of a magnesium oxide FGD system to treat the balance of the
flue gas from Eddystone 1 and for a system to treat the flue gas
from the 334 MW (gross) Eddystone 2 unit. A contract was also
awarded to United Engineers for a third magnesium oxide FGD
system to be installed on one of two boilers at the Cromby power
station. The initial startup of all three systems is tentatively
scheduled for mid-1980.
South Carolina Public Service reports that the Winyah 2 FGD
system had availabilities of 98% and 99% for the months of July
and August, respectively. In July minor problems were reported
with nozzle plugging and the quencher pump packing. The only
unscheduled outage in August was a result of booster fan control
problems.
The recently operational dual alkali system at the A.B. Brown
station of Southern Indiana Gas and Electric had an availability
of 94% during the month of August. The only major problem
reported during this month was a forced outage due to problems
with the recycle pump impellers.
Tampa Electric is now requesting/evaluating bids for the Big Bend
4 FGD installation. The utility is considering a lime or lime-
stone FGD system with direct hot air injection reheat and an ESP
for particulate matter control. Big Bend 4 is scheduled to begin
operations in March 1985.
xv
-------
Plans to install an emission control system at the Cumberland
Power Station of Tennessee Valley Authority were cancelled
during the period. Although initial indications were that an FGD
system would have to be installed, further testing at this unit
revealed that emissions were within the appropriate state and
federal standards and an emission control system would not
therefore be necessary.
Tennessee Valley Authority reported July and August FGD system
availabilities of 100% and 99%, respectively, for the Widows
Creek 8 unit. The only operational problems reported for the
two-month period were corrosion of the carbon steel reheat tubes
and ball mill outage time due to broken flange bolts.
xvi
-------
REFERENCES
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.
xvi i
-------
i:PA UTILITY FGD SURVEY: THIRD QUARTER 1"79
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAMt
ALABAMA ELECTRIC COOP
TOMPlGtiEE
TOMB1GE(E£
ALLEGHENY POWER SYSTEM
MITCHELL
PLEASANTS
PLEASANTS
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
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
ANTELOPE VALLEY
LARAPUE RIVER
LARAMIE RIVER
LARAHIE RIVER
BIG RIVERS ELECTRIC
GREEN
GREEN
CENTRAL ILLINOIS LIGHT
DUCK CREEK
DUCK CREEK
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
CENTRAL MAINE POWER
SEARS ISLAND
CINCINNATI 6AS 8 ELECTRIC
EAST BEND
COLORADO UTt ELECTRIC ASSN.
CRAIG
CRAIG
COLUMBUS i, SOUTHERN OHIO ELEC.
CONESVILLE
CONESV1LLE
POSTON
POSTON
UNIT
2
7
33
1
£.
2
3
1
2
4
1
2
3
4
5
3
1
2
1
2
3
1
2
1
2
1
1
2
1
2
5
6
5
6
NO. UMT LOCATION
LEROY
LEKGY
COURTNEY
DELTONT
BELMONT
COCHISE
COCHISE
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARM1NGTON
FAfMlNGTON
FARfllNGTON
FARSI NGTON
FARMINGTON
SOBERLY
BEULAH
BEULAH
WHEATLAND
WHEATLANO
UHEATLAND
SEBREE
S ED SEE
CANTON
CANTON
NEWTON
PENCBSCOT BAY
RADBITHASH
CRAIG
CRAIG
CONESVILLE
CONESVILLE
ATHENS
ATHENS
ALABAMA
ALABAMA
PENNSYLVANIA
UEST VIRGINIA
WEST VIRGINIA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
NEW MEXI CO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
MISSOURI
NORTH DAKOTA
NORTH DAKOTA
WYOMING
yYOMING
WYOMING
KENTUCKY
KENTUCKY
ILLINOIS
ILLINOIS
ILLINOIS
MAINE
KENTUCKY
COLORADO
COLORADO
OHIO
OHIO
OHIO
OHIO
START-UP
DATE
9/78
6/79
8/82
3/79
9/80
8/78
6/79
10/73
4/78
6/BQ
0/79
0/79
0/79
0/82
0/82
1/82
11/81
11/83
A/ 80
10/80
7/81
10/79
6/SO
9/76
1/84
9/79
11/87
10/81
1/80
8/79
1/77
6/78
0/83
0/89
STATUS
1
1
3
1
2
1
1
1
1
2
2
2
2
3
3
2
3
6
2
2
3
2
2
T
5
1
6
2
2
2
1
1
6
6
REC
CLASS
A
A
B
A
A
B
B
B
B
B
B
B
B
B
B
A
B
B
A
A
A
A
A
A
A
A
A
A
B
B
E
B
B
B
1. OPERATIONAL UNITS
2. UNITS UNDtR CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. BOILER CONSTRUCTED SUBJECT TO FEDERAL N5PS
B. BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
C. BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
D. OTHER
E. REGULATl/PY CLASS UNKNOWN
-------
EPA UTILITY FuD SURVEY: THIRD QUARTER 1979
SECTION 1
COMPANY NAME/
UNIT NAME
COMMONWEALTH EDISON
POUERTON
COOPERATIVE POWER ASSOCIATION
COAL CREEK
COAL CREEK
DELMARVA POWER 8 LIGHT
DELAUARE CITY
DUQUESNE LIGHT
EL RAMA
PHILLIPS
EAST KENTUCKY POWER COOP
SPUR LOCK
GENERAL PUBLIC UTILITIES
COHO
SEWARO
HOOSIER ENERGY
KERCH
HEROM
HOUSTON LIGHTING £ POWER CO.
U.A. PARISH
INDIANAPOLIS POUER & LIGHT
PETERSBURG
PETERSBURG
KANSAS CITY POWER & LIGHT
HAWTHORN
HAWTHORN
LA CYGNE
KANSAS POUER & LIGHT
JEFFREY
JEFFREY
LAURENCE
LAURENCE
KENTUCKY UTILITIES
GREEN RIVER
LAKELAND UTILITIES
HCINTOSH
LOUISVILLE GAS K ELECTRIC
CANE RUN
CANE RUN
CANE RUN
MILL CREEK
MILL CREEK
HILL CREEK
HILL CREEK
PADDY'S RUN
TRIMBLE COUNTY
TRIMBLE COUNTY
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
START-UP
UNIT NO. UNIT LOCATION DATE STATUS
51
1
2
1-3
1-4
1-6
2
1
7
1
2
8
3
4
3
4
1
1
2
4
5
1-3
3
4
5
6
1
2
3
4
6
1
2
4.
5.
3. PLANNED - CONTRACT AWARDED 6.
7.
PERKIN ILLINOIS 11/79
UNDERWOOD NORTH DAKOTA 8/79
UNDERUOOD NORTH DAKOTA 10/80
DELAUARE CITY DELAUARE 4/80
ELRAHA PENNSYLVANIA 10/75
SOUTH HEIGHT PENNSYLVANIA 7/73
MAYSVILLE KENTUCKY 10/80
ERIE PENNSYLVANIA 12/88
SEUARD PENNSYLVANIA 12/8?
SULLIVAN INDIANA 4/81
SULLIVAN INDIANA 1/82
THOMPSONS TEXAS 11/82
PETERSBURG INDIANA 12/77
PETERSBURG INDIANA 10/83
KANSAS CITY MISSOURI 11/72
KANSAS CITY MISSOURI 8/72
LA CV6NE KANSAS 2/73
W AH EGO KANSAS 8/78
UAMEGO KANSAS 6/80
LAURENCE KANSAS 1/76
LAURENCE KANSAS 11/71
CENTRAL CITY KENTUCKY 9/75
LAKELAND FLORIDA 10/81
LOUISVILLE KENTUCKY 8/76
LOUISVILLE KENTUCKY 12/77
LOUISVILLE KENTUCKY 4/79
LOUISVILLE KENTUCKY 4/81
LOUISVILLE KENTUCKY 4/82
LOUISVILLE KENTUCKY 8/78
LOUISVILLE KENTUCKY 7/81
LOUISVILLE KENTUCKY 4/73
BEDFORD KENTUCKY 7/84
BEDFORD KENTUCKY 7/86
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
2
1
2
2
1
1
2
6
6
3
2
3
1
2
1
1
1
1
2
1
1
1
3
1
1
1
2
2
1
2
1
6
6
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE
REE
CLASS
C
A
A
C
B
B
•
*
A
A
A
A
A
A
B
B
C
B
B
B
B
C
A
A
A
A
B
B
B
B
C
D
C
METHODS
A. BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
B. BOILER SUBJECT TO STATE
C. BOILER SUBJECT TO STATE
D. OTHER
E. REGULATORY CLASS UNKNOWN
STANDARD
STANDARD
THAT IS MORE STRINGENT THAN THE FEDERAL
THAT IS EQUAL TO OR LESS STRINGENT THAN
NSPS
NSPS
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAMi
MIDDLE SOUTH UTILITIES
ARKANSAS COAL
ARKANSAS COAL
LOUISIANA COAL
LOUISIANA COAL
MISSISSIPPI COAL
MISSISSIPPI COAL
UNIT NO. UNI T LOCATION
5
6
1
2
1
2
ARKANSAS
ARKANSAS
LOUISIANA
LOU1SI ANA
MISSISSIPPI
MISSISSIPPI
START-UP
DATE
1/86
1/68
0/86
Q/88
C/£5
0/87
STATUS
5
5
5
5
5
5
REC
CLASS
D
D
D
0
D
D
MINNESOTA POWER & LIGHT
CLAY BOSWELL
M1NNKOTA POWER COOPERATIVE
MILTON R. YOUNG
MONTANA POWER
COLSTRIP
COLSTRIP
COLSTS1P
COLSTRIP
MUSCAT INE POWER 8 WATER
MUSCATINE
COHASSET
CENTER
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
MUSCATINE
MINNESOTA
NORTH DAKOTA
MONTANA
MONTANA
MONTANA
MONTANA
IOWA
2/80
9/77
9/75
5/76
1/84
0/84
9/82
NEVADA POWER
HAHRY ALLEN 1
HARRY ALLEN 2
HARRY ALLEN 3
HARRY ALLEN 4
REID GARDNER 1
REID GARDNER 2
REID GARDNER 3
REID GARDNER 4
WARMER VALLEY 1
WARNER VALLEY 2
NEW ENGLAND ELECTRIC SYSTEM
BRAYTON POINT 3
N.E. LAS VEGAS NEVADA
N.E. LAS VEGAS NEVADA
N.E. LAS VEGAS NEVADA
N.E . LAS VEGAS NEVADA
MOAPA NEVADA
MOAPA NEVADA
MOAPA NEVADA
MOAPA NEVADA
ST. GEORGE UTAH
ST. GEORGE UTAH
6/86
6/87
6/88
6/89
4/74
4/74
6/76
0/83
6/85
6/86
6
6
6
6
1
1
1
6
6
6
SOMERSET
MASSACHUSETTS
01 0
NEW YORK STATE ELEC & GAS
SOMERSET
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY
66
SOMERSET
BUFFALO
NEW YORK
NEW YORK
6/84
4/82
NORTHERN INDIANA PUB SERVICE
BA1LLY 7
BA1LLY 8
DEAN H. MITCHELL 11
SCHAHFER 17
SCHAHFER 18
NORTHERN STATES POWER
SHERBURNE 1
SHE.RBURNE 2
SHERBURNE 3
OTTER .TAIL POWER
COYOTE 1
CHESTERTON
CHESTERTON
GARY
WHEATFIELD
WHEATFIELD
BECKER
PECKER
BECKER
BEULAH
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
MINNESOTA
MINNESOTA
MINNESOTA
NORTH DAKOTA
O/ 0
O/ 0
7/76
6/83
6/85
3/76
4/77
5/84
3/81
1.
2 .
A.
B.
C.
D.
E .
OPERATIONAL UNITS
UNITS UNDER CONSTRUCTION
PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING F&D SYSTEMS; ALSO ALTERNATIVE METHODS
BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
BOILER SUbJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
BOILER SUbJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
OTHER
REGULATORY CLASS UNKNOWN
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
PACIFIC GAS & ELECTRIC
HONTEZUHA
NONTEZUMA
PACIFIC POWER 8 LIGHT
JIM BRIDGER
PENNSYLVANIA POWER
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
PHILADELPHIA ELECTRIC
CROMBY
EDDYSTONE
EDDVSTONE
EOOYSTONE
UNIT K
1
2
4
1
2
3
1A
1B
2
10. UNIT LOCATION
COLLINSVILLE
COLL1NSVILLE
ROCK SPRINGS
SHIPPINGPORT
SH1PPINGPORT
SHIPPINGPORT
PHOENIXVILLE
EOOYSTONE
EDDYSTONE
EDDYSTONE
CALIFORNIA
CALIFORNIA
WYOMING
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
START-UP
DATE
6/86
6/87
9/79
12/75
7/77
5/80
6/80
9/75
6/80
6/80
REE
POTOMAC ELECTRIC POWER
OICKERSON
POWER AUTHORITY Of NEW YORK
ARTHUR KILL
PUBLIC SERVICE Of INDIANA
GIBSON
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
SAN JVM
SAN JUAN
SAN JUAN
SALT RIVER PROJECT
CORONA DO
CORONADO
CORONADO
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL
SEMINOtE ELECTRIC
SEMI HOLE
SEMINOLE
SIKESTON BOARD OF HUNK. UTIL.
SIKESTON
SOUTH CAROLINA PUBLIC SERVICE
WINVAH
WINVAH
WINVAH
SOUTH MISSISSIPPI ELEC PWO
R.D. MORROW
R.D. MORROW
SOUTHERN ILLINOIS POWER COOP
MARION
MARION
DICKERSON
MARYLAND
STATEN ISLAND NEW YORK
PRINCETON
HATfcRFLOW
WATERFLOW
WATERFLOW
WATERFLOW
ST. JOHNS
ST. JOHNS
ST. JOHNS
INDIANA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
ARIZONA
ARIZONA
ARIZONA
0/87
11/87
0/82
4/78
8/78
12/79
1/82
11/79
1/80
0/84
6
6
1
1
2
1
2
3
4
1
2
4
5
SAN MI6UEL
PALATKA
PALATKA
SIKESTON
GEORGETOWN
GEORGETOWN
GEORGETOWN
HATTISBURG
HATTISBURG
MARION
BAR ION
TEXAS
FLORIDA
FLORIDA
MISSOURI
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
MISSISSIPPI
MISSISSIPPI
ILLINOIS
ILLINOIS
7/80
6/83
6/85
1/81
7/77
5/80
5/81
8/78
6/79
5/79
0/84
2
5
5
2
1
2
3
1
1
1
6
A
A
A
A
A
A
A
A
A
A
A
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
*. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
B. BOILER SUBJECT TO STATE STANDARD T4AT IS MORE STRINGENT THAN THE FEDERAL NSPS
C. BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
D. OTHER
E. REGULATORY CLASS UNKNOWN
-------
[PA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 1
SUKKARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAMt
SOUTHERN INDIANA GAS & ELtC
A.B. BROWN
SOUTHWESTERN ELECTRIC POWER
HENRY W. PERKEY
SPRINGFIELD CITY UTILITIES
SOUTHWEST
SPRINGFIELD HATER, LIGHT £ PUR
OALLMAN
ST. JOE ZINC
G.F. UEATON
TAMPA ELECTRIC
BIG BEND
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE
PARADISE
PARADISE
SHAWNEE
SHAHNEE
WIDOWS CREEK
WIDOWS CREEK
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK
TEXAS POWER R LIGHT
SANDOU
TWIN OAKS
TWIN OAKS
TEXAS UTILITIES
FOREST GROVE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
HILL CREEK
HILL CREEK
MONTICELLO
UTAH POUER & LIGHT
HUNTER
| HUNTER
HUNT1NGTON
UNIT NO. UNIT LOCATION
1
1
1
3
1
4
1-10
1
2
10A
10B
7
8
1
4
1
2
1
1
2
3
4
1
2.
3
1
2
1
WEST FRANKLIN
HALLSVILLE
SPRINGFIELD
SPRINGFIELD
MONACA
TAMPA
INDIANA
TEXAS
MISSOURI
ILLINOIS
PENNSYLVANIA
FLORIDA
NEW JOHNSONVILLTENNESSEE
PARADISE
PARADISE
PADUCAH
PADUCAH
BRIDGEPORT
BRIDGEPORT
CARLOS
ROCKDALE
BREMOND
BREKOND
ATHENS
TATUM
TATUM
TATUM
TATUM
HENDERSON
HENDERSON
HT. PLEASANT
CASTLE DALE
CASTLE DALE
PRICE
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
ALABAMA
ALABAMA
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
UTAH
UTAH
UTAH
START-UP
DATE
3/79
12/83
4/77
7/80
11/79
3/85
0/82
6/82
3/82
4/72
4/72
10/80
5/77
1/82
7/80
8/84
8/85
0/81
4/77
5/78
2/79
0/85
0/85
0/86
5/78
5/79
6/80
5/78
STATUS
1
3
1
2
2
5
5
3
3
1
1
2
1
3
2
5
5
5
1
1
1
3
6
6
1
1
2
1
REG
CLASS
A
A
A
A
B
A
C
C
C
C
C
C
C
A
A
A
A
A
A
A
A
A
D
D
A
A
A
A
WISCONSIN POWER & LIGHT
COLUMBIA
PORTAGE
WISCONSIN
1/8?
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
B. BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
C. BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
D. OTHER
E. REGULATORY CLASS UNKNOWN
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ALABAMA ELECTRIC COOP
TOMBIGBEE
2
NEW 255.0 MW (GROSS>
179.0 MW (ESC)
COAL
1.15 ZS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.1Z
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 FLO* OF 953,000
ACFW AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.21 AND
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB. THE UNIT S02 EMMISSION LIMITA-
TION VALUE IS 1-2 LB/MMBTU. PRIMARY PARTICULATE MATTER CONTROL IS PROVID-
ED BY A HOT SIDE ESP. THE S02 REMOVAL EQUIPMENT CONSISTS OF TWO SPRAY
TOWERS SUPPLIED BY PEABODY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REA-
GENT. A CHEVRON MIST ELIMINATOR IS INCLUDED FOR EACH TOUER AND THE FLUE
GAS IS REHEATED WITH BYPASSED &AS BEFORE BEING VENTED TO A «00 FOOT ACID-
BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN HATER LOOP KCDE AND
SPENT ABSORBENT IS DISPOSED OF IN AN ON-SlT£ LINED POND.
ALABAMA ELECTRIC COOP
TOMBIGBEE
3
NEW 255.0 MW (GROSS)
179.0 My (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.IX
STATUS 1 STARTUP 6/79
TOMBIEBEE 3 OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LCROY, ALABAMA. THE BOILER GENERATES A MAXIMUM FLUE 6AS FLOK OF 953,000
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.22 AND
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB. THE UNIT S02 EMISSION LIMITATION
VALUE IS 1.2 LB/MMBTU. PRIMARY PART1:CULATE CONTROL IS PROVIDED B» » HOT
SIDE ESP. THE S02 REMOVAL EQUIPMENT CONSISTS OF WO SPRAY TOWERS SUPPLIED
BY PEABODY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REAGENT. A CHEVRON
MIST ELIMINATOR IS INCLUDED IN EACH TOWER, AND THE FLUE 6AS IS REHEATED
WITH BYPASSED GAS BEFORE BEING V£NT£D 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
MITCHELL
33
RETROFIT 300.0 MU (GROSS)
300.0 MU (ESC)
COAL
2.80 XS BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 8/82
UNIT 33 AT ALLEGHENY POWER SYSTEM'S MITCHELL POUER STATION IN COURTNEY,
PENNSYLVANIA IS A 2.8% SULFUR COAL FIRED BOILER. A CONTRACT WAS
AWARDED TO CHEHICO FOR A LIME SCRUBBING PROCESS. S02 REMOVAL
EFFICIENCY MILL BE 95%. START UP IS PLANNED FOR AUGUST OF 1982.
ALLEGHENY POWER SYSTEM
PLEASANTS
1
NEW 625.0 MW (GROSS)
519.0 MW (ESC)
COAL
3.70 XS BITUMINOUS
LIME
BABCOCK f, WILCOX
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 3/79
ALLEGHENY POWER SYSTEM'S PLEASANTS 1 IS A BITUMINOUS COAL (3.7Qt S, 12,150
BTU/LB) FIRED BOILER IN BELMONT, WEST VIRGINIA. BABCOCK AND WILCOX SUP-
PLIED A LIME FGO SYSTEM DESIGNED TO REMOVE 90X OF THE FLUE GAS SOZ FROM
THIS UNIT. THE EMISSION CONTROL SYSTEM INCLUDES AN ESP UPSTREAM OF FOUR
SPRAY TOWER ABSORBERS. A FLUE CAS BYPASS SYSTEM PROVIDES REHEAT OF THE
CLEANED GAS BEFORE IT IS DISCHARGED THROUGH A 1200 FOOT PLACITE LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGD SYSTEM ON THIS
UNIT HAS BEEN OPERATIONAL SINCE MARCH OF 1979.
ALLEGHENY POWER SYSTEP
PLEASANTS
2
NEW 625.0 MW (GROSS)
519.0 MU (ESC)
COAL
4.50 ZS BITUMINOUS
LIME
BABCOCK R WILCOX
ENERGY CONSUMPTION: **»*X
STATUS 2 STARTUP 9/80
ALLEGHENY POWER SYSTEM'S PLEASANTS 2 IS A BITUMINOUS COAL <3.7X S. 12,150
BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN BELMONT, WEST VIRGINIA. BABCOC*
AND WILCOX IS SUPPLYING A LIME FGD SYSTEM DESIGNED TO REMOVE 9CX 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 GA.S BEFORE IT IS DISCHARGED THROUGH A
1200 FOOT PLACITE LINED STACK. THE SYSTEM WILL OPERATE IN AN OPEN WATER
LOOP. FGD SYSTEM START UP IS EXPECTED IN SEPTEMBER, 1980.
ARIZONA ELECTRIC POWER COOP
APACHt
2
NEW 195.0 MW (GROSS)
195.0 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 4.IX
STATUS 1 STARTUP 8/78
APACHE 2 OF ARIZONA ELECTRIC POWER COOP IS LOCATED IN COCH1SE, ARIZONA AND
IS A DRY BOTTOM PULVERIZED COAL FIRED UNIT WITH A FLUE GAS FLOfc OF 735,000
ACFM. BITUMINOUS COAL WITH A HEATING VALUE OF 10,000 BTU/LB, A SULFUR CON-
TENT OF C.7X AND AN ASH CONTENT OF 15X IS THE FUEL USED FOR THIS UNIT.
PART1CULATE CONTROL IS EFFECTED BY A HOT SIDE ESP. THE UNIT IS CURRENTLY
IN OPERATION WITH STARTUP IN AUGUST 1978. TWO PACKED TOWERS EMPLOYING
LIMESTONE ABSORBENT AND HAVING A DESIGN S02 REMOVAL OF 85X WERE SUPPLIED
BY RESEARCH COTTRELL. MIST ELIMINATION IS PROVIDED BY CHEVRON TYPE ELIMI-
NATORS. NO REHEAT IS EMPLOYED. A 400 FT COLE BRAND CXL2000 LINED STACK IS
IN USE. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE AND HASTE MATERIAL
IS DISPOSED OF IN OFF-SITE SLUDGE PONDS.
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF fGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZONA ELECTRIC POWER COOP
APACHE
3
NEW 195.0 MW (GROSS)
195.0 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 4.U
STATUS 1 STARTUP 6/79
APACHE 3 OF ARIZONA ELECTRIC POWER COOP IS A OKI BOTTOM, PULVERIZED COAL
FIRED UNIT IN COCHISE, ARIZONA. LOW (0.7X) SULFUR BITUMINOUS COAL WITH AN
AVERAGE HEATING VALUE OF ICiCOO BTU/LB PRODUCES A MAXIMUM FLUE GAS FLOW OF
735,ODD ACFM. THE FLUE GAS PASSES THROUGH A HOT SIDE ESP TO TWO RESEARCH
COTTRELL PACKED TOUERS, WHERE LIMESTONE IS USED TO REMOVE 852 (DESIGN) OF
THE SO;. 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 FGD,
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
PLANKED, WHICH WOULD ADD ANOTHER 20 YEARS* CAPACITY.
ARIZONA PLBLIC SERVICE
CHOLLA
1
RETROFIT 119.0 MU (GROSS)
119.0 «W (ESC )
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 3.42
STATUS 1 STARTUP 10/73
ARIZONA PUBLIC SERVICE'S CHOLLA 1 IS LOCATED IN JOSEPH CITY, ARIZONA AND
IS A TANGENT1ALLY FIRED, WET BOTTOM PULVERIZED COAL UNIT. IT IS FUELED BY
BITUMINOUS COAL THAT HAS A SULFUR CONTENT OF 0.52 AND A HEATING VALUE OF
10,153 BTU/LB. PARTICULATE MATTER IS CONTROLLED BY TWO FLOODED DISC SCRUB-
BERS. THE FGD SYSTEM BEGAN IN OCTOBER, 1973 AND IS NOW OPERATIONAL. S02 jS
CONTROLLED BY ONE TOWER WITH HUNTERS PACKING EMPLOYING A LIMESTONE
ABSORBENT. THE UNIT WAS SUPPLIED BY RESEARCH COTTRELL AND HAS A DESIGN
REMOVAL OF 921. CHEVRON MIST ELIMINATORS ARE LOCATED PRIOR TO AN IN-LINE
STEAK 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 MW (GROSS)
350.0 MW (ESC)
COAL
.50 2S BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: ****%
STATUS 1 STARTUP 4/78
CHOLLA 2 OF ARIZONA PUBLIC SERVICE IS LOCATED IN JOSEPH CITY, ARIZONA. THE
BOILER BURNS PULVERIZED BITUMINOUS COAL (0.52 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 S02. THE DESIGN S02 REMOVAL FOR THE
SYSTEM, WHICH BEGAN OPERATIONS IN APRIL, 1978. IS 752. 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 POND*
ARIZONA PUBLIC SERVICE
CHOLLA
4
NEW 350.0 MW (GROSS)
126.0 MW (ESC)
COAL
.50 XS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: *****
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, 1980. THE PULVERIZED
COAL (0.52 S, 10,150 RTU/LB) FIRED BOILER WILL EXHAUST FLUE GAS THROUGH AN
ESP TO A PACKED TOWER WHICH WILL TREAT 362 OF THE GAS WITH LIMESTONE.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT 175.0 MW (GROSS)
175.0 MW (ESC)
COAL
.75 2S SUBBITUMINOUS
LIME/ALKALINE FLYASH
CHEMICO
ENERGY CONSUMPTION: ***»2
STATUS 2 STARTUP 0/79
ARIZONA PUBLIC SERVICE IS UPGRADING THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1, 2, AND 3 IN FARMINGTON, NEW MEXICO TO HANDLE ADDITIONAL
SO2 REMOVAL. CURRENTLY, THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.752 S, 8650 BTU/LB) UNITS 1 AND 2 SUPPLY 814*000 ACFM EACH
INTO 2 CHEMICO VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICULATE CONTROL
AND APPROXIMATELY 302 S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02
REMOVAL EFFICIENCY A£TER THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67.52. START UP IS EXPECTED SOMETIME IN 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
RETROFIT 175.0 MW (GROSS)
175.0 MW (ESC)
COAL
.75 2S SUBBITUMINOUS
LIME/ALKALINE FLYASH
CHEMICO
ENERGY CONSUMPTION: ****2
STATUS 2 STARTUP 0/79
ARIZONA PUBLIC SERVICE IS UPGRADING THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1,2. AND 3 IN FARMINiGTON, NEW MEXICO TO HANDLE ADDITIONAL
S02 REMOVAL. CURRENTLY, THE FRONT FIRED, DRV BOTTOM, PULVERIZED COAL CSUB-
BITUKINOUS, 0.752 S, 8650 BTU/LB) UNITS 1 AND 2 SUPPLY 814,000 ACFM EACH
INTO 2 CHEMICO VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICULATE CONTROL
AND APPROXIMATELY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02
REMOVAL EFFICIENCY AFTER THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUb91NG IS 67.5X. START UP IS EXPECTED SOMETIME IN 1979.
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZONA PUBLIC SERVICE
FOUR CORNERS
3
RETROFIT 229.0 nu (GROSS)
229.0 MW (ESC)
COAL
.75 ZS SUBBITUNINOUS
LIME/ALKALINE FLYASH
CHEMICO
ENER6Y CONSUMPTION: *«**Z
STATUS 2 STARTUP 0/79
ARIZONA PUBLIC SERVICE IS UPGRADING THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1,2, AND 3 IN FARMINGTON, NEW MEXICO TO HANDLE ADDITIONAL
S02 REMOVAL. CURRENTLY, THE FRONT FIRED, DRV BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.752 S, 8650 BTU/LB) UNIT 3 SUPPLIES 1,030,000 ACFM INTO 2
CHEMKO VENTURI SCRUBBERS FOR PRIMARY PARTICULATE CONTROL AND APPROXIMATE-
LY 3CX S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02 REMOVAL EFFICI-
ENCY AFTER THE CONVERSION TO LIME AND ALKALINE FLY ASH SCRUBBING IS 67.5X,
STARTUP IS EXPECTED SOMETIME IN 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
4
RETROFIT 755.0 MW (GROSS)
755.0 MW (ESC)
COAL
.75 ZS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: ***«Z
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 FARMINGTON, 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 (0.75? S, 8650 BTU/LB) FIRED UNITS.
THE PARTICULATE 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 NW (ESC)
COAL
.75 ZS
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 FARMINGTON, 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 (0.752 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 730.0 NU (GROSS)
670.0 MW (ESC)
COAL
4.80 ZS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: ****Z
THOMAS HILL 3 OF ASSOCIATED ELECTRIC COOP IS A PULVERIZED COAL (4.8Z S,
9.7CC BTU/LB) FIRED UNIT LOCATED IN MOBERLY, MISSOURI. TWO COLD SIDE ESP'!
WILL PRECEDE THE FOUR 91.51 EFFICIENT PULLMAN KELLOGG HORIZONTAL HEIR FGD
MODULES USING MAGNESIUM-PROMOTED LIMESTONE AS THE ABSORBENT. THE CLEANED
GAS WILL PASS THROUGH A VERTICAL CHEVRON MIST ELIMINATOR TO A £20 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 FGD SYSTEM IS UNDER CONSTRUCTION AND START UP IS
EXPECTED IN JANUARY, 1982.
STATUS 2
STARTUP 1/82
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
1
NEW 440.0 MW (GROSS)
440.0 MW (ESC)
COAL
.68 ZS LIGNITE
LIME/SPRAY DRYING
JOY MFG. CO, WESTERN PRECIPITA
ENERGY CONSUMPTION: ****Z
STATUS 3 STARTUP 11/81
UNIT 1 OF BASIN ELECTRIC POKER COOP'S ANTELOPE VALLEY PLANT IS PRESENTLY
UNDER CONSTRUCTION IN BEULAH, NORTH DAKOTA. THIS UNIT WILL BURN PULVERIZED
COAL (0.68Z St 6600 BTU/LB LIGNITE) AND SUPPLY 2,055,000 ACFM TO A DRY
LIME FGD SYSTEM SUPPLIED BY WESTERN PRECIPITATION. THE 6EX EFFICIENT
SYSTEM WILL CONSIST OF 5 NIPO ATOMIZER SPRAY DRYERS AND TWO BAGHOUSES.
THE CLEANED GAS, ALONG WITH A 4Z BYPASS REHEAT, WILL EXIT A 60C 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 NOVEMBER, 1981.
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
2
NEW 440.0 MW (GROSS)
440.0 MW (ESC)
COAL
.68 ZS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 11/83
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 NOVEMBER, 1983.
-------
tPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
1
NEW 600.0 MW (GROSS)
6CC.O MW (ESC )
COAL
.SO ZS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 4/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 1 IS PRESENTLY UNDER CONSTRUC-
TION IN WHEATLAND, WYOMING. THfc PULVERIZED COAL (O.S1X S, 8139 PTU/LB)
FIRED BOILER WILL FEED ?,30C,OCO ACfM OF FLUE GAS THROUGH A COLD SIDE
CSP TO FIVE RESEARCH COTTRELL LIMESTONE PACKED TOWER MODULES, UHICH HILL
REMOVE "505; OF THE S02. THE CLEANED GAS HILL EXIT FROM A VERTICAL CHEVRON
DEMISTER INTO A 600 FOOT ACID BRlCK LINED J>TACK. NO REHEAT WILL BE USED.
THE FLYASH FIXATED SLUDGE »ILL BE DEWATERED TO 831 SOLIDS BEFORE BEING
LANDFILLED, AND THE SYSTEM WILL EMPLOY A CLOSED nATER LOOP. START UP IS
SCHEDULED FOR APRIL, 1980.
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
2
NEW 600.0 MW (GROSS)
600.0 MW (ESC>
COAL
.80 ZS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 10/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 2 IS PRESENTLY UNDER CONSTRUC-
TION IN WHEATLAND, WYOMING. THE PULVERIZED COAL (0.81Z S, 8139 eTU/LB>
FIRED BOILER WILL FEED 2,300,000 ACFM OF FLUE GAS THROUGH A OLD SIDE
ESP TO FIVE RESEARCH COTTRELL LIMESTONE PACKED TOWER MODULES, hHlCH WILL
REMOVE 9DX OF THE so2. THE CLEANED GAS WILL EXIT FROM A VERTICAL CHEVRON
DEMISTER INTO A 600 FOOT ACID BRlCK LINED STACK. NO REHEAT WILL BE USED.
THE FLYASH FIXATED SLUDGE WILL BE DEWATERED TO 83% SOLIDS BEFORE BEING
LANDFILLED, AND THE SYSTEM WILL EMPLOY A CLOSED WATER LOOP. START UP IS
SCHEDULED FOR OCTOBER, 1980.
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
3
NEW 6CO.O My (GROSS)
600.0 MW {ESC)
COAL
.54 2S
LIHE/SPRAY DRYING
BABCOCK R WILCOX
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 7/61
LARAKIE RIVER 3 OF BASIN ELECTRIC POWER COOP IS TO BE CONSTRUCTED IN
WHEATLAND, WYOMING, AND WILL UTILIZE FOUR DRY LIME INJECTION MODULES,
EACH FOLLOWED BY AN ESP. THE BOILER WILL FIRE PULVERIZED COAL (0.54Z S,
81CD 3TU/LB) AND WILL SUPPLY 2,800,000 ACFM OF FLUE GAS TO THE FGD
SYSTEM, WHICH WILL REMOVE 85X OF THE S02 BEFORE THE GAS EXITS THROUGH
A 600 FOOT ACID BRICK LINED STACK. A 3X BYPASS WILL BE USED FOK REHEAT.
THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP, AND WILL LANDFILL THE
DRY POWDER WASTE; CONSTRUCTION IS SLATED TO BEGIN IN JANUARY, 1980,
AND START UP IS SCHEDULED FOR JULY, 1981.
BIG RIVERS ELECTRIC
GREEN
1
NEW 242.0 MW (GROSS)
242.0 MW (ESC)
COAL
3.75 ZS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: ****Z
STATUS 2 STARTUP 10/79
UNIT 1 OF BIG RIVERS ELECTRIC'S 6REEN STATION IS BEING CONSTRUCTED IN
SEBREE, KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75Z S, 975C BTU/LB)
FIRED BOILER WILL SUPPLY 1,000,000 ACFM TO A COLD SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH WILL REMOVE 90S OF THE
S02. THE CLEANED GAS WILL PASS THROUGH A CHEVRON MIST ELIMINATOR AND
WILL EXIT A SAVER1SEM 72 LINED STACK AFTER IT IS HEATED BY STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM WILL BE POZ-0-TEC
STABILIZED. START UP IS SCHEDULED FOR OCTOBER, 1979.
BIG RIVERS ELECTRIC
GREEN
2
NEW 242.0 MW (GROSS)
242.0 MW (ESC)
COAL
3.75 ZS BITUHINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 6/8Q
UNIT 2 OF BIG RIVERS ELECTRIC'S GREEN STATION IS BEING CONSTRUCTED IN
SEBREE, KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.752 S, 975C BTU/LB)
FIRED BOILER WILL SUPPLY 1,000,000 ACFH TO A COLD 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 SAVER1SEM 72 LINED STACK AFTER IT IS HEATED BY STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM WILL BE POZ-0-TEC
STABILIZED. START UP IS SCHEDULED FOR JUNE, 1980.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
NEW 416.0 MW (GROSS)
378.0 MW (ESC)
COAL
3.30 ZS BITUMINOUS
LIMESTONE
SILEY STOKER/ENVIRONEERING
ENERGY CONSUMPTION: 2.9%
STATUS 1 STARTUP 9/76
DUCK CREEK 1 OF CENTRAL ILLINOIS LIGHT IS LOCATED IN CANTON, ILLINOIS. THE
BALANCED DRAFT, FRONT FIRED, DRY BOTTOM UNIT BURNS PULVERIZED BITUMINOUS
COAL (3.3X S, 10,500 BTU/LB) AND SUPPLIES 2,415,000 ACFM OF FLtE GAS TO
TWO COLD SIDE ESP'S FOLLOWED BY FOUR RILEY STOKER/ENVIRONEERING ROD DECK
SPRAY TOWER MODULES. THE FGD SYSTEM HAS BEEN OPERATIONAL (ONE NODULE)
SINCE JULY, 1976, AND IS DESIGNED TO REMOVE 85X OF THE S02. HORIZONTAL
CHEVRON MIST ELIMINATORS FOLLOW THE ABSORBERS, AND THE CLEANED GAS EXITS
TO A 5DC 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.
-------
EPA UTILITY F&D SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CENTRAL ILLINOIS LIGHT
DUCK CREEK
2
NEW 416.0 MW (GROSS)
416.0 MW (ESC)
COAL
3.30 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.9Z
STATUS 5 STARTUP 1/84
CENTRAL ILLINOIS LIGHT IS CURRENTLY EVALUATING BIDS ON A LIMESTONE OR DUAL
ALKALI FGD SYSTEM FOR UNIT 2 OF ITS DUCK CREE* 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 10 BEGIN
OPERATIONS IN JANUARY, 1984.
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
NEW 617.0 NW (GROSS)
617.0 MW (ESC)
COAL
4.00 XS BITUMINOUS
DUAL ALKALI
BUELL/ENVIROTECH
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 9/79
NEWTON 1 OF CENTRAL ILLINOIS PUBLIC SERVICE IS A TANGENT1ALLY FIRED, DRY
BOTT01, PULVERIZED BITUMINOUS COAL (4* S, 10,900 BTU/LB) flRED UNIT
LOCATED IN NEWTON, ILLINOIS. A COLD SIDE ESP RECIEVES 2,163,480 ACFM
OF FLUE GAS AND FEEDS IT TO FOUR BUELL ENVIROTECH POLYSPHERE PACKED
TRAY TOWERS FOLLOWED BY TWO VERTICAL HIST ELIMINATORS PER MODULE. THE
CLEANED GAS IS BOOSTED 25 DE6 F B* A COMBINATION OF TWO DIFFERENT TYPES
OF IN-LINE REHEATERS PLUS BYPASS REHEAT, AND THEN EXITS A 530 fOOT
PRECRETE LINED STACK. THE WATER LOOP IS CLOSED, AND THE SLUDGE IS
POZ-C-TEC TREATED.
CENTRAL MAINE POWER
SEARS ISLAND
1
NEW 600.0 MW (GROSS)
600.0 MW (ESC)
COAL
***** XS
LIME/LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****%
STATUS 6 STARTUP 11/87
SEARS ISLAND 1 IS A PLANNED UNIT TO BE BUILT ON PENOBSCOT BAY BY CENTRAL
MAINE POWER. BECAUSE OF THE DISCOVERY OF A GEOLOGICAL FAULT ON SEflHS
ISLAND, PLANS FOR A 1150 WW NUCLEAR POWER PLANT HAVE BEEN REPLACED WITH
PLANS FOR A 600 MW COAL FIRED PLANT. LIME AND LIMESTONE SCRUBBING ARE
THE PRIMARY METHODS BEING CONSIDERED FOR COMPLIANCE WITH THE NSPS. IT
WILL BE TWO YEARS BEFORE ALL PERMITS REQUIRED HAKE BEEN RECIEVED. START
UP IS SCHEDULED FOR NOVEMBER, 1987.
CINCINNATI GAS & ELECTRIC
EAST BEND
2
NEW 650.0 MU (GROSS)
650.0 MW (ESC)
COAL
5.00 ZS
LIME
BABCOCK 8 WILCOX
ENERGY CONSUMPTION: 2.9Z
STATUS 2 STARTUP 10/81
EAST BEND 2 OF CINCINNATI GAS AND ELECTRIC IS A PULVERIZED COAL (5Z 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 87Z CLEANED GAS WILL PASS THROUGH A CHEVRON
MIST ELIMINATOR BEFORE BEING WARMED BY AN INDIRECT HOT AIR REHEATER AND
EXITING THROUGH A BRICK LINED 650 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 OCTOBER, 1981.
COLORADO
CRAIG
1
NEW
UTE ELECTRIC ASSN.
447.0 nu (GROSS)
447.0 Hki (ESC)
COAL
.45 ZS SUBBITUMI NOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 5.4X
STATUS 2 STARTUP 1/80
THE COLORADO UTE ELECTRIC ASSN IS PRESENTLY CONSTRUCTING TWO IDENTICAL
UNITS IN CRAIG, COLORADO, CRAIG 1 AND 2. BOTH UNITS WILL FIRE PULVERIZED
SUBB1TUMINOUS COAL (0.45% S, 10,000 BTU/LB). EACH UNIT'S HOT SIDE ESP AND
FOUR MAGNESIUM PROMOTED LIMESTONE SPRAY TOWERS WILL REMOVE S52 OF THE S02.
THE SCRUBBER EXHAUST WILL BE WARMED BY AN IN-LINE STEAM COIL REHEATER AND
WILL PASS THROUGH A 600 FOOT TALL ACID BRICK LINED STACK. THE SYSTEM WILL
OPERATE IN A CLOSED WATER LOOP, AND THE STABILIZED SLUDGE WILL BE DISPOSED
OF Ifc AN OFF SITE MINEFILL. UNIT 1 START UP IS EXPECTED IN AUGUST, 1979.
COLORADO UTE ELECTRIC ASSN.
CRAIG
2
NEW 447.0 MW (GROSS)
447.0 MW (ESC)
COAL
.45 XS SUBBITUM1NOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 5.4%
STATUS Z STARTUP 8/79
THE COLORADO UTE ELECTRIC ASSN IS PRESENTLY CONSTRUCTING TWO IDENTICAL
UNITS IN CRAIG, COLORADO, CRAIG 1 AND 2. BOTH UNITS WILL FIRE PULVERIZED
SUBB1TUM1NOUS COAL (0.45X S, 10,000 BTU/LB). EACH UNIT'S HOT SIDE ESP AND
FOUR «AGNES1UW PROMOTED LIMESTONE SPRAY TOWERS WILL REMOVE 85Z OF THE S02.
THE SCRUBBER EXHAUST WILL BE WARMED BY AN IN-LINE STEAM COIL REHEATER AND
KILL PASS THROUGH A 600 FOOT TALL ACID BRICK LINED STACK. THE SYSTEM WILL
OPERATE IN A CLOSED WATER LOOP, AND THE STABILIZED SLUDGE WILL BE DISPOSED
OF III AN OFF SITE MINEFILL. START UP OF UNIT 2 IS EXPECTED IN OCTOBER,
1979.
10
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COLUMBUS R SOUTHERN OHIO ELEC.
CONESVILLE
5
NEW 411.0 MW (GROSS)
411.0 MW (ESC)
COAL
4.67 ZS 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,
PULVIRIZED BITUMINOUS COAL (4.67% S, 10,850 BTU/LB) FIRED UMT LOCATED
IN CONtSVlLLE, OHIO. « COLD SIDE ESP RECIEVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TWO THIOSORBIC LIME TCA MODULES SUPPLIED hT UOP.
THE SDZ REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH BEGAN INITIAL
OPERATION IN JANUARY, 1977, IS 89.5X (DESIGN). EACH MODULE HAS ONE
BULK ENTRAINMENT SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. ThE
CLEANED GAS EXITS THROUGH Afi 800 FOOT TALL ACID BRICK LINED STACK.
THE POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON SITE DIKED LAND-
FILL. THE SYSTtM OPERATES IN At» OPEN WATER LOOP.
COLUMBUS S SOUTHERN OHIO ELEC.
CONCSVILLE
6
NEW 411.0 MW (GROSS)
411.0 NW (ESC)
COAL
4.67 ZS BITUMINOUS
LIMt
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 3.92
STATUS 1 STARTUP 6/78
CONESVILLE 6 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.67X S, 10,850 BTU/LB) FIRED UNIT LOCATED
IN CCNESVILLE, OHIO. A COLD SIDE ESP RECIEVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TWO THIOSORBIC LIME TCA MODULES SUPPLIED BY UOP-
THE SD2 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 TyO 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.
COLUMBUS & SOUTHERN OHIO ELEC.
POSTON
5
NEW 375.0 NW (GROSS)
375.0 MU (ESC)
COAL
2.50 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/83
COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TWO NEW UNITS, POSTON 5
AND 6, TO BE LOCATED IN ATHENS, OHIO. THE COAL (2.52 S, 11,000 BTU/LB)
FIREC UNITS WILL UTILIZE EITHER A LIME, LIMESTONE, OR DUAL ALKALI FGD
SYSTEM. START UP OF UNIT 5 IS EXPECTED IN 1983.
COLUMBUS & SOUTHERN OHIO ELEC.
POSTON
6
NEW 375.0 MW (GROSS)
375.0 MW (ESC)
COAL
a.so zs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****%
STATUS 6 STARTUP 0/89
COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TWO NEW UNITS* POSTON 5
AND 6, TO BE LOCATED IN ATHENS, OHIO. THE COAL (2.5X S, 11,000 BTU/L6>
FIRED UNITS WILL UTILIZE EITHER A LIME. LIMESTONE, OR DUAL ALKALI FGD
SYSTEM. START UP OF UNIT 6 IS EXPECTED IN 1989.
COMMONWEALTH EDISON
POUERTON
51
RETROFIT 450.0 Mtf (GROSS)
450.0 MW (ESC)
COAL
3.60 ZS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 5.bl
STATUS 2 STARTUP 11/79
COMMONWEALTH EDISON IS PRESENTLY RETROFITTING BOILER NUMBER 51 AT ITS
POWERTON STATION WITH A UOP LIMESTONE FGD SYSTEM. UNIT 51 IS ONE Of TWO
IDENTICAL BOILERS SUPPLYING STEAM TO AN 850 MW TURBINE. THE PULVERIZED
COAL (3.6Z S, 10,500 BTU/LB) FIRED BOILER FEEDS FLUE GAS THROUGH AN ESP
TO 3 TCA MODULES WHICH ARE DESIGNED TO REMOVE 74X OF THE SO?. A STEAM
INDIRECT HOT AIR REHEATER WILL BOOST THE TEMPERATURE BEFORE THE GAS 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
NOVEMBER, 1979.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
1
NEW 545.0 MW (GROSS)
327.0 MW (ESC)
COAL
.63 ZS LI6MTE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 8/79
COAL CREEK. 1 AND 2 ARE TWO PULVERIZED LIGNITE (0.63Z S, 6258 BTU/LB) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AND UNITED POWER. A COLD SIDE
ESP RECEIVES 2,200,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FOUR COUNTER-
CURRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED BY A BULK ENTRAINBENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40Z BYPASS REHEAT
WILL BE PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT ACID BRICK
LINED STACK. THE TOUER DESIGN SO? REMOVAL EFFICIENCY IS 90*. 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.
11
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COOPERATIVE POWER ASSOCIATION
COAL CREEK
2
NEW 545.0 nu (GROSS)
327.0 MW (ESC)
COAL
.63 ZS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 10/80
COAL CREEK 1 AND 2 ARE TWO PULVERIZED LIGNITE (0.63* S, 6258 BTU/LB) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AND UNITED POWER. A COLD SIDE
ESP RECEIVES 2,200tOQO ACFM OF FLUE GAS AND EXHAUSTS IT TO FOUR COUNTER-
CURRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED BY A BULK EKTRAlNMENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 4oz BYPASS REHEAT
WILL BE PROVIDED BEFORE THE CLEANED GAS EXITS THE 65Q FOOT ACID BRICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90Z. 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 OCTOBER, 1980.
DELHARVA POWER & LIGHT
DELAWARE CITY
1-3
RETROFIT 180.0 nu (GROSS)
160.0 MU (ESC)
COKE
7.50 ZS
UEU.HAN LORD
DAVY POUERGAS
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 4780
DELMARVA POWER & LIGHT'S DELAWARE CITY PLANT HAS FOUR BOILERSt THREE OF
WHICH HAVE STEAM CAPACITIES OF 500K LB/HR EACH. THE BOILERS GENERATE STEAM
AS WELL AS ELECTRICITY FOR GETTY REFINING AND MARKETING. LOW SULFUR CRUDE
OIL WILL BE REPLACED WITH COKE (7-8Z S) IN THE BOILER WHEN THE FGD SYSTEM
IS COMPLETE, IN APRIL, 1980. A VENTURI PART1CULATE SCRUBBER AND A WELLHAN-
LORD FGD SYSTEH (90X DESIGN EFFICIENCY) SUPPLIED BY DAvY POWER6AS ARE
PRESENTLY UNDER CONSTRUCTION. AN INDIRECT GAS REHEATER WILL BE USED*
THE SYSTEM WILL OPERATE IN AN OPEN WATER LOOP.
DUQUESNE LIGHT
ELK AHA
RETROFIT 510.0 nu (GROSS)
510.0 MU (ESC>
COAL
2.20 ZS
LIME
CHEMICO
ENERGY CONSUMPTION: 3.5Z
STATUS 1 STARTUP 10/?5
ELRAMA 1-4 OF DUQUESNE LIGHT CONSISTS OF FOUR PULVERIZED COAL (2.2* S,
11,350 BTU/LB) FIRED UNITS LOCATED IN ELRAMA, PENNSYLVANIA. THE EMISSION
CONTROL SYSTEM ON THIS SITE CONSISTS OF AN ESP FOLLOWED BY A MECHANICAL
COLLECTOR AND FIVE VARIABLE THROAT VENTURI LIME ABSORBER MODULES SUPPLIED
BY CHEMICO. WHICH ARE DESIGNED TO REMOVE 83Z 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 POZ-0-TEC STABILIZED SLUDGE IS HAULED TO AN OFF SITE LAND-
FILL. THE SYSTEM HAS BEEN OPERATIONAL SINCE OCTOBER, 1975.
DUQUESNE LIGHT
PHILLIPS
1-6
RETROFIT 403.0 NW (GROSS)
410.0 MU (ESC)
COAL
1.92 ZS BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: 3.4Z
STATUS 1 STARTUP 7/73
THE PHILLIPS POWER STATION OF DUQUESNE LIGHT CONSISTS OF SIX DRY BOTTOM
PULVERIZED COAL (2.2Z 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 R3% OF THE 502 FROM THE FLUE GAS. TWO CHEVRON MIST
ELIMINATORS/MODULE ARE FOLLOWED BY A DIRECT OIL FIRED REHEATER WHICH RAIS-
ES THE GAS TEMPERATURE BY 20 DEG F BEFORE IT LEAVES VIA A 340 FOOT TALL
ACID BRICK LINED STACK. THE SYSTEM ORERATES IN AN OPEN WATER LOOP, AND
THE POZ-0-TEC STABILIZED SLUDGE IS TRUCKED TO AN OFF SITE LANDFILL. THE
SYSTEM HAS BEEN OPERATIONAL SINCE JULY, 1973.
EAST KENTUCKY POWER COOP
SPURLOCK
2
NEW 500.0 MW (GROSS)
500.0 MW (ESC)
COAL
3.50 ZS
LIME
ADL/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 10/80
SPURLDCK 2 OF EAST KENTUCKY POWER COOPERATIVE IS A BALANCED DRAFT PULVER-
IZED COAL (3.5X S, 11,000 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN MAYS-
VILLE, KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP FOL-
LOWED BY AN AOL/COMBUSTION EQUIPMENT ASSOCIATES LIME FGD SYSTEM (90Z
DESIGN S02 REMOVAL EFFICIENCY). FLUE GAS FROM UNIT ONE WILL BE USED TO
REHEAT THE CLEANED GAS. THE SYSTEM, SLATED FOR START UP IN OCTOBER, 1980.
WILL EMPLOY A CLOSED WATER LOOP AND POZ-0-TEC SLUDGE STABILIZATION.
GENERAL PUBLIC UTILITIES
COHO
1
NEW 800.0 HW (GROSS)
800.0 MW (ESC)
COAL
3.50 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****Z
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 F*D SYSTEMS. THE UNIT AND F6D SYSTEM
ARE SCHEDULED TO START UP IN DECEMBER, 1988.
12
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
GENERAL PUBLIC UTILITIES
SEWARD
7
NEW 800.0 MW (GROSS)
800.0 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 12/87
GENERAL PUBLIC UTILITIES IS PLANNING A NEW UMTt SEWARD 7, TO BE BUILT IN
SEWARD, PENNSYLVANIA. THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS THE
EMISSION CONTROL STRATEGY, WITH NON-SLURRY TYPE LIME AND LIMESTONE SYSTEMS
LOOKING THE MOST PROMISING. START UP IS EXPECTED IN DECEMBER, 1987.
HOOSIER ENERGY
MEROW
1
NEW 490.0 nw (GROSS)
441.0 nw (ESC)
COAL
3.SO ZS
LIMESTONE
MITSUBISHI INTERNATIONAL
ENERGY CONSUMPTION: ****«
STATUS 3 STARTUP 4/81
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 1,732,000
ACFK OF FLUE GAS WHICH WILL 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 SLUDGE WILL
BE STABILIZED AND LANDflLLED, AND THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP OF UNIT 1 IS SCHEDULED FOR APRIL, 1981.
HOOSIER ENERGY
MEROM
2
NEW 490.0 HU (GROSS)
441.0 MW (ESC)
COAL
3.SO XS
LIMESTONE
MITSUBISHI INTERNATIONAL
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 1/82
BEROfl 1 AND 2 ARE TWO NEW UNITS BEING BUILT BY HOOSIER ENERGY IN SULLIVAN,
INDIANA. THESE PULVERIZED COAL (3.52 S) FIRED UNITS WITH PRODUCE 1,732,000
ACFM OF FLUE GAS WHICH WILL BE CLEANED BY A COLD SIDE ESP UPSTREAM OF A
MITSUBISHI LIMESTONE GRID TOWER ABSORBER (9DZ DESIGN SO? REMOVAL}. THE
SYSTEM WILL UTILIZE BYPASS REHEAT AND A 700 FOOT STACK. THE SLUDGE WILL
BE STABILIZED AND LANDFILLED, AND THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP OF UNIT 2 IS SCHEDULED FOR JANUARY, 19B2.
HOUSTON LIGHTING & POWER CO.
W.A. PARISH
8
NEW 550.0 MW (GROSS)
512.0 MW (ESC)
COAL
.60 2S SUBBITUMI NOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 11/82
W.A. PARISH 6 IS A PULVERIZED COAL (0.6X S, 8700 BTU/LB) FIRED UNIT PLAN-
NED BY HOUSTON LIGHTING AND POWER CO TO BE LOCATED IN THOMPSONS, TEXAS.
THE UTILITY HAS AWARDED A CONTRACT TO CHEHICO FOR A LIMESTONE
FGD SYSTEM WHICH WILL REMOVE 85Z OF THE FLUE GAS S02. REHEAT
WILL BE PROVIDED BY BYPASSING 7Z OF THE PARTICULATE CLEANED fLUE GAS.
SLUDGE WILL BE DEWAT£R£D, BLENDED WITH FLYASH, AND DISPOSED IN AN ON
SITE LANDFILL. START UP IS EXPECTED IN NOVEMBER, 1982.
INDIANAPOLIS POWER S. LIGHT
PETERSBURG
3
NEW 532.0 MW (GROSS)
532.0 MW
COAL
3.25 ZS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 2.4*
STATUS 1 STARTUP 12/77
PETERSBURG 3 OF INDIANAPOLIS POWER AND LIGHT IS LOCATED IN PETERSBURG,
INDIANA, AND BURNS 4.52 S BITUMINOUS COAL (11,000 BTU/LB). TWO COLD SIDE
ESP'S ARE LOCATED UPSTREAM OF 4 852 EFFICIENT UOP LIMESTONE TCA MODULES.
A HORIZONTAL MIST ELIMINATOR PRECEOE'S AN INDIRECT HOT AIR REHEATER THAT
BOOSTS THE GAS TEMPERATURE BY 30 DEC F BEFORE IT EXITS THE 616 FOOT RIGI-
FLAKE 4850 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 & LIGHT
PETERSBURG
4
NEW 530.0 MW (GROSS)
530.0 MW (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: ****Z
STATUS 2 STARTUP 10/83
PETERSBURG 4 OF INDIANAPOLIS POWER AND LIGHT IS A BITUMINOUS COAL (3.50% S
11,000 6TU/LB) FIRED BOILER UNDER CONSTRUCTION IN PETERSBURG, INDIANA. THE
LIMESTONE FGD SYSTEM FOR THIS UNIT WILL BE SUPPLIED BY RESEARCH COTTRELL.
THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP, AND SLUDGE WILL BE POZ-0-
TEC STABILIZED BEFORE PONDING. START UP IS SLATED FOR OCTOBER CF 1983.
13
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 197S
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KANSAS CITY POWER & LIGHT
HAWTHORN
3
RETROFIT 90.0 MW (GROSS)
90.0 MW (ESC >
COAL
.60 ZS BITUMINOUS
LIME
COMBUSTION ENGIKEERING
ENERGY CONSUMPTION: 2.2%
STATUS 1 STARTUP 11/72
HAWTHORN 3 Of KANSAS CITY PQUER AND LIGHT IS A 0 BY BOTTOM PULVERIZED
BITUMINOUS COAL (Q.6Z S, 980D BTU/LB) FIRE0 UNIT LOCATED IN KANSAS CITY,
MISSOURI, WHICH WAS CONVERTED FROM LIMESTONE FURNACE INJECTION AND TAIL
END SCRUBBING TO A LIME SLURRY SYSTEM. TWO COMBUSTION EN6INEER1N6 MARBLE
BED ABSORBERS, WHICH WERE DESIGNED TO REMOVE 70? OF THE FLUE GAS S02,
BEGAfc OPERATION IN JANUARY, 1977. ONE HORIZONTAL CHEVRON HIST ELIMINATOR
PER MODULE IS UPSTREAM OF AN IN-LINE FINNED TUBE REHEATER. WHICH RAjSES
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
SLUDtE POND. THE SYSTEM OPERATES IN ,A CLOSED WATER LOOP MODE.
KANSAS CITY POWER 8 LIGHT
HAWTHORN
4
RETROFIT 90.0 BW
90.0 My (ESO
COAL
.60 ZS BITUMINOUS
LIME
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 (0.6% 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 A8SORBERS, WHICH WERE DESIGNED TO REMOVE 701 OF THE FLUE 6AS SO?,
BEGAN OPERATION IN JANUARY, 1977. ONE HORIZONTAL CHEVRON HIST 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 A CLOSED WATER LOOP MODE.
KANSAS CITY POWER R LIGHT
LA CVGNE
1
NEW 874.0 MW (GROSS)
874.0 MW (ESC)
COAL
5.39 ZS SUBblTUMINOUS
LIMESTONE
BABCOCK K UILCOX
ENERGY CONSUMPTION: 2.7*
STATUS 1 STARTUP 2/73
LA CYGNE 1 IS A WET BOTTOM, CYCLONE FIRED PULVERIZED SUBBITUMI NOUS COAL
(5.39!! S, 9421 BTU/LB) FIRED UNIT OF KANSAS CITY POWER AND LIGHT, LOCATED
IN LA CYGNE, KANSAS. THE EMISSION CONTROL SYSTEM CONSISTS Of EI6HT VARIA-
BLE THROAT VENTURI/LIHESTONE SIEVE TRAY TOWER TRAINS SUPPLIED BY BABCOCK
AND UILCOX. EACH 80Z (S02 REMOVAL, DESIGN) EFFICIENT TRAIN IS FOLLOWED BY
A COMBINATION SIEVE TRAY AND CHEVRON MIST ELIMINATOR, FOLLOWED BY AN INDI-
RECT REHEATER. THE CLEANED GAS EXITS THROUGH A 700 FOOT STEEL LINED STACK.
THE SYSTEM OPERATES IN A CLOSED HATER LOOP, AND THE SCRUBBER SLUDGE IS
DISPOSED IK AN UNLINED POND. INITIAL OPERATIONS OF THE FGD SYSTEM BEGAN IN
FEBRUARY, 1973.
KANSAS POWER & LIGHT
JEFFREY
1
NEW 720.0 MW (GROSS)
540.0 MW (ESC)
COAL
.32 ZS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 8/78
KANSAS CITY POWER AND LIGHT'S JEFFREY 1 IS A TAN6ENTIAL FIRED PULVERIZED
COAL (0.32% S, 8125 BTU/LB) UNIT IN WAMEGO, KANSAS. THE EMISSION CONTROL
SYSTEM FOR THIS UNIT CONSISTS Of A COLD SIDE ESP FOLLOWED BY SIX CONE
SPARE) LIMESTONE SPRAY TOWER MODULES SUPPLIED BY COMBUSTION ENGINEERING.
THE DESIGN S02 REMOVAL EFFICIENCY IS 502 (INCLUDING A 30Z BYPASS REHEAT).
HAS BEEN OPERATIONAL SINCE AUGUST, 1978.
KANSAS POWER & LIGHT
JEFFREY
2
NEW 700.0 MW (GROSS)
490.0 MW (ESC)
COAL
.30 ZS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****Z
STATUS 2 STARTUP 6/80
UNIT 2, PRESENTLY UNDER CONSTRUCTION AT KANSAS POWER AND LIGHT'S JEFFREY
ENERGY CENTER IN JEFFREY, KANSAS, WILL BURN 0.3Z S PULVERIZED COAL C8100
6TU/LB). THIS UNIT'S EMISSION CONTROL SYSTEM WILL CONSIST OF A COLD SIDE
ESP AND COMBUSTION ENGINEERING LIMESTONE SPRAY TOWERS. A 3QZ FLUE GAS
BYPASS WILL PROVIDE REHEAT OF THE CLEANED GAS BEFORE IT EXITS THROUGH A
600 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 CN-SlTE
CLAY LINED POND. SCHEDULED START UP OF THE SYSTEM IS JUNE 1980.
LIGHT
.0 nw
.0 MW
(GROSS)
(ESC)
KANSAS POWER
LAWRENCE
4
RETROFIT 125,
125.
COAL
.55 ZS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *»***
STATUS 1 STARTUP 1/76
LAWRENCE 4 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT. TANGENTIAL FIRED
PULVERIZED COAL (0.55Z S, 10,000 BTU/LB) UNIT LOCATED IN LAWRENCE, KANSAS.
A NEW COMPUSTION ENGINEERING LIMESTONE ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MARBLf BFD TAIL END SCRUBBER IN JANUARY, 1977. THE
SYSTEM TREATS 403,000 AC F« OF FLUE GAS, WITH A DESIGN S02 REMOVAL OF
73Z. MIST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS AND ONE BULK
ENTRAPMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DEC F BEFORE
IT IS EXHAUSTED THROUGH A 120 FOOT STACK. THE SLUDGE IS DISPOSED IN AN
UNLIKED INTERIM POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTE" OPERATES IN A CLOSED WATER LOOP.
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KANSAS POWER i. LIGHT
LAURENCE
5
RETROFIT 420.0 MW (GROSS)
420.0 HW CESC)
COAL
.55 ZS
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 BTU/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 APRIL, 1978. THE
SYSTEM TREATS 403,000 ACFM Of FLUE GAS, WITH A DESIGN S02 REMOVAL OF
73X. HIST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS AND ONE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO NODULES. A FINKED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DEC F BEFORE
IT IS EXHAUSTED THROUGH A 1?D 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 MU (GROSS)
64.0 MW (ESC)
COAL
4.00 ZS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 3.1Z
STATUS 1 STARTUP 9/75
GREEK RIVER 1-3 OF KENTUCKY UTILITIES ARE THREE DRY BOTTOM PULVERIZED
BITUMINOUS COAL (4Z S, 11.COO BTU/LB,} FIRED UNITS LOCATED IN CENTRAL
CITY, KENTUCKY. EACH BOILER SUPPLIES 360,000 ACFH OF FLUE 6AS TO A
VARIABLE THROAT VENTURI FOLLOWED BY AN AMERICAN AIR FILTER LIME MOBILE
BED CONTACTOR (80* DESIGN S02 REMOVAL EFFICIENCY). A RADIAL VANE MIST
ELIMINATOR IS FOLLOWED BY A STEAM TUBE REHEATER AND A 165 FOOT STACK.
SLUDGE IS DISPOSED IN AN ON-SITE UNLINED POND. AND THE SYSTEM OPERATES
IN A CLOSED WATER LOOP. THE SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER.
1975.
LAKELAND UTILITIES
MCINTOSH
3
NEW 364.0 MW (GROSS)
364.0 MU (ESC)
COAL
2.56 XS BITUMINOUS
LIMESTONE
BABCOCK R W1LCOX
ENERGY CONSUMPTION: ****Z
STATUS 3 STARTUP 10/81
KCINTOSH 3 OF LAKELAND UTILITIES IS A PLANNED UNIT TO BE LOCATED IN LAKE-
LAND. FLORIDA. BABCOCK AND WILCOX HAS BEEN AWARDED A CONTRACT TO SUPPLY AN
85Z EFFICIENT (S02) LIMESTONE FGD SYSTEM FOR THIS UNIT. THE EMISSION CON-
TROL SYSTEM WILL CONSIST OF A COLD SIDE ESP FOLLOWED BY TWO PARALLEL FGD
MODULES AND A 250 FOOT ACID BRICK LINED STACK. THE SYSTEM WILL OPERATE IN
A CLOSED WATER LOOP, AND THE P07-0-TEC STABILIZED SLUDGE WILL BE USED AS
A CONSTRUCTION BASE. CONSTRUCTION IS SET TO BEGIN IN EARLY 198C AND START
UP IS SCHEDULED TO BE IN OCTOBER, 1981.
LOUISVILLE GAS & ELECTRIC
CANE RUN
4
RETROFIT 188.0 MU (GROSS)
188.0 MU (ESC)
COAL
3.75 ZS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6Z
STATUS 1 STARTUP 8/76
UNIT I AT LOUISVILLE GAS AND ELECTRIC'S CANE RUN STATION IS A PULVERIZED
BITUMINOUS COAL (3.75Z S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. AN ESP AND TWO AMERICAN AIR FILTER CARBIDE LIME MOBILE BED ABSORBER
MODULES (85Z DESIGN S02 REMOVAL) TREAT 734,000 ACFM OF FLUE GAS FROM THE
BOILER. TWO CHEVRON MIST ELIMIUATORS/.MODULE ARE FOLLOWED BY A DIRECT
COMBUSTION REHEATER AND A 250 FOOT STACK. THE WATER LOOP IS OPEN, AND
THE SLUDGE IS DISPOSED IN AN ON-SITE LINED POND. THIS RETROFIT SYSTEM
HAS BEEN OPERATIONAL SINCE AUGUST, 1976.
LOUISVILLE GAS & ELECTRIC
CANE RUN
5
RETROFIT 190.0 MW (GROSS)
190.0 MW (ESC)
COAL
3.75 ZS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.6Z
STATUS 1 STARTUP 12/77
CANE RUN 5 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS COAL
(3.75X S, 11,500 BTU/LB) FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY. THE
BOILER SUPPLIES 700,000 ACFM OF FLUE GAS TO AN EMISSION CONTROL SYSTEM
CONSISTING OF AN ESP FOLLOWED AND TUO COMBUSTION ENGINEERING 85X EFFICIENT
(DESIGN) CARBIDE LIME SPRAY TOWERS. A STEAM TUBE REHEATER RAISES THE 6AS
TEMPERATURE 40 DEG F. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE, AND
THE SLUDGE IS POZ-0-TEC STABILIZED. OPERATION OF THIS RETROFIT SYSTEM
BEGAN IN DECEMBER, 1977.
LOUISVILLE GAS & ELECTRIC
CANE RUN
6
RETROFIT 288.0 «U (GROSS)
288.0 MW (ESC)
COAL
4.60 ZS BITUMINOUS
DUAL ALKALI
AOL/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: 1.0Z
STATUS 1 STARTUP 4/79
LOUISVILLE GAS AND ELECTRIC'S CANE RUN 6 IS A PULVERIZED BITUMINOUS COAL
(3.75Z S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KENTUCKY. ADL/COMBUS-
TION E8UIPMENT ASSOCIATES SUPPLIED A RETROFIT DUAL ALKALI DEMONSTRATION
FGD SYSTEM FOR THIS UNIT. THE EMISSION CONTROL SYSTEM, DESIGNED TO REMOVE
952 CF THE FLUE GAS S02, CONSISTS OF A COLD SIDE ESP AND TUO TRAY TOWER
MODULES. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND TUO
DIRECT COMBUSTION REHEATERS BEFORE EXITING A 518 FOOT STACK. THE WATER
LOOP IS OPEN, AND THE SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED POND.
FOR A ONE YEAR PERIOD FOLLOWING THE FIRST QUARTER OF OPERATION (UHICH BE-
GAN IN APRIL, 1979), THE U.S.EPA WILL SUBSIDIZE A MAX OF $4.5 *M FOR OPER
ATIOK, R&D, AND REPORT WRITING (NOT APPLIED TO ANY CAPITAL EXPENDITURES).
15
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE GAS & ELECTRIC
HILL CREEK
1
RETROFIT 358.0 nw (GROSS)
558.0 MW (ESC)
COAL
3.75 XS
LIME/LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS Z STARTUP 4/81
MILL CREEK 1 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT LIME FGD SYSTEM IS PRESENTLY UNDER CONSTRUCTION ON THIS
PULVERIZED COAL (3.752 S, 11,500 BTU/LB) FIRED UNIT. COMBUSTION ENGINEER-
ING IS SUPPLYING A LIME FGD SYSTEM UHICH WILL COMPLT WITH LOCAL EMISSION
STANDARDS BY APRIL OF 1981.
LOUISVILLE GAS & ELECTRIC
MILL CREEK
2
RETROFIT 350.0 MU (GROSS)
350.0 HW (ESC)
COAL
3.75 XS
LIME/LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 2 STARTUP 4/82
KILL CREEK 2 OF LOUISVILLE GAS AMD ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT LIME FGD SYSTEM IS PRESENTLY UNDER CONSTRUCTION ON THIS
PULVERIZED COAL (3.752 S, 11,500 BTU/LB) FIRED UNIT. COMBUSTION ENGINEER-
ING IS SUPPLYING A LIME FGD SYSTEM WHICH HILL COMPLY WITH LOCAL EMISSION
STANDARDS BY APRIL OF 1982.
LOUISVILLE GAS & ELECTRIC
MILL CREEK
3
NEW 442.0 MW (GROSS)
442.0 My (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 8/78
LOUISVILLE GAS AND ELECTRIC'S MILL CREEK 3 IS A 3.75Z S COAL (11,500 BTU/
LB> FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY. AMERICAN AIR FILTER SUP-
PLIED A CARBIDE LIKE FGD SYSTEM FOR !THIS UNIT WHICH WAS DESIGNED TO REMOVE
85X OF THE S02 FROM THE FLUE GAS. AN ESP IS FOLLOWED BY FOUR MOBILE BED
SPRAY TOWERS AND A STEAM TUBE REHEATER. THE WATER LOOP IS OPEN, AND THE
FLYASH AND LIME STABILIZED SLUDGE IS PONDED. THIS UNIT HAS BEEK OPERATION-
AL SINCE AUGUST, 1978.
LOUISVILLE GAS & ELECTRIC
MILL CREEK
4
NEW 495.0 NU (GROSS)
495.0 MW (ESC)
COAL
3.75 XS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: "**X
STATUS 2 STARTUP 7/81
MILL CREEK 4 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS
COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN LOUISVILLE.
KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP AND FOUR
MOBILE BED SPRAY TOWERS. THE SYSTEM'S WATER LOOP WILL BE CLOSED, AND
THE SLUDGE WILL BE STABILIZED WITH LIME AND FLYASH. STEAM TUBES WILL
PROVIDE REHEAT OF THE CLEANED GASES. THE SYSTEM IS SCHEDULED TO START
UP 1H JULY OF 1981.
LOUISVILLE GAS I ELECTRIC
PADDY'S RUN
6
RETROFIT 72.0 MW (GROSS)
72.0 MW (ESC)
COAL
2.50 XS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.8X
STATUS 1 STARTUP 4/73
UNIT 5 AT LOUISVILLE GAS AND ELECTRIC'S PADDY'S RUN STATION IS A DRV BOT-
TOM PULVERIZED COAL (2.5X S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. A RETROFIT CARBIDE LIME FGD SYSTEM BY COMBUSTION ENGINEERING TREATS
400,030 ACFM OF FLUE GAS FROM THE BOILER. AN ESP IS FOLLOWED BY TWO MARBLE
BED ABSORBERS, A DIRECT COMBUSTION RIEHEATER, AND A 250 FOOT STACK. MIST
ELIMINATION IS PROVIDED BY ONE CHEVRJJN/HODULE • THE LIME FIXATED SLUDGE IS
TRUCKED TO AN UNLINED POND, AND THE WATER LOOP IS CLOSED. TH£ FGD SYSTEM
BEGAN INITIAL OPERATIONS IN APRIL, 1973.
LOUISVILLE GAS i. ELECTRIC
TRIMBLE COUNTY
1
NEW 575.0 MW (GROSS)
575.0 MW (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 BE INSTALLING FGD SYSTEMS ON TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 4X S (IF NO COAL WASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS WILL BE CLEANED BY ESP'S AND WET SCRUBBING (90JI REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 1 IS SCHEDULED
FOR START UP IN JULY OF 1984.
16
-------
EPA UTI.LITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS Of FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE GAS K ELECTRIC
TRIMBLE COUNTY
2
NEW 575.0 MW (GROSS)
575.0 My (ESC)
COAL
4.00 ZS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 7/86
LOUISI/1LLE 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 PULVERI7ED 4% S (IF NO COAL WASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS WILL BE CLEANED BY ESP'S AND WET SCRUBBING (901 REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 2 IS SCHEDULED
FOR START UP IN 1986.
MIDDLE SOUTH UTILITIES
ARKANSAS COAL
5
NEW 890.0 KU (GROSS)
890.0 MU (ESC)
COAL
.50 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 1/86
MIDDLE SOUTH UTILITIES HAS AWARDED CONTRACTS ON SIX NEW LOW SULFUR (0.5X)
COAL FIRED UNITS. THE UTILITY IS CURRENTLY REQUESTING/EVALUATING elDS FOR
THE FGD SYSTEMS, ALTHOUGH THE TYPE OF SYSTEM HAS NOT BEEN DECIDED. ARKAN-
SAS COAL 5 IS SCHEDULED TO BEGIN OPERATIONS IN JANUARY, 1986.
MIDDLE SOUTH UTILITIES
ARKANSAS COAL
6
NEW 890.0 HW (GROSS)
890.0 MU
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MIDDLE SOUTH UTILITIES HAS AWARDED CONTRACTS ON SlX~NEW LOW SULFUR (0.5X>
COAL FIRED UNITS. THE UTILITY IS CURRENTLY REQUeSTiNfi/EV*LU*T11. THE CLEANED GAS PASSES THROUGH A CHEVRON
MIST ELIMINATOR BEFORE IT JOINS A 15* BYPASS REHEAT AND EXITS A 550 FOOT
STACK. THE WATER LOOP IS OPEN, AND THE SLUDGE IS TRUCKED TO AN OFF-SITE
M1NEFILL. THIS SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER, 1977.
MONTANA POWER
COLSTRIP
1
NEW 360.0 MW (GROSS)
360.0 HW (ESC)
COAL
.77 XS SUBB1TUMINOUS
LIME/ALKALINE FLYASH
AOL/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: J.3Z
STATUS 1 STARTUP 9/75
COLSTRIP 1 OF MONTANA POWER IS A SUBBITUMINOUS COAL (0.77X S, 8843 BTU/LB)
FIRED UNIT LOCATED IN COLSTRIP, MONTANA. ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES SUPPLIED A LINE/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON MIST ELIMINATORS, A STEAM TUBE REHEATER, AND A 500
FOOT STACK. THE UNSTAfiILIZE0 StUDGE IS DISPOSED IN AN ON-S1TE LINED POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN SEPTEMBER OF 1975.
MONTANA POWER
COLSTRIP
2
NEW 360.0 MW (GROSS)
360.C MW (ESC)
COAL
.77 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 5/76
COLSTRIP 2 OF MONTANA POWER IS A SUBBITUMINOUS COAL (0.77Z S, 8843 BTU/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 TOWER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON MlST ELIMINATORS, A STEAM TUBE REHEATER. AND A 500
FOOT STACK. THE UNSTABILIZED SLUDGE IS DISPOSED I" AN ON-SlTE LINED POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN MAY OF 1976.
MONTANA POWER
COLSTRIP
3
NEW 700.0 MW (GROSS)
700.0 MW (ESC)
COAL
.70 ZS
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: ****Z
STATUS 2 STARTUP 1/84
MONTANA POWER'S COLSTRIP 3 IS A PLANNED LOW SULFUR COAL (0.7Z S, 8800 BTU/
LB) FIRED UNIT TO BE LOCATED IN COLSTRIP, MONTANA. A CONTRACT MAS BEEN
AWARDED TO ADL/COMBUSTION EQUIPMENT ASSOCIATES FOR A LIME/ALKALINE FLVASH
FGD SYSTEM ON THIS UNIT. START UP IS SCHEDULED FOR JANUARY, 1584.
18
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MONTANA POWER
COISTR1P
4
NEW 7CD.O MW
700.0 MW (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
ADL/COHBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 0/84
MONTANA POWER'S COLSTRIP 4 IS A PLANNED LOW SULFUR COAL (0.7* S» 8800 BTU/
LB) FIRED UNIT TO BE LOCATED IN COLSTRIP, MONTANA. A CONTRACT HAS BEEN
AWARDED TO ADL/COMBUSTION EQUIPMENT ASSOCIATES FOR A LINE/ALKALINE FLVASH
FGD SYSTEM ON THIS UNIT. START UP IS SCHEDULED FOR 1984.
IXUSCATINE POWER g WATER
MUSCATINE
9
N£U 160.0 MW (GROSS)
160.0 MW (ESC)
COAL
.30 ZS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 5.0Z
STATUS 5 STARTUP 9/82
MUSCAT1NE 9 IS A PULVERIZED BITUMINOUS COAL (31 S. 11.200 BTU/LB) FIRED
UNIT PLANNED BY MUSCATINE POWER AND WATER TO BE LOCATED IN MUSCATINE.
IOWA. THE UTILITY IS CONSIDERING LIKE AND LIMESTONE SLURRY SYSTEMS FOR
EMISSION CONTROL. THE F6D SYSTEM WILL FEATURE AN ESP, TWO 1002 CAPACITY
TOWERS, STEAM COIL REHEAT. A CLOSED WATER LOOP, AND FORCED OXIDATION OF
THE SLUDGE BEFORE LANDFILL. THE DESIGN Sfl2 REMOVAL HILL BE 941. START UP
WILL TAKE PLACE IN 1982.
NEVADA POWER
HARRY ALLEN
1
NEW soo.o nw (GROSS)
500.Q MW (ESC)
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 6/86
NEVADA POWER'S HARRY ALLEN 1 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IK CONJUNC-
TION U1TH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT VET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE, 1986.
NEVADA POWER
HARRY ALLEN
2
NEW 500.0 MW (GROSS)
SOO.O MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 6/87
NEVADA POWER'S HARRY ALLEN 2 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE, 1987.
•NEVADA POWER
HARRY ALLEN
3
MEW 500.0 MW (GROSS)
500.0 MW (ESC)
COAL
***** %s
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 VET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE, 1988.
NEVADA POWER
HARRY ALLEN
4
NEW 500.0 MW (GROSS)
500.0 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 6/89
NEVADA POWER'S HARRY ALLEN 4 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT VET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE, 1989.
19
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEVADA POWER
REID GARDNER
1
RETROFIT 125.0 MW CGROSS>
125.0 MW CESC>
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 4/74
REID GARDNER 1 IS A WET BOTTOM LOU SULFUR COAL CQ.5Z S, 12.450 BTU/LB)
FIRED UNIT OWNED BY NEVADA POWER, LOiCATED IN MOAPA, NEVADA. A SODIUM CAR-
BONATE-BASED (TRONA) SCRUBBING SYSTEM BY ADI/COMBUSTION EQUIPMENT ASSOCI-
ATES CONSISTS OF ONE MODULE CONTAINING TUIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFORATED PLATE MASH
TOWER. PRIMARY PARTICUL«T£ CONTROL IS PROVIDED BY UPSTREAM MULTICIONES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM HOT AIR REHEATER
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN UATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION POND. THE
DESIGN SO? REMOVAL EFFICIENCY IS 90Z. THE SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL, 1974.
NEVADA POWER
REID GARDNER
2
RETROFIT 125.0 MW (GROSS)
125.0 MU
COAL
.50 ZS BITUMINOUS
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIA'
ENERGY CONSUMPTION: ****!
STATUS 1 STARTUP 4/74
REID GARDNER 2 IS A WET BOTTOM LOW SULFUR COAL (0.5* S, 12,450 BTU/LB)
FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA. A SODIUM CAR-
BONATE-BASED (TRONA) SCRUBBING SYSTEM BY ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFORATED PLATE WASH
TOWER. PRIMARY PARTICULATE CONTROL IS PROVIDED BY UPSTREAM MULTICLONES.
A RADIAL VANE HIST ELIMINATOR PRECEDES AN INDIRECT STEAM HOT AIR REHEATER
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN UATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SIT£ CLAY LINED SOLAR EVAPORATION POND. THE
DESIGN S02 REMOVAL EFFICIENCY IS 90%. THE SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL, 1974
NEVADA POWER
REID GARDNER
3
NEW 125.0 MM (GROSS)
125.0 MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
ADI/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 6/76
REID GARDNER 3 IS A WET BOTTOM LOW SJULFUR COAL (0.5Z S, 12.450 BTU/LB)
FIRED UNIT OWNED BY NEVADA POWERt LOCATED IN HOAPA, NEVADA. A SODIUM CAR-
BONATE-BASED (TRONA) SCRUBBING SYSTEM BY ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFORATED PLATE WASH
TOWER. PRIMARY PARTICIPATE CONTROL IS PROVIDED BY UPSTREAM MULTICLONES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM HOT AIR REHEATER
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN UATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION POND. THE
DESIGN S02 REMOVAL EFFICIENCY IS 90Z. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE, 1976.
NEVADA POWER
REID GARDNER
4
NEU 250.0 MW (GROSS)
250.0 NW (ESC)
COAL
.75 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***
-------
EPA UTILITY FGD SURVEY! THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEW ENGLAND ELECTRIC SYSTEM
BRAYTON POINT
3
RETROFIT 650.0 MW (GROSS)
650.0 MW (ESC)
OIL
2.20 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION! *****
STATUS 7 STARTUP 0/0
THE BRAYTON POINT 3 UNIT OF THE NEW ENGLAND ELECTRIC SYSTEM IS LOCATED IN
SOMERSET, MASSACHUSETTS. THE UNIT IS CURRENTLY FIRING LOW SULFUR FUEL OIL
BUT THE EPA HAS GIVEN THE UTILITY PERMISSION TO BURN 1.5Z SULFtR COAL.
THE UTILITY IS INVESTIGATING VARIOUS ADVANCED RE6ENERABLE FGD SYSTEMS
WHICH OFFER A BREAKTHROUGH IN OPERATING COSTS AND PRODUCE ELEMENTAL SULFUR
AS Ah END PRODUCT.
NEW YORK STATE ELEC & GAS
SOMERSET
1
NEW 870.0 nu (GROSS)
870.0 MW (ESC)
BITUMINOUS
***** ZS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****Z
STATUS 6 STARTUP 6/84
THE SOMERSET 1 UNIT OF THE NEW YORK STATE ELECTRIC 8 GAS CORP. IS A
PULVERIZED COAL BOILER LOCATED IN SOMERSET, NEW YORK. THE BOILER
GENERATES A FLUE GAS FLOW OF 3,100,000 ACFM AND FIRES A BITUMINOUS COAL
WITH AN AVERAGE SULFUR CONTENT OF 2.4% AND AN AVERAGE HEAT CONTENT OF
12.4DO BTU/LB. A COLD SIDE ESp WITH A DESIGN EFFICIENCY OF 99.77X WILL
PROVIDE THE PRIMARY PARTICULATE REMOVAL. A LIMESTONE ABSORBER WITH A
DESIGN REMOVAL EFFICIENCY OF >90Z WILL BE USED FOR S02 REMOVAL. THE
SYSTEM WILL OPERATE IN A CLOSED LOOP MODE. THE SLUDGE IS TO BE DEWATERED
AND STABILISED BEFORE BEING LANDFILLED.
NIAGARA MOHABK POWER COOP
CHARLES R. HUNTLEV
66
RETROFIT 100.0 MW (GROSS)
IGO.O nw CESO
COAL
1.80 ZS
AQUEOUS CARBONATE
ROCKWELL INTERNATIONAL
ENERGY CONSUMPTION: ****Z
STATUS 2 STARTUP */82
CHARLES R. HUNTLEY 66 OF NIAGARA POWER COOP IS A PULVERIZED COAL (1.8Z S,
12,5CD BTU/LB) FIRED UNIT LOCATED IN BUFFALO, NEW YORK. A CONTRACT WAS
AWARDED TO ATOMICS INTERNATIONAL FOR THE DESIGN AND INSTALLATION OF A 90X
EFFICIENT RETROFIT AQUEOUS CARBONATE FGD SYSTEM WHICH WILL PRODUCE ELEMEN-
TAL SULFUR AS AN END PRODUCT. FUNDS ARE BEING PROVIDED BY THE U.S.EPA AND
THE EMPIRE STATE ELECTRIC ENERGY RESEARCH CORP. A SPRAY DRYER HILL BE
FOLLOWED BY TWO BANKS OF EIGHT CYCLONES AN ESP, AND A 200 FOOT STEEL LINED
STACK. THE WATER LOOP WILL BE OPEN. START UP OF THE FGD SYSTEM WILL BE IN
1982.
NORTHERN INDIANA PUB SERVICE
BAlLLf
7
RETROFIT 190.0 BW (GROSS)
190.0 m» CESO
COAL
3.00 ZS
PROCESS HOT SELECTED
VENDOR NOT SELECTED
EMEBGY CONSUMPTION: ****Z
STATUS 6 STARTUP O/ 0
BAILLY 7 OF NORTHERN INDIANA PUBLIC SERVICE IS A 3Z SULFUR COAL FIRED UNIT
IN CHESTERTON, INDIANA. THE UTILITY IS CURRENTLY CONSIDERING RETROFITTING
A LIRE OR LIMESTONE FGS ON THIS BOILER AND IS WAITING FOR PERFORMANCE RE-
SULTS FROM THE WELLMAN LORD UNIT IN SERVICE ON DEAN H. BITCHELL 11. LOW
SULFUR COAL MAY BE BURKED TO COMPLY WITH S02 EMISSION REGULATIONS. APPLI-
CABLE INDIANA S02 REGULATIONS ARE STILL NOT FIRMLY ESTABLISHED.
NORTHERN INDIANA PUB SERVICE
BAILLY
8
RETROFIT ',00,0 nw (GROSS)
400.0 MU (ESC)
COAL
3.00 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP O/ 0
BAILLY 8 OF NORTHERN INDIANA PUBLIC SERVICE IS A 32 SULFUR COAL FIRED UNIT
IN CHESTERTON, INDIANA. THE UTILITY IS CURRENTLY CONSIDERING RETROFITTING
A LIME OR LIMESTONE FGD ON THIS BOIUER AND IS WAITING FOR PERFORMANCE RE-
SULTS FROM THE WELLMAN LORD UNIT IN SERVICE ON DEAN H. MITCHELL 11. LOW
SULFUR COAL HAY BE BURNED TO COMPLY WITH S02 EMISSION REGULATIONS. APPLI-
CABLE INDIANA S02 REGULATIONS ARE STILL NOT FIRMLY ESTABLISHED.
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
RETROFIT 115.0 MW (GROSS)
115.0 MW (ESC)
COAL
3.50 ZS
WELLMAN LORD
DAVY POWERGAS
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 7/76
NORTHERN INDIANA PUBLIC SERVICE'S DEAN H. MITCHELL 11 IS A COAL O.5Z S,
11,OCD BTU/LB) FIRED UNIT LOCATED IN GARY, INDIANA. A RETROFIT WELLMAN
LORD FGD SYSTEM BY DAVY POUERGAS HAS BEEN OPERATING ON THIS UNIT SINCE
JULY, 1976. AN ESP IS FOLLOWED BY A VARIABLE THROAT VENTUR1 SCRUBBER
AND A TRAY TOWER ABSORBER (90Z DESIGN S02 REMOVAL EFFICIENCY). A DIRECT
COMBUSTION RAISES THE CLEANED GAS TEMPERATURE 50 DEG F BEFORE THE GAS
IS DISCHARGED THROUGH A 168 FOOT STAINLESS STEEL AND FRP LINED STACK.
ELEMENTAL SULFUR AND SULFATE IS PRODUCED BY THE PROCESS DEVELOPED BY
ALLIED CHEMICAL. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.
21
-------
EPA UTILITY FGD SURVEY: THIKD QUARTER 1979
SECTION 2
STATUS OF fGD SYSTEMS
UNIT IDENTIf1CAT10N
ABSTRACT
NORTHERN INDIANA PUH SERVICE
SCHAHFER
17
NEW 421.0 MW (GROSS)
121.0 MW (ESc>
COAL
3.20 XS IUTUM1NOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***%
STATUS 5 STARTUP 6/83
SCHAHFER 17 OF NORTHE»N INDIANA PUBLIC SERVICE IS A 3.2X SULFUR COAL FIRED
UNIT PLANNED FOR CONSTRUCTION IN WHEATflELO, INDIANA. THE UTILITY IS
REQUESTING/EVALUATING BIDS FOR F6D SYSTEMS FOR THIS UNIT. ALTHOUGH THE S02
CONTROL STRATEGY HAS NOT BEEN SELECTED, THE UTILITY IS CONSIDERING A SODI-
UM ElAStD SYSTEM. PARTICULATE MATTER WILL BE CONTROLLED BY AN ESP, AND THE
SYSTEM WILL INCLUDE A REHEATER. START UP IS SCHEDULED FOR JUNE OF 1983.
NORTHERN INDIANA PUB SERVICE
SCHAHFER
18
NEW 421.0 HW (GROSS)
421.0 MU (ESC)
COAL
3.20 XS EITiJMlNOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 6/85
SCHAHFER 18 OF NORTHERN INDIANA PUBLIC SERVICE IS A 3.2Z SULFUR COAL FIRED
UNIT PLANNED FOR CONSTRUCTION IN WHEATFIELD, INDIANA. THE UTILITY IS
REQUESTING/EVALUATING BIDS FOR FGD SYSTEMS FOR THIS UNIT. ALTHOUGH THE S02
CONTROL STRATEGY HAS NOT BEEN SELECTED, THE UTILITY IS CONSIDERING A SODI-
UM BASED SYSTEM. PARTICULATE MATTER WILL BE CONTROLLED BY AN ESP, AND THE
SYSTE1 WILL INCLUDE A REHEATER. ST*RT UP IS SCHEDULED FOR JUNE OF 1985.
NORTHERN STATES POWER
SHERBURNE
1
NEW 740.0 MW (GROSS)
740.0 HW (ESC)
COAL
.£0 XS SUBBITUMINOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.72
STATUS 1 STARTUP 3/76
NORTHERN STATES POyER'S SHERBURNE 1 IS A BALANCED DRAFT PULVERIZED SUBBI-
TUMIKOUS COAL (0.80% S, 8500 BTU/LB> FIRED BOILER IN BECKER, MINNESOTA. A
50* EFFICIENT (DESIGN) LINE STONE /ALICALINE FLYASH FGD SYSTEM SUPPLIED BT
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MARCH OF
1976. TWELVE VARIABLE THROAT ROD DECK VENTURI/«ARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MIST ELIfllNATORS/TRAIN, AN IN-LINE HOT WATER
REHEATER, AND A 650 FOOT CORTEM LINED STACK. THE SLUDGE IS FORCIBLY 0X1
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE HATER LOOP IS OPEN.
NORTHERN STATES POWER
SHERBURNE
2
NEW 740.0 MW (GROSS)
740.0 MW (ESC)
COAL
.83 ZS SUBblTUMlNOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.7X
STATUS 1 STARTUP 4/77
NORTHERN STATES POWER'S SHERBURNE 2 IS A BALANCED DRAFT PULVERIZED SUBBI-
TUMINOUS COAL (0.807 S, 8500 BTU/LB) FIRED BOILER IN BECKER, MINNESOTA. A
50% EFFICIENT (DESIGN) LIKE STONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE APRIL OF
1977. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MIST ELIMINATORS/TRAIN, AN IN-LINE HOT BATER
REHEATER, AND A 650 FOOT CORTEM LINED STACK. THE SLUDGE IS FORCIBLY OX I
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LOOP IS OPEN.
NORTHERN STATES POWER
SHERBURNE
3
NEW 860.0 MW (GROSS)
860.0 MW (ESC )
COAL
.80 %S
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****Z
STATUS 5 STARTUP 5/84
SHER6URNE 3 IS A PLANNED TANGENTIAL :FIREO PULVERIZED SUBBITUMINOUS COAL
(0.30Z S, 8500 BTU/LB) FIRED UNIT TO BE CONSTRUCTED IN BECKER, MINNESOTA
NORTHERN STATES POWER. 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. KAY, 198* IS EXPECTED START UP.
OTTER TAIL PO.ER
COYOTE
1
NEW 440.0 MW (GROSS)
440.0 MW (ESC)
COAL
.57 ZS LIGMTE
AQUEOUS CARBONATE/SPRAY DRYING
WHEELABRATOR-FRYE/R.I.
ENERGY CONSUMPTION: 1.1*
STATUS 2 STARTUP 3/81
COYOTE 1 IS A CYCLONE FIRED PULVERIZED LIGNITE C0.875X 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 AND
CONSTRUCTOR. AN AQUEOUS CARBONATE DRY FGO SYSTEM DESIGNED TO REMOVE 70X
OF THE S02 IS BEING SUPPLIED BY WHEELABRATOR-FRTE AND ATOMICS INTERNATION-
AL. THE SPRAY DRYER/9AGHOUSE SYSTEM IS SCHEDULED TO START UP IN 1981.
-------
EPA UTILITY FGD SURVEY: THIRo OUARTfR 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PACIFIC GAS 8 ELECTRIC
MONTEZUKA
1
NEW 800.0 MW (GROSS)
800.0 MU (ESC)
COAL
.80 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 6/86
FOSSIL 1 OF PACIFIC GAS AND ELECTRIC IS A COAL (0.8X S, 12,000 BTU/LB)
FIRED BOILER PLANNED FOR COLLINSVILUE , CALIFORNIA. THE EMISSION CONTROL
SYSTEW WILL CONSIST OF A BAGHOUSE AND A LIMESTONE FGD SYSTEM. SLUDGE MILL
BE DISPOSED OF IN A LANDFILL. START UP DATE IS JUNE, 1986.
PACIFIC GAS & ELECTRIC
MONTEZUMA
2
NEW 800.0 MU (GROSS)
800.0 MU (ESC)
COAL
.80 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****Z
STATUS 6 STARTUP 6/87
FOSSIL 2 OF PACIFIC GAS AND ELECTRIC IS A COAL <0.8X S, 12*000 BTU/LB)
FIRED BOILER PLANNED FOR COLLUNSVILLE, CALIFORNIA. THE EMISSION CONTROL
SYSTEM WILL CONSIST OF A BAGHOUSE AND A LIMESTONE FGD SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START UP DATE IS JUNE, 1987.
PACIFIC POWER & LIGHT
JIM BH1DGER
NEU 550.0 MU (GROSS)
550.0 MW (ESC)
COAL
.56 ZS SUSBITUniNOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: -.2*
STATUS 2 STARTUP 9/79
PACIFIC POWER AND LIGHT'S JIM BRIDGER A IS A DRY BOTTOM PULVERIZED SUB81-
TUMI NOUS COAL (0.56% S, 9300 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN
ROCK SPRINGS, WYOMING. A 91* EFFICIENT SODIUM CARBONATE FGD SYSTEM FOR
THIS UNIT WILL BE SUPPLIED BY THE AM CORRECTION DIVISION OF UOP. A COLO
SIDE ESP MILL TREAT 2,720,000 ACFM OF FLUE GAS, FOLLOWED BY THREE SIEVE
TRAY ABSORBERS. THE SYSTEM UILL OPERATE IN A CLOSED WATER LOOP MODE. A
SYSTEM CHECK OUT WAS CONDUCTED IN JULY Of 1979. AND START UP IS EXPECTED
IK SEPTEMBER.
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
NEW 917.0 MU (GROSS)
917.0 MU tESC)
COAL
3.00 XS BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: 6.CZ
STATUS 1 STARTUP 12/75
BRUCE MANSFIELD 1 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.0% S, 11,500 BTU/LBJ IN SH1PPINGPORT,
PENNSYLVANIA. A CHEMICO THIOSORBIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (9Z.1X) FROM 3,350,000 ACFM OF FLUE GAS. THE FGD SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIX FIXED
THROAT VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT LOMBUS-
TION REHEATERS, AND A 950 FOOT FLAKEGLASS STACK SHARED BY UNITS 1 AND 2.
THE WATER LOOP IS OPEN, AND THE CALCILOX STABILIZED SLUDGE IS DISPOSED IN
AN OFF SITE LANDFILL. THIS SYSTEM HAS BEEN OPERATIONAL SINCE DECEMBER,
1975.
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
NEU 917.0 MU (GROSS)
917.0 My (ESC)
COAL
3.00 ZS BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: 6.OX
STATUS 1 STARTUP 7/77
BRUCE MANSFIELD 2 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.OX S, 11,500 BTU/LB) IN SHIPPIN6PORI,
PENNSYLVANIA. A CHEMICO THIOSORBIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (92.1X> FROM 3,350,000 ACFK OF FLUE GAS. THE FGD SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIS FIXED
THROAT VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT COMBUS-
TION REHEATERS, AND A 950 FOOT FLAKEGLASS STACK SHARED BY UNITS 1 AND 2.
THE WATER LOOP IS OPEN, AND THE CALCILOX STABILIZED SLUD6E IS DISPOSED IN
AN OFF SITE LANDFILL. THIS SYSTEM HA'S BEEN OPERATIONAL SINCE JULY, 1977.
PENNSYLVANIA POWER
BRUCE MANSFIELD
3
NEW 917.0 MW (GROSS)
917.0 MU (ESC)
COAL
3.00 XS
LIME
PULLMAN KELLOGG
ENERGY CONSUMPTION: *»**X
STATUS 2 STARTUP 5/80
BRUCE MANSFIELD 3 OF PENNSYLVANIA POWER IS A SUPERCRITICAL PULVERIZED COAL
(3.OX S, 11,500 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN SHIFPIN6PORT,
PENNSYLVANIA. FOUR ESP'S WILL TREAT 3,308,000 ACFM OF FLUE GAS, FOLLOWED
BY FIVE (ONE SPARE) PULLMAN KELLOGG THIOSORBIC LIME ABSORBERS fcHICH
UILL REMOVE 92.2X OF THE S02. THE CLEANED GAS UILL PASS THROUGH
CHEVRON MOST ELIMINATORS AND DIRECT COMBUSTION REHEATERS BEFORE
DISCHARGE THROUGH A 600 FOOT INCONEL 625 LINED STACK. THE FLYASH STA-
BILIZED SLUDGE UILL BE PIPED TO THE .EXISTING OFF SITE LANDFILL PRESENTLY
USED BY UNITS ONE AND TWO. START UP IS EXPECTED IN APRIL OF 1980.
23
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PHILADELPHIA ELECTRIC
CROHBY
RETROFIT 150.0 MW (GROSS)
150.0 MU (ESC)
COAL
3.00 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: *»**X
STATUS 3 STARTUP 6/80
PHILADELPHIA ELECTRIC HAS PLANS FOR THE RETROFIT OF AN FGD SYSTEM ON ONE
OF THE TWO 3.OX SULFUR COAL FIRED BOILERS AT CROMBY STATION IN PHQENIX-
VILLE, PENNSYLVANIA. A CONTRACT HAS BEEN AWARDED TO UNITED ENGINEERS
FOR A MAGNESIUM OXIDE SYSTEM. THE SiTART UP DATE IS SET FOR JUNE, 1980.
PHILADELPHIA ELECTRIC
EDDYSTONE
1A
RETROFIT 120.0 MW CGROSS)
120.0 MU (ESC>
COAL
2.60 ZS BITUMINOUS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: ****Z
STATUS 1 STARTUP 9/75
UNIT 1 OF PHILADELPHIA ELECTRIC'S EDD*STONE, PENNSYLVANIA STATION IS A
BITUMINOUS COAL <2.6* 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 ROD DECK SPRAY T(OWER FOLLOWING THE VENTURI SCRUBBER.
THE 90i EFFICIENT CDESIGN) ABSORBER, A RETROFIT BY UNITED ENGINEERS, LEADS
TO A LOUVER TYPE MIST ELIMINATOR, A DIRECT COMBUSTION REHEAT£R, AND A
249 FOOT STACK. THE SPENT SLURRY IS REGENERATED AT THE ESSEX SULFURIC
^CID PLANT IN NEWARK, NEW JERSEY, ANS THE HAG-OX is RETURNED TO EDDY-
STONE. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND HAS BEEN OPERA-
TIONAL SINCE SEPTEMBER, 1975.
PHILADELPHIA ELECTRIC
EDDYSTONE
1B
RETROFIT 240.0 MW (GROSS)
240.0 Mw (ESC)
COAL
2.60 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION:
UNIT 1 OF PHILADELPHIA ELECTRIC'S EDDYSTONE, PENNSYLVANIA STATION IS A
BITUMINOUS COAL (2.6% S, 13,600 BTU/LB) FIRED UNIT WHICH USES ESP'S,
MECHANICAL COLLECTORS, AND THREE PAR.TICULATE SCRUBBERS (TWO ROC DECK
SPRAY TOWERS AND ONE VENTURI) FOR PRIMARY PARTICULATE CONTROL- THE
IB FGD WILL FOLLOW THE TWO ROD DECK SPRAY TOWERS. A CONTRACT HAS
BEEN AWARDED TO UNITED ENGINEERS FOR A MAGNESIUM OXIDE FGD SYSTEM.
THE START UP DATE IS SET FOR JUNE, 1980.
STATUS 3
****x
STARTUP 6/80
PHILADELPHIA ELECTRIC
EDDYSTONE
2
RETROFIT 334.0 MW (GROSS)
334.0 Mw (ESC)
COAL
2.50 ZS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: ****Z
STATUS 3 STARTUP 6/80
EDDYSTONE 2 OF PHILADELPHIA ELECTRIC IS A 2.5Z SULFUR COAL FIRED BOILER
LOCATED IN EDDYSTONE, PENNSYLVANIA. THE PLANT'S GENERATING
CAPACITY IS 334 MW. A CONTRACT HAS BEEN AWARDED TO UNITED ENGINEERS
FOR A MAGNESIUM OXIDE FGD SYSTEM. THE START UP DATE IS SET FOR JUNE, 1980
POTOMAC ELECTRIC POWER
DICKERSON
4
NEW 800.0 MW (GROSS)
800.0 HW (ESC)
COAL
2.00 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****Z
STATUS 6 STARTUP 0/87
01CKERSON 4 OF POTOMAC ELECTRIC POWER IS A PULVERIZED COAL (2.OX S, 11,000
BTU/LB) FIRED UNIT PLANNED FOR LOCATION IN DICKERSON, MARYLAND. THE UTIL-
ITY IS CONSIDERING AN FGD SYSTEM FOR THIS UNIT, BUT THERE ARE NO FIRM
PLANS FOR THE INSTALLATION OF AN FGD SYSTEM. START UP OF THE BOILER IS
EXPECTED IN 1985. FGD SYSTEM START UP, IF ANY, WILL BE IN 1987.
POWER AUTHORITY OF NEW YORK
ARTHUR KILL
NEW 7CO.O MW (GROSS)
700.0 MW (ESC)
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 11 /8 7
THE POKER AUTHORITY OF NEW YORK PLANS A NEW 3.0Z SULFUR COAL FIRED UNIT
WHICH kilLL 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.
24
-------
FPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PUBLIC SERVICE OF INDIANA
GIBSON
5
NEW 650.0 MW (GROSS)
650.0 MW (ESC)
COAL
3.30 XS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: ****%
STATUS 3 STARTUP 0/82
GIBSCM 5 OF PUIL1C SERVICE CF INDIANA IS A 3.3X SULFUR COAL FIRED UNIT
PLANNED FOR LOCATION IN PRINCETON, INDIANA- A CONTRACT WAS AWARDED TO
PULLKAN KELLOGG FOS A LIMESTONE FGD SYSTEM CONSISTING OF FOUR KELLOGG-
WEIR AbSORBER-REACTOR MODULES. SYSTEM START UP IS EXPECTED IN 1982. THE
SYSTE1 WILL USE KELLOGG'S PROPRIETARY MAGNESIUM-PROMOTED LIMESTONE.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
1
RETROFIT 361.0 MW (GROSS)
361.0 MW (ESC)
COAL
.SO ZS
UELLHAN LORD
DAVY POUERGAS
ENERGY CONSUMPTION: 4.*,%
STATUS 1 STARTUP 4/78
SAN JUAN 1 OF PUBLIC SERVICE OF NEW MEXICO IN WATERFLOW, NEW MEXICO IS A
COAL (O.SS S, 8100 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,OCO ACFM OF
FLUE GAS TO A RETROFIT WELLMAN LORD FGD SYSTEM BY DAVY POWER6AS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE APRIL OF 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSOR-
BER TRAINS WHICH WERE DESIGNED TO REMOVE 85% OF THE FLUE GAS SO?. AN IN-
DIRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END PRODLCT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE WATER LOOP IS
CLOSED.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
RETROFIT 350.0 MW (GROSS)
350.0 MW CEEC)
COAL
.80 ZS
WELLMAN LORD
DAVY POUERGAS
ENERGY CONSUMPTION: 4. 6Z
SAN JUAN Z OF PUBLIC SERVICE OF NEW MEXICO IN WATERFLOW, NEW MEXICO IS A
COAL (C.8% S, £100 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,OCO ACFM OF
FLUE GAS TO A RETROFIT WELLMAN LORD FGD SYSTEM BY DAVY POWERGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE AUGUST OF 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSOR-
BER TRAINS WHICH WERE DESIGNED TO REMOVE 85% OF THE FLUE GAS S02. AN IN-
DIRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END PRODUCT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE WATER LOOP IS
CLOSED.
STATUS 1
STARTUP 8/78
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
3
NEW 534.0 MW (GROSS)
534.0 MW
-------
EPA UTILITY FGD SUPVET: THIRD CUARTLR 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SALT RIVEK PROJECT
CORONADO
2
NEW 35C.C «w (GROSS)
280.0 MW (£SC>
COAL
1.00 XS SUBiilTUMlNOUS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: ****X
STATUS Z STARTUP 1/80
SALT RIVER PROJECT'S CORONADO 2 IS A DRY BOTTOM PULVERIZED SUBB1TUM INDUS
COAL C1.C% S, g?CO BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN ST. JOHNSi
ARIZONA. PULLMAN KELLOGG IS SUPPLYING TWO LIMESTONE HORIZONTAL WEIR SPHA»
TOyERS WHICH WILL REMOVE 82.5X OF THE S02 fROM THE FLUE GAS PASSED THROUGH
THE*. VERTICAL HEIL WIST ELIMINATORS PRECEDE A 500 FOOT STACK. A MINIMUM
OF 2C* BYPASS WILL PROVIDE REHEAT. THE WATER LOOP WILL BE OPEN, AND THE
UNSTABILIZED SLUDGE WILL BE DISPOSED IN AN UNLINED POND. START UP IS EX-
PECTED IN JANUARY, 1980.
SALT RIVER PROJECT
CORONADO
3
NEW 350.0 MW (GROSS)
280.0 Wtf (ESC)
COAL
1.00 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/84
CORONADO 3 IS A DRY BOTTOM PULVERIZED SUBBITUHINOUS COAL (1.0* S, 8300 BTU
/LB) FIRED UNIT PLANNED BY SALT RIVER PROJECT TO BE LOCATED IN ST. JOHN'S,
ARIZONA. THE UTILITY IS PRESENTLY CONSIDERING THE INSTALLATION OF TWO HOR-
IZONTAL SPRAY TOWERS UTILIZING LIMESTONE AS THE ABSORBENT. PLANS FOR AN
EMISSION CONTROL SYSTEM HAVE NOT BEEN FINALIZED. THE SYSTEM HILL HAVE A
20* BYPASS REHfAT, ftND THE SLUDGE W1LL PROBABLY BE PONDED. SCHEDULED OPER-
ATION DATE IS 1984.
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL
1
NEW 400.0 HW (GROSS)
4GO.O nw (ESC)
COAL
1.7C XS LIGNITE
LIMESTONE
BABCOCK 8 WILCOX
ENERGY CONSUMPTION:
STATUS 2
SAN MIGUEL 1 OF THE SAN MIGUEL ELECTRIC COOP IS A LIGNITE (1 .75! S, 5000
BTU/LB) FIRED RADIANT BOILER UNDER CONSTRUCTION IN SAN MIGUEL, TEXAS. THE
EMISSION CONTROL SYSTEM ON THIS UNIT HILL CONSIST OF A COLO SIDE ESP FOL-
LOWED BY FOUR BABCOCK AND WILCOX 861 EFFICIENT LIMESTONE TCA MODULES.
CHEVRON MIST ELIMINATORS WILL PRECEDf 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.
5.0Z
STARTUP 7/EO
SEHINOLE ELECTRIC
SEMINOLE
1
NEW 620.0 My (GROSS)
623.0 My (ESC)
COAL
2.75 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **»*X
STATUS 5 STARTUP 6/83
SEMINOLE 1 OF SEMINOLE ELECTRIC IS A COAL CZ.75X S, 11.700 BTU/LB) FIRED
UNIT PLANNED FOR LOCATION IN PALATKA, FLORIDA. THE EMISSION CONTROL SYSTEM
WILL CONSIST OF ESP'S AND A LIMESTONE FGO SYSTEM. THE UTILITY IS CURRENTLY
REQUESTING/EVALUATING BIDS FOR THE SYSTEM. START UP IS EXPECTED IN JUNE OF
1983.
SEMINOLE ELECTRIC
SEM1NOLE
2
NEW 620.0 NV (GROSS)
62C.O MW (ESC>
COAL
2.75 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 6/85
SEK1NOLE 2 OF SEMINOLE ELECTRIC IS A COAL C2.75X S, 11,700 BTU/LB) FIRED
UNIT PLANNED FOR LOCATION IN PALATKA, FLORIDA. THE EMISSION CONTROL SYSTE*
WILL CONSIST Of ESP'S AND A LIMESTONE FGD SYSTEM. THE UTILITY IS CURRENTLY
REQUESTING/EVALUATING BIDS FOR THE SYSTEM. START UP IS EXPECTED IN JUNE OF
1985.
S1KESTON BOARO OF MUNIC. UT1L.
SIKESTON
1
NEW 235.0 MU (GROSS)
235.0 WW (ESC)
COAL
2. 80 XS
LIMESTONE
BABCOCK R WILCOX
ENERGY CONSUMPTION: 1 . 6X
THE SIKESTON BOARD OF MUNICIPAL UTILITIES' SIKESTON 1 IS A PULVERIZED COAL
(2.81 S, 11,340 BTU/LB) FIRED BOILER UNDER CONSTRCTION IN SIKESTON, MIS-
SOURI. BABCO£K AND UILCOX IS SUPPLYING AN EMISSION CONTROL SYSTEM CONSIST-
ING CF TWO ESP'S AND THREE 50X CAPACITY LIMESTONE VENTURI FGD MODULES. THE
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, 1981.
STATUS 2
STARTUP 1 /S 1
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOOTH CAROLINA PUOLIC SERVICE
UIN Y A H
2
NEW
280.0 MW
1*0.0 MW
(GROSS)
(ESC)
COAL
1.70 %S BITUMINOUS
LIMESTONE
BAB COCK t, WILCOX
ENERGY CONSUMPTION: 1. IX
STATUS 1 STARTUP 7/77
WINYAH 2 OF SOUTH CAROLINA PUBLIC SERVICE IS A PULVERIZED BITUK1NOUS COAL
(1 .70* S, 11,SCO BTU/LB) FIRLD UNIT LOCATED IN GEORGETOWN, SOUTH CAROLINA.
A COLD SIDE ESP AND A UA6COCK AND WILCOX VENTURI SCRUBBER/LIME STONE TRAY
TOWER ABSORBER TRAIN DESIGNED TO REMOVE 69Z OF THE SO? FROM THE BOILER
FLUE SAS WAKE L'P THE EMISSION CONTROL SYSTEM ON THIS UNIT. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP, AND THE SLUDGE IS DISPOSED IN AN ON-SITE
UNLINED POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY OF 1977.
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
3
NEW 280.0 MW (GROSS)
?80.0 MW (ESC)
COAL
1.70 %S
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: 2.1*
STATUS i STARTUP 5/SC
WINYAH 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 KAY, 1980.
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
4
NEW 280.0 MW (GROSS)
280.0 MW (ESC>
COAL
1.70 ZS BITUMINOUS
LIMESTONE
AMERICAN AIR FILTER
ENERGY CONSUMPTION! 2.1Z
STATUS 3 STARTUP 5/31
SOUTH CAROLINA PUBLIC SERVICE'S WINYAH 4 IS A PLANNED BITUMINOLS COAL
(1.7% S, 11,500 BTU/LB) FIRED UNIT TO BE LOCATED IN GEORGETOWN, SOUTH
CAROLINA. TWO AMERICAN AIR FILTER LIMESTONE SLURRY SPRAY TOWERS WILL
FOLLOW AN ESP- THE TEMPERATURE OF THE CLEANED CAS WILL BE RAISED BY AN
INDIRECT STEAM REHEATER. THE SYSTEM WILL OPERATE IN A CLOSED HATER LOOP
MODE. THE CONTRACT FOR THE FGD SYSTEM HAS BEEN AWARDED, AND START UP IS
EXPECTED IN MAY, 1981.
SOUTH MISSISSIPPI ELEC PWR
R.O. MORROW
1
NEW 2GO.O MW (GROSS)
124.0 «W (ESC)
COAL
1.30 ZS
LIMESTONE
RILEY STOKER/ENVIRONEER1NG
ENERGY CONSUMPTION: 5.5%
STATUS 1 STARTUP 8/78
R.D. MORROW 1 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVERIZED COAL (1.3Z
S, 12,000 BTU/LB) FIRED UNIT IN HATTISBURG, MISSISSIPPI- THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-RQD ABSORBER SUPPLIED BY RILEY STOKER/ENVIRONEERING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT IS
JOINED BY A 38% BYPASS REHEAT BEFORE IT IS DISCHARGED THROUGH A 408 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUDGE IS
HAULED BY TRUCK TO AN OFF SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE AUGUST OF 1978.
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW
2
NEW 200.0 MW (GROSS)
124.0 MW (ESC)
COAL
1.30 ZS
LIMESTONE
RILEY STOKER/ENVIRONEERING
ENERGY CONSUMPTION: 5.5Z
STATUS 1 STARTUP 6/79
R.D. MORROW 2 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVERIZED COAL <1 .3Z
S, 12,000 BTU/LB) FIRED UNIT IN HATTISBURG, MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A MOT SIDE ESP FOLLOWED BY A L1BE-
STONE VENTRI-RCD ABSORBER SUPPLIED BY RILEY STOKER/ENVIRONEERING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT IS
JOINED BY A 38% BYPASS REHEAT BEFORE IT IS DISCHARGED THROUGH A 408 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLU06E IS
HAULED BY TRUCK TO AN OFF SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE OF 1979.
SOUTHERN ILLINOIS POWER COOP
MARION
4
NEW 184.0 MW (GROSS)
184.0 MW (ESC)
COAL
3.50 %S
LIMESTONE
BABCOCK 8 WILCOX
ENERGY CONSUMPTION: ****%
STATUS 1 STARTUP 5/79
UNIT 4 AT SOUTHERN ILLINOIS POWER COOP'S MARION STATION IN MARION, ILLI-
NOIS IS A CYCLONE FIRED COAL (3.0Z S, 9000 BTU/LB) BOILER WHICH IS SERVED
BY A 89.4X EFFICIENT (DESIGN} LIMESTONE FGD SYSTEM SUPPLIED BY BABCOCK AND
WILCOX. 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. THE SYSTEM BECAME OPERATIONAL DURING MAY Of
1979.
27
-------
EPA UTILITY FGD SURVEY: THIRD OUARTER 1979
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTHERN
WAR ION
5
NEW
ILLINOIS POWER COOP
700.0 My (GROSS)
300.0 WW (ESC)
COAL
3.00 IS
PROCESS NOT StLEcTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **•**
STATUS 6 STARTUP 0/B4
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 UTILI™ HAS NOT
YET DECIDED ON AN FGD PROCESS AS IT IS WAITING FOR THE F1NAL1ZATION OF
THE S02 REGULATIONS THE UNIT WILL HAVE TO MEET. START UP IS EXPECTED IN
1984.
SOUTHERN INDIANA GAS & ELEC
A.B. BROWN
1
NEW 265.0 nw (CROSS)
265.0 NW (ESC)
COAL
4.50 ZS
DUAL ALKALI
FNC CORPORATION
ENERGY CONSUMPTION: . 8Z
STATUS 1 STARTUP 3/79
SOUTHERN INDIANA GAS AND ELECTRIc'S A.B.BROWN 1 IS A DRY BOTTOM PULVERIZED
COAL (4.5Z S, 13,010 BTU/LB) F1HED UNIT IN WEST FRANKLIN. INDIANA- F«C
SUPPLIED A DUAL ALKALI FGD SYSTEM DESIGNED TO REMOVE 85Z OF THE FLUE GAS
S02. THE UNIT CONSISTS OF TWO THREE STAGE DISC CONTACTORS. A COLD SIDE ESP
PROVIDES PRIMARY PARTICULATE CONTROLi AND ONE CHEVRON MIST ELIMINATOR/MOD-
ULE PRECEDES A 498 FOOT AC ID BRICK LINED STACK. THE SYSTEM PRODUCES A
FILTER LAKE WASTE PRODUCT WHICH IS DISPOSED IN AN ON SITE LANDFILL. THE
WATER LOOP CAN BE EITHER OPEN OR CLOSED. THE SYSTEM HAS BEEN OPERATIONAL
SINCE MARCH OF 1979.
SOUTHWESTERN ELECTRIC POWER
HENRY W. PERKEV
1
NEW 720.0 nu (GROSS)
720.0 NW (ESC)
COAL
.80 ZS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION. UOP
ENERGY CONSUMPTION: ****Z
STATUS 3 STARTUP 12/83
HENRY W. PERKEY 1 IS A WET BOTTOM LIGNITE (0.8Z S. 6300 BTU/LB) FIRED UNIT
PLANNED BY SOUTHWESTERN ELECTRIC POWER FOR LOCATION IN HALLSV1LLE, TEXAS.
A CONTRACT HAS BEEN AWARDED TO THE AIR CORRECTION DIVISION OF UOP FOR FOUR
LIMESTONE SPRAY TOWERS (99+* EFFICIENCY). MIST 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-C-TEC STABILIZED. START UP IS EXPECTED BY DECEMBER. 1983.
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
NEW 194.0 MW (GROSS)
194.0 MW (ESC)
COAL
3.SO ZS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 4.6Z
STATUS 1 STARTUP 4/77
SPRINGFIELD CITY UTILITIES' SOUTHWEST 1 IS A PULVERIZED BITUMINOUS COAL
(3.SZ S, 12,500 BTU/LB) FIRED BOILER LOCATED IN SPRINGFIELD, MISSOURI. THE
EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A COLD SIDE ESP FOLLOWED
BY TWO UOP LIMESTONE TCA MODULES WHICH WERE DESIGNED TO REMOVE 80Z OF THE
FLUE 6AS S02. ONE CHEVRON/MODULE LEADS TO A 384 FOOT CEILCOTE LINED STACK.
THE DRV FLYASH STABILIZED SLUDGE IS DEWATERED BY A ROTARY DRUM VACUUM AND
TRUCKED TO A LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL SINCE APRIL. 1977.
SPRINGFIELD WATER, LIGHT S PWR
DALLNAN
3
NEW 205.0 NW (GROSS)
205.0 NW (ESC)
COAL
3.30 ZS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 5.«
STATUS 2 STARTUP 7/80
DALLMAN 3 OF SPRINGFIELD WATER. LIGHT. AND POWER IS A PULVERIZED COAL
(3.3* S, 10,500 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN SPRINGFIELD,
ILLINOIS. RESEARCH COTTRELL IS SUPPLYING A LIMESTONE FGD SYSTEM DESIGNED
TO REMOVE 95Z OF THE S02 FROM 850.000 ACFM OF BOILER FLUE GAS. A HOT SIDE
ESP KILL PRECEDE TWO PACKED TOWER ABSORBERS. ONE HORIZONTAL CHEVRON PER
MODULE, AND A 500 FOOT ACID BRICK LINED STACK. NO REHEAT WILL BE PROVIDED.
A SLtO&E DISPOSAL STRATEGY HAS NOT B€EN FINALIZED, BUT THE UTILITY IS CON-
SIDERING EITHER PONDING OR LANDFILL. FGD OPERATIONS SHOULD BEGIN IN
JULY OF 1980.
ST. JOE ZINC
G.F. WEATON
1
RETROFIT 6C.O nw (GROSS)
60.0 NW (ESC)
COAL
3.00 ZS
CITRATE
BUREAU OF WINES
ENERGY CONSUMPTION: ***»z
STATUS 2 STARTUP 11/79
G.F. KEATON 1, OWNED BY ST. JOE ZINC, IS A COAL (3.OZ S, 12,500 BTU/LB)
FIRED BOILER LOCATED IN BONACA. PENNSYLVANIA. THE BUREAU OF H1HES IS RE-
TROFITTING A PROTOTYPE CITRATE FGD SYSTEM ON THIS UNIT, WHICH PROVIDES
POWER FOR THE LOCAL UTILITY GRID. ONE VENTURI SCRUBBER/ABSORBER TRAIN WILL
FOLLOW A COLD SIDE ESP. TWO CHEVRON MIST ELIMINATORS ARE TO BE FOLLOWED BY
A COMBINATION OF INDIRECT HOT AIR AND DIRECT COMBUSTION REHEATERS. AND A
102 FOOT FIBERGLASS LINED SCRUBBER STACK. THE SYSTEM S02 REMOVAL EFFICIEN-
CY WILL BE OVER 90Z. THE WATER LOOP WILL BE CLOSED. THE F60 SYSTEM IS CUR-
RENTLY UNDER CONSTRUCTION, WITH STAfcT UP EXPECTED IN NOVEMBER OF 1979
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1
NEW 475.0 MW (GROSS)
475.0 MW (ESC)
COAL
85.03 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 3/85
UNIT 4 AT TAMPA ELECTRIC'S PIG BEND STATION is A PLANNED DRY BOTTOM PUL-
VERIZED COAL (2.55! S, 10.3CC BTU/LB) FIRED UNIT TO FE LOCATED IN TAPPA,
FLORIDA. THE FGD PROCESS HAS NOT YET SEEN CHOSEN. AN ESP WILL PROVIDE
PRIMARY PARTICIPATE CONTROL. THE FGD SYSTEM, WHICH WILL REMOVE 9CX OF THE
FLUE GAS S02, WILL IMCLUOE AN INDIRECT HOT AIR REHEATER LEADING TO A 490
FOOT CONCRETE LINED STACK.
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE
1-10
RETROFIT uso.o MW (GROSS)
600.0 MW (ESC)
COAL
3.10 XS
MAGNESIUM OXIDE
TVA/UNITFD ENGINEERS
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 0/82
UNITS 1 THROUGH 10 AT JOHNSONVILLE STATION OF TVA ARE COAL <2.£* S, 10,750
BTU/LB) FIRED BOILERS LOCATED IN NEW JOHNSONVILLE, TENNESSEE. I'NITED EN-
GINEERS HAS BEEN AWARDED A CONTRACT TO PROVIDE ENGINEERING ASSISTANCE TO
TVA FOR A 9QX EFFICIENT MAGNESIUM OXIDE FGO SYSTEM TO BE RETROFITTED ON
THESE UNITS. SULFURIC ACID WILL BE PRODUCED AS A BYPRODUCT FROM THIS SYS-
TEM, h/HICH WILL FEATURE FOUR VENTURl S CRUBBER/AB SORBER TRAINS (ONE SPARE),
60* EYPASS REHEAT, AND A 600 FOOT STACK. START UP IS EXPECTED IN 1982.
TENNESSEE VALLEY AUTHORITY
PARADISE
1
RETROFIT 704.0 MW (GROSS)
704.0 MU CESC)
COAL
***** xs
LIMESTONE
CHEMICO
ENERGY CONSUMPTION: ****x
STATUS 3 STARTUP 6/82
PARADISE 1 OF TVA IS A 4.2* SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHE«ICO FOR AN 84.23! EFFICIENT
LIMESTONE FGO SYSTEM TO BE RETROFITTED ON THIS BOILER. SIX VENTURl SCRUB-
BERS AND VENTURl ABSORBER TRAINS WIL1, FOLLOW AN ESP. INLET FLUE GAS WILL
BE USED TO HEAT WATER, WHICH IN TURN WILL BE USED TO REHEAT THE OUTLET
FLUE 6AS. FORCED OXIDATION WILL BE USED IN ONE MODULE TO CONTROL SCALING
THROUGHOUT THE SYSTEM. THE UTILITY EXPECTS TO GET AN SOX SOLIDS LANDFILL-
ABLE ERADE SLUDGE. OPERATIONS SHOULD START IN JUNE, 1982.
-NULL--NULL—NULL — NULL—NULL—NULL—NULL — NULL—NULL—NULL—N ILL — NULL—N
TENNESSEE VALLEY AUTHORITY
PARADISE
2
RETROFIT 704.0 MU (GROSS)
704.0 «W (ESC)
COAL
4.20 XS
LIMESTONE
CHEMICO
ENERGY CONSUMPTION:
STATUS 3
PARADISE 2 OF TVA IS A 4.22 SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR AN 84.21 EFFICIENT
LIMESTONE FGD SYSTEM TO BE RETROFITTED ON THIS BOILER. SIX VENTURl SCRUB-
BERS AND VENTURl 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 WILL BE USED IN ONE MODULE TO CONTROL SCALING
THROUGHOUT THE SYSTEM. THE UTILITY EXPECTS TO GET AN 80X SOLIDS LANDFILL-
ABLE BRADE SLUDGE. OPERATIONS SHOULD START IN MARCH, 1982.
-NULL--NULL— NULL—NULL—NULL—NULL—NULL--NULL—NULL—NULL—NULL — NULL—N
*****
STARTUP 3/82
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10*
RETROFIT 'ij.o MW (GROSS)
:o,o My (ESC)
COAL
2.90 XS BITUMINOUS
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 4/72
SHAMNEE 10 OF TVA IS A 2.9* SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
PADUCAH, KENTUCKY. MODULE IDA IS A RETROFIT PROTOTYPE LIME/LIMESTONE UA
SYSTEM SUPPLIED BY THE AIR CORRECTION DIVISION, UOP. THE SYSTE* 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 SAS FRANCISCO
IS THE MAJOR CONTRACTOR, TEST DIRECTOR, AND REPORT WRITER. THE SYSTEM HAS
BEEN OPERATIONAL SINCE APRIL, 1972.
TENNESSEE VALLEY AUTHORITY
SHAWNEE
108
RETROFIT 10.0 MW (GROSS)
10.0 MW (ESC)
COAL
2.90 XS BITUMINOUS
LIME/LIMESTONE
CHEMICO
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 4/72
SHAWNEE 10 OF TVA IS A 2.92 SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
PAOUCAH, KENTUCKY. MODULE 10B IS A RETROFIT PROTOTYPE LIME/LIBESTONE VEN-
TURl SCRUBBER/SPRAY TOWER ABSORBER SUPPLIED BY CHFMICO. THE SYSTEM, OPERA-
TIONAL SINCE APRIL, 1972, INCLUDES A CHEVRON MIST ELIMINATOR AND A DIRECT
COMBUSTION REHtATER, AND OPERATES IN A CLOSED WATER LOOP. THIS TEST PRO-
GRAM IS FUNDED BY THE EPA WITH TVA AS THE CONSTRUCTOR AND FACILITY OPERA-
TOR. THE BECHTEL CORP- OF SAN FRANCISCO IS THE MAJOR CONTRACTOR, TEST DI-
RECTOR, AND REPORT WRITER.
-NULL — NULL—NULL — NULL—NULL — NULL—NULL — NULL--NULL—NUL L--NULL — NULL—N
-------
EP» UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TENNESSEE VALLEY AUTHORITY
WIDOWS CPEEK
7
RETROFIT 575.0 MW (GROSS)
575.0 MW (ESC)
COAL
3.70 XS BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS Z STARTUP 10/80
WIDOkS CREEK 7 IS A PULVERIZED BITUMINOUS COAL (3.71 S, 11,100 BTU/LB)
FIREt BOILER OF TVA LOCATED IN BRIDGEPORT, ALABAMA. COMBUSTION EN6INEERIN6
IS PRESENTLY RETROFITTING A LIMESTONE VENTRI ROD SCRUBBER/SPRA1 TOWER AB-
SORBER FGD SYSTEM ON THIS UNIT. AN ESP WILL PRECEDE THE SCRUBBING TRAIN,
AND A COMBINATION OF A BULK ENTRAlNMlENT SEPARATOR, TWO CHEVRON MIST
ELIMINATORS AND A FINNED TUBE REHEATER FOLLOW THE SYSTEM. THE
SCRUEBER SLUDGE WILL BE DISPOSED IN A SLUDGE POND. CONSTRUCTION! BEGAN
IN SEPTEMBER, 1978, AND START UP IS EXPECTED IN OCTOBER, 1980.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
6
RETROFIT 550.0 MU (GROSS)
550.0 MW (ESC)
COAL
3.70 ZS
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 5/77
WIDOWS CREEK E OF TVA IS A BALANCED DRAFT, TANCENTIALLT FIRED COAL <4.3X
S, 1C.OOC BTU/LB) BOILER IN BRIDGEPORT, ALABAMA. TVA RETROFITTED THIS UNIT
WITH A LIMESTONE FGD SYSTEM (80* DESIGN S02 REMOVAL EFFICIENCY) WHICH BE-
GAN OPERATIONS IN HAY, 1977. AN ESP PRECEDES FOUR VARIABLE THRCAT VENTURI
SCRU63ER/MULT1GRID TQWER ABSORBER TR'AINS
-------
FPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
AhSTRACT
TEXAS UTILITIES
FOREST GROVE
1
NEW 750.0 MW (GROSS)
750.0 Nto (ESC)
COAL
.80 XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 0/81
TfXAS UTILITIES IS PLANNING A LIGNITE (Q.8X S, 7QQO BTU/LB) FIRED BOILER,
FOREST GROVE 1, WHICH WILL BE LOCATED IN ATHENS, TEXAS. THE UTILITY IS
PRESENTLY REQUESTING P1DS ON AN FGD SYSTEM FOR THIS UNIT. TWO ESP'S WILL
PROVIDE PRIMARY PARTICUIATE CONTROL, AND NO STACK GAS REHEAT IS PLANNED.
START UP IS EXPECTED IN LATE 1981.
TEXAS UTILITIES
MARTIN LAKE
1
NEW 793.0 My (GROSS)
595.C MW (ESC)
COAL
.90 ZS LIGNITE
LIMESTONE
NONE
ENERGY CONSUMPTION: 1.32
STATUS 1 STARTUP 4/77
TEXAS UTILITIES' MARTIN LAKE 1 IS A LIGNITE (0.9J S, 7380 BTU/LB) FIRED
BOILER IN TATUW, 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 75* OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02 REMOVAL EFFICI-
ENCY IS 70.5*. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEAMNG 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
MARTIN LAKE
2
NEW 793.0 MW (GROSS)
595.0 MW (ESC)
COAL
.90 ZS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1 . 3Z
STATUS 1 STARTUP 5/78
TEXAS UTILITIES* MARTIN LAKE 2 IS A LIGNITE (0.9Z S, 7380 BTU/LB) FIRED
BOILER IN TATUK, 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 75Z OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02 REMOVAL EFFICI-
ENCY IS 70.5%. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEAMNG WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SI1E LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP. INITIAL SYSTEM OPERATIONS TOOK
PLACE IN MAY, 1978.
TEXAS UTILITIES
MARTIN LAKE
3
NEW 793.0 MW (GROSS)
595.0 wy (ESC)
COAL
.90 ZS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1.3%
STATUS 1 STARTUP 2/79
TEXAS UTILITIES' MARTIN LAKE 3 IS A LIGNITE <0.9Z S, 7380 BTU/LB) FIRED
BOILER IN TATUK, 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 75i OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02 REMOVAL EFFICI-
ENCY IS 7C.5Z- TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEAMNG 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, 1979.
TEXAS UTILITIES
MARTIN LAKE
t,
NEW 750.0 HU (GROSS)
750.0 HU (ESC)
COAL
.90 ZS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: ****Z
STATUS 3 STARTUP 0/85
MARTIN LAKE 4 OF TEXAS UTILITIES IS A LIGNITE (0,9Z S» 7380 BTU/LB) FIRED
BOILER UNDER CONSTRUCTION IN TATUM, TEXAS. A CONTRACT FOR A LIMESTONE FGD
SYSTEM FOR THIS UNIT HAS BEEN AWARDED TO RESEARCH COTTHELL. CONSTRUCTION
HAS NOT YET BEGUN ON THE FGD SYSTEM. FGD START UP IS EXPECTED IN 1985 OR
1986.
TEXAS UTILITIES
MILL CREEK
1
NEW 750.0 MW (GROSS)
750.0 MW (ESC)
COAL
***** %S LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/85
MILL CREEK 1 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TO BE
LOCATED IN HENDERSON, TEXAS. THE UTILITY WILL INCLUDE AN FGD SYSTEM ON
THIS UNIT, BUT NO DECISIONS HAVE BEE.N MADE AS TO THE PROCESS TYPE OR
VENDOR. ESP'S WILL PROVIDE PRIMARY PART1CULATE CONTROL. START UP IS
EXPECTED IN 1985.
-------
EPA UTILITY fGO SURVEY: THIRD QUARTER 1979
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS UTILITIES
MILL CREEK
2
NEW 750-0 Mu (GROSS)
750.0 Ml. (£SC)
COAL
*»•** IS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/86
HILL CREEK 2 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TO BE
LOCATED IN HENDERSON, TEXAS. THE UTILITY WILL INCLUDE AN FGD SYSTEM ON
THIS UMT, BUT NO DECISIONS HAVE BEEW MADE AS TO THE PROCESS TTPE OR
VENDOR. ESP'S WILL PROVIDE PRIMARY PARTICULATE CONTROL. START tP IS
EXPECTED IN 19E6.
TtXAS UTILITIES
BONTICELLO
I
NEW 800.0 NU (GROSS)
8CO.O MW (ESC)
COAL
1.50 ZS LIGNITE
LIMESTONE
CHEMICO
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 5/78
MONTKfcLLO 3 OF TEXAS UTILITIES IS A LIGNITE < 1 . 5Z S, 7000 BTU/LB) FIRED
UNIT IN PIT. PLEASANT, TEXAS. THIS UNIT'S EMISSION CONTROL SYSTEM CONSISTS
OF Tk.0 COLD SIDE ESP'S FOLLOWED BY THREE CHEMICO LIMESTONE SPRAY TOWERS
(74Z DESIGN S02 REMOVAL EFFICIENCY), ONE HORIZONTAL CHEVRON MIST ELIK1NA-
TOR/frODULE, AND AN INDIRECT HOT AIR REHEATER. THE WATER LOOP IS CLOSED,
AND THE FLYASH STABILIZED SLUDGE IS DISPOSED IN AN ON SITE LANDFILL. THIS
SYSTEM HAS BEEN OPERATIONAL SINCrMAY OF 1978.
UTAH POWER & LIGHT
HUNTER
1
NEW 400.0 MW (GROSS)
360.0 MW t£SC)
COAL
.55 ZS BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 5/79
HUNTER 1 OF UTAH POWER AND LIGHT IS A COAL (0.55!! S, 12,500 BTt/LB> FIRED
UNIT IN CASTLEDALE, UTAH. CHEH1CO SUPPLIED A PEBBLE LIME WET SCRUBBING
SYSTEM WHICH BECAME OPERATIONAL IN MAY, 1979. THE SCRUBBING SYSTEM IS DE-
SIGNED TO OPERATE IN AN OPEN WATER LOOP WITH AN S02 REMOVAL EFFICIENCY OF
8QZ. PRIWAR* PARTICULATE CONTROL is PROVIDED BY AN UPSTREAM ESP, AND STACK
GAS REHEAT IS PROVIDED BY BYPASS. THE SLUDGE IS FLYASH STABILIZED AND DIS-
POSED ON-S1TE.
UTAH POWER S. LIGHT
HUNTER
2
NEW 400.0 MW (GROSS)
360.0 MW (ESC)
COAL
.55 IS
LIME
CHENICO
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 6/80
UTAH POWER AND LIGHT'S HUNTER 2 IS A COAL CO.55* S, 12,500 BTU/LB) FIRED
UNIT UNDER CONSTRUCTION IN CASTLEDALiE, UTAH. CHEMICO IS SUPPLYING A PEBBLE
LIME WET SCRUBBING SYSTEM DESIGNED TO OPERATE IN AN OPEN WATER LOOP WITH
AN S02 REMOVAL EFFICIENCY OF 80Z. AN UPSTREAM ESP PROVIDES PRIMARY PARTIC-
ULATE CONTROL, AND A BYPASS SYSTEM PROVIDES STACK GAS REHEAT. THE SLUDGE
WILL BE FLYASH STABILIZED AND DISPOS.ED ON-SITE. START UP OF BOTH THE BOIL-
ER AND FGD SYSTEM is EXPECTED IN JUNE, 1980.
UTAH POWER & LIGHT
HUNTINGTON
1
NEW 430.0 MW (GROSS)
366.0 MW (ESC)
COAL
.55 IS BITUMINOUS
LIME
CHEMICO
ENERGY CONSUMPTION: 1.6Z
STATUS 1 STARTUP 5/78
HUNTINGTON 1 OF UTAH POWER IS A TANGENTIALLY FIRED PULVERIZED COAL (0.55Z
S, 12,500 BTU/LB) BOILER IN PRICE, UTAH. A COLD SIDE ESP TREATS 1,742,000
ACFM OF FLUE GAS AND IS FOLLOWED BY A CHEMICO LIME FGD SYSTEM CONSISTING
OF FOUR SPRAY TOWERS (SOX DESIGN EFFICIENCY). ONE FOUR PASS CHEVRON/MODULE
PROVIDES MIST ELIMINATION, AND A COMBINATION OF A STEAM TUBE AUD 10-20%
BYPASS REHEATERS BOOST THE GAS TEMPERATURE 45-50 DEG F. THE SYSTEM OPER-
ATES IN A CLOSED WATER LOOP, AND THE FLYASH STABILIZED SLUDGE lS TRUCKED
TO AN ON-SITE LANDFILL. THE SYSTEM INCLUDES A 600 FOOT ACID BRICK LINED
STACK, AND HAS BEEN OPERATIONAL SINCE MAY OF 1978.
WISCONSIN POWER & LIGHT
COLUMBIA
2
RETROFIT 527.0 MW (GROSS)
316.0 MU (ESC)
COAL
.80 ZS
LIME/ALKALINE FLYASH
CHEMICO
ENERGY CONSUMPTION: ****Z
STATUS 3 STARTUP 1/82
UNIT 2 AT WISCONSIN POWER AND LIGHT'S COLUMBIA STATION IN PORTAGE, WISCON-
SIN IS A PULVERIZED COAL (0.6Z S, 6600 BTU/LB) FIRED BOILER WHICH BEGAN
OPERATIONS IN 197P. CHEMICO HAS BEEN AWARDED A CONTRACT FOR A RETROFIT
LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF TWO SPRAY TOWER ABSORBERS, A
HORIZONTAL CHEVRON MIST ELIMINATOR AND 202 BYPASS REHEAT. A HOT SIDE ESP
WILL PROVIDE PRIMARY PARTICULATE CONTROL. THE CLEANED GAS WILL BE DIS-
CHARGED THROUGH A 650 FOOT Gl/NITE COATED -CARBON STEEL LINED STACK. THE
WATER LOOP WILL BE CLOSED, AND THE LIME AND FLYASH STABILIZED SLUDGE WILL
BE LANDFILLED. CONSTRUCTION SHOULD BEGIN AROUND MARCH OF 1980, AND PRO-
JECTED FGD SYSTEM START UP DATE IS JANUARY, 1982.
32
-------
EPA UTILITY FOD SURVEY: THIRD QUARTER 1979
SECTION 3
OtSIGN AND PERFORMANCE DATA FOP OPERATIONAL FGO SYSTEMS
COKPANY NAI»E
PLANT NAME
UNIT NUKHER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - PV.
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - NW
ALABAMA ELfCTKIC COOP
TOMBI&BEE
2
LEROY
ALABAMA
255.0
235.0
1 7 e . C
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - JAG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 5£
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
SOZ DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE' CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
COAL
BITUMINOUS
26749. ( 11500 BTU/LB)
14.00
7.CO
1.15
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
NEW
?.1
9/76
** /**
85.00
99.50
.0
.0
OPEN
17.6 ( 280 GPW)
** DISPOSAL
TYPE
LINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
9/78
A
B
SYSTEM
61.4 81.4
PROBLEMS/SOLUTIONS/COMMENTS
START DATE
81 .4
81.4
720
183
149
9/78 END DATE 9/7S
INITIAL OPERATION OF THE FGD SYSTEM BEGAN ON SEPTEMBER 23.
10/78
11/78
A
B
SYSTEM 66.3 57.9 57.9
A
B
SYSTEM 88.9 68.4 88.4
** PROBLEMS/SOLUTIONS/COMMENTS
46.4
83.9
744
596
720 683
345
604
START DATE 10/78 END DATE 11/78
IN LATE OCTOBER AND EARLY NOVEMBER BREAKS WERE FOUND IN THE FIBERGLASS R
PIPING LEADING TO AND FROM THE DISPOSAL POND. THE PROBLEMS WERE QUICKLY
CORRECTED EY THE ARCHITECT/ENGINEER.
12/78 A
33
-------
EPA UTILITY FGD SURVEY: THIRD GUARTtP 1979
ALABAMA ELECTRIC COOP: TOMEIGBEE 2 (CCNT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPtRABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
B
SYSTEM 97.8 97.6 97.6 91.8 744 700 683
1/79 A
B
SYSTEM 89.2 89.2 89.2 89.C 744 742 662
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 1/79 END DATE 1/79
SOME PLUGGING WAS ENCOUNTERED IN THE HIST ELIMINATOR DUE TO AN ESP OITAGE.
2/79 A
b
SYSTEM 98.4 96.2 96.2 42.6 672 297 286
3/79 A
6
SYSTEM 94.5 94.4 94.4 93.5 744 737 696
4/79 A
B
SYSTEM 100.0 100.0 100.0 40.6 720 292 292
** PR06LEMS/SOLUTIONS/COMNENTS
START DATE 2/79 END DATE 4/79
THE UTILITY HAS REPORTED THAT NO UNUSUAL PROBLEMS HAVE OCCURRED.
5/79 A
b
SYSTEM 92.7 92.6 92.6 90.2 744 725 671
6/79 A
B
SYSTEM 98.3 96.9 96.9 52.6 72 C 391 379
*• PROBLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED UELL DURING MAY AND JUNE
WITH THE EXCEPTION THAT THE MIST ELIMINATORS HAD TO BE REPLACED. THE MIST
ELIMINATORS WERE DEFORMED DURING A TEMPERATURE EXCURSION.
7/79 A
B
SYSTEM 93.0 91.1 91.1 71.9 744 587 535
9/79 A
B
SYSTEM 99.2 92.3 92.3 70.2 744 566 522
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 8/79 END DATE 8/79
THE SCRUBF-IR WAS NOT OPERATED FOR ABOUT 6 HOURS DUE TO A NECESSARY
ADJUSTMENT TO THE MODICON CONTROLLER. E
START DATE E/79 END DATE 8/79
THE SCRUBBER WAS BYPASSED FOR ABOUT 37 HOURS DUE TO AN ESP OUTAGE.
9/79 A 8T.2 68.3
B 21 .F 17.9
SYSTEM 1CC.C 92.9 92.9 76.3 720 591 549
*• PROkLEMS/SOLUTIONS/COMMENTS
START DATE °/79 END DATE 9/79
THE UTILITY REPORTED THAT THE SYSTEM WAS AVAILABLE AT ALL TIMES DURING
SE PTEKBEft.
34
-------
CPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUKHER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATt EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - WW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - KW
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
ALABAMA ELECTRIC COOP
TOCGIGBEE
3
LEROY
ALABAMA
A
516.
(****** L8/MMBTU)
< 1.200 LB/MMBTU)
255.0
235.0
243.0
179.0
RILEY STOKER
PULVERIZED COAL
BASE
6/79
449.72
143.9
122.
t 953000 ACFM)
C 291 F)
I 400 FT)
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - *
RANGE ASH CONTENT - %
AVERAGE MOISTURE CONTENT - %
RANGE MOISTURE CONTENT - 2
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
COAL
BITUMINOUS
26749.
14.00
10-16
7.00
1.15
0.8-1.5
< 11500 BTU/LB)
11000-12000
ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
HOT SIDE
RESEARCH COTTRELL
99.3
** FGD SYSTEM
SALEABLE PRODUCT/THROW AWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
CONTRACT AWARDED
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENT INDEX
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
BURNS & MCDONNELL
FULL SCALE
NEW
99.30
85.OU
6/79
8/75
.0
.0
** ABSORBER
NUMBER
TYPE
INITIAL START UP
SHELL MATERIAL
SHELL LINEK MATERIAL
BOILER LOAO/ABSORBER - %
LIQUID REC1RCULATION RATE - LITEK/S
L/G RATIO - L/CU.M
S02 DESIGN REMOVAL EFFICIENCY - 5!
SIEVE TRAY TOWER
6/79
CARBON STEEL
RUBBER LINED
35.0
1259.
9.4
35.0
(19980 GPM>
( 70.0 GAL/1000ACF)
-------
EPA UTILITY FGO SURVEY: THIRD QUARTtR 1979
ALABAMA ELECTRIC COOP: TOKBIGBEE 3 CCONT.)
FANS
NUMBER
TYPE
CONSTRUCTION MATERIALS
ID, DIRECT COUPLED
CARBON STEEL
»* MIST ELIMINATOR
NUMBER
TYPE
CHEVRON
** MIST ELIMINATOR
NUMBER
TTPE
BULK ENTRAINMENT SEPARATOR
PUMPS
SERVICE
RECYCLE
MILL RECYCLE
SLURRY FEED
WASH WATER
WASTE SLURRY
SUPERNATc RETURN
NUMBER
6
2
2
3
2
** TANKS
SERVICE
RECYCLE
LIMESTONE SLURRY
MASH WATER
NUMBER
1
1
r
•• REHEATER
NUMBER
*« THICKENER
NUMBER
** WATER LOOP
TYPE OPEN
FRESH MAKEUP WATER ADDITION - LITERS/S 17,6
< 280 GPM>
*• REAGENT PREPARATION EQUIPMENT
NUMBER OF BALL HILLS
BALL MILL CAPACITY- M T/H
REAGENT PRODUCT - Z SLURRY SOLIDS
•• TREATMENT
1
9.1
35.0
t 10.0 TPH)
DISPOSAL
NATURE
TYPE
LOCATION
TRANSPORTATION
AREA - ACRES
FINAL
LINED POND
ON-SITE
PUMPED
34.8
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
7/79 A
B
SYSTEM
8/79 A
B
SYSTEM
73.7
28.1
99.7 63.7
•• PRObLEMS/SOLUTIONS/COMMENTS
28.1
63.7
11.2
41.9
744 295
83
744 49Q 312
START DATE g/79 END DATE 8/79
AN ADJUSTMENT TO THE KODICOM CONTROLLER CAIUSED A SCRUBBER OUTAGE OF ABOUT
2 HOURS.
START DATE 8/79
END DATE 8/79
36
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
ALABAMA ELECTRIC COOP: TOMBIGBEE 3 (CDNT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEPABlLITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
THE SCRUBBER WAS DOWN DURING AN ESP OUTAGE FOR APPROXIMATELY 34 HOURS.
9/79 A 73.0 13.9
B 10.9 2.1
SYSTEM 100.0 75.2 75.2 14.5 720 137 103
** PROBLEMS/SOLUTIONS/COMKENTS
START DATE 9/79 END DATE 9/79
CONTINUING GENERATOR PROBLEMS CAUSED THE UNIT'S UTILIZATION TO BE LOk
DURING SEPTEMBER.
37
-------
EPA UTILITY F&D SURVEY: THIRD QUARTtR 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY H/FGD - KU
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
ALLEGHENY POWER SYSTEM
PLEASANTS
1
BELMONT
WEST VIRGINIA
A
21. < .050 LB/MHBTU)
516. ( 1.200 LFJ/MHBTU)
1250.0
625.0
625.0
519.0
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 - %
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - *
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - Z
BASE
0/79
1152.85
132.2
366.
.6
COAL
BITUMINOUS
27912.
15.00
10-20
3.70
2-*.5
********
(2*43000 ACr«>
( 270 F>
41200 FT>
< 2.0 FT)
( 12QOO BTU/LB)
11,000-13.300
ESP
NUMPER
SUPPLIER
FGD SYSTEM
SALEABLE PROD UCT/THROWAWA Y PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - 2
INITIAL START-UP
ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
BOILER LOAD/ABSORBER - Z
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
L/6 RATIO - L/CU.M
PRESSURE DROP - KPA
AIR CORRECTION DIVISION, UOP
THROVAWAY PRODUCT
WET SCRUBBING
LIME
MG/2-6Z
BABCOCK g W1LCOX
UNITED ENGINEERS & CONSTRUCTORS
UNITED ENGINEERS & CONSTRUCTORS
FULL SCALE
NEW
- 7- 99.55
90.00
3/79
SPRAY TOWER
3/79
BABCOCK K WILCOX
1
HILD CARBON STEEL
RUBBER
SS
21.0
242.10 ( 513030 ACFM)
132.2 < 270 F)
7-4 < 55.0 6AL/1000ACF)
1-2 < 5.G IN-H20)
38
-------
EPA UTILITY FGD SURVEY; THIRD QUARTER 1979
ALIEGHENY POWER SYSTEM: PLEASANTS 1 (CONT.)
** MIST ELIMINATOR
TYPE
CONSTRUCTION MATERIAL
** REHEATER
TYPE
TEMPERATURE BOOST - C
** WATER LOOP
TYPE
CHEVRON
FRP
BYPASS
11.1
CLOSED
« 20 F>
------------------------------------------ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION
X REMOVAL PER BOILER F60 CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79
4/79
5/79
6/79
7/79
8/79
9/79
SYSTEM
SYSTEM
*« PROBLEMS/SOLUT10NS/COMWENTS
744
720
START DATE 3/79 END DATE 4/79
,THE UNIT STARTED ON MARCH 7 1979. NO HOURS ARE YET AVAILABLE BECAUSE OF
THE RECENT OPERATING STATUS.
START DATE 3/79 END DATE 4/79
A-HODULE HAS BEEN REMOVED FROM SERVICE DUE TO WELD FAILURE ON THE AB-
SORBER DOUNCOMER.
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
720
START DATE 6/79 END DATE 6/79
THE UTILITY REPORTED THAT THE UNIT WAS TAKEN OUT OF SERVICE ON JUNE 19
DUE TO SEVERE STACK LINER FAILURE. THE UNIT IS PROJECTED TO BE OUT OF
SERVICE UNTIL THE MIDDLE OF AUGUST.
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
744
720
START DATE 7/79 END DATE 9/79
THE UNIT RESTARTED IN LATE SEPT. AFTER COMPLETION OF THE STACK REL1NIN6.
39
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
ARIZONA ELECTRIC POWER COOP
APACHE
2
COCHISE
ARIZONA
195.0
175.0
195.0
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 - Z
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
COAL
BITUMINOUS
23260.
15.00
9.00
.55
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEU
«.1
8/78
1/79
85.00
99.50
.0
.0
C 1COOO BTU/LB)
WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
OPEN
115.9
< 1840 GPM>
DISPOSAL
TYPE
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
672
744
720
•* PROBLEHS/SOLUTIONS/COHMENTS
5/79 SYSTEM
6/79 SYSTEM
START DATE 2/79 END DATE 4/79
COMPLIANCE TESTS WERE RUN ON THIS UNIT LAST NOVEMBER AND THE UNIT UAS
DECLARED COMMERCIAL IN FEBRUARY. THE FGD SYSTEM OPERATES ONLY ABOUT 50
PERCENT OF THE BOILER HOURS BECAUSE THE UNIT OPERATES AT SUCH A LOW
RATING 50 PERCENT OF THE TIME THAT THE FGD SYSTEM IS NOT NEEDED.
START DATE 2/79 END DATE 3/79
A BOILER EXPLOSION AT THE BURNER FACE CAUSED THE UNIT TO BE DOWN FROM THE
LAST WEEK IN FEBRUARY THROUGH THE MIDDLE OF MARCH.
744
720
40
-------
EPA UTILITY FGD SURVEY; THIRD QUARTER 1979
ARIZONA ELECTRIC PO*ER COOP; APACHF 2 (CONT.)
PERFORMANCF DATA
PERIOD MODULE AVAILABILITY OPERA6ILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
SQi PART. HOURS HOURS HOURS FACTOR
** PROBLEPtS/SOLUTIONS/CCKMENTS
START DATE 6/79 END DATE 6/79
THfc UTILITY REPORTED THAT THE UNIT ITSELF RAN WELL BUT WAS EXPERIENCING
FAILURE OF THE FRP REAGENT FEED PIPELINE. THE PIPING IS NOW BEING RE-
PLACED WITH CARBON STEEL.
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
** PROBLEMS/SOLUTIfNS/COMMENTS
START DATE 7/79 END DATE 9/79
DURING THE THIRD QUARTER THE UNIT ONLY OPERATED ABOUT Z5X OF THE lift
BECAUSE OF CONTINUING PROBLEMS WITH THE REAGENT FEED LINE. THE SECTION
FROM THE GRINDER TO THE SCRUBBERS WAS FRP AND IT FAILED. THE LINE HAS
REPAIRED AT THE END OF SEPTEMBER.
START DATE 7/79 LND DATE 9/79
ON NOVEMBER THIRD THE UNIT WILL GO DOWN FOR A 4-6 WEEK SCHEDULED OUTAGE.
41
-------
EPA UTILITY FbD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORKANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EOUIWALENT 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 - 2
AVERAGE MOISTURE CONTENT - 1
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - f.
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 2
RANGE CHLORIDE CONTENT - 7.
** ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
ARIZONA ELECTRIC POWER COOP
APACHE
3
COCHISE
ARIZONA
B
( .100 LB/HMBTU)
( .800 LB/KMBTU)
43.
34*.
59C.O
195.0
175.0
183.0
195.0
RILEY STOKER
PULVERIZED COAL
BASE
**/**
122.
4.9
COAL
BITUMINOUS
23260.
15.00
9.00
<******* ACFM>
{»*** f)
C 400 FT)
( 16.2 FT)
C 10000 BTU/LB)
10000-11000
.55
0.5-0.8
1
HOT SIDE
AIR CORRECTION DIVISION! UOP
99.6
F60 SYSTEM
SALEABLE PRODUCT/THROW AWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEy/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - I
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION COMPLETION
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENT INDEX
ABSORBER
NUMPER
TYPE
INITIAL START UP
SUPPLItR
NUMRER OF STAGES
SHELL MATERIAL
SHELL LINER MATEHAL
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
LlbUID RECIRCULATION RATE - LITER/S
THROWAUAY PRODUCT
WET SCRUBBING
LIMESTONE
NONE
RESEARCH COTTRELL
BURNS 8 MCDONNELL
FULL SCALE
NEW
99.50
85.00
4/79
6/79
4/79
.0
.0
PACKED/SPRAY TOWER
4/79
RESEARCH COTTRELL
1
CARBON STEEL
GLASS-FLEX
188.76
132.2
1260.
( 400000 ACFM)
< 270 F)
(20000 GPW>
42
-------
fPA UTILITY fGD SURVEY: THIRD QUARTER 1
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Wfc
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEt TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 1
AVERAGE CHLORIDE CONTENT - X
ARIZONA PUBLIC SERVICE
CHOLLA
1
JOSEPH CITY
ARIZONA
119.0
115.0
119.0
COAL
BITUMINOUS
23609.
13.50
15.00
.50
.02
( 10150 BTU/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 - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
- Z
UET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
RETROFIT
3.4
10/73
12/73
92.00
80.00
.0
.0
WATER LOOP
TYPE
FRESH HAKE-UP yATER - LITER/S
OPEN
7.6
( 120 GPM)
DISPOSAL
TYPE
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION
1/79
3/79
Z REMOVAL PER BOILER FGD CAP-
SO? PART. HOURS HOURS HOURS FACTOR
78 A
B
SYSTEM
88.2
85.6
86.9
88.1
88.3
88.2
88.2
85.6
86.9
744 744 647
A
B
SYSTEM
99.2
100.0
99.6
99.1
100.0
99.6
99.2
100.0
99.6
744
744
741
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 12/78 END DATE 1/79
THE UTILITY HAS REPORTED THAT THE FGD SYSTEM EXPERIENCED CONTROL PHCB-
LE MS •
2/79 A
B
SYSTEM
A
B
SYSTEM
100.0
100.0
100.0
95.3
100.0
97.7
100.0
100.0
100.0
95.0
100.0
97.5
100.0
100.0
100.0
95.3
100.0
97.7
672 672
744
744
672
727
44
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1* PROBLEMS/SOLUT10NS/CCMMENTS
START DATE
3/79 END DATE 3/79
THE UTILITY HAS EXPERIENCED PLUGGED REHEAT TUBES. THE OLD TUBES, IN UN-
SECT10NALIZED BUNDLES, WERE REPLACED WITH NEW TUBES OF SPLIT COIL CON-
STRUCTION AND MADE OF 316L SS. THE NEW TYPE OF TUBES ALON6 WITH BETTER
MAINTENANCE PROCEDURES HAS ADDED TO THE REHEAT TUBE LIFE AND AVAILABILI-
TY .
4/79
5/79
A
B
SYSTEM
100.0
100.0
100.0
A
B
SYSTEM
99.1
44.1
71 .6
** PROBL.EHS/SOLUTIONS/COMMENTS
START DATE
100.0
100.0
100.0
99.4
44.1
71 .8
100.C
100.0
100.G
99.1
44.1
71 .6
720 720
744
744
720
533
5/79 END DATE 5/79
CORRODED DUCTWORK ON MODULE B WAS REPLACED DURING MAY.
6/79
A
B
SYSTEM
78.0
100.0
89.0
78.0
100.0
89.0
78.0
100.0
89.0
720 720
642
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
THE HUNTERS PACKING WAS REPLACED AND MAINTENANCE WAS PERFORMED ON THE
MODULE A DISCHARGE HEADER.
7/79
8/79
9/79
SYSTEM
SYSTEM
SYSTEM
** PR08LEHS/SOLUTIONS/COMMENTS
START DATE
744
744
720
7/79 END DATE 9/79
NO INFORMATION WAS AVAILABLE FROM THE UTILITY FOR THIS PERIOD.
-------
EPA UTILITY F6D SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORHANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - «W
NET UNIT GENERATING CAPACITY W/FGC - My
EQUIVALENT SCRUBBED CAPACITY - HW
•• FUEL DATA
FUEL TYPE
FUEL GRACE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEy/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP PATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
•• HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•* DISPOSAL
TYPE
ARIZONA PUBLIC SERVICE
CHOLLA
2
JOSEPH CITY
ARIZONA
350.0
250.0
350.0
COAL
BITUMINOUS
23609.
13.50
15. 00
.50
.02
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
< 10150 BTU/LB)
4/78
**/**
75.00
Z 99.70
33.0
1.0
OPEN
7.6
< 120 6PMJ
POND
A AT * — -—. F-»-»--»I——,-—— — — ——• • •. • ••. ••••••-• ——^ •••••. —••••- ir- TIT
V A f A
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP-
S02 PART. HOURS HOURS HOURS FACTOR
12/78 SYSTEM
1/79 SYSTEM
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
6/79 SYSTEM
** PR06LEMS/SOLUTIONS/COMMENTS
744
744
672
744
720
744
720
7/79 SYSTEM
8/79 SYSTEM
9/79 SYSTEM
START DATE 12/78 END DATE 6/79
OPERATION PARAMATERS ARE STILL UNAVAILABLE FOR THIS UNIT.
744
744
720
46
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
ARIZONA PUBLIC SERVICE: CHOLLA 2 (CCNT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERARIL1TY RELIABILITY UTILIZATION 5! REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PRObLEHS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 9/79
NO INFORMATION WAS AVAILABLE FROM THE UTILITY FOR THIS PERIOD.
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FED SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
MOSS UNIT GENERATING CAPACITY - MU
MET UNIT 6ENERAT1N6 CAPACITY W/F6D - MU
EQUIVALENT SCRUBBED CAPACITY - fU
*• FUEL BATA
fUiL TYPE
FUEL 6RADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - T
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** F60 SYSYEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICIPATE DESIGN REMOVAL EFFICIENCY - X
ABSORBER SPARE COMPONENTS INDEX
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
CANTON
ILLINOIS
416.0
378.0
378.0
( 10500 BTU/LB)
COAL
BITUMINOUS
24423.
9.12
18.00
3.30
.03
WET SCRUBBING
LIMESTONE
RILEY STOKER/ENVIRONEER1NG
NEU
Z.9
9/76
8/78
85.00
99.80
1.0
HATER LOOP
T»PE CLOSED
FRESH MAKE-UP WATER - LITER/S 37.8
DISPOSAL
TYPE LINED POND
( 6BO 6PM)
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/78
A
e
c
6
SYSTEM
23.0
26.0
21.0
10.0
20.0
25.0
28.0
23.0
11.0
21.0
25.0
28.0
23.0
11.0
21.0
23.0
26.0
21.0
10.0
20.0
744 7Q6
151 66.0
** PR08LEMS/SOLUTIONS/COMHEN1S
START DATE 12/7P END DATE 12/78
ISOLATION CAMPER FAILURES AND SLURRY RECYCLE DISCHARGE VALVE FAILURES
OCCURRED DURING DECEMBER.
START DATE 12/78 END DATE 12/78
LIMESTONE MILL PROBLEMS AND A PLUGGED LIMESTONE FEEDER HAMPERED SCRUBBER
OPERATIONS DURING DECEMBER.
START DATE 12/78 END DATE 12/78
FROZEN INSTRUMENT CONTROL LINES WERE A PR06LCM.
1/79 A
B
C
0
SYSTEM
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.c
.0
,r
.0
744
738
48
-------
EPA UTILITY FCD SURVEY: THIRD QUARTER 1979
CENTRAL ILLINOIS LIGHT: DUCK CREEK 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER ~fll""le"
S02 PART. HOURS HOURS HOURS FACTOR
2/79
3/79
4/79
** PR08LEMS/SOLUTIONS/COPIMENTS
START DATE 1/79 END DATE 1/79
FROZEN INSTRUMENT CONTROL LINES, RECYCLE TANK. SUCTION LINES, MAIN MODULE
DRAIN LINES AND MIST ELIMINATOR DRA*h LINES WERE MAJOR PROBLEM AREAS
DURING JANUARY.
START DATE 1/79 END DATE 1/79
SLURRY RECYCLE VALVE PLUGGAGE AND SLURRY TRANSFER PUMP FAILURE CONTRIBUTED
TO THE SYSTEM OUTAGE TIME.
A
B
C
D
SYSTEM
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
•0
.0
.0
.0
.0
.0
.0
.0
.0
672 533
0 80.5
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79
START DATE
END DATE 2/79
RECYCLE PUMP SUCTION VALVE FAILURES AND A SLURRY TRANSFER PUMP FAILURE
CONTRIBUTED TO THE NON-OPERATION OF THE FGD SYSTEM.
2/79 END DATE 2/79
FROZEN KIST ELIMINATOR DRAINS. ABSORBER DRAINS AND INSTRUMENT LINES tERE
A MAJOR PROBLEM DURING FEBRUARY.
A
B
C
D
SYSTEM
33.7
6.7
.0
.0
10.1
31.1
6.7
.0
.0
9.4
31.1
6.7
.0
.0
9.4
31.1
6.7
.C
.0
9.4
744
744
7G
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 3/79 END DATE 3/79
FREEZING PROBLEMS CONTINUED TO HAMPER FGD OPERATIONS DURING MARCH.
START DATE 3/79 END DATE 3/79
BROKEN MIST ELIMINATOR SPRAY LINES AND PLUGGED MIST ELIMINATOR NOZZLES
WERE PROBLEM AREAS DURING MARCH.
START DATE 3/79 END DATE 3/79
RECYCLE PUMP FAILURES AND WASTE WATER PUMP FAILURES WERE EXPERIENCED
DURING MARCH.
START DATE 3/79 END DATE 3/79
PLUGGED SLURRY NOZZLES AND GENERAL INSTRUMENTATION PROBLEMS WERE REPORTED
BY THE UTILITY.
A
B
C
D
SYSTEM
100.0
.. 84.3
86.5
21.3
73.0
71.9
50.5
81 .2
22.7
56.4
67.3
47.3
76.0
21.3
72.0 53.0
720 674
80
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 4/79
.. . . END DATE 4/79
INLET DAMPER MALFUNCTIONS HINDERED FGD OPERATION DURING APRIL.
START DATE 4/79
END DATE 4/79
PLUGGED MIST ELIMINATOR SPRAY NOZZLES DURING APRIL HINDERED FGD OPERATION.
START DATE 4/79
END DATE 4/79
SLURRY CONTROL VALVE MALFUNCTIONS fcERE REPORTED BY THE UTILITY-
START DATE 4/79
[NO DATE 4/79
RECYCLE TANK MIXER FAILURES WERE EXPERIENCED DURING APRIL.
-------
EP» UTILITY FGD SURVEY: THIRD QUARTER 1979
CENTRAL ILLINOIS LIGHT: DUCK CREEK 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/79
START DATE
A
B
C
D
SYSTEM
95.7
95.7
94.6
1.3
71.9
4/79 END DATE 5/79
RECYCLE PUMP BELT AND BEARING FAILURES AND SLURRY SUPPLY LINE FAILURES
HERE REPORTED BY THE UTILITY.
37.4
44.2
41.8
5.0
32.1
51 .4
1.3
11.7
11.1
1.3
8.5
744
197
** PROBLEMS/SOLUT10NS/COMHENTS
6/79
A
B
C
D
SYSTEM
START DATE
START DATE
70.6
79.9
76.1
82.6
87.4
5/79 END DATE 5/79
MIST ELIMINATOR PUMP MALFUNCTIONS WERE REPORTED DURING MAY.
5/79 END DATE 5/79
MILL SHAKER BASKET DRIVE MOTOR FAILURES WERE ENCOUNTERED.
76.9
86.9
83.1
90.0
£4.2
86.1
70.5
79.9
76.3
82.6
77.3
72Q 661
557
*• PROBLEMS/SOLUTIONS/COMMENTS
7/79
START DATE 6/79 END DATE 6/79
DURING JUNE SOME PROBLEMS KITH THE MIST ELIMINATOR WERE ENCOUNTERED. THESE
PROBLEMS INCLUDED PLUGGING IN THE MIST ELIMINATOR AND THE HIST ELIHIMTO*
LINES AND A BROKEN MIST ELIMINATOR RETURN LINE.
59.8
61.6
61.4
60.5
95.9 60.9 744 520 453
** PROBLEMS/SOLUTIONS/COMMENTS
A
B
C
D
SYSTEM
61.6
61.6
60.3
95.0
85.6
88.3
87.9
86.5
87.1
START DATE
7/79 END DATE 7/79
IN JULY THE MIST ELIMINATOR PLUGGED CAUSING OPERATIONAL PROBLEMS.
START DATE 7/79 END DATE 7/79
RECYCLE PUMP FAILURES WERE ENCOUNTERED DURING JULY.
8/79
A
B
C
D
SYSTEM
3.0
23.4
13.6
9.5
13.0
4.2
31.4
18.4
12.8
16.6
22.9
3.1
23.4
13.7
9.5
12.3
744 555
92
PROBLEMS/SOLUTIONS/COMMENTS
9/79
START DATE 8/79 END DATE 8/79
IK AUGUST THE MIST ELIMINATOR AND THE HIST ELIMINATOR DRAIN LINES PLUGGED
CAUSING SOME DOWN TIME.
START DATE 8/79 END DATE 8/79
FAILURES WITH THE LIMESTONE SLURRY FORWARDING PUMP AND THE RECYCLE PUMP
START DATE 8/79 END DATE 8/79
DAMPER MALFUNCTIONS WERE REPORTED BY THE UTILITY.
49.9
44.7
35.9
79.6
6*'8 52-5 720 665 378
A
B
C
D
SYSTEM
49.9
44.6
35.9
79.6
65.7
54.0
48.4
38.9
.86.2
56. f
50
-------
FPA UTILITY FGo SURVEY: THIRD QUARTER 1979
CENTRAL ILLINOIS LIGHT: DUCK CREEK 1 ICONT.)
------------------------------------------ PERFORMANCE DATA ---- - -------------------------------------
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION I REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLLMS/SOLUT10NS/COMMENTS
START BATE 9/79 END DATE 9/79
PLUGGING IN THE MIST ELIMINATOR, MIST ELIMINATOR HEADER AND NOZZLES
WERE ENCOUNTERED IN SEPTEMBER.
START DATE 9/79 END DATE 9/79
THE DAMPER FAILED CAUSING A PROBLEM DURING SEPTEMBER.
START DATE 9/79 END DATE 9/79
THE UTILITY REPORTED MIST ELIMINATOR CAVITAT10N PROBLEMS.
START DATE 9/79 END DATE 9/79
PLUGGED SLURRY NOZZLES AND LIMESTONE CONVEYOR FAILLES CONTRIBUTED TO THE
OUTAGES EXPERIENCED.
-------
EPA UTILITY F6D SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - flu
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - nu
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
NEWTON
ILLINOIS
A
* *****
617.0
575.0
** **** *
617.0
(****** LB/MMBTU)
(****** LB/MMBTU)
** BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.H/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
0/78
1020.95 <2163480 ACFM>
163.9 < 327 F)
162. < 530 FT>
******* (***** FT>
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
BANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - TL
COAL
BITUMINOUS
25353.
t.co
******
4.00
.20
( 10900 BTU/LB)
* * **•* *
ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FLUE GAS TEMPERATURE - C
- x
COLD SIDE
RESEARCH COTTRELL
99.5
162.8 < 325 F>
** FGD SYSTEM
SALEABLE PRODUCT/THROWAWA Y PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
MEM/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
SO 2 DESIGN REMOVAL EFFICIENCY - t
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION INITIATION
•• ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
SMELL LINER MATERIAL
L/G RATIO - L/CU.M
SUPERFICAL GAS VELOCITY - M/SEC
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONTRATION - PPM
THROWAWAY PRODUCT
WET SCRUBBING
DUAL ALKALI
BUELL/ENVIROTECH
SARGENT ft LUNDY
FULL SCALE
NEW
- X 99.50
95.00
12/79
9/79
11/76
TRAY TOyER
11/79
BUELL ENVIROTECH
CE1LCOTE
1«3 < 10.0 GAL/1000ACF)
2.5 { 8.3 FT/S)
2590
200
52
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
CENTRAL ILLINOIS PUBLIC SERV: NEWTOfc 1 (CONT.)
** FANS
NUMBER
TYPE
** VACUUM FILTER
TYPE
** HIST ELIMINATOR
NUMBER
CONFIGURATION
** REHEATER
NUMBER
TYPE
** REHEATER
NUMBER
TYPE
TEMPERATURE BOOST - C
** THICKENER
NUMBER
CONSTRUCTION MATERIAL
DIAMETER - H
** THICKENER
NUMBER
CONSTRUCTION MATERIAL
DIAMETER - M
** WATER LOOP
TYPE
** TREATMENT
TYPE
CONTRACTOR
BOOSTER
EXTRACTION FILTERS,HORIZONTAL.BELT T
VERTICAL
BYPASS
IN-LINE
13.9
CONCRETE
30.5
25 F)
(100 FT)
COATED STEEL
15.2 ( 50 FT)
CLOSED
POZ-0-TEC
IUC S
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
2 REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/79 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
START DATE 9/79 END DATE 9/79
INITIAL OPERATIONS BEGAN AT THIS UNIT ON SEPTEMBER 1 WHEN FLUE GAS WAS
PASSED THROU6H THE INDIVIDUAL FGD MODULES FOR TESTING PURPOSES. TESTING
OF THE SYSTEM IN AN INTEGRATED MODE IS EXPECTED TO BEGIN IN DECEMBER.
53
-------
EPA UTILITY FGD SURVEY: THIRD QUARTLR 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mk
NET UNIT GENERATING CAPACITY W/FGD - MW
EOUIVALENT SCRUBBED CAPACITY - MW
COLUMBUS 8 SOUTHERN OHIO ELEC .
CONESVILLE
5
CON£SVjLLE
OHIO
411.D
375.0
411.0
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - 1
AVERAGE CHLORIDE CONTENT - %
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEM/RETROFIT
ENERGY CONSUMPTION - Z
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
- z
COAL
BITUMINOUS
25237. t 10850 BTU/LB>
15.10
7.50
4.67
UET SCRUBBING
LIME
AIR CORRECTION DIVISION, UOP
NEW
3.9
1/77
2/77
89.50
99.60
.0
.0
OPEN
31.5
( 500 6PM>
TREATMENT
TYPE
POZ-0-TEC
DISPOSAL
TYPE
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
A
B
SYSTEM
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
672 0
** PROULEMS/SOLUTIONS/COMMENTS
START BATE 2/79
END DATE 2/79
THE SYSTEM DID NOT OPERATE DURING FEBRUARY BECAUSE OF SEVERE WINTER kEATMER
3/79
4/79
A
B
SYSTEM
A
B
SYSTEM
50.0
.C
25.0
17.0
.0
8.5
49.0
.0
24.5
5P.O
.0
29.0
50.0
.0
25.0
73.0
.0
36.5
43.0
.0
21.5
12.0
.0
6.0
744 652
720
149
160
43
'• PROBLEMS/SOLUTIONS/COMMENTS
START DATE 3/79 END DATE 4/79
MODULE B DID NOT OPERATE DURING APRIL BECAUSE OF SEVERE CORROSION
AT THE PRESATURATOR INLET DUCT WHICH UOP HAS BEEN REPAIRING SINCE MARCH.
-------
fcPA UTILITY FGD SURVEY: THIRD QUARTER 1979
COLUMBUS & SOUTHERN OHIO ELEC.: CONtSVILLE 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA6IL1TY RELIABILITY UTILIZATION % REMOVAL PER BOILER FGO CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
5/79
6/79
A
B
SYSTEM
.0
.0
.0
,c
.0
.0
.0
.0
.0
.0
.0
.0
744
744
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 5/79
7/79
8/79
9/79
START DATE
END DATE 5/79
REPAIRS WERE MADE TO THE SEAL BETWEEN THE THICKENER BASE AND
5/79 END DATE 5/79
THE FGD SYSTEM WAS DOWN DURING MAY FOR AN ANNUAL OUTAGE.
A
B
SYSTEM
69.0
50.0
59.5
35.0
21 .0
28.0
36.0
22.0
29. 0
33.0
20.0
26.5
720 670
191
PROBLEMS/SOLUTIONS/COMMENTS
START DATE
START DATE
5/79 END DATE 6/79
PLUGGED PH LINES WERE A PROBLEM DURING MAY AND JUNE.
5/79 END DATE 6/79
FLYASH CONVEYING PROBLEMS RESULTED IN ABOUT 2 DAYS OUTAGE.
START DATE 6/79
END DATE 6/79
OUTLET DAMPER PROBLEMS MERE REPORTED BY THE UTILITY.
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
744
720
START DATE 7/79 END DATE 9/79
NO INFORMATION WAS AVAILABLE FROM THE UTILITY FOR THE THIRD 8UARTER.
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITT
STATE
CROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD -
EQUIVALENT SCRUBBED CAPACITY - RU
»• 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
COLUMBUS & SOUTHERN OHIO ELEC-
CONESV1LLE
6
CONESVILLE
OHIO
411.0
375.0
411.0
COAL
BITUMINOUS
25237.
15.10
7.50
4.67
< 10850 BTU/LB)
FGD SYSTEM
GENERAL PROCESS TTPE
PROCESS TVPE
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
UET SCRUBBING
LIME
AIR CORRECTION DIVISION, UOP
NEW
3.9
6/78
**/**
89.50
99.60
.0
.0
HATER LOOP
TTPE
f*ESM MAKE-UP WATER - LITER/S
OPEN
31.5
( 500 6PM>
TREATMENT
TYPE
DISPOSAL
TYPE
POZ-0-TEC
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL
SO? PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
2/79 A
e
SYSTEM
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
672
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE
3/79
A
a
SYSTEM
4/79 A
B
SYSTEM
5/79 A
B
SYSTEM
43.0
32.0
37.5
82.0
72.0
77.0
.0
.0
.0
2/79 END DATE 2/79
THE FGO SYSTEM DID NOT OPERATE DURING FEBRUARY DUE TO SEVERE WINTER LEATHER
37.0
28.0
32.5
79.0
59.0
69.0
.0
.0
.0
39.0
29.0
34.0
79.0
59.0
69.0
.0
.0
.0
33.0
25.0
29.0
78.0
58.0
68.0
.0
.0
.0
744 664
720 711
744
216
489
56
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
COLUMBUS & SOUTHERN OHIO ELEC.: CONESVILLE 6 (CONT.)
PER FORMAN'CE DATA
PERIOD MODULE AVAILABILITY OPERARIL1TY RELIABILITY UTILIZATION X REMOVAL PER B01LE I" FG l""lp~.~
SOt PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 5/79
REPAIRS WERE HADE TO THE SEAL BETWEEN THE THICKENER BASE AND SIDEWALL.
START DATE
5/79 END DATE 5/79
THE BOILER DID NOT OPERATE DURING KAY.
6/79 A
B
SYSTEM
43.0
49.0
46.0
37.D
4P.O
43.0
39.0
52.0
45.5
27.D
31.0
29.0
720 433
186
PROBLEMS/SOLUT1 JNS/COMMENTS
START DATE 6/79 END DATE 6/79
FLTASH CONVEYING PROBLEMS RESULTED It* ABOUT 2 DAYS OUTAGE.
START DATE 5/79 END DATE 6/79
PLUGGED PH LINES WERE A PROBLEM DURING THIS PERIOD.
7/79 SYSTEM
8/79 SYSTEW
9/79 SYSTEH
** PR06LEHS/SOLUTIONS/COMHENTS
START DATE
744
744
720
7/79 END DATE 9/79
NO INFORMATION WAS AVAILABLE FROM THE UTILITY FOR THE THIRD OUARTER.
57
-------
EPA UTILITY Fl>D SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - KW
GROSS UNIT GENERATING CAPACITY - Mfc
NET UNIT GENERATING CAPACITY V/FGO - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - HW
** BOILER DATA
SUPPLIER
TYPF
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 - t
AVERAGE MOISTURE CONTENT - Z
RAN6E MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - Z
•• ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FLUE GAS TEMPERATURE - C
PARTICULATE OUTLET LOAD - G/CU.H
*• FGD SYSTEM
SALEABLE PRODUCT/THR OW AWA V PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
CONSTRUCTION INITIATION
«» ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMPER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
N027LE TYPE
L/6 RATIO - L/CU.M
S02 INLET CONCENTRATION - PPf
S02 OUTLET CONTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
COOPERATIVE POWER ASSOCIATION
COAL CREEK
UNDERWOOD
NORTH DAKOTA
A
43.
516.
1100.0
545. 0
495.0
( .,100 LB/MMBTU)
( 1.200 LB/MMBTU)
327.0
COMBUSTION ENGINEERING
PULVERIZED LIGNITE
BASE
**/**
******** <«*««**i
160.0 t 320 F>
198. C 650 FT)
6.7 ( 22.0 FT)
COAL
LIGNITE
14556.
7.14
3.89-15.95
39.83
27.78-52.55
.63
0.18-1.41
.02
0.00-0.08
1
COLD SIDE
WHEELABRATOR-FRYE
99.5
160.6 <
.02 (
C 6258 BTU/LB)
3068-7660
321 F)
.01 GR/SCF)
THROWAWAV PRODUCT
WET SCRUBBING
LIME/ALKALINE FLVASH
COMBUSTION ENGINEERING
BLACK g VEATCH
FULL SCALE
NEW
- X 99.50
90.00
8/79
8/77
SPRAY TOWER
8/79
COMBUSTION ENGINEERING
3
22 X 22 X ZG
316L SS
PROPRIETARY ATOMIZING
8.0 C 60.0 GAL/1000ACF)
1000
100
90.0
58
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
COOPERATIVE POWER ASSOCIATION: COAL CREEK' 1 CCONT.)
FANS
NUMBER
TYPf
WIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
MUMPER Of STAGES
HIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
A
I .D.
CHEVRON
FRP
2
BULK ENTRAPMENT SEPARATOR
FRP
PUMPS
SERVICE
BLEED STREAM
SLURRY FEED
REACTION TANK
NUMBER
3
* ** *
6
TANKS
SERVICE
RE ACTION-RECYCLE-THICKENER
FLYASH WETTING
LIME FEED
NUMBER
2
*** *
****
REHEATER
TYPE
TEMPERATURE BOOST - C
MATER LOOP
TYPE
BYPASS
47.2 ( 85 F>
OPEN
REAGENT PREPARATION EQUIPMENT
NUMBER OF SLAKERS
TREATMENT
TYPE
DISPOSAL
NATURE
TYPE
AREA - ACRES
FLYASH STABILIZED
FINAL
LINED POND
104.0
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION % REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
8/79 SYSTEM
9/79 SYSTEH
744
720
** PR06LEMS/SOLUTIONS/CCMMENTS
START DATE 8/79 END DATE 9/79
THIS UNIT STARTED COMMERCIAL OPERATIONS ON AUGUST 1, 1979.
PROBLEMS WERE REPORTED DURING START UP.
SOME MINOR
59
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MW
MET 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 - Z
AVERAGE CHLORIDE CONTENT - X
** f6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICIPATE DESIGN REMOVAL EFFICIENCY - X
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER'S
•* TREATMENT
TYPE
*» DISPOSAL
TYPE
OUQUESNE LIGHT
ELRAHA
1-4
ELRAMA
PENNSYLVANIA
510.0
475.0
510.0
********
UET SCRUBBING
LIME
CHEMICO
RETROFIT
3.5
10/75
10/75
83.00
99.00
35.0
1.3
OPEN
BTU/LB)
{***** GPM)
POZ-0-TEC
LANDFILL
ft AT A • ••••
u M I I* —*™
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
Z REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
7/78 101
201
301
401
501
SYSTEM
8/78
101
201
301
401
501
SYSTEM
63.8
100.0
70.8
100.0
82.1
85.7
84.4
100.0
55.6
100.0
77.9
87.5
*• PROBLEMS/SOLUTIONS/COMMENTS
59.9
100.0
66.5
99.3
77.2
80.5
76.9
100.0
50.7
100.0
70.9
79.7
744 699
599
744 678
593
START DATE 8/78 END DATE 9/78
DURING AUGUST, MODULES 301 AND 501 WERE TAKEN OFF LINE FOR CLEANING.
START DATE 8/78 END DATE 9/7P
RUBBER LINING ON THREE FAN HOUSINGS WAS REPAIRED.
60
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
DUQUESNE LIGHT: ELRAMA 1-4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FED CAP.
502 PART. HOURS HOURS HOURS FACTOR
START DATE 8/78 END DATE 9/78
IT WAS NECESSARY TO SHUT DOWN THE LIME MIXING BAS1M IN ORDER TO CLEAN OUT
EXCESSIVE 6RIT AND SOLIDS BUILD UP.
START DATE 12/78 END DATE 12/78
A COMPLIANCE TEST WAS RUN IN DECEMBER WHICH SHOWED THE UNITS TO BE I ((
COMPLIANCE.
9/78 101
201
301
401
501
SYSTEM
10/78 101
201
301
401
501
SYSTEM
11/78 101
201
301
401
501
SYSTEM
12/78 101
201
301
401
501
SYSTEM
78.2
61 .0
96.5
84.6
100.0
84.3
84.9
100.0
100.0
69.3
87.2
96.4
1DO.O
94.2
100.0
100.0
75.0
98.8
100.0
77.8
91.7
69.4
74. 4
82.8
72.1
56.3
89. D
78.1
93.6
77.8
76.6
98.9
100.0
80.5
78.6
86.9
100.0
78.4
84.2
86.8
62.5
82.4
94.7
72.7
85.6
64. S
69.5
77.4
720 664
560
744 671
647
720 600
593
744 695
576
*» PROBLEBS/SOLUTIONS/COMMENTS
START DATE 12/78 END DATE 1/79
THE UTILITY HAS STARTED HAULING SLUDGE OFF SITE TO AN AREA ABOUT 10 JULES
AWAY.
1/79 101
201
301
401
501
SYSTEM
2/79 101
201
301
j 401
' 501
SYSTEM
3/79 101
201
301
401
501
SYSTEM
1/79 101
201
301
401
501
SYSTEM
45.9
100.0
22.9
100.0
100.0
91.2
100.0
96.3
15.1
100.0
100.0
85.8
100.0
100.0
97.5
51.9
87.0
96.6
E1 .1
70.0
100.0
100.0
1CO.C
1QO.C
39.8
95.2
60.2
100.0
1QO.O
79.0
100.0
90.2
14.1
97.3
100.0
80.4
95.4
91.0
73.8
39.2
65.9
73.1
61.9
53.5
99.3
89.9
90.4
76.5
744 645
588
672 629
540
744
563
544
720 550
569
61
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
DUQUESNE LIGHT: ELRAKA 1-4 CCONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
2 REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR
5/79
6/79
7/79
8/79
201
301
401
5C1
SYSTEM
101
201
301
501
SYSTEM
1C1
201
301
401
501
SYSTEM
101
201
301
401
501
SYSTEM
100.0
100.0
94 .5
100.D
24.3
91.5
100.0
63.1
43.2
1CO.O
1CO.O
86.1
89.1
100.0
94.5
100.0
44 .8
88.3
100.0
100.0
100.0
36.7
80.3
88.4
100.0
97.8
83.1
100.0
21.4
80.5
100.0
58.5
40.0
100.0
100.0
79.7
81.0
94.8
66.0
99.3
40.7
80.4
98.7
100.0
96.5
33.3
72.8
80.2
744 655
599
7ZO 667
574
744 677
598
744 675
597
62
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - WW
NET UNIT GENERATING CAPACITY W/FGD - MW
EOUIVALENT SCRUBBED CAPACITY - WH
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J /(,
AVERAGE ASH CONTENT - X
AVERAGE H01STURE CONTENT - X
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
DUQUESNE LIGHT
PHILLIPS
1-6
SOUTH HEIGHT
PENNSYLVANIA
408.0
373.0
410.0
COAL
BITUMINOUS
26830.
16.27
5.02
1.92
( 11535 STU/LBJ
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
WET SCRUBBING
LIME
CHEMICO
RETROFIT
3.4
7/73
**/**
83.CO
99.00
18.0
.6
** WATER LOOP
TYPF
FRESH MAKE-UP WATER - LITER/S
OPEN
<***«* 6PM)
** TREATMENT
TYPE
POZ-0-TEC
** DISPOSAL
TYPE
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
% REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/78
101
201
301
4D1
SYSTEM
8/78 101
201
301
4C1
SYSTEM
9/78 101
201
301
401
SYSTEM
82.8
75.3
1CO.O
100.0
100.0
100.0
88.1
10C.O
1CO.O
100.0
91.6
100.0
99.2
81 .8
95.9
48.3
43.9
78.7
76.0
61.7
97.3
71.9
88.8
85.1
85.8
62.4
75.5
67.5
55.7
65.3
744 434 459
744 607 638
720 490 470
63
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
DUOUESNE LIGHT: PHILLIPS 1-6 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
2 REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
** PROBLENS/SOLUTIONS/COMMENTS
START DATE
START DATE
START DATE
START DATE
START DATE
START DATE
8/78 END DATE 9/78
DURING THE AUGUST-SEPTEMBER PERIOD HIST ELIMINATOR CLEANING TOOK PLACE IN
ORDER TO CORRECT THE PLUGGING PROBLEM.
8/78 END DATE 9/78
IN AUGUST THE INTERNAL MIST ELIMINATOR ON MODULE 201 UAS REPLACED.
8/78 END DATE 9/78
THE LIME MIXING BASIN HAD TO BE SHUT DOWN OVER A WEEKEND SO THAT EXCESSIVE
GRIT AND SOLID PARTICLES THAT HAD BUILT UP COULD BE CLEANED OUT,
8/78 END DATE 9/78
HIGH PRESSURE WATER CLEANING WAS PERFORMED ON NODULES 101 AND 401.
8/78 END DATE 9/78
THE RUBBER LINING IN MODULE 101 UAS REPAIRED.
8/78 END DATE 9/78
A MAJOR PROBLEM AREA DURING THE PERIOD UAS CAUSED BY INSUFFICIENT SUPPLIES
OF DRY FLYASH TO MIX WITH THE SLUDGE. AS A RESULT THE SLUDGE HAS BEEN
LEAKING OUT OF THE TRANSPORT TRUCKS WHILE IN TRANSIT TO THE FINAL DISPOSAL
SITE. APPARENTLY NOT ENOUGH FLYASH IS BEING COLLECTED WITH THE PRESENT
SYSTEM.
10/78
11/78
12/78
101
201
301
401
SYSTEM
101
201
301
401
SYSTEM
101
201
301
401
SYSTEM
100.0
100.0
100.0
3.3
98.5
51.5
100.0
100.0
86.4
93.6
100.0
100.0
38.5
100.D
100.0
96.1
87.5
87.9
2.2
68.4
41.1
100.C
88.9
69.0
74.7
90.9
88. 0
27. 8
87.5
73.5
744 517 509
720 575 538
744 537 547
** PROBLEMS/SOLUTIONS/COHMENTS
START DATE 12/78 END DATE 1/79
DURING THE PERIOD THE LACK
1/79
2/79
3/79
101
201
301
401
SYSTEM
101
201
301
401
SYSTEM
1C1
2C1
301
401
SYSTEM
4/79 101
100.0
95.5
69.0
100.0
1CC.O
50.3
93.4
100.D
1CO.O
96.9
.0
100.0
100.0
100.0
96.2
100.0
OF FLYASH FOR MIXING WITH SLUDGE HAS A PROBLEM.
86.7
69.2
50.0
83.7
72.4
38.P
72.1
88. 2
100.C
74.8
.0
96.2
88.0
1CO.C!
71.1
86.P
744 539
672 519
744
550
539
503
529
64
-------
IPA UTILITY FCO SURVEY: THIRD QUARTER 1979
DUOUESNE LIGHT: PHILLIPS 1-c (CCNT.)
PE RfORMANCF DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION
% REMOVAL
soz PART.
PER BOILER FGD CAP-
HOURS HOURS HOURS FACTOR
201
301
1,01
SYSTEM
5/79 101
2C1
301
401
SYSTEM
6/79 101
201
301
401
SYSTEM
7/79 101
201
3C1
401
SYSTEM
8/79 101
201
301
401
SYSTEM
9.3
100.0
1CO.C
100.0
1CO.O
.0
1 CO .C
1CO.D
100.0
100.0
34.2
1 CO .C
1 CO .C
97.6
1 CO.C
100.0
£9.8
32.1
91 .7
1CO.O
100.0
1 00 .0
.0
5.F
85.C
84.9
65.7
100.0
.C
96.6
99.1
73.
-------
FPA UTILITY FC,D SURVEY: THIRD GUARTtR 1979
SECTION 3
DISIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY IjAME
PLANT NAME
UNIT NUMDER
CITY
STATE
GROSS UNIT GiNtRATING CAPACITY - MW
NET UNIT GENtRATlNli CAPACITY W/FGD -
EQUIVALENT SCRUBBED CAPACITY - fW
INDIANAPOLIS PO*ER i. LIGHT
PETLRSRURG
j
PETERSBURG
INDIANA
532.0
515.0
532.0
** FUEL DATA
FUEL TYPE
FUtL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - T
AVERAGE SULFUR CONTENT - '/,
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - •>.
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - 2f
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
COAL
BITUMINOUS
25004. < 10750 STU/LB)
- X
MET SCRUBBING
LIMESTONE
AIR CORRECTION DIVlSlONt UOP
NEW
2.4
12/77
** /* *
85.00
99.30
.6
** HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
55.6
( 8S2 GPM)
•* TREATMENT
TYPE
POZ-0-TEC
** DISPOSAL
TYPE
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION
% REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
•« PROoLEMS/SOLUTIONS/COMMENTS
START DATE
672
3/79
A
6
C
D
SYSTEM
2/79 END DATE 2/79
THu UTILIZATION FIGURES GIVEN BELOW ARE FOR THE PERIOD SEPTEMBER-DEC EMBER
1978.
31.2
30. C
48.0
48.C
39.C 744 715
•« PRObLEMS/SOLUTlONS/COMMENTS
START DATE 1/79 tND DATE 3/79
THE FGD SYSTEM WAS DOyN FROM JANUARY 1 TO MARCH 15 DUE TO SEVERE WINTER
WE ATHE R.
4/79 SYSTEM
722
66
-------
EPA UTILITY FGO SUKVEV: THIRD QUARTER 1979
INDIANAPOLIS POWER & LIOHTr PETERSBURG 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY CPEPARIL1TY RELIABILITY UTILIZATION % REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PRObLEMS/SOLUTIONS/COMMENTS
START DATE 4/79 END DATE 5/79
DUE TO THE FORMER STACK LINING PEELING AWAY, THE STEEL
SHELL WAS SAfcfD BLASTED AND R1G1FLAKE 4050 APPLIED BY TROWEL.
START DATE MTt END DATE 5/79
ALL MIST ELIMINATORS WERE CLEANED DUE TO SEVERE SCALING PROBLEMS.
START DATE 4/79 END DATE 5/79
EXTENSIVE REPAIRS WERE HADE TO THE INLET DAMPERS, THE OUTLET DUCTS WERE
LINED WITH RESISTIFLAKE 1150, AND MAJOR REPAIRS WERE MADE TO SONNETS
BECAUSE OF ACID CORROSION.
START DATE 4/79 END DATE 5/79
THE SYSTEM HAS BEEN DOWN SINCE MID-MARCH FOR INSPECTION AND MAINTENANCE.
5/79 SYSTEM 744
6/79 SYSTEM 7?0
** PR08LEMS/SOLUT1 ONS/COMMENTS
START DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT THE SYSTEM RAN ABOUT THREE DAYS TOTAL DURING THIS
PERIOD.
START DATE 5/79 END DATE 6/79
PROCESS CONTROL HAS BEEN A VERY MAJOR PROBLEM AREA.
START DATE 5/79 END DATE 6/79
MIST ELIMINATOR PLUGGING CONTRIBUTED TO THE OUTAGE EXPERIENCED DURING.THIS
PERIOD.
7/79 SYSTEM
8/79 SYSTEM
9/79 SYSTEM
** PRObLEMS/SOLUTIONS/COMKENTS
744
744
720
START DATE 7/79 END DATE 9/79
NO INFORMATION WAS AVAILABLE FROM THE UTILITY FOR THE THIRD QUARTER 1979.
67
-------
EPA UTILITY F&D SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FCD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - I»U
KANSAS CITY POWER & LIGHT
HAWTHORN
3
KANSAS CITY
MISSOURI
90.0
85.0
90.0
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - X
COAL
BITUMINOUS
22795.
11.00
.60
( 9800 BTU/LB)
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO 2 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
11/72
** /**
70.00
99.00
.6
CLOSED
(***** GPM>
TREATMENT
TYPE
DISPOSAL
TYPE
FLYASH STABILIZED
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
** PROBLEHS/SOLUTION'./COMMENTS
672
744
START DATE 1/79 END DATE 3/79
OPERATING INFORMATION IS STILL NOT AVAILABLE FOR UNIT 3.
4/79 SYSTEM 18.0 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
18.1
720 130
130 9.0
START DATE 4/79 tND DATE 4/79
THE BOILER WAS DOWN IN APRIL FOR 543 HOURS FOR TURBINE OVERHAUL.
5/79 SYSTEM 55.0 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
55.0
744 409
409 29.0
6/79 SYSTEM
START DATE 5/79 END DATE 5/7"
IN MAY THE OUTAGE TIME WAS DUE TO BOILER TUBE LEAKS.
96.C
720 6«1
68
-------
EPA UTILITY FCD SURVEY: THIRD QUARTER 1979
KANSAS CITY POWLR f LIGHT: HAWTHORN J tCONT.)
PER FORMANCE DATA
PERIOD MODULE AVAILABILITY UPERABIL1TY RELIABILITY UTILIZATION % REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
7/79 SYSTEM
g/79 SYSTEM
9/79 SYSTEM
100.0
75.0
84.0
744 744
744 55K
720 605
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 8/79
THt UTILITY BURNED PRIMARILY GAS DURING JUNE, JULY AND AUGUST. THE LN1T
RETURNED TC FIRING ALL COAL IN StPTEKBER. THE SCRUBBER WAS LARGELY
AVAILABLE [>UT WAS NOT NEEDED FOR KGST OF THE PERIOD- THt UTjLlTY REPORTED
ONLY REGULAR MAINTENANCE TOOK PLACE UITH NO PROBLEMS ENCOUNTERED.
69
-------
EPA UTILITY fCD SURVEY: THIRD GUARTER 1979
SECTION 3
DFS1GN AMD PERFORMANCE DATA FOR OPERATIONAL FGO SYSTEMS
COMPANY NAI'E
PLANT NAME
UNIT NUP'iER
CITY
STATE
GROSS UVIT GENERATING CAPACITY - *U
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - I"W
»* FuEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE MEAT CONTENT - J/G
AVLRAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - *
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 - i
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH KAK.E-UP WATER - L1TER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
KANSAS CITY POWE" 6 LIGHT
HAWTHORN
i.
KANSAS CITY
MISSOURI
9C.C
85.0
90.C
( 9800 BTU/LB)
COAL
BITUMINOUS
22795.
11.Co
.60
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
8/72
* * /**
70.00
99.00
CLOSED
(***»*
FLYASH STABILIZED
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
i/79 SYSTEM
3/79 SYSTEM
** PROLL£MS/SOLUTIONS/COWENTS
672
744
START DATE 1/79 tND DATE 3/7"?
OPERATING INFORMATION FOR UNIT 4 IS STILL NOT AVAILABLE.
720 410 410 30.0
4/75 SYSTEM 57.0 100.0 57.C
•* PROuLEMS/SOLUTIONS/COMMENTS
START DATE 4/79 END DATE 4/79
AN EXCITER FAILURE ON THE GENERATOR CAUSED THE APRIL OUTAGE T1*E.
SYSTEM 94.0 100.0 94. G
** PROLLEMS/SOLUTIONS/COM"> ENTS
744 699
699 49.C
START DATE 5/79 END DATF 5/70
fAY OUTAGE TIWE WAS FOR SCRUBBER CLEANING AND GENERAL KAINTENANCE.
6/79 SYSTEM
720 101
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
KANSAS CITY POWER £ LIGHT: HAWTHORN 6 (CONT.)
PERIOD
7/79
S/79
9/79
_ _ __-... __K|: K hUKHH
MODULE AVAILABILITY OPERAPIL1TY RELIABILITY
SYSTEM
SYSTEM
SYSTEM
93. C
100.0
69.0
UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
744
744
720
692
744
497
** PRObLEMS/SOLUTlONS/COWENTS
START BATE 6/79 END DATE 9/79
DURING JULY AND AUGUST MOSTLY GAS WAS FIRED. THERE WERE NO MAJOR SCRUBBER
PROBLEMS AND HIGH AVAILABILITY RESULTED BECAUSE OF THE LOW DEMAND FOR THE
UNIT.
71
-------
EPA UTILITY FGO SURVEY: THIRD CUAHTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAMF
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - KW
KANSAS CITY POWER
LA CYGNE
1
LA Cf&NE
KANSAS
871. C
P20.0
"74.0
LIGHT
DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 7
AVERAGE CHLORIDE CONTENT - 7.
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
COAL
SUBBITUMINOUS
21913.
24.36
8.60
5.39
.03
( 9421 BTU/LB)
WET SCRUBBING
LIMESTONE
8ABCOCK S
NEW
2.7
2/73
6/73
80.00
99.50
.6
WILCOX
** MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
72.3
( 1148 6PM)
** DISPOSAL
TYPE
UNL1NED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION
r REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
2/79
3/79
A
B
C
0
E
T
G
H
SYSTEM
A
B
C
D
E
F
G
H
SYSTEM
95.0
94.6
92.6
93.5
95.1
94.3
94.1
93.8
94.1
96.1
96.0
93.2
95.6
96.5
94.8
672
342
95,
93,
95,
744
314
** PRObLEMS/SOLUTIONS/CCMMENTS
START DATE 2/79 END DATE 3/79
NO MAJOR FED SYSTEM PROBLEMS WERE REPORTED BY THE UTILITY FOR FEBRUARY OR
MARCH*
72
-------
TPA UTILITY FGD SURVEY: THIRD QUARTER 1979
KANSAS CITY POWER t LIGHT: LA CYGNE 1 (CONT.)
PER FORMANCE DATA
PERIOD MODULE AVAILABILITY OPER Afi 1L ] T Y RELIABILITY UTILIZATION '/ REfOVAL PER BOILER FGD CAP-
SOt PART. HOURS HOURS HOURS FACTOR
START DATE 2/79 END DATE 1/79
THE UTILITY HAS REPORTED THAT MANY TUBE LEAKS AND CYCLONE LEAKS WERE
EXPERIENCED WITH THE BOILER.
4/79 A 95.5
B 95.7
C 94.4
D 91 .4
E 95.5
F 96.2
G 95.9
H 95.7
SYSTEM 95.0 72C 638
5/79 A 96.5
B 96.3
C 96.7
D 95.3
E 95.4
F 95.7
G 96.3
H 95.5
SYSTEM 96.0 744 476
** PROBLEMS/SOLUTIONS/CCMMENTS
START DATE 5/79 END DATE 5/7"
THE UTILITY REPORTED THAT NO MAJOR FGD PROBLEMS HAD OCCURRED.
6/79 SYSTEM 720 C
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 6/79
THE UNIT WAS REMOVED FROM SERVICE THE LATTER PART OF MAY FOR SCHEDULED
BOILER OVERHAUL AND REMAINED OUT OF SERVICE THROUGH JUNE.
7/79 SYSTEM 744 0 0
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 7/79
THE TURBINE WAS OVERHAULED DURING JULY. DUPING THE OUTAGE SOME MINOR
MAINTENANCE WAS PERFORMED ON THE SCRUBBING SYSTEM.
8/79 A 86.8
B 95.9
C 96.3
D 96.3
E 95.9
F 96.2
6 88.5
H 96.9
SYSTEM 94.1 744 2?1
9/79
A
8
C
D
E
F
G
H
SYSTEM
96.0
96.1
95.6
94.3
96.7
96.1
96.0
96.9
96.0
7JQ
-------
EPA UTILITY F&D SURVEY: THIRD CUARTIR
KANSAS CITY POWER f. LIGHT: LA C Yt >if 1 (CCNT.)
PtRFORHANCE DATA
PERIOD MODULE AVAILABILITY OPEPAF-U1TY RELIABILITY UTILIZATION X R.EPIOVAL PER BOILER FGD CAP.
SG2 PART. HOURS HOURS HOURS FACTOR
«* PKOL'LEMS/SOLUTI ONS/COMKENTS
START DATE g/79 END BATE 9/7'
THE FGD UNITS OPERATED WITH NO MAJOR PROBLEMS AND ONLY REGULAR MAINTENANCE
WAS PERFORMED DURING AUGUST AND SEPTEMBER.
-------
PPA UTILITY FGb SURVEY: THIRD QUARTFR 1979
DFSIGN AMD PERFORMANCE
SECTION :
DATA FOR
OPERATIONAL FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
&RCSS UNIT GENERATING CAPACITY - !*W
NET UNIT GENERATING CAPACITY W/FO.D - MW
EOUIVALFNT SCRUBBED CAPACITY - MW
** FUEL DATA
FULL TYPt
fUEL GRADE
AVERAGE HEAT CONTENT - J/C
AVERAGE ASH COMTENT - I
AVLRAGE MOISTURE CONTENT - 7,
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - %
KANSAS POWER f» LIGHT
JEFFREY
1
WAHEGO
KANSAS
720.0
68C.O
54C.O
COAL
1P899.
5.80
28.CO
.32
.01
( 3125 OTU/LQ)
*« 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 - *
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
- 5.
JET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
NEW
8/78
* * / * *
8C.OO
99.00
20.C
1.0
«* WATER LOOP
TYPF
FRESH MAKE-UP WATER - LlTtR/S
** TREATMENT
TYPE
CLOSED
NONPROPRIfcTARY
C 557 GPM)
** DISPOSAL
TYPF
POND
p£B fORMANCE DATA
PERIOD MODULE AVAILABILITY CPERABILITY RELIAEMLITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
** PRObL£MS/SOLUTIONS/CCMMENTS
672
744
720
744
.C
.0
START DATE 4/79 END DATE 5/79
THE BOILER HAS SHUT DOWN FOR WARRANTY INSPECTION ON APRIL 1 AND REMAINED
OUT OF SERVICE DURING MAY.
6/79 SYSTEM
** PROoLEMS/SOLUTIONS/CCMMENTS
720
START DATE 6/79 IND DATE 6/79
THE UTILITY REPORTED THAT THE UNIT RETURNED TO SERVICE THE FIRST *EEK Of
JUNE AND HAS SUFFERED NO OPERATIONAL DIFFICULTIES SINCE RESTART.
SYSTEM 744
75
-------
EPA UTILITY FGD SURVEY: THIRD QUARTIR 1979
KANSAS POtaER & LIGHT: JEFFREY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEPAB1LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
8/79 SYSTEM 744
9/79 SYSTEM 720
** PR08LEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 9/79
OPERATIONS HERE NOT UNUSUAL THROUGH JULY AND AUGUST. THE UN IT PASSED THE
COMPLIANCE TEST DURING THE JUNE-JULY PERIOD. THE UNIT WILL SHUT DOWN
IN MID-SEPTEMBER FOR THE NORMAL 2 WEEK INSPECTION AND MAINTENANCE OUTAGE.
THE UNIT IS EXPECTED BACK ON LINE ON OCTOBER 1.
76
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 2
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mk.
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - Mfc
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 7!
AVERAGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
** FGD SYSTEM
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
PART1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - 2
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
KANSAS POWTR
LAWRENCE
4
LAWRENCE
KANSAS
125. C
115.0
125.0
COAL
LIGHT
( 1CODO BTU/LB)
232tO.
9.80
17.00
.55
,01
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
1/76
* / * *
73.00
9P.90
.0
CLOSED
FORCED OXIDATION
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM
744
** PROBLEMS/SOLUTIONS/COMMENTS
4/79 SYSTEM
5/79 SYSTEM
6/79 SYSTEM
START DATE 2/79 END DATE 3/79
UM1T 4 EXPERIENCED A MOTOR FAILURE ON AN 1.0. FAN DURING THE FEBRUARY-
MARCH PERIOD.
72G
744
720
«* PROBLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT THE SYSTEM RAN WELL. THE ONLY FGD SYSTEM RELATED
OUTAGES WERE DUE TOA MIXER FAILURE AND GENERAL MAINTENANCE.
744
744
7/79 SYSTEM
8/79 SYSTEM
77
-------
EPA UTILITY FuD SURVEY: THIRD GljARTLR 1979
KANSAS PO-FR o LIGHT: LAWRENCE A (CCNT.)
ptR FQRHANCE DATA
PERIOD MODULE AVAILABILITY OPEPAPH1TY RELIAPILITY UTILIZATION X REMOVAL PER BOILER fGO CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
9/79 SYSTtM 730
*• PROBLEMS/SOLUTI ONS/COMMENTS
START DATE 7/79 END DATE 9/79
DURING THE THIRD QUARTER AN OUTAGE WAS CAUSED 8V MIXER MOTOR AND OTHER
MIXER RELATED PROBLEMS. DURING THE OUTAGE MAINTENANCE WAS DONE ON THE
BOILER AND SCRUBBERS AND REPAIR WORK WAS DONE ON THE MIXERS.
START DATE 7/71? [NO DATE 9/79
THE UNIT WAS OPERATED AT HALF LOAD DURING THE LAST UEEK OF SEPTEMBER AND
WAS SHUT DC.rfN COMPLETELY IN EARLY OCTOBER FOR THE ANNUAL FALL OUTAGE.
78
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUKbER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - (U
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 - %
AVERAGE MOISTURE CONTENT - ?
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DAT E
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE 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
KANSAS POWER & LIGHT
LAURENCE
5
LAWRENCE
KANSAS
420.0
400.0
420.0
( 10000 BTU/LB)
COAL
23260.
9.80
12.00
.55
.03
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
11/71
* * /* *
52.00
% 98.90
.0
.0
CLOSED
(***** GPM)
FORCED OXIDATION
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 1 REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
672
744
720
744
START DATE 5/79 END DATE 5/79
THE UNIT WAS BROUGHT DOWN TO 1/2 CAPACITY FOR A SCHEDULED 3 WEEK
OUTAGE TO REBUILD AN AIR PREHEATER FAN MOTOR.
6/79 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
START DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT THE SYSTEM RAN WELL. THE ONLY FGD SYSTEM RELATED
OUTAGES WERE DUE TO MIXER FAILURE AND GENERAL MAINTENANCE.
7/79 SYSTEM
79
-------
EPA UTILITY FGD SURVEY: THIRD OUARTER 1979
KANSAS POWER & LIGHT: LAWRENCE 5
-------
EPA UTILITY fGD SURVEY: THIRC QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
(OKPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGO - MK
EQUIVALENT SCRUBBED CAPACITY - MW
• « FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 5!
A it r D Af C fUinDTHF C flW T C liiT — V
AV t K no t LMLU K 1 U t v UN I t Pi I A
** F£0 SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - 2
INITIAL START-UP DATE:
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY - '/,
ABSORBER SPARE CAPACITY INDEX - i
ABSORBER SPARE COMPONENTS INDEX
KENTUCKY UTILITIES
GREEN RIVtR
1-~
CENTRAL CITY
KENTUCKY
64. C
60.0
64.0
COAL
BITUMINOUS
25586. < 11000 BTU/LB)
1?.40
12. 1C
4.00
WET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
3.1
9/75
6/76
60.00
99.50
.0
.0
»* WATER LOOP
TYPE
fRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
CLOSED
4.7 ( 75 GPM)
LINED POND
PER FORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM .0
** PR06LEMS/SOLUT1QNS/COMHENTS
.0
.0
672
.0
START DATE 1/79 CND DATE 2/79
THE PROBLEMS IN JANUARY AND FEBRUARY WERE A RESULT OF FREEZING WEATHtP.
3/79 SYSTEM 11.2 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
100.0
11.2
744
83
83
START DATE 3/79 END DATE 4/79
THE LOW OPERATIONAL HOURS FOR MARCH AND APRIL WERE DUE TO RECYCLE PUfP
PROBLEMS.
*/79 SYSTEM 18.2 100.0
5/79 SYSTEM
** PROfcLEMS/SOLUTIONS/CCKMENTS
100.0
18.2
.0
72G 131
744 0
131
C
START DATE 5/79 END DATE 5/79
THE 130ILER .IAS TAKEN DOWN IN I"AY FOR REPAIRS THAT ARE PROJECTED TO LAST
THROUGH THE END OF SEPTEMBER.
SYSTEM
10C.O
72C
.0
-------
EPA UTILITY FLD SURVEY: THIRD OUARTIR i
-------
LPA UTILITY FGD SURVEY: TMIR[> QUARTER 1979
SECTION 3
DESIGN AND PERFORKANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT HAKE
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - KU
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - %
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 WATER - LITER/S
LOUISVILLE GAS & ELECTRIC
CANE RUN
4
LOUISVILLE
KENTUCKY
188.0
175.0
188.0
COAL
BITUMINOUS
26749.
17-10
9.00
3.75
.04
MET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
1.6
8/76
9/77
85.00
99.00
.0
.0
C 11500 BTU/LD)
OPEN
6.3
< 100 GPB)
** DISPOSAL
TYPE LINED POND
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
2/79 SYSTEM 100.0 .0
3/79 SYSTEM 100.0 .C
4/79 SYSTEM 100.0 .0
X REMOVAL PER
S02 PART. HOURS
672
744
720
BOILER
HOURS
0
0
0
FGD CAP.
HOURS FACTOR
0 .0
0 .0
0 .0
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/79
THE UNIT DID NOT OPERATE DURING THESE MONTHS BECAUSE THE BOILER WAS STILL
DOUN WITH TUBE LEAKS.
5/79 SYSTEM 100.0
6/79 SYSTEM 46.2
** PROBLEMS/SOLUTIONS/COMMENTS
.0
17.1
7906 0
720 266
0
123
.0
START DATE 5/79 END DATE 6/79
THE UMT REGAINED DOKN DURING MAY FOR CONTINUED REPAIRS AT THE BOILER.
THE UNIT WAS PLACED BACK IN SERVICE IN JUNE.
7/79 SYSTEW
£/79 SYSTEM
99.0
89.0
93.0
69.0
744 701
744 744
692
664
S3
-------
EP* UTILITY FGD SURVEY: THIRD QUARTER 1979
LOUISVILLE GAS £ ELECTRIC: CANE RUN 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERARILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/79 SYSTEM .0 .0 720 168 C
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 9/79
THE. ONLY MAJOR PROBLEMS OCCURRED DURING SEPTEMBER. TUBE FAILURES WERE
ENCOUNTERED CAUSING THE BOILER OUTAGE AND MECHANICAL FAILURE UITH THE
DAMPER GATES CAUSED THE SCRUBBED DOWNTIME.
-------
tPA UTILITY FCD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOP OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATt
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - HW
EQUIVALENT SCRUBBED CAPACITY - MU
** FUEL DATA
FUEL TYPE
FUEL SHADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - %
AVERAGE MOISTURE CONTENT - f,
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
502 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
LOUISVILLE GAS t, ELECTRIC
CANE RUN
5
LOUISVILLE
KENTUCKY
190.0
1SO.C
190.0
f 11500 BTU/LB)
COAL
BITUMINOUS
26749.
17.10
9.DC
3.75
.04
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
1.6
12/77
5/79
85.00
99.00
.0
.0
«* HATER LOOP
TYPE
FRESH KAKE-UP HATER - L1TER/S
OPEN
<***««
** TREATMENT
TYPE
** DISPOSAL
TYPE
P07-0-TEC
LINED POND
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION % REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 70.6
** P.iOBLEMS/SOLUTIONS/COHMENTS
50.1
672 477
337
START DATE 2/79 END DATE 2/79
DURING FEBRUARY FREEZING CAUSED PROBLEMS WITH LIME DELIVERY.
3/79 SYSTEM 71.8
4/79 SYSTEM 99.2
*» PRObLEMS/SOLUTIONS/COWENTS
57.5
49.6
744 596
720 360
42?
357
START DATE 2/79 END DATE 4/79
SOME PROBLEMS WERE EXPERIENCED WITH DAMPERS AND THERE WERE PUMP FAILLRES.
5/79 SYSTEM
6/79 SYSTEM
84.7
77. r;
49.1
53.2
744 433
720 544
365
419
-------
EPA UTILITY FGD SURVEY: THIRD OUARTLR 1979
LOUISVILLE GAS 4. ELECTP1C: CANE RUN 5 (CO*JT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY GPERAPIL1TY RELIABILITY UTILIZATION * REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROoLfcMS/SOLUTlONS/COWMENTS
START DATE 5/79 tNO DATE 6/79
THt ONLY PKOBLEWS REPORTED BY THE UTILITY WERE SPRAY PUMP PACKING FAILURES
AND WELDING FAILURES ON THE REHEATER.
7/79 SYSTEM 72.n 56.C 744 583 420
6/7Q SYSTEM 88.0 73.0 744 613 540
9/79 SYSTEM £4.C 54.0 720 469 392
-. PROLiLEMS/SOLUTlONS/COMMENTS
START DATE 7/79 END DATE 9/79
THE WELDING PROBLEMS WITH THE REHEATER MERE ENCOUNTERED IN JULY AND
SEPTEMBER. THE FAILURES ARE CONTINUING AND ARE EXPECTED TO BE RESOLVED
BY THIS WINTER.
-------
EPA UTILITY FtD SURVEY: THIRD 6UARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATt
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NE/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - Kk
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGC - Wbi
EQUIVALENT SCRUBBED CAPACITY - WW
LOUISVILLE
CAME RUN
6
LOUISVILLE
KENTUCKY
A
50.
516.
992.0
288.0
?69.0
272.0
288.0
GAS £ ELECTRIC
< .116 LB/MMBTU)
< 1.200 LB/MMBTU)
,
•* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM bOlLEP FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GSAOE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - eTU/LB
AVERAGE ASH CONTENT - %
RANGE ASH CONTENT - 5!
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - ?.
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - K
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
0/69
502.57
148.9
158.
4.9
COAL
BITUMINOUS
25586.
17.10
15.5-24.5
9.00
8.0-10.75
4.SO
3.5-6.3
.04
3.03-0.06
(1065000 ACFM)
(. 300 F)
( 518 FT)
< 16.0 FT)
< 11000 BTU/LB)
10,400-11,900
ESP
NUMPER 1
TYPE COLD SIDE
PARTICULATE DESIGN REMOVAL EFFICIENCY - * 99.4
FLUE GAS CAPACITY - CU.M/S 502.6
FLUE GAS TEMPERATURE - C 14*.9
11065000 ACFH)
< 3CO F)
FCD SYSTEM
SALEABLE PRODUCT/THROWAHAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRW
DEVELOPMENT LEVEL
NEW/RETROFIT
S02 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
CONTRACT AWARDED
ABSORBER SPARE CAPACITY INDEX - %
ABSORBER SPARE COMPONENT INDEX
THROWAWAY PRODUCT
WET SCRUBBING
DUAL ALKALI
AOL/COMBUSTION EQUIP ASSOCIATE
FLUOR - PIONEER
DEMONSTRATION
RETROFIT
95.00
4/79
10/76
20.0
.3
ABSORBER
NUMPER
TYPE
INITIAL START UP
SUPPLIER
NUMPER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINEk MATERIAL
INTERNAL MATERIAL
bOILEP LOAD/ABSORBER - %
GAS FLOW - CU.K/S
GAS TEMPERATURE - C
TRAY TOWER
12/78
COMBUSTION EQUIP ASSOCIATES
2
32 DIA X 45
A2S3 CARBON STEEL
FLAKE REINFORCED POLYESTER
317L SS, 316 SS, FRP PIPING
60.0
251.29 t 532500 ACFM)
8C.O < 176 F)
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
LOUISVILLE GAS & ELECTRIC: CANE RUN 6 (CONT.)
L/& RATIO - L/CU.M
PRESSURE DROP - KPA
SUPERF1CAL GAS VELOCITY - P/SEC
S02 INLET CONCENTRATION - PPM
SOZ CUTLET CONTRATION - PPK
S02 DESIGN REMOVAL EFFICIENCY - 2
** CENTRIFuGt
NUMBER
1.3
2.2
2.7
200
95.0
( lu.O GAL/1DCOACF)
( 9.0 1N-H20)
( 9.D FT/S)
** FANS
NUMBER
TYPE
CONSTRUCTION MATERIALS
SERVICE - WET/DRY
CAPACITY - CU.N/S
BOOSTER, CENTRIFUGAL
A441 CARBON STEEL
DRY
251.52 < 533000 ACFM)
•« VACUUM FILTER
NUMBER
TYPE
CONSTRUCTION MATERIAL
CAPACITY - M T/D
INLET SOLIDS - X
OUTLET SOLIDS - 1.
** MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
NUMBER OF PASSES
FREEBOARD DISTANCE - M
PRESSURE DROP - KPA
ROTARY-DRUM WITH WATER WASH
316 SS [FILTER DRUM3, FRPtBELT CLOTH3
684.8 ( 755 T/D)
25.0
63.0
CHEVRON
POLYPROPYLENE
HORIZONTAL
4
1.52 < 5.0 FT)
.2 ( 1.C IN-H20)
** PUMPS
SERVICE
REACTOR PUMP
RECYCLE
THICKENER HOLD TANK PUMP
LIME SLURRY
SODA ASH PUMP
THICKENER UNDERFLOW
VACUUM
NUMBER
2
4
2
2
2
2
3
TANKS
SERVICE
PRIMARY REACTION TANK
SECONDARY REACTION TANK
FEED FORWARD TANK
FILTRATE SUMP
THICKENER HOLD TANK
NUMBER
** REHEATER
NUMBER
TYPE
TEMPERATURE BOOST - C
ENERGY REQUIRED
** THICKENER
NUMBER
TYPE
CONSTRUCTION MATERIAL
DIAMETER - M
OUTLET SOLIDS - X
DIRECT COMBUSTION
27.8 ( 50 F)
25632000 eTU/HR FOR FLUE GAS PLUS 1282000 BTU/HR
1
FLAT BOTTOM
CONCRETE SHELL, CARBON STEEL INTERIOR, FLAKE &EI
3S.1 (125 FT)
25.0
** HATER LOOP
TYPE
EVAPORATOR WATER LOSS - LITER/S
** TREATMENT
CONTRACTOR
PRODUCT CHARACTERISTICS
CLOSED
17.5
1UCS
t 278 GPM)
2CASOI-H2C C?5%:,CAS04 C10-15X3, CAC03 [5-10X3,N
88
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
LOUISVILLE GAS & ELECTRIC: CANE RUN 6 (CONT.)
** DISPOSAL
NATURE FINAL
TYPE LINED POND
LOCATION ON-SITE
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION 2 REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79 SYSTEM 43.3 37.9 t>2 475 ?37
** PROBLEMS/SOLUTIONS/COKMENTS
START DATE 4/79 END DATE 4/79
THIS UNIT STARTED OPERATING ON APRIL 4, 1979. COMPLIANCE TESTING IS
SCHEDULED FOR THE WEEK OF JUNE 3.
5/79 SYSTEM 21.5 14.7 744 506 109
6/79 SYSTEM 12.3 10.3 720 601 74
** PR06LEMS/SOLUTIONS/COMMENTS
START DATE 6/75 END DATE 6/79
THE UTILITY REPORTED THAT THE SYSTEM IS STILL CONSIDERED IN START-UP AND
THAT NO UNUSUAL PROCESS PROBLEMS HAVE BEEN ENCOUNTERED. HOWEVER THE SYS-
TEM IS NOW OUT OF SERVICE DUE TO THE COMPLETE FAILURE OF THE HIST ELIM-
INATORS. IT IS EXPECTED TO BE DOWN FOR A MONTH.
7/79 SYSTEM .0 .0 744 529 C
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 7/79
THE UNIT DID NOT OPERATE IN JULY AS PROCEDURES CONTINUED TO REPLACED THE
HIST ELIMINATORS.
8/79 STSTEH 7.0 7.0 744 683 51
9/79 SYSTEM 60.0 44.0 72C 531 317
** PROBLEHS/SOLUTIONS/COMMENTS
START DATE 8/79 END DATE 9/79
DURING AUGUST AND SEPTEMBER THE UNIT DOWNTIME WAS DUE TO THE COMPLETE
FAILURE OF FIVE PUdPS. THE PUMP PROBLEMS WERE THE LOSS OF THE IMPELLERS
OFF OF THE SHAFTS.
89
-------
EPA UTILITY F&D SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - *w
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBbED CAPACITY - Ku
«* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVEPAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
*« FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - *
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICIPATE. DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITFR/S
•* TREATMENT
TYPE
•* DISPOSAL
TYPE
LOUISVILLE GAS 8. ELECTRIC
MILL CPEEK
^
LOUISVILLE
KENTUCKY
442.0
420.0
442.0
COAL
BITUMINOUS
26749.
11.50
3.75
WET SCRUBBING
LIME
AMERICAN AIR FILTER
NEW
1.6
8/78
3/79
85.CO
99.00
C 11500 BTU/LBJ
OPEN
9.4
< 150 6P«>
FLYASH/LIME STABILIZED
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER f6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 18.0
3/79 SYSTEM 53.1
•* PRObLEMS/SOLimONS/COMMENTS
17.4
52.4
672 651
74* 735
117
390
START DATE 3/79 END DATE 3/79
COMPLIANCE TESTING HAS PERFORMED DURING MARCH AND THE UNIT WAS DECLARED
COMMERCIAL.
4/79 SYSTEM 63.6
** PROBLEMS/SOLUTIONS/COWSENTS
44.4
720 503
32C
START DATE 2/79 END DATE 4/79
THE ONLY PROBLEMS REPORTED WERE WITH DAMPERS AND PUHP FAILURES.
5/79 SYSTEM
6/79 SYSTEM
97.8
51 .«>
64.7
47.9
744 492
720 665
481
345
-------
fPA UTILITY FGD SURVEY: THIRD QUARTER 1979
LOUISVILLE GAS £, ELECTRIC: WILL CREEK 3
-------
EPA UTILITY fGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY V/FGD - Mtt
EOUIVALENT SCRUBBED CAPACITY - MW
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN
6
LOUISVILLE
KENTUCKY
72.0
67.0
72.0
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - 7.
COAL
** ** **
26749.
11.50
2.50
t 11500 BTU/LB)
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - 3C
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.8
4/73
** /**
90.00
99.10
.0
.0
** WATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
CLOSED
3.1 C SC GPM)
•* TREATMENT
TYPE LIME STABILIZED
** DISPOSAL
TYPE POND
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
2/79 SYSTEM 100.0 .0
3/79 SYSTEM 100.0 ,C
4/79 SYSTEM 100.0 .0
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
672 0 0 .0
744 < 0 C .0
72C 0 0 .C
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/79
THE UNIT WAS NOT OPERATED DURING THESE MONTHS BECAUSE OF LACK OF DEMAND.
5/79 SYSTEM 100.Q
6/79 SYSTEM 100.0
** PKOBLEMS/SOLUTIONS/COMMENTS
.0
744
720
.C
.C
START DATE 5/79 ttvD DATE 6/79
THE UTILITY REPORTED THAT THE UNIT DID NOT OPERATE DURING MAY OR JUNE DUE
TO INSUFFICIENT DEMAND.
7/79 SYSTEM
744
19
92
-------
F.PA UTILITY FGi> SURVEY: THIRD QUARTER 1979
LOUISVILLE &AS Is. ELECTRIC: PADDY'S RUN 6 (CONT.)
------------------------------------------ PER (ORhANCE DATA -----------------------------------
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D "CAP"
SO? PART. HOURS HOURS HOURS FACTOR
8/79 SYSTEM 45 .? U.n ?4A 21g „
9/79 SYSTEM .C .C 720 3* 0
PROOLEMS/SOLUTIONS/COKMENTS
**
START DATE 7/79 END DATE 9/79
NO PROBLEMS i»ERE REPORTED WITH RESPECT TO OPERATION AT THIS UNIT DURING THE
THIRD CHARTER 1979.
-------
EPA UTILITY FL.D SURVEY: THIRD C'L'ARTtR 1979
SECTION ?
'.D PESFORhANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NANE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - "-'U
NET UNIT GENERATING CAPACITY W/F GD -
EQUIVALENT SCRUBBED CAPACITY - KW
MNNKOTA POfcER
MILTON R. YOUNG
2
CENT E&
NORTH DAKOTA
AAO.O
402.0
405. C
COOPERATIVE
FUEL DATA
FUEL TYPt.
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - i
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - t
COAL
LIGNITE
6.50
38.00
.70
< 6500 BTU/LB)
*• FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL STAKT-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
WET SCRUBBING
LIME/ALKALINE FLYASH
ADL/COKBUSTlON EQUIP ASSOCIATE
NEW
1.6
9/77
6/78
85.00
99.60
.0
.0
WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
OPEN
44.1
( 7.00 GPM)
** DISPOSAL
TYPE
MINEFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAP1LITY RELIABILITY UTILIZATION
7. REMOVAL PER BOILER F6 D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/79
A
b
SYSTEM
4.6
37.7
21.1
5.1
28.4
16.8
4.6
25.7
15.1
1488 1345
225
P ROLL EMS/SOLUTIONS/COMMENTS
START DATE 12/7?. END DATE 1/79
THE APOVE FIGURES ARE FOR THE PERIOD DECEMBER THROUGH JANUARY.
START DATE 1/79 END DATE 1/79
THE UTILITY REPORTED THAT THE A-TOWER WAS OUT OF SERVICE FOR A PERIOD IN
JANUARY DUE TO BROKEN INLET ISOLATION DAMPER CHAINS.
START DATE 1/79
END DATE 1/79
A-TOUER WAS OUT OF SERVICE TO REPAIR A BOOSTER FAN SERVO MECHANISM.
START DATE 12/76 END DATE 12/7?
THi B-TOWER WAS OUT OF SERVICE DURING DECEMBER DUE TO PLUGGING Of THE
THICKENER LNDERFLOU f>r RUBBER LINING. THE THICKENER WAS PUMPED OUT AND
REPAIRED.
START DATE 12/7f END DATC 1/79
THE B-TOWEF- In A S OUT OF SERVICE THROUGH JANUARY DUE TO A FAN MOTOR.
2/7C SYSTEM 672
94
-------
tPA UTILITY FGD SURVEY: THIRD QUARTER 1-579
M1NNKOTA POfcER COOPERATIVE: MILTON F. . YOUNG I (CONT.)
PER FORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAHIL1TY RELIABILITY UTILIZATION 5! REMOVAL PER B01LE R~~F6 D""C A™
SO? PART. HOURS HOURS HOURS FACTOR
3/79
A
it
SYSTEM
«« PK06LEMS/SOLUTIONS/CCWENTS
START DATE 2/79
1416
END DATE 3/79
THE ABOVE FIGURES ARE fOR THE PERIOD FEBRUARY THROUGH MARCH.
START DATE 2/79
END DATE 3/79
A BOOSTER FAN MOTOR FIRE WAS EXPERIENCED-
START DATE 2/79
END DATE 3/79
4/7? SYSTEM
5/79 A
b
SYSTEM
3.C
57.1
30.0
3.2
61 .6
32.4
6/79
7/79
HOLES IN THE ABSORBER TQWER WERE REPAIRED.
3.0
57.1
30.0
720
1464 1358
440
«* PRObLEMS/SOLUTlONS/COKMENTS
START DATE 4/79 END DATE 5/79
THE ADOVE FIGURES ARE FOR THE PERIOD APRIL THROUGH WAY.
A
El
SYSTEM
17.2
36.3
26.7
17.2
36.3
26.7
17.2
36.3
26.7
720 720
192
** PROBLEMS/SOLUTIONS/COKMENTS
START DATE 6/79 END DATE 6/79
THE A-TOWER WAS DOWN FOR REPAIR TO THE FLAKE LINING.
START DATE 6/79 END DATE 6/79
A-TOWER TRAY RECYCLE DISTRIBUTION HEADER WAS CLEANED.
START DATE 6/79 END DATE 6/79
THE SYSTEM WAS FORCED OUT OF SERVICE WHEN BOILER PROBLEMS CAUSED AN EX-
CESSIVE AMOUNT OF HEAVY PARTICLES TO ENTER THE FGD SYSTEM RESULTING IN THE
PLUGGING OF SEVERAL LINES AND STOPPING THE THICKENER RAKE.
START DATE 6/79 END DATE 6/79
THE A-TOWEfi WAS OUT OF SERVICE DUE TO PROBLEMS WITH THE WATER BALANCE AND E
THE VACUUM FILTERS AS WELL AS TO UNPLUG THE ABSORBER BLEED LINE. LIME
WAS USED FOR SEVERAL DAYS TO EASE THE HIGH SOLIDS PROBLEM.
A
6
SYSTEM
44.5
.0
44.0
44.5 44.5
.G .0
44.0 44.0 44.0 744 744 331
** PROfcLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 7/79
THE UTILITY HAS REPORTED THAT THE TRAY RECYCLE VALVE AND THE ABSORBER
TRAIN VALVE FAILED DURING SEPTEMBER.
START DATE ?/79 END DATE 7/79
THE UTILITY REPORTED PROBLEMS WITH PLUGGING IN THE MIST ELIMINATORS,
THE THICKEr.Ef! AND IN THE ABSORBER FEED LINE.
START DATE 7/79 [N0 DATE 7/79
THE UNIT EXPERIENCED A BOOSTER FAN TRIP.
START DATE 7/79
[HO DATE 7/79
PROBLEMS WITH THE VACUUM FILTERS AND THE SEAL WATER PUMP WERE ENCOUNTERED.
START DATE 7/79
END DATE 7/79
-------
EPA UTILITY FGD SURVEY: THIRD CHARTER 1979
MINNKOTA POWER COOPERATIVE: MILTON (.. YOUNG 2 (CONT.)
PERIOD
MODULE
AVAILABILITY
OPERAB1L1TV
THE ABSORBER
8/79
A
B
SYSTEM
28.8
10.6
39.0
28.8
10.6
29. 0
PtK HJRPIAI
RELIABILITY
AGITATOR WAS
39.0
MLh DAIA
UTILIZATION X REMOVAL PER
S02 PART. HOURS
REPLACED
28.8
10.6
39 . :.
DURING
THE THIRD
BOILER
HOURS
FGD
HOURS
CAP.
FACTOR
QUARTER.
744
744
293
.» PROfaLEMS/SOLUTlONS/COMMENTS
START DATE 8/79 END DATE P/79
DURING AUGUST HIGH VIBRATIONS AND BEARING TEMPERATURE IN THE BOOSTER FAN
WERE ENCOUNTERED CAUSING SOME DOWN TIME.
START DATE 8/79 END DATE 8/79
THE INABILITY TO ADD ALKALIi FLYASH OR LIME TO THE SYSTEM CAUSED SOWE
OPERATIONAL PROBLEMS.
START DATE 8/79 END DATE 8/79
DURING AUGUST THE THICKENER RAKE WAS BURIED IN THE SLUDGE AND ALL OF THE
SLUDGE HAD TO BE REMOVED BY MINING IT FROM THE TOP.
START DATE 8/79 END DATE 8/79
PLUGGING OF THE FLYASH TANK AND THE LIME SLURRY FEED LINE CAUSED SOME
OUTAGE TIME DURING AUGUST.
START DATE 8/79 END DATE 8/79
DUE TO A LACK OF LIME THE SYSTEM HAD TO GO OFF LINE.
START DATE 8/79 END DATE 8/79
THE HOLES IN THE SIDES OF THE ABSORBER TOWER HAD TO BE REPAIRED CAUSING
AN OUTAGE.
9/79 A
B
SYSTEM
21.4
1.2
23.0
21 .4
1 .2
23. C
23.0
21.4
1.2
23.C
720
717
163
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 9/79 END DATE 9/79
DURING SEPTEMBER THE A-SIDE WAS DOWN DUE TO HEAVY SOLIDS IN THE THICKENER
AND CLARIFIER. HIGH VIBRATIONS WERE EXPERIENCED WITH THE BOOSTER FAN.
START DATE 9/79 END DATE 9/79
THE B-SIDE REMAINED OUT OF SERVICE DUE TO PROBLEMS WITH THE THICKENEh AND
CLARIFIER.
96
-------
tPA UT1LITT FCD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORtoANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY MAKE
PLAN! NSME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mm
NET UNIT GENERATING CAPACITY W/FGD - KW
EGUIVALENT SCRUBBED CAPACITY - MW
«* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE K01STURE CONTENT - 7.
AVERAGE SULFUR 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 - X
PARTKULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
8843 BTU/LB)
COLSTR1P
1
COLSTRIP
MONTANA
760.0
733.0
360.0
COAL
SUBBITUM1NOUS
20569.
P.60
23.90
.77
.01
WET SCRUBBING
LIKE/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
NEW
7.3
9/75
11/75
6 C . 0 0
99.50
20.C
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
23.3
{ 370 GPM)
** DISPOSAL
TYPE
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SC2 PART. HOURS HOURS HOURS FACTOR
12/78
1/79
2/79
3/79
4/79
S/79
6/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
96.7
97.6
90.3
97.3
98.9 88.4
8P.7
95.2
744
744
672
744
80.2 720 597
744
720
PRODLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END D-ATE 6/79
DURING MAY AND JUNE THE UNIT WAS PE1NG OVERHAULED. THE AVAILABILITY FOR
THESE PERIODS IS BASED UPON OPERATIONS BEFORE AND AFTER OVERHAUL.
7/79 SYSTEM
8/79 SYSTEM
9/79 SYSTEM
744
744
720
-------
EF» UTILITY FtD SURVEY: THIRD QUARTER 1979
MONTANA POWER: COLSTR1P 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAP1L1TY RELIABILITY UTILIZATION % REMOVAL PER BOILER FGD CUP.
S02 PART. HOURS HOURS HOURS F»CTCB
*• PkObLEMS/SOLUTIONS/COPMENTS
START DATE 7 IT> END DATE 9/7»
Nf! INFORMATION WAS AVAILABLE FROM THE UTILITY FOR THE THIRD QUARTER 1979.
98
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - r«W
NET UNIT GENERATING CAPACITY W/FGO - NW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPfc
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - Z
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - %
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
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
" DISPOSAL
TYPF
< E843 BTU/LB)
MONTANA POWER
COLSTRIP
2
COLSTRIP
MONTANA
360.0
332.0
.360.C
COAL
SUPB1TUMINOUS
20569.
8.60
23.90
.77
.01
WET SCRUBBING
LIME/ALKALINE FLYASH
AOL/COMBUSTION EQUIP ASSOCIATE
NEW
3.3
5/76
10/76
60.00
99.50
20.0
.5
CLOSED
23.3
POND
< 370 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP-
S02 PART. HOURS HOURS HOURS FACTOR
12/78
1/79
2/79
3/79
4/79
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
91 .2
94.3
98.3
94.3
100.0
744
744
672
744
720
** PROBLEMS/SOLUTIONS/COMMENTS
START BATE 4/79 END DATE 4/7
-------
EP* UTILITY FoD SURVEY: THIRD QUARTER 1979
MONTANA POWER: COLSTRIP 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILUY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PRObLEMS/SOLUTlONS/COMMENTS
START DATE 7/79 END DATE 9/79
NO INFORMATION WAS AVAILABLE FROM THE UTILITY FOR THE THIRD QUARTER 1C79.
100
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PE RF ORIT ANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME NEVADA POyER
PLANT NAME REID GARDNER
UNIT NUMBER 1
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mh
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/C
AVERAGE ASH CONTENT - !t
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - ';.
AVERAGE CHLORIDE CONTENT - %
*« FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - f, *»***.*
INITIAL START-UP DATE 4/74
COMMERCIAL START-UP DATE «*/**
S02 DESIGN REMOVAL EFFICIENCY - X 90.00
PARTICULATE DESIGN REMOVAL EFFICIENCY - X 97.00
ABSORBER SPARE CAPACITY INDEX - 't. .0
ABSORBER SPARE COMPONENTS INDEX .0
( 12450 BTU/LB)
NEVADA
125.0
11C.D
135. C
COAL
BITUMINOUS
28959.
£.00
.50
WET SCRUBBING
SODIUM CARBONATE
AOL/COMBUSTION EQUIP ASSOCIATE
RETROFIT
** HATER LOOP
TYPE
FRESH MAKE-UP WATER - L1TER/S
** DISPOSAL
TYPE
CLOSED
5.8
POND
( 155 GPM>
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAG1L1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM 97.9 96.5
** PROBLEHS/SOLUTIONS/COBMENTS
96.5
78.3
744 6C3 582
START DATE 3/79 END DATE 3/79
THE FGD SYSTEM WAS OFF TO UNPLUG VENTURI NOZZLES AND TO CLEAN SENSING
LINES. THE DOWNTIME yAS ABOUT 15 HOURS.
START DATE 3/79 END DATE 3/79
THE FGD SYSTEM WAS OFF FOR ABOUT 146 HOURS FOR REPAIR OF BOILER TUBE
LEAKS.
4/79 SYSTEM 100.0 98.7
** PROELEMS/SOLUTIONS/CCMMEMTS
98.6
25.7
72C 1BB 185
START DATE 4/79 END DATE 4/70
THt tOILER AND FGD SYSTEM WERE OFF FOR APPROXIMATELY 533 HOURS FOR SCHED-
ULED MAINTENANCE.
5/79 SYSTEM 99.8
74.4
74 .4
27.5
744 275 2C4
1 01
-------
EPA UTILITY FijD SURVEY: THIRD l.UARTCR 1979
POwES: RtID GARDNER 1 (CGMT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
• •* PRObLEMS/SOLUTIONS/COWENTS
START DATE 5/79 END DATE 5/79
THL BOILER AND SCRUBBER WERE RETURNED TO SERVICE ON THE 22ND AFTER
MA INTENANCl.
START CATE 5/79 LND DATE 5/79
THE BOILER HAS FORCED OUT OF SERVICE TO REPAIR A COAL LEAK ON THE «8
BURNER LINE.
6/79 SYSTcM
97.7
95 .1
95.2
84.7
720 6*1
610
»* PROBLEMS/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
A FEW DAYS OUTAGE TIKE WAS REQUIRED TO REPAIR A BOILER TUBE LEAK.
START DATE
6/79 END DATE 6/79
OUTAGE TIMt yAS REQUIRED TO UNPLUG A VENTURI LINE.
START DATE 6/79 END DATE 6/79
TRAY SPRAY VALVES WERE REPLACED DURING JUNE.
7/79 SYSTEM
81.2
80.5
80.5
80.3
744 742
598
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 7/79
THE BOILER AND FGD SYSTEM WAS TRIPPED OFF FOR TURBINE OVERSPEEO GOVERNOR
TEST. THE DOWNTIME WAS ABOUT 7 HOURS.
START DATE 7/79
END DATE 7/79
THE SCRUBBER WAS OFF ABOUT 67 HOURS TO CLEAN THE SCRUBBER TRAYS.
START DATE 7/79 END DATE 7/79
LOST INSTRUMENT AIR TO THE SCRUBBER CONTROLS CAUSED A LOSS OF POWER TO THE
SCRUBBER AIR COMPRESSOR. THE SCRUBBER WAS OFF-LINE FOR ABOUT 74 HOURS.
8/79 SYSTEM
96.8
96.8
96.8
96. f
744
744
721
** PKObLEMS/SOLUTIONS/COWENTS
START DATE 8/79 END DATE 8/79
THE SCRUBBER WAS REMOVED FROM SERVICE TO CLEAN THE SCRUBBER PRESSURE
SENSING LINES. THE SCRUBBER WAS DOWN FOR ABOUT 11 HOURS.
START DATE
8/7<3 END DATE 8/79
THE SCRUBBER WAS DOWN AT THE END OF THE MONTH TO CLEAN THE PRESSURE
SENSING LIKE ON THE SCRUBBER. THE SCRUBBER UAS OFF-LINE FOR ABOUT 4 HOURS.
9/79 SYSTEM
10C.O
1CO.O
100.0
53.2
720 383
383
• « PROBLbMS/SOLUTI ONS/COKMENTS
START DATE 9/79 END DATE 9/7«
IN SEPTEMBER THE SCRUBBER WENT OFF WITH THE BOILER AND TURBINE FOR
SCHEDULED KAINTENANCE.
1C2
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY t,AHE
PLANT NAME
UNIT NU^bEk
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mfc
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 SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - ~
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - 5!
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 KAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
NEVADA POWER
REID GARDNER
2
KOAPA
NEVADA
125.0
110.0
135.0
COAL
BITUMINOUS
28842.
8.00
t 12400 BTU/LB)
.50
.05
WET SCRUBBING
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
RETROFIT
4/74
**/**
90.00
97.00
.0
.0
CLOSED
9.E
POND
155 GP»>
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM 97.8 96.6
** PKOSLEMS/SOLUTIONS/COMMENTS
START DATE
96.6
89.;
744 688
665
START DATE
3/79 END DATE 3/79
THE BOILER AND SCRUBBER WERE OFF FOR ABOUT TWO DAYS FOR REPAIR OF BOILER
TUBE LEAKS.
3/79 END DATE 3/79
THE BOILER TRIPPED DUE TO HIGH FURNACE PRESSURE- WHILE THE BOILER WAS
DOhN SENSIhG LINES WERE CLEANED ON THE SCRUBBER.
4/79 SYSTEM
88.8
95 .9
96.0
88.8
720 666
640
** PROf'LEMS/SOLUTIONS/COHMENTS
START DATE
4/7? END DATE 4/7S
A HIGH PRESSURE ALARM ON THE SCRUBBER DUCT TRIPPED THE SCRUBBER OFF LINE.
THE SCRUBBER PRFSSURF SENSING LINES WERE CLEANED. THIS OCCURRED TWICE
DURING THE HCNTH OF APRIL.
START DATE 4/75
END DATE 4/78
5/79 SYSTEM
99.8
*+ f I O t:«Ui'"IU-»»l*-' * n 11
A CONTROL F-OfcER FAILURE OCCURRED CAUSING A SCRUBBER TRIP WHEN THE 10 KW
GENERATOR UAS PUT BACK IN SERVICE.
744 627 624
99.4
99 .5
33.9
103
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
NEVADA POUER: REID GARDNER 2 (CON 1.)
----------------------------------------- PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
* REMOVAL PER BOILER FGD CAP.
302 PART. HOURS HOURS HOURS FACTOR
«* PROBLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 5/79
THE BOILER WAS OUT OF SERVICE FOR ABOUT 5 DAYS TO REPAIR TUBE LEAKS.
START DATE 5/79 END DATE 5/79
PRESSURE SENSING LINES ON THE SCRUBBER CONTROLS WERE CLEANED.
6/79 SYSTEM
93.2
86 .8
66.9
73.2
72 Q 607
527
«* PRObLEMS/SOLUTlONS/COMMENTS
START DATE 6/79 END DATE 6/79
THE SCRUBBER HAS FORCED OUT OF SERVICE DUE TO VENTUR1 PUMP POWER LOSS.
START DATE 6/7S END DATE 6/79
SOME OUTAGE TIME WAS REQUIRED TO REPAIR VENTURI PUMP DISCHARGE VALVES.
START DATE 6/79 END DATE 6/79
SOME BOILER OUTAGE WAS REQUIRED DURING JUN£ TO REPAIR HIGH PRESSURE HEATER
TUBE LEAKS, TO WELD A CAP ON THE HIGH PRESSURE HEATER, TO WORK ON PRIMARY
AIR FANS, AND TO REPAIR A BOILER TUBE LEAK.
START DATE 6/79 END DATE 6/79
SCRUBBER OUTAGE TIME WAS REQUIRED TO CLEAN PRESSURE SENSING LINES*
7/79 SYSTEM 86.8 90.6
** PROBLEMS/SOLUTIONS/COMMENTS
85.5
78.1
744
642
646
START DATE 7/79 END DATE 7/79
THE SCRUBBER WAS OFF AT THE START OF THE MONTH WITH A BAD VENTURI PRCBE
TEMPERATURE AND A BLOWN BOILER TUBE. THIS OUTAGE LASTED ABOUT 76 HOLRS.
START DATE 7/79 END DATE 7/79
THE BOILER AND SCRUBBER WAS OFF TO REPAIR BOILER TUBE LEAK.
START DATE 7/79 END DATE 7/79
SCRUBBER AND BOILER TRIPPED OFF FOR ABOUT 50 HOURS. THIS OUTAGE WAS CAUSED
BY LOST CONTROL AIR TO THE SCRUBBER AND POWER LOSS TO SCRUBBER A IP
COMPRESSOR.
START DATE 7/79 END DATE 7/79
THE SENSING LINES ON THE SCRUBBER WERE CLE'ANED TO PREVENT HIGH SCRUBBER
DUCT PRESSURE. THE SYSTEM WAS OFF FOR ABOUT 16 HOURS.
8/79 SYSTEM
93.2
98.9
93.2
93.1
744
701
694
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 8/79 LND DATE 8/79
THE SCRUBBER AND THE BOILER WENT DOWN FOR ABOUT 40 HOURS TO REPAIR A
BOILER TUBE LEAK.
START DATE 8/79 END DATE 8/79
THE SCRUBBER WAS OFF TO REPAIR LEAK IN VENTURI PUMP DISCHARGE BODY. THE
REPAIR TOOK ABOUT 9 HOURS.
START DATE 6/79 END DATE 8/79
HIGH PRESSLRE IN SCRUBBER DUCT CAUSED THE SCRUBBER TO GO DOWN TO CLEAN THE
SCRUBBER PRESSURE SENSING LINES.
9/79 SYSTEM
85.8
fc'J .7
82.3
66.2
720
569
477
t* PROoLEMS/SOLUTIONS/COKMENTS
START DATE 9/79 END DATE 9/70
DURING SEPTEMBER THE SCRUBBER HENT OFF LINE WITH THE BOILER TO REPAIR
BOILER TUBE LEAKS. THIS OCCURRED TWICE CAUSING A TOTAL OF 126 HOURS OF
1Q4
-------
CPA UTILITY FGD SURVEY: THIRD QUARTER 1979
NEVADA
POWER: RtID GARDNER £ (CONT.>
Pt F FOkPANCE DATA
PERIOD MODULE AVA1LA91LITY CPERAf-lLITY RELIABILITY UTILIZATION
! REMOVAL PEP BOILER FGD CAP.
SO: PART. HOURS HOURS HOURS FACTOR
DO»N TIKE.
iTART DATE 9/7r, END DATE 9/79
SOF.E OUTAGE TIME WAS REQUIRED TO UNPLUC. EFFLUENT AND VENTURI LINES AKD
TO CLEAN TIE VE'JTUftl RACE TRACK.
START DATE <>/79 END DATE 9/79
HIGH PRESSURE WAS ENCOUNTERED TWICE IN THE SCRUBBER DUCT AND ONCE IN THE
BOILER FURNACE. THIS CAUSED SO!«IE OUTAGE TIME TO CLEAN THE SCRUBBER
PRESSURE SENSING LINES.
START BATE 9/79 END DATE 9/7?
THE SCRUBBER WAS DOWN WITH THE ROILEh SO REPAIRS TO THE MAIN STEAI" DfcAIN
LINE COULD BE CONDUCTED.
START DATE 9/79 END DATE 9/79
THE SCRUBBER WAS DOWK FOR APPROXIMATELY 7 HOURS TO WORK ON THE CONTROLS.
-------
EPA UTILITY FbD SUCVFY: T H 1 h D QUARTER 1979
SfcCTION I
DESIGN AND PERFORMANCE DATA FOR OFF-RATIONAL FGD SYSTEMS
CO!*PANY NAI'.E
PLANT NAPE
UNIT NU^RER
CITY
STATE
GROSS DMT GENERATING CAPACITY - Xlk
NET UNIT GENERATING CAPACITY y/FGD -
EQUIVALENT SCRUBBED CAPACITY - WW
NEVADA POycR
REID GARDNER
i
MOAPA
NEVADA
125.0
110.0
125.C
FUEL DATA
FUEL TYpL
FUEL GRADE
AVERAGE HEAT CGNTEfcT - J/C
AVERAGE ASH CONTENT - %
AVEPAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - ">
AVERAGE CHLORIDE CONTENT - 1
COAL
BITUMINOUS
Z8959.
8.00
.50
.05
< 12450 BTU/LB)
•* FGD SYSTE*
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEy/RETROFIT
ENERGY CONSUMPTION - J
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - \
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t.
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPF
FRESH MAKE-UP WATER - LITFR/S
** DISPOSAL
TYPE
WET SCRUBBING
SODIUM CARBONATE
ADL/COMBUSTlON EQUIP ASSOCIATE
NEW
6/76
7/76
85.QG
% 99.00
.0
.0
CLOSED
9.S
POND
( 155 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY &PERA8ILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM 100.0 97,0
** PROuLEMS/SOLUTIONS/CPIWENTS
100.0
67.7
744
246
241
START DATE 3/79 END DATE 3/79
THE BOILER AND FCD SYSTEM WERE OFF FOR ABOUT 2 DAYS TO REPAIR AND BALANCE
A bOILtR I.D. FAN.
START DATE 3/70 END DATE 3/79
THE SOILER AND FGD SYSTEM UERE OFF FOR ABOUT 19 CAY FOR SCHEDULED HAIN-
TENANCt.
4/79 SYSTEM 100.0 1CO.D
*• PROuLEMS/SOLUTIONS/COKWENTS
100.0
1 00 . 0
72C
719
719
START DATE 4/79 [ND DATE 4/79
NO OUTAGES WERE REPORTED FOP APRIL.
5/79 SYSTEC
9?.7
97.7
97 .7
97.5
744
742
725
106
-------
EPA UTILITY FCD SURVEY; THIRD QUARTER 1979
POWER: RtID L.At
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - l«fc
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 - J
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
GARY
INDIANA
115.D
94.0
115.0
COAL
25586.
11.00
3.50
( 11000 BTU/LB)
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - i
ABSORBER SPARE COMPONENTS INDEX
WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
WET SCRUBBING
WELLMAKI LORD
DAVY POWERGAS
RETROFIT
-72.3
7/76
6/77
90.00
98.50
.0
.0
CLOSED
{*.*** 6PM)
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELEMENTAL SULFUR
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION
Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
7.0
1.0
1.0
720
** PROfcLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 2/79
THE BOILER OPERATED CN LOW SULFUR COAL FEBRUARY 1-12 AND HIGH SULFUR COAL
FEBRUARY 13-MARCH 2. THE FGD SYSTEM REMAINED DOWN THROUGH FEBRUARY 22
FOR COMPLETION OF SULFUR CONDENSER REPAIRS FOLLOWED BY REPAIR OF EXPANSION
JOINT LEAKS.
START DATE 2/79 END DATE 2/79
A POWER INTERRUPTION ON FEBRUARY 24 RESULTED IN LOSS Of SEAL WATER TO THE
EVAPORATOR PUMP AND PACKING FAILURE. THE FGD SYSTEM REMAINED DOWN THROUGH
MARCH 2.
3/79 SYSTEM 47.0
«* PRObLEMS/SOLUTIONS/COMWENTS
44 .0
43.0
72 C
308
START DATE 3/79 END DATE 3/79
THE bOlLER OPERATED ON HIGH SULFUR COAL DURING THE MONTH.
START DATE 3/79 END DATE 3/79
THE FC-D SYSTEM WAS SHUT DOWN DUE TO HIGH LEAKAGE IN THE EVAPORATOR CIR-
-------
CPA UTILITY FGD SURVEY: THIRD QUARTER 1<579
NORTHERN INDIANA PUB SERVICE: DEAN t. C1TCHELL 11 (COMT.)
PER FORM AMCC DATA
PERIOD MODULE AVAILABILITY OPERAFIL1TY RtLlADILITY UTILIZATION 7. htPOVAL PER 601LE R~~ FGo" CAp"
S0< PART. HOURS HOURS HOURS FACTOR
CULAT1NG PUMP PACKING GLAND. THE PUMP SHAFT SLEEVE fcAS RE PLAC E D ~AN D THf""
PUKP REALIGNED. THE SYSTEM *AS DOWN FOR A&OUT 16 DAYS.
4/79 SYSTEM 73.0 77.0
5/79 SYSTEM 86.C 76.0
«« PROULEMS/SOLUTIONS/COWENTS
720
744
527
499
START DATE 4/79 FND DATE 5/79
FGD OUTAGES IN THE EVAPORATOR SYSTEM RESULTED FROM HIGH VIBRATION IN THE
CIRCULATING PU^P, PARTIAL PLUGGING OF THE HEATER TUBES AND A LEAK IN THE
S02 SUPERHIATER. fGD OUTAGES IN THE SO? REDUCTION SYSTEM RESULTED FROM
PLUGGING OF THE TAIL GAS LINE AND MALFUNCTION OF THE INCINERATOR COM-
BUSTION CONTROLS.
START DATE 5/79 END DATE 5/79
B01LEP OUTAGES WERE REQUIRED FOR REPAIR OF A TUBE LEAK AND FOR REPAIR OF
A STEAK STOP VALVE.
6/79 SYSTEM 91.0
»« PR06LEMS/SOLUTIONS/COWENTS
£0.0
tJ.D
7?D
455
START DATE
START DATE
6/79 END DATE 6/79
THt UNIT 11 BOILER OPERATED PART OF THE PERIOD ON HIGH SULFUR COAL At«D
PART ON A KIXTURE OF HIGH AND MEDIUM SULFUR COAL.
6/79 END DATE 6/77
AN OUTAGE WAS REQUIRED FOR REPAIR OF A REHEAT STOP VALVE AND THE OPERATINGE
RATF WAS LIMITED DUE TO AN ID FAN BEARING PROBLEM AND AN FO FAN FAILLRE.
LOw WAIN STEAK PRESSURE LOW S02 IN THE FLUE GAS CAUSED FGD OUTAGES. FGD
OUTAGES ALSO RESULTED FROM A FLUE LEAK, A PLUGGED WATER VALVE AND REPAID
OF AN EXPANSION JOINT.
7/79 SYSTEM
90.0
39.0
682
538
«* PROtfLEflS/SOLUTIONS/COWENTE
8/79 SYSTEM
9/79 SYSTEM
START DATE 7/79 END DATE 7/79
UNIT 11 BOILER OPERATED ON HIGH SULFUR COAL. OUTAGES OCCURRED FOR REPACK-
ING OF THE STEAM PRV VALVE WHICH SUPPLIES FGD AND AN ELECTRICAL GROUND.
SPECIAL TESTING OF THE UNIT 11 BOILER - FGO SYSTEM WAS CONDUCTED RY TRW
FOR EPA FROK JULY 17-28 WHICH REQUIRED THAT THE UNIT 11 RATE BE VARIED AND
THAT THE SC2 REDUCTION UNIT BE DOWN FOR A PORTION OF THE PERIOD. IN
ADDITION TO THE FGD OUTAGE REQUIRED BY THE TRW TESTING, FGD OUTAGES
RESULTED FFDM INSPECTION OF THE BOOSTER BLOWER SPEED REDUCER AND HIGH FLOW
RESISTANCE IN THE S02 REDUCTION UNIT.
744
720
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE
8/79 tND DATE 9/713
NO DATA WAS AVAILABLE FOR THE MONTHS OF AUGUST AND SEPTEMBER.
-------
EPd UTILITY FbD SUFVEY: THIRD (iUARTER 1979
SFCT10N ?
DESIGN AND PERFORMANCE DATA FOP OPERATIONAL FGD SYSTEMS
COl-.PANV NAKE
PLANT MAKE
UNIT NU^PER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mu
NET UNIT GENERATING CAPACITY W/FGD -
EQUIVALENT SCRUBBED CAPACITY - WW
fvORTHERN STATES POWER
SHEHPURNE
1
PECKER
MINNESOTA
7AC.O
700.0
740.C
«• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/C
AVERAGE ASH CONTENT - 1
AVtPAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - '/
AVERAGE CHLORIDE CONTENT - 'i.
** FGD SYSTEh
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTE1 SUPPLIER
NEy/RETROFIT
ENEPGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - *
COAL
SUPBITUMINOUS
1"771 . ( 8500 BTU/LB)
9.00
25.00
.80
.03
WET SCRUBBING
LIMESTONE/ALKALINE FLVASH
COMBUSTION ENGINEERING
NEW
2.7
3/76
5/76
50.00
PARTICULATE DESIGN REMOVAL EFFICIENCY - X 99.00
ABSORBER SPARE CAPACITY INDEX - *
ABSORBER SPARE COMPONENTS INDEX
«* WATER LOOP
TYPE
FRESH MAKE — U P WATER •" LITER/S
«* TREATMENT
TYPE
«* DISPOSAL
TYPE
PERIOD MODULE AVAILABILITY OPERAR1L1TY
2/75 1C1 7?.C
1C2 7?. .0
103 70.0
1C4 7fc .0
1^5 50.0
K6 91.0
1~7 92.0
10? 92.0
1"9 75. ~
11: 77.0
111 66 .0
112 9' ,C
SYSTEM 85.0 1CO.O
3/7<; 1?1 61 .0
102 ^8.0
10.' 45.0
104 86.0
105 94. C
1r6 71.0
1C 7 91.0
8.0
.9
CLOSED
FORCED OXIDATION
LINED POND
RELIABILITY UTILIZATION % REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
78 .0
73.0
70. C
76.0
50. C
91. 0
92.0
92.0
75.0
77. G
66. C
93. G
100.0 672 672 672 67.9
60.1
86. P
44 .4
84.8
92.7
70.0
89.?
110
-------
NORTHERN STATES POWfcR: SHERBUKNE 1 (CtNT.)
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
PERFORMANCE DATA
PEP10D MODULE AVAILABILITY CPEMDILITY RELIABILITY UTILIZATION % REMOVAL PER BOILER~~FCD~~~CAP~~
S02 PART. HOURS HOURS HOURS FACTOR
1Ch
109
110
111
112
SYSTEM 92. 0
73.0
91 .C
80 .0
89.0
FO.O
72.0
89. 8
78.9
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mfc
NET UNIT GENERATING CAPACITY W/FGD - dW
EQUIVALENT SCRUBBED CAPACITY - IHW
•• 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
NORTHERN STATES POWER
SHERBURNE
2
MINNESOTA
740.0
700.0
740. C
COAL
SUBB ITUMINCUS
19771.
9.00
25.00
.80
( 8500 BTU/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 SPARE CAPACITY INDEX - 1
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
WET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
2.7
4/77
4/77
50.00
99.00
8.0
.9
OPEN
(***** GPK)
FORCED OXIDATION
DISPOSAL
TYPE
LINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION
% REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
2/79 201
202
204
205
206
2C7
2Cs
209
210
211
212
SYSTEM
93.0
3/79
201
202
203
2C4
205
2C6
2C7
208
E6.0
84.0
89.0
59.0
76.0
72.0
68.C
60.0
75.0
92.0
65 .0
100.0
85.0
69.0
78 ,P
47.0
71 .0
76. •?
90 .C
672
671
112
-------
" STATtS POWER: SHERBURNE 2 (CONT.)
FPA UTILITY FGD SURVEY: THIRD QUARTER 1979
PER FORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAflLITY RELIABILITY UTILIZATION X REMOVAL PER E CILEfT~ FG D ~ ~~C AP~~
so? PART. HOURS HOURS HOURS FACTOR
2C9
21C
211
212
SYSTEM
50 .C
85.0
57.0
86.0
91 .0 100 .0
** PROBLEMS/SOLUTIONS/COMMENTS
744
744
4/79 SYSTEM
5/79 SYSTEM
START DATE-
START DATE
99.0
95.0
>/79
LND DATE 3/79
THE ONLY REAL PROBLEMS ENCOUNTERED DURING THIS PERIOD WERE PROBLEMS HTH
WET COAL.
V79 END DATE 3/79
THE RECYCLE PUMPS ARE BEING REPLACED WITH LARGER 8000 GPM WORTHINGTON
PUMPS. DOSING THIS PERIOD THE PUMPS WERE INSTALLED ON MODULES 204 AND
206.
100.0
100-0
720
744
717
263
** PROaLEKS/SOLUTIONS/COKNENTS
START DATE
START DATE
START DATE
5/79 END DATE 5/79
THE LOW BOILER HOURS IN WAY WERE DUE TO COMMENCEMENT Of THE ANNUAL BOILER
AND TURBINE INSPECTION.
4/79 END DATE 5/79
ALL PIPING HAS BEEN CHANGED TO FIBERGLASS.
5/79 END DATE 5/79
THE UTILITY WILL NOW REPORT THE AVAILABILITY OF THE TOTAL SYSTEM ONLY.
6/79 SYSTEM
90.0
100.0
720 454
»* PROULEMS/SOLUTIONS/COIWENTS
START DATE 6/79 END DATE 6/79
THE ONLY PROBLEM REPORTED BY THE UTILITY WAS THE LOSS OF A BOILER SUSCE
PUMP AFTER THE UNIT RESTARTED.
7/79 SYSTEM 95.0
8/79 SYSTEM 96.0
9/79 SYSTEH 95.0
** PROBLEBS/SOLUTIONS/COWIENTS
START DATE
744
744
720
741
740
657
9/79 END DATE 9/79
NO MAJOR OPERATIONAL PROBLEMS HAVE BEEN ENCOUNTERED KITH THIS UNIT SINCE
IT CAME BACK ON LINE AFTER THE ANNUAL BOILER/TURBINE OVERHAUL.
11 J
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mk
NET UNIT GENERATING CAPACITY W'/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - tnU
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - X
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - %
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP iiATER - LITER/S
** TREATMENT
TYPE
•» DISPOSAL
TYPF
PENNSYLVANIA
BRUCE MANSFIELD
1
SHIPPlNGPORT
PENNSYLVANIA
917.0
825.0
017.Q
COAL
BITUMINOUS
26749.
12.90
7.00
3.00
WET SCRUBBING
LIME
C 11500 BTU/LEO
NEU
6.0
12/75
6/76
92.10
99.80
.0
.0
OPEN
CALCILOX
LANDFILL
(***** GPMl
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEPAB1L1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO2 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 672
1/79 SYSTEM 744
4/7? SYSTEM 720
5/79 SYSTEM 744
** PRObLEMS/SOLUTIONS/CCMWENTS
START BATE 2/79 END DATE 5/79
UNIT 1 IS CURRENTLY DOWN FOP A BOILER OUTAGE.
START BATE 2/7-: END DATE 5/79
six OF THE TWELVE FAN HOUSINGS HAVE BEEN CHANGED FROM CARBON STEEL
If.COLLGY
t/79 SYSTEM
4344
114
-------
TPA UTILITY FGD SURVEY: THIRD QUARTER 1979
POWER: ?«UCE MANiSFlELD 1 (CONT.)
PER FORM ANCE DATA
PERIOD MODULE AVAILABILITY OPEPAPILITY RELIABILITY UTILIZATION % REMOVAL PER BOILER~~fGD~"cAP™
so<- PART. HOURS HOURS HOURS FACTOR
** PROSiLEMS/SOLUTlONS/CCMMENTS
START BATE 1/79 tND DATE 6/79
THE APOVE AVAILABILITY IS THE AVAILABILITY FROM JANUARY 1. 1979 THROUGH
HAY 31, 1979.
START DATE 1/79 END DATE 6/79
THE UTILITY REPORTED THAT FAN MOTOR FAILURES WERE A MAJOR PROBLEM AREA
DURING THE FIRST HALF Of 1979.
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 9/79
FAN HOUSING kORK (CHANGING FROM LINED CARBON STEEL TO INCOLLOY 825) IS
CONTINUING.
START DATE 7/79 END DATE 9/79
MEW PH MONITOR MODIFICATIONS HAVE YIELDED PROMISING RESULTS WITH RESPECT
TO MONITOR AVAILABILITY.
START DATE 7/79 END DATE 9/79
THE FGD SYSTEM ATTRIBUTED 17.4X OF THE TOTAL UNIT UNAVAILABILITY FOR 1979
TO DATE. THE BREAKDOWN IS AS FOLLOWS:
7.61 SCRUBBER ID FAN WORK/PROBLEMS
8.3% GENERAL SCRUBBER PROBLEMS AND MAINTENANCE
1.0% REAGENT HANDLING PROBLEMS CLIME SLAKER AND PIPING)
0.5X KIST ELIMINATOR PLUGGING
115
-------
EPA UTILITY F&O SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY td/FGD - KW
EQUIVALENT SCRUBBED CAPACITY - MH
•• 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 - 2
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO2 DESIGN REMOVAL EFFICIENCY - £
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS JNDEX
*» WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
** TBEATMENT
TYPE
*» DISPOSAL
TYPE
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
SHlPPINfcPORT
PENNSYLVANIA
917.0
825.0
917.C
COAL
BITUMINOUS
26749.
12.90
7.CO
3.00
WET SCRUBBING
LIME
< 11500 BTU/LB)
NEW
6.0
7/77
* * f**
92.10
99.80
.0
.0
OPEN
CALCILOX
LANDFILL
(«»*.* GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART- HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
672
744
720
START DATE 1/79 END DATE 4/79
NO INFORMATION WAS REPORTED FOR THIS PERIOD BY THE UTILITY.
5/79 SYSTtM
6/79 SYSTEM 88.8 1CO.C
«* PROBLEMS/SOLUTIONS/COMMENTS
744
4344
START DATE 1/75 tND DATE 6/79
THE ABOVE AVAILABILITY IS THE AVAILABILITY FOR JANUARY 1, 1979 THROUGH
MAY II , 1979.
START DATE 1/79
IND DATE
116
-------
EPA UTILITY FGD SURVEY: THIRD OUARTER 1979
PENNSYLVANIA POWER: BRUCE WANSFIELD 2 (CONT.)
PERFORMANCE DATA
CFPIOD MODULE AVAILABILITY OPEPABIL1TY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER fGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/79 SYSTEM
8/79 SYSTEM
9/79 SYSTEM
THE UTILITY REPORTED THAT SOME FAN PROBLEMS WERE RECENTLY ENCOUNTERED.
744
744
720
** PROBLEMS/SOLUTIONS/COMKENTS
START DATE 7/79 END DATE 9/79
CHIMNEY LIMNG WORK (APPLICATION OF CXL 2000) WAS COMPLETED IN EARLY 1979.
START DATE 7/7" END DATE 9/7P
FAN HOUSING kORK (CHANGING FROM LINED CARBON STEEL TO INCOLLOY 825) IS
CONTINUING.
START DATE 7/79 END DATE 9/79
NEW PH MONITOR MODIFICATIONS HAVE YIELDED PROMISING RESULTS WITH RESFECT
TO MONITOR AVAILABILITY.
START DATE 7/79 END DATE 9/79
THE FGD SYSTEM ATTRIBUTED IQ.8% OF THE TOTiAL UNIT UNAVAILABILITY FOR 1979
TO DATE. THE BREAKDOWN IS AS FOLLOWS:
5.C2 CHIMNEY (FINISHED CXL 2000 APPLICATION)
1.3Z GENERAL SCRUBBER PROBLEMS AND MAINTENANCE
1.5% ID FAN VORK/PROBLFMS
2.0% F.IST ELIMINATOR PLUGGING
1.0Z EMISSION VIOLATION (CUT BACK OF BOILER LOAD BECAUSE OF LOW S02
REMOVAL EFFICIENCY)
117
-------
EPA UTILITY FL-E> SURVEY: THIhD QUARTER 1979
SECTION 3
DiSlGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT MJCC'ER
CITY
STATt
GROSS UNIT GENERATING CAPACITY - P>fc
MET UMT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
** FuEL DATA
FUEL TYPE
FUEL GRACE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - i
AVERAGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - 2
** FGD SYSTEM
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
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - %
ABSORBER SPARE COMPONENTS INDEX
*• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
PHILADELPHIA ELECTRIC
EDDYSTONE
1A
EDDYSTONE
PENNSYLVANIA
120.0
120.0
120.0
COAL
BITUMINOUS
31634.
9.40
5.90
2.60
********
WET SCRUBBING
MAGNESIUM OXIDE
UNITED ENGINEERS
RETROFIT
( 13600 BTU/LB)
9/75
9/75
90.00
99.00
.0
.0
OPEN
8.3
SULFURIC ACID
t 13Z GPU)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 672
3/79 SYSTEM 744
** PR06LEMS/SOLUTIONS/CCMMENTS
START DATE 2/79 EfJD DATE 3/79
NO INFORMATION WAS REPORTED FOR THIS REPORT PERIOD.
4/79 SYSTfcM 7JO
5/79 SYSTEM 744
6/79 SYSTEM 72 Q
•* PRObLEWS/SOLUTIONS/COKMENTS
START DATE 6/7"? END DATE 6/79
NG INFORMATION IS AVAILABLE FOR THIS PERIOD BUT SHOULD BE FOR THE NEXT
REPORT PERIOD.
7/79 SYSTEM 744
fe/79 SYSTEM
118
-------
FPA UTILITY FGD SURVEY: THIRD QUARTER 1979
PHILADELPHIA ELECTRIC: tDDYSTONE 1A ((.ONT.)
PER fORWANCF DATA
PERIOD MODULE AVAILABILITY OPERARUITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
9/79 SYSTEM 720
«* PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 9/79
NO DATA WAS AVAILABLE FOR THE UNIT DURING THE THIRD QUARTER 1979.
119
-------
EPA UTILITY FbD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORKANCE DATA FOB OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - HW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - fU
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - 1
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - *
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEH 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 INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
«• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
PUPLIC SERVICE OF NEW MEXICO
SAN JUAN
1
NEW MEXICO
?61.0
314. 0
COAL
18841.
22.45
14.82
.80
WET SCRUBBING
UELLMAN LORD
DAVY POUERGAS
RETROFIT
4.4
4/7F
** /* *
85.00
99.50
33.0
1.0
CLOSED
30.2
( 8100 BTU/LB)
( 480 6PIO
ELEMENTAL SULFUR
MARKETED
PERIOD MODULE AVAILABILITY
PERFORMANCE DATA
OPERABIL1TY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
** PRObLEMS/SOLUTlONS/cOMMENTS
672
744
720
744
7/79 SYSTEM
8/79 SYSTEM
9/79 SYSTEM
START DATE 1/79 END DATE 5/79
HOURS ARE NOT YET AVAILABLE BECAUSE THE UTILITY IS CONCENTRATING EFFORTS
ON OPERATICN OF THIS NEW UNIT. THE UTILITY REPORTED THAT THE SCRUBBING
MODULES THEMSELVES ARE OPERATING FINE. ALSO THE CHEMICAL PLANT IS READY
AND THERE IS NO SYSTEM PLUGGING WHATSOEVER.
START DATE 1/79 tND DATE 5/79
THE MAJOR PROPLEM ENCOUNTERED WAS GYRATING FANS.
744
744
720
120
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
PUBLIC SFRVlCt OF NEW MEXICO: SAN JLftN 1 (CGNU)
PER F0PMA MCE DATA
PERIOD MODULE AVAILABILITY OPERAPIL1TY RELIABILITY UTILIZATION * REMOVAL PER BOILER FCD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
.* PROBLEMS/SOLUTIONS/CCWENTS
START OATF 7/79 END DATE 9/79
DURING THE THIRD QUARTER THE UNIT OPERATED ON TWO ABSORBERS. ALL FCIR
ABSORBERS HAVE BEEN LARGELY AVAILABLE. ONE ABSORBER WAS DOWN DUE TO
BOOSTER BLCUER VIBRATION PROBLEMS.
-------
EPA UTILITY FGD SURVEY: THIRD QUARTfcR 1979
DESIGN
SECTION 3
PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - ML.
NET UNIT GENERATING CAPACITY W/FGD - Mta
EQUIVALENT SCRUBBED CAPACITY - MW
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
NEW MEXICO
350.0
306.0
35Q.O
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
COAL
20934.
22.45
U.82
.80
( 9000 BTU/LB)
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - %
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - %
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
WET SCRUBBING
WKLLMAN LORD
DAVY POWE»GAS
RETROFIT
4.6
8/78
**/**
85.00
99.50
33.0
1.0
*« WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
(***** 6PM)
** BYPRODUCT
3YPRODUCT NATURE
DISPOSITION
ELEMENTAL SULFUR
MARKETED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
1 REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
672
744
720
744
«« PROBLEMS/SOLUTIONS/COMMENTS
7/79 SYSTEM
8/79 SYSTEM
9/79 SYSTEM
START DATE 1/79 END DATE 5/79
HOURS ARE NOT YET AVAILABLE BECAUSE THE UTILITY IS CONCENTRATING EFFORTS
ON OPERATICN OF THIS NEW UNIT. THE UTILITY REPORTED THAT THE SCRUBBING
MODULES THEMSELVES ARE OPERATING FINE. ALSO THE CHEMICAL PtANT IS HEADY
AND THEPE IS NO SYSTEM PLUGGING WHATSOEVER.
START DATE 1/79 END DATE 5/79
THE MAJOR PRCPLEM ENCOUNTERED WAS GYRATING FANS.
744
744
72 C
-------
EPA UTILITY FGD SURVEY: THIRD SUARTER 1979
PUPLK SERVICE OF NEW MEXICO: SAN Jl^K 2 (CONT.)
PERFORMANCE DATA
MODULE AVAILABILITY OPERAEILITY RELIAL1L1TY UTILIZATION X REMOVAL PER EOILtR FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
t* PROOLEMS/SOLUTIONS/CCMMENTS
START DATE 7/79 END DATE 9/79
DURIN6 THf THIRD QUARTER TWO OF THE FOUR ABSORBERS WERE DOWN DOE TO
BOOSTER BLOWER VIBRATION PROBLEMS.
123
-------
FPA UTILITY Ft.0 SURVEY: THIRD QUARTER 1979
SECTION I
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MW
** 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 HATE
SO2 DESIGN REMOVAL EFFICIENCY - %
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDE»
** WATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
** DISPOSAL
TYPE
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
2
GEORGETOWN
SOUTH CAROLINA
28C.O
258.0
140-0
COAL
BITUMINOUS
26749.
13.50
1.70
UET SCRUBBING
LIMESTONE
BABCOC* 8 UILCOX
NEW
1.1
7/77
**/**
69.00
99.40
.0
.0
< 11500 BTU/LB)
OPEN
POND
{ 100 GPK>
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM 96.6 96.4
** PROBLEMS/SOLUTIONS/COMMENTS
96.4
92.7
672
1416 1361
1313
START DATE 2/79 END DATE 3/79
AN OUTAGE WAS REQUIRED TO RENEW QUENCHER PUMP BELTS AND FOR REPAIRS TO A
QUENCHER SUCTION VALVE.
START DATE 2/79 END DATE 3/79
OUTAGES WERE REQUIRED TO REPAIR A HOLE IN THE FEED SLURRY LINE, TO INSPECT
THE MODULE FOR PLUGGAGE, AND BECAUSE OF A BOOSTER FAN TRIP.
START DATE 2/79 END DATE 3/79
THE OPERATING VALUES SHOWN AHE THE FIGURES FOR FEB. AND MARCH COMBINED.
4/79 SYSTEM
99.4
99.4
99.4
99.4
720 720
716 73.4
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 4/79 END DATE 4/79
THE UTILITY REPORTED THAT THE S02 MONITOR HAS PASSED THE STATE CERTIFICA-
TION TEST CUT REQUIRES CONTINUING MAINTENANCE TO KEEP IT OPERATING.
124
-------
EPA UTILITY FED SURVEY: THIRD QUARTER 1979
SOUTH CAROLINA PUBLIC SERVICE: WINY AH ; (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPE K AP IL IT Y RELIABILITY UTILIZATION X REMOVAL P ER~"OILER"FGO~ "CAP"
S02 PART- HOURS HOURS HOURS FACTOR
START DATE 4/79
END DATE 4/79
A MALFUNCTION OF TH£ F'ECl RCULATION TANK LEVEL INDICATOR RESULTED IN * .Ok
LIQUID LEVEL WHICH RESULTED IN A FORCED OUTAGE. "EiULFED IN » L0k
5/79 SYSTEM 98.A 98.7
** PROBL.EMS/SOLUT1 ONb/COMMENTS
100.0
95.6
744
721
711 82.0
START DATE 5/79
END .DATE 5/79
START DATE
THt UTILITY REPORTED THAT THE S02 MONITOR SAMPLE PUMP REQUIRES MAINTENANCE
ALt*'QST tVcKT c *• HOURS*
r/79 END DATE 5/79
A BOILER OUTAGE ALLOWED TIME FOR CLEANING ABSORBER TRAYS, UNPLUGGING FOUR
NOZZLES, CLEANING THE SUMP POTTOW, AND REPAIRING A SPRAY WASH VALVE.
6/79 SYSTEM
92.4
92."5
92.1
91.
80.00
720
716
66C 86.6
** PROhLEMS/SOLOTIONS/COWENTS
START DATE 6/79 END DATE 6/79
FOUR OUTAGES IN JUNE WERE DUE TO PLUGGED ABSORBER NOZZLES. THE PRIMARY
CAUSE APPEARED TO £>E THAT A SCREEN IN THE ABSORBER SIDE OF THE SUMP BOTTOM
WAS LEFT OUT DURING THE PREVIOUS OUTAGE.
START DATE
START DATE
6/79 END DATE 6/79
A HEAVY SCALE BUILD-UP IN THE SUMP BELOW THE VENTURI WAS NOTED.
6/79 END DATE 6/79
THE UTILITY REPORTED THAT MGO TESTING HAS BEGUN.
7/79 SYSTEM
98.4
98 .4
98 .4
97. g
84.00
744
740
732
'* PR06LENS/SOLUTIONS/COMWENTS
START DATE 7/79 END DATE 7/79
THE ABSORBER WENT OFF-LINE DUE TO QUENCHER PUMP PACKING PROBLEMS.
START DATE 7/79 END DATE 7/79
SOME PLUGGING WAS ENCOUNTERED WITH ONE OF THE ABSORBER NOZZLES.
START DATE 7/79 END BATE 7/79
SOME OUTAGE TIKE WAS NEEDED TO INSTALL A QUENCHER WALL WASH NOZZLE.
8/79 SYSTEM
99.4
99 .0
99.4
98.1
80.00
744 73E
739
** PROBLEKS/SOLimONS/COBMENTS
START DATE 8/79 END DATE 8/79
A 4 HOUR OUTAGE U.AS THE RESULT OF BOOSTER FAN CONTROL PROBLEMS.
A NEW PORT fOR THE SCRUBBER OUTLET GAS SAMPLE PROBE HAD TO BE INSTALLED.
THIS TOOK 1 HOUR OF SCHEDULED DOWN TIME.
-------
EPA UTILITY FED SURVEY: TBlfcf CLUARTER 1979
SECTION 3
DESIGN AfiD PERFORMANCE DATA FOR OPERATIONAL FCD SYSTEMS
COMPANY NAf.E
PLANT NAo'E
UNIT NU"bER
CITY
STATt
GROSS UNIT GENERATING CAPACITY - Mt
NET UNIT GENERATING CAPACITY W/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - HW
«• FUEL DATA
FULL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J fC
AVERAGE ASH CONTENT - S
AVERAGE MOISTURE CONTENT - 7,
AVbRAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
** FGt> SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - 1
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - 2
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
SOUTH MISSISSIPPI ELEC PWR
R.(>. MORROW
1
HATTISBURG
MISSISSIPPI
230.0
180.0
124.0
t 12000 BTU/LB)
COAL
27912.
8.00
6.50
1.30
MET SCRUBBING
LIMESTONE
RILEY STOKER/E.NVIRONEERING
NEW
5.5
8/78
** /* *
85.00
99.60
.0
.0
CLOSED
<***** GPM)
FLYASH STABILIZED
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
I REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
<./?<> SYSTEM
*» PROBLEMS/SOLUTIONS/COMMENTS
672
744
720 631
5/79 SYSTEM
6/79 SYSTEM
START DATE 4/79 END DATE 4/79
THE BOILER RETURNED TO SERVICE ON APRIL 1 AFTER COMPLETION OF REPAIRS
TO THE BOILER TUBES.
START BATE 4/79 tND DATE 4/79
NO FGD SYSTEK RELATED PROBLEMS WERt REPORTED BY THE UTILITY FOR APRIL.
744
720
126
-------
EPA UTILITY fGD SURVEY: THIRD QUARTER 1979
OU1H MISSISSIPPI ELEC PW R : R.O. MORROW 1 (CONT.)
PtKfORMANCF DATA
PERIOD MODULE AVAILABILITY OPERAP1L1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FCD ~CApT
SO? PART. HOURS HOURS HOURS FACTOR
.* PRObLEMS/SOLUTIONi/COMMENTS
START DATE 5/79 END DATE 6/79
THt UTILITY REPORTED THAT THE SYSTEM OPERATED MOST OF MAY AND JUNE WITH
NO MAJOR PROBLEMS.
7/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 7/79
DURING THE FIRST WEEK OF JULY THE UNIT WAS REMOVED FROM SERVICE DUE TO
SEVERE PROtLEMS hlTH THE FGD SYSTEM. THE UTILITY NOTED THAT ABOUT HALF
OF THf MODULE HEADERS WERE PLUGGED, HOLES WERE NOTED IN THE MODULE SHELL,
THE UPPER ROD DANK CORRODED AWAY FROM THE SHELL, AND EXTENSIVE PLUGGING
OF THE MIST ELIMINATOR OCCURRED. LINER .FAILURE AT THE OUTLET DUCTWORK WAS
ALSO EXPERIENCED. THE UTILITY PLANS TO REPLACE THE DUCTWORK WITH
HASTALLOY. THE FGD SYSTEM IS EXPECTED TO BE OFF LINE FOR SEVERAL MONTHS
FOR REPAIRS TO FJE COMPLETED.
8/79 SYSTEM 7*4 0
9/79 SYSTEM 72° °
«* PROBLEMS/SOLUTIONS/COMHENTS
START DATE 3/79 END DATE 9/79
THE UNIT REMAINED OFF LINE DURING THE MONTHS OF AUGUST AND SEPTEMBER AS
MAINTENANCE AND REPAIR WORK CONTINUED.
127
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - KU
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGO - MW
NET UNIT GtNERATING CAPACITY UO/FGt - MW
EQUIVALENT SCRUBBED CAPACITY - My
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW
HATT1SBURG
MISSISSIPPI
A
40.0
200.0
180.0
191.0
124.0
LB/MMBTU)
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 - Z
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - %
RANGE MOISTURE CONTENT - 5!
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - %
RANGE CHLORIDE CONTENT - X
** ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
** FGD SYSTEM
SALEABLE PRODUCT/THR OW AWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - %
IMITIAL START-UP
** ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
GAS FLOW - CU.K/S
GAS TEMPERATURE - C
RILEY STOKER
PULVERIZED COAL
BASE
**/**.
132.2
124.
*******
COAL
27912.
8.00
(*****.* ACFM)
I 270 F)
( 408 FT)
(***** FT>
( 12000 BTU/LB>
6.50
6-7
1.30
1 - 1.75
1
HOT SIDE
BUELL
99.6
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
NONE
RILEY STOKER/ENVIRONEERING
BURNS 8 MCDONNELL
RILEY STOKER
FULL SCALE
NEW
- X 99.60
85.00
6/79
ROD DECK SCRUBBER
6/79
RILEY STOKER/ENVIRONEERING
7
10 X 40 X 10
CAPBCN STEEL
DUDICK FLAKEGLASS
516L SS RODS, HASTELLOY 6 SUPPORTS
192.03 C 4C6940 ACFM)
132.2 ( 270 F)
128
-------
EPA UTILITY
SOUTH MISSISSIPPI ELEC PWR: R.B. MORROW 2 (CONT.)
SURVEY; THIRD CUARTER 1979
** FANS
TYPE
*« WIST ELIMINATOR
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
NUMBER OF STAGES
MASH SYSTEM
** REHEATER
TYPE
«* THICKENER
NUMBER
DIAMETER - M
** HATER LOOP
TYPE
** TREATMENT
TYPE
** DISPOSAL
NATURE
TYPE
LOCATION
TRANSPORTATION
BOILER ID
CHEVRON
FRP
VERTICAL
3
CONTINUOUS
BYPASS
1
12.2
CLOSED
t 40 FT)
FLYASH STABILIZED
FINAL
LANDFILL
ON-SITE
TRUCK
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FG D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/79 SYSTEM
** PR06LENS/SOLUTIONS/COMMENTS
START DATE
720
6/79 END DATE 6/79
R.D. MORROW UNIT #2 BEGAN OPERATION IN THE LATTER PART OF JUNE. OPERA-
TIONAL DATA ARE NOT YET AVAILABLE.
7/79 SYSTEM
8/79 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
744
START DATE 7/79 END DATE 8/79
NO INFORMATION WAS AVAILABLE FOR THE JULY-AUGUST 1979 PERIOD.
9/79 SYSTEM 4.7 5.0
** PROBLEMS/SOLUTIONS/COKWENTS
5.0
4.7
720
58
START DATE 9/79 END DATE 9/79
DURING SEPTEMBER THE UNIT WAS TAKEN OFF LINE DUE TO FAILURE OF LINERS AND
PLUGGING Ih THE MIST ELIMINATOR SECTIONS.
129
-------
EP* UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAKE
OMIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE tMlSSlON LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - »W
GROSS UNIT GENERATING CAPACITY - WU
NET UNIT GENERATING CAPACITY W/FGD - KW
NET UNIT GENERATING CAPACITY WO/FGC - MW
EQUIVALENT SCRUBBED CAPACITY - I»M
SOUTHERN ILLINOIS POUtR COOP
MARION
4
MARION
ILLINOIS
370.0
184.Q
160.0
184.0
LP/MMBTU)
LB/HHBTU)
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 - K
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 - Z
RANGE MOISTURE CONTENT - %
AVERAGE SULFUR CONTENT - %
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - «
RANGE CHLORIDE CONTENT - X
BABCOCK K UILCOX
******
BASE
10/78
COAL
20934.
16.00
10.00
3.50
h* ***
.10
<**«**** ACFH>
C**** FJ
C***» FT)
(.«*** FT)
< 9000 BTU/LB)
ESP
NUMBER
SUPPLIER
PART1CULATE DESIGN REMOVAL EFFICIENCY - Z
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
FGD SYSTEM
SALEABLE PRODUCT/T HR OW AUA Y PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY - I
S02 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
ABSORBER SPARE CAPACITY INDEX - £
ABSORBER SPARE COMPONENT INDEX
ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
PRESSURE DROP - KPA
S02 DESIGN REMOVAL EFFICIENCY - *
BABCOCK &
99.6
Z85.5
143.3
W1LCOX
( 605000 ACFM)
I 290 F>
****** »«— u?ni
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
BABCOCK g WILCOX
BURNS s KCDONNELL
BABCOCK & UILCOX
FULL SCALE
NEW
99.60
89.40
5/79
SPRAY TOWER
10/78
BABCOCK 8 WILCOX
3.0
86.7
(12.2 1N-H20)
PROCESS CONTROL CHEMISTRY
CONTROL VAR1APLES PH
CONTROL RANGE 5-6
130
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SOUTHERN ILLINOIS POWER COOP: RAfUON 4 (CONT.)
«* REHEATER
TYPE
«* HATER LOOP
TYPF
«* TREATMENT
TYPF
** DISPOSAL
NATURE
TYPE
NONE
OPEN
FLYASH STABILIZED
FINAL
LANDFILL
PERFORMANCE DATA
PERIOD BOODLE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/79 SYSTEM
6/79 SYSTEM
** PRObLEMS/SOLUTIONS/COMMENTS
744
720
START DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT THE UNIT BEGAN OPERATION IN HAY. HOWEVER THE
UNIT IS NOt DOWN AND SUFFERED TWO PREVIOUS OUTAGES. THE PREVIOUS OUT-
AGES WERE CUE TO CENTRIFUGE AND THICKENER PROBLEMS. THE PRESENT OUTAGE
IS DUE TO BEARING FAILURES ON THE PUG MILL AND IMPROPER FIT OF THE SLUDGE
CONVEYING BELT.
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 72C
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE
START DATE
7/79 END DATE 9/79
DURING THE THIRD QUARTER A ROUTINE INSPECTION OF THE SCRUBBER INTERNALS
SHOWED NO SCALE FORMATION.
7/79 END DATE 9/79
THE UTILITY REPORTED THAT THE FGD SYSTEM HAS ACHIEVED A 0.7 LB/MMBTU OF
SOZ EMISSION LEVEL. THE UNIT IS SUBJECT TO THE 1.2 LB/KMBTU S02 EMISSION
STANDARD.
START DATE 7/79
END DATE 9/79
THE CONTINUOUS MONITORS HAVE NOT BEEN OPERATING ACCEPTABLY.
START DATE 7/7S
END DATE 9/79
A TURBINE OVERHAUL/INSPECTION IS SCHEDULED FOR OCTOBER It 1979.
1 J1
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PA8TICULATE EMISSION LIMITATION - ME/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - Mw
6ROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - MU
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** BOILED DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - «
STACK TOP DIAMETER - K
•» FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - %
AVERAGE MOISTURE CONTENT - Z
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - Z
SOUTHERN INDIANA GAS & ELEC
A.B. BROUN
1
WEST FRANKLIN
INDIANA
A
43. t .100 LB/HMBTU)
516. C 1.i200 LB/MMBTU)
250.0
265.0
250.0
252.0
265.0
BABCOCK g WILCOX
PULVERIZED COAL
BASE
0/79
372.82 < 790036 ACFM)
143.3 C 290 F)
152. « 498 FT)
4.4 t 14.5 FT)
COAL
30261.
8.80
11.40
4.50
.05
< 13010 BTU/LB)
*• ESP
NUMBER
TYPE
SUPPLIER
*» FGD SYSTEM
SALEABLE PRODUCT/T HR OU AWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
CONSTRUCTION INITIATION
CONTRACT AWARDED
STARTED REQUESTING BIDS
ABSORBER SPARE CAPACITY INDEX - 2
ABSORBER SPARE COMPONENT INDEX
** ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
NUMBER Of NOZZLES
COLD SIDE
BUELL
THROUAWAY PROPUCT
WET SCRUBBING
DUAL ALKALI
FMC CORPORATION
BROWN g ROOT
HID VALLEY
FULL SCALE
NEW
- X 99.50
85.00
3/79
10/77
12/76
4/76
20.0
.3
DISC CONTACTOR
3/79
FMC CORPORATION
3
62 HIGH X 32 OIA.
CARBON STEEL
CEILCOTE
HASTELLOY
1
132
-------
SOUTHERN INDIANA GAS R ELEC: A.n. FROWN 1 (COfJT.)
UTILITY FGD SURVEY: THIRD QUARTER 1979
NOZZLE TYPE
BOILER LOAD/APSORBER - ».
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
S02 INLET CONCENTRATION - PPK
S02 OUTLET COMTRATION - PP(*
S02 DESIGN REMOVAL EFFICIENCY -
«* CENTRIFUGE
TYPE
*« FANS
NUMBER
TYPE
SERVICE - WET/DRY
CAPACITY - CU.M/S
** VACUUM FILTER
NUMBER
TYPE
CONSTRUCTION MATERIAL
CAPACITY - B T/D
OUTLET SOLIDS - X
** MIST ELIMINATOR
NUMBER
TYPE
NUMBER OF STAGES
WASH SYSTEM
** PROCESS CONTROL CHEMISTRY
** PUMPS
SERVICE
RECYCLE
** TANKS
SERVICE
REACTION
SURGE TANK
** REHEATER
TYPE
** THICKENER
NUMBER
DIAMETER - «
** WATER LOOP
TYPE
** REAGENT PREPARATION EQUIPMENT
NUMBER OF SL.AKERS
** DISPOSAL
NATURE
TYPE
LOCATION
TRANSPORTATION
SINGLE PIPE
60.0
237.?4
U5.0
a? id
520
85.0
NOME
BOOSTER
DRY
117.97
ROTARY ORUf*
NYLON BELT
174.1
60.0
CHEVRON
2
OCCASIONAL
NUMBER
2
NUMBER
****
* * * *
NONE
1
30.5
CLOSED
3
FINAL
LANDFILL
ON-SITE
TRUCK
' 5Q4C&C ACFfi)
< Z93 F)
< 250000 ACFK)
< 192 T/0)
1100 FT>
•- PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEf?ABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
SYSTEM
4/79 SYSTEM
744
720
133
-------
EP* UTILITY FuD SURVEY: THIKD CUARTtS 1979
SOUTHtRN INDIANA GfcS <, fXEC: A.b. FKD*N 1 (CONT.)
PERFORMANCE DATA-
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FG D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PHOuLEMS/SOLUTIONS/COWIENTS
START DATE J/79 END DATE 4/79
THE FCD SYSTEM BEGAN OPERATIONS ON MARCH 18t 1979. NO OPERATIONAL DATA
ARE YET AVAILABLE.
5/79 SYSTEM 7*4
6/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 6/79
OPERATING HOURS ARE NOT YET AVAILABLE. HOWEVER THE UNIT HAS BEEN RUNNING
INTERMITTENTLY AS A RESULT OF PUMP LINER AND FRP PIPING DESIGN PROBLEMS.
7/79 SYSTEM 63.0 55.0 744 650 408
8/79 SYSTEM 94.0 94.0 744 743 701
** PROOLEMS/SOLUTIONS/COKMENTS
START DATE 8/79 END DATE 8/79
IN AUGUST THE FGD SYSTEM WAS FORCED OFF LINE FOR 43 HOURS DUE TO PROBLEMS
UITH THE RECYCLE PUMP IMPELLERS.
9/79 SYSTEM 75.0 74.0 720 716 534
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 9/79 END DATE 9/79
THE ONLY FORCED OUTAGE DURING THE MONTH BE.GAN ON SEPTEMBER 28 AND LASTED
THROUGH THE END OF THE MONTH. THIS OUTAGE WAS DUE TO PROBLEMS UITH THE
VACUUM FILTERS AS y£LL AS CHEMICAL PROBLEMS.
START DATE 9/79 END DATE 9/79
IN SEPTEMBER 52 HOURS OF .SCHEDULED OUTAGE MERE USED TO INSTALL A WATER
FILTER. THE SCRUBBER WAS ALSO TAKEN OFF LINE FOR 72 HOURS FOR PRECIPITATOR
TESTING. THE ONLY FORCED OUTAGE DURING THE MONTH BEGAN ON SEPTEMBER 28 AND
LASTED THROUGH THE END OF THE MONTH AS A RESULT OF POOR FILTER CAKE
QUALITY. THIS HAS RESULTED FROM PROBLEMS UITH THE VACUUM FILTERS AS WELL
AS CHEMICAL PROBLEMS.
134
-------
EPA UTILITY Ff,D SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATt
6ROSS UNIT GENERATING CAPACITY - Ml»
NET UNIT GENERATING CAPACITY W/FGD - Kw
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 - %
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 KAKE-UP WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
- X
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
SPRINGFIELD
MISSOURI
194.Q
173.0
194.0
< 12500 BTU/LB)
COAL
BITUMINOUS
29075.
13.CO
3.50
.30
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEU
4.6
4/77
* * /* *
80.00
99.70
.0
.0
CLOSED
19.8
NONPROPRIETARY
LANDFILL
I 315 6PMX
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 S-1 25.0 .0 .0 .0
S-2 24.0 32.0 32.0 24.0
SYSTEM 24.5 16.0 16.0 12.1
672 508 81 71.4
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 2/79
THE S-1 MODULE EXPERIENCED PLUGGING PROBLEMS IN THE FIRST AND SECOND
STAGE DURING FEBRUARY AND DID NOT OPERATE. DUE TO FLUE GAS LEAKAGE INTO H
THE MODULE ACCESS COULD NOT BE OBTAINED TO CLEAN THE NODULE.
START DATE 2/79 END DATE 2/79
EXPANSION JOINT PROBLEMS ANB BROKEN LINES WERE REPORTED.
START DATE 2/79
END DATE 2/79
3/79 S-1
START DATE
62.0
A LACK OF SCRUBBING MEDIUM DURING THE LATTER PART OF FEBRUARY WAS REPORTED
BY THE UTILITY.
2/79 LN'D DATE 2/7"
THE S-2 MODULE PROBLEMS INCLUDED FROZEN VALVES AND LINES.
39.5
39.5
38.7
135
-------
EPA UTILITY FGD SURVEY: THIRD GUARTER 1979
SPRINGFIELD CITY UTILITIES: SOUTHWEST 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA61L1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER fGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79
5/79
7/79
S-2
SYSTEM
55.0
58.5
14.0
2t .8
14 .0
26.8
13.7
26.2
744
730
195 52.8
*• PROBLEMS/SOLUTIONS/COMMENTS
START DATE 3/79 END DATE 3/79
THE MAJORITY OF MODULE S-1 DOWNTIME WAS DUE TO A BROKEN SUP£RNATE
MAKEUP CROSS TIE.
AMD
START DATE 3/79 END DATE 3/79
THE UTILITY REPORTED THAT THE MODULE WAS UNABLE TO RUN FOR A TIME DUE TO
A DESIGN PROBLEM WITH A 500 HP MOTOft.
S-2
S-1
SYSTEM
51.6
42.6
47.1
26.5
30.9
37.9
45.0
30.9
50.4
27.0
18.5
22.8
720 432
164
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 4/79 END DATE 4/79
MODULE S-1 EXPERIENCED AN EXPANSION JOINT FAILURE ON THE I.D. FAN DIS-
CHARGE.
START DATE 4/79 END DATE 4/79
LOW DENSITY AT THE SLURRY HOLD TANK WAS A MAJOR PROBLEM.
START DATE 4/79 END DATE 4/79
SOME PLUGGING OF THE FIRST STAGE OF THE S-2 MODULE WAS REPORTED BY THE
UTILITY.
S-1
S-2
SYSTEM
84.1
.0
42.1
77.5
.0
3S.8
77.5
.0
48.5
67.0
.0
33.5
744
644
249
** PR06LEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 5/79
THE S-2 MODULE WAS NOT OPERATED DURING MAY DUE TO A BROKEN RECYCLE TANK
AGITATOR SHAFT. A NEW ONE HAS BEEN ORDERED. RUBBER LINING OF THE SHAFT
AND REPAIR OF DAMAGED LINING ON THE IMPELLER WILL BE DONE ON SITE.
6/79 S-1
S-2
SYSTEM
55.0
.0
27.5
53.0
.0
26.5
54.2
.0
27.1
52.9
.0
26.5
720
719
191
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
THE BROKEN AGITATOR SHAFT WAS REPLACED AND LINED DURING JUNE.
START DATE 6/79 END DATE 6/79
THE S-2 MODULE HAS OUT OF SERVICE ON THREE OCCASIONS DUE TO PLUGGAGE OF
THE FIRST AND SECOND STAGES. THE UTILITY REPORTED THAT WITH THE EXCEPTION
OF THE PLUGGING PROBLEM ONLY A FEW MINOR SHORT DURATION TRIPS WERE NOTED.
s-i
S-2
SYSTEM
59.2
55.3
57.3
34.1
47.4
40.?
34.1
47.4
40.8
34.1
47.3
40.7
744 743
111
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 7/79
THE S-1 KOLULE WAS NOT OPERATED DURING THE FIRST PART OF THE PERIOD DUE TO
THE PLUGGAGE IN THE FIRST AND SECOND STAGES. TWO OTHER OUTAGES OCCURRED.
ONE DUE TO * BROKEN LINE AND THE OTHER TIME IT WAS P,C. TROUBLE.
START DATE 7/79 END DATE 7/7"
THE S-2 MODULE WAS NOT OPERATED FOR TWO PERIODS. ONCE WHEN THE TANK WAS
BEING REFILLED AFTER AN AGITATOR WAS INSTALLED AND ONCE TO CLEAN THE FIRST
AND SFCOND STAGES.
136
-------
tPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SPRINGFIELD CITY UTILITIES: SOUTHWEST 1 (CONT.)
PER fORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION
% REMOVAL PER BOILER FGD CAP.
302 PART. HOURS HOURS HOURS FACTOR
8/79
S-1
S-2
SYSTEM
74
94
&4
.5
.6
.7
53
70
62
.E
.9
.4
50
66
62 .4 58
.7
.P
.8
744 701 437
PROBLEMS/SOLUTIONS/COMMENTS
START DATE
8/79 END DATE 8/79
THE S-1 MODULE WAS DOWN FOR TWO PERIODS DUE TO PLUGGING IN THE ABSORBER
SECTION. THE MODULE ALSO TRIPPED OFF DUE TO LOSS OF SUPERNATE PUMPS.
APART FROM THIS BOTH MODULES WERE EITHER AVAILABLE OR IN OPERATION.
9/79 S-1
SYSTEM
48.6
68.8
71.3
58.3
60.2
59.3
5S.3
73.8
65.7
45.8
47.4
46.6
720 566
336
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 9/79 END DATE 9/79
THE S-1 MODULE WAS OFF LINE DUE TO PLUGGING IN THE ABSORBER SECTION FOR
TWO PERIODS AND IT ALSO TRIPPED DUE TO LOSS OF SUPERNATE PUMPS. APART FROM
THIS IT WAS EITHER OPERATING OR AVAILABLE.
START DATE 9/79 END DATE 9/79
THE S-2 MODULE WAS OfF LINE ONCE DUE TO BR.OKEN SUPERNATE LINE, AND OfcCE
DUE TO BAD PH PROBES IN SEPTEMBER. IT WAS ALSO OFF LINE FOR SEVERAL SHORT
PERIODS DUE TO NUISANCE TRIPS; HOWEVER, IT WAS EITHER ON LINE OR AVAILABLE
THE REST OF THE PERIOD.
1Z7
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAP.E
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - KW
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
** F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - ?
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 WATER - LITER/S
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10A
PADUCAH
KENTUCKY
10.0
10.0
10.0
COAL
BITUMINOUS
BTU/LB)
?.90
WET SCRUBBING
LIME/LIMESTONE
AIR CORRECTION DIVISION. OOP
RETROFIT
4/72
**•/**
CLOSED
(***** GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
0/79 SYSTEM
** PROBLEHS/SOLUTIONS/COHMENTS
START DATE
0/72 END DATE 9/79
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR SHAUNEE 106.
133
-------
EPA UTILITY FED SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Ml,
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - KW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - %
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - t
AVERAGE CHLORIDE CONTENT - X
** FGE> 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
PARTKULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
TENNESSEE VALLEY AUTHORITY
SHAWNEE
106
PADUCAH
KENTUCKY
1C.D
10.0
10.0
COAL
BITUMINOUS
2.90
t****** BTU/LB)
WET SCRUBBING
LIME/LIMESTONE
CHEN1CO
RETROFIT
1,172
* * / * *
.0
CLOSED
(*****
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
672
744
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 3/79
ONE TEST RUN WAS CONDUCTED ON EACH OF THE TWO SCRUBBER SYSTEMS IN
EARLY FEBRUARY TO PROVIDE SAMPLES FOR LEVEL 1 BIOASSY TESTING BY LITTON
BIONETICS CORPORATION UNDE& CONTRACT WITH EPA. ACTUAL SAMPLING OF SLUR-
RIES AND CCNDENSATES FROM THE SCRUBBER AND OXIDATION TANK OFF-CASES UflS
PERFORMED BY BATTELLE COLUMBUS LABORATORY. FOR THIS PURPOSE, THE TCA WAS
OPERATED WITH LIMESTONE/FLYASH SLURRY.AS A BASE CASE, AND THE VENTURI/
SPfiAY TOWER WAS OPERATED WITH LIHESTONE/FLYASH SLURRY AND WITH ADIPIC
ACID ADDITIVE AND TWO-SCRUBBER-LOOP FORCED OXIDATION.
A SERIES OF TESTS WAS CONDUCTED ON THE VENTURI/SPRAY TOWER SYSTEM FROM
MID-FEBRUARY THROUGH THE END OF MARCH TO SIMULATE THE PLANNED TVA WIDOWS
CREEK UNIT 8 FULL-SCALE, TWO-SCRUBBER-LOOP FORCED-OXIDATION SCHEME.
SPECIAL WIDOteS CREEK LIMESTONE (STONEMAN) AND COAL (PITTSBURGH MIDWAY)
WERE USED AT SHAWNEE DURING THESE TESTS. NEAR COMPLETE SULF1TE OXIDATION
WAS ACHIEVED AT OXIDATION TANK PH UP TO 6.Q AND AN AIR STOICH10M ETRY AS
LOW AS 1.5 ATOMS OXYGEN/ MOLE SG2 ABSORBED. EXPECTED SLURRY CARRY-OVER
FROM THE FIRST TO THE SECOND SCRUBBER LOOP AT WIDOWS CREEK WAS SIMULATED
BY AN ARTIFICIAL BACKMIX STREAM OF UP TO 65 GPM.
A NEW LIKE/ADIPIC ACID TEST BLOCK WITH AND WITHOUT FORCED OXIDATION
BEGAN IN EARLY FEBRUARY ON THE Si KGLE-UOOP TCA SYSTEM USING FLUE GAS WITH
HIGH FLYASH LOADINGS. AT TCA INLET PH OF 7.0, 2400 TO 2900 PPM INLET S02,
L/G OF 50 GAL/ tfCF, AND 15 INCHES TOTAL STATIC BED HEIGHT OF 1-7/8 IKCH
NITRILE FOAM SPHERES, SOZ REMOVALS WERE 83, 93, AND 97 PERCENT WITH ZERO,
139
-------
EPA UTILITY FGD SURVEYr THIRD QUARTER 1979
TENNESSEE VALLEY AUTHORITY: SHAUNEE KB (CONT .)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA61LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
60C, AND 1230 PPM ADIP1C ACID, RESPECTIVELY, WITHOUT FORCED OXIDATION.
SO? REMOVAL REMAINED HIGH AT 91 PERCENT WITH 1200 PPM ADIP1C ACID WHEN L/C
WAS REDUCED FROM 50 TO 37 GAL/MCF- WHEN OXIDATION WAS FORCED UlTH ABOUT
1.8 AIR STOICHIOMETRY, NEAR COMPLETE SULFITE OXIDATION WAS ACHIEVED AT
OXIDATION TANK PH OCA INLET PK) UP TO ABOUT 5.5, AND izoo PPM ADIPIC
ACID. S02 REMOVAL ABOVE 90 PERCENT WAS OBTAINED AT TCA INLET PH AS LOW
AS 5.C WITH FORCED OXIDATION.
4/79 SYSTEM
5/79 SYSTEM
720
744
** PROBLENS/SOLUTIONS/COMMENTS
6/79 SYSTEM
7/79 SYSTEM
8/79 SYSTEM
9/79 SYSTEM
START DATE 4/79 END DATE 5/79
A SERIES OF BLEED STREAM OXIDATION TESTS USING LIMESTONE AND ADIPIC
ACID WAS CONDUCTED ON THE VENTURI/SPRAY TOWER DURING THE MONTH OF APRIL.
NEAR COMPLETE SULFITE OXIDATION WAS ACHIEVED UNDER CONDITIONS OF EITHER
LOW FLUE GAS THROUGHPUT, WHICH RESULTED IN LOW BLEED RATES AND SUBSEflUENT-
LY HIGHER RESIDENCE TIMES IN THE OXIDATION TANK, OR RECIRCULATION AT
LIQUOR BACK TO THE EFFLUENT HOLD TANK WHICH ARTIFICIALLY MAINTAINED A LOU
PH IN THE OXIDATION TANK.
DURING THE MONTH OF APRIL. THE TCA WAS OPERATED WITH LIMESTONE, ADIPIC
ACID AND FORCED OXIDATION USING A SINGLE TANK. AT AIR STOICHIOMETRIC
RATIOS OF 1.7-2.0 ATOMS OXYGEN/HOLE S02 ABSORBED* AN UNUSUAL SET OF C0tt~
OITIONS WAS ENCOUNTERED DURING WHICH THE LIQUID SULFITE ION LEVEL IN-
CREASED TO A RANGE OF 8DO TO 1700 PPH AND THE DEMAND FOR LIMESTONE TO
MAINTAIN THE SCRUBBER INLET PH AT 5.1 INCREASED TO A RANGE OF 1.8 10 (.0
MOLES LIMESTONE/HOLE S02 ABSORBED. THE CAUSE HAS NOT VET BEEN DETERMINED
ALTHOUGH IT WAS FOUND THAT THE SITUATION COULD BE ALLEVIATED BY EITHER
INCREASING THE AIR STOICHIOMETRY TO GREATER THAN 2.2, OR BY MOVING THE
LIMESTONE FEED TO A SECOND TANK DOWNSTREAM OF THE OXIDATION TANK.
BOILER NO. 10 WENT DOWN ON MAY 5TH FOR A SCHEDULED 6 WEEK BOILER GUT-
AGE. DURING THIS PERIOD, THE VENTURI/SPRAY TOWER WILL BE DOWN BUT THE
TCA IS BEING OPERATED ON FLUE GAS FROM BOILER NO. 9 THROUGH THE NEWLY IN-
STALLED DUCT. DURING THIS PERIOD, THE TCA WILL COMPLETE A SERIES OF
LIMESTONE/ADIPIC ACID FACTORIAL TESTS WITH AND WITHOUT FORCED OXIDATION.
720
744
744
720
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 9/79
BOILER NO. 10 WAS RESTARTED ON JULY 6, 1979 AFTER NINE WEEKS OF SCHEDULED
MAINTENANCE OUTAGE.
START DATE 9/79 END DATE 9/79
LIMESTONE FACTORIAL TESTING WITH ADIPIC ACID ADDITION ON THE VEN TUR1 /SPRAY
TOWER SYSTEM CONTINUED THROUGHOUT THE THIRD QUARTER. THESE TESTS WERE
MADE WITH TWO-LOOP OPERATION WITH FORCED OXIDATION AND SPRAY TOWER OKLY
OPERATION WITHOUT FORCED OXIDATION, BOTH UNDER CLOSED-LOOP CONDITIONS.
OPEN-LIQUOR-LOOP TESTS WITH TWO-LOOP OPERATION AND WITHOUT FORCED OXIDATION
WERE ALSO CONDUCTED TO COMPARE THE RESULTS WITH "FRESH" ADIPIC ACID
»GAINST THOSE WITH "AGED" ACID OBTAINED UNDER CLOSED-LIQUOR-LOOP
CONDITIONS.
START DATE 7/79 END DATE 9/79
DURING THE THIRD QUARTER, ADDITIONAL LIMESTONE FACTORIAL TESTS WITH
ADIPIC ACID WERE CONDUCTED ON THE TOA SYSTEM TO SUPPLEMENT THOSE WADE IN
MAY AND JUNE. IN ATDITION, A SERIES OF LIMESTONE TESTS WITHOUT ADIPIC
ACID WERE PERFORMED USING A SINGLE TANK TO INVESTIGATE THE EFFECT OF AIR
STOICHIOMETRV AND OXIDATION TANK AGITATOR SPEED ON SULFITE OXIDATION. IN
A SIMILAR SERIES OF TESTS CONDUCTED IN APRIL BUT WITH ADIPIC ACID, Ah
UNUSUAL SET OF CONDITIONS WAS ENCOUNTERED WHICH GAVE HIGH LIQUOR SUIF1TE
140
-------
FPA UTILITY FGD SURVEY: THIRD QUARTER 1979
TENNESSEE VALcEY AUTHORITY: SHAWNEE KB CCONT.)
-PERFORMANCE DATA-
oPBIOB MODULE AVAILABILITY OPERAP1L1TY RELIABILITY UTILIZATION % REMOVAL PER BOILER fGD CAP.
p S02 PART. HOURS HOURS HOURS FACTOR
CONCENTRATION tfOQ-1700 PPM) AND DEMANDED HIGH LIMESTONE STOI CHI OH ET KY
(1.S-4.0 HOLES CA/MOLE S02 AOSORBFD) TO MAINTAIN A SCRUBBER INLET PH OF
5.1. THESE PHENOMENA WERE ALSO OPSERVED DURING TESTS hITHOUT AD1P1C ACID.
INSUFFICIENT SULFITE OXIDATION RATE (CAUSED BY REDUCED AIR ST01CHIOHtTRY
AND/OR REDUCED AGITATION IN THE OXIDATION TANK) AND DECREASED AMOUNT OF
SOLID CAS03 SEEDS WERE BELIEVED TO CAUSE HIGH SULFITE SUPERSATUR AT ICh
(HIGH SULFITE CONCENTRATIONS) AND THE RESULTANT BLINDING OF LIMESTONE Bt
SULFITE (HIGH LIMESTONE STOICH10METRY).
141
-------
EPA UTILITY FGD SURVEY: THIRD OUARTtR 197Q
SECTION I
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITT
STATE
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - HW
EQUIVALENT SCRUBBED CAPACITY - MW
*« FUEL DATA
FUEL TYPt
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - %
AVERAGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - %
•* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - %
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO2 DESIGN REMOVAL EFFICIENCY - X
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
BRIDGEPORT
ALABAMA
550.0
516.0
550.0
COAL
23260.
25.00
10.00
3.70
t 10DOO BTU/LB)
WET SCRUBBING
LIMESTONE
TENNESSEE VALLEY AUTHORITY
RETROFIT
5/77
1/78
80.00
X 99.50
.0
.0
DISPOSAL
TYPE
POND
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER f6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
672
744
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE
START DATE
2/79 END DATE 3/79
CONSTRUCTION OF THE FORCED OXIDATION TEST WAS COMPLETED AND THE TESTING
HAS BEGUN ALTHOUGH NO RESULTS ARE YET AVAILABLE (THIS TESTING IS BEING
DOME ON ONE OF THE FOUR MODULES).
2/79 END DATE 3/79
THE UNIT OUTAGE yHlCH BEGAN IN OCTOBER AND WAS SCHEDULED TO END IN FEB-
RUARY CONTINUED THROUGH MARCH BECAUSE THERE yERE BOILER AND TURBINE
FAILURES AFTER A FEW START UPS.
4/79 SYSTEM
5/79
A
b
C
D
SYSTEM
100.0
100.0
100.0
100.0
130.3
97.5
59.2
100.0
1CO.O
90.9
83.6
53.8
89.7
37.9
78.0
80.Z.D
720
744 638
580
*• PRObLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 5/79
THt VENTURI HEADERS AND NOZZLES HAVE PLUGGED WITH SCALE AND SOLIDS. A NEW
VEUTURI HEADER HAS BEEN INSTALLED AND IS BEING TESTED ON TRAIN B. THE
142
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
TENNESSEE VALLEY AUTHORITY: WIDOWS CREEK 8 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
% REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/79
A
B
C
0
SYSTEM
100.0
100.0
100.0
99.6
99.9
93.6
89.9
<51 .1
93 .8
92.1
75.7
72.6
73.6
75.8
74.4
84.20 99.50 720
582
536
** PR03LEP!S/SOLUTIONS/CO«I«!ENTS
START DATE 6/79 END DATE 6/79
THE NEW HEADER IN TRAIN B PROVED SATISFACTORY SO NEW HEADERS ARE TO BE
INSTALLED ON ALL VENTURIS.
7/79 A
B
C
SYSTEM
START DATE
100.0
100.0
100.0
100.0
100.0
6/79 END DATE 6/79
OPTIMIZATION TESTS ON UNIT 8 SCRUBBER HAVE BEGUN AND WILL BE COMPLETED BY
THE END OF OCTOBER. THE TESTS HILL INCLUD* TESTING THE ADDITIONAL FIBER-
GLASS REINFORCED PLASTIC GRIDS. NEW ABSORBER FULL-CONE SPRAY NOZZLES,
POLYPROPYLENE GRID-TYPE PACKING, AND TURBULENT CONTACT ABSORBER SPHERES.
100.0
100.0
100.0
8 s
THE ELEVATOR WILL BE REPLACED WITH BELT CONVEYORS
U3
-------
EPA UTILITY FbD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mki
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
•* FuEL DAT*
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTEXT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - %
• * FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP »ATE
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
** TREATMENT
TYPE
• * DISPOSAL
TYPE
TEXAS UTILITIES
MARTIN LAKE
1
TATUM
TEXAS
793.0
750.0
595.0
COAL
LIGNITE
17166.
8.00
33.00
.90
* *** *** *
WET SCRUBBING
LIMESTONE
NONE
NEW
1.3
4/77
10/78
( 7380 BTU/LB)
99.40
.0
.0
CLOSED
34.6
( 550 GPM)
FLYASH STABILIZED
LANDFILL
PERFORMANCE DATA-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
302 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
*/79 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
67?
744
720
START DATE 2/79 END DATE 4/79
UNIT 1 IS NOy IN FULL OPERATION ALTHOUGH A SLUDGE DISPOSAL PROBLEM STILL
EXISTS.
START DATE 2/79 END DATE 4/79
THE UTILITY HAS REPLACED THE LOUVER DAMPERS WITH GUILLOTINE DAMPERS WHICH
SEEM TO WORK BETTER. HOWEVER, THEY STILL HAVE PROBLEMS WITH THE GUIL-
LOTINE DAMPERS FAILING TO SEAL WHEN THEY BCCOME SCALED.
START DATE 2/79 END DATE 4/79
THERE HAVE SEEN REPORTS OF TOWER LEAKS FROM LINER FAILURE BUT IT DOESN'T
SEEM TO BE SERIOUS.
5/79 SYSTEM 744
144
-------
CPA UTILITY fGO SURVEY: THIRD QUARTER 1<579
TEXAS UTILITIES: MARTIN LAKE 1 (CQNT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION % REMOVAL PER BOILER FGD CAP-
S02 PART. HOURS HOURS HOURS FACTOR
6/79 SYSTEM 720
*» PROBLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 6/79
THfc SLUDGE DISPOSAL SYSTEM IS STILL CAUSING SOME OPERATING PROBLEMS. THE
PROBLEMS REPORTED LAST QUARTER WERE CAUSED BY HEAVY RAINS WHICH KNOCKED
OUT THE THICKENERS.
7/79 SYSTEM 744
g/79 SYSTEM 744
9/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 7/79 END DATE 9/79
DURING THE THIRD QUARTER THE UTILITY REPORTED THE SYSTEM IS OPERATING WELL.
THE SLUDGE DISPOSAL SYSTEM PROBLEMS PLAGUING THE UNIT HAVE BEEN SOLVED.
-------
EPA UTILITY FGD SURVEY: THIRD GUARTER 1979
SECTION 3
DESIGN AND PERFORKANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - KU
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL OATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-ilp DATE
COMMERCIAL START-UP DATE
SOa DESIGN REMOVAL EFFICIENCY - *
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
*• WATER LOOP
TYPE
FRESH WAKE-UP WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
TEXAS UTILITIES
MARTIN LAKE
2
TATUH
TEXAS
793.0
750.0
595.0
COAL
LIGNITE
17166.
8.00
33.00
.90
( 7380 BTU/LB)
HET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
1.3
5/78
**/* *
99. 40
.0
.0
CLOSED
34.6
( 550 6PM)
FLYASH STABILIZED
LANDFILL
---------------------------------------- PERFORMANCE DATA ------------------ -— • -— -- >--— -------- - ---
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t RliKOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
*» PROBLtMS/SOLUTIONS/COMKENTS
672
744
720
START DATE 2/79 END DATE 4/79
THE UTILITY REPORTS THAT OPERATIONAL PROBLEMS HAVE INCLUDED ABSORBER
LIUER FAILURES AND TOWER LEAKS.
START DATE 2/79 END DATE 4/79
UNIT Z IS NOW IN FULL OPERATION ALTHOUGH A SLUDGE DISPOSAL PROBLEM STILL
EXISTS.
START BATE Z/79 END DATE 4/79
THE UTILITY HAS REPLACED THE LOUVER DAMPER'S WITH GUILLOTINE DAMPERS I>HI€M
SEEM TO WORK BETTER. HOWEVER, THEY STILL HAVE PROBLEMS WITH THE GUIL-
LOTINE DAMPERS FAILING TO SEAL WHEN THEY BCCOME SCALED.
5/70 SYSTEM
146
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
UTUITIbS: MARTIN LAKE 2 (CONT.)
-PERFORMANCE DATA-
PERIOD MODULE AVAILABILITY OPERAR1L1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
503 PART. HOURS HOURS HOURS FACTOR
6/79 SYSTEM 720
*« PRObLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 6/79
THE SLUDGE DISPOSAL SYSTEM IS STILL CAUSING SOME OPERATING PROBLEMS. THE
PROBLEMS REPORTED LAST QUARTER WERE CAUSED BY HEAVY RAINS WHICH KNOCKED
OUT THE THICKENERS.
7/79 SYSTEM 744
g/79 SYSTEM 744
9/79 SYSTEM 720
** PROdLEMS/SOLUTlONS/COHMENTS
START DATE 7/79 END DATE 9/79
DURING THE THIRD QUARTER THE UTILITY REPORTED THE SYSTEM WAS OPERATING
WELL. THE SLUDGE DISPOSAL SYSTEM PROBLEMS PLAGUING THE UNIT HERE SOLVED.
U7
-------
EPA UTILITY F6D SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - MW
NET UNIT GENERATING CAPACITY WO/FCC - MW
EQUIVALENT SCRUBBED CAPACITY - MW
TEXAS UTILITIES
MARTIN LAKE
3
TATUM
TEXAS
A
43.
516.
3000.0
793.0
750.0
760.0
595.0
< .100 LB/HHBTU)
( 1.200 LB/MNBTU)
•* 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/6
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 - X
RANGE CHLORIDE CONTENT - X
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
** /* *
1494.51 <3167000 ACFM)
168.3 C 335 F)
****** C***** FT>
******* (***-** FT)
COAL
LIGNITE
17166.
8.00
5.6-13.2
33.00
29.0-37.9
.90
0.5-1.5
t 7380 BTU/LB)
6972-7894
** ESP
NUMBER
TYPE
SUPPLIER
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
COLD SIDE
RESEARCH COTTRELL
1494.5
168.3
(3167000 ACFM)
< 335 F)
(***** IN-H20)
FGD SYSTEM
SALEABLE PRODUCT/THR OW AWA Y PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICIPATE DESIGN REMOVAL EFFICIENCY
INITIAL START-UP
ABSORBER SPARE CAPACITY INDEX - 2
ABSORBER SPARE COMPONENT INDEX
ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
BOILER LOAD/ABSORBER - Z
GAS FLOW - CU.M/S
&AS TEMPERATURE - C
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
NONE
RESEARCH COTTRELL
C.T. MAIN
H.B. ZACHARY
FULL SCALE
NEW
- X 99.40
2/79
.0
.0
PACKED TOWER
2/79
RESEARCH COTTRELL
3
12.5
177-13 ( 375350 ACFH)
162.8 t 325 F)
148
-------
TEXAS UTILITIES: MARTIN LAKE * CCONT.)
fPA UTILITY FGD SURVEY: THIRD QUARTER 1979
.» CENTRIFUGE
NUMBER
OUTLET SOLIDS - X
** FANS
NUMBER
TYPE
SERVICE - UET/DRY
CAPACITY - CU.M/S
** MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES
WASH SYSTEM
SUPERFICIAL GAS VELOCITY - ft /S
PRESSURE DROP - KPA
** PUMPS
SERVICE
QUENCHER FEED PUMP
SLURRY FEED
RECYCLE
** TANKS
SERVICE
ABSORBER FEED
** REHEATER
TYPE
** THICKENER
NUMBER
TYPE
DIAMETER - M
OUTLET SOLIDS - X
** TREATMENT
TYPE
** DISPOSAL
NATURE
TYPE
LOCATION
TRANSPORTATION
69.0
4
BOILER
DRY
375.48
I.D.
( 795680 ACFM)
12
CHEVRON
POLPROPYLENE
HORIZONTAL
2
3
TOP AND BOTTOM WASH
• 2 C .8 FT/S)
• 2 f 1.0 IN-H20)
NUMBER
**
54
NUMBER
3
BYPASS
1
GRAVITY
42.7
35.0
(140 FT)
FLYASH STABILIZED
FINAL
LANDFILL
ON-S1TE
RAIL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM
4/79 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
720
START DATE 3/79 END DATE 4/79
MARTIN LAKE UNIT 3 BECAME OPERATIONAL DURING MARCH. NO OPERATIONAL DE-
TAILS ARE YET AVAILABLE.
5/79 SYSTEM
6/79 SYSTEM
149
-------
fPA UTILITY FGD SURVEY: THIRD OUARTtR 1979
TEXAS UTILITIES: MAKTIN LAKE 3 (CONT.)
----------------------------------------- PERFORMANCE" DATA-- ---------------------------------- - ----
PfcFIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION % REMOVAL PER BOILER F6D CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
** PHOBLEMS/SOLUTIONS/COWWENTS
START DATE 4/79 END DATE 6/79
THE UNIT UAS IN OPERATION DURING THIS PERIOD ALTHOUGH OPERATIONAL DATA
HERE NOT AVAILABLE.
7/79 SYSTEM
S/79
9/79 SYSTEH
** PRObLt«S/SOLUT10NS/COHWENT5
7*4
7*4
720
START DATE 7/79 END DATE 9/79
DURING THE THIRD QUARTER THE UTILITY REPORTED TWAJ THE F,GD SYSTEJ*
ylTHOUT ANY MAJOR OPERATIONAL PROBLEMS.
-------
tPA UTILITY FGD SURVEY: THIRD OUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT 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 - %
AVERAGE MOISTURE CONTENT - 3!
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - %
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYP6
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
«* DISPOSAL
TYPE
TEXAS UTILITIES
KONTICELLO
7
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
7. 99.50
.0
.0
CLOSED
34.4
< 546 GPK)
FLYASH STABILIZED
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION % REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
** PROBLEHS/SOLUTIONS/COMHENTS
672
744
720
5/79 SYSTEM
6/79 SYSTEM
START DATE 2/79 fcND DATE 4/79
THE UNIT IS CURRENTLY DOWN FOR A SCHEDULED OVERHAUL. THE TOWERS HAVE
BEEN INSPECTED AND NO SCALING WAS FOUND.
START DATE 2/79 END DATE 4/79
SOKE MINOR RECYCLE PUMP LINER PROBLEMS HAV€ BEEN REPORTED.
START DATE 2/79 END DATE 4/79
DUE TO HIGH ASH LEVELS SOME PLATES IN THE ESP WERE KNOCKED OUT OF
ALIGNMENT CAUSING AN OPACITY PROBLEM.
744
720
151
-------
EPA UTILITY FCD SURVEY: THIRD QUARTER 1979
TEXAS UTILITIES: MONTJCELLO 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*• PRObLEMS/SOLUTIONS/COMNENTS
START DATE 4/79 END DATE 6/79
THE UNIT WAS IN OPERATION DURING THIS PERIOD ALTHOUGH OPERATIONAL DATA
WERE NOT AVAILABLE.
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
*• PROBLEMS/SOLU110NS/COMMENTS
START DATE 7/79 END DATE 9/79
THE ESP HAS REBUILT AND SINCE THE INITIATION OF GAS CONDITIONING WITH
AMMONIA THE OPACITY PROBLEM HAS BEEN MINIMIZED.
START DATE 7/79 END PATE 9/79
DURING THE THIRD QUARTER THE UNIT OPERATED WITHOUT ANY MAJOR PROBLEMS.
SOM€ MINOR ABSORBER RECYCLE PUMP LINER FAILURES HAVE BEEN ENCOUNTERED.
15Z
-------
EPA UTILITY FGD SURVtY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGB SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - KE/J
S02 EMISSION LIMITATION - MG/J
NET PLANT GENERATING CAPACITY - KM
GROSS UNIT GENERATING CAPACITY - RW
NET UNIT GENERATING CAPACITY W/FGD - MW
MET UNIT GENERATING CAPACITY VIO/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - Nh
** BOILER DATA
SUPPLIER
TTPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.K/S
fLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - %
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - %
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - t
RANGE CHLORIDE CONTENT - %
UTAH POWER £ LIGHT
HUNTER
1
CASTLE DALE
UTAH
A
******
******
(*»**** LB/MMBTU)
(***»*» LB/MMBTU)
4QO.O
400.0
360.0
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
** /**
822.05
130.0
1S3.
7.3
COAL
BITUMINOUS
29075.
10.00
9-12
6.50
.55
(1742000 ACFH)
< 266 F)
( 600 FT)
( 24.0 FT)
< 12500 BTU/LBJ
12,200 - 12,700
** ESP
NUMBER
SUPPLIER
** FGD SYSTEM
SALEABLE PRODUCT/THROWAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
OEVELOPRENT LEVEL
HEb/RETROFIT
Pf.RTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - K
INITIAL START-UP
1
BUELL
THROUAWAY PRODUCT
WET SCRUBBING
LIME
NONE
CHEMICO
STEARNS-ROGER
FULL SCALE
MEW
99.50
80.00
5/79
** ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
SHELL LINER MATERIAL
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
L/G RATIO - L/CU.M
PRESSURE DROP - KPA
** FANS
NUMBER
TYPE
CONSTRUCTION MATERIALS
SPRAY TOWER
5/79
CHEMICO
4
CARBON STEEL
POLYESTER FLAKEGLASS
205.51
130.0
5.7
.6
SCRUBBER FD
CARBON STEEL
( 435500 ACFH)
{ 266 F)
< 43.0 GAL/1000ACF)
( 2.5 IN-H20)
15:
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
UTAH POWER i LIGHT: HUNTER 1 (CONT.)
SERVICE - wET/DRY
CAPACITY - CU.I'i/S
DRY
. C2
< 671000 ACFM)
** «1ST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
MUMPER OF STAGES
NUMBER OF PASSES
FREEBOARD DISTANCE - M
*ASH SYSTEM
SUPERFICIAL GAS VELOCITY - W/S
4
CHEVRON
POLYPROPYLENE
HORIZONTAL
1
4
3.66 H2.0 FT)
CONTINUOUS SPRAT OPERATED ON EACH OF THE 12 SECT
.3 < 1.0 FT/S)
•* PUMPS
SERVICE
ABSORBER RECYCLE
NUMBER
16
** REHEATER
TYPE
HEATING MEDIUM
"TEMPERATURE BOOST - c
INDIRECT
STEAM
26.7
48 F)
•* REHEATER
TYPE
TEMPERATURE BOOST -
BYPASS
26.7 ( 48 F>
** WATER LOOP
TYRE
** TREATMENT
TYPE
** DISPOSAL
MATURE
TTPE
LOCATION
PERIOD MODULE AVAILABILITY OPERABILITY
5/79 SYSTEM 78.6
6/79 SYSTEM 98.0
7/79 SYSTEM 100.0
8/79 SYSTEM 100.0
9/79 SYSTEM 100.0
OPEN
FLYASH STABILIZED
FINAL
POND
ON-SITE
RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
32.8 744 311 244
96.9 7ZQ 713 698
99.2 744 738 738
100.0 744 744 744
100.0 7ZO 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 9/79 END DATE 9/79
NO MAJOR OPERATIONAL PROBLEMS WERE REPORTED BY THE UTILITY FOR THIS INIT
DURING THE THIRD QUARTER 1979.
154
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Kfc
NET UNIT GENERATING CAPACITY W/FGD - I"
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J /G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - %
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT — X
*« FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU /RETRO FIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
UTAH POWER k, LIGHT
HUNTINGTON
1
PRICE
UTAH
430. C
'W 4DO.O
366.0
COAL
BITUMINOUS
29075. ( 12500 BTU/LB)
10.00
6.50
.55
WET SCRUBBING
LIME
CHEMICO
NEU
1.6
5/78
** /* *
80.00
PARTICULATE DESIGN REMOVAL EFFICIENCY - X 99.50
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
PERIOD MODULE AVAILABILITY OPERAB1LITY
2/79 SYSTEM 90.1
3/79 SYSTEM 100.0
4/79 SYSTEM 100.0
2.5
.0
CLOSED
18.9 ( 300 GPM)
FLYASH STABILIZED
LANDFILL
RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
58.2 672 434 391
86.5 744 644 644
76. E 720 553 553
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/79
THE UTILITY REPORTED THAT THE PROBLEMS ENCOUNTERED DURING FEBRUARY-APRIL
INCLUDED LINING FAILURE, PUMP PROBLEMS AND DAMPER PROBLEMS.
START DATE 2/79 END DATE 4/79
PROBLEMS HAVE BEEN EXPERIENCED WITH DAMPER MECHANISMS CLOGGING.
5/79 SYSTEM
6/79 SYSTEM
7/79 SYSTEM
8/79 SYSTEM
100.0
62.5
79.7
30.0
92.6
54.9
79.5
27.0
744
720
744
744
689
632
742
669
689
395
591
201
155
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
UTAH POWER £ LIGHT: HUNT1NGTON 1 (CCNT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/79 SYSTEM 54.9 54.3 720 712 391
** PRObLEMS/SOLUTlONS'COMMENTS
START DATE 9/79 END DATE 9/79
THt PROBLEMS ENCOUNTERED DURING THE THIRD QUARTER 1979 INCLUDED FAILLRE
OF CONTROL VALVES AND SOME AGITATOR PROBLEMS.
156
-------
UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 4
SUMMARY OF FGD SYSTEMS BY COMPANY
TOTAL
COMPANY MANE
ALABAKA tLECTRIC COOP
ALLEGHENY POWER SYSTEM
ARIZONA 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 8 ELECTRIC
COLORADO UTE ELECTRIC ASSN.
COLUMBUS g SOUTHERN UH10 ELEC.
COMMONWEALTH EDISON
COOPERATIVE POWER ASSOCIATION
DELMARVA POWER 8 LIGHT
DUQUESNE LIGHT
EAST KENTUCKY POWER COOP
GENERAL PUBLIC UTILITIES
HOOSIER ENERGY
HOUSTON LIGHTING g POWER CO.
INDIANAPOLIS POWER 8 LIGHT
KANSAS CITY POWER * LIGHT
KANSAS POWER & LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LOUISVILLE GAS & ELECTRIC
MIDDLE SOUTH UTILITIES
MINNESOTA POWER £ LIGHT
MINNKOTA POWER COOPERATIVE
MONTANA POWER
MUSCATINE POWER i WATER
NEVADA POWER
NEW YORK STATE ELEC & GAS
NIAGARA MOHAWK POWER COOP
NORTHERN INDIANA PUB SFRVICE
NORTHERN STATES POWER
OTTER TAIL POWER
PACIFIC GAS & ELECTRIC
PACIFIC POWER & LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
POTOMAC ELECTRIC POWER
POWER AUTHORITY OF NEW YORK
PUBLIC SERVICE OF INDIANA
PUBLIC SERVICE OF NEW MEXICO
SALT RIVER PROJECT
SAN MIGUEL ELECTRIC COOP
SEMINOLE ELECTRIC
SIKESTON BOARD OF MUNIC. UTIL.
SOUTH CAROLINA PUBLIC SERVICE
SOUTH MISSISSIPPI ELEC PWR
SOUTHERN ILLINOIS POWER COOP
SOUTHERN INDIANA GAS & fLEC
SOUTHWESTERN ELECTRIC POWER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER, LIGHT & PWR
ST. JOE ZINC
TAMPA ELECTRIC
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER & LIGHT
TEXAS UTILITIES
UTAH POWER & LIGHT
WISCONSIN POWER & LIGHT
NC.
2
3
2
B
1
5
I
2
1
1
1
2
l>
1
2
1
2
1
2
2
1
2
3
4
1
1
10
6
1
1
4
1
ID
1
1
c
s
3
1
2
1
5
4
1
1
1
4
3
1
2
1
3
2
2
1
1
1
1
1
1
7
1
3
g
2
1
fU
35B.
1338.
390.
2684.
67C.
266C.
484.
794.
617.
600.
650.
894.
157?.
450.
654.
18C.
920.
500.
1600.
883.
512.
1062.
1054.
1575.
64.
364.
3533.
5340.
475.
405.
2120.
16C.
3125.
870.
100.
1547.
2340.
44C.
1600.
550.
2751.
844.
BOC.
700.
650.
1779.
840.
400.
1240.
235.
700.
24?.
484.
265.
720.
194.
205.
6C.
475.
3153.
400.
188 2.
5585.
1086.
316.
OPERATIONAL
NO.
2
1
2
2
0
0
0
1
1
0
0
a
2
0
1
0
2
0
0
0
0
1
3
3
1
0
5
0
0
1
2
0
3
0
0
1
2
0
0
0
2
1
0
0
0
2
0
0
0
0
1
2.
1
1
0
1
0
0
0
3
0
0
4
2
0
MW
358.
519.
390.
469.
0.
0.
0.
378.
617.
0.
0.
0.
822.
0.
327.
0.
920.
a.
0.
3.
0.
532.
1054.
1085.
64.
0.
1180.
0.
0.
405.
720.
a.
375.
0.
0.
115.
1480.
0.
0.
0.
1834.
120.
0.
0.
0.
711.
0.
0.
0.
0.
140.
348.
184.
265.
0.
194.
0.
0.
0.
570.
0.
0.
2585.
726.
0.
STATUS
CONSTRUCTION CONTRACT
AWARDED
NO.
0
1
0
4
1
2
2
0
0
0
1
2
0
1
1
1
0
1
0
1
0
1
0
1
0
0
3
0
1
Q
2
0
0
0
1
0
0
1
0
1
1
0
0
Q
0
2
2
1
0
1
1
0
0
0
0
0
1
1
0
1
0
1
0
1
0
MW
0.
519.
0.
7C5.
670.
1200.
484.
0.
0.
0.
650.
894.
0.
450.
327.
180.
0.
500.
0.
441.
0.
530.
0.
490.
0.
Q.
1203.
0.
475.
0.
1400.
0.
0.
0.
100.
0.
0.
44C.
0.
550.
917-
0.
0.
0.
0.
1068.
560.
400.
0.
235.
280.
0.
0.
0.
0.
3.
205.
60.
!•*
Q .
575.
0.
382 .
0.
360.
i
J .
NO*
Q
1
o
2
o
2
0
0
0
0
0
0
D
0
0
0
0
0
0
1
1
0
0
0
0
1
0
0
0
0
0
0
0
c
0
0
0
0
0
0
0
3
0
0
1
0
0
0
0
0
1
0
0
0
1
0
0
0
2
1
1
0
*
1
MU
p
\J •
300.
0.
1 510.
0.
1040.
0.
0.
0.
0.
0.
0.
0.
0.
0.
c.
0.
0.
0.
441.
512.
c.
0.
0.
0.
364.
0.
Q.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
724.
0.
0.
650.
0.
0.
0.
0.
0.
280.
0.
0.
0.
720.
0.
c .
0.
0 .
1408.
/on
HUU •
0»
750.
*
316*
PLANNED
NO.
Q
1
fi
U
1
o
1
Q
o
2
0
o
0
0
0
2
0
0
0
0
0
0
0
2
6
D
0
0
1
7
1
0
4
1
0
2
0
0
0
1
1
0
0
1
0
2
0
0
0
1
0
0
0
0
1
1
Q
2
3
o
MW
•
.
.
p
L .
.
44n
•• •* VJ .
.
416 .
C.
6CO.
0.
0.
750.
0.
0.
0.
0.
0.
16CO.
o.
0.
o.
c.
0.
0.
0.
1150.
5340.
0.
0.
0.
160.
2750.
870.
0.
1422.
860.
0.
16CO.
0.
0.
0.
SCO.
7CO.
0.
0.
Z.^P.
c.
124C.
C.
0.
0.
3CQ.
.
0.
o.
.
.
475.
6CO.
C.
15 CO.
2250.
0.
o.
TOTALS
111 72165.
56 19387-
42 17250.
19 9415.
44 26113.
NOTE - PLANfiED STATUS INCLUDES LETTER CF INTENT SIG
AND CONSIDERING ONLY FC-D SYSTEMS
NED, REQUESTING/EVALUT1NG BIDS,
157
-------
EPA UTILITY F(jO SURVEY: THIRD QUARTER 197Q
SECTION ?
SUGARY OF FGD SYSTEMS BY SYSTEM SUPPLIER
TOTAL
TYSTEM SUPPLIER /PROCESS
AOL/COMDUSTION EQUIP ASSOCIATE
DUAL ALKALI
LIKE
LIME/ALKALINE FLYASH
SODIUM CARBONATE
TOTAL -
AIR CORRECTION DIVISION, UOF
LIME
LIMESTONE
LIME/LIMESTONE
SODIUM CARBONATE
TOTAL -
AMERICAN AIR FILTER
LIME
LIMESTONE
TOTAL -
BABCOCK S UILCOX
LIME
LIMESTONE
LIME/SPRAY DRYING
TOTAL -
BUELL/ENVIROTECH
DUAL ALKALI
TOTAL -
BUREAU OF MINES
CITRATE
TOTAL -
CHEKICO
LIME
LIMESTONE
LIME/ALKALINE FLYASH
LIME/LIMESTONE
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLYASH
LIME/LIMESTONE
TOTAL -
DAVY POyERGAS
WELLKAN LORD
TOTAL -
FKC CORPORATION
DUAL ALKALI
TOTAL -
JOY MFG. CO, yESTERN PRECIPITA
LIME/SPRAY DRYING
TOTAL -
flTSUblSHI INTERNATIONAL
LIMESTONE
TOTAL -
NO.
1
1
5
3
10
2
it
1
1
8
6
1
7
3
7
1
11
1
1
1
1
8
3
4
1
16
4
r
2
2
2
17
fc
6
1
1
1
1
c
2
KW
288.
500.
2525.
375.
3688.
822.
1896.
10.
550.
3278.
1673.
280.
1953.
1688.
2477.
600.
4765.
617.
617.
60.
60.
4140.
2208.
895.
10.
7253.
442.
2932.
1480.
654.
70S.
6216.
2074.
2074.
265.
265.
440.
440.
S82.
882.
OPERATIONAL
MO.
1
0
3
3
7
2
2
1
0
5
3
0
3
1
3
0
4
1
1
0
0
6
1
0
1
8
4
3
2
1
0
10
3
3
1
1
0
0
0
0
MW
288.
0.
1U5.
375.
1788.
822.
726.
10.
0.
1558.
694.
0.
694.
519.
1.198.
0.
1717-
617.
617.
0.
0.
3480.
800.
0.
10.
4290.
442.
1085.
1480.
327.
0.
3334.
826.
826.
265.
265.
0.
0.
0.
0.
CONSTRUCTION
NO-
0
1
2
0
3
0
1
0
1
2
3
0
3
2
3
0
5
0
0
1
1
1
0
3
0
4
0
3
0
1
2
6
3
3
0
0
0
0
1
1
MW
0.
500.
1400.
0.
1900.
0.
450.
0.
550.
1000.
979.
0.
979.
1169.
915.
0.
2084.
0.
0.
60.
60.
360.
0.
579.
0.
939.
0.
1447.
0.
327.
708.
2482.
1248.
1248.
0.
0.
0.
0.
441.
441.
CONTRACT
AWARDED
NO.
0
0
0
0
0
0
1
0
0
1
0
1
1
0
1
1
2
0
0
0
0
1
2
1
0
4
0
1
0
0
0
1
0
0
0
0
1
1
1
1
MW
0.
0.
o.
0.
0.
0.
720.
0.
0.
720.
0.
280.
280.
0.
36*.
600.
964.
0.
0.
0.
0.
300.
1408.
316.
0.
2024.
0.
400.
0.
0.
0.
400.
0.
0.
0.
0.
440.
440.
441.
441.
153
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 5
SUMMARY OF FGD SYSTEMS BY SYSTEM SUPPLIER
TOTAL
SYSTEM SUPPLIER/PROCESS
NONE
LIMESTONE
TOTAL -
PEABODY PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
PULLMAN KELLOGG
LIME
LIMESTONE
TOTAL -
RESEARCH COTTRELL
LIMESTONE
TOTAL -
RILEY STOKER/ENVIRONEERING
LIMESTONE
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE
TOTAL -
TENNESSEE VALLEK AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
LIME
MAGNESIUM OXIDE
TOTAL -
VENDOR NOT SELECTED
LIMESTONE
TOTAL -
WHEELABRATOR-FRYE/R.I.
AQUEOUS CARBONATE/SPRAY DRYING
TOTAL -
NO.
1
1
4
1
5
1
4
5
12
12
3
3
1
1
1
1
2
4
6
1
1
1
1
KW
595.
595.
1252.
475.
1727-
917.
1880.
2797.
4860.
4860.
626.
626.
100.
100.
550.
550.
1510.
844.
2354.
512.
512.
440.
440.
OPERATIONAL
NO.
1
1
2
0
2
0
0
0
6
6
3
3
0
0
1
1
0
1
1
0
0
0
0
MW
595.
595.
358.
0.
358.
0.
0.
0.
2049.
2049.
626.
626.
0.
0.
550.
550.
0.
120.
120.
0.
0.
0.
0.
CONSTRUCTION
NO.
0
0
2
1
3
1
3
4
5
5
0
0
1
1
0
0
0
0
0
0
0
1
1
Ntf
0.
0.
894.
475.
1369.
917.
1230.
2147.
2061.
2061.
0.
0.
100.
100.
0.
0.
Q.
0.
0.
0.
0.
440.
440.
CONTRACT
AWARDED
NO.
o
0
0
o
c
0
1
1
1
1
0
0
0
0
0
0
2
3
5
1
1
0
0
MU
.
0.
0.
0«
0.
0.
650.
650.
750.
750.
0.
0.
0.
0.
0.
0.
1510.
724.
2234.
512.
512.
0.
0.
TOTAL -
117 46052.
56 19387.
42 17250.
19 9415.
159
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 6
SUMMARY OF FGD SYSTEMS BY PROCESS
TOTAL
OPERATIONAL
STATUS
CONSTRUCTION CONTRACT
AWARDED
PLANNED
PROCESS
AQUEOUS CARBONATE
CITRATE
MAGNESIUM OXIDE
WELLHAN LORD
SUBTOTAL - SALEABLE PRODUCT
AQUEOUS CARBONATE/SPRAY DRYING
DUAL ALKALI
LIME
LIMESTONE
LIMESTONE/ALKALINE FLVASH
LIME/ALKALINE FLTASH
LIME/LIMESTONE
LIME/SPRAY DRYING
PROCESS NOT SELECTED
SODIUM CARBONATE
SUBTOTAL - THROWAWAY PRODUCT
TOTALS
SALEABLE Z OF TOTAL KW
NC.
1
1
5
6
1J
1
1
27
63
I
•\z
5
Z
32
4
148
161
MU
100.
6Q.
1444.
2074.
3678.
44C.
1170.
11692.
27716.
1480.
4549.
1328.
1040.
18147.
925.
68487.
72165.
5
NO.
0
0
1
3
4
0
3
16
22
2
4
2
0
0
3
52
56
MU
o.
o.
120.
526.
946.
0.
1170.
5957.
7987.
1480.
1452.
20.
0.
0.
375.
18441.
19387.
5
NO.
1
1
0
3
5
1
0
8
18
0
7
2
0
0
1
37
42
MW
100.
60.
0.
1248.
1408.
440.
0.
39C5.
7438.
0.
2781.
708.
0.
0.
550.
15842.
17250.
8
NO.
0
0
3
0
3
0
0
3
10
0
1
0
2
0
0
16
19
MW
0.
0.
724.
0.
724.
0.
0.
1810.
5525.
0.
316.
0.
1040.
0.
0.
8691.
9415.
8
NO.
0
0
1
0
1
0
0
0
10
0
0
1
0
32
0
43
44
MU
0.
0.
6CO.
0.
600.
0.
0.
0.
6766.
0.
0-
«co.
o.
18147.
0.
25513.
26113.
2
160
-------
ePA UTILITY FGD SURVEY: THIRD QUARTER 1979
StCTION 7
SUMMARY OF OPERATIONAL (GD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT MAKE
DUAL ALKALI
A.B. BROWN
" CANE RUN
NEWTON
LIME
BRUCE MANSFIELD
BRUCE MANSFIELD
CANE RUN
CANE RUN
CONESV1LLE
CONESVILLE
ELRAMA
GREEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNT1NGTON
BILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS
LIMESTONE
APACHE
APACHE
CHOLLA
CHOLLA
DUCK CREEK
JEFFREY
LA CYGNE
LAURENCE
LAWRENCE
MARION
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MONTICELLO
PETERSBURG
R.D. BORROW
R.D. MORROW
SOUTHWEST
TOMBIGBEE
TOMBIGBEE
WIDOWS CREEK
WINYAH
LIMESTONE/ALKALINE FLYASH
SHEBBURNE
SHERBURNE
LIME/ALKALINE FLYASH
COAL CREEK
COLSTRIP
COLSTRIP
MILTON R. YOUNG
UNIT NO.
1
6
1
1
2
4
5
5
6
1-4
1-3
3
4
1
1
3
6
1-6
1
2
3
1
2
1
1
1
4
5
A
1
2
3
3
3
1
2
1
2
3
8
2
1
2
1
1
2
2
CAPACITY
MW
265.
288.
617.
117Q.
917.
917.
188.
190.
411.
411.
510.
64.
90.
90.
360.
366.
442.
72.
410.
519.
5957.
195.
195.
119.
350.
378.
540.
874.
125.
420.
184.
595.
595.
595.
800.
532.
124.
124.
194.
179.
179.
550.
140.
7987.
740.
740.
148Q.
327.
360.
360.
405.
INITIAL
STARTUP
3/79
4/79
9/79
12/75
7/77
8/76
12/77
1/77
6/,78
10/75
9/75
11/72
8/72
5/79
5/78
8/78
4/73
7/73
3/79
8/78
6/79
10/73
4/78
9/76
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
3/76
4/77
8/79
9/75
5/76
9/77
COMMERCIAL
STARTUP
o/ c
O/ 0
12/79
6/76
O/ 0
9/77
5/79
2/77
O/ 0
10/75
6/76
O/ 0
O/ 0
O/ 0
O/ 0
3/79
O/ 0
O/ 0
O/ 0
1/79
4/79
12/73
01 0
8/78
O/ 0
6/73
O/ 0
O/ 0
O/ 0
10/78
O/ 0
O/ 0
10/78
O/ 0
O/ 0
01 0
O/ 0
O/ 0
01 0
1 /78
O/ 0
5/76
4/77
O/ 0
11/75
10/76
6/78
1452.
-------
EPA UTILITY FOD SURVEY: THIRD QUARTER 1979
SECTION 7
SUMMARY OF OPERATIONAL FGD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
LIME/LIMESTONE
SHAwNEE
SHAwNEE
UNIT MO.
10A
10B
CAPACITY
MW
10.
10.
INITIAL
STARTUP
4/72
4/72
COMMERCIAL
STARTUP
O/ 0
O/ 0
MAGNESIUM 0X1OE
EDOYSTONE
SODIUM CARBONATE
REID GARDNER
REID GARDNER
REID GARDNER
1A
20.
120.
120.
125.
125.
125.
9/75
4/74
4/74
6/76
9/75
O/ 0
O/ 0
7/76
375.
WE.LLMAN LORD
DEAN H. MITCHELL
SAN JUAN
SAN JUAN
11
1
2
11S.
361.
350.
826.
7776
4/78
8/.7S
6/77
O/ 0
O/ 0
TOTAL
19387.
162
-------
DUAL. ALKALI
UTILITY FGD SURVEY: THIRD QUARTER 1979
FOR OPERATIONAL FGD SYSTEMS
ST*">-IZED UNSTABILIZED
TYPE
BYPRODUCT-
DISPOSITION
*.B. BROWN
CANE RUN
NEWTON
LIKE
BRUCE MANSFIELD
BRUCE MANSFIELD
CANE RUN
CANE RUN
CONESVILLE
CONESVILLE
ELRAMA
GREEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTINGTON
WILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS
LIMESTONE
APACHE
APACHE
C HOLLA
CHOLLA
DUCK CREEK
JEFFREY
LA CYGNE
LAWRENCE
LAURENCE
MARION
MARTIN LAKE
HARTIN LAKE
MARTIN LAKE
NONTICELLO
PETERSBURG
R.D. nORROW
R.D. MORROW
SOUTHWEST
TOMBIGBEE
TOMBIGBEE
WIDOWS CREEK
WINYAH
i
6
1
1
2
4
5
S
6
1-4
1-3
3
4
1
1
3
6
1-6
1
2
3
1
2
1
1
1
4
5
4
1
a
3
3
3
1
2
1
2
3
8
i
LIMESTONE/ALKALINE FLYASH
SHER6URNE
SHERBURNE
HflE/ALKALINE FLYASH
COAL CREEK
COLSTRIP
COLSTRIP
WILTON R. YOUNG
1
i
1
1
2
2
LINED POND
LANDFILL
1
2
4
5
5
6
1-4
1-3
3
4
1
1
3
6
1-6
1
LANDFILL
LANDFILL
LINED POND
LINED POND
LANDFILL
LANDFILL
LANDFILL
POND
POND
POND
LANDFILL
POND
POND
LANDFILL
I I«E/LI PIE STONE
SHAWNEE
SHAUNEE
POND
POND
POND
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
LANDFILL
LANDFILL
LANDFILL
LINED POND
LINED POND
LINED POND
LINED POND
LINED POND
LINED POND
POND
POND
POND
POND
LIMED POND
UNLINED POND
POND
POND
POND
POND
RINEFILL
10A
10B
163
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 8
SUMMARY Of END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGO SYSTEMS
PROCESS/
UNIT HARE
THROW AWAY
UNIT NO STABILIZED (JNSTABI LI ZED
TYPE
-BYpRODUCT-
OISPOS1TICN
MAGNESIUM OXIDE
EDDYSTONE
1A
SULFURIC ACID
SODIUM CARBONATE
REID GARDNER
REID GARDNER
REID GARDNER
WELLMAN LORD
DEAN H. MITCHELL
SAN JUAN
SAN JUAN
11
1
2
POND
POND
POND
POND
MINE FILL
ELEMENTAL SULFUR
ELEMENTAL SULFUR
ELEMENTAL SULFUR
MARKETED
MARKETED
164
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAKt/
UNIT NAME UNIT NO.
ALABAMA ELECTRIC COOP
TOMBIGBEE ~i
ALABAMA ELECTRIC COOP
TOMBIGBEE 3
ALLEGHENY POWER SYSTEM
PLEASANTS 1
ARIZONA ELECTRIC POWER COOP
APACHE 2
ARIZONA ELECTRIC POWER COOP
APACHE 3
ARIZONA PUBLIC SERVICE
CHOLLA 1
ARIZONA PUBLIC SERVICE
CHOLLA 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEWTON ' 1
COLUMBUS & SOUTHERN OHIO ELEC.
CONESVILLE 5
COLUMBUS & SOUTHERN OHIO ELEC-
CONESVILLE 6
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
OUQUESNE LIGHT
ELRAMA 1-4
DUBUESNE LIGHT
PHILLIPS 1-6
INDIANAPOLIS POWER & LIGHT
PETERSBURG 3
KANSAS CITY POWER & LIGHT
HAWTHORN 3
KANSAS CITY POWER 8 LIGHT
HAWTHORN 4
KANSAS CITY POWER 8 LIGHT
LA CYGNE 1
KANSAS POWER 6 LIGHT
JEFFREY 1
KANSAS POWER & LIGHT
LAWRENCE 4
KANSAS POWER £ LIGHT
LAWRENCE 5
KENTUCKY UTILITIES
GREEN RIVER 1-3
LOUISVILLE GAS fc ELECTRIC
CANE RUN 4
LOUISVILLE GAS & ELECTRIC
ffiwp DIIW c
NEW OR I
RETROFIT
NLU
NEW
NEW
NEW
NEW
RETROFIT
MEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
:APACITY
NW
179.C
179.0
519.0
195.0
195.0
119.0
350.0
378.0
617.0
411.0
411.0
327.0
510.0
410.0
532.0
90.0
90.0
S74.0
540.0
125.0
420.0
64.0
18S.O
190.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
PtABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
BABCOCK 8 WlLCOX
LIMESTONE
RESEARCH COTTHELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RILE* STQKER/EMVIRONEERING
DUAL ALKALI
BUELL/ENVIRflTECH
LIME
AIR CORRECTION DIVISION, UOP
LIME
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIKE
CHEMICO
LIME
CHEMICO
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME
COMBUSTION .ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK 8 WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIKE
COP'faUST ION ENGINEERING
START-UP
DATE
9/78
6/79
3/79
8/78
6/79
10/73
4/78
9/76
9/79
1/77
6/78
8/79
10/75
7/73
12/77
11/72
8/72
2/73
8/78
1/76
11/71
9/75
8/76
1 2/77
165
-------
EPA UTILITY FGD SURVEY: THIRD QUARTtR 1979
SECTION 9
SUGARY OF FGC SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
LOUISVILLE GAS (. ELECTRIC
CANE RUN 6
LOUISVILLE GAS & ELtCTRIC
MILL CREEK 3
LOUISVILLE GAS £ ELECTRIC
PADDY'S RUN 6
MINNKOTA PO*ER COOPERATIVE
WILTON R. YOUNG 2
MONTANA POWER
COLSTRIP 1
MONTANA POyER
COLSTRIP i
NEVADA POWER
REID GARDNER 1
NEVADA POWER
REID GARDNER 2
NEVADA POWER
REID GARDNER 2
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
NORTHERN STATES POWER
SHERBURNE 1
NORTHERN STATES POWER
SHERBURNE 2
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
PHILADELPHIA ELECTRIC
EBDYSTONE 1A
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 2
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 2
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW 1
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW i
SOUTHERN ILLINOIS POWER COOP
MARION 4
SOUTHERN INDIANA &A S & ELEC
A.B. BROWN 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
TENNESSEE VALLEY AUTHORITY
NEW OR
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
MEW
NEW
RETROFIT
CAPACITY
MW
288.0
44?. 0
72.0
405.0
360.0
360.0
125.0
125.0
125.0
115.0
740.0
740.0
917.0
917.0
120.0
361.0
350.0
140.0
124.0
124.0
134.0
265.0
194.0
10. C
PROCESS/
SYSTEM SUPPLIER
DUAL ALKALI
ADL/COMBUSTION EQUIP ASSOCIATE
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
LIME /ALKALINE FLTASH
ADL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
UELLMAN LORD
DAVY POWER&AS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLTASH
COMBUSTION ENGINEERING
LIME
CHEMICO
LIME
CHEMICO
MAGNESIUM OXIDE
UNITED ENGINEERS
UELLMAN LORD
DAVY POWERGAS
WELLMAN LORD
DAVY POwEHGAS
LIMESTONE
BABCOCK & W1LCOX
LIMESTONE
RILEY STOKEH/ENVIRONEERING
LIMESTONE
RILEY STOKER/ENVIRONEERING
LIWESTONE
BABCOCK 8 WILCOX
DUAL ALKALI
FMC CORPORATION
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIKE/LIMESTONE
START-UP
DATE
4/7?
8/78
4/73
9/77
9/75
5/76
4/74
4/74
6/76
7/76
3/76
4/77
12/75
7/77
9/75
4/78
8/78
7/77
8/78
6/79
5/79
3/79
4/77
4/72
AIR CORRECTION DIVISION, UOP
166
-------
EPA UTILITY fGD SURVEY: THIRD QUARTER 1979
SfcCTION 9
OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UMT NAKE
NEW OR CAPACITY PROCESS/
UMT NO. RETROFIT MW SYSTEM SUPPLIER
START-IP
DATE
TENNESSEE VALLEY AUTHORITY RETROFIT
SHAWNEE IQB
TENNESSEE VALLEY AUTHORITY RETROFIT
WIDOWS CREEK 8
TEXAS UTILITIES NEW
MARTIN LAKE 1
TEXAS UTILITIES NEW
MARTIN LAKE 2
TEXAS UTILITIES NEW
MARTIN LAKE 3
TEXAS UTILITIES SEW
MONTICELLO 3
UTAH POWER 8 LIGHT NEW
HUNTER 1
UTAH POWER 8 LIGHT NEW
HUNTINGTON 1
10.0 LIME/LIMESTONE
CHEMICO
550.0 LIMESTONE
TENNESSEE VALLEY AUTHORITY
595.0 LIMESTONE
NONE
595.C LIMESTONE
RESEARCH COTTRELL
595.0 LIMESTONE
RESEARCH COTTRELL
800.0 LIMESTONE
CHEMICO
360.C LIME
CHEMICO
366.0 LIME
CHEMICO
4/72
5/77
4/77
5/78
2/79
5/78
5/79
5/78
167
-------
EPA UTILITY F&D SURVEY: THIRD CUARTER 1979
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
ALLEGHENY POWER SYSTEM
PLEASANTS 2
ARIZONA PUBLIC SERVICE
CHOLLA 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZONA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
ASSOCIATED ELECTRIC COOP
THOMAS HILL 3
BASIN ELECTRIC POWER "OOP
LARAMIE RIVER 1
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 2
BIG RIVERS ELECTRIC
GREEN 1
BIG RIVERS ELECTRIC
GREEN 2
CINCINNATI GAS & ELECTRIC
EAST BEND 2
COLORADO UTE ELECTRIC ASSN>
CRAIG 1
COLORADO UTE ELECTRIC ASSN.
CRAIG 2
COMMONWEALTH EDISON
POWERTON 51
COOPERATIVE POWER ASSOCIATION
COAL CREEK 2
DELHARVA POWER g LIGHT
DELAWARE CITY 1-3
EAST KENTUCKY POWER COOP
SPURLOCK 2
HOOSIER ENERGY
HERO* 2
INDIANAPOLIS POWER & LIGHT
PETERSBURG 4
KANSAS POWER & LIGHT
JEFFREY 2
LOUISVILLE GAS & ELECTRIC
MILL CREEK 1
LOUISVILLE GAS & ELECTRIC
MILL CREEK 2
LOUISVILLE GAS & ELECTRIC
HILL CREEK A
MINNESOTA POWER 8 LIGHT
NEW OR
RETROFIT
NEW
MEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEU
MEW
NEW
NEW
NEW
NEU
NEW
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
CAPACITY
MW
519.0
126.0
175.0
175.0
229.0
670.0
600.0
600.0
242. 0
242- C
650.0
447.0
447-.0
450.0
327.0
180.0
500.0
441.0
530.0
490.0
35?. 0
350.0
495.0
475.0
PROCESS/
SYSTEM SUPPLIER
LIME
BABCOCK & WILCOX
LIMESTONE
RESEARCH COTTRELL
LIME/ALKALINE FLYASH
CHEMlcO
LIME/ALKALINE FLYASH
CHEMICO
LIME/ALKALINE FLYASH
CHEMICO
LIMESTONE
PULLMAN KELLOCG
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
L1HE
BABCOCK 8 WILCOX
LIMESTONE
PEABODY PRO-CESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
WELLMAN LORD
DAW POWERGAS
LIME
ADL/COMBUSTION EQUIP ASSOCIATE
LIMESTONE
MITSUBISHI INTERNATIONAL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
COMBUSTION ENGINEERING
LIME/LIMESTONE
COMBUSTION ENGINEERING
LIKE/LIMESTONE
COMBUSTION ENGINEERING
LIKE
AMERICAN AIR FILTER
LIME/ALtCALIWE FLYASH
START-IP
DATE
9/80
6/80
0/79
0/79
0/79
1/82
4/80
10/80
10/79
6/80
10/81
1/80
8/79
11/79
10/80
4/80
10/80
1/82
10/83
6/80
4/81
4/82
7/81
2/80
PEABODY PROCESS SYSTEMS
168
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME
MONTANA POWER
COLSTRIP
MONTANA POWER
COLSTRIP
UNIT NO.
7
4
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
OTTER TAIL POWER
COYOTE
PACIFIC POWER E LIGHT
JIM BRI06ER
PENNSYLVANIA POWER
BRUCE MANSFIELD
PUBLIC SERVICE OF NEW
SAN JUAN
PUBLIC SERVICE OF NEW
SAN JUAN
SALT RIVER PROJECT
CORONAOO
SALT RIVER PROJECT
CORONADO
1
4
3
MEXICO
3
MEXICO
4
t
2
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SIKESTON BOARD OF MUNIC. UT1L.
SIKESTON 1
SOUTH CAROLINA PUBLIC
WINYAH
SERVICE
3
SgRINGFlELD WATER, LIGHT & PWR
DALLKAN 2
ST. JOE ZINC
G.F. WEATON
1
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TEXAS POKER 8 LIGHT
SANDOW
UTAH POWER & LIGHT
HUNTER
t,
•>
NEW OR CAPACITY
RETROFIT MW
NEW
NEW
RETROFIT
HEW
NEU
MEW
NEW
MEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
700.0
700. D
100.0
440. 0
550.0
917.0
534.0
534.0
28o.o
280.0
400.0
235. 0
280.0
205.0
60.0
575.0
38?. 0
360.0
PROCESS/
SYSTEM SUPPLIER
LINE/ALKALINE FLYASH
ADL/COMBUSTION EOUIP ASSOCIATE
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
AQUEOUS CARBONATE
ROCKWELL INTERNATIONAL
AQUEOUS CAR60NATE/SPRAY DRYING
WHEELABRATOR-FRYE/R.l.
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
LIME
PULLMAN KELLOGG
WELLMAN LORD
DAVY POWERGAS
WELLMAN LORD
DAVY POWERGAS
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BABCOCK 8 yiLCOX
LIMESTONE
BABCOCK & WILCOX
LIMESTONE
BABCOCK 8 WILCOX
LIMESTONE
RESEARCH COTTRELL
CITRATE
BUREAU OF WINES
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
CHEM1CO
START-OP
DATE
1/84
0/64
4/82
3/81
9/79
5/8C
12/79
1/82
11/79
1/80
7/80
1/81
5/80
7/80
11/79
10/80
7/80
6/EO
If 9
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
StCTION 11
OF CONTRACT AWARDED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UMT NO.
ALLEGHENY POWER SYSTEM
MITCHELL 33
ARIZONA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUDLIC SERVICE
FOUR CORNERS 5
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 1
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 3
HOOSIER ENERGY
HERO* 1
HOUSTON LIGHTING & POWER CO.
W.A. PARISH 6
LAKELAND UTILITIES
MCINTOSH 3
PHILADELPHIA ELECTRIC
CROMBY
PHILADELPHIA ELECTRIC
EDOYSTONE la
PHILADELPHIA ELECTRIC
EDDTSTONE 2
PUBLIC SERVICE OF INDIANA
GIBSON 5
SOUTH CAROLINA PUBLIC SERVICE
WINTAH ^
SOUTHWESTERN ELECTRIC POWER
HENRY W. PERKEY 1
TENNESSEE VALLEY AUTHORITY
PARADISE 1
TENNESSEE VALLEY AUTHORITY
PARADISE 2
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
TEXAS UTILITIES
MARTIN LAKE 4
WISCONSIN POWER 8 LIGHT
NEW OR
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
CAPACITY
MW
300.0
755.0
7S5.C
440.0
600.0
441.0
512.0
364.0
150.0
240.0
334.0
650.0
280.0
720.0
704.0
704.0
400.0
750.0
316.0
PROCESS/
SYSTEM SUPPLIER
LIME
CHEKICO
LIHE
UNITED ENGINEERS
LIME
UNITED ENGINEERS
LIME/SPRAY DRYING
JOY MFG. COi WESTERN PRECIPITA
LIME/SPRAY DRYING
BABCOCK & WItCOX
LIMESTONE
MITSUBISHI INTERNATIONAL
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
BAECOCK 8 WILCOX
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
AIR .CORRECTION DIVISION, UOP
LIMESTONE
CHEMICO
LIMESTONE ^"
CHEMICO
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH COTTRELL
LIME/ALKALINE FLYASH
START-UP
DATE
8/82
0/82
0/82
11/81
7/81
4/81
11/82
10/81
6/8C
6/8C
6/8C
0/82
5/81
12V83
6/82
3/82
1/82
0/85
1/82
CHEMICO
170
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
REQUESTING/ EVALUATING
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
MIDDLE SOUTH UTILITIES
ARKANSAS COAL 5
MIDDLE SOUTH UTILITIES
ARKANSAS COAL fc
KIDDLE SOUTH UTILITIES
LOUISIANA COAL 1
MIDDLE SOUTH UTILITIES
LOUISIANA COAL 2
KIDDLE SOUTH UTILITIES
MISSISSIPPI COAL 1
MIDDLE SOUTH UTILITIES
MISSISSIPPI COAL 2
MUSCATINE POWER 8 WATER
MUSCATINE 9
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
NORTHERN INDIANA PUB SERVICE
SCHAHFER 18
NORTHERN STATES POWER
SHERBURNE 3
SEMINOLE ELECTRIC
SEMINOLE 1
SEMINOLE ELECTRIC
SEHINOLE 2
TAMPA ELECTRIC
BIG BEND 4
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE 1-10
TEXAS POWER 8 LIGHT
TWIN OAKS 1
TEXAS POWER 6 L16HT
TWIN OAKS Z
TEXAS UTILITIES
FOREST GROVE 1
NEW OP
RETROFIT
BIDS
NEW
NEW
NEW
MEW
NEW
NEW
NCW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
CAPACITY
MU
416.0
890.0
890.0
890.0
890.0
890. C
890.0
160.0
421.0
421.0
860.0
620.0
620.0
475.0
600.0
750.0
750.0
750.0
PROCESS/
SYSTEM SUPPLIER
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 HOT 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
COMBUSTION ENGINEERING
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
MAGNESIUM OXIDE
TVA/UMTED ENGINEERS
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
START-UP
DATE
1/84
1/86
1/8fi
0/86
0/88
0/85
0/87
9/82
6/83
6/85
5/84
6/83
6/85
3/85
0/82
8/84
8/85
0781
CONSIDERING Ffit> SYSTEMS
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 2
CENTRAL MAINE POWER
SEARS ISLAND 1
COLUWEUS & SOUTHERN OHIO ELEC.
POSTON 5
COLUMBUS & SOUTHERN OHIO ELEC.
POSTON fc
RfMFDAI PliF.ITr I IT 1 1 TTTFS
NEW
NEW
NEW
NEW
NEW
440.0
600. C
375.0
375.0
800. C
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMt/LI«ESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
11/83
11/87
0/83
0/8S
12/88
VENDOR NOT SELECTED
171
-------
EPA UTILITY FED SURVEY: THIRD QUARTER 1979
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
GENERAL PUBLIC UTILITIES
SEUAPD 7
LOUISVILLE &AS & ELECTRIC
TRIMBLE COUNTY 1
LOUISVILLE GAS & ELECTRIC
TRIHBLE COUNTY 2
NEVADA POWER
HARRY ALLEN 1
NEVADA POWER
HARRY ALLEN 2
NEVADA POWER
HARRY ALLEN 3
NEVADA POWER
HARRY ALLEN 4
NEVADA POWER
REID GARDNER 4
NEVADA POWER
WARNER VALLEY 1
NEVADA POWER
WARNER VALLEY 2
NEW YORK STATE ELEC & GAS
SOMERSET 1
NORTHERN INDIANA PUB SERVICE
BAILLY 7
NORTHERN INDIANA PUB SERVICE
BAILLY 8
PACIFIC GAS 8 ELECTRIC
MONTE ZUMA 1
PACIFIC GAS 8 ELECTRIC
MONTE ZUMA 2
POTOMAC ELECTRIC POWER
01CKERSON A
POWER AUTHORITY OF NEW YORK
ARTHUR KILL
SALT RIVER PROJECT
CORONADO 3
SOUTHERN ILLINOIS POWER COOP
MARION 5
TEXAS UTILITIES
HILL CREEK 1
TEXAS UTILITIES
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
NW
800.0
575.0
575.0
500.0
500.0
500.0
500.0
250.0
250.0
250.0
870.0
190.0
AQO. C
800.0
800.0
800.0
700.0
280.0
300.0
750.0
750.0
PROCESS/
SYSTEM SUPPLIER
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDO" 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
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
START-UP
DATE
12/87
7/8*
7/86
6/86
6/87
6/88
6/85
0/83
6/85
6/86
6/84
O/ C
o/ c
6/86
6/87
0/87
11/87
0/84
0/84
0/85
0/86
BILL CREEK
VENDOR NOT SELECTED
172
-------
tPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 13
TOTAL FGD UNITS AND CAPACITY (MW) INSTALLED BY YEAR
YEAR
1968
1969
1971
1972
1973
197*.
1975
1976
1977
1976
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
UNDEFINED
NEt, ON LINE
NO. f'U
1
C
1
9
t
t
6
6
1C
13
21
22
11
17
7
9
8
7
8
4
2
IE
UO.
0.
536.
671 .
1938.
606.
2C1E.
3786.
4674.
4736.
6795.
3629.
5053.
8126.
3356.
5451.
4906.
4655.
5950.
3080.
875.
5030.
TERMINATED
NO . MW
0
1
0
0
1
3
3
3
1
0
1
0
0
0
0
0
0
0
0
0
0
0 .
140.
0.
0.
175.
340.
1637.
850.
47.
0.
23.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
TOTAL
NO.
1
G
3
12
19
19
22
27
36
49
69
91
102
119
12fc
135
143
150
158
162
164
ON LINE
MW
140.
0.
536.
1207.
2970.
3236.
361E.
5554.
1018D.
14916.
21688.
30317.
35370.
43496.
46852.
52303.
57209.
61864.
67814.
70894.
71769.
173
-------
EPA UTILITY FOD SURVEY: THIRD QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY ~ Mw
NET UNIT GENERATING CAPACITY W/FGD - NW
NET UNIT GENERATING CAPACITY WO/FGfc - MW
EQUIVALENT SCRUBBED CAPACITY - MW
COMMONWEALTH EDISON
WILL COUNTY
1
ROMEOVILLE
ILLINOIS
86.
774.
11*7.0
167.0
137.0
C .200 LB/HMBTU)
( 1.600 LB/MMBTU)
** BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM DOILER 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 - 2
RANGE ASH CONTENT - %
AVERAGE MOISTURE CONTENT - %
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
BABCOCK 8 WILCOX
CULIC
0/55
363.36
179.4
107.
3.8
COAL
22260.
7.40
3-16
1.50
0.3 - 4.5
********
( 770000 ACFM)
( 355 F)
C 350 FT)
( 12.4 FT)
( 9570 BTU/LB)
9,100 - 10,500
«* ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY - 51
FLUE GAS TEMPERATURE - C
** PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
TYPE OF NOZZLES
FLUE GAS CAPACITY - CU.H/S
FLUE GAS TEMPERATURE - C
LlGUiD REClRCUtATioN RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTKULATt INLET LOAD - G/CU.H
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
1
COLD SIDE
WESTERN PRECIPITATION
79.0
179.4 C 355 F)
ADJUSTABLE THROAT VENTURI
BABCOCK & WILCOX
CARBON STEEL
PLASITE AND KAOCRETE
STAINLESS STEEL
181.7
179.4
365.4
2.4
36.6
.4
98.0
385000 ACFB)
355 F)
5800 GPW)
18.0 GAL/1000ACF)
***** JN-H20)
120.0 FT/S)
.16 6R/SCF)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/75
A
B
SYSTEM
94.0
.0
90.2
.0
81.2
.0
744 609
174
-------
tPA UTILITY FGD SUKVEY: THIRD QUARTER 1979
COMMONWEALTH tDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER"^""Ipl"
S02 PART. HOURS HOURS HOURS FACTOR
** PR06LEMS/SOLUTIONS/CCWENTS
START DATE 3/75 END DATE 3/75
A VENTURI HOSE LEAK FORCED MODULE A OUT ONCE.
START DATE 3/75 END DATE 3/75
MODULE B WAS OUT OF SERVICE TWICE FOR NO DEMAND AND ONCE AS A RESULT OF AN
ACCIDENTAL 50 MINUTE TRIP.
START DATE 3/75 END DATE 3/75
COAL BURNED THIS MONTH AVERAGED LESS THAN ONE PERCENT SULFUR.
4/75 A
a
SYSTEM
37.0
.0
39,
.0
35.0
.0
720
638
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 3/75 END DATE 4/75
CHICAGO FLY ASH IS TREATING MATERIAL FROM THE SCRUBBER WITH LINE AND FLY
ASH AND DUMPING IT INTO THE HOLDING BASIN.
START DATE 4/75 END DATE 4/75
A BOILER OUTAGE FORCED MODULE A OUT OF SERVICE ONCE THIS MONTH (MODULE 6
WAS ALREADY OUT OF SERVICE).
START DATE 4/75 END DATE 4/75
COAL BURNED THIS MONTH WAS RECLAIM COAL AND VARIED IN SULFUR CONTENT.
5/75
A
B
SYSTEM
84.5
37.1
84.5
37.1
84.5
37.1
744
744
** PROBLEMS/SOLUTIONS/COMHENTS
START DATE
START DATE
START DATE
START DATE
START DATE
START DATE
START DATE
4/73 END DATE 5/75
MODULE B WAS IN SERVICE ON MAY 20 FOR THE FIRST TIME SINCE APRIL 13, 1973.
5/75 END DATE 5/75
RE CIRCULATION TANK MIXERS.
4/75 END DATE 5/75
MODULE A (WHICH WAS THE ONLY ONE OPERATING) WAS FORCED OUT TWICE IN APRIL
TO AVOID POND OVERBOARDING INTO THE DES PLAINES RIVER. THE SECOND OUTAGE
LASTED UNTIL MAY 5. DURING THE PAST SEVERAL MONTHS OF GENERALLY CONTINUOUS
OPERATION OF MODULE A. IT HAS BECOME APPARENT THAT THE PRESENT LIQUID
CIRCULATING SYSTEM CANNOT BE OPERATED IN A CONTINUOUSLY CLOSED CYCLE. THE
WATER IMBALANCE POSES A HIGH RISK OF OVERBOARDING FROM THE SLUDGE POND
DURING LONG PERIODS OF SUSTAINED OPERATON. THE FOLLOWING REVISIONS HAVE
BEEN MADE TO REDUCE THE WATER IMBALANCE:
1. THE PUMP GLAND WATER FLOWS HAVE BEEN CUT FROM 10 GPM TO 5 6PM.
2. THE SCRUBBER HOUSE SERVICE WATER FILTER BACKWASH HAS BEEN ROUTED
OUT OF THE SYSTEM.
*. THE CONTINUOUS UNDERSPRAY HAS BEEN CHANGED TO AN INTERMITTENT
SPRAY 5 MINUTES ON, 5 MINUTES OFF.
4/75 END DATE 5/75
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.
5/75 END DATE 5/75
DURING WAY, MODULE A WAS OUT FOR 45 MINUTES DUE TO A DAMPER TRIP.
5/75 END DATE 5/75
MODULE A W*S OUT ONCE FOR SPRAY NOZZLE CLEANING.
MODULE P. UAS£OUTDTWICE AFTER START UP, ONCE FOR A VENTURI PUMP TRIP AND
175
-------
EPA UTILITr FGD SURVEY: THIRD QUARTER 1979
COMMONWEALTH EDISON: WILL COUNTY 1
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
COMMONWEALTH E.DXSON: WILL COUNTY 1 (CONT.)
------------------------------------------ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
% REMOVAL PER BOILER F6D CAP-
502 PART. HOURS HOURS HOURS FACTOR
ORDER BECAUSE OF MATERIAL FAILURES EXPERIENCED IN MODULE B *S CARBON STEEL
REhEATER .
START DATE
START DATE
START DATE
START DATE
7/75 LND DATE 8/75
MODULE B SUFFERED TWO OUTAGES IN JULY AND ONE IN AUGUST BFCAUSE OF REHEATER
TUBE LEAKS. THE FAILURES WERE DUE TO VIBRATION FATIGUE. THE REHEATER, yHlCH
WAS INSTALLED IN MAY, HAS LOST SIX OF ITS TWELVE TUBE BUNDLES SO FAR. THE
LENGTH OF TIME THAT THE TUBES HAVE LASTED WOULD SEEM TO INDICATE THAT THERE
IS A D1ESIGN RELATED MATERIAL DEFICIENCY. THREE OF THE TUBE BUNDLES WERE
REPLACED WITH MARGINAL BUNDLES LEFT OVER FROM MODULE A'
E/75 END DATE 8/75
A SMALL STEAM HEADER LEAK CAUSED ONE MODULE B OUTAGE^
8/75 END DATE 8/75
MODULE B WAS OUT FOUR TIMES FOR NO DEMAND AND ONCE FOR A LOW FLOW TRIP.
8/75 END DATE 8/75
HIGH SULFUR COAL WAS BURNED ALL MONTH, CAUSING AN INCREASE IN SLUDGE
PRODUCTION WHICH HAS FORCED A MINIMUM SIX DAY A yEEK, TEN HOUR A DAY
SLUDGE DISPOSAL OPERATION. THE SLUDGE IS BEING TREATED WITH LIKE AND
FLY ASH AND BEING DUMPED INTO THE ON SITE HOLDING POND. STABILIZED
MATERIAL IS BEING TRUCKED FROM THE POND TO AN OFF SITE DISPOSAL AREA.
9/75 A
B
SYSTEM
10/75 A
B
SYSTEM
.0
32.3
.0
100.0
.0
26.6
720
744 194
PROBLEMS/SOLUTIONS/COWMENTS
START DATE 10/75 END DATE 10/75
MODULE A HAS OFF THE ENTIRE 11 DAYS THE BOILER OPERATED THIS MONTH, WAITING
FOR ITS NEfc REHEATER, WHICH HAS NOW BEEN RELEASED FOR MANUFACTURING BY
SMED.
START DATE 10/75 END DATE 10/75
MODULE B HAD TWO OUTAGES. ONE FOR NO DEMAND AND ONE MINOR 15 MINUTE TRIP.
START DATE 10/75 END DATE 10/75
HIGH SULFUR COAL HAS BURNED THIS MONTH WHEN THE SCRUBBER WAS IN SERVICE.
START DATE
WITH LIME AND FLY ASH AND HAULED TO AN OFF SITE
DISPOSAL AREA.
11/75 A
B
SYSTEM
12/75 A
B
SYSTEM
1/76 A
B
SYSTEM
2/76 A
B
SYSTEM
3/76 A
B
SYSTEM
30.1
8.8
45.2
20.4
.0
,C
.0
.0
.0
.0
18.8
8.5
720 0
744 0
744 D
696 0
744 309
177
-------
EPA UTILITY r&D SURVEY: THIRD QUARTER 1979
COMMONWEALTH EDISON: WILL COUNTY 1 CCONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1UITY RELIABILITY UTILIZATION
Z REMOVAL
S02 PART.
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
** PHOBLEMS/SOLUTIONS/COHMENTS
START DATE 10/75 END DATE 5/76
UNIT 1 WAS DOUN FROM OCTOBER 11 THROUGH MARCH 19 FOR ITS BOILfcR TURBINE
AND SCRUBBER OVERHAUL. THE HAJOB ITEMS TO BE ACCOMPLISHED DURING THE
OUTAGE WERE:
1. SIMPLIFICATION OF THE MILLING SYSTEM CONTROL.
2. PULLING AND CLEANING OF THE MODULE B REHEATER AMD RETURNING IT
REPLACED WITH MARGINAL BUNDLES LEFT OVER FROM MODULE A.
3. CLEANING OF THE POND PUMP BAY.
4. REMOVAL OF THE VENTURI AND ABSORBER PUMP CHfCK VALVES CONE OF THEM
FAILED LAST SPRING AND DESTROYED A PUMP LINER AfiO IMPELLER).
5. CLEANING AND REPAIR OF THE VENTURI NOZZLES A SO SUPPORTS.
6. REPAIR OF CORRODED REHEATER SUPPORTS.
7. RESETTING AND ADJUSTMENT OF ALL DAMPESS.
8. REVISION OF SCRUBBER CONTROLS BY RiEROVISG THE CONTROLS NO LONGER
USED OR NEEDED.
9. INSPECTION AND CLEANING OF THE ENTIRE SCRUBBER AND RELATED
EQUIPMENT.
START DATE 3/76 £«0 DATE 3/76
MODULE A HAS PUT INTO THE GAS PATH ON MARCH 22 ANO REMAINED AVAILABLE FOR
SERVICE THE REST OF THE MONTH.
START DATE 3/76 END DATE 3/76
NODULE B HAD TO REMAIN OUT OF SERVICE UNTIL MARCH 29 WHILE ITS 8EPAIRED
REHEATER WAS INSTALLED.
4/76
A
B
SYSTEM
23.0
20.0
49,3
19.2
47.3
720
*« PROBLEMS /SOLUTIONS/COMMENTS
START DATE 4/76 END DATE 4/76
UNIT 1 RETURNED TO SERVICE APRIL 2 AFTER A SHORT TURBINE CONTROL OUTAGE.
BOTH MODULES CAME ON LINE JUST BEFORE THE BOILER.
START DATE 4/76 END DATE 4/76
A FIVE DAY OUTAGE OF MODULE B HAS DUE TO REHEATER TUBE BUNDLE LEAKS.
START DATE 4/76 END DATE 4/76
SEVERAL MODULE B OUTAGES WERE DUE TO PLUGGED ABSORBER TANK SCREENS CAUSED
BY MILL AND CLASSIFIER FAILURES WHICH ALLOWED ROCK TO GET INTO THE SYSTEM.
MODULE B WAS THOROUGHLY CLEANED.
START DATE 4/76 END DATE 4/76
ONLY ONE AESORBER PUMP IS BEING USED IN MODULE B* SINCE THE 1B2 PURP LINER
FAILED AS A RESULT OF A BROKEN DISCHARGE VALVE. A REPLACEMENT LINER IS
BEING INSTALLED.
START DATE 4/76 END DATE 4/76
A SCRUBBER TESTING AND EVALUATING PROGRAM WAS STARTED THIS MONTH. MUCH or
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
SYSTEM
744 665
PROBLEMS /SOLUTI ON S/COKMENTS
START DATE 5/76 END DATE 5/76
A VENTRUI HOSE LEAK FORCED MODULE B OFF ONCE THIS MONTH.
START DATE 5/76 END DATE 5/76
MODULE B WAS TAKEN OUT OF SERVICE ONCE BECAUSE OF A PLUGGED ABSORBER TANK
SCREEN.
START DATE 5/76
END DATE 5/76
173
-------
EPA UTILITY FCD SURVEY: THIRD QUARTER 1979
COMMONWEALTH EDISON: WILL CGUNTY 1 (CDNT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABlLlTY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
MODULE 6 WAS OFF ONCE DUE TO A FOULED I.D. FAN.
START DATE 5/76 END DATE 5/76
MODULE B WAS OUT OF THE GAS PATH ONCt DUE TO NO DEMAND.
6/76
A
B
SYSTEM
52.0
86.2
44.2
84.5
37.6
71 .9
720 612
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 4/76 END DATE 6/76
MODULE A SUFFERED VENTURI PUMP LINER FAILURES ON APRIL 78 WHEN AN INLET 16
INCH BUTTERFLY ISOLATION VALVE BROKE APART AND FELL INTO THE VENTURI PUMP.
BOTH THE A AND BACKUP AB VENTURI PUMP LINERS WERE DESTROYED. MODULE A
REGAINED OL'T SERVICE UNITL JUNE 9, WHEN THC LINERS WERE REPLACED.
START DATE 6/76 END DATE 6/76
MODULE A WAS OFF ONCE FOR SHEARED BYPASS DAPPER PINS.
START DATE 6/76 END DATE 6/76
1.0. BOOSTER FAN FOULING FORCED MODULE A OFF ONCE THIS MONTH FOR ABOUT
164 HOURS.
START DATE
START DATE
START DATE
START DATE
7/76
A
6
SYSTEM
19.9
86.2
6/76 END DATE 6/76
BOTH MODULES WERE OFF TWICE DUE TO NO DEMAND. DURING THESE OUTAGES. THE
DEMISTERS UEPE WASHED AND ABSORBER TRAY SCALE, IF ANY, WAS KNOCKED OFF.
6/76 END DATE 6/76
MODULE B WAS OUT OF THE GAS PATH FOR SEVERAL SHORT VENTURI LOW FLOW TRIP
OUTAGES DUE TO A PLUGGED, SCALED VENTURI TA.NK SCREEN. AT THE END OF THE
MONTH, THE NODULE WAS TAKEN OUT TO CLEAN THE SCREEN.
6/76 END DATE 6/76
THE MODULE B I.D. BOOSTER FAN REQUIRED CLEANING DURING THE MONTH.
6/76 END DATE 6/76
THE REHEATER TUBES ARE SCALING, WHICH RESULTS IN A LOWER HEAT TRANSFER RATE
RATE, AND THEREFORE INCREASES I.D. BOOSTER FAN FOULING. THE ONLY WAV TO
CLEAN THE REHEATERS EFFECTIVELY IS TO REMOVE THEM, WHICH DEMANDS A SUBSTAN-
TIAL OUTAGE.
.0
90.0
.0
72.3
744
598
»* PROQLEMS/SOLUTIONS/COMMENTS
START DATE 6/76 END DATE 7/76
MODULE A WAS OFF THE FIRST PART OF THE MONTH DURING REPAIRS TO THE ABSORBER
START DATE 7/76 END DATE 7/76
THE LATTER PART OF THE MONTH THE MODULE WAS READY FOR SERVICE BUT WAS NOT
OPERATED BECAUSE OF THICKENER-POND SLUDGE OVERLOADING.
START DATE 7/76
END DATE 7/76
MODULE B WAS FORCED OFF ONCE TO BALANCE THE I.D. BOOSTER FAN, AND ONCE TO
, WASH THE FAN.
START DATE 7/76 END DATt 7/76
MODULE B WAS OUT OF THE GAS PATH TWICE DUE TO NO DEMAND.
8/76
A
b
SYSTEM
98.?
65.4
57.6
61 .4
38.3
40.9
744 495
179
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
COMMONWEALTH EDISON: ylLL COUNTY 1 (CONT.)
. PERFORMANCE OATA--— —
PERIOD MODULE AVAILABILITY OPERABILITr RELIABILITY UTILIZATION Z REMOVAL PER BOILER fGD CAP.
502 PART. HOURS HOURS HOURS rACTOR
** PROBLEMS/SOLUTIONS/COHMENTS
START DATE 8/76 END DATE 8/76
MODULE A HAS OUT OF THE GAS PATH THE FIRST HALF OF THE MONTH T AVOID
THICKENER-POND OVERLOADING.
START DATE 8/76 END DATE 8/76
DURING THE LATTER HALF OF THE MONTH* MODULE A WAS USED KITH THREE MINOR
FORCED OUTAGES AND ONE FOUR DAY NO DEMAND OUTAGE.
START DATE 8/76 END DATE 8/76
MODULE B WAS OUT OF THE 6AS PATH TtM»£E TIM£S DUE TO NO DEMAND*
START DATE 8/76 END DATE 8/76
LOSS OF CHEMICAL CONTROL CAUSED TWO HO DOLE A OUTAGES.
START DATE 8/76 END DATE 8/76
ROOULt B MAS OFF FOR HIDE OATS DUE TO JOULW6.
START DATE Sj76 END DATE B/?6
SPENT SLURRY VALVE REPAIRS FORCED A MODULE B OUTAGE.
STAflT DATE B/76 END DATE 8/76
OW AUGUST 12 THE OPERATIfiG PN CONTROL SET P0I«? WAS SEDUCED FROM 5.4 TO
5.1. IT IS BELIEVED THAT THIS LOWER PH IS THE CAUSE OF TME FOULING OUTAGE
OF «OOUL£ B ON AUGUST 21. MODULE A HAS ALSO OPERATED FOR THREE 0AVS, fttttt
IT. TOO* EXPERIENCED INCREASEC SACLE fOULIHG. THE *>H SET POINT HAS THEN
INCREASED BACK TO 5.4.
err* A
B
SYSTEM
42,3
79.4
28.7
22.6
59.9
720 566
*• PROBLEMS/SOLUTIONS/COHMEMTS
START DATE 9/76 END BATE 9/76
MOftULE A UE*T Off ONCE OUE TO A LOU CLOW TRIP.
STABT BATE 9/76 END DATE 9/76
MODULE A WAS TAKEN OFF ONCE FOR CLEANING OF THE RECIRC ULATION TANK AMD
PUMPS. AND INSPECTION OF PUMP ISOLATION VALVES.
START DATE 9/76 END DATE 9/76
A LINER LEAK IN TA2 ABOSORBEH PUMP ALSfl FOHCED MODULE A OFF.
START DATE 9/76 END DATE 9/76
MOl^LE A WAS OUT Of TM GAS PATH TWICE DUE TO NO DEMAND.
START DATE 9/76 END DATE 9/76
MODULE A HAS TAKEN OFF ONCE TO AVOID THICKENER-POND OVERLOADING.
START DATE 9/76 END DATE 9/76
SPENT SLURRY VALVE TROUBLE CAUSED TWO MODULE B OUTAGES.
tO/76 A
B
SYSTEM
27.9
76.4
28.9
56.?
37.9
S4.8
744
726
PROBLEMS/S0LUTIONS/CORMENTS
START DATE 3/76 END DATE 10/76
HIGH SULFUR ILLINOIS COAL WAS BURNED IN TH-E BOILER FROM MARCH THROUGH
OCTOBER.
START DATE 3/76
END DATE "0/76
THt SCRUBBER WASTE MATERIAL WAS TREATED WITH LIME AND FLY ASH AND HAULED TO
AN OFF SITE DISPOSAL AREA.
START DATE 10/76
END DATE 10/76
180
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
COMMONWEALTH EDISON: WILL COUNTY 1 CCONT.)
PER FORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER fGD C KP~.
so2 PART. HOURS HOURS HOURS FACTOR
MODULE A OPERATED ON ONE ABSORBER PUMP, ALLOWING TESTING ON A LOyFR
An SORBER FAH.
START DATE 10/76 END DATE 10/76
MODULE A WAS OUT OF THE GAS PATH ONCE FOR AN I .D. BOBOOSTER FAN TRIP.
START DATE 10/76 END DATE 10/76
WORK ON REC1RCULAT10N TANK LEVEL CONTROLS CAUSED A MODULE A OUTAGE.
START DATE 10/76 END DATE 10/76
MODULE B WAS FORCED OFF ONCE TO REPAIR A REHE.ATER HEADER LEAK.
START DATE 10/76 END DATE 99/99
ONE MODULE B OUTAGE yAs FOR VENTURI NOZZLE CLEANING.
START DATE 10/76 END DATE 10/76
MODULE B WENT OFF FOR A VENTURI LOW FLOW TRIP.
START DATE 10/76 END DATE 1Q/76
MODULE B REMAINED OUT OF SERVICE WHILE MODULE A WAS BEING TESTED TO AVOID
THICKENER-FOND OVERLOADING.
START DATE 10/76 END DATE 11/76
A VACUUM FILTER WAS TIED IN AT THE THICKEN£R.
11/76 A 20.1 25.6 20.1
B 72.2 69.6 4.7
SYSTEM 720 566
»* PROBLEMS/SOLUTIONS/COMKENTS
START DATE 11/76 IND DATE 11/76
MODULE A OPERATED ON ONE ABSORBER PUMP DURING MODULE B OUTAGE.
START DATE 11/76 END DATE 11/76
MODULE B WAS FORCED OUT OF THE GAS PATH ONCE FOR A MILLING SYSTEM FAILURE.
START DATE 11/76 END DATE 11/76
MODULE B ENCOUNTERED A VENTURI HEADER LEAK.
START DATE 11/76 END DATE 11/76
THE VENTURI NOZZLES REQUIRED CLEANING DURING THE MONTH.
START DATE 11/76 END DATE 11/76
REPLACEMENT OF THE SPENT SLURRY VALVE NECESSITATED A MODULE OUTAGE.
START DATE 11/76 END DATE 11/76
MODULE B WAS OFF ONCE DUE TO A CHEMICAL SYSTEM UPSET.
START DATE 11/76 END DATE 11/76
MODULE B WAS OUT OF THE GAS PATH TWICE DUE TO NO DEMAND (MODULE A WAS NOT
IN SERVICE AT THE TIME OF THE OUTAGE).
12/76 A 44.9 4R.3 ^.9
B "'* 51'? 4S'C 744 692
SYSTEM 744 692
** PROBLEMS/SOLUTIONS/COfMENTS
START DATE 12/76 ^ EH» DATE "'J*^, § ^ ^ ABSORpER puMp wss TAKEN 0||T 0,
SERVICE FOR OVERHAUL. THE REPAIRS WERE COMPLETED ON DECEMBER 6, WHEN THE
KCDULE ASSUMED A ONE ABSORBER PUMP STANDBY CAPABILITY UNTIL THE 1A1 ABSOR-
BER PUMP CAN BE REPAIRED.
START DATE 12/76^ ^ ^NO DATEf 12/76^
BEING REPAIRED.
START DATE 12/76 END DATE 12/76
1S1
-------
EPA UTILITY FGD SURVEVr THIRD QUARTER 1979
COMMONWEALTH tDlSGN: WlLL COUNTY 1 (CCMT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION 5! R€MOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
MODULE R PERFORMED SATISFACT10RILY DURING THE FIRST HALF OF THE MONTH,
EXPERIENCING ONLY ONE NO DEMAND OUTAGE. ON THE 17TH, HOWEVER, THE SPENT
SLURRY VALVE FAILED AND THE MODULE HAS REMAINED OUT OF SERVICE.
1/77
A
B
SYSTEM
98.2
13.5
98.7
1 .1
95.8
1.1
744 722
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 12/76 END DATE 12/76
THE 1A1 ABSORBER PUMP WENT OUT IN LATE SEPTEMBER WITH BURNED OUT BEARINGS
AND REMAINED OUT THROUGH JANUARY WAITING FOR PARTS.
START DATE 11/76 END DATE 1/77
LOW SULFUR COAL WAS BURNED IN THE BOILER FROM NOVEMBER THROUGH JANUARY.
START DATE 11/76 END DATE 1/77
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 RECIRCULATION PONDS. THIS MATERIAL, ALONG WITH SCRUBBER
WASTE MATERIAL, WAS TREATED WITH LIME AND FLYASH AND HAULED TO AN OFF
SITE DISPOSAL AREA.
START DATE 1/77 END DATE 1/77
NODULE A WAS FORCED OUT ONCE BY A FAILED SPENT SLURRY VALVE.
START DATE 1/77 END DATE 1/77
PLUGGED DEHISTER UNDERSPRAYS CAUSED ANOTHER MODULE A OUTAGE.
START DATE 1/77 END DATE 1/77
MODULE A HINT OUT ONCE BECAUSE OF NO DEMAND AND ONCE DUE TO A BOILER OUTAGE
(MODULE B WAS ALREADY OUT OF SERVICE FOR REPAIRS).
START DATE 1/77 END DATE 1/77
MODULE B BECAME AVAILABLE FOR SERVICE ON JANUARY 27, AFTER REPAIRS TO THE
SPENT SLURRY VALVE WERE COMPLETED. DUE TO SEVERE WEATHER CONDITIONS, THE
MODULE WAS PLACED IN THE GAS PATH JANUARY 31.
2/77 A
B
SYSTEM
38.8
72.0
42.6
45.7
38.8
41.7
672 613
** PROBLEnS/SOLUTIONS/COMflENTS
START DATE 2/77 END DATE 2/77
THERE WAS VERY LITTLE DIGGING IN THE RECIRCULATION PONDS. CHICAGO FLYASH
SPENT MOST OF THEIR TIME ON CLEANING AND MAINTENANCE.
3/77 A
B
SYSTEM
96.9
80.9
66.7
75.5
64.2
73.9
744 728
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 3/77 ENC DATE 3/77
AN ERT S02 ANALYZER WAS INSTALLED ON THE DISCHARGE SIDE OF MODULE B I-D.
BOOSTER FA*. THIS IS AN "IN SITU" ON-DISPERSIVE ANALYZER THAT CONTINUALLY
MEASURES AND READS OUT CONCENTRATIONS OF SOZ, CO, C02, AND NO.
START DATE
!/77
END DATE 3/77
AN ABSOR6ER SUCTION HEADER LEAK FORCED MODULE B FROM THE GAS PATH.
START DATE 3/77 tND DATE 3/77
MODULE p WAS FORCED CUT DUE TO A SLURRY VALVE GASKET LEAK.
START DATE 3/77
END DATE 3/77
A PLUGGED fEED SLURRY RECIRCULATICN LINE WAS ENCOUNTERED IN MODULE B.
START DATE
5/77
END DATE 3/77
182
-------
LPA UTILITY FGD SURVEY: THIRD QUARTER 1979
COMMONWEALTH cDlSON: WILL COUNTY 1 (CCNT.)
PERrORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION
% REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
START DATE
HIGH SULFUR COAL WAS BURNFD FOR SEVEN DAYS THIS MONTH TO PROVIDE HIGH
SULFUR SLUDGE FOR THE UOP SLUDGE TEST.
3/77 END DATE 3/77
CHICAGO FLYASH SPENT 75% OF THEIR TIME DIGGING IN THE POND. THE REST WAS
SPENT ON THE THICKENER AND VACUUM FILTER IPERATlON. THE SCRUBBER WASTE
MATERIAL UAS TREATED WITH LIME FLYASH AND HAULED OFF SITE.
DISPOSAL AREA.
4/77
A
6
SYSTEM
86.1
45.5
67.7
30.2
61 .2
27.3
720 650
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE
START DATE
START DATE
START DATE
START DATE
START DATE
4/77 END DATE 4/77
THE PERFORMANCE OF THE ERT S02 ANALYZER TO DATE HAS BEEN, AT BEST, UNRELIA-
BLE AND INCONSISTENT. THE ERT TECHNICIANS ARE OUT TO SERVICE THE ANALYZER
ALMOST EVERY OTHER DAY. THE PROBLEM, ACCORDING TO ERT TECHNICIANS, IS OF A
"THERMAL NATURE". WHEN THE ANALYZER REACHES A CERTAIN TEMPERATURE, A CHIP
SHORTS OUT. THEY HAVE NOT BEEN ABLE TO LOCATE THE FAULTY INTEGRATED CIRCUIT
YET.
4/77 END DATE 4/77
A BOILER TUBE LEAK. REPAIR FORCED MODULE A OUT OF THE GAS PATH ONCE THIS
MONTH fMODULE B WAS ALREADY DOWN FOR REPAIRS).
4/77 END DATE 4/77
MODULE B WAS FORCED OUT OF THE GAS PATH TWICE FOR AN ABSORBER SUCTION
HEADER LEAK REPAIR.
4/77 END DATE 4/77
MODULE 6 UAS OUT OF SERVICE ONCE TO WASH THE I.
BOOSTER FAN.
4/77 END DATE 4/77
HIGH SULFUR COAL WAS BURNED FOR SEVEN DAYS THIS MONTH TO PROVIDE HIGH
SULFUR SLUDGE FOR THE UOP SLUDGE STUDY.
4/77 END DATE 4/77
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME DIGGING IN THE SMALL POND,
GETTING READY FOR THE MGO ADDITION AND FORCED OXIDATION TEST. THE SCRUBBER
WASTE MATERIAL WAS TREATED WITH LIME AND FJ.YASH AND HAULED TO AN OFF SITE
DISPOSAL AREA.
5/77
A
B
SYSTEM
89.4
98.0
2.2
50.9
2.0
47.2
744 691
** PRODLEMS/SOLUTIONS/COMMENTS
START DATE
START DATE
5/77 END DATE 5/77
THE ERT S02 ANALYZER HAS BEEN REMOVED FROM SERVICE DUE TO A POOR PERFORM-
ANCE RECORD OVER THE LAST THREE MONTHS. ERT IS IN THE PROCESS OF RE-
ENG1NEERINC THEIR ANALYZER.
5/77 END DATE 5/77
THfc MGO ADDITION TEST WENT WELL. ALTHOUGH THE MGO INCREASED S02 REMOVAL
FFF1CTFNCY ABOUT 10%. IT DID PRACTICALLY NOTHING FOR THE TWO MORE SERIOUS
PROBLEMS, SINCE THICKENER AND SLUDGE PRODUCTION AND LIMESTONE CONSUCFTION
RATE WERE ABOUT THE SAME.
MODULE A w«E"p'c»E6«?'K THE GAS PATH ONCE THIS MONTH WHEN THE INLET
VALVE ON 1A2 A6SORBER PUMP FAILED.
MODULE B
AND INSPECT THE REHEATER TUBES.
BOTH MDULESESDE«"IcPC«7Jir FOR THE FIRST FIFTEEN DAYS OF THE MONTH DUE TO
163
-------
EPA UTILITY F&D SURVEY: THIRD QUARTER 1979
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
A FAILED 1T3V CONTROL TRANSFORMER FOR THE "POND RETURN PUMPS- THE TRANSFORM-
ER HAP TO BE ORDERED FROM WEST1NGHOUSE.
START DATE 5/77
END DATE 5/77
HIGH SULFUR COAL HAS BURNED FOR ELEVEN DAYS DURING THE MONTH.
6/77
A
B
SYSTEM
31.8
93.2
13.3
93.4
10.5
73.5
720 566
*« PROBLEHS/SOLUT10NS/COMMENTS
START DATE
7/77
B
SYSTEM
START DATE
START DATE
STABT DATE
70.3
6/77 END DATE 6/77
THE 1A1 ABSORBER PUMP IS STILL OUT OF SERVICE WAITING FOR PARTS 1A2
ABSORBER PUMP'S ISOLATION VALVES FORCED MODULE A OFF FOR MOST OF T(E MONTH.
6/77 END DATE 6/77
NODULE A HAD ONE NO DEMAND AND ONE BOILER OUTAGE THIS MONTH.
6/77 END DATE 6/77
MODULE B WAS ALSO FORCED OFF TO CLEAN THE I'D. BOOSTER FAN.
6/77 END DATE 6/77
NO HIGH SULFUR COAL WAS BURNED THIS MONTH.
41.4
21 .0
744 377
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE
START DATE
START DATE
START DATE
6/77 END DATE 7/77
HIGH SULFUR COAL HAS BURNED FOR EIGHT DAYS THIS MONTH. LIMESTONE OPERATION
HAS NORMAL FOR HIGH SULFUR OPERATION.
7/77 END DATE 7/77
NODULE B WAS FORCED OUT OF THE 6AS PATH ON-CE TO REMOVE A PLUGGED DIFFUSER.
THE FINAL TEST, FORCED OXIDATION SEEMDD TO BE THE MOST SUCCESSFUL OF ALL.
USING LIQUID OXYGEN, UP TO 12.000 CFM OF GASEOUS 02 WAS FED INTO EACti
VENTURI DOUNCOHER, OXIDATION OF SULFITE TO SULFATE MAS INCREASED FROM
35 TO 90 X
7/77 END DATE 7/77
MODULE B WAS ALSO FORCED OFF DUE TO A LOW LEVEL IN THE SLURRY STORAGE TANK.
7/77 END DATE 7/77
MODULE B WAS ALSO FORCED OFF DUE TO REHEATER TUBE BUNDLE LEAKS.
8/77
A
B
SYSTEM
99.8
9.7
99.6
12.0
80.8
9.7
744 604
PROBLEMS/SOLUTIONS/COMMENTS
START DATE
8/77 END DATE 8/77
MODULE A 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
52.3
720
499
PROBLEMS/SOLUTIONS/COMMENTS
10/77 A
START DATE 9/77 END DATE 9/77
MODULE B ENCOUNTERED HIGH VIBERATIONS IN ITS BOOSTER FAN DURING THE FIRST
WEEK OF THE MONTH. AFTER THE FAN WAS BALANCED, THE MODULE OPERATED
THE UNIT OUTAGE ON SEPTEMBER 21.
.0 .0
184
-------
COMMONWEALTH EDISON: WILL CCUNTY 1 (CONT.)
EPA UTILITY FGb SURVEY: THIRD QUARTER 1579
p£ R
PERIOD MODULE AVAILABILITY OPERADIHTY RELIABILITY UTILIZATION % REMOVAL PER BOILER~~F6 D~~~C AP ~~
S02 PART. HOURS HOURS HOURS FACTOR
11/77
B
SYSTEM
A
b
SYSTEM
.0
.0
8.8 50.1
.0
« u
8.R
744 0
->-> n 13*
12/77
1/78
»* PR08LEMS/SOLUTIONS/COMKENTS
START DATE 9/77 END DATE 11/77
UNIT ONE CAKE UP ON NOVEMBER 25 AFTER A SIXTY-THREE DAY OUTAGE.
START DATE 11/77 END DATE 11/7'
MODULE B IS IN THE GAS PATH FATER EXPERIENCING SOME DIFICULTY IN BALANCING
A
B
SYSTEM
ITS BOOSTEk FAN.
42.5 42.5
84.1 84.1
47.8
94 .6
42.5
744
661
** PROBLEHS/SOLUTIONS/COMNENTS
START DATE 12/77 END DATE 12/77
PLUGGAGE WAS ENCOUNTERED IN TH EMODULE B R.EHEATER. BECAUSE NO SPARE REHRAT
COILS WERE AVAILABLE, THE UTILITY TRIED TAKING SOME COILS FROM MODULE A
MODULE D APPEARED TO BE MORE ORE SEVERELY PLUGGED THAN ORIGINALLY THOUGHT.
START DATE 12/77 END DATE 12/77
MODULE A WAS DOWN HALF THE MONTH BECAUSE OF A MAIN STEAM LEAK WHICH COULD
NOT BE ISOLATED.
START DATE
9/77 END DATE 12/77
MODULE A OPERATED UNTIL SEPTEMBER 19, WH E A COMBINATION OF MUO AND SCALE
6UILD-UP ON THE SUMP FLOOR STRUCTURALLY DAMAGED THE MODULE. REPAIRS PUT
THE MODULE OUT OF SERVICE UNTIL KID DECEMBER.
A
B
SYSTEM
69.0
22.0
89.9
29.B
66.3
22.0
744
549
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE
1/78 END DATE 99/99
ON JANUARY 7, THE MOBULE B I.D. BOOSTER FAN DISCHARGE DUCT STARTED VIBRAT-
ING WILDLY. THIS FORCED THE BOILER OFF WHILE THE SHOP MADE REPAIRS TC THE
DUCTWORK AND BALANCED THE FAN WITH AN I.R.D. MACHINE.
START DATE 1/78
END DATE 1/78
WHEN THE UTILITY ATTEMPTED TO PUT MODULE B PACK IN THE GAS PATH, A LEAK IN
THE SLURRY LINE FORCED IT BACK OFF.
START DATE 1/73
tND DATE 1/73
A PLUGGED VE(4TURI PUMP FORCED MODULE B OFF THE REST OF THE MONTH.
START DATE 1/73
END DATE 1/78
DURING THE OUTAGE, THE REHEATER COILS WERE CLEANED WITH A HIGH PRESSLRE
(5QCO LE!) SPRAYER.
START DATE 1/78
DATE 1/78
START DATE
MODULE A WAS FORCED OFF WHEN A STEAM REGULATING VALVE bLEW ITS PACKING.
1/78 END DATE 1/73
ON THE 23Rt, BOTH MODULES WERE TAKEN OFF AND DRAINED TO ALLOW THE SHOP TO
INSTALL NEU ISOLATION VALVES IN THE ABSORBER AND VENTURI PUMPS.
START DATE 1/78
DATE 1/7S
TOWARD THE END OF THF MONTH, SOME PROBLEMS WERE ENCOUNTERED WITH THE POND
RETURN PUMPS FREEZINt.
2/78
40."
34.4
-------
FP« UTILITY Fk,D SURVEY: THIRD QUARTER 1979
£DISON: WILL COUNTY 1 (CONT.)
PER FORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
0
SYSTEM
69.5
92.9
56.5
672 409
** PROiiLEMS/SOLUTIONS/COMMENTS
START DATE 2/78 END DATE 2/78
MODULE A RAN INTO DIFFICULT OPERATION6 CONDITIONS THIS BONTH DUE TO RAPID
PLUGGING Of THE REHEAT COILS.
START DATE 2/78 tND DATE O/ 0
INSPECTION AND SUBSEQUENT CLEANING OF MODULE A UNCOVERED PLUGGED SPRAT
NOZZLES AND DEMISTER TRAYS DUE TO NOZZLE INEFFICIENCY.
START DATE 2/7S END DATE 2/78
MODULE F1 OPERATED VERY WELL AND AN INSPECTION SHOWED THE MODULE TO BE VERT
CLEAN.
3/78
B
SYSTEM
93.5
88.5
100.0
84.7
90.6
76.0
26.2
744
230
*• PROdLEMS/SOLUTlONS/COMMENTS
START DATE 3/78 END DATE 3/78
THIS MONTH, DUE TO COAL CONSERVATION, UNIT 1 WAS ON THE SYST£« V £« Y LITTLE.
START DATE 3/78 END DATE 3/73
MODULE B HAD DIFFICULTY FOR SEVERAL DAYS BECAUSE OF A CRACKED SHEAVE ON THE
VENTURI PUMP.
START DATE
3/78 END DATE 3/78
HIGH PRESSURE CLEANING ON BOTH MODULES DURING THE COAL CONSERVATION ALONG
WITH REMOVING THE VENTURI THROAT RESTRICTOR BLOCKS PROVED BENEFICIAL IN
MAINTAINING BETTER CONTROL OF THE DRAFT CONDITIONS IN THE SCRUBBER.
4/78
A
B
SYSTEM
99.9
100.0
99.7
99.9
92.0
92.2
720 665
PROBLEMS/SOLUTIONS/COMMENTS
START DATE
4/78 END DATE 4/78
THE PRESSURE DIFFERENTIAL ACROSS THE VENTURIS HAS BEEN REDUCED BY APPROXI-
MATELY 40Z AT 140 MW BY REMOVING THE VENTUH1 RESTRICTOR BLOCKS. PARTICULATE
REMOVAL AND SOLIDS CARRYOVER COULD BE ADVERSELY AFFECTED BY THIS ACTION.
SINCE PARTICULATE REMOVAL AT THE VENTURI 13 A FUNCTION OF WATER DROPLET
SIZE, WHICH IN TURN IS A FUNCTION OF PRESSURE DROP. INCREASED SOLIDS CARRY-
OVER COULD POSSIBLY COMPUND REHEATER PLUGGING PROBLEMS. THE UTILITY IS
KEEPING A CLOSE WATCH FOR PLUGGING, BUT HAS NOT YET FOUND ANYTHING UNUSUAL*
START DATE
4/78
MODULE
LEAK.
END DATE 4/78
A WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH FOR A VENTURI PIPE
5/78
A
b
SYSTEM
9.5
89.2
99.4
100.0
55.2
56.1
744 413
• * PROBLtMS/SOLUTIONS/COMMENTS
START DATE
5/78 END DATE 99/99
DURING THE LAST PART OF THE MONTH BOTH MODULES WERE FORCED OUT OF THE 6AS
PATH DUE TC REHEATER LEAKS. IT REQUIRED A TWO DAY OUTAGE TO REMOVE THE
LEAKING REHEATER DUNDLES. ADDITIONAL REHAT.ERS ARE ON ORDER AND ARE EUPECT-
Et> TO ARRIVE IN JUNE .
6/78
07.1
SYSTEM
94.5
10C.O
23.7
25.1
720 181
1S6
-------
tPA UTILITY FGC SURVEY: THIRD QUARTER 1979
COMMONWEALTH tDISON: WILL CCUNTY 1 (CONT.)
D.ATA
PERIOD MODULE AVAILABILITY OPERARUlTY RELIABILITY UTILIZATION % REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROtiLEMS/SOLUTI ONS/CCWIENTS
START DATE
START DATE
START DATE
START DATE
START DATE
7/78
A
B
SYSTEM
97.Q
99.2
6/78 END DATE 6/78
DURING A SCRUBBER INSPECTION, 25X DIEMISTER AND 752 ABSORBER SPRAY PLUGGAGE
WAS DISCOVERED IN MODULE A. KODULE B WAS NOT AS BAD.
6/78 END DATE 6/78
HIGH VIBRATION WAS ENCOUNTERED IN THE TURBINE BEARINGS DURING BOILER START
UP, CAUSING THE BOILER TO SHUT BACK DOWN.
6/78 END DATE 99/99
THE PUG MILL FOR CHICAGO ADMIXTURES HAS BtEN APPROVED, AND THE NEW SLUDGE
TREATMENT SYSTEM SHOULD BE OPERATING BY FALL.
6/78 END DATE 6/78
THE SCRUBBER WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH WHEN THE 1B1
ABSORBER DISCHARGE VALVE FAILED TO OPEN.
6/7S END DATE 6/78
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.
100.0
100.0
11.6
11.6
744
77
** PROBLEMS/SOLUTIQNS/COMWENTS
START DATE 7/73 END DATE 7/78
THE BOILER WAS PLAGUED ALL MONTH BY CYCLONE CASING LEAKS. BECAUSE OF THE
CYCLONE PROBLEMS AND THE COAL CONSERVATION PROGRAM, THE BOILER WAS ONLY
OPERATED SEVENTY-SEVEN HOURS FOR THE MONTH.
START DATE 7/78 END DATE 7/78
THE BOILER DOWN TIME HAS USED FOR PREVENTATIVE MAINTENANCE ON THE SCRUBBER.
SIX NEW REHEATERS WERE INSTALLED AND A DRAIN VALVE ON THE SPENT SLURRY LINE
MAS REPAIRED.
START DATE 7/78 END DATE 7/78
A VALVE FAILURE ON THE 1A1 ABSORBER PUMP FORCED THE SCRUBBER FROM THE GAS
PATH ONCE DURING THE MONTH.
START DATE 7/78
END DATE 7/78
MODULE B EXPERIENCED A LEAKING VENTURI HEADER.
8/78
A
B
SYSTEM
97.8
99.6
100.0
1CO.O
59.1
59.1
744
440
** PROBLEMS/SOLUTIONS/COMKENTS
START DATE
8/7S END DATE 8/78
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIKE OPERATING OUT OF THE THICKENER.
THE SCRUBBER WASTE MATERIAL WAS TREATED WITH LIME AND FLY ASH AND HAULED
OFF TO AN OFF SITE DISPOSAL AREA.
START DATE S/7P
END DATE 8/78
REPAIRS TO THE VENTURI EMERGENCY SPRAY VALVE CAUSED ONE BOILER OUTAGE
DURING THE MONTH.
START DATE 8/7?
END DATE 8/7P
9/78 A
START DATE
77.7
A REHEATER FLANGE LEAK WAS RESPONSIBLE FOR FORCING THE UNIT OFF.
8/7E END DATE E/7&
MODULE A WAS FORCED OFF ONCE DUE TO HIGH VIBRATION OF THE l.D. BOOSTER FAN.
THE PROBLEI* WAS CORRECTED BY REPACKING THE COUPLING ON THE FAN.
95 .
55.4
157
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
COMMONWEALTH EDISON: UILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA6ILITY RELIABILITY UTILIZATION 5! REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
B
SYSTEM
77.7
96.0
55.5
720 416
.* PR08LEMS/SOLUTIONS/COMMENTS
START DATE
START DATE
START DATE
START DATE
5/77 END DATE 9/78
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME OPERATING OUT Or THE THICKENER.
THE SCRUBBER WASTE MATERIAL WAS TREATED WITH LIME AND FLY ASH AND HAULED TO
AN OFF SITE DISPOSAL AREA.
9/78 END DATE 9/78
REHEATER TUBE LEAKS, ONE IN MODULE A AND FOUR IN MODULE B, CAUSED ONE
BOILER OUTAGE AND CAUSED THE FGO SYSTEM TO BE UNAVAILABLE FOB A TOTAL
OF NINETY HOURS. SAMPLES OF THE TUBCS HAVE BEEN SUBMITTED TO 0 .A .D . FOR
METALLURGICAL EXAMINATION.
9/7£ END DATE 9/78
A RUPTURED AIR LINE ON A VENTURI PUMP ISOLATION VALVE WOULD NOT ALLOb THE E
VALVE TO GO COMPLETELY CLOSED.
9/78
WHEN THE A
END DATE 9/78
P Up|P WAS STARTEOt A VENTURI SPRAY HOSE RUPTURED.
START DATE 9/78 END DATE 9/78
IT WAS DISCOVERED THAT THE NODULE A VENTURI TANK LEVEL PRESSURE SWITCH WAS
NOT WORKIN6 PROPERLY.
START DATE
START DATE
9/78 END BATE 9/78
THE PUGMILL ORDERED FOR CHICAGO ADMIXTURES HAS ARRIVED ON SITE. IN OCTOBER,
THEY WILL FINISH THE CONVERSION, WHICH wiu. ALLOW THE MATERIAL SERVICE
MIXER TRUCKS TO BE ELIMINATED.
9/78 END DATE 9/78
IN OCTOBER, THE THICKENER WILL HAVE TO BE BYPASSED WHILE THE UTILITY DOES
MAINTENANCE ON THE RAKE AND REPLACES SOME LEAKING VALVES.
10/78
A
B
SYSTEM
100.0
100.0
100.0
100.0
35.0
35.0
744 261
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 10/78 END DATE 10/78
LOW BOILER HOURS WERE DUE TO FOUR OUTAGES :CAUSED BY HIGH BEARING HETAL
TEMPERATURES AND EXCESSIVE VIBRATION IN THE 1-B FORCED DRAFT FAN.
START DATE 10/78 E.ND DATE 10/78
THE OILER DOWN TIME WAS UTILIZED FOR CLEANING AND REPAIR OF THE VENTURI
THROAT, SUMP AND SUMP SCREENS, AND INLET BLOCK DAMPERS OF MODULE A, AS
WELL AS THE VENTURI AND ABSORBER TANKS AND SCREENS AND ALL ABSORBER SPRAY
NOZZLES OF BOTH MODULES.
START DATE 10/78 END DATE 10/78
ON INSPECTION, IT WAS DISCOVERED THAT THE B MODULE ABSORBER DEPARTMENTAL
DAMPER HAD SLIPPED 5OZ CLOSED. THE DAMPERS WERE JACKED OPFN AND WELDED
IN PLACE.
START DATE 10/78 END DATE 10/78
TO CORRECT A HIGH PRESSURE DROP ACROSS THE MODULE B REHEATER, A NEW METHOD
WAS EMPLOYED WHEREBY ONLY THE MIDDLE TUBES WERE REMOVED, ALLOWING THE TOP
AND BOTTOM TUBES TO BE SEEN AND CLEANED, ELIMINATING THE REMOVAL OF ALL THE
TUBES. THIS PROCEDURE CUT OUTAGE TIME FROM ONE OR TWO WEEKS TO TWO DAYS.
11/78
A
B
SYSTEM
96.2
85.2
100.C
100.0
48.?
720 348
138
-------
TPA UTILITY FGD SURVEY; THIRD QUARTER 1979
COMMONWEALTH EDISON: «ILL COUNTY 1 (CONT.)
------------------------------------------ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIAD1LITY UTILIZATION
% REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 11/7S LND DATE 11/73
THE UNIT WAS DOWN THREE TIMES THIS MONTH DUE TO A VENTUR1 PUMP AND TkO
BOOSTER FAN OUTAGES.
12/78
1/79
2/79
3/79
A
B
SYSTEM
65.3
64.5
1 OC.O
100.0
64.5
64.5
744
480
** PROBLEMS/SOLUTIONS/COKMENTS
START DATE 1?/7S END DATE 12/78
REHEATER TU3E LEAKS CAUSED TWO OUTAGES.
START DATE 12/78 END DATE 12/78
THE MODULE B SPENT SLURRY DRAIN WAS REPAIRED.
A
B
SYSTEM
S3.5
62.2
1CO.O
£7.1
61 .3
53.4
744
456
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE
START DATE
START DATE
1/79 END DATE 1/79
THE S02 PLANT WAS FORCED OFF TWICE THIS MONTH DUE TO REHEATER TUBE LEAKS.
TWO TUBES ON MODULE A AND FOUR TUBES ON MODULE B WERE REPLACED.
1/79 tND DATE 1/79
THE I.D. BOOSTER FAN ON MODULE B WAS FOULED AND HAD TO BE REPLACED.
1/79 END DATE 1/79
TWO SPECIAL SECTIONS OF VENTURI piPiNGt A SIXTEEN TO EIGHT INCH ECCENTRIC
REDUCER AND AN OFFSET TEE WERE PREPARED BY LOCKPORT FABRICATING AND INSTAL-
LED THIS MONTH. THE ORIGINAL REDUCER AND TEE HAD BEEN PATCHED AND WELDED SO
MANY TIMES THAT THEY WERE BEYOND REPAIR.
A
B
SYSTEM
93.0
93.0
91 .3
91 .3
54.2
54.2
672
399
"* PROBLEMS/SOLUTIONS/COMMENTS
START DATE
2/79 END DATE 2/79
THfc UNIT WAS FORCED OFF ONCE FOR A MAIN STEAM HEADER LEAK.
A
8
SYSTEM
100.0
68.6
1CO.O
1CO.O
46. Q
46.0
744 343
4/79
5/79
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 1/79 END DATE 3/79
THE SYSTEM HAS FORCED OUT TWICE IN FEBRUARY AND FOUR TIMES IN MARCH DUE
TO A VENTUR1 HEADER LEAK. A TEN FOOT SECTION OF PIPE WILL HAVE TO BE
REPLACED DUE TO EXTENSIVE CORROSION.
START DATE 3/79 END DATE 3/79
THE SYSTEM WAS DOWN ONCE FOR A SPRAY HEADER LEAK.
START BATE 3/79 END DATE 3/79
MODULE B EXPERIENCED A LEAK IN THE VENTURI DOWNCOMER. A FIVE FOOT SECTlOh
OF THE PIPE WILL HAVE TO BE REPLACED.
A
SYSTEM 7?0
189
-------
fPA UTILITY F&D SURVEY: THIRD QUARTER 1979
COMMONWEALTH EOISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERARIL1TY RELIABILITY UTILIZATION 2 REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
8 .S
SYSTEM 744 0
** PRObLEMS/SOLUTIONS/COWMENTS
START DATE 5/79 END DATE 5/79
UNIT 1 WAS OUT OF SERVICE THE ENTIRE MONTH DUE TO A BOILER OVERHAUL.
START DATE 10/7P END DATE 5/79
CHICAGO ADMIXTURES WILL STOCKPILE THE FIXED SLUDGE ON STATION PROPERTY.
6/79 SYSTtM 720 0
7/79 SYSTEM 744 0
8/79 SYSTEM 744 0
** PROBLEMS/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 8/79
UNIT 1 WAS OUT OF SERVICE TO REPLACE THE AIR HEATER TUBES, TUBE SHEEl AND
HOPPERS. DURING THIS OUTAGE, THE WORN VENTURI SPRAY NOZZLES AND DEfllSTERS
WERE REPLACED. WELDING LEAKS AND GENERAL CLEANING OF THE 502 INTERNALS
WAS ALSO DONE AT THIS TIME.
START DATE 6/79 END DATE 8/79
THE BOILER AND THE SCRUBBER ARE SCHEDULED TO RETURN TO SERVICE OCTOBER 1,
1979.
190
-------
EPA UTILITY FGD SURVEY: THIRD 6UARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARMCULATE SCRUBBERS
COMPANY NAME
PLANT MAKE
UNIT NUMEER
CITY
STATE
REGULATORY CLASSIFICATION
S02 EMISSION LIMITATION - MG/J
NET PLANT GENERATING CAPACITY - «U
GROSS UNIT GENERATING CAPACITY - MS,
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
DETROIT EDISON
ST. CLAIR
6
BELLE RIVER
MICHIGAN
c
1376.
1775.0
325.0
<****** LB/PIMBTU)
< 3.200 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 - «
FUEL DATA
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTW/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - %
AVERAGE MOISTURE CONTENT - %
RANGE MOISTURE CONTENT - %
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 2
RANGE CHLORIDE CONTENT - %
COMBUSTION ENGINEERING
TWO-STAGE SUPERHEATER
BASE
0/61
******** {******
13?.2 ( 270 F)
****** {**** FT)
******* (***** FT)
COAL
SUBBITUMINOUS
4.00
I****** BTU/LB)
9,500 - 9,600
22 - 24
.35
0.3 - 0.4
** ESP
** MECHANICAL COLLECTOR
** PARTICULATE SCRUBBER
NUMBER
TYPE
VENTURI
191
-------
EPA UTILITY F&D SURVEY: THIRD QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE 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 - NW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - MU
NET UNIT GENERATING CAPACITY WO/FGC - MU
EOU1VALENT SCRUBBED CAPACITY - WU
MINNESOTA POWER & LIGHT
AURORA
AURORA
MINNESOTA
******
258.
116.0
58.0
57.3
58.0
58.0
.600 LB/MHBTU>
>**** LB/MMBTU)
BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.B/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - «
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 - Z
AVERAGE MOISTURE CONTENT - Z
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - Z
MECHANICAL COLLECTOR
NUMBER
COMBUSTION ENGINEERING
PULVERIZED COAL. BALANCED DRAFT
***** *
0/53
141.57 ( 300000 ACFM>
171.1 < 340 F>
****** ( * * * * f T->
******* (***** FT}
COAL
SUBBITUHINOUS
20469.
9.00
******
26.70
******
1.37
( 8800 BTU/LB1
** *** *
.01
0.00-0.07
PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.H/S
FLUE GAS TEMPERATURE - c
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.K
PARTICULATE OUTLET LOAD - G/CU.PI
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - Z
ELBAIR SPRAY-IMPINGEMENT
KREBS ENGINEERING
316 ELC STAINLESS STEEL
FLAKE-POLYESTER
100.0
137.4 ( 291160 ACFM>
171.1 340 F>
1.1 8.3 GAL'IOOOACF)
******* ***** JN-H20)
2.1 7.0 FT/S)
4.7 2.06 GR/SCF)
.1 .040 GR/SCF)
800.000
500.000
37.0
192
-------
EPA UTILITY FGD SURVEY; THIRD QUARTER 1979
SECTION 14
DESIGN AMD PERFORMAKCL DATA FOR OPERATIONAL PARTlCULATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTlCULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - liiG/J
NET PLANT GENERATING CAPACITY - HW
GROSS UNIT GENERATING CAPACITY - wt
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY UC/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MM
** 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/6
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 2
RANGE ASH CONTENT - %
AVERAGE MOISTURE CONTENT - %
RANGE MOISTURE CONTENT - 2
AVERAGE SULFUR CONTENT - %
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - 7,
MINNESOTA POWER *. LIGHT
AURORA
l
AURORA
MINNESOTA
( .600 LB/MMBTU)
{**««*. LB/MMBTU)
258.
116.C
5B.O
57.3
58.0
58.0
COMBUSTION ENGINEERING
PULVERIZED COAL, BALANCED DRAFT
0/53
141.57
171.1
COAL
SURBITUMINOUS
20469.
( 300000 ACFM)
< 340 F)
(**** FT)
(*«*** FT)
< 8800 BTU/LB)
•5.00
26.70
1.37
.01
D. 00-0.07
** MECHANICAL COLLECTOR
NUMBER
** PARTlCULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
BOILER LOAD/SCRUBBER - X
fLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - c
L/F RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL 6AS VELOCITY - M/S
PARTlCULATE INLET LOAD - G/CU.K
PARTlCULATE OUTLET LOAD - G/CU.H
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
1
ELBAIR SPRAY-I*P1NGEMENT
KREBS ENGINEERING
316 ELC STAINLESS STEEL
FLAKE-POLYESTER
100.0
137.4 ( Z91160 ACFM)
171.1 ( 340 F»
1.1 ( S.3 GAL/1000ACF)
******* (***** JN-H20)
J.1 ( 7.0 FT/S)
4.7 < H.06 GR/SCF)
.1 ( .040 GR/SCF)
300.000
500.COO
37.0
193
-------
EPA UTILITY FGD SURVEY: THIRD GUARTtR 1979
SECTION 14
DESIGN AND PERfOR MANC£ DATA FOR OPERATIONAL PARTICULATE 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 - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - HU
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - Mki
** BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE 6AS TEMPERATURE - C
STACK HEIGHT - B
STACK TOP DIAMETER - M
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTUALB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
** MECHANICAL COLLECTOR
NUMBER
*» PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
INTERNAL MATERIAL
BOILER LOAD/SCRUBBER - X
FLUE GAS TEMPERATURE - C
LIQUID REC1RCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - H/S
MINNESOTA POWER 8 LIGHT
CLAY BOSWELL
3
COHASSET
MINNESOTA
LB/«HBTU>
LP/MMBTU)
350.0
347.1
350.0
350.C
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
0/73
613.47 0300000 ACFM)
123.3 I 254 F)
****** t**** FT>
******* <**.*» FT>
COAL
SUBBITUMINOUS
19538. < 8400 BTU/LBJ
******
9.00
26.00
.92
.01
SPRAY IMPINGEMENT
KREBS ENGINEERING
2
316L SS
316L S.S.
110.0
123.3
714.4
1.1
2.4
( 254 F)
C11340 6P«>
( 8.3 GAL/1000ACF)
C***** IN-H20)
t 8.0 TT/S)
194
-------
EPA UTILITY FGD SURVEY; THIRD QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME MONTANA-DAKOTA UTILITIES CO.
PLANT NAME LEWIS 8 CLARK
UNIT NUMBER ******
CITY ******
STATE ******
REGULATORY CLASSIFICATION ******
PARTICULATE tMISSION LIMITATION - NG/J ****** (*..*** LO/MMBTU)
S02 EMISSION LIMITATION - NG/J ****** (***,,* LB/M«BTU>
NET PLANT GENERATING CAPACITY - MW *******
GROSS UNIT GENERATING CAPACITY - 1w *******
NET UNIT GENERATING CAPACITY W/FGD - MW *******
NET UNIT GENERATING CAPACITY UO/FGD - MW *******
EQUIVALENT SCRUBBED CAPACITY - WW *******
** BOILER DATA
SUPPLIER ******
TYPF ******
SERVICE LOAD ******
COMMERCIAL SERVICE DATE **/**
MAXICtUH BOILER FLUE GAS FLOW - CU.IWS ******** (******* ACFM)
FLUF GAS TEMPERATURE - C ******* c***'* F>
STACK HEIGHT - M ****** (**** FT)
STACK TOP DIAMETER - M ******* (***** FT)
** FUEL DATA
FUEL TYPE COAL
FUEL GRADE LIGNITE
AVERAGE HEAT CONTENT - J/G ******* (****** BTU/LFJ)
RANGE HEAT CONTENT - BTU/LB ******
AVERAGE ASH CONTENT - X 9.00
RANGE ASH CONTENT - % ******
AVERAGE MOISTURE CONTENT - ?! ********
RANGE MOISTURE CONTENT - Z ******
AVERAGE SULFUR CONTENT - X .45
RANGE SULFUR CONTENT - 1. ******
AVERAGE CHLORIDE CONTENT - T ********
RANGE CHLORIDE CONTENT - 2 ******
** MECHANICAL COLLECTOR
NUMBER 1
** PARTICULATE SCRUBBER
TYPE
SUPPLIER
L/G RATIO - LITER/CU.H
PRESSURE DROP - KPA
VENTURI-FLOODED DISC
RESEARCH COTTERELL
1.7 (13.0 6AL/1000ACF)
******* {***** IN-H20)
195
-------
EPA UTILITY FGO SURVEY: THIRD QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - KS/J
SOZ EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - My
NET UNIT GENERATING CAPACITY WO/FGD - MW
EOUIVALENT SCRUBBED CAPACITY - WW
PACIFIC POWER & LIGHT
DAVE JOHNSTON
4
6LENROCK
WYOMING
90.
215.
330.0
326.5
330.0
33.0
.210 LB/HMBTU)
.500 IB/MHBTU)
** 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 - 2
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 1
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - %
RANGE CHLORIDE CONTENT - X
COMBUSTION ENGINEERING
PULVERIZED COAL, BALANCED DRAFT
>/**
707.85
132.2
76.
COAL
SUBBITUMINOUS
17282.
12.00
26.00
.50
*** #**
.04
(1500000 ACFH)
( 270 F)
< 250 FT»
(***** FT)
t 7430 BTU/LB)
SiOOO-9,000
•* PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L1TER/CU.K
PRESSURE DROP - KPA
PARTICULATE INLET LOAD - G/CU.fl
PAHTICULATE DESIGN REMOVAL EFFICIENCY
SOZ INLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
VENTURI. PLUMB BOB
CHEHICO
STEEL. 3/8" AT VENTUR1 THROAT
POLYESTER-LINED STEEL
327.5
135.0
4Q9.5
1.3
9.2
99.7
459.000
40.0
< 694000 ACFM)
( 275 F)
( 6500 6PM)
( 9.4 GAL/100CACF)
(***** IN-H20)
< 4.00 6R/SCF)
196
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTlCULATE SCRUBBERS
I-OMPANY NAME POTOMAC ELECTRIC POWER
"LANT NAME CHALK POINT
UN1T NUMBER ******
STATE " MARYLAND
REGULATORY CLASSIFICATION ******
PARTlCULATE EMISSION LIMITATION - NG/J ****** (*«»*** LP/KMBTU)
* BOILER DATA
SUPPLIER ******
TypE ******
SERVICE LOAD BASE
COMMERCIAL SERVICE DATt **/**
MAXIMUM BOILER FLUE GAS FLOW - CU.K/S ******** C******* ACF«>
FLUE GAS TEMPERATURE - C ******* (**** f)
STACK HEIGHT - N *"*** «"*'* "1
STACK TOP DIAMETER - M ******* (»**** FT)
** FUEL DATA
FUEL TYPE OIL
IvERAGEAHEAT CONTENT - J/G ******* I****** BTU/LB)
RANGE HEAT CONTENT - BTU/LB ******
AVERAGE ASM CONTENT - X ********
RANGE ASH CONTENT - X ******
AVERAGE MOISTURE CONTENT - % ********
RANGE KOISTURE CONTENT - Z ******
AVERAGE SULFUR CONTENT - 'A ********
RANGE SULFUR CONTENT - X ******
AVERAGE CHLORIDE CONTENT - Z ********
RANGE CHLORIDE CONTENT - * ******
197
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PART1CULATE SCRUBBERS
COMPANY NAME POTOMAC ELECTRIC POWER
PLANT NAME DICKERSON
UNIT NUMBER 1
CITY DICKERSON
STATE MARYLAND
REGULATORY CLASSIFICATION ******
PARTICULATE EMISSION LIMITATION - N6/J ****** (**..** L0/HMBTU)
S02 EMISSION LIMITATION - NG/J ****** c****** LP/BBBTU)
NET PLANT GENERATING CAPACITY - fU 1348.Q
&ROSS UNiT GENERATING CAPACITY ~ MW 190.0
NET UNIT GENERATING CAPACITY y/FGD - HV 183.0
NET UNIT GENERATING CAPACITY WO/FGL - «W *******
EQUIVALENT SCRUBBED CAPACITY - MU *******
** BOILER DATA
SUPPLIER ******
TYPE ******
SERVICE LOAD ******
COMMERCIAL SERVICE DATE **/**
MAXIMUM BOILER FLOE GAS FLOW - CU.M/S ******** {******* ACFM)
FLUE GAS TEMPERATURE - C ******* c**** ft
STACK HEIGHT - M ****** (**** fT)
STACK TOP DIAMETER - H ******* (***"** FT)
** FUEL DATA
FUEL TYPE COAL
FUEL GRADE ******
AVERAGE HEAT CONTENT - J/G E7214. C 11700 BTU/LBJ
RANGE HEAT CONTENT - BTU/LB ******
AVERAGE ASH CONTENT - 2 14.00
RANGE ASM CONTENT - % ******
AVERAGE MOISTURE CONTENT - Z ********
RANGE MOISTURE CONTENT - X ******
AVERAGE SULFUR CONTENT - % 2.00
RANGE SULFUR CONTENT - * ******
AVERAGE CHLORIDE CONTENT - 3! ********
RANGE CHLORIDE CONTENT - X ******
** PARTICULATE SCRUBBER
NUMBER OF STAGES 2
198
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME POTOMAC ELECTRIC POWER
PLANT NAWF D1CKERSON
UNIT NUMBER 2
CITY BlCKERSQN
STATE MARYLAND
REGULATORY CLASSIFICATION .***..
PARTICULATE EMISSION LIMITATION - tvG/J ****** (****«* LB/MMBTU>
S02 EMISSION LIMITATION - NG/J ****** (**.*** LB/MMBTU)
NET PLANT GENERATING CAPACITY - MW 1348.0
GROSS UNIT GENERATING CAPACITY - MW 190.0
NET UNIT GENERATING CAPACITY W/f6D - MW 183.0
NET UNIT GENERATING CAPACITY WO/FGD - KW *******
EQUIVALENT SCRUBBED CAPACITY - MW *******
** BOILER DATA
SUPPLIER ******
TYPE ******
SERVICE LOAD ******
COMMERCIAL SERVICE DATE **/**
MAXIMUM BOILER FLUE GAS FLOW - CU.K/S ******** (**.«*.* ACFM)
FLUE GAS TEMPERATURE - C ******* (**** f)
STACK HEIGHT - M ****** (.*** fT)
STACK TOP DIAMETER - M ******* {***** FT)
** FUEL DATA
FUEL TYPE COftL
FUEL GRADE ******
AVERAGE HEAT CONTENT - J/G 272U. ( 11700 BTU/LB)
RANGE HEAT CONTENT - ETU/LB ******
AVERAGE ASH CONTENT - X 14.00
RANGE ASH CONTENT - Z ******
AVERAGE MOISTURE CONTENT - * ********
RANGE MOISTURE CONTENT - 2 ******
AVERAGE SULFUR CONTENT - % 2.00
RANGE SULFUR CONTENT - 7. ******
AVERAGE CHLORIDE CONTENT - Z ********
RANGE CHLORIDE CONTENT - % ******
** PARTICULATE SCRUBBER
NUMBER OF STAGES 2
199
-------
EPA UTILITY FGD SURVEY: THIRD UUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - Mfc
NET UNIT GENERATING CAPACITY W/FGO - MU
NET UNIT GENERATING CAPACITY WO/FGD - HU
EQUIVALENT SCRUBBED CAPACITY - MW
POTOMAC ELECTRIC POWER
DICKERSON
3
DiCKERSON
MARYLAND
688.
548.0
190.0
183.0
(****** LB/KMBTU)
( 1.600 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 - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
RANGE MOISTURE CONTENT - 1
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - Z
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
0/62
278.43 t 590000 ACF*>
126.1 ( 259 F>
122. t 400 FT)
******* {***'** FT)
COAL
******
27214.
14.00
******
2.00
( 11700 BTU/LB)
******
ESP
NUMBER
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
BOILER LOAD/SCRUBBER - Z
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
L/G RATIO - LITER/CU.n
PRESSURE DROP - KPA
RESEARCH COTTRELL
- Z 94.0
ADJUSTABLE VENTURI
CHEMICO
50.0
139.2 < 295000 ACFM)
126.1 ( 259 F)
2.7 <20.0 GAL/1000ACF>
******* c***** IN-H20>
200
-------
tPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION u
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - Ml,
NET UNIT GENERATING CAPACITY W/FGD ~ MW
NET UNIT GENERATING CAPACITY UO/FGC - MW
EQUIVALENT 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 - «
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - *
RANGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - %
RANGE CHLORIDE CONTENT - %
PUBLIC SERVICE OF COLORADO
ARAPAHOE
A
DENVER
COLORADO
43.
11.2
109.8
11.2
PULVERIZED COAL
0/55
245.39
148.9
t .100 LP/MMBTU)
{****.* LB/MMBTU)
< 52GOOO ACFH)
( 300 F)
t**** FT)
<***** FT)
COAL
SUBS ITUMI NOUS
23725.
9.30
13.70
.95
.01
< 10200 BTU/LB)
** 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 - Z
RANGE MOISTURE CONTENT - %
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - f.
RANGt CHLORIDE CONTENT - 5£
" ESP
NUMBER
•* MECHANICAL COLLECTOR
NUMBER
** PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
L/G RATIO - LITER/CU.K
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - P/S
PARTICULATE INLET LOAD - G/CU.P
PARTICULATE OUTLET LOAD - t/CU.*»
PARTICULATE DESIGN REMOVAL EFFICIENCY
COAL
23493.
12.50
11.20
.65
.01
t 10100 BTU/LB)
2
TCA
AIR CORRECTION DIVISIONt UOP
CARBON STEEL
RUBBER
STAINLESS STEEL, PLASTIC SPHERES
7.5 (56.0 GAL/1000ACF)
******* (***** IN-H20)
3.4 t 11.0 FT/S)
1.8 f .80 GR/SCF)
.0 < .020 GR/SCF)
93.0
2G1
-------
EPfc UTILITY FGD SURVEY: THIRD CUAKTER 1979
PUPL1C SCRVICc. OF COLORADO; ARAPAHOE t (CONT.)
S02 INLET CONCENTRATION - PPfl 500.000
$02 OUTLtT CONCENTRATION - PPM 350.000
SCU DESIGN RE^OVAL EFFICIENCY - i 30.0
2D2
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATt EMISSION LIMITATION - NG / J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - HU
GROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - My
NET UNIT GENERATING CAPACITY WO/FGC - BW
EQUIVALENT SCRUBBED CAPACITY - MW
** BOILER DATA
SUPPLIER
TYPF
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.H/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 - %
AVERAGE MOISTURE CONTENT - %
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - *
RANGE CHLORIDE CONTENT - X
PUBLIC SERVICE OF COLORADO
CHEROKEE
1
DENVER
COLORADO
43.
710.0
115.0
100.C
115.0
102.2
BABCOCK & W1LCOX
PULVERIZED COAL
.100 LB/MMBTU)
•**** LB/MMBTU)
0/57
245.39
146.1
COAL
BITUPUNOUS
23493.
( 520000 ACFM)
< 295 F)
<**** FT)
{*•*** FT)
( 10100 BTU/LB)
12.50
11.30
.65
.01
** ESP
NUMBER
" FIECHAMCAL COLLECTOR
NUMBER
** PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
BOILER LOAD/SCRUBBER - 2
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
L/G RATIO - LITER/CU.tf
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.K
PARTICULATE OUTLET LOAD - G/CU.K
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPK
S02 OUTLET CONCENTRATION - PPK
S02 DESIGN REMOVAL EFFICIENCY - X
1
TCA
AIR CORRECTION DIVISION,
3
CARBON STEEL
RUBBER
STEEL
UOP
STAINLESS
67.0
164.4
146.1
7.5
3.4
1.8
.0
97.0
500.000
420.000
16.0
1.5" PLASTIC SPHERES
( 348400 ACFH1
< 295 F)
(56.0 GAL/1000ACF)
(***** IN-H20)
11.0 FT/S)
.80 GP/SCF)
.020 GR/SCF)
203
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION 14
DESIGN AND PERFORMASCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY SAKE
PLANT NAKE
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - KU
GROSS UNIT GENERATING CAPACITY - Bk
NET UNIT GENERATING CAPACITY H/FGD - HU
NET UNIT GENERATING CAPACITY WO/FGC - MW
EQUIVALENT SCRUBBED CAPACITY - MH
** 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 - «
*• 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 - 7.
RANGE MOISTURE CONTENT - %
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
PUBLIC SERVICE OF COLORADO
CHEROKEE
3
DENVER
COLORADO
******
43.
710.0
170.0
150.0
170.0
152.6
BABCOCK g U1LCOX
PULVERIZED COAL
******
0/62
.100 LB/MNBTlO
>**** LB/MMBTU)
287.86
137.8
******
COAL
BITUMINOUS
23493.
12.50
******
11.30
( 610000 ACFM)
( 280 F)
(**** FT)
(*.*** FT)
( 10100 BTU/LB)
.65
.01
ESP
NUMBER
MECHANICAL COLLECTOR
NUMBER
PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - c
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.K
PARTICULATE OUTLET LOAD - G/CU.H
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPfl
SO? OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - t
2
TCA
AIR CORRECTION DIVISION, UOP
3
CARBON STEEL
RUBBER
STAINLESS STEEL, PLASTIC SPHERES
20.0
57.6 { 122000 ACFM)
137.8 ( 280 F)
7.5 (56.Q GAL/1000ACF)
******* i***** JN-H20)
3.4
.9
.0
95.0
500.000
420.000
16.0
11.0 FT/S)
.40 GR/SCF)
.020 GR/SCF)
204
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY MAKE
PLANT MAKE
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - NG/J
SOZ EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - Mw
KET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGl) - MW
EQUIVALENT SCRUBBED CAPACITY - «U
** BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATt
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 - 2
RANGE ASH CONTENT - %
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 2
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - %
PUBLIC SERVICE
CHEROKEE
I,
DENVER
COLORADO
OF COLORADO
43.
710.0
375.0
350.0
375.0
356.4
COMBUSTION ENGINEERING
PULVERIZED COAL
.100 LB/MMBTU)
***** LB/MHBTU)
D/6B
717.29
135.0
COAL
BITUMINOUS
23493.
12.50
11.30
.65
.01
M52QOGO ACFM)
< 275 F)
(***•* FT)
(**»** FT)
( 10100 BTU/LB)
** ESP
NUMBER
** MECHANICAL COLLECTOR
NUMBER
** PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
L/G RATIO - L1TER/CU.W
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD - G/CU.M
PARTJCULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - %
it
TCA
AIR CORRECTION DIVISION. UOP
3
CARBON STEEL
RUBBER
STAINLESS STEtL, PLASTIC SPHERES
7.5 C56.0 6AL/1000ACF)
******* (***** IN-H20)
3.4
1.6
.0
97.0
500.000
420.000
16.0
11.0 FT/S)
.70 GR/SCF)
.020 GR/SCF)
-------
EPA UTILITY F&D SURVEY: THIRD CUARTtK 1979
DESIGN AND PERFORMANCE
SECTION U
DATA FOR OPERATIONAL PARTUULATE SCRUBBERS
COMPANY NAME
PLANT NAPE
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - IVG/J
SOi EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - «V
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGC - MW
EQUIVALENT SCRUBBED CAPACITY - Ky
** 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 - W
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - %
RANGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - *
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - %
RANGE CHLORIDE CONTENT - X
PUBLIC SERVICE
VALMONT
5
VALMONT
COLORADO
43.
273.8
166.0
163.0
83.0
166.0
OF COLORADO
< .100 LB/MHBTU)
COMBUSTION ENGINEERING
PULVERISED COAL
BASE
0/64
436.98 < 9Z6000 ACFW)
126.7 C 260 F>
****** (***"* FT)
******* (*»*** FT>
COAL
SUBBITUHINOUS
25121.
6.00
5.4-7.0
15.00
12.7-18.3
.70
0.68-.73
I 108.00 BTU/LBJ
******
** ESP
NUMBER
TYPE
FLUE GAS CAPACITY - CU.M/S
** MECHANICAL COLLECTOR
NUMRER
FLUE GAS CAPACITY - CU.M/S
•* PARTICULATE SCRUBBER
NUMBER
TYPE
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
TYPE OF NOZZLES
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
COLD SIDE
218.5
1
218.5
2
TCA
3
CARBON STEEL
RUBBER
S.S.
25.
7.8
< 463000 ACFH)
C 463000 ACFM>
3.4
158.3 GAL/1000ACF)
C***** iN-HZO)
( 11.0 FT/S>
2C6
-------
FPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION U
DESIGN AND PERFORMAKCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - KG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - flU
GROSS UNIT GENERATING CAPACITY - Mk
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - My
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 - %
RANGE MOISTURE CONTENT - %
AVERAGE SULFUR CONTENT - %
RANGE SULFUR CONTENT - %
AVERAGE CHLORIDE CONTENT - 2
RANGE CHLORIDE CONTENT - %
SOUTHWESTERN PUBLIC SERVICE
HARRINGTON STATION
1
AMARILLO
TEXAS
350.0
******
** /**
(*****. LB/HMBTU)
(****** LB/MMBTU)
COAL
19538.
******
.50
<******* ACFM)
(**** fj
(**** ft)
(***** FT)
( 8400 BTU/LB)
** ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
** PARTICULATE SCRUBBER
TYPE
PARTICULATE DESIGN REMOVAL EFFICIENCY
SO? INLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - Z
1
COLD SIDE
RESEARCH COTTRELL
7. 95.0
MARBLE BED
X 99.0
400.000
50.0
207
-------
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 1978
report, the format and content of the cost appendix were revised
to include reported and adjusted costs for the operational FGD
systems.
The rationale for including adjusted as well as reported
costs stems primarily from the lack of comparability of the
reported costs. Many of the reported cost figures, both capital
and operating, are largely site-sensitive values that cannot be
accurately compared because they refer to different FGD battery
limits and different years in which the expenditures were made.
As a result, an analysis of the cost data was made for the opera-
tional units since these systems offer the potential of having
complete and accurate economic data. The adjustments were made
to provide comparable, accurate cost data for the sulfur dioxide
portion of the emission control system. This, in effect, will
eliminate much of the confusion that exists concerning the re-
ported data, and it will provide a common basis for the reported
costs.
A-2
-------
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.
° 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:
0 Direct Charges
Raw materials, including those required by the FGD
process for sulfur dioxide control, absorbent regenera-
tion, sludge treatment, sludge fixation, flocculants,
etc.
Utilities, including water for slurries, cooling and
cleaning; electricity for pumps, fans, valves, lighting
controls, conveyors, and mixers; fuel for reheating of
flue gases; and stream for processing.
Operating labor, including supervisory, skilled, and
unskilled labor required to operate, monitor, and
control the FGD process.
Maintenance and repairs, consisting of both manpower
and materials to keep the unit operating efficiently.
The function of maintenance is both preventive and
corrective to keep outages to a minimum.
Byproduct Sales; credit from the sale of byproducts
regenerable FGD processes (e.g. sulfur, sulfuric acid)
is a negative charge deducted from the annual direct
cost to obtain the net annual direct cost of the FGD
system.
0 Fixed Charges
Depreciation - the annual charge to recover direct and
indirect costs of physical assets over the life of the
asset.
Interim, replacement - costs expended for temporary or
provisional replacement of equipment that has failed or
malfunctioned prematurely.
Insurance, including the costs of protection from loss
by a specified contingency, peril, or unforeseen event.
Required coverage could include losses due to fire,
personal injury or death, property damage, explosion,
lightning, or other natural phenomena.
A-ll
-------
Taxes, including franchise, excise, and property taxes
levied by a 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:
a
Contingency
Direct annual costs:
Raw materials:
Fixation chemicals
Lime
Limestone
Magnesium oxide
Sodium carbonate
Salt cake (credit)
Sulfur (credit)
Sulfuric acid (credit)
Utilities:
Electricity
Water
Steam
Operating labor:
Direct labor
Supervision
10% of total direct capital costs
10% of total direct capital costs
5% of total direct capital costs
10% of total direct capital costs
2% of total direct capital costs
1% of total direct capital costs
5% of total direct capital costs
20% of total direct and indirect
capital costs
$2/ton
$40/ton
$10/ton
$150/ton
$80/ton
$50/ton
$65/ton
$25/ton
25 mills/kWh
$0.20/103 gal
$0.80/106 Btu
$8.50/man-hour
15% of direct labor costs
a 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
Particulate 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.
L
M
N
0
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, cen-
trifugation, or forced oxidation, which
ultimately produces a dry sludge cake
for final disposal, is included in the
total capital cost.
The cost of an off-site area used as a
landfill for flue gas cleaning wastes is
included in the total capital cost.
The cost of an on-site disposal area for
ponding of treated or untreated flue gas
cleaning wastes is included in the total
capital cost.
The cost of additional SO- waste disposal
capacity required for FGD system operation
over the anticipated service life of the
unit is included in the total capital cost.
The cost of the stack is included in the
total capital cost.
Modifications to existing equipment (stack,
fans, ducts, etc.) which are required be-
cause of inclusion of an FGD system.
Complete cost of entire regeneration
facility included in total capital cost.
Part of the cost associated with the re-*
generation facility included in the total
capital cost.
Bench scale or pilot plant studies to de-
termine process and design characteristics.
(continued)
A-16
-------
TABLE A-3. (continued)
Code
Title
Description
W
X
Costs underwritten by system supplier in-
cluded in capital cost.
Excess reagent supply costs included in
capital cost.
Total direct annual costs included.
Partial direct annual costs included.
Total fixed annual costs included.
Partial fixed annual costs included.
Overhead cost included in total annual
cost.
Particulate control costs included in
direct annual cost.
Sludge disposal service costs (contract)
included in direct annual cost.
Replacement energy costs included in
total annual costs.
Capital expenditures underwritten by the
system supplier for system repairs or
modifications for optimization of perfor-
mance or R 6 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, »/KU ANNUAL, HILLS/KUH---
RANGE AVG DEV RANGE AVG DEV
— ADJUSTED-
CAPITAL, «/KU ANNUAL, KILLS/KUH—
RANGE AVG DEV RANGE AVG DEV
AIL
NEM
RETROFIT
THROUAUAY PRODUCT
SALEABLE PRODUCT
LIMESTONE
DUAL ALKALI
LINE
LINE/ALKALINE FLYASH
SODIUM CARBONATE
UELLHAN LORD
LIHESTONE/ALKALINE FLYASH
HA6NESIUH OXIDE
29.2-232.5 90.3 52.4 .3- 14.9 5.4 4.7
31.8-232.5 94.8 58.1 .3- 14.3 4.1 4.5
29.2-154.9 83.9 41.9 2.1- 14.9 7.3 4.5
29.2-232.5 84.3 51.8 .3- 14.3 5.0 4.4
127.9-154.9 142.3 14.5 !4.9- 14.9 14.9 .0
31.8-232.5 103.7 47.9 1.3- 3.3 2.2 .7
43.2-189.0 94.7 45.5 3.2- 3.2 3.2 .0
29.2-120.4 73.4 32.1 5.8- 14.3 9.7 3.4
77.1- 85.9 80.0 4.1 .3- .3 .3 .0
42.9-113.4 44.5 33.3 2.1- 2.1 2.1 .0
127.9-154.9 137.4 13.7 14.9- 14.9 14.9 .0
47.9- 47.9 47.9 .0 2.0- 2.0 2.0 .0
154.7-154.7 154.7 .0 «*«*»- .0 .0 .0
40.9-233.2 94.2 35.2 2.7- 12.4 3.5 2.4
66.4-117.6 85.5 16.9 2.8- 8.7 5.2 2.0
40.9-233.2 103.4 45.B 2.7- 12.4 5.8 2.4
40.9-140.6 87.0 21.2 2.7- 8.7 3.2 1.9
134.8-233.2 184.0 49.2 12.4- 12.4 12.4 .0
46.4-117.6 93.1 21.9 2.9- 6.6 5.0 1.4
*»**•- .0 .0 .0 **•**- .0 .0 .0
67.5-140.6 90.8 22.2 2.7- B.7 6.4 2.0
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
71.5- 71.5 71.5 .0 2.8- 2.8 2.8 .0
233.2-233.2 233.2 .0 •*«»*- .0 .0 .0
-------
FCA UTILITY FI.D SURVEY: TH1KP OUARTIR T.-
ALABAMA ELECTRIC COOP
TOI»BI&BEE
3
179.0 MW (NET)
SECTION A-1
COSTS FOR OPERATIONAL FGO SYSTEMS
UNIT DESCRIPTION
ALAUAMA ELECTRIC COOP
TO^FU&BLE
179. C MW (NET)
COST DESCRIPTION
CAPACITY FACTOR, X
TOTAL CAPITAL, 1/KW(YEA")
TOTAL ANNUAL, KILLS /K WH ( YE A9 )
COST ELEMENTS
REPORTED
***
A,D
ADJUSTED
65
STANDARDIZED
ADJUSTED
65
CAPACITY FACTOR, X ***
TOTAL CAPITAL, $/KU(YEAR) 69.5(1978)
TOTAL ANNUAL, HILLS/K WH ( YE AR ) ****««( 0)
COST ELEMENTS C.E.J
65
65
o» ***•**( 01
o> *••*••( C>
ARIZONA ELECTRIC POWER COOP
A PA: HE
2
195.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, PILL.S/KMH ( YE AR>
COST ELEMENTS
44 65
35.9(1977) **«***(
2.1(19781 ****•*(
C ,E,H,J,L,S,
U,W,Y,Z
0)
01
65
OJ
0)
ARIZONA ELECTRIC POWER COOP
APACHE
-i
195.0 My (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/Ky(YEAft)
TOTAL ANNUAL, KILLS/KUH(YEAR)
COST ELEMENTS
44 65
31.8<7700) ****«*(
2.1M97S) ******€
C,E,H,J,L,S,
U.H.Y.Z
65
0) .....M
0) *****«(
0)
0)
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
37S.Q rtw (NET)
CAPACITY FACTOR, Z
TOTAL CAPITAL, S/Ky(VEAR>
TOTAL ANNUAL, "ILLS/KWH(YEARJ
COST ELEMENTS
*** 65
93.3(1978) «*****(
3.3<1976) *****•<
C.E.J.H
65
0>
0)
CENTRAL ILLINOIS PUBLIC SERV
NEUTON
1
617.0 MU (NET)
CAPACITY FACTOR, X ***
TOTAL CAPITAL, S/KU(YEAR) 189.0(1979)
TOTAL ANNUAL, MILLS/KWH ( YE AR) ******( 0)
COST ELEMENTS C,E,G
65
65
0) ******( 0)
0) *****»{ 0)
COLUMBUS S SOUTHERN OHIO ELEC.
CONESVILLE
5
411.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, f/KU(YEAR>
TOTAL ANNUAL, MILLS/KUN(YEAR>
COST ELEMENTS
48 65 65
55.5(1975) 70.7O977) 70.7(1977)
5.8(1978) 7.4(1977) 7.4(1977)
B.C.J.M.S.U, C,E. J,M,S,L!, C.E.J.M.S.U,
U,X,Y U,Y U,Y
COLUMBUS K SOUTHERN OHIO ELEC.
CONESVILLE
6
411.0 MW (SET)
CAPACITY FACTOR, X
TOTAL CAPITAL. $/KU(YEAR)
TOTAL ANNUAL, WILLS /KWH ( YE AR )
COST ELEMENTS
48 65
55.5(1978) 70.7(1977)
5.8(1978) ****»»{ 0)
O.C.J.FI.S.U, C,E,J,M,S,U,
W.X.Y W,Y
65
C>
0)
DUOUESNE LIGHT
ELRAMA
1-4
510.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KU(YEAR)
TOTAL ANNUAL, MI LLS/K WH ( YE AR )
COST ELEMENTS
64 65 65
11J.4(1976) 127.1(1977) 127.1(1977)
8.6(1977) 7.8(1977) 7.5(1977)
B,D,F,I,J,M, C,E,1,J,H,S. C.E.I.J.H.S,
T,V,X,Y U,Y U,Y
DutUESNE LIGHT
PHILLIPS
1-6
41j.Q HW (NET)
CAPACITY FACTOK, X
TOTAL CAPITAL, J/KW(YEAR)
TOTAL ANNUAL, I»I LL S /K UH ( YE A R )
COST ELEMENTS
70 65 65
106.9(1973) 140.6(1977) 140.6(1977)
7.8(1977) 8.6(1977) 8.2(1977)
B,D,F,I,J,M, C,E,1,J,M,S, C.E.I.J.M.S,
T.V.X.Y U,Y U,Y
INDICATES COST FIGURES NOT YET AVAILABLE
A- JO
-------
tPA UTILITY F6D SURVEY: THIRD QUARTER 1979
SECTION A-1
COSTS FOR OPERATIONAL FGD SYSTEMS
------ --- — -
UNIT DESCRIPTION COST DESCRIPTION REPORTED ADJUSTED STANDARDIZED
ADJISTEO
INDIANAPOLIS POWER & LIGHT CAPACITY FACTORt X **« 65 "II
PETERSBURG TOTAL CAPITAL, £/ 99.5(1976) 100.6(1977) 100-6(1977)
3 "TAL ANNUAL, HI LLS /K WH ( YE AR ) .«****( 0) 6.6C1977) 7.4(1977)
532.0 HW (NET) COST ELEMENTS C.F.6.J.H C , E , G,J ,M, S , C .E ,6 .J.H.S .
U.W.Y U.W.Y
KANSAS CITY POWER R LIGHT CAPACITY FACTOR, X U 65 65 ~"
HAWTHORN TOTAL CAPITAL, $/KW(YEAR) 29.2(1972) 87.2(1977) 87. 2(1977)
3 TOTAL ANNUAL, HI LLS /K WH ( YEA R ) 8.4(1977) 4.3(1977) 4.4(1977)
90.0 PIN (NET) COST ELEMENTS B.O.F.T.X B,C,E,J,K,S, B ,C , E ,J ,K , S .
u,y,x u,w,x
KANSAS CITY POWER 8 LIGHT CAPACITY FACTOR, % *** 65 65
HAWTHORN TOTAL CAPITAL, t/KU(YEAR) 29.2(1972) 87.2(1977) 87.2(1977)
4 TOTAL ANNUAL, MILLS /K WH (YE AR ) 8.4(1977) 4.3U977) 4.4(1977)
90.0 HW (NET) COST ELEMENTS B,D,F,T,X B.C.E.J.K.S, B,C,E,J,K,S,
U,W,X U,W,X
KANSAS CITY POWER £ LIGHT CAPACITY FACTOR, % 42 65 65
LA CY6NE TOTAL CAPITAL, $/KW(YEAR) 53.6(1972) 68.0(1977) 68.0(1977)
1 TOTAL ANNUAL, RILLS /KUH( YE AR ) 1.3(1978) 3.8(1977) 3.9(1977)
B74.0 MW (NET) COST ELEMENTS T C,E,J,K,S,U C,E,J,K,S,U
KENTUCKY UTILITIES CAPACITY FACTOR, X 16 65 65
6REEN RIVER TOTAL CAPITAL, $/Khl(YEAR> 70.3(1975) 77.5(1977) 77.5(1977)
1-3 TOTAL ANNUAL, MILLS /KWH (YEAR ) 14.3(1977) 2.7(1977) 5.2(1977)
64.0 MH (NET) COST ELEMENTS B,C,E,J,S,U, C,E,J,S,U,W C,E,J,S,U,W
w
LOUISVILLE GAS & ELECTRIC CAPACITY FACTOR, % 55 65 65
CANE RUN TOTAL CAPITAL, $/KW(YEAR) 66.5(1975) 80.6(1977) 80.6(1977)
4 TOTAL ANNUAL, WILLS /KWH ( YE AR ) ******(1977) 5.8(1977) 6.2(1977)
188.0 HW (NET) COST ELEMENTS C,E,H,J,Q,T C,E,H,J,K,Q, C,E,K,J,K,0,
s.u.u s.u.w
LOUISVILLE GAS & ELECTRIC CAPACITY FACTOR, X *** 65 65
CANE RUN TOTAL CAPITAL, f/KW(YEAR) 62.4(1977) 67.5(1977) 67.5(1977)
5 TOTAL ANNUAL, MI LLS/KWH ( YE AR ) *«****( 0) 5.6(1977) 5.6(1977)
190.0 MM (NET) COST ELEMENTS C,E,H,J C,E,H,J,K,S, C,E,H,J,K,S,
u,u u.w
LOUISVILLE GAS & ELECTRIC CAPACITY FACTOR, X *** 65 65
CANE RUN TOTAL CAPITAL, $/KW(YEAR) 57.9(1977) ******( 0) ******( 0)
6 TOTAL ANNUAL, HILLS/KUH ( YE AR ) 3.2(1979) ******( 0) ******( 0)
288.0 MW (NET) COST ELEMENTS C,E,H,M,S,V,
W
LOUISVILLE GAS & ELECTRIC CAPACITY FACTOR, X *** „,,„,.„ " ,,,D,,, 7? i/1O77^
PADDY'S RUN TOTAL CAPITAL, S/KWCYEAR) 52.8(1973) 76.4(1977) 76.4(1977)
6 TOTAL ANNUAL, KILLS /KWH ( YE AR ) ******( 0) 6.5(1977) 6.4(1977)
72.0 HW (NET) COST ELEMENTS C.E C,E, S.U.W C .E . S.U.W
"INNKOTA POWER COOPERATIVE CAPACITY FACTOR, X *** ....,,. " n,tO77% ol TMC771
MILTON R. YOUNG TOTAL CAPITAL. S/KW(YEAR) 85.9 1976 «-°.C""J |'- 1077
2 TOTAL ANNUAL, HI LLS /K WH ( YE AR ) ******( 0) 5.2(1977) 5.^(1977)
405.0 MW (NET) COST ELEMENTS C.E.H.P C,E,H,M,P,S, C.E.H.M.P.S.
*.*.«« H.DICATES COST FIGURES MOT YET AVAILABLE
A- 21
-------
EPA UTILITY FGO SURVEY: THIKD CUARTCR 1979
SECTION A-1
COSTS FOR OPERATIONAL FGD SYSTEMS
COST
UNIT DESCRIPTION COST DESCRIPTION REPORTED ADJUSTED STANDARDIZED
ADJUSTED
MONTANA POWER CAPACITY FACTOR, X 76 65 65
COLSTRIP TOTAL CAPITAL, S/KWCYEAR) 77.1(1975) 77.2(1977) 77.2(1977)
1 TOTAl ANNUAL, KILLS/KWH(YEAR) .3(1977) 4.1(1977) 4.CM977)
360.C MW (NET) COST ELEMENTS B.C.E.J.P.T C,E,J .K,P.S. C ,E ,J ,K , P , S ,
u.w u.u
MONTANA POWER CAPACITY FACTOR, i 76 65 65
COLSTRIP TOTAL CAPITAL, t/KW(YEAR) 77.1(1975) 77.2(1977) 77.2(1977)
2 TOTAL ANNUAL, I'll LLS/KWH (TEAR) .3(1977) 4.1(1977) 4.1(1977)
36G.U MW (NET) COST ELEMENTS B.C.E.J.P.T C,E.J.K.P.S, C,E,J .K.P.S.
u,y u.w
NEVADA POWER CAPACITY FACTOR, Z 67 65 65
REID GARDNER TOTAL CAPITAL, $/KW(YEAR) 42.9(1973) 60.9(1977) 6C.9O977)
1 TOTAL ANNUAL, MILLS/KWH(YEAR) 2.1(1977) 3.2(1977) 3.4(1977)
.25.0 MW (NET) COST ELEMENTS B,D,E,P,S,U, B.D.E.P.S.U, B.D.E.P.S.U,
W,X W,X W,X
NEVADA POyER CAPACITY FACTOR, Z 67 65 65
REID GARDNER TOTAL CAPITAL, S/KW(YEAR) 42.9(1973) 60.9(1977) 60.9*1977)
2 TOTAL ANNUAL, HILLS/KWH(YEAR) 2.1(1977) 3.2(1977) 3.4(1977)
125.0 NU (NET) COST ELEMENTS 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 CAPACITY FACTOR, X 67 65 65
REID GARDNER TOTAL CAPITAL, $/KW(YEAR) 113.6(1975) 107.9(1977> 107.9(1977)
3 TOTAL ANNUAL, MI LLS/K WH (YE AR) 2.H1977) 4.4(1977) 5.0(1977)
125.0 MW (NET) COST ELEMENTS B,C,E,L,S,U, B.C.E.L.S.U. B.C.E.L.S.U,
W.X W.X W.X
NORTHERN INDIANA PUB SERVICE CAPACITY FACTOR, X 77 65 65
DEAN H. MITCHELL TOTAL CAPITAL, S/KWCYEAR) 156.9(1976) 134.8(1977) 134.8(1977)
11 TOTAL ANNUAL, MI LL S /K WH (YE AR) 14.9(1976) 12.4(1977) 11.0(1977)
115.0 MW (NET) COST ELEMENTS B,C,E,L,N,S, C.E.L.N.S.U. C.E.L.N.S.U,
,> U.W.X.Z U.Z. U,Z
NORTHERN STATES POWER CAPACITY FACTOR, t 73 65 65
SHEKBURNE TOTAL CAPITAL, $/KW(YEAR) 47.9(1972) 71.5(1977) 71.5(1977)
1 TOTAL ANNUAL, MILLS/KHH (YE AR) 2.0(1977) 2.8(1977) 3.3(1977)
740.0 MU (NET) COST ELEMENTS B,C,J,S,U,X, C.E.J.K.S.U. C,E,J,K,S,U.
I W W
NORTHERN STATES POWER CAPACITY FACTOR, % 73 65 65
SHERBURNF TOTAL CAPITAL, $/KW(YEAR) 47.9(1972) 71.5(1977) 71.5(1977)
2 TOTAL ANNUAL, »lLLS/KWH(YEAR) 2.0(1977) 2.8(1977) 3.3(1977)
740.0 MW (NET) COST ELEMENTS B,C,J,S,U,X, C , E, J.K ,S,U, C ,E , J ,K , S.U ,
Z W U
PENNSYLVANIA POWER CAPACITY FACTOR, % 40 65 65
BRUCE MANSFIELD TOTAL CAPITAL, $/KW(YEAR) 120.6(1975) 102.1(1977) 102.1(1977)
1 TOTAL ANNUAL, MILLS/KUH(YEAR) 14.3(1977) 8.7(1977) 10.6(1977)
917.C MW (NET) COST ELEMENTS B,C,E,G,I,L, C.E.C.I,M.S. C.E.G.I.P.S,
S.U.W.X U,W U,W
PENNSYLVANIA POWER CAPACITY FACTOR, % 40 65 65
BRUCE MANSFIELD TOTAL CAPITAL, $/KW(YEAR) 120.6(1975) 102.1(1977). 102.1(1977)
2 TOTAL ANNUAL, MILLS/KWH(YEAR) 14.3(1977) 8.7(1977) 1C.£(1977)
917.0 MW (NET) COST ELEMENTS B.C.E.G.I.I. C,E.G.I.M.S. C,E.G.I,M.S.
S.U.W.X U.W U.W
«».»«* INDICATES COST FIGURES NOT YET AVAILABLE
A- 22
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION A-1
COSTS FOR OPERATIONAL FGD SYSTEMS
————————— — ——— — .. ____ _-.„ _____»»__ — — -.________ —»»_»•.. — — -.«.— — —.__..__..___»_._._ ___. __..____.._«_..___ __ .••••••
COST
UNIT DESCRIPTION COST DESCRIPTION REPORTED ADJUSTED STANDARDIZED
ADJLSTED
PHILADELPHIA ELtcTRlc CAPACITY FACTOR. X **« 65 65
EDDYSTONE TOTAL CAPITAL, S/KW(YFAR) 156.7(1972) 233.2(1977) 233.2(1977)
1A TOTAL ANNUAL, MILLS/KWH(YEAR) ******(1972) *****»(1977) ******(1977)
120.0 HW (NET) COST ELEMENTS D.F.N.P C.E.N.P C.E.N.P
PUBLIC SERVICt OF NEW MEXICO CAPACITY FACTOR, % *** 55 65
SAN JUAN TOTAL CAPITAL, J/KW(YEAR) 127.9(1977) **«**.( 0) «...*.( C)
1 TOTAL ANNUAL, f!I LLS/KWH ( YEAR ) ******( 0) ******{ Q) ******( 0)
361.0 MW (NET) COST ELEMENTS A,C,E,N
PUBLIC SERVICE OF NEW MEXICO CAPACITY FACTOR, x *** 6s 65
SAN JUAN TOTAL CAPITAL, $/KW(YEAR) 127.9(1977) ****•*( 0) *****•( 0)
2 TOTAL ANNUAL, MILLS/KWH(YEAR) *«****( 0) »*****( 0) *****«( 0)
350.0 HW (NET) COST ELEMENTS A,C,E,N
SOUTH CAROLINA PUBLIC SERVICE CAPACITY FACTOR, K SC 65 65
WINYAH TOTAL CAPITAL, S/KUCYEAR) 47.4(1976) 66.4(1977) 6.4(197?)
2 TOTAL ANNUAL, «ILl_S/IC UH(YEAR) 1.6( 0) 2.9(1977) 3.2(1977)
UQ.Q HW (NET) COST ELEMENTS C,F,J,M,S,V C,E,J,K,W,S, C,E,J,K,W,S,
U,W U,W
SOUTH MISSISSIPPI ELEC PWR CAPACITY FACTOR, X *»* 65 65
R.D. MORROW TOTAL CAPITAL. $/KW(YEAR> 232.5(1978) ****«*( 0) *****•( 0)
1 TOTAL ANNUAL, MILLS/KWH(YEAR) »*****( 0) ******( 0) ******( 0)
124.0 MW (NET) COST ELEMENTS 0
SOUTH MISSISSIPPI ELEC PWR CAPACITY FACTOR, X *** 65 65
R.D. MORROW TOTAL CAPITAL, $/KW(YEAR) 232.5(1978) ******{ 0) ***•**( 0»
2 TOTAL ANNUAL, fll LLS/K WH (YE AR) ***»*»( 0) ******( 0) ******( 0)
124.C MW (NET) COST ELEMENTS 0
SOUTHERN INDIANA GAS & ELEC CAPACITY FACTOR, % *** 65 65
A.B. BROWN TOTAL CAPITAL. WKW(YEAR) 43.2(1979) *»****( 0) **»*•*( 0)
1 TOTAL ANNUAL, HILLS/KKH(YEAR) ****»*( 0) **«***( 0) «**•**( 0)
265.0 MH (NET) COST ELEMENTS C ,E ,G
SPRINGFIELD CITY UTILITIES CAPACITY FACTOR, % *** 65 65
SOUTHWEST TOTAL CAPITAL. $/KW(YEAR) 77.3(1974) 117.6(1977) 117.6M977)
1 TOTAL ANNUAL, H1LLS/K WH (YE AR) ******( 0) 6.2(1977) 6.9(1977)
194.0 HW (NET) COST ELEMENTS C,F,H,J,P C,E,H,J,K,P, C,E,H,J,K,P,
S,U,W S,U ,W
TENNESSEE VALLEY AUTHORITY CAPACITY FACTOR, % 60 65 "
WIDOWS CREEK TOTAL CAPITAL, $/KW(YEAR) 98..K1976) 113.1(1977) 113.1(1977)
wicows TQTAL ANNUAL, I«ILLS/KWH(YEAR) 3.0(1977) 5.3(1977) 5.1(1977)
550.C MW (MET) COST ELEMENTS B,C,E,P,R,T, C.E.JiSiU.U C.E.J.S.U.U
U
*«„»„* INDICATES COST FIGURES NOT YET AVAILABLE
A- 23
-------
EPA UTILITY FGD SURVEY: THIRD QUARTER 1979
SECTION A-2
COSTS FOR NON-OPERATIONAL FGO SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJlSTED
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
1
600.0 MW (NET)
CAPACITY FACTOR, X *** 65
TOTAL CAPITAL, $/Ky(YEAR> 68.4(1980) ******(
TOTAL ANNUAL, RILLS/KWH(YEAR) *•****( 0) *»****(
COST ELEMENTS C,E
0)
0)
65
O
0
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
2
600.0 HW (NET)
CAPACITY FACTOR, Z
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, KILLS/KWH(YEAR>
COST ELEMENTS
***
68.2(1980)
.***.*{ 0)
C,E
0)
0)
0)
0)
BIG RIVERS ELECTRIC
GREEN
1
342.0 MW (NET)
CAPACITY FACTOR, 1
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, »ILLS/KHH(YEAR)
COST ELEMENTS
*** 65
43.2(1976) ******(
***«**{ 0) ******{
B,C
0)
0)
65
C)
C)
BOSTON EDISON
MYSTIC
6
150.0 MU (NET)
CAPACITY FACTOR, I
TOTAL CAPITAL, J/KU(YEAR)
TOTAL ANNUAL, PILL S/K WH ( YE AR )
COST ELEMENTS
*** 65
63.4(1972) ******( 0)
3.0(1974) ***«**( 0)
B,C,E,N,Q
65
C)
0)
COLORADO UTE ELECTRIC ASSN.
CRAIG
1
447.0 MW (NET)
CAPACITY FACTOR, Z
TOTAL CAPITAL, S/KW(YEAR>
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
*** 65
117.0(1979) ******( 0)
******( Q) ******( 0)
B.D.E
65
C)
0)
COLORADO UTE ELECTRIC ASSN.
CRAIG
2
447.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, H1LLS/KHH(YEAR)
COST ELEMENTS
*** 65
117.D(1979) ******( 0)
«.*..*( 0) ******( 0>
A.C
65
0)
0)
COMMONWEALTH EDISON
POWERTON
51
450.0 NW (NET)
CAPACITY FACTOR, Z
TOTAL CAPITAL, $/KW(YEAR>
TOTAL ANNUAL. MILLS /KWH ( YE AR)
COST ELEMENTS
*** 65
117.7C1979I ******( 0)
**»***f Q) ******( 0)
C.E.H.J
65
0)
0)
COMMONWEALTH EDISON
WILL COUNTY
1
.0 MU (NET)
CAPACITY FACTOR, Z
TOTAL CAPITAL. $/KU(YEAR>
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
49 65
113.0(1972) •*****(
13.1(1975) ******(
B,C,E,G,J,X
0)
0)
65
0)
0)
DETROIT EDISON
ST. CLAIR
6
.0 MW (NET)
CAPACITY FACTOR, Z ***
TOTAL CAPITAL, S/KWCYEAR) 80.3(1976)
TOTAL ANNUAL, MILLS/KWH(YEAR) 9.6(1976)
COST ELEMENTS B,C,E,J,M,X
65
0)
0)
65
0)
0)
ILLINOIS POWER COMPANY
WOOD RIVER
4
110.0 MW (NET)
CAPACITY FACTOR, X «** 65
TOTAL CAPITAL, $/KW(YEAR) 82.15(1972) **•***(
TOTAL ANNUAL, Ml LLS /K WH C YE AR ) ******( 0) ****«(
COST ELEMENTS A,C,E,l«tN
0)
0)
65
0)
0)
INDICATES COST FIGURES NOT YET AVAILABLE
A- 24
-------
E.PA UTILITY fCD SURVEY: THIPO QUARTER 1975
Cl CT1GN, A-i
CCS1S FOR MOM-OPERATIONAL FOT SYSTEMS
U M I T OESChH'TIC\
PACIFIC POWtR f, LIGHT
j IM &! R 1 D^ f K
4
5 5 C. . C- Mi. ( "• i T )
POTOMAC ELECTRIC HO-ER
£i 1 C n E K S 0 N
. C M W ( N : ' i
PUPLIC SERVICE OF COLORADO
16t.O MW (NET)
SALT RIVER PROJECT
CORONADO
1
2RO.Q MM (NET)
SALT RIVfR PROJECT
CORONADO
280.0 MW (NET)
COST DL SC :. I PT J -~N
C A f ft C I 1 ¥ FACTOk, 5t
10TAL CAPITAL, t/KW(YEAR)
TOTAL ,'NNUAL, f I LL S /K WH ( YE A R )
COST ELEMENTS
CAPACITY FACTOR, 7.
TOTAL CAPITAL, J/KWtYEAf)
TCTA!. ANNUAL, VI LL S fK. WH ( YE A 0 )
COST EL'CFNTS
CAPACITY fACTOH, X
TOTAL CAPITAL, $/KU(YEAK)
TOTAL AtiNL'AL, "I LL S /K wH ( YE A R )
COST ELEMENTS
CAPACITY FACTOR, %
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, M LLS /K WH ( YE A R )
COST ELEMENTS
CAPACITY fACTOC, %
TOTAL CAPITAL, t/KW(YEAR>
TOTAL ANNUAL, I«I LL S / K WH ( YE A P )
COST ELEMENTS
SLTJRTEO ADJUSTED S TAN D AP D I Z t P
ADJLSTEfc
*** 65 M
C ,C , J
*** 65 65
A »C i E. ,M
*** 65 65
B.c.e.j
*** 65 65
C»E
*** 65 65
C.E
COST frGURES NOT YET AVAILABLt
-------
APPENDIX B
FGD PROCESS FLOW DIAGRAMS
THIS APPENDIX COMPRISES OPERATING FGD SYSTEMS
ARRANGED ALPHABETICALLY ACCORDING TO UTILITY
B-l
-------
CO
PO
LIMESTONt SI WRY PUMPS
(TWO TOTAL)
LI«STPHE SlUBRlf
TO UHH 3
5C«U(«EI>
STO»»GE P01D
Alabama Electric,
Simplified Process Flow Diagram for Tombigbee 3
-------
DO
I
oo
SINGLE LOUVER
DAMPER
DOUBLE LOUVER
DAMPER
STACK
I.D. FAN
, TO DISPOSAL POND
DOUBLE-BLADED
*~~ GUILLOTINE
DAMPER
r
i" ii "i
VVLIQUIB
~|
o
TO PROCESS
SEAL WATER
(SERVICE MATER)
TOTAL PROCESS
MAKE-UP UATER
(COOLING TOWER
SLOWDOWN)
DISTRIBUTOR!
LIMESTONE
{STORAGE BIN
'HEIGH
' FEEDER
''BALL HILL
ABSORBER
REAGENT
SLURRY
TANK
WET LIMESTOKE
GRINDING SYSTEM
-*• TO UNIT NO. 3
FROM UNIT NO. 3
TO UNIT NO. 3
TO UNIT NO. 3
ABSORBER REAGENT -
FEED PUMPS
Arizona Electric Power Coop, Apache 2 and 3
Process Flow Diagram
-------
CO
I
CaO
SILO
WATER
SLAKER
I SLURRY!
STORAGE
I^TANKJ
SCRUBBED
GAS
REACTOR
SYSTEM
NO. 2 {{ i
FUEL OIL
HOLD
TANK
1 ^
1
1 — ""
H20
1
1
i r
*» MTV
TANK
J
Q
Na2C03
SILO
Y
VACUUM WATER Jn
RECOVERY "2U
WASH
H20
SOLIDS
Louisville Gas and Electric, Cane Run 6
Dual Alkali FGD System: Simplified Process Flow Diagram
-------
HOT REHEAT GAS
FLUE GAS FROM
UPPER ESP
co
en
FLUE GAS FROM
LOWER ESP
-1 J
/ — i
— ^ i
J=t-
1 1 1 ^B.
| 1 1
N
STACK INLET
DAMPERS (2)
(1 EACH SIDE)
1
F*
E
•*— is
D
(4 F
HAUST PLENUM
XHAUST
OLATION
AMPERS
>ER UNIT)
_J ^tjp=
r -^ — \
UFNTII
y
us 1^
INLET
.? : PLENUM-
f TNI FT T<;ni ATTON
DAMPERS (4 PER UNIT)
1 -
"'\^- - BOOSTER FAN FLOW
^V\ CONTROL DAMPERS
1 n — 1 1 (4 PER UNIT)
I'—' \ *VT7Tfl*
— 1 ]| 1
STACK - ABSORBERS HftKUNli; BOOSTER FANS
(4 PER UNIT) (4 PER UNIT)
Public Service of New Mexico, San Juan 1 and 2
FGD System Flue Gas Flow Path
-------
LIME SILO
CO
I
Ol
FLUE GAS
BY-PASS
FLUE GAS FROM
ELECTROSTATIC-
PRECIPITATOR
CLEAN GAS
TO STACK
WATER
FILTER WCaS03/CaS04
SOLID TO
ON-SITE
LANDFILL
Southern Indiana Gas and Electric, A.B. Brown 1:
Dual Alkali FGD System: Simplified Process Flow Diagram
-------
VENTURI SORBER
SCRUBBER^
(ONE IN USE)
oo
I
MIST t
ELIMINATOR
TANK(ONE
IN USE)
HIST ELIMINATOR
PUMP
{ONE IN
ONE SPARE )
LIMESTONE
FEED BIN
(ONE IN USE
FOR TWO
WEIGH FEEDER
(ONE IN USE)
WET BALL MILL
(ONE IN USE)
MILL SLURRY
TANK
PUMP
SLURRY STORAGE
TANK
l«n*. in.lf tu iitr '"""
(ONE IN USE)(2Jr «,£) (ONE IN USE)
>=£
SLURRY
PUMP
(ONE IN USE
ONE SPARE)
RECYCLE TANK
(ONE IN USE)
RECYCLE
PUMP
(TWO IN USE
ONE SPARE)
THICKENER
SUPPLY
TANK
(ONE IN USE)
PUMP
IN USE
ONE SPARE)
South Mississippi Electric, R.D. Morrow
Simplified Process Flow Diagram
2:
-------
00
FAN OUTLET DUMPER
FROM BORER
AIR PREHEATfRS
TOHER [NUT DUMPER
TOMER OUTIET
S DAMP
—
LOW:
— PUT
REHF
R
t
»
ON
JRE
«TE
DAMPER
_jai
—
or
R
t
«
TT
FO
~ »
R FUTUI
TOMERS
FAN INLET '
LOUVER DAMPER
MIST/
ELIMINATOR
CONTINUOUS
RECIRCULATION
WET CVCLOtES
ro~ij
H r-1
ABSORBER
l__ SPRAY PUMPS
^\3*^'nNr SPARE)
.PUMP SEA MATER.
BAIL MILL COOLING
AMH HOSE STATIONS
MAKEUP MATER TO
LIMESTONE AREA
SERVICE MATER
(LAKE HATER)
ASH POND
HETURN HATER
(RECYCLE HATER)
| SOLIDS [
w* 'uu
Texas Utilities,
Simplified Process Flow Diagram for One of the Three Identical
Martin Lake FGD Systems
-------
APPENDIX C
DEFINITIONS
C-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 S02
removed from the flue gas by
the FGD system.
C-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
C-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,
04
-------
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 S02 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.
C-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 S02
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).
C-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
C-7
-------
the gross unit rating if the
system is not meant to bring
the facility into compliance
with S02 emission standards.
Unit Rating
Gross Operational - Maximum contin-
uous gross generation capacity
in MW; Preoperational - maxi-
mum continuous design genera-
tion capacity in MW.
New w/FGD Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
inclusive of emission control
systems.
Net w/o FGD Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
exclusive of emission control
systems.
C-8
-------
APPENDIX D
TABLE OF UNIT NOTATION
D-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
ft3/min
(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
Notation
ACRE
SQ.FT
GR/SCF
PPM
LB/MMBTU
ACFM
GPM
LB/MIN
TPD
TPH
BTU/LB
FT
IN
MI
GAL/1 OOOACF
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
Megagram
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/g
m
cm
km
liter/m3
kg
Mg
kPa
°C
m
mj
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
D
I
NJ
-------
TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing!
EPA-600/7-79-Q22f
4. TITLE AND SUBTITLE
EPA Utility FGD Survey: July-September 1979
6. PERFORMING ORGANIZATION CODE
3. RECIPIENT'S ACCESSION NO.
5. REPORT DATE
October 1979
'. AUTHOR(S) ~
M. Smith and M. Melia
8. PERFORMING ORGANIZATION REPORT NO.
PN 3470-1-C
9. PERFORMING ORGANIZATION NAME AND ADDRESS
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
10. PROGRAM ELEMENT NO.
EHE624
11. CONTRACT/GRANT NO/
68-01-4147, Task 79
12. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
Quarterly;' 7-9779"
14. SPONSORING AGENCY CODE
EPA/600/13
is.SUPPLEMENTARY NOTES EPA project officers are N. Kaplan (IERL-RTP, MD-61, 919/541-
2556) and J.D. Herlihy (DSSE, 202/755-8137). EPA-600/7-79-022c through -022e
are previous reports in this series.
IB. ABSTRACT The report jg the last of three suppiements updating the December 1978-
January 1979 report (EPA-600/7-79-022c) and should be used in conjunction with it.
The report was generated by a new computerized data base system and differs from
those of the previous series in that the scope of design data for operating FGD sys-
tems is vastly expanded, section formats are revised somewhat, and a new section
includes operational particulate scrubbers. The report gives a survey of utility flue
gas desulfurization (FGD) systems in the U.S. It summarizes information contributed
by the utility industry, process suppliers, regulatory agencies, and consulting engi-
neering firms. Systems are tabulated alphabetically by development status (oper-
ational, under construction, or in planning stages), utility company, process sup-
plier, 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 the FGD systems. Process flow diagrams and FGD system economic
data are appended to the report.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS
c. COSATI Field/Group
Pollution
Flue Gases
Desulfurization
Electric Utilities
Waste Disposal
Boilers
Maintenance
Pollution Control
Stationary Sources
Utility Boilers
13B
21B
07A, 07D
15E
13A
13. DISTRIBUTION STATEMENT
Release to Public
19. SECURITY CLASS (ThisReport}
Unclassified
!1. NO. OF PAGES
268
20. SECURITY CLASS (Thispage)
Unclassified
22. PRICE
EPA Form 2220-1 (9-73)
D-3
------- |