&EPA
United States Industrial Environmental Research EPA 600 7 79 022>'
Environmental Protection Laboratory August 1979
Agency Research Triangle Pa-k NIC 2771 1
EPA Utility FGD
Survey:
April-June 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-600/7-79-022e
August 1979
EPA Utility FGD Survey:
April-June 1979
by
M. Smith, M. Melia, and T. Koger
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
Contract No. 68-02-2603
Task No. 48
Program Element No. EHE624
EPA Project Officers:
N. Kaplan
J.C. Herlihy
Industrial Environmental Research Laboratory
Office of Energy, Minerals, and Industry
Research Triangle Park, NC 27711
Division of Stationary Source Enforcement
Office of Enforcement
Washington, D.C. 20460
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Research and Development
Washington, DC 20460
-------
NOTICE
This report, (prepared by PEDCo Environmental, Inc., Cincin-
nati, Ohio, under EPA Contract No. 68-02-2603, Task No. 48) is
provided as an information transfer document. Data in this
report are supplied voluntarily by utility representatives; flue
gas desulfurization (FGD) system designers, and suppliers; regu-
latory personnel; and others. Neither EPA nor the designated
contractor warrants the accuracy or completeness of information
contained in this report.
This report is the second 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.
ii
-------
CONTENTS
Notice
Tables
Executive Summary and Highlights
Section 1 Summary List of FGD Systems
Section 2 Status of FGD Systems
Section 3 Design and Performance Data for Operational
FGD Systems
Alabama Electric
Tombigbee 2
Tombigbee 3
Allegheny Power System
Pleasants 1
Arizona Electric Power
Apache 2
Apache 3
Arizona Public Service
Choila 1
Choila 2
Central Illinois Light
Duck Creek 1
Columbus and Southern Ohio Electric
Conesville 5
Conesville 6
Duguesne Light
Elrama 1-4
Phillips 1-6
Gulf Power
Scholz 1,2
Indianapolis Power and Light
Petersburg 3
Kansas City Power and Light
Hawthorn 3
Hawthorn 4
LaCygne 1
Kansas Power and Light
Jeffrey 1
Lawrence 4
Lawrence 5
Kentucky Utilities
Green River 1-3
Pafle
ii
vi
vii
1
6
34
34
35
37
39
41
43
45
46
49
51
53
54
55
57
59
61
63
65
66
67
69
iii
-------
CONTENTS (continued)
Louisville Gas and Electric
Cane Run 4 /.,
Cane Run 5 '2
Cane Run 6 '4
Mill Creek 3 77
Paddy's Run 6 79
Minnkota Power Cooperative
Milton R. Young 2 80
Montana Power
Colstrip 1 82
Colstrip 2 83
Nevada Power
Reid Gardner 1 84
Reid Gardner 2 86
Reid Gardner 3 88
Northern Indiana Public Service
Dean H. Mitchell 11 90
Northern States Power
Sherburne 1 92
Sherburne 2 94
Pennsylvania Power
Bruce Mansfield 1 96
Bruce Mansfield 2 98
Philadelphia Electric
Eddystone 1A 100
Public Service Company of New Mexico
San Juan 1 101
San Juan 2 102
South Carolina Public Service Authority
Winyah 2 103
Southern Illinois Power Coop
Marion 4 105
Southern Indiana Gas and Electric
A.B. Brown 1 107
Southern Mississippi Electric
R.D. Morrow 1 10g
R.D. Morrow 2 HI
Springfield City Utilities
Southwest 1 H3
Tennessee Valley Authority
Shawnee 10A '
Shawnee 10B
Widows Creek 8
Texas Utilities
Martin Lake 1 H9
Martin Lake 2 12i
Martin Lake 3 123
Monticello 3 125
iv
-------
CONTENTS (continued)
Page
Utah Power and Light
Hunter 1 127
Huntington 1 129
Section 4 Summary of FGD Systems by Company 131
Section 5 Summary of FGD Systems by System Supplier 132
Section 6 Summary of FGD Systems by Process 134
Section 7 Summary of Operating FGD Systems by Process
and Unit 135
Section 8 Summary of End-Product Disposal Practices
for Operational FGD Systems 137
Section 9 Summary of FGD Systems in Operation 139
Section 10 Summary of FGD Systems Under Construction 142
Section 11 Summary of Contract Awarded FGD Systems 144
Section 12 Summary of Planned FGD Systems 145
Section 13 Total FGD Units and Capacity (MW) Installed
by Year ' 148
Section 14 Design and Performance Data for Operational
Particulate Scrubbers 149
Appendix A FGD System Cost Data: Operational and
Nonoperational Systems
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-l9
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
Appendix C Definitions C-l
Appendix D Glossary of Units D-l
-------
TABLES
No. Page
I Number and Total Capacity of FGD Systems vii
II Summary of Changes, Second Quarter 1979 ix
III Performance of Operational Units, Second Quarter 1979 x
vi
-------
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 Divi-
sion of Stationary Source Enforcement of the U.S. Environmental
Protection Agency. Prior to this issue, reports were compiled on
a bimonthly basis (every two months). This is the third issue
generated by a newly developed 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 June 1979. Table II lists the units that have
changed status during the second quarter 1979, and Table III
shows the performance of operating units during this period.
TABLE I. NUMBER AND TOTAL CAPACITY OF FGD SYSTEMS
Status
Operational
Under construction
Planned:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only FGD
systems
TOTAL
No. of
Units
55
42
16
2
; 16
31
162
Total
Controlled
Capacity, MW*
19,967
18,637
9,149
1,100
12,088
15,824
76,765
Equivalent
Scrubbed
Capacity, MWt
18,504
17,135
8,938
1,100
11,200
15,054
71,931
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).
VI1
-------
H-
H-
H-
PI 10!
PlJWt
r
wsontiK
CEKTIiruOC
ruK
'
FCO
CCONOMICS
_
rco
[N(RCr
CONSUVTKM
«ACUUM
riLTCR
rco
DC SIC*
1
NIST
[LINIMTOR
cnoctss
CHtNISTBY
com «.
tc»ac
PUTS
SOtUTIM
DC^OI'TION
P»OB
xnoi
1 1 1 1 1 1
KtCTCU
TANKS
BEHtATCII
tHICmNEB
UATCB 10»
RCACCRT
raCPARATIW
COUIPICIIT
[NO P«
BT-PKOOUCI
SlUOU
DISPOSAL
Figure 1. Computerized data base structure diagram.
-------
TABLE II. SUMMARY OF CHANGES: FGD SUMMARY REPORT,
SECOND QUARTER 1979
H-
X
FGD status report
3/31/79
AlabaM Electric Coop
Toablgbee 3
Arizona Electric Power Coop
Apache 3
Associated Electric Coop
Thaws Hill 3
East Kentucky Power Coop
Spurlock 2
Louisville Gas 1 Electric
Hill Creek 2
Public Service of Indiana
Gibson S
Public Service of New Mexico
San Juan 4
ScMlnole Electric
Swtnole 1
S«1nole 2
Southern California Edison
Alaaltos
Southern Illinois Power Coop
Marlon 4
Southern Mississippi Electric
R.O. Morrow 2
Texas Power « Light
Twin Oaks 1
Twin Oaks 2
TOTAL
Operational
No.
51
+1
+1
+1
*1
55
MM*
17.822
179
195
184
124
18.504
Under
construction
No.
42
-1
-1
*1
+1
+1
+1
-1
-1
42
MM*
15,763
179
195
670
500
350
534
184
124
17.T35
Contract
awarded
No.
20
-1
-1
-1
+1
-1
-1
16
Mtf*
10.517
670
500
350
650
534
175
8.938
Letter of
Intent
No.
2
2
MM*
1.100
1.100
Requesting/
eval. bids
No.
13
-1
+1
+1
»!
+1
16
MM*
9,110
650
620
620
750
750
11.200
Considering
FGO
No.
34
-1
-1
-1
31
MM*
17,17*
620
750
750
15.054
To
No.
162
+1
-1
162
tal
MH*
71.486
620
175
71.931
Equivalent scrubbed capacity.
-------
TABLE III. PERFORMANCE OF OPERATIONAL UNITS
SECOND QUARTER 1979
Plant
Toablgbee 2
Toablgbee 3
Pleasants 1
Apache 2
Apache 3
Choi la 1
Choi la 2
Duck Creek 1
Conesvllle 5
Convesllle 6
Clraauj 1-4
Phillips
Scholi 1.2
Petersburg 3
Hawthorn 3
Hawthorn 4
LaCygne 1
Jeffrey 1
Lawrence 4
Lawrence 5
Green Rivers 1-3
Cane Run 4
Cane Run 5
Cane Run 6
Hill Creek 3
Paddy's Run 6
Hilton R. Young 2
Colstrlp 1
Colstrlp 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
FGD systea
capacity.
179
179
519
195
195
119
350
416
411
411
510
410
23
532
90
90
874
540
125
420
64
188
190
288
442
72
405
360
360
125
125
125
Flue gas
S scrubbed
70
70
84
100
100
100
100
100
100
100
100
100
H/Ad
100
100
100
100
75
100
100
100
100
100
100
100
100
85
100
100
100
100
100
FGD capacity
on line
during
period,
179
179
519
195
195
119
350
416
411
411
23
532
90
90
874
540
125
420
64
188
190
288
442
405
360
360
125
125
125
No Information
for this
period,
HU
510
410
Shut down
through-
out
period,
MM
72
FGD systea
availability.
Apr.
73
8
77
18
57
95
18
100
100
100
Hay
72
55
94
96
0
100
100
30'
100
100
100
June
60
46
100
27
98
93
100
FGD systea
operabjllty.
Apr.
100
56
29
69
100
100
100
99
43
64
99
100
Hay
72
32
0
0
100
100
84
22
98
32«
74
99
98
June
28
43
46
77
12
52
27
95
87
91
FGD systea
reliability.
Apr.
100
72
36
69
100
99
100
Hay
72
51
0
74
100
98
June
29
46
95
87
100
FGD systea
utilization.
Apr.
100
53*
6
68
18
57
18
50
38
44
0
26
100
Hay
72
8
0
0
55
94
0
0
49
15
65
0
30e
28
84
98
June
26
29
17
58
10
48
0
27
85
73
84
(continued)
-------
TABLE III. (continued)
Plant
Dean H. Mitchell 11
Sherburne 1
Sherfaurne 1
Bruce Mansfield 1
Bruce Nwsfleld 2
Eddystone 1A
San Juan 1
SOT Juan 2
Mlnyah 2
Marlon 4
A.B. Brom 1
R.D. Nornw 1
ft ^bk^^^M« 9
K.V. nui VOM c
Southwest 1
Snatmee 10A
Sbawwe 10B
Widows Creek 8
Martin Late 1
Martin Late 2
Martin late 3
Montlcello 3
Hunter 1
Hontlngtm 1
TOTAL
FGO system
capacity.
MU*
115
740
740
917
917
120
361
350
140
184
265
124
124
194
10
10
550
595
595
595
800
360
18.504
Flue gas
I scrubbed
100
100
100
100
100
I/A"
100
100
so
100
100
62
62
100
N/Ad
N7Ad
100
75
75
75
100
360
85
FGO capacity
on line
during
period.
Mb*'1"
115
740
740
917
917
361
350
140
184
265
124
200
194
10
to
595
595
595
800
16.842
No Information
for tills
period.
m
120
550
1.590
Shut down
through-
out
period.
MM
72
FGO system
availability.
»c
Apr.
73
93
99
92f
89f
99
47
Nay
86
98
95
98
42
June
93
90
92
28
FGO systM
operabnity.
Apr.
99
38
Hay
99
39
June
92
26
FGO system
reliability.
tc
Apr.
73
99
50
May
76
100
48
June
92
27
FGO syste*
utilization.
«c
Apr.
73
99
23
May
69
96
34
June
92
26
'Equivalent scrubber capacity.
Shis category Includes the flue gas capacity being handled by the FGO syste* at least part of the tine during the report period.
cThe percent figures listed are average values for all systeo scrubbing trains during the period.
dF1ue gas S scrubbed for prototype and demonstration units Is not applicable unless the systen Is designed to bring a unit Into
co«p1lance with SO; emission standards.
*Th1s figure represents a system average for the months of Nay and June.
fTh
-------
As indicated in Table I, 55 power generating units (all coal-
fired) are now equipped with operating FGD systems. These units
represent a total controlled capacity of 19,967 MW. Projections
indicate that the total power generating capacity of the U.S.
electric utility industry will be approximately 904 GW by 1999.
(This value reflects the annual loss resulting from the retire-
ment of older units, which is considered to be 0.4% of the aver-
age generating capacity at the end of each year.b) Approximately
352 GWa or 39% of the 1999 total will come from coal fired units.
The other 61% is distributed as follows: 24% nuclear, 17% oil,
10% hydro, 8% gas, 1% unknown and 1% other. Since all of the
162 FGD-equipped units (76,765 MW) shown in Table I are scheduled
for operation by 1999, approximately 22 percent of the projected
coal-fired capacity will be controlled by FGD by the end of 1999
based on these committments to FGD by utilities. In light of the
revised New Source Performance Standards, actual FGD control is
expected to be greater than this figure.
HIGHLIGHTS: SECOND QUARTER 1979
The following paragraphs highlight FGD system developments during
the second quarter, 1979.
FGD system operations at Tombigbee 3 of Alabama Electric Coop
began in June 1979. Performance figures for the wet scrubbing
limestone slurry system are not yet available. However, no
major start-up problems have been reported.
Start-up of the FGD system at Apache 3 of Arizona Electric Power
Coop took place during June. Although performance data are not
yet available for this system, the utility reports that some
minor problems were encountered during the initiation of oper-
ation.
Arizona Public Service reported that the Cholla 1 FGD system
remained operational during most of the second quarter of 1979.
The FGD system had average operability, reliability and utili-
zation figures of 100% for the month of April and 72% for the
month of May. The lower figures for May were due to outage time
needed for the replacement of corroded ductwork in the B module.
June data are not yet available. No boiler outages were reported
for the three month period.
Associated Electric Coop reported that construction began on the
FGD system at Thomas Hill during the report period. The system,
which is scheduled to begin operation in January 1982, will
utilize a magnesium-promoted limestone as the reagent. The four
module Weir FGD system is being supplied by Pullman Kellogg.
xii
-------
Construction also began on the FGD system at Spurlock 2 of East
Kentucky Power Coop during the period. Operations at this new
500 MW (gross) unit are expected to begin in October 1980. ADL/
Combustion Equipment Associates is supplying the lime slurry
system that will include an electrostatic precipitator for the
control of particulate matter.
Kansas City Power and Light reported that both Hawthorn 3 and 4
were operational during the period with operabilities of 100% for
both April and May. The boiler operated 130 and 409 hours during
April and May, respectively, at unit 3 and 410 and 699 hours
during April and May, respectively, at unit 4. At Hawthorn 3 the
low boiler hours were reported to be caused by tube leaks and a
turbine overhaul during the period. An excitor failure on the
generator and general maintenance caused outages at unit 4 during
the period. June data are not yet available.
At LaCygne 1 of Kansas City Power and Light average FGD system
availabilities of 95% and 96% were reported for the months of
April and May, respectively. No major problems were reported for
these two months. The unit was removed from service the latter
part of May for a scheduled boiler overhaul and remained out of
service through June.
Louisville Gas and Electric reported that construction has begun
on the Mill Creek 2 FGD system and operations are scheduled to
begin in April 1982. Combustion Engineering is supplying the FGD
system for this new 350 MW (gross) unit.
Nevada Power reported that the FGD systems at Reid Gardner 1, 2,
and 3 were in service during most of the second quarter 1978.
FGD system availabilities for April, May and June were 100%, 99%,
and 97%, respectively, for unit 1. Unit 2 availabilities were
88%, 99%, and 93% with unit 3 availabilities being 100%, 98%, and
100% respectively for April, May, and June.
At Sherburne 1 of Northern States Power the FGD system had avail-
abilities of 92%, 93%, and 98%, respectively, for April, May, and
June. The only operational problem reported for the three month
period was some general system plugging during June. The Sherburne
2 FGD system availabilities were 99%, 95%, and 90% for April,
May, and June, respectively. The only problems reported for unit
2 were boiler related.
Pennsylvania Power reported during the period that the average
FGD system availability at Bruce Mansfield 1 was 92% for the
period January 1, 1979 through May 31, 1979. The only major
problem experienced during this period was reportedly fan motor
failures.
Public Service of Indiana announced that a contract has been
awarded to Pullman Kellogg for the installation of a limestone
xiii
-------
FGD system at Gibson 5. This new 650 MW (gross) unit is sched-
uled to begin operation in 1982.
Construction began during the second quarter of 1979 on the FGD
system at San Juan 4 of Public Service of New Mexico. This
Wellman Lord system, which is being supplied by Davy Powergas, is
scheduled to begin operation in January, 1982. System design
includes an electrostatic precipitator for primary particulate
matter control.
Seminole Electric announced plans to install a limestone FGD
system on Seminole 2, the second of two new 620 MW (gross) boil-
ers. Presently, the utility is requesting/evaluating bids for
this system and no supplier has been chosen.
South Carolina Public Service reported that the FGD system at
Winyah 2 had availabilities of 99%, 98%, and 92% for April, May,
and June, respectively. The boiler logged 2157 hours for the
three month period and the FGD system logged 2087 hours.
Sohio officially announced during the period that all plans for
the oil tanker terminal/pipeline project that was designed to
carry surplus Alaskan crude oil to Texas have been cancelled. As
a result, the contractural agreement between Sohio and Southern
California Edison for the installation of an FGD system at the
Alamitos 6 unit have also been cancelled. This agreement had
been the result of an "emission offset" program that would have
allowed the construction of an oil terminal and storage facility
at Long Beach, California providing that Sohio would have sup-
plied 100% of the FGD system capital cost and projected operating
costs for a period of 15 years.
FGD system operations began in May at Marion 4 of Southern
Illinois Power Coop. Operational data are not yet available but
the utility reports that only minor start-up problems have been
encountered.
Southern Mississippi Electric reported that FGD operations began
at R.D. Morrow 2 during the latter part of June. No operational
data are yet available.
Texas Power and Light announced that bids are now being requested/
evaluated for FGD systems at the two new 750 MW (gross) Twin Oaks
units. Limestone has been selected as the reagent that will be
tsed and unit start-ups are scheduled for August 1984 and August
1985 for units 1 and 2, respectively.
xiv
-------
REFERENCES
a. U.S. Department of Energy. Office of Utility Project
Operations. Inventory of Power Plants in the United States,
December 1977. Pub. No. DOE/RA-0001.
b. Rittenhouse, R.C. New Generating Capacity: When, Where and
By Whom. Power Engineering 82(4):57. April 1978.
xv
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 1
SUMMARY LIST OF F&D SYSTEHS
COMPANY NAME/
UNIT NAMt
ALABAMA ELECTRIC COOP
TONBIGBEE
TOMB 1 6 BEE
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
LARAMIE RIVER
LARAMIE RIVER
LARAMIE RIVER
BIG RIVERS ELECTRIC
GREEN
GREEN
CENTRAL ILLINOIS LIGHT
DUCK CREEK
DUCK CREEK
CENTRAL ILLINOIS PUBLIC S ERV
NEWTON
CENTRAL MAINE POWER
SEARS ISLAND
CINCINNATI GAS C ELECTRIC
FAST BFUh
UNIT NO.
2
3
3
1
2
2
3
1
2
4
1
2
3
4
5
3
1
2
1
2
3
1
2
1
2
1
1
2
UNIT LOCATION
LEROY
LEROY
COURTNEY
BELMONT
BELMONT
COCHISE
COCHISE
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARMIN6TON
FARMINGTON
FARMIN6TON
FARMINGTON
FARMINGTON
MOBERLY
BEULAH
BEULAH
WHEATLAND
WHEATLAND
WHEATLAND
SEBREE
SEBPEE
CANTON
CANTON
NEWTON
PENOBSCOT BAY
RABRITHASH
ALABAMA
ALA9AMA
PENNSYLVANIA
WEST VIRGINIA
WEST VIRGINIA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
MISSOURI
NORTH DAKOTA
NORTH DAKOTA
WYOMING
WYOMING
WYOMING
KENTUCKY
KENTUCKY
ILLINOIS
ILLINOIS
ILLINOIS
MAINE
KENTUCKY
START-UP
DATE
9/79
6/7"
6/62
3/79
9/80
E/78
6/79
10/73
4/78
6/£0
0/79
0/79
0/79
O/ fc2
0/82
1/£2
11/61
11/83
4/eo
10/80
4/82
10/79
6/80
9/76
1/84
11/79
11/87
10/61
STATUS
1
1
6
1
2
1
1
1
1
2
2
2
2
3
7
2
3
t
2
2
r
2
2
1
c
2
6
2
REG
CL*SS
I
'
F.
A
A
p
5
=
F
t.
c
Q
a
B
f
A
3
f-
A
A
A
t
A
A
A
A
A
A
COLORADO UTE ELECTRIC ASSM.
CRAIG 1
CRAIG 2
COLUMBUS t SOUTHERN OHIO ELEC.
CONESVILLE 5
CONESVILLE 6
POSTON S
POSTON 6
CRAIG
CRAIG
CONESVILLE
CONESVILLE
ATHENS
ATHENS
COLORADO
COLORADO
OHIO
OHIO
OHIO
OHIO
8/79
11/79
1/77
6/78
0/83
0/89
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 F6D SYSTEMS
7. PLANNED - CONSIDERING F6D SYSTEMS; ALSO ALTERNATIVE METHODS
A. BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
B. BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRIN6ERT THAN THE FEDERAL NSPS
C. BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
6. OTHER
E. REGULATORV CLASS UNKNOWN
-------
EP» UTILITY FfeO SURVEY: SECOND QUARTER 1979
SECTION 1
SUMMARY LIST OF F60 SYSTEMS
CO" PANT NAME/
UNIT NAME
C01MONHEALTH EDISON
ROBERTO*
COOPERATIVE POWER ASSOCIATION
COAL CREEK
COAL CREEK
DELNARVA PO.ER t LI6HT
DELAWARE CITY
DUQUESHE LIGHT
ELRANA
PHILLIPS
EAST KENTUCKY POWER COOP
SPURLOCK
GENERAL PUBLIC UTILITIES
COHO
SEUARD
6ULF POWER
SCHOLZ
MOOSIER ENERGY
HERON
MEROM
HOUSTON LIGHTING I POWER CO.
W.A. PARISH
INDIANAPOLIS POKER t LIGHT
PETERSBURG
PETERSBURG
KANSAS CITY POWER S LIGHT
HAWTHORN
HAWTHORN
LA CVGNE
KANSAS POWER t LIGHT
JEFFREY
JEFFREY
LAWRENCE
LAWRENCE
UNIT NO.
51
1
2
1-3
1-4
1-6
2
1
7
1.2
1
2
8
3
4
3
4
1
1
2
4
5
UNIT LOCATION
PERKIN
UNDERWOOD
UNDERWOOD
DELAWARE CITY
ELRAHA
SOUTH HEIGHT
MAVSV1LLE
ERIE
SEWARD
SNEADS
SULLIVAN
SULLIVAN
THOMPSONS
PETERSBURG
PETERSBURG
KANSAS CITY
KANSAS CITY
LA CVGNE
WANE60
WAHE60
LAWRENCE
LAWRENCE
ILLINOIS
NORTH DAKOTA
NORTH DAKOTA
DELAWARE
PENNSYLVANIA
PENNSYLVANIA
KENTUCKY
PENNSYLVANIA
PENNSYLVANIA
FLORIDA
INDIANA
INDIANA
TEXAS
INDIANA
INDIANA
MISSOURI
MISSOURI
KANSAS
KANSAS
KANSAS
KANSAS
KANSAS
START-UP
DATE
11/79
7/79
10/80
4/80
10/75
7/73
10/80
5/88
12/85
8/78
4/81
1/82
10/82
12/77
10/83
11/72
8/72
2/73
8/7B
6/80
1/76
11/71
STATUS
2
2
2
2
1
1
2
6
6
1
2
2
5
1
2
1
1
1
1
2
1
1
REG
CLASS
C
A
A
C
P
B
A
A
A
C
A
A
A
A
A
B
e
c
B
B
B
B
KENTUCKY UTILITIES
GREEN RIVER 1-3
LAKELAND UTILITIES
NCIKTOSH 3
LOUISVILLE GAS ( ELECTRIC
CANE RUN 4
CANE RUN 5
CANE RUN 6
MILL CREEK 1
HILL CREEK 2
MILL CREEK 3
MILL CREEK 4
PADDY'S RUN 6
1. OPERATIONAL UNITS 4.
2. UNITS UNDER CONSTRUCTION 5.
3. PLANNED - CONTRACT AWARDED 6.
7.
CENTRAL CITY KENTUCKY
LAKELAND
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
FLORIDA
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
9/75
10/81
8/76
12/77
4/79
4/81
4/82
8/78
7/81
4/73
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REOUESTIN6/EVALUAT1N6 BIDS
PLANNED - CONSIDERING ONLY F6D SYSTEMS
PLANNED - CONSIDERING F6D 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 EOUAL TO OR LESS STRINGENT THAN NSPS
0. OTHER
E. REGULATORY CLASS UNKNOWN
-------
EPA UTILITY F60 SURVEY: SECOND OUARTEP 1979
SECTION 1
SUMMARY LIST OF F60 SYSTEMS
COMPANY NAME/
UNIT NAME
LOUISVILLE GAS C ELECTRIC
TRIABLE COUNTY
TRIMBLE COUNTY
MIDDLE SOUTH UTILITIES
ARKANSAS COAL
ARKANSAS COAL
LOUISIANA COAL
LOUISIANA COAL
MISSISSIPPI COAL
MISSISSIPPI COAL
UNIT NO. UNIT LOCATION
1 BEDFORD
2 BEDFORD
5
6
1
2
1
2
KENTUCKY
KENTUCKY
ARKANSAS
ARKANSAS
LOUISIANA
LOUISIANA
MISSISSIPPI
MISSISSIPPI
START-UP
DATE
7/84
0/86
1/86
1/88
0/86
0/88
0/85
0/87
STATUS
6
6
5
5
5
5
5
5
P.? 6
CLASS
0
D
D
D
D
D
D
D
MINNESOTA POWER t LIGHT
CLAY BOS WELL 4
MINNKOTA POWER COOPERATIVE
MILTON R. YOUN6 2
MONTANA POWER
COLSTRIP 1
COLSTRIP 2
COLSTRIP 3
COLSTRIP 4
NUSCATINE POWER t HATER
MUSCAT INE 9
NEVADA POWER
HARRY ALLEN 1
HARRY ALLEN 2
HARRY ALLEN 3
HARRV ALLEN 4
REID GARDNER 1
REID GARDNER 2
REID GARDNER 3
REID GARDNER 4
WARNER VALLEY 1
WARNER VALLET ' 2
NEW ENGLAND ELECTRIC SYSTEM
BRAYTON POINT 3
NIAGARA MOHAUK POWER COOP
CHARLES R. HUNTLET 66
NORTHERN INDIANA PUB SERVICE
BAILLY
BAILLY
DEAN H. MITCHELL
SCHAHFER
SCHAHFER
NORTHERN STATES POWER
SHERBURNE 1
SHERBURNE 2
SHERBURNE 3
OTTER TAIL POWER
COYOTE 1
COHASSET
CENTER
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
MUSCATINE
MINNESOTA
NORTH DAKOTA
MONTANA
MONTANA
MONTANA
MONTANA
IOWA
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. GEOR6E UTAH
SOMERSET
BUFFALO
MASSACHUSETTS
NEW YORK
7
8
11
17
18
CHESTERTON
CHESTERTON
GARY
UHEATFIELD
WHEATFIELD
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
BECKER
BECKER
BECKER
BEULAH
MINNESOTA
MINNESOTA
MINNESOTA
NORTH DAKOTA
5/80
9/77
9/75
5/76
7/80
7/81
0/82
O/ 0
0/82
O/ 0
O/ 0
7/76
6/83
6/85
3/76
4/77
5/84
5/81
6/85
6/86
6/87
6/88
4/74
4/74
6/76
0/63
6/84
6/85
6
6
6
6
1
1
1
6
6
6
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 F6D SYSTEMS
7. PLANNED - CONSIDERING FGO 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. REGULATOR? CLASS UNKNOWN
-------
EPA UTILITY Fee SURVEY: SECOND fiUARTER 1979
SECTION 1
SUMMARY LIST Of F6D SYSTEMS
NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP RE6
DATE STATUS CLASS
PACIFIC CAS ( ELECTRIC
FOSSIL 1
FOSSIL 2
PACIFIC POWER t LIGHT
JIM BRID6ER *
PENNSYLVANIA POUER
BRUCE MANSFIELD 1
BRUCE MANSFIELD 2
BRUCE MANSFIELD 3
PHILADELPHIA ELECTRIC
CR04BV
EDDVSTONE 1A
EDDYCTONE 1B
EDDYSTONE 2
POTOMAC ELECTRIC POUER
DICKERSON 4
POUER AUTHORITY OF NEU YORK
ARTHUR KILL
PUBLIC SERVICE OF INDIANA
GIBSON 5
PUBLIC SERVICE OF NEU MEXICO
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
SAN JUAN 4
SALT RIVER PROJECT
CORONADO 1
CORONADO 2
CORONADO 3
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SEMINOLE ELECTRIC
SENINOLE 1
SEMINOLE 2
SIKESTON BOARD OF MUNIC. UTIL.
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
MINYAH 2
UINYAH 3
UINYAH 4
SOUTHERN ILLINOIS POUER COOP
MARION 4
MARION 5
SOUTHERN INDIANA (AS i ELEC
A.B. BROUN 1
COLLINSVILLE
COLLINSVILLE
CALIFORNIA
CALIFORNIA
ROCK SPRINGS UVOMIN6
SHIPPIN6PORT
SHIPPINGPORT
SHIPPINGPORT
PHOENIXVILLE
EDDYSTONE
EDDVSTONE
EDDYSTONE
DICKERSON
STATEN ISLAND
PRINCETON
UATERFLOU
UATERFLOW
UATERFLOU
UATERFLOU
ST. JOHNS
ST. JOHNS
ST. JOHNS
SAN MIGUEL
PALATKA
PALATKA
SIKESTON
6EOR6ETOUM
GEORGETOWN
6EOR6ETOUN
MARION
MARION
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
MARYLAND
NEu YORK
INDIANA
NEU MEXICO
NEU MEXICO
NEU MEXICO
NEU MEXICO
ARIZONA
ARIZONA
ARIZONA
TEXAS
FLORIDA
FLORIDA
MISSOURI
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
ILLINOIS
ILLINOIS
6/86
6/87
9/79
12/75
7/77
4/BO
6/80
9/75
6/ao
6/80
0/87
11/88
0/82
4/78
8/78
9/79
1/82
8/79
1/80
0/87
2
2
6
VEST FRANKLIN INDIANA
8/80
6/83
6/85
11/80
7/77
5/80
5/81
5/79
0/84
3/79
2
5
5
2
1
2
3
1
6
1
A
A
A
A
A
A
A
A
A
A
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AUARDED
4.
5.
6.
7.
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY F&D SYSTEMS
PLANNED - CONSIDERING F6D 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 UNKNOUN
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 1
SUMMARY LIST OF F60 SYSTEMS
COMPANY NAME/
UNIT NAME
SOUTHERN MISSISSIPPI ELECTRIC
R.D. MORROW
R.D. MORROy
SOUTHWESTERN ELECTRIC POWER
HENRY W. PERKET
SPRINGFIELD CITY UTILITIES
SOUTHWEST
SPRINGFIELD WATER. LI6HT I PWR
ALLNAN
ST. JOE ZINC
G.F. BEATON
TAHPA ELECTRIC
BI6 BEND
TENNESSEE VALLEY AUTHORITY
CUMBERLAND
JOHNSONVILLE
PARADISE
PARADISE
SHAUNEE
SHAWNEE
WIDOWS CREEK
WIDOWS CREEK
TEIAS MUNICIPAL POWER AGENCY
CIBBONS CREEK
TERAS POWER t LIGHT
SANDOW
TWIN OAKS
THIN OAKS
TEIAS UTILITIES
FOREST BROVE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MILL CREEK
MILL CREEK
NONTICELLO
UTAH POWER I LIGHT
HUNTER
HUNTER
HUNTINGTON
UNIT NO. UNIT LOCATION
1
2
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
HATTISBUR6
HATTISBUR6
HALLSVILLE
SPRINGFIELD
SPRINGFIELD
MONACA
TAHPA
CUMBERLAND
MISSISSIPPI
MISSISSIPPI
TEXAS
MISSOURI
ILLINOIS
PENNSYLVANIA
FLORIDA
CITYTENNESSEE
NEW JOHNSONVILLTENNESSEE
PARADISE
PARADISE
PADUCAH
PADUCAH
BRIDGEPORT
BRIDGEPORT
CARLOS
ROCKDALE
BREMOND
BREMOND
ATHENS
TATUM
TATUM
TATUM
TATUM
HENDERSON
HENDERSON
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
ALABAMA
ALABAMA
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
MT. PLEASANT TEXAS
CASTLE DALE
CASTLE DALE
PRICE
UTAH
UTAH
UTAH
START-UP
DATE
8/78
6/79
2/84
4/77
7/80
7/79
3/85
7/82
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
1
3
1
2
2
6
6
5
7
T
1
1
2
1
T
2
5
5
5
1
1
1
3
6
6
1
1
2
1
RE6
CL*SS
A
A
A
1
A
e
A
c
c
c
c
c
c
c
c
A
II
A
A
A
A
A
A
A
D
D
A
A
A
A
WISCONSIN POWER t LIGHT
COLUMBIA
PORTAGE
WISCONSIN
1/82
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 FGD SYSTEMS; ALSO ALTERNATIVE METHODS
OILER 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
-------
?PA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ALABAMA ELECTRIC COOP
TOMBIGBEE
?
NEW 355.Q «U (6ROSS)
179.0 HW (ESC)
COAL
1.15 ZS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
SNERGY CONSUMPTION: 3.11
STATUS 1 STARTUP 9/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
PEABODT ENGINEERING WAS AWARDED A CONTRACT FOR THE INSTALLATION OF A
LIMESTONE FGD SYSTEM ON THIS UNIT. A HIGH-EFFICIENCY ESP INSTALLED
UPSTREAM OF THE FGD SYSTEM PROVIDES PRIMARY PARTICULATE CONTROL. THE FGD
SYSTEM CONTAINS TWO SCRUBBING TRAINS, TREATING APPROXIMATELY 701 OF THE
FLUE GAS FOR REMOVAL OF S02. STACK GAS REHEAT IS NOT REQUIRED. THE UNIT
IS CURRENTLY IN THE SHAKEDOWN-DEBUGGING PHASE OF OPERATIONS.
ALABAMA ELECTRIC COOP
TOMBIGBEE
t
NEW 255.0 *w (GROSS)
179.0 Kb (ESC>
COAL
1.15 ZS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
CNERSY CONSUMPTION: 3.12
STATUS 1 STARTUP 6/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
PEABODY ENGINEERING WAS AWARDED A CONTRACT FOR THE INSTALLATION OF A
LIMESTONE FGD SYSTEM ON THIS UNIT. A HIGH-EFFICIENCY ESP INSTALLED
UPSTREAM OF THE FGD SYSTEM PROVIDES PRIMARY PARTICULATE CONTROL. THE FGD
SYSTEM CONTAINS TWO SCRUBBING TRAINS* TREATING APPROXIMATELY 70Z OF THE
FLUE GAS FOR REMOVAL OF SOZ. STACK GAS REHEAT IS NOT REQUIRED.
ALLEGHENY POWER SYSTEM
«ITCHELL
3
RETROFIT 300.0 KW (GROSS)
300.0 MW (ESC)
COAL
2.80 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***«X
STATUS 6 STARTUP 8/82
ALLEGHENY POWER SYSTEM WILL INSTALL FLUE GAS DESUlFURIZATION EQUIPMENT
ON UNIT 3 AT THE MITCHELL POWER STATION. THE UTILITY IS CURRENTLY
IN THE PROCESS OF EVALUATING VARIOUS FGD TECHNOLOGIES. THE FGD IN-
STALLATION IS SCHEDULED TO BEGIN OPERATIONS IN AUGUST 1982.
ALLEGHENY POWER SYSTEM
PLEASANTS
1
NEW 625.0 1W (GROSS)
519.0 1W (ESC)
COAL
3.70 ZS BITUMINOUS
LIME
3ABCOCK 8 WILCOX
ENERGY CONSUMPTION: ***«X
STATUS 1 STARTUP 3/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE THREE PRINCIPAL OPERATING UTILITY COMPANIES OF THE ALLEGHENY POWER
SYSTEM HAVE INSTALLED AN EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED
UNIT WHICH INCLUDES A HIGH-EFFICIENCY ESP UPSTREAM OF FOUR TRAY TOWERS
FOR THE CONTROL OF PARTICULATES AND SULFUR DIOXIDE. DESIGN REMOVAL
EFFICIENCIES FOR THIS EMISSION CONTROL SYSTEM ARE 90 AND 99.5 PERCENT,
RESPECTIVELY. THE DRAVO CO. IS SUPPLYING THIOSORBIC LIME. THE CONSULTING
A-E DESIGN FIRM FOR THIS PROJECT IS STEARNS-ROGER.
LLESHENY POWER SYSTEM
PLEASANTS
2 ' I '
NEW 625.0 *W (GROSS)
519.0 flW (ESC)
COAL
4.50 XS BITUMINOUS
LIME
9ABCOCK g WILCOX
ENERGY CONSUMPTION: *«**X
STATUS 2 STARTUP 9/80
THE THREE PRINCIPAL OPERATING UTILITY COMPANIES OF THE ALLEGHENY POWER
SYSTEM ARE INSTALLING AN EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED
UNIT WHICH INCLUDES A HIGH-EFFICIENCY ESP UPSTREAM OF FOUR TRAY TOWERS
FOR THE CONTROL OF PARTICULATES AND SULFUR DIOXIDE. DESIGN REMOVAL
EFFICIENCIES FOR THIS EMISSION CONTROL SYSTEM ARE 90 AND 99.5 PERCENT*
RESPECTIVELY. THE DRAVO CO. IS SUPPLYING THIOSORBIC LIME. THE CONSULTING
ENGINEERING FIRM IS UNITED ENGINEERS AND CONSTRUCTORS. CURRENTLY,
FOUNDATION WORK ON THE SCRUBBER PLANT IS IN PROGRESS.
ARIZONA ELECTRIC POWER COOP
APACHE
?
NEW 195.0 «W (GROSS)
195.0 « (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 4.IX
STATUS 1 STARTUP 8/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE FGD
SYSTEM FOR THIS NEW 19$ MW UNIT WAS SUPPLIED BY RESEARCH COTTREL. THE
DESIGN INCLUDES A 22 ACRE SLUDGE POND AND A 64 ACRE ASH POND* BOTH OF
WHICH ARE UNLINED AND TEN FEET DEEP. A REHEAT SYSTEM IS NOT INCLUDED. THE
LINERS USED IN THE STACK AND THE DUCTS THAT LEAD TO THE STACK ARE A NEW
COLE BRAND CXL2000 WHICH HAS A VERY HIGH HEAT RESISTANCE. THIS UNIT BURNS
BITUMINOUS COAL WITH ASH CONTENTS OF .7X AND 10X RESPECTIVELY.
INITIAL OPERATION OF THIS UNIT BEGAN IN AUGUST, 1978.
. 6
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
RIZONA ELECTRIC POWER COOP
APACHE
y
1EW 195.0 4W (GROSS)
195.0 *W (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 4.11
STATUS 1 STARTUP 6/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
ERECTION Of THE SCRUBBER-ABSORBER TOWERS IS COMPLETE. EACH SCRUBBER CAN
HANDLE 400,000 ACFM AT 270F AND RECIRCULATE 20,000 6P" OF SLURRY.
THERE ARE CURRENTLY TWO PONDS WITH A TOTAL OF 20-
YRS CAPACITY FOR DISPOSAL OF UNFIXATED SLUD6E. TWO ADDITIONAL PONDS
ARE PLANNED PROVIDING AN ADDITIONAL 20 YRS OF DISPOSAL CAPABILITY. THERE
IS NO REHEAT. BECAUSE OF THE HJ6H COST OF THE UNIT 2 STACK LINER.
UNIT 3 USES A CEILCOTE LINING INSTEAD OF THE CXL2000 USED IN UNIT 2.
ARIZONA PUBLIC SERVICE
CHOLLA
1
RETROFIT 119.0 *u (GROSS)
119.0 MW (ESC)
COAL
.50 ZS BITUMINOUS
LIMESTONE
9ESEARCH COTTRELL
ENERGY CONSUMPTION: 3.4X
STATUS 1 STARTUP 10/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION
THIS LIMESTONE SCRUBBING SYSTEM MAS PLACED IN SERVICE IN OCTOBER 1973.
THIS SCRUBBER PLANT CONSISTS OF TWO PARALLEL SCRUBBING TRAINS.
PARTICULATE CONTROL IS PROVIDED BY TWO FLOODED DISC SCRUBBERS. S02
CONTROL IS PROVIDED BY ONE PACKED (MUNTERS PACKING) TOWER (A-SIDE).
FLUE EAS CLEANING WASTES ARE DISCHARGED TO AN EXISTING FLY ASH POND.
NO WATER IS RECYCLED BACK FROM THE DISPOSAL POND. IN-LINE STEAM
REHEATERS RAISE THE GAS TEMPERATURE 40 F.
ARIZONA PUBLIC SERVICE
CHOLLA
2
HEW 350.0 1W (GROSS)
350.0 "W (ESC)
COAL
.50 ZS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: *«»
STATUS 1 STARTUP 4/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE CONTRACT FOR THIS WET LIMESTONE SCRUBBING SYSTEM WAS AWARDED BY THE
UTILITY TO RESEARCH-COTTRELL. THE DESIGN INCLUDES MECHANICAL COLLECTORS
FOR PRIMARY PARTICULATE REMOVAL. THE FGD SYSTEM CONSISTS OF FOUR PARALLEL
FLOODED DISC AND PACKED TOWER ABSORBER TRAINS. THREE ARE RECUIRED FOR
FULL LOAD CAPACITY. INITIAL OPERATIONS BEGAN IN APRIL 1978. COMPLIANCE
TESTING WAS COMPLETED DURING THE SECOND WEEK OF AUGUST 1978.
ARIZONA PUBLIC SERVICE
CHOLLA
4
«EW 350.0 MW (GROSS)
126.0 MW (ESC>
COAL
.50 ZS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: ««(
STATUS 2 STARTUP 6/80
UNIT NO. 4 IS CURRENTLY UNDER CONSTRUCTION. APS HAS AWARDED THE FGD
CONTRACT TO RESEARCH COTTRELL. THE STATE REGULATORY AGENCY HAS NOT YET
DECIDED THE EMISSION REGULATIONS WHICH WILL APPLY TO THE PLANT. THE C-E
BOILER WILL FIRE THE SAME COAL AS CHOLLA N0.1, WITH SULFUR CONTENT OF
0.44-1.0 PERCENT* THE A-E FIRM IS EBASCO. THE FGD SYSTEM IS A DOUBLE LOOP
LIMESTONE ABSORPTION PROCESS AND REVENUES OF THE CONTRACT TO R-C ARE
REPORTED TO BE SS MM. FOR CONTROL OF PARTICULATE, AN ESP WILL HANDLE
100Z OF THE FLUE GAS.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT 175.0 MW (GROSS)
175.0 «W (ESC)
COAL
.75 ZS SUBB1TUHINOUS
LIME/ALKALINE FLYASH
CHEMICO
ENERGY CONSUMPTION: X
STATUS 2 STARTUP 0/79
APS IS UPGRADING THE OPERATIONAL PARTICULATE SCRUBBERS AT THE FOUR
CORNERS 1.2* AND 3 FOR ADDITIONAL S02 REMOVAL. CURRENTLY, EACH UNIT HAS 2
CHEMICO VENTURI SCRUBBER MODULES FOR PARTICULATE CONTROL. ROUGHLY 30X OF
THE FLUE CAS S02 CONTENT IS REMOVED AT THE PRESENT TIME IN THE VENTURIS
WITH THE HIGH AKALINE FLYASH. NEW MEXICO APC OFFICIALS INDICATED THAT
THE 5 FOUR CORNERS UNITS WILL BE REQUIRED TO REMOVE AT LEAST 67.5Z OF THE
STATION S02(ALL 5 UNITS CONSIDERED TOGETHER). ADDITIONAL ALKALINITY WILL
BE IMPARTED TO THE SCRUBBING SOLUTION BY ADDING LIME.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
RETROFIT 175.0 NW (GROSS)
175.0 MW (ESC)
COAL
.75 IS SUBBITUHINOUS
LIME/ALKALINE FLYASH
CHEHICO
ENERGY CONSUMPTION: X
STATUS 2 STARTUP 0/79
APS IS UPGRADING THE OPERATIONAL PARTICULATE SCRUBBERS AT THE FOUR
CORNERS 1.2, AND 3 FOR ADDITIONAL S02 REMOVAL. CURRENTLY, EACH UNIT HAS 2
CHEMICO VENTURI SCRUBBER MODULES FOR PARTICULATE CONTROL. ROUGHLY 3OX OF
THE FLUE GAS S02 CONTENT IS REMOVED AT THE PRESENT TIME IN THE VENTURIS
WITH THE HIGH ALKALINE FLYASH. NEW MEXICO APC OFFICIALS INDICATED THAT
THE 5 FOUR CORNERS UNITS WILL BE REQUIRED TO REMOVE AT LEAST 67.5Z OF THE
STATION S02(ALL 5 UNITS CONSIDERED TOGETHER). ADDITIONAL ALKALINITY WILL
BE IMPARTED TO THE SCRUBBING SOLUTION BY ADDING LIME.
-------
EP* UTILITY FGD SUPVEY: SECOND QUARTER 1«79
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDEXTIfICATION
ABSTRACT
ARIZONA PUBLIC SERVICE
FOUR CORNERS
v
RETROFIT 229.0 MW (GROSS)
229.0 «W (ESC)
COAL
.75 IS SUBBITUMINOUS
LIME/ALKALINE FLVASH
CHEMICO
?NER6Y CONSUMPTION: «!
STATUS 2 STARTUP 0/79
APS IS UPGRADING THE OPERATIONAL PARTICULATE SCRUPBERS AT THE FOUR
CORNERS 1.2t AND 3 FOR ADDITIONAL S02 REMOVAL. CURRENTLY. EACH UNIT HAS i
CHEMICO VENTURI SCRUBBER MODULES FOR PARTICULATE CONTROL. ROUGHLY 301 OF
THE FLUE GAS S02 CONTENT IS REMOVED AT THE PRESENT TIME IN THE VENTURIS
WITH THE HIGH AKALINE FLVASH. NEW MEXICO APC OFFICIALS INDICATED THAT
THE 5 FOUR CORNERS UNITS WILL BE REQUIRED TO REMOVE AT LEAST 67.5Z OF THE
STATION S02(ALL 5 UNITS CONSIDERED TOGETHER). ADDITIONAL ALKALINITY KILL
BE IMPARTED TO THE SCRUBBING SOLUTION BY ADDING LIME.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
I
RETROFIT 755.o MW (GROSS)
7SS.O "W (ESC)
COAL
.75 tS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: !
STATUS 3 STARTUP 0/62
THE UTILITY IS CURRENTLY EVALUATING THE DATA AND INFORMATION ACCUMULATED
DURING THE HORIZONTAL PROTOTYPE SCRUBBING PROGRAM IN ORDER TO ASCERTAIN
VARIOUS POSSIBLE STRATEGIES TO CONTROL THE EMISSIONS FROM THIS COAL FIRED
75S-MW UNIT. APS WILL BE REQUIRED TO REDUCE THE CURRENT LEVEL OF 502
EMISSIONS FROM THE ENTIRE PLANT BY INCREASING THE REMOVAL EFFICIENCY
TO AT LEAST 67.St. A CONTRACT HAS BEEN AWARDED TO UNITED ENGINEERS FOR
THE ENGINEERING AND CONSTRUCTION OF AN FGD SYSTEM.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5
RETROFIT 755.0 MM (GROSS)
755.0 MU (ESC)
COAL
.75 IS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: *»
STATUS 3 STARTUP 0/82
THE UTILITY IS CURRENTLY EVALUATING THE DATA AND INFORMATION ACCUMULATED
DURINE THE HORIZONTAL PROTOTYPE SCRUBBING PROGRAM IN ORDER TO ASCERTAIN
VARIOUS POSSIBLE STRATEGIES TO CONTROL THE EMISSIONS FROM THIS COAL FIRED
7S5-MH UNIT. APS WILL BE REQUIRED TO REDUCE THE CURRENT LEVEL OF S02
EMISSIONS FROM THE ENTIRE PLANT BY INCREASING THE REMOVAL EFFICIENCY
TO AT LEAST 67.51. A CONTRACT HAS BE AWARDED TO UNITED ENGINEERS FOR
THE ENGINEERING AND CONSTRUCTION OF AN FGD SYSTEM.
ASSOCIATED ELECTRIC COOP
THOMAS HILL
i
NEW 730.0 MM (GROSS)
670.0 NW (ESC)
COAL
4.83 ZS
LIMESTONE
PULLMAN KELL066
ENERGY CONSUMPTION: Z
STATUS 2 STARTUP 1/62
ASSOCIATED ELECTRIC COOP AWARDED A CONTRACT TO PULLMAN KELLOGG FOR THE
ENGINEERING. PROCUREMENT AND CONSTRUCTION OF AN FGD SYSTEM ON THE UTILI-
TY'S THOMAS HILL UNIT NO. 3 POWER PLANT. S02 REMOVAL EQUIPMENT WILL OPER-
ATE IN CONJUNCTION WITH A HIGH EFFICIENCY ESP. THE SYSTEM, SCHEDULED FOR
START-UP IN 1982, WILL UTILIZE MAGNESIUM-PROMOTED LIMESTONE AS A REAGENT
IN THE FOUR MODULE WEIR FGD SYSTEM. REHEAT WILL PROBABLY NOT BE INCLUDED.
THE STACK WILL BE BRICK LINED. THE DRV FIXATED SLUDGE WILL BE
HAULED TO AN ACTIVE STRIP MINE. CONSTRUCTION IS NOW IN PROGRESS.
FGD SYSTEM HAVE BEGUN.
9ASIN 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
THE UTILITY HAS SELECTED A LIME SCRUBBING PROCESS FOR THEIR PLANNED
FGD SYSTEM. THE UNIT WILL FIRE LIGNITE COAL WITH A SULFUR CONTENT
OF 0.68 PERCENT AND AN ASH CONTENT OF 8.0 PERCENT (6600 6TU/LB). THE
WATER LOOP WILL BE OPEN WITH MAKE-UP COMING FROM COOLING TOWER SLOWDOWN.
THE SLUDGE WILL BE DISPOSED IN A NINE LANDFILL. A CONTRACT HAS BEEN
AWARDED TO WESTERN PRECIPITATION OIVISON, JOY MFG. CO. FOR A DRY FGD
SYSTEM. THE SPRAY DRYER HAS BEEN SUBCONTRACTED TO NIRO ATOHITER.
3ASIN 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: Z
STATUS 6 STARTUP 11/83
THE UTILITY IS TENTATIVELY INVESTIGATING VARIOUS F6D PROCESSES FOR THIS
SECOND LIGNITE-FIRED UNIT SCHEDULED AT THE NEW STATION LOCATED IN MERCER
COUMTY. NEAR BEULAH, NORTH DAKOTA. THIS NEW FACILITY WILL BE KNOWN AS
THE ANTELOPE VALLEY STATION AND WILL BE REQUIRED TO COMPLY WITH STATE
AIR EMISSIONS STANDARDS VIA THE BEST AVAILABLE TECHNOLOGY. START-UP IS
NOW SCHEDULED FOR NOVEMBER 1983.
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS Of F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
BASIV ELECTRIC POWER COOP
LARAMIE RIVER
1
NEW 600.0 MM (CROSS)
600.0 MM (ESC)
COAL
.80 ZS
LIMESTONE
RESEARCH COTTRELL .
ENERGY CONSUMPTION: X*
STATUS 2 STARTUP 4/80
RESEARCH-COTTRELL IS CURRENTLY FABRICATING THE DUAL-LOOP LIMESTONE WET
SCRUBBERS. ON-SITE CONSTRUCTION COMMENCED IN JANUARY 1978. SLU06E WILL BE
DEWATERED TO 8TI SOLIDS BEFORE LANDFILL. THE SCRUBBERS WILL BE FADE OF
STAINLESS STEEL AND WILL HANDLE 2.3 MM ACFM AT 386 F. L/6 RATIO WILL 6E
60. BU HAS BEEN AWARDED A CONTRACT FOR TWO ESP'S. THE DESIGN DOES NOT
INCLUDE STACK 6AS REHEAT. COOLING TOMER SLOWDOWN WILL BE USED FOR H»«E-UP
WATER IN THIS CLOSED LOOP SYSTEM. CONSTRUCTION IS NOW 20X COMPLETE.
3ASIN ELECTRIC POWER COOP
LARAM IE RIVER
2
EH 600.0 MU (6ROSS)
600.0 MM (ESC>
COAL
.80 XS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: **!
STATUS 2 STARTUP 10/80
RESEARCH-COTTRELL IS CURRENTLY FABRICATING THE DUAL-LOOP LIMESTONE WET
SCRUBBERS. ON-SITE CONSTRUCTION COMMENCED IN JANUARY 1978. SLUDfE WILL 8E
DEMATERED TO SIX SOLIDS BEFORE LANDFILL. THE SCRUBBERS MILL BE »ADE OF
STAINLESS STEEL AND MILL HANDLE 2.3 MM ACFM AT 206 F. L/6 RATIO WILL BE
60. EU HAS BEEN AWARDED A CONTRACT FOR TWO ESP'S. THE DESIGN DOES NOT
INCLUDE STACK EAS REHEAT. COOLING TOMER SLOWDOWN WILL BE USED FOR MAKE-UP
MATER IN THIS CLOSED LOOP SYSTEM. CONSTRUCTION IS NOW 201 COMPLETE.
BASIN ELECTRIC POMER COOP
LARANIE RIVER
3
NEW 600.0 MM (CROSS)
600.0 MM (ESC)
COAL
.54 ZS
LIME/SPRAY DRVINC
9ABCOCK I WILCOX
ENERGY CONSUMPTION: X
STATUS 3 STARTUP 4/82
LARAMIE RIVER STATION MILL FIRE SUfiBlTUMINOUS COAL WITH THE FOLLOWING
CHARACTERISTICS: S100 BTU/LB, 0.8 PERCENT SULFUR AND 7.0 PERCENT ASH A
CONTRACT FOR A DRY TYPE FGD SYSTEM HAS BEEN AWARDED TO BABCOCK 8 HLCOX.
9IG RIVERS ELECTRIC
GREEN
1
NEW 242.0 MU (GROSS)
242.0 MM (ESC>
COAL
3.75 SS BITUMINOUS
LINE
AMERICAN AIR FILTER
ENERGY CONSUMPTION: X
STATUS 2 STARTUP 10/79
THE EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED UNIT IS BEING
SUPPLIED BY AMERICAN AIR FILTER. THE SYSTEM WILL CONSIST OF A COLD-SIDE
ESP AND TWO SPRAY TOMERS CONTROLLING PARTICULATE AND S02 TO 99.6 PEPCEST
AND 90 PERCENT. RESPECTIVELY. THE BtW BOILER WILL FIRE HIGH SULFUR (3.5
TO 4.5 PERCENT) WESTERN KENTUCKY COAL. CONSTRUCTION IS NOW C61 COMPLETE
ON THE BOILER AND SOX COMPLETE ON THE FGD SYSTEM. THE DESIGN INCLUDES AN
INDIRECT HOT AIR REHEAT SYSTEM. IUCS MILL CONSTRUCT A SLUDGE DISPOSAL
SYSTEM TO SERVICE BOTH GREEN 1 AND 2.
BIG RIVERS ELECTRIC
GREEN
?
NEW 242.0 MM (GROSS)
242.0 MM (ESC)
COAL
3.75 SS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: X
STATUS 2 STARTUP 6/80
THE EMISSION CONTROL SYSTEM FOR THIS N£H COAL-FIRED UNIT IS BEING
SUPPLIED BY AMERICAN AIR FILTER. THE SYSTEM WILL CONSIST OF A COLD SIDE
ESP AND TWO SPRAY TOWERS CONTROLLING PARTICULATE AND S02 TO 99.6 PERCENT
AND 90 PERCENT, RESPECTIVELY. THE B»M BOILER WILL FIRE HIGH SULFUR (3.5
4.5 PERCENT) WESTERN KENTUCKY COAL. THE FGD SYSTEM HILL INCLUDE AN
INDIRECT HOT AIR REHEAT SYSTEM. IUCS MILL CONSTRUCT A SLUDGE DISPOSAL
SYSTEM TO SERVICE BOTH GREEN 1 AND 2. THE BOILER IS CURRENTLY CX COMPLETE
AND CONSTRUCTION HAS JUST BEGUN ON THE FGD SYSTEM.
CENTRAL ILLINOIS LI6HT
DUCK CREEK
1
NEW 416.0 MW (GROSS)
416.0 NU (ESC)
COAL
3.30 IS BITUMINOUS
LIMESTONE
ILEY STOKER/ENVIRONEERIN6
ENERGY CONSUMPTION: 2.9Z
STATUS 1 STARTUP 9/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. RILEY
STOKER WAS THE SUPPLIER OF THE FOUR VENTURI-ABSORBER MODULES AT THIS
UNIT. SCRUBBER TANKS AND PUMPS ARE NEOPRENE LINED. A HIGH EFFICIENCY ESP
IS UPSTREAM OF THE FOUR VENTURI-ABSORBER SCRUBBER MODULES FOR PARTICULATE
CONTROL. THE CONCRETE STACK IS LINED WITH CEILCOTE FLAKELINE 151. NO RE-
HEAT SYSTEM IS INCLUDED. THE FIRST LIMESTONE SLURRY SCRUBBER MODULE WAS
PLACE* IN SERVICE ON SEPTEMPER 9,1976. AND OPERATED INTERMITTENTLY UNTIL
APRIL 1, 1977. ALL FOUR NODULES BECAME OPERATIONAL ON JULY 24. 1978.
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CENTRAL ILLINOIS LIGHT
DUCK CREEK
2
NEW 416.0 WW (CROSS)
416.0 «W (ESC)
COAL
3.30 ZS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENER&Y CONSUMPTION: 2.9Z
STATUS 5 STARTUP 1/84
THE UTILITY HAS NOT YET SELECTED A STSTE* SUPPLIER. THE UTILITY HILL
USE ESP'S FOR PARTICULATE CONTROL AND EITHER LIMESTONE OR DOUBLE ALKALI
FOR S02 APSORPTION. THE UTILITY IS NOB IN THE PROCESS OF EVALUATING
BIOS AND A STUDY IS UNDERWAY TO DETERMINE THE SLUD6E DISPOSAL STRATE6Y
THAT HILL BE EMPLOYED.
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
NEW 617.0 MM (CROSS)
617.0 «W (ESC)
COAL
4.03 ZS BITUMINOUS
DUAL ALKALI
3UELL/ENVIROTECH
ENERGY CONSUMPTION: X
STATUS 2 STARTUP 11/79
A CONTRACT HAS BEEN AWARDED BY CIPSO TO BUELL/ENWIROTECH FOR THE
INSTALLATION OF AN EMISSION CONTROL SYSTEM ON UNIT 1. THE KEY COM-
PONENTS OF THE EMISSION CONTROL SYSTEM INCLUDE: A HIGH-EFFICIENCY ESP;
FOUR PRECOOLERS. FOUR POLVSPHERE ABSORBERS, THREE THICKENERS, TWO EX-
PERIMENTAL REHEAT SYSTEMS. AND THREE HORIZONTAL EXTRACTION FILTERS FOR
SLUDGE DEWATERINC. CONSTRUCTION WORK IS NOW COMPLETE AND TESTS
ARE BEING RUN ON THE SYSTEM.
CENTRAL 1AINE POKER
SEARS ISLAND
1
NEW 600.0 MW (GROSS)
600.0
COAL
**. xs
LINE/LIHESTONt
VENDOR NOT SELECTED
ENER6V CONSUMPTION: Z
STATUS 6 STARTUP 11/67
BECAUSE OF THE DISCOVERY OF A GEOLOGICAL FAULT ON SEARS ISLAND, THE
UTILITY HAS CANCELLED PLANS FOR A 1150-MW NUCLEAR POWER PLANT. A 600-MW
COAL FIRED UNIT IS NOW BEING PLANNED IN ITS PLACE. COMMERCIAL OPERATION
IS PROJECTED FOR NOVEMBER 1987. COMPLIANCE WITH SOZ NSPS WILL BE
ACHIEVED BY INSTALLING AN F6D SYSTEM. LINE AND LIMESTONE SCRUBBING
PROCESSES ARE BEING GIVEN PRIMARY CONSIDERATION. CURRENTLY, CMPCO HAS
FILED AN APPLICATION WITH THE STATE PUBLIC UTILITIES COMMISSION. A DE-
LAY IN RECEIVING A PERMIT FROM THE MAINE PUBLIC UTILITIES COMMISSION
HAS RESULTED IN A REVISED START-UP DATE OF NOVEMBER 1987.
CINCINNATI GAS t ELECTRIC
EAST BEND
2
NEW 6SQ.O
-------
EP> UTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION Z
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COLUMBUS t SOUTHERN OHIO ELEC.
CONESVILLE
5
NEW 411.0 *W (GROSS)
411.0 KH CESC)
COAL
4.67 IS BITUMINOUS
LIKE
«IR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 3.91
STATUS 1 STARTUP 1/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE
BOILER AND ESP WERE COMPLETED AND PLACED IN SERVICE IN SEPTEMBER 1976.
THE B-SIDE MODULE BECAME AVAILABLE FOR SERVICE IN JANUARY 1977.
COMMERCIAL OPERATIONS HERE ACHIEVED ON FEBRUARY 13, 1977. THE EMISSION
CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A COLD-SIDE ESP FOLLOWED BY
TWO LIME TCA MODULES SUPPLIED B* OOP. ORAVO IS SUPPLING THE THIOSORBIC
LIME REAGENT. IUCS IS SUPPLYING A POZ-0-TEC SLUDGE STABILIZATION FACILITY.
COLUMBUS ( SOUTHERN OHIO ELEC.
CONESVILLE
5
NEW 411.0 MM (GROSS)
411.0 My
COAL
4.67 tS BITUMINOUS
LIME
«IR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 3.91
STATUS 1 STARTUP 6/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. CCSOE
SIGNED LONG TERM CONTRACTS WITH DRAVO FOR THE PURCHASE OF THIOSORelC
AND WITH IUCS FOR A SLUDGE FIXATION SYSTEM. CONSTRUCTION COMMENCED IN
1977 AND HAS COMPLETED IN JANUARY 1978. SIMILAR TO UNIT 5, THIS MINE
MOUTH PLANT BURNS COAL WITH i?x ASH AND 4.5 TO 4.9* SULFUR CONTENTS. THE
DESIGN INCLUDES AN ESP UPSTREAM OF THE FGD SYSTEM FOR PARTICIPATE
CONTROL. THE FGD SYSTEM INCLUDES TUO LIME TCA MODULES FOR THE REMOVAL OF
S02.
COLUMBUS
COS TON
5
NEW
t SOUTHERN OHIO ELEC.
375.0 MW (CROSS)
375.0 MU (ESC)
COAL
2.50 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:
STATUS 6 STARTUP 0/83
THIS UNIT WILL BURN HIGH SULFUR OHIO COAL (APPROXIMATELY 2.5 PERCENT
SULFUR CONTENT). THE DESIGN OF THE EMISSION CONTROL STRATEGY HAS NOT
YET BEEN FINALIZED. THE PROCESS MILL EITHER BE LIME, LIMESTONE, OR
DOUBLE ALKALI.
COLUMBUS
POSTON
6
NEtf
I SOUTHERN OHIO ELEC.
THIS UNIT HILL BURN HIGH SULFUR COAL (APPRO*IMATELY 2.5 PERCENT SULFUR
CONTENT). THE DESIGN OF THE EMISSION CONTROL STRATEGY FOR THIS UNIT
HAS NOT YET BEEN FINALIZED.
375.0 NW (GROSS)
375.0 MU (ESC)
COAL
2.50 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »
STATUS 6 STARTUP 0/89
COMMONWEALTH EDISON
POWERTON
51
RETROFIT 450.0 NW (GROSS)
450.0 MW (ESC)
COAL
3.60 ZS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 5.61
STATUS 2 STARTUP 11/79
THE AIR CORRECTION DIVISION OF UOP WAS AWARDED THE CONTRACT FOR A WET
LIMESTONE SYSTEM THAT WILL BE BACKFITTED ON TO BOILER NO. 51, ONE OF TWO
IDENTICAL BOILERS SUPPLING STEAM TO AN 850-MW TURBINE-GENERATOR. THE
SLUDGE WILL BE STABILIZED AND HAULED TO A LANDFILL. REHEAT WILL BE
PROVIDED BY A STEAM COIL WHICH WILL HEAT THE AMBIENT AIM THAT IS PUMPED
INTO THE SCRUBBER OUTLET BEFORE THE FLUE GAS ENTERS THE STACK. THE S02
EMISSION STANDARD IS 1.8 LB. S02/MH BTU. CONSTRUCTION IS
ABOUT 801 COMPLETE.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
1
NEW 545.0 1W (GROSS!
327.0 MW (ESC)
COAL
.63 ZS LIGNITE
LIME/ALKALINE FLVASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: «*««Z
STATUS 2 STARTUP 7/79
THIS UNIT IS UNDER THE COMBINED OWNERSHIP OF COOP POWER AND UNITED POWER.
A CONTRACT HAS BEEN AWARDED TO COMBUSTION ENGINEERING FOR THE INSTALLA-
TION OF LIME FGD SYSTEMS ON UNITS 1 AND 2 AT THIS STATION. THE FGD SYSTEM
FOR EACH BOILER WILL CONSIST OF FOUR SPRAT TOWER ABSORBER MODULES FOR $02
REMOVAL. ELECTROSTATIC PRECIPITATORS WILL BE INSTALLED UPSTREAM OF EACH
ABSORBER TRAIN. CONSTRUCTION BEGAN EARLY IN AUGUST 1977. THE UNIT IS NOW
85-90S COMPLETE. BAD WINTER WEATHER SLOWED CONSTRUCTION SLIGHTLY.
11
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COOPERATIVE POWER ASSOCIATION
COAL CREEK
2
«EU 5*5.0 4W <6ROSS>
327.0 'W IESC>
COAL
63 ZS LIGNITE
LIME/ALKALINE FLVASH
COMBUSTION ENGINEERING
FNEBST CONSUNPTION; !
STATUS 2 STARTUP 10/80
THIS UNIT IS UNDER TME COMBINED OWNERSHIP OF COOP POwER AND UNITED POWER.
A CONTRACT HAS BEEN AWARDED TO COMBUSTION ENGINEERING FOR THE INSTALLA-
TION OF LIRE F6D SYSTEMS ON UNITS 1 AND 2 AT THIS STATION. THE F6D STSTEH
FOR EACH BOILER WILL CONSIST OF FOUR SPRAT TOWER ABSORBER MODULES FOR S02
REMOVAL. ELECTROSTATIC PRECIPITATORS WILL BE INSTALLED UPSTREAM OF EACH
ABSORBER TRAIN. CONSTRUCTION BEGAN EARLt IN AUGUST 1977 AND THE UNIT IS
NOW SOX COBPLETE. THERE HAVE BEEN MINOR DELAYS BUT START-OP IS STILL
SCHEDULED FOR NOVEMBER 1979.
DELMARVA POWER ft LIGHT
DELAWARE CITY
1-3
RETROFIT 160.0 4W (GROSS)
180.0 *W (ESC)
COKE
7.50 XS COKE
HELL*AN LORD
DAVY POWERGAS
ENERGY CONSUNPTION: «!
STATUS 2 STARTUP */80
DELAARVA'S DELAWARE CITY PLANT HAS 4 BOILERS* 3 OF WHICH HAVE STEAM
CAPACITIES OF 500* LBS/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS
ELECTRICAL POWER FOR GETTY REFINING t MARKETING. 7-8X S COKE WILL BE
BURNED IN THE BOILERS (INSTEAD OF THE LOW-S CRUDE OIL NOW BURNED) WHEN
THE CONTROL SYSTEM GOES INTO OPERATION IN APRIL 1980. DELMARVA WILL USE
VENTUR1 SCRUBBERS FOR PARTICULATE REMOVAL AND WELLMAN-LORD F6D SYSTEMS AT
EACH BOILER GAS EXIT FOR S02 CONTROL. DESIGN PARTICULATE AND S02 REMOVAL
EFFICIENCIES ARE 90 AND 85-90 PERCENT RESPECTIVELY. CONSTRUCTION IS 61X
COMPLETE.
DUOUESNE LIGHT
ELRAHA
RETROFIT
510.0 4W (GROSS)
510.0 MW (ESC)
* XS
LIME
CHEMICO
ENERGY CONSUMPTION: 3.52
STATUS 1 STARTUP 10/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE FGD SYSTEM ON THIS 4-BOILER UNIT CONSISTS OF FIVE COMMON-HEADERED
SINGLE STAGE VENTURI SCRUBBER-ABSORBERS DOWNSTREAM FROM A MECHANICAL
COLLECTQR-ESP PARTICULATE REMOVAL SYSTEM. THE PLANT BURNS COAL WITH A
HEATING VALVE OF 11.000 BTU/LB AND SULFUR AND ASH CONTENTS OF 1.8 TO 2.2X
AND 21X RESPECTIVELY. DEWATERED SLUDGE FROM THE IUCS PLANT IS HAULED To
AN OFF-SITE LANDFILL. THE SYSTEM INCLUDES A DIRECT OIL-FIRED STACK GAS
REHEAT SYSTEM. DESIGNED REMOVAL EFFICIENCIES ARE 991 (PART) AND 83X
(S02).
DUOUESNE LIGHT
PHILLIPS
1-6
RETROFIT *io.o MW (GROSS)
410.0 MW (ESC)
COAL
2.20 XS BITUMINOUS
LINE
CHEHIcO
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 7/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE FGD SYSTEM ON THIS 6-60ILER UNIT CONSISTS OF ONE 2-STAGE AND THREE
SINGLE STAGE VENTURI SCRUBBER-ABSORBERS DOWNSTREAM FROM A MECHANICAL
COLLECTOR-ESP PARTICULATE REMOVAL SYSTEM. THE PLANT BURNS COAL WITH A
HEATING VALVE OF 11.000 BTU/LB AND SULFUR AND ASH CONTENTS OF 1.8 TO 2.2X
AND 211 RESPECTIVELY. DEWATERED SLUDGE FROM THE IUCS PLANT IS HAULED TO
AN OFF-SITE LANDFILL. THE SYSTEM INCLUDES A DIRECT OIL-FIRED STACK GAS
REHEAT SYSTEM. DESIGNED REMOVAL EFFICIENCIES ARE 99KPART) AND 83X(S02).
EAST KENTUCKY POWER COOP
SPURLOCK
2
ȣW 500.0 *W (GROSS)
100.0 MH (ESC)
COAL
3.50 XS
LIME
ADL/CONBUSTION E9UIP ASSOCIATE
ENERGY CONSUMPTION: X
STATUS 2 STARTUP 10/80
A CONTRACT HAS BEEN AWARDED TO ADL/COMfiUSTlON EQUIPMENT ASSOCIATES FOR
A LIME SLURRY FGD SYSTEM ON THE NEW 500-MW UNIT SPURLOCK 2. PARTICULATES
HILL BE CONTROLLED BY A 99.5X EFFICIENT ESP. COOLING TOMER SLOWDOWN HILL
BE USED AS THE MAKE-UP WATER SOURCE FOR THE FGD SYSTEM. THE DESIGN $02
REMOVAL EFFICIENCY IS 90X. THE SYSTEM IS NOW ABOUT 10X COMPLETE.
GENERAL PUBLIC UTILITIES
COHO
1
HEM 800.0 MW (GROSS)
800.0 NW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: X
STATUS 6 STARTUP 5/88
STARTUP DATE WAS CHANGED TO 5/88 FOR BOTH BOILER AND DESULFURIZATION
SYSTEM. LIME AND LIMESTONE SCRUBBING ARE THE PRIMARY STRATEGIES BEING
CONSIDERED FOR COMPLIANCE WITH NEW SOURCE PERFORMANCE STANDARDS. NO
DECISION HAS BEEN MADE YET, ALTHOUGH A SLURRY TYPE SYSTEM IS NOT
CONTEMPLATED.
12
-------
EPA UTILITY F60 SURVEY: SECOND 8UARTER 1979
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
GENERAL PUBLIC UTILITIES
SEVARD
7
NEW 800.0 MW (CROSS)
SOO.O NW (ESC)
COAL
** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: !
STATUS 6 STARTUP 12/85
START-UP DATE WAS CHANGED TO 12/85 FOR BOTH BOILER AND DESULFURIZATION
SYSTEM. LIKE AND LIMESTONE SCRUBBING ARE THE PRIMARY STRATEGIES BEIN6
CONSIDERED FOR COMPLIANCE WITH THE NEW SOURCE PERFORMANCE STAND*RDS.
NO DECISION HAS BEEN MADE YET. ALTHOUGH A SLURRY TYPE WILL NOT ff USED,
SULF POWER
SCHOLZ
tfZ
RETROFIT 23.0 *H (GROSS)
23.0 MW (ESC)
COAL
2.50 ZS BITUMINOUS
LIMESTONE/THOROUGHBRED 121
CHIfODA INTERNATIONAL
ENER6Y CONSUMPTIONS !
STATUS 1 STARTUP 8/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. CMIYQDA
INTERNATIONAL SUPPLIED THIS 23 MH PROTOTYPE UNIT WHICH BE6AN OPERATION
ON AUGUST 30, 1978. THE CT-121 SYSTEM INCLUDES A NEWLY DEVELOPED JET
BUBBLING REACTOR WHICH FEATURES A LARGE GAS-LI8UID INTERFACIAL AREA AND
PROVIDES PARTICULAR AS WELL AS $02 REMOVAL. MIST ELIMINATION is PROVIDED
BY A DOUBLE PASS VERTICAL CHEVRON. GYPSUM IS PRODUCED AND STACKED IN THE
EXISTING POND. THE STACKING CAPABILITIES OF THE GYPSUM ARE BEING TESTED,
ALONG WITH THE GROUND WATER NEAR THE STACK SITE TO CHECK FOR LEACHING.
HOOSIER ENERGY
MEROM
1
«EW 490.0 MW (GROSS)
441.0 MW (ESC)
COAL
3.50 IS
LIMESTONE
MITSUBISHI INTERNATIONAL
ENERGY CONSUMPTION: *!
STATUS 2 STARTUP 4/81
HOOSIER ENERGY AWARDED A CONTRACT TO MITSUBISHI INTERNATIONAL CORP. FOR
TWO LIMESTONE FGD SYSTEMS FOR HEROM 1 AND 2. THE NEW 490 MW COAL-FIRED
UNITS ARE PLANNED FOR LOCATION IN SULLIVAN, INDIANA. THE FLUE GAS STREAMS
WILL BE CLEANED OF PARTICULATE WITH ESP'S (99.41) AND OF SULFUR DIOXIDE
WITH GRID-TOWER ABSORBERS (9oz>. SLUDGE WILL BE STABILIZED AND
STOCKPILED. THE GROUND WAS BROKEN FOR CONSTRUCTION IN NOVEMBER 1977.
BOILER STRUCTURAL STEEL IS NOW BEING ERECTED AND FGD FOOTINGS ARE IN PLACE
HOOSIER ENERGT
MEROM
2
NEW 490.0 MW (GROSS)
441.0 MW (ESC)
COAL
3.50 ZS
LIMESTONE
MITSUBISHI INTERNATIONAL
ENERGY CONSUMPTION: *«
STATUS 2 STARTUP 1/82
HOOSIER ENERGY AWARDED A CONTRACT TO MITSUBISHI INTERNATIONAL CORP. FOR
TWO LIMESTONE FGD SYSTEMS FOR MEROM 1 AND 1. THE NEW 490 MW COAL-FIRED
UNITS ARE PLANNED FOR LOCATION IN SULLIVAN, INDIANA. THE FLUE GAS STREAMS
WILL BE CLEANED OF PARTICULATE WITH ESP'S (99.4X) AND OF SULFUR DIOXIDE
WITH GRID-TOMER ABSORBERS (90S). SLUDGE WILL BE STABILIZED AND
STOCKPILED. THE (ROUND HAS BROKEN FOR CONSTRUCTION IN NOVEMBER 1977, BUT
DUE TO THE BAD WINTER WEATHER. CONSTRUCTION WAS DELAYED. THE BOILER IS
ESSENTIALLY COMPLETE. STARTUP IS EXPECTED SHORTLY.
HOUSTON LIGHTING ( POWER CO,
H.A. PARISH
B
MEW 550.0 MH (GROSS)
512.0 MW (ESC)
COAL
.60 ZS
LIMESTONE
VENDOR NOT SELECTED
ENER6T CONSUMPTION: »*!
STATUS 5 STARTUP 10/82
HUP WILL BE INSTALLING AN FGD SYSTEM ON TH£ UTILITY'S 600 MW W. »--
PARISH 8 UNIT. PARTICUALTE MATTER HILL BE CONTROLLED BY BAGHOUSE UP-
STREAM OF THE LIMESTONE SLURRY FGD SYSTEM. THE FGD SYSTEM WILL BE
DESIGNED TO REMOVE S02 HITH AN EFFICIENCY OF GREATER THAN 85*. REHEAT
HILL BE PROVIDED BT BY-PASSING 7X OF THE PARTICULATE CLEANED
GAS. SLUDGE HILL BE DEHATERED. BLENDED HITH FLYASH AND DISPOSED IN AN
ON SITE LANDFILL. INITIAL STARTUP IS SCHEDULED FOR FALL, 1982.
INDIANAPOLIS POHER t LIGHT
PETERSBURG
3
EH 532.0 MW (GROSS)
532.0 MH (ESC)
COAL
3.25 ZS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, U0f>
ENER6T CONSUMPTION: 2.4Z
STATUS 1 STARTUP 12/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE WET
LIMESTONE FGD SYSTEM INSTALLED ON THIS UNIT WAS SUPPLIED BY THE AIR
CORRECTION DIVISION OF UOP. UNIT 3 FIRES BITUMINOUS COAL HAVING A SULFUR
CONTENT OF 1.5-4.5Z, AN ASH CONTENT OF 9-101 AND A 11.000 BTU/LB
VALUE. TWO ESPS PROVIDE PRIMARY PARTICULATE CONTROL UPSTREAM OF A FOUR-
MODULE TCA FCD SYSTEM. STABILIZED SLUDGE IS DISPOSED ON AN ON-SITE POND.
THE DESIGN INCLUDES AN INDIRECT STEAM TUBE REHEAT SYSTEM. SHAKE DOWN
AND DEBUGGING OPERATIONS ARE STILL PROCEEDING.
13
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
INDIANAPOLIS POKER t LIGHT
PETERSBURG
t
NEW 530-0 1W (GROSS)
530.0 «W CESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: !
STATUS 2 STARTUP 10/P3
INDIANAPOLIS POWER * LIGHT AWARDED A CONTRACT TO RESEARCH COTTRELL
FOR A LIMESTONE F6D SYSTEM. S02 REMOVAL EFFICIENCY WILL BE
APPROXIMATELY 60 PERCENT. THIS NEW UNIT ylLL FIRE HIGH-SULFUR
BITUMINOUS COAL WITH A HEATING VALUE OF 11,000 BTU/LB AND ASH AND
SULFUR CONTENTS OF 10 PERCENT AND 3.5 PERCENT. RESPECTIVELY. SLUDGE MILL
BE DEWATERED AND MIXED WITH FLYASH TO PRODUCE A DRY STABILIZED PRODUCT.
EXCAVATION, FOUNDATION UORK AND SOME STEEL WORK IS NOW IN
PROGRESS ON THE UNIT.
KANSAS CITY POWER ( LIGHT
HAWTHORN
t
RETROFIT 90.0 MW C6ROSS)
90.0 *W (ESC)
COAL
.60 XS BITUMINOUS
HME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.2X
STATUS 1 STARTUP 11/72
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE SCRUBBER-ABSORBER SYSTEM ON THIS UNIT WAS CONVERTED FROM A LIMESTONE
FURNACE INJECTION AND TAIL-END SYSTEM TO A TAIL-END LINE SLURRY SYSTEM.
OPERATION IN THE LIME SCRUBBING MODE COMMENCED ON JANUARY 1, 1977. COM-
PLIANCE TEST INDICATED THE UNIT MEETS THE KANSAS CITY 0.17 LB/MM
BTU FARTICULATE REG. FGD SYSTEM DESIGN INCLUDES A FINN£D-TUBE STEAM
REHEATER, AN ON-SITE UNLINED SLUDGE DISPOSAL POND, AND A CHEVRON MIST
ELIMINATOR SYSTEM. THE 2 FGD MODULES CAN BE BY-PASSED IN EMERGENCIES.
KANSAS CITY POWER t LIGHT
HAWTHORN
4
RETROFIT 90.0 4W (GROSS)
90.0 MW (ESC)
COAL
.60 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENER6V CONSUMPTION: 2.2X
STATUS 1 STARTUP 8/72
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE SCRUBBER-ABSORBER SYSTEM ON THIS UNIT WAS CONVERTED FROM A LIMESTONE
FURNACE INJECTION AND TAIL-END SYSTEM TO A TAIL-END LINE SLURRY SYSTEM.
OPERATION IN THE LIME SCRUBBING NODE COMMENCED ON JANUARY 1, 1977. COM-
PLIANCE TEST INDICATED TH£ UNIT MEETS THE KANSAS CITY 0.17 LB/MM
BTU PARTICULATE REG. FGD SYSTEM DESIGN INCLUDES A FINNED-TUBE STEAM
REHEATER, AN ON-SITE UNLINED SLUDGE DISPOSAL POND, AND A CHEVRON
ELIMINATOR SYSTEM. THE ? F60 MODULES CAN BE BY-PASSED IN EMERGENCIES.
KANSAS CITY POWER t LIGHT
LA CY6NE
t
HEW
§74.0 MW (GROSS)
874.0 MW (ESC)
SUBBITUNINOUS
COAL
5.39 XS
LIMESTONE
9ABCOCK I WILCOX
ENERGY CONSUMPTION: 2.71
STATUS 1 STARTUP 2/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED POWER-GENERATING UNIT
CONSISTS OF EIGHT SCRUBBER MODULES FOR FLY ASH AND SO? REMOVAL. EACH
MODULE INCLUDES A VENTURI SCRUBBER IN SERIES WITH A 2-STA6E IMPINGEMENT
PLATE ABSORBER. THE SCRUBBER PLANT IS AN INTEGRAL PART OF THE POWER-
GENERATING COMPLEX, ALLOWING NO FLUE GAS BYPASS. INITIAL OPERATIONS
COMMENCED IN FEB. 1073. COMMERCIAL SERVICE WAS ATTAINED BY JUNE 1973.
KANSAS POWER t LIGHT
JEFFREY
1
HEW 720.0 MW (GROSS)
540.0 MW (ESC)
COAL
.32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: X
STATUS 1 STARTUP 8/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. CONBUSTION
ENGINEERING SUPPLIED THE LINESTONE EMISSION CONTROL SYSTEM FOR THIS NEW
COAL FIRED UNIT. THE UNIT CONSISTS OF A COLD-SIDE ESP AND SPRAY TOWERS
FOR THE CONTROL OF S02 AND PARTICULATE EMISSIONS. 30X OF THE FLUE GAS IS
BYPASSED FOR REHEAT. NOX EMISSIONS ARE CONTROLLED BY AN AIR OVERFIRE
SYSTEM AT THE TAN6ENTIALLV FIRED PULVERIZED BUNKERS. THE CLEANED CASES
ARE VENTED TO A 600 FT STACK. SLUDGE IS NIXED WITH BOTTON ASH AND
DISPOSED OF IN THE EXISTING ON-SITE BOTTON ASH POND.
KANSAS POWER I
JEFFREY
LIGHT
HEW 700.0 MW (GROSS)
490.0 MW (ESC)
COAL
.30 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: t
STATUS 2 STARTUP 6/80
CONBUSTION ENGINEERING IS SUPPLYING THE EMISSION CONTROL SYSTEM FOR THIS
NEW COAL FIRED UNIT. THE SYSTEN HILL CONSIST OF A COLD-SIDE ESP AND SPRAT
TOWERS FOR THE CONTROL OF PARTICULATE AND S02 EMISSIONS. 30X OF THE FLUE
GAS WILL BE BYPASSED FOR REHEAT. AN OVERFIRE AIR SYSTEM AT THE TANGENTIAL
FIRED PULVERIZED BURNERS WILL CONTROL NOX EMISSIONS. THE CLEANED GASES
HILL BE VENTED TO A 600 FT STACK. SLUDGE WILL BE MIXED HITH BOTTON ASH
AND DISPOSED ON-SITE IN THE BOTTON ASH POND. THE STSTEN STEEL WORK IS UP
AND CONSTRUCTION IS APPROXINATELV 60S CONPLETE.
14
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KANSAS POWER I
LAURENCE
4
RETROFIT
LIGHT
125.0 1* C6ROSS)
125.0 "»W (ESC>
COAL
.55 tS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *«*«X
STATUS 1 STARTUP 1/76
REFER TO SECTION J Of THIS REPORT FOR ADDITIONAL INFORMATION.
THE NEW LIMESTONE F6D SYSTEM COMMENCED OPERATIONS IN EARLY JANUARY 1977.
THE NEW SYSTEM REPLACED MARBLE-BED TOWERS WITH SPRAY TOWERS. THERE HAVE
BEEN NO FORCED SCRUBBER OUTAGES REPORTED SINCE START-UP. CONTINUOUS SOS
MONITORS HAVE RECORDED 502 REMOVAL EFFICIENCIES OF BETTER THAN P5X.
THE UTILITY REPORTED PARTICIPATE REMOVAL IS SUCH THAT NO VISIBLE PLUME
EXITS THE STACK. THE PLANT IS FIRING COAL RATED AT 10,000 6TU/LB WITH A
SULFUR CONTENT OF O.St
KANSAS POWER I LIGHT
LAWRENCE
5
RETROFIT 420.0 nw (GROSS)
420.0 MW (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: X
STATUS 1 STARTUP 11/71
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE
ORIGINAL LIMESTONE INJECTION AND TAIL-END SCRUBBING SYSTEM WAS SHUT
DOWN ON MARCH 20 SO THAT THE NEW ROD-SCRUBBER AND SPRAY TOWER ABSORBER
SYSTEM COULD BE TIED INTO THE UNIT. THE NEW SYSTEM, WHICH INCLUDES TWO
MODULES, EACH CAPABLE OF HANDLING APPROXIMATELY 50 PERCENT OF THE TOTAL
BOILER FLUE GAS FLOW, CAME ON LINE APRIL 1*, 1978. THE SYSTEM DESIGNER
AND SUPPLIER WAS COMBUSTION ENGINEERING. THE UNIT FIRES LOW SULFUR
WYOMING COAL WITH A HEAT CONTENT OF 10,000 BTU/LB.
KENTUCKY UTILITIES
GREEK RIVER
1-3
RETROFIT 64.0 *w (GROSS)
64.0 4W (ESC)
COAL
4.00 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 3.H
STATUS 1 STARTUP 9/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE SCRUBBER PLANT INSTALLED AT THIS STATION CONSISTS OF ONE MODULE
DESIGNED TO REMOVE PARTICULATE (VARIABLE-THROAT VENTURI) AND S02 (MOBILE
-BED CONTACTOR} FROM COAL-FIRED BOILER FLUE GAS. THE SCRUBBER WAS
DESIGNED AND SUPPLIED BY AAF. SLUDGE IS DISPOSED IN AN ON-SITE UNLINED
POND. THE COAL BURNED HAS SULFUR AND ASH CONTENTS OF 4.Q AND 11X
RESPECTIVELY AND A MOISTURE CONTENT OF 6-10 PERCENT. INITIAL STARTUP
OCCURRED IN SEPTEMBER 1975. COMMERCIAL OPERATION BEGAN IN JANUARY 1976.
LAKELAND UTILITIES
4CINTOSH
*
HEW 364.0 MW (GROSS)
364.0 MW
-------
EPA UTILITY F6D SURVEY: SECOND OUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE 6»S t ELECTRIC
CANE RUN
«,
RETROFIT 268.0 *w (GROSS)
288.0 *W (ESC)
COAL
4.60 ZS BITUMINOUS
DUAL ALKALI
IDL/CON8USTION EBUIP ASSOCIATE
ENERGY CONSUMPTION: 1 . Qt
STATUS 1 STARTUP 4/79
REFER TO SECTION 5 OF THIS REPORT FOR ADDITIONAL INFORMATION.
A.D. LITTLr/COMBUST ION E8U1PMENT ASSOCIATES HAS SUPPLIED THE INSTALLATION
OF A DOUBLE ALKALI SYSTEM. THE FEDERAL EPA KILL SUBSIDIZE A MAXIMUM
$4.5 PIP* FOR OPERATION. RESEARCH AND DEVELOPMENT, AND REPORT WRITING FOR
A ONE-YEAR PERIOD FOLLOWING THE FIRST THREE MONTHS OF OPERATIONS (NOTE:
THIS SUBSIDY WILL NOT BE APPLIED FOR ANY CAPITAL EXPENDITURES).
LOUISVILLE GAS I ELECTRIC
ILL CREEK
1
RETROFIT sse.o *w (GROSS)
358.0 4W (ESC)
COAL
3.75 ZS
LIME/LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 2 STARTUP 4/81
A COMPLIANCE SCHEDULE WAS SUBMITTED TO THE JEFFERSON COUNTY AIR POLLUTION
CONTROL DISTRICT WITH 4/81 ESTABLISHED AS THE STARTUP DATE FOR AN F6D
SYSTEM. OPERATING DATA AND INFORMATION FROM THE FULL-SCALE SCRUBBER PLANT
NOW IN SERVICE ON THE NO. 4 UNIT AT CANE RUN WILL BE OBTAINED BEFORE THE
UTILITY PROCEEDS «ITH ADDITIONAL SYSTEM DESIGN WORK. A CONTRACT WAS
AWARCED TO COMBUSTION ENGINEERING FOR A LIME/LIMESTONE F6D SYSTEM.
LOUISVILLE GAS t ELECTRIC
ILL CREEK
?
RETROFIT 350.0 «w (GROSS)
350.0 «W (ESC>
COAL
3.75 ZS
LIME/LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION; 1.41
STATUS 2 STARTUP 4/82
A COMPLIANCE SCHEDULE WAS SUBMITTED TO THE JEFFERSON COUNTY AIR POLLUTION
CONTROL DISTRICT WITH 4/82 ESTABLISHED AS THE STARTUP DATE FOR AN FGD
SYSTEM. OPERATING DATA AND INFORMATION FROM THE FULL-SCALE SCRUBBER PLANT
NOW IN SERVICE ON THE NO. 4 UNIT AT CANE RUN WILL BE OBTAINED BEFORE THE
UTILITY PROCEEDS WITH ADDITIONAL SYSTEM DESIGN WORK. A CONTRACT WAS
AWARDED TO COMBUSTION ENGINEERING FOR A LIME/LIMESTONE FGD SYSTEM.
LOUISVILLE GAS g ELECTRIC
ILL CREEK
3
HEW 442.0 4W (GROSS)
442.0 1W (ESC)
COAL
3.75 SS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.61
STATUS 1 STARTUP 8/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE SYSTEM
WAS DESIGNED AND SUPPLIED BY AAF AND UTILIZES CARBIDE LIME
AS THE ABSORBENT. FOUR MOBILE-BED ABSORBERS TREAT THE FLUE GAS RESULTING
FROM THE COMBUSTION OF HIGH-SULFUR COAL. THE SYSTEM OPERATES IN AN OPEN
WATER LOOP. THE SCRUBBING WASTE is STABILIZED WITH FLVASH AND LIME.
THE UNIT BECAME OPERATIONAL ON AUGUST 13. 1978.
LOUISVILLE GAS t ELECTRIC
RILL CREEK
t
HEW 495.0 *W (GROSS)
495.0 MM (ESC)
COAL
3.75 ZS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *»
STATUS 2 STARTUP 7/B1
BECAUSE POWER DEMAND HAS NOT CONE UP AS RAPIDLY AS HAD BEEN EXPECTED.
UNIT START-UP HAS BEEN MOVED BACK TO JULY 1981. CONSTRUCTION OF THIS
NEW 495-MW COAL-FIRED UNIT IS ON SCHEDULE. CURRENTLY, FOUNDATION WORK
IS IN PROGRESS. THIS AAF SYSTEM WILL INCLUDE MOBILE-BED ABSORBERS
TREATING HIGH SULFUR COAL FLUE GAS. THE SYSTEMS WATER LOOP WILL BE
CLOSED. THE SLUDGE WILL BE STABILIZED WITH LIME AND FLYASH. STEAM
REHEAT WILL PROVIDE GAS TEMPERATURE ELEVATION OF THE SCRUBBED GASES
PRIOR TO DISCHARGE TO THE MAIN STACK.
LOUISVILLE GAS t ELECTRIC
PADDY'S RUN
6
RETROFIT 72.0 MW (GROSS)
72.0 MM (ESC)
COAL
2.50 ZS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.»Z
STATUS 1 STARTUP 4/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS SCRUBBING SYSTEM WAS DESIGNED BY COMBUSTION ENGINEERING AND PLACED
IN SERVICE IN APRIL 1973. THE FGD SYSTEM CONSISTS OF TWO 2-STAGE MARBLE
BED ABSORBERS WHICH ARE DESIGNED TO USE CARBIDE LIME ADDITIVE AS THE
SCRUBBING REAGENT. PADDYS RUN NO. 6 is A PEAK-LOAD UNIT THAT OPERATES
ONLY DURING DEMAND PERIODS. AN EXTENSIVE EPA SCRUBBER/SLUDGE EVALUATION
STUDY WAS COMPLETED IN AUGUST 1977.
16
-------
EPA UTILITY FCt SURVEY: SECOND OUARTER
CECTION i
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE GAS i ELECTRIC
TRIM3LE COUNTY
1
NEW srs.o iy (GROSS)
575 .0 »W (ESC)
COAL
4.00 ZS BITUMINOUS
ofiOCESS MOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «*««X
STATUS 6 STARTUP 7/84
LG8E WILL 6E INSTALLING F6D SYST£»S ON T*0 OF THE UTILITY'S TR1-6LE
COUNTY UNITS. THE 575-MW UNITS WILL BURN COAL WITH AN AVERAGE <' SULFU;
CONTENT (IF NO COAL WASH IS INCLUDED). PAPTICULATE "ATTER WILL CE
CONTROLLED EY ESP'S AND S32 WILL BE CONTROLLED SY WET SCRU6F-1N& <9O
REMOVAL EFFICIENCY). SLUDGE DISPOSAL STRATEGY is AS YET, UNDECIDED.
START-UP IS SCHEDULED FOR JULY 1984 AND 1°fc6 RESPECTIVELY.
LOUISVILLE 6AS i. ELECTRIC
TRIMBLE COUNTY
?
NEW 575.0 «w (GROSS)
575.0 *W (ESC)
COAL
4.00 ZS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
tNERSY CONSUMPTION: **!
STATUS 6 STARTUP 0/86
L61E WILL BE INSTALLING F6D SYSTEMS ON TWO OF THE UTILITY'S TUMBLE
COUNTY UNITS. THE 575-MW UNITS WILL fcURN COAL MITH AN AVE°AfE <-T SULfU-
CONTENT (IF NO COAL wASH IS INCLUDED). PANICULATE BATTER WILL EE
CONTROLLED BY ESP'S AND S?2 WILL BE CONTROLLED ? Y WET SCRUBfl'JO (ejT
REMOVAL EFFICIENCY). SLUDGE DISPOSAL STRATEGY is AS YET, UNDECKED.
START-UP IS SCHEDULED FOR JULT 1 98 4 AND 1«S< RESPECTIVELY.
1IDDLE SOUTH UTILITIES
ARKANSAS COAL
5
HEW 890.0 XW (GROSS)
89C.O «u (ESC)
COAL
.53 ZS
PROCESS WOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «*«!
STATUS 5 STARTUP 1/56
A CONTRACT HAS BEEN AWARDED FOR BOILERS AND TURBINES ON SIX NE MIDDLE
SOUTH UTILITIES UNITS. THc UTILITY IS CURRENTLY RcOUESTING/EVALUATING
BIDS FOB THE F6D INSTALLATIONS ALTHOUGH THE TYPE OF FGD SYSTt* HAS NOT
YET cEEN DETERMINED.
IDDLE SOUTH UTILITIES
ARKANSAS COAL
>
NEW 890.0 *H (GROSS)
890.0 «U (ESC)
COAL
.50 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***«Z
STATUS 5 STARTUP 1/S8
A CONTRACT HAS BEEN AWARDED FOR BOILERS AND TURBINES ON SIX NEW MIDDLE
SOUTH UTILITIES UNITS. THE UTILITY IS CURRENTLY REOUtSTI NG/EVALUATI N6
EIDS FOR THE FGD INSTALLATIONS ALTHOUGH THE TYPE OF FGD SYSTEM HAS NCT
YET 6EEN DETERMINED.
IDDLE SOUTH UTILITIES
LOUISIANA COAL
1
NEW 890.0 IV (GROSS)
890.0
-------
EPA UTILITY fbo SURVEY: SECOND QUART*
SECTION 2
STATUS or FGD SYSTEMS
UNIT IDENTI FICAT10N
ABSTRACT
DIDDLE S3UTH UTILITIES
MISSISSIPPI COAL
1
NEW 690.0 «IW (GROSS)
890.0 «W (ESC)
COAL
.50 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
FNERSV CONSUHPTI9N: !
STATUS 5 STARTUP 0/f 5
A CONTRACT HAS BEEN AWARDED FOR BOILERS AND TURBINES ON SII NEW
SOUTH UTILITIES UNITS. THE UTILITY IS CURRENTLY RE8UESTING/EVALUATING
BIDS FOR THE F6D INSTALLATIONS ALTHOUGH THE TYPE OF F60 SYSTEM HAS NOT
YET 6EEN DETERMINED.
IDDLE SOUTH UTILITIES
ISSISSIPPI COAL
>
NEW B9C.O MM (GROSS)
893.0 «W (ESC)
COAL
.53 IS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
CNERSV CONSUMPTION: *:
STATUS 5 STARTUP 0/87
A CONTRACT HAS BEEN AWARDED FOR BOILERS AND TURBINES ON SIX NEW MIDDLE
SOUTH UTILITIES UNITS. THE UTILITY IS CURRENTLY REOUESTIN6/EVALUATIN6
BIDS FOR THE FGD INSTALLATIONS ALTHOUGH THE TYPE OF FGD SYSTEM HAS NOT
YET EEEN DETERMINED.
INNESOTA POWER I LIGHT
CLAY BOSnELL
I
NEW 500.0 «W (GROSS)
475.0 XW (ESC)
COAL
.54 ZS SUBBITUMINOUS
LIME/ALKALINE FLYASH
PEAbODV PROCESS SYSTEMS
ENERGY CONSUMPTION: *!
STATUS 2 STARTUP 5/60
MINNESOTA PIL HAS AWARDED A CONTRACT TO PEABODY PROCESS SYSTEMS FOR A
LIME/ALKALINE FLVASH SCRUBBING SYSTEM. THF CONFIGURATION WILL BE VENTURI
SCRUBBERS FOLLOWED BY SPRAY TOWERS. HOT SIDE ESP'S WILL BE USED FOR
PARTICULATE CONTROL. STACK GAS REHEAT HILL BE ACCOMPLISHED BY BYPASSING
5Z OF FLUE GAS AROUND THE SCRUBBER. THE UNIT WILL FIRE SUBBITUMINOUS
COLSTRIP COAL WjTH A SULFUR CONTENT OF 0."X. AND AN ASH CONTENT OF 9.0Z
(HEATING VALUE-8300 BTU/LB). MAKE-UP WATER SOURCE WILL BE THE RIVER AND
THE CLAY LINED POND. CONSTRUCTION OF THE FGD SYSTEM IS ABOUT 8CZ
COMPLETE .
MNNKOTA POWER COOPERATIVE
ILTON R. YOUNG
I
NEW 440.0 «W (GROSS)
405.0 «W (ESC)
COAL
.70 ZS LIGNITE
LIME/ALKALINE FLYASH
(DL/COMBUSTjON EBUIP ASSOCIATE
ENERGY CONSUMPTION: 1.61
STATUS 1 STARTUP 9/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS LIME/ALKALINE FLVASH SCRUBBING WAS DESIGNED AND SUPPLIED faV
ADL/COMBUSTION EQUIPMENT ASSOCIATES. IT CONSISTS OF A COLD-SIDE ESP
FOLLOWED BY TWO SPRAY TOWERS. THE DESIGN INCLUDES A WASH TRAY AND A
CHEVRON MIST ELIMINATOR. 15Z FLUE GAS BYPASS PROVIDES STACK GAS REHEAT.
THE UNIT FIRES A LOW-SULFUR NORTH DOKOTA LIGNITE WITH AN AVERAGE ASH
CONTENT OF 6 PERCENT. SULFUR CONTENT OF 0.7 PERCENT. AND HEAT CONTENT OF
6500 BTU/LB. THE FLVASH ALKALINITY IS USED AS THE PRIMARY 502 REAGENT.
ONTANA POWER
COLSTRIP
1
NEW 360.0 *W (GROSS)
360.0 1W (ESC)
COAL
.77 ZS SUBBITUMINOUS
LIME/ALKALINE FLYASH
«DL'COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: 3.3Z
STATUS 1 STARTUP 9/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS FGD EQUIPPED UNIT HAS DECLARED COMMERCIAL IN NOVEMBER 1975. THE
SCRUBBING SYSTEM PROVIDES PARTICULATE AND S02 CONTROL WITH THREE SCRUBBER
MODULES. EACH MODULE CONSISTS OF A DOWNFLOW VENTURI SCRUBBER CENTERED
WITHIN AN UPFLOW SPRAY TOWER ABSORBER. EACH MODULE CAN TREAT *oz OF
THE TOTAL BOILER FLUE GAS AND THE MODULES CANNOT BE BYPASSED. THE UN-
STABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED DISPOSAL POND. IN-LINE
STEAM REHEAT AND CLOSED WATER LOOP CAPABILITY ARE INCLUDED IN THE SYSTEM.
MONTANA POWER
COLSTRIP
>
NEW 360.0 »W (GROSS)
360.0 «W (ESC)
COAL
.77 ZS SUBBITUMINOUS
LIME/ALKALINE FLYASH
ADL/COMBUSTION E8UIP ASSOCIATE
ENERGY CONSUMPTION: 3.3Z
STATUS 1 STARTUP 5/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS FGD EQUIPPED UNIT HAS DECLARED COMMERCIAL IN AUGUST 1976. THE
SCRUEBIN6 SYSTEM PROVIDES PARTICULATE AND S02 CONTROL WITH THREE SCRUBBER
MODULES. EACH MODULE CONSISTS OF A DOWNFLOW VENTURI SCRUBBER CENTERED
WITHIN AN UPFLOW SPRAY TOWER ABSORBER. EACH MODULE CAN "TREAT 40z or
THE TOTAL BOILER FLUE GAS AND THE MODULES CANNOT BE BYPASSED. THE UN-
STABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED DISPOSAL POND. IN-LINE
STEAM REHEAT AND CLOSED HATER LOOP CAPABILITY ARE INCLUDED IN THE SYSTEM.
18
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MONTANA POWER
COLSTRIP
T
NEW 700.0 *W iEROSS)
700.0 *W
COAL
.70 ZS
LIME/ALKALINE FLYASH
DL/COHBUSTION E9UIP ASSOCIATE
FNERGY CONSUMPTION: >
STATUS 3 STARTUP 7/80
A CONTRACT FOR THE INSTALLATION OF TWO ADDITIONAL LIME/ALKALINE FLYASH
SCRUBBING SYSTEMS HAS BEEN AWARDED TO A.D. LITTLE/COMBUSTION EQUIPMENT
ASSOCIATES. THESE SYSTEMS HILL BE INSTALLED ON UNITS 3 AND 4 OF THE
COLSTRIP POWER STATION. COLSTRIP UNITS 1 AND 2 ARE BOTH EQUIPPED WITH
OPERATIONAL LIME/ALKALINE FLYASH SCRUBBING SYSTEMS FOR THE REMOVAL OF
PARTICIPATES AND SULFUR DIOXIDE.
MONTANA POWER
COLSTRIP
4
HEW 700.0 «W (GROSS)
700.0 NW (ESC)
COAL
.70 IS
LIME/ALKALINE FLYASH
DL/CONBUSTION EBUIP ASSOCIATE
ENERGY CONSUMPTION: x
STATUS 3 STARTUP 7/81
A CONTRACT FOR THE INSTALLATION OF TWO ADDITIONAL LIME/ALKALINE FLYASH
SCRUBBING SYSTEMS HAS BEEN AWARDED TO A.D. LITTLE/COMBUSTION EQUIPMENT
ASSOCIATES. THESE SYSTEMS WILL BE INSTALLED ON UNITS 3 AND 4 OF THE
COLSTRIP POWER STATION. COLSTRIP UNITS 1 AND 2 ARE BOTH EQUIPPED WITH
OPERATIONAL LlME/ALKALINE FLYASH SCRUBBING SYSTEMS FOR THE REMOVAL OF
PARTICIPATES AND SULFUR DIOXIDE.
4USCATINE POWER I WATER
USCAT1NE
9
HEW 160*0 *W CGROSS)
160.0 NW CESO
COAL
.30 ZS BITUMINOUS
PROCESS HOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: S.Ot
STATUS 6 STARTUP 0/82
MPIW ANNOUNCED PLANS TO INSTALL A LIME OR LIMESTONE SLURRY FGD
SYSTEM ON MUSCATINE 9. PARTICULATE HATTER WILL BE CONTROLLED BY AN
ESP FOLLOWED BY THE F6D SYSTEM FOR SO? REMOVAL. THE SYSTEM DESIGN
FEATURES TWO 100Z CAPACITY ABSORBER TOWERS, A STEAM COIL REHEAT
SYSTEM AND A FORCED OXIDATION SYSTEM TO PRODUCE SLUDGE PRODUCT
SUITABLE FOR LANDFILL AFTER DRYING.
NEVADA POWER
HARRY ALLEN
1
NEW 500.0 NW CGROSS)
SCO.O NW (ESC)
COAL
* ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: X
STATUS 6 STARTUP 6/85
CONSIDERING HOT SIDE ESP IN CONJUNCTION WITH AN FGD SYSTEM. SPECIFICA-
TIONS HAVE NOT VET BEEN PREPARED.
NEVADA POWER
HARRY ALLEN
2
NEW 500.0 NW (GROSS)
500.0 NW (ESC)
COAL
** ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGV CONSUMPTION: *«*X
STATUS 6 STARTUP 6/86
CONSIDERING HOT SIDE ESP IN CONJUNCTION WITH AN FGD SYSTEM. SPECIFICA-
TIONS HAVE NOT YET BEEN PREPARED.
NEVADA POWER
HARRY ALLEN
3
NEW 500.0 NW (GROSS)
500.0 NW (ESC)
COAL
ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGV CONSUMPTION: !
STATUS 6 STARTUP 6/87
CONSIDERING HOT SIDE ESP IN CONJUNCTION WITH AN FGD SYSTEM. SPECIFICA-
TIONS HAVE NOT YET BEEN PREPARED.
-------
EPA UTILITY F6D SURVEY! SECOND QUARTER 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEVADA POWER
HARRY ALLEN
t
NEW SOO.O NU (GROSS)
500.0 NU (ESC)
COAL
IS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 'X
STATUS 6 STARTUP 6/88
CONSIDERIN6 HOT SIDE ESP IN CONJUNCTION KITH AN F6D SYSTEM. SPECIFICA-
TIONS HAVE NOT YET BEEN PREPARED.
NEVADA POUER
REID GARDNER
1
RETROFIT 125.0 «w (GROSS)
125.0 NW (ESC)
COAL
.50 ZS BITUMINOUS
SODIUM CARBONATE
ADL'CONBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: X
STATUS 1 STARTUP 4/74
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS SODIUM
CARBONATE-BASED (TRONA) SCRUBBING SYSTEM CONSISTS OF ONE MODULE CONTAIN-
ING A TWIN VARIABLE THROAT VENTURI SCRUBBER FOLLOWED BY A SEPARATOR
IN SERIES WITH A SINGLE-STAGE PERFORATED-PLATE WASH TOWER. PRIMARY
PARTlCULATE CONTROL IS PROVIDED BY UPSTREAM MECHANICAL COLLECTORS.
AN INDIRECT STEAM HOT AIR REHEAT'SYSTEM RAISES THE GAS TEMPERATURE 30F
PRIOR TO DISCHARGE TO THE MAIN STACK, THE FLUE GAS CLEANING WASTES ARE
ULTIMATELY DISPOSED IN AN ON-SITE CLAY-LINED SOLAR EVAPORATION POND.
NEVADA POWER
REID GARDNER
2
RETROFIT 125.o «w (GROSS)
125.0 4W (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
ADL/CONBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: X
STATUS 1 STARTUP 4/74
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS SODIUM
CARBONATE-BASED (TRONA) SCRUBBING SYSTEM CONSISTS OF ONE MODULE CONTAIN-
ING A TWIN VARIABLE THROAT VENTURI SCRUBBER FOLLOWED BY A SEPARATOR
IN SERIES WITH A SINGLE-STAGE PERFORATED-PLATE WASH TOWER. PRIMARY
PARTlCULATE CONTROL IS PROVIDED BY UPSTREAM MECHANICAL COLLECTORS.
AN INDIRECT STEAM HOT AIR REHEAT SYSTEM RAISES THE GAS TEMPERATURE 30F
PRIOR TO DISCHARGE TO THE MAIN STACK. THE FLUE GAS CLEANING WASTES ARE
ULTIMATELY DISPOSED IN AN ON-SITE CLAY-LINED SOLAR EVAPORATION POND.
NEVADA POWER
REID GARDNER
3
NEW 125.0 'W (GROSS)
125.0 NW (ESC)
COAL
.50 X$ BITUMINOUS
SODIUN CARBONATE
ADL/CONBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: *!
STATUS 1 STARTUP 6/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS UNIT IS A NEW COAL-FIRED BOILER THAT IS EQUIPPED WITH SODIUM
CARBONATE-BASED (TRONA) SCRUBBING SYSTEM WHICH INCORPORATES A TWIN
VARIABLE-THROAT VENTURI SCRUBBER FOLLOWED BY A SEPARATOR IN SERIES WITH
A SINGLE-STAGE PERFORATED-PLATE WASH TOWER. MECHANICAL COLLECTORS PROVIDE
PRIMARY PARTlCULATE CONTOL. REHEAT IS PROVIDED BY A INDIRECT STEAM HOT
AIR REHEAT SYSTEM. WASTE IS DISPOSED IN AN ON-SITE CLAY-LINED POND.
NEVADA POWER
REID GARDNER
4
NEC 250.0 NW (GROSS)
250.0 NW (ESC)
COAL
.75 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: X
STATUS 6 STARTUP 0/83
NEVADA POWER COMPANY HAS SCRAPPED THEIR ORIGINAL PLANS TO MAKE UNIT 4 A
COPY OF UNIT 3. THE NEW PLANS CALL FOR A 250-MW UNIT TO BE IN OPERATION
BY 1983. THE UTILITY IS PREPARING SPECIFICATIONS AT THIS TIME.
CONSTRUCTION IS SCHEDULED TO START IN 1980.
NEVADA POWER
WARNER VALLEY
1
NEW 250.0 NW (GROSS)
250.0 NW (ESC)
COAL
* ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: x
STATUS 6 STARTUP 6/84
SPECIFICATIONS ARE BEING PREPARED FOR A SCRUBBING SYSTEM. NEVADA POWER
HAS NOT VET ANNOUNCED PLANS FOR THIS UNIT'S EMISSION CONTROL STRATEGY.
20
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEVADA POWER
WARNER VALLEY
2
MEW 250.0 MW (6ROSS)
250.0 MW (ESC)
COAL
*«* XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENER6V CONSUMPTION: *!
STATUS 6 STARTUP 6/85
SPECIFICATIONS ARE BEING PREPARED FOR A SCRUBB1N6 SYSTEM. N£V«D# POWER
HAS NOT YET ANNOUNCED PLANS FOR THIS UNIT'S EMISSION CONTROL STRATEGY.
HEM ENGLAND ELECTRIC SYSTEM
9RAVTON POINT
5
RETROFIT 650.0 NW (CROSS)
650.0 MW (ESC)
OIL
1.00 IS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *!
STATUS 7 STARTUP O/ 0
NEW ENGLAND ELECTRIC SYSTEM HAS REQUESTED PERMISSION TO BURN 1.5X SULFUR
COAL AT THIS UNIT. THIS IS ALLOWABLE UNDER STATE STANDARDS BIT S02
EMISSIONS WOULD BE ABOVE ALLOWABLE FEDERAL LEVELS. A DECISIOI BY THE EPA
IS STILL PENDING. MEANWHILE, THE UTILITY IS INVESTIGATING VARIOUS ADVANCE
REGENERABLE FGD SYSTEMS WHICH OFFER A BREAKTHROUGH IN OPERATING COSTS
AND PRODUCE ELEMENTAL SULFUR AS AN END PRODUCT. THE UTILITY IS CURRENTLY
INVOLVED IN BENCH AND LABORATORY SCALE INVESTIGATIONS OF SUlfUR RECOVERY.
THIS UNIT IS CURRENTLY OPERATIONAL FIRING LOU SULFUR FUEL OIL.
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLET
66
RETROFIT 100.o MW (GROSS)
100.0 MM (ESC)
COAL
1.80 XS
AQUEOUS CARBONATE
ROCKWELL INTERNATIONAL
ENERGY CONSUMPTION: *!
STATUS 3 STARTUP 0/82
A CONTRACT WAS AWARDED TO ATOMICS INTERNATIONAL FOR THE DEJI6N AND
INSTALLATION OF AN AQUEOUS CARBONATE FGD SYSTEM. THIS DEMOISTR»TION
SYSTEM WILL PRODUCE END-PRODUCT SULFUR. FUNDS ARE BEING PROVIDED BY THE
U.S. EPA AND THE EMPIRE STATE ELECTRIC ENERGY RESEARCH CORP. THE DESIGN
so2 REMOVAL EFFICIENCY WILL BE 90 PERCENT. ROCKWELL INTERNATIONAL is
PRESENTLY IN THE DESIGN PHASE.
NORTHERN INDIANA PUB SERVICE
BAILLY
r
RETROFIT 190.0 MW (GROSS)
190.0 MW (ESC)
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: X
STATUS 6 STARTUP O/ 0
NORTHERN INDIANA PUBLIC SERVICE IS CURRENTLY CONSIDERING A LIME OR LIME-
STONE SCRUBBING UNIT FOR BAILLV 7 AND 8. THEY ARE ALSO WAITING FOR
PERFORMANCE RESULTS OF THE UELLMAN LORD/ALLIED CHEMICAL UNIT IN SERVICE
AT DEAN H. MITCHELL 11. LOW SULFUR COAL MAY BE EMPLOYED TO COMPLY WITH
502 EMISSION RE6UALTIONS. APPLICABLE INDIANA S02 REGULATIONS ARE STILL
NOT FIRMLY ESTABLISHED.
NORTHERN INDIANA PUB SERVICE
9AILLY
8
RETROFIT *oo.o MW (GROSS)
«oo.o NW (ESC>
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: !
STATUS 6 STARTUP O/ 0
NORTHERN INDIANA PUBLIC SERVICE IS CURRENTLY CONSIDERING A LIME OR LIME-
STONE SCRUBBING UNIT FOR BAILLY 7 AND 8. THEY ARE ALSO WAITING FOR
PERFORMANCE RESULTS OF THE WELLNAN LORD/ALLIED CHEMICAL UNIT IN SERVICE
AT DEAN H. MITCHELL 11. LOW SULFUR COAL MAY BE EMPLOYED TO COMPLY WITH
S02 EMISSION REGULATIONS. APPLICABLE INDIANA S02 REGULATIONS ARE STILL
NOT FIRMLY ESTABLISHED.
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
RETROFIT 115.0 MW (GROSS)
115.0 MW (ESC)
COAL
3.50 XS
WELLMAN LORD
DAVY POWERGAS
ENERGY CONSUMPTION: X
STATUS 1 STARTUP 7/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION
THIS FGD SYSTEM IS AN INTEGRATION OF THE WELLMAN-LORD S02 RECOVERY
PROCESS OFFERED BY DAVY POWERGAS AND THE S02 TO SULFUR REDUCTION PROCESS
DEVELOPED BY ALLIED CHEMICAL. DAVY POWERGAS WAS THE DESIGN AND
CONSTRUCTION FIRM AND ALLIED CHEMICAL IS SYSTEM OPERATOR AND PRODUCT
-MARKETER. PERFORMANCE TESTS WERE SUCCESSFULLY COMPLETED ON SEPTEMBER 14,
1977. A DEMONSTRATION YEAR COMMENCED ON SEPTEMBER 16. 1977.
21
-------
EP» UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNI' IDENTIFICATION
ABSTRACT
NORTIERN INDIANA PUG SERVICE
5CHAIFER
17
NEW 421.0 Ny (GROSS)
421.0 N* (ESC)
COAL
3.20 ZS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **!
STATUS S STARTUP 6/83
NIPSCO IS REQUESTING/EVALUATING BIDS FOR F6D SYSTEMS ON SCHAHFER 17
AND 1B. ALTHOUGH THE S02 CONTROL STRATEGY HAS NOT BEEN SELECTED THE
UTILITY IS CONSIDERIN6 A SODIUM BASED SYSTEM. PARTICIPATE MATTER
KILL BE CONTROLLED BY AN ESP. THE SYSTEM DESIGN WILL INCLUDE A
REHEAT SYSTEM.
NORTHER* INDIANA PUB SERVICE
SCHAHFEi
18
NEW 421.0 NW (GROSS)
421.0 NH (ESC)
COAL
3.20 IS BITUMINOUS
PROCESS IOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: X
STATUS 5 STARTUP 6/85
NIPSCO IS REQUESTING/EVALUATING BIDS FOR F6D SYSTEMS ON SCHAHFER 17
AND 11. ALTHOUGH THE S02 CONTROL STRATEGY HAS NOT BEEN SELECTED THE
UTILITY IS CONSIDERING A SODIUM BASED SYSTEM. PARTICULATE MATTER
HILL BE CONTROLLED BY AN ESP. THE SYSTEM DESIGN HILL INCLUDE A
REHEAT SYSTEM.
NORTHERN STATES POWER
SHERBURNE
1
NEW 740.0 «W (GROSS)
740.0 NW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE/ALKALINE FLTASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.7X
STATUS 1 STARTUP 3/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
FULL COMMERCIAL OPERATION OF THE SYSTEM BEGAN ON MAY 1, 1976. THE SCRUB-
BING SYSTEM FOR THIS UNIT CONSISTS OF 12 MODULES. EACH SCRUBBING MODULE
INCORPORATES A VENTRI-ROD SECTION AND A MARBLE BED ABSORBER FOR PAR-
TICULATE AND SULFUR DIOXIDE REMOVAL. A FORCED OXIDATION SYSTEM CONVERTS
ALL THE CALCIUM SULFITE TO SULFATE PRIOR TO DISCHARGE TO A CLAY-LINED
SETTLING POND. STACK GAS REHEAT IS PROVIDED BY IN-LINE HOT WATER TUBES.
THE COAL BURNED AT THIS UNIT CONTAINS 0.8T SULFUR AND 9-10X ASH.
NORTHERN STATES POWER
SHERBURNE
2
NEW 740.0 NW (GROSS)
740.0 1W (ESC)
COAL
.80 *S SUBBITUMINOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.7X
STATUS 1 STARTUP 4/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE SHERBURNE NO. 2 AIR QUALITY CONTROL SYSTEM IS IDENTICAL IN DESIGN TO
THE SYSTEM IN OPERATION ON THE NO. 1 UNIT AT THIS STATION. TWELVE 2-STAGE
PARTICULATE SCRUBBER (VENTRI-ROD SCRUBBER) AND SULFUR DIOXIDE ABSORBER
(MARBLE-BED ABSORBER) NODULES ARE PROVIDED FOR FLYASH AND S02 CONTROL.
ELEVEN MODULES ARE REQUIRED FOR FULL GENERATING CAPACITY OPERATIONS.
THE CALCIUM SULFITE IS FORCIBLY OXIDIZED TO SULFATE PRIOR TO DISCHARGE TO
THE DISPOSAL POND. IN-LINE HOT WATER TUBES PROVIDE STACK GAS REHEAT.
NORTHERN STATES POWER
SHERBURNE
3
NEW 860.0 «W (GROSS)
860.0 MW (ESC)
COAL
.80 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: X
STATUS 4 STARTUP 5/84
TWO ADDITIONAL COAL-FIRED POWER-GENERATING UNITS ARE SCHEDULED TO BE IN-
STALLED AT NSP'S SHERBURNE COUNTY GENERATING STATION IN BECKER MINNESOTA.
A LETTER OF INTENT HAS BEEN SIGNED WITH C-E FOR A LIMESTONE SLURRY SPRAT
TOWER SYSTEM FOR THIS NEW 860-MW UNIT. THE 2-STAGE SCRUBBING SYSTEN HILL
REMOVE PARTICULATES I99.sx> t so2 (Box). THE BOILER CONTRACT HAS BEEN
AWARDED TO BABCOCK ( WILCOX AND THE TURBINE WILL BE SUPPLIED BY GENERAL
ELECTRIC. START-UP HAS BEEN DELAYED TO MAY 1984 AND CONSTRUCTION START-UP
HAS BEEN DELAYED UNTIL APRIL 1980 DUE TO ENVIRONMENTAL PROBLEMS.
OTTER TAIL POWER
COYOTE
1
NEW 440.0 NW (GROSS)
440.0 MW (ESC)
COAL
.87 ZS LIGNITE
AQUEOUS CARBONATE/SPRAY DRYING
WHEELABRATOR-FRYE/R.I.
ENERGY CONSUMPTION: 1.1X
STATUS 2 STARTUP 5/81
THIS NEW COAL-FIRED STATION IS JOINTLY OWNED BY FIVE UTILITIES. OTTER
TAIL POWER IS THE MAJOR OWNER AND CONSTRUCTOR. MONTANA-DAKOTA UTILITES
IS THE FACILITY OPERATOR. THIS PLANNED UNIT HILL FIRE LOW SULFUR LIGNITE
FROM THE MERCER COUNTY AREA IN A BtW CYCLONE BOILER. THE CONTRACT FOR
THIS AQUEOUS CARBONATE/FABRIC FILTER $02 SCRUBBER-ABSORBER HAS AHARDEU TO
WHEELABRATOR-FRYC AND ATOMICS INTERNATIONAL. TNE DRY REMOVAL SYSTEM
COMBINES Al'S AQUEOUS CARBONATE PROCESS IN A W-F FABRIC FILTER.
CONSTRUCTION IS BOX COMPLETE FOR THE DRYER AND 2SX COMPLETE FOR THE
BAGHOUSE*
-------
EPA UTItlTf F6D SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PACIFIC SAS
FOSSIL
1
I ELECTRIC
NEW
BOO.O MW (GROSS)
BOO.O «U (ESC>
COAL
.80 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »
STATUS 6 STARTUP 6/86
P6»E ANNOUNCED PLANS TO BUILD TWO 800-HW COAL-FIRED POWER GENERATING
UNITS IN NORTHERN CALIFORNIA. THE FIRST UNIT WILL BURN COAL WITH A
HEATING VALUE OF 12000 BTU/LB, 0.8Z SULFUR AND 10X ASH CONTENTS. THE
SECOND UNIT WILL BURN COAL OF AN EQUAL OR BETTER QUALITY. THE EMISSION
CONTROL SYSTEM WILL CONSIST OF A BA6HOUSE AND A LIMESTONE F60 SYSTEM.
SLUDGE WILL BE DISPOSED OF IN A LANDFILL. START-UP DATES ARE 1986 AND
1987 FOR NOS. 1 AND 2 RESPECTIVELY. CONSTURCTION IS NOT ENVISIONED TO
BEGIN BEFORE TWO OR THREE YEARS.
PACIFIC EAS c ELECTRIC
FOSSIL
2
NEW 800.0 MW <6ROSS>
BOO.O MW (ESO
COAL
.80 ZS
LIMESTONE
VENDOR NOT SELECTED
ENERSf CONSUMPTION: X
STATUS 6 STARTUP 6/87
PGIE ANNOUNCED PLANS TO BUILD TWO 800-MW COAL-FIRED POWER GENERATING
UNITS IN NORTHERN CALIFORNIA. THE FIRST UNIT WILL BURN COAL WITH A
HEATING VALUE OF 12000 BTU/LB. 0.8* SULFUR AND 10S ASH CONTENTS. THE
SECOND UNIT WILL BURN COAL Of AN EQUAL OR BETTER QUALITY. THE EMISSION
CONTROL SYSTEM HILL CONSIST OF A BAGHOUSE AND A LIMESTONE F6D SYSTEM.
SLUDGE WILL BE DISPOSED OF IN A LANDFILL. START-UP DATES ARE 1986 AND
1987 FOR NOS. 1 AND 2 RESPECTIVELY. CONSTURCTION IS NOT ENVISIONED TO
BEGIN BEFORE TWO OR THREE YEARS.
PACIFIC POWER I LIGHT
JIM 9RID6ER
t
NEW 550.0 *w (GROSS)
550.0 MW (ESC>
COAL
.56 XS SUBBITUNINOUS
SODIUM CARBONATE
MR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: *!
STATUS 2 STARTUP 9/79
THE AIR CORRECTION DIVISION OF UOP WAS AWARDED A CONTRACT FOR AN F6D
SYSTEM AT THIS NEW-509 MW COAL-FIRED UNIT. THE FGD SYSTEM WILL CONSIST OF
PARALLEL TRAY TOWER ABSORBER MODULES, EACH TREATING ONE-THIRD OF THE
BOILER FLUE GAS AT FULL LOAD. AN ESP WILL PROVIDE PRIMARY PARTICULATE
CONTROL. AN ACID BRICK LINED WET STACK IS INCLUDED IN THE SYSTEM. PPL'S
PILOT STUDY INSPECTION REVEALED SCALE FORMATION PROBLEMS. TESTS ARE BEING
CONDUCTED TO RESOLVE THIS PROBLEM. THE UTILITY EXPECTS TO CONDUCT A
SYSTEM CHECKOUT IN 7/79 WITH COMMERCIAL STARTUP AT THE END OF 1979.
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
NEW 917.0 NW (GROSS)
917.0 MW (ESC)
COAL
3.00 ZS BITUMINOUS
LINE
CHEMICO
ENERGY CONSUMPTION: 6.OX
STATUS 1 STARTUP 12/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS EMISSION CONTROL SYSTEM WAS DESIGNED TO REMOVE FLYASH AND S02 FROM
3.35 MM ACFM OF FLUEGAS USING THIOSORBIC LIME AS A SCRUBBING ABSORBENT.
THE INITIAL SHAKEDOWN AND DEBUGGING PHASE OF OPERATION BEGAN FOR PART OF
THE SYSTEM IN DECEMBER 1975. PARTIAL COMMERCIAL OPERATION COMMENCED IN
APRIL 1976. THE UNIT WAS CERTIFIED FULL-LOAD COMMERCIAL IN JUNE 1976.
THE F6D SYSTEM HAS EXPERIENCED OPERATIONAL PROBLEMS SINCE IT HAS BEEN IN
SERVICE REQUIRING A NUMBER OF SYSTEM REPAIRS AND DESIGN MODIFICATIONS.
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
NEW 917.0 MW (GROSS)
917.0 MW (ESC)
COAL
3.00 ZS BITUMINOUS
LINE
CHEMICO
ENERGY CONSUMPTION: 6.0Z
STATUS 1 STARTUP 7/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS EMISSION CONTROL SYSTEM WAS DESIGNED TO REMOVE FLYASH AND S02 FROM
3.35 MM ACFN OF FLUE GAS USING THIOSORBIC LIME AS A SCRUBBING ABSORBENT.
SIX SCRUBBING TRAINS, EACH INCLUDING TWO VENTURI SCRUBBERS IN SERIES
ARRANGEMENT, ARE PROVIDED FOR FULL-LOAD OPERATION. THE INITIAL SHAKEDOWN
AND DEBUGGING PHASE OF OPERATION BEGAN FOR THREE TRAINS IN JULY. 1977.
FULL COMMERCIAL OPERATION FOR THE ENTIRE SYSTEM COMMENCED ON OCTOBER 1,
1977.
PENNSYLVANIA POWER
BRUCE MANSFIELD
3
NEW 917.0 «W (GROSS)
917.0 MW (ESC)
COAL
3.00 ZS
LIME
PULLMAN KELLOGG
ENERGY CONSUMPTION: x
STATUS 2 STARTUP 4/80
A CONTRACT WAS AWARDED TO PULLMAN KELLOGG FOR THE FGD SYSTEM AT THIS
UNIT. THE EMISSION CONTROL SYSTEM FOR THIS UNIT WILL CONSIST OF ESP'S
UP-STREAM OF FIVE WEIR HORIZONTAL CROSSFLOW WET SCRUBBING MODULES.
EACH MODULE CONSISTS OF SII STAGES, ONE BEING A SPARE. SLUDGE WILL BE
DISPOSED OF BY THE EXISTING SYSTEM AT THE BRUCE MANSFIELD PLANT. LINER
IN THE STACK WILL BE AN INCONEL 625 MATERIAL. THE UNIT IS CURRENTLY
UNDER CONSTRUCTION WITH ESP'S 70-80 PERCENT COMPLETE AN* THE FGD
SYSTEM 30 PERCENT COMPLETE. UNIT START-UP HILL BE IN APRIL 1980.
23
-------
EP* UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PHILADELPHIA ELECTRIC
CROH9V
RETROFIT iso.o MW (GROSS)
150.0 MW (ESC)
COAL
3.00 ZS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERCV CONSUMPTION: X
STATUS 6 STARTUP 6/80
THE UTILITT PLANS TO RETROFIT ONE Of THE THO BOILERS AT CROMBY WITH AN
F6D SYSTEM. HOWEVER, A FINAL DECISION HAS NOT BEEN HADE- THE SYSTEX
BEIN6 GIVEN PRIMARY CONSIDERATION IS MAGNESIUM OXIDE. CURRENTLY. THE
UTILITY IS RE-NEGOTIATING CONSENT ORDERS AND THE START-UP DATE OF JUNE
1980 IS TENTATIVE.
PHILADELPHIA ELECTRIC
EDDYS TONE
1A
RETROFIT 120.0 MM (GROSS)
120.0 MW (ESC)
COAL
2.60 XS BITUMINOUS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: »
STATUS 1 STARTUP 9/75
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMNISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF THREE PARALLEL
SCRUBBING TRAINS FOR THE CONTROL OF PARTICULATE AND SULFUR DIOXIDE.
THE C-SIDE SCRUBBING TRAIN INCLUDES AN S02 ABSORBER MODULE IN SERIES
WITH A PARTICULATE SCRUBBER. APPROXIMATELY ONE-THIRD OF THE BOILER FLUE
GAS IS SCRUBBED WITH MAGNESIUM OXIDE SLURRY FOR S02 REMOVAL. THE SPENT
SLURRY IS REGENERATED AT THE ESSEX SULFURIC ACID PLANT IN NEWARK, N.J.
THE REGENERATED MAGOX IS RETURNED TO THE PLANT FOR S02 SCRUBBING SERVICE,
PHILADELPHIA ELECTRIC
EDDYS TONE
IB
RETROFIT 2*0.0 MM (GROSS)
240.0 MM (ESC)
COAL
2.60 ZS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: *«««t
STATUS 4 STARTUP 6/80
THE INSTALLATION OF AN FGD SYSTEM ON THE BALANCE OF THE FLUE GAS FROM
THIS UNIT WILL FOLLOW PENDING THE OUTCOME OF THE PERFORMANCE OF THE
EXPERIMENTAL SCRUBBING UNIT WHICH HAS BEEN INSTALLED AND CURRENTLY
OPERATIONAL ON THIS UNIT. CURRENTLY, 3 PARTICULATE SCRUBBERS ARE TREATING
THE FULL GAS LOAD FROM THIS UNIT. CONSENT ORDERS ARE PRESENTLY BEING
RE-NEGOTIATED AND THE START-UP DATE OF JUNE* 1980 IS TENTATIVE.
PHILADELPHIA ELECTRIC
EDDYS TONE
2
RETROFIT 334.0 MW (GROSS)
334.0 MW (ESC)
COAL
2.50 ZS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: !
STATUS 6 STARTUP 6/80
THE UTILITY IS AWAITING PERFORMANCE RESULTS FROM THE EXPERIMENTAL FGD
SYSTEM INSTALLED ON UNIT 1 AT THIS STATION BEFORE PRECEEDIN6 WITH THE
DESIGN OF AN FGD SYSTEM FOR THIS COAL-FIRED BOILER. THE SYSTEM BEING
GIVEN PRIMARY CONSIDERATION IS MAGNESIUM OXIDE, DESIGNED JOINTLY BY
UNITED ENGINEERS AND PHILADELPHIA ELECTRIC. CURRENTLY, THE UTILITY IS
RE-NEGOTIATING CONSENT ORDERS AND THE START UP DATE OF JUNE 1980 IS
TENTATIVE.
POTOMAC ELECTRIC POWER
DICKERSON
4
NEW 800.0 MW (GROSS)
800.0 MW (ESC)
COAL
2.00 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *
STATUS 6 STARTUP 0/87
THERE ARE NO FIRM PLANS FOR INSTALLATION OF AN FGD SYSTEM. STARTUP DATE
OF THE BOILER IS PLANNED FOR 1985. THIS UNIT WILL BURN 2Z SULFUR COAL
WITH A HEATING VALUE OF 11000 BTU/LB.
POWER AUTHORITY OF NEW YORK
ARTHUR KILL
NEW 700.0 MW (GROSS)
700.0 MW (ESC)
COAL
3.00 ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: X
STATUS 6 STARTUP 11/88
FGD TECHNOLOGY IS BEING CONSIDERED FOR THIS FOSSIL FUEL BURNING UNIT WHICH
WILL EMPLOY COAL AS THE PRIMARY FUEL AND OIL AS BACKUP. REFUSE WILL BE
PROVIDED AS A SUPPLEMENTAL FUEL SUPPLY. THE PREFERRED PLANT SITE IS THE
ARTHUR KILL FACILITY LOCATED ON STATEN ISLAND. THE PROJECT DESIGN
ENGINEERING FIRM IS SARGENT AND LUNDY. PUBLIC SERVICE COMMISSION HEARINGS
ARE IN PROGRESS.
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PUBLIC SERVICE OF INDIANA
SIBSON
3
HEW 650.0 NW <6ROSS>
650.0 NW (ESC>
COAL
3.30 ZS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: Z
STATUS 3 STARTUP 0/82
PUBLIC SERVICE CO. OF INDIANA HAS ANNOUNCED THAT A CONTRACT HAS BEEN A-
WARDED TO THE PULLMAN KELLOGG DIVISION OF PULLMAN INC. FOR THE INSTAL-
LATION OF FOUR KELLOGG-WEIR ABSORBER-REACTOR MODULES. THE ABSORBING
MEDIUM WILL CONSIST OF KELLOGG'S PROPRIETARY MAGNESIUM-PROMOTED LIME-
PUBLIC SERVICE OF NEU MEXICO
SAN JUAN
1
RETROFIT 361.0 *U (GROSS)
361.0 MW
COAL
BO is
WELL*AN LORD
DAVY POWERGAS
ENERGY CONSUMPTION: 4.4Z
STATUS 1 STARTUP 4/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS FGD
SYSTEM IS AN INTEGRATION OF THE WELLMAN LORD SO? RECOVERY PROCESS OF
DAVY POWERGAS AND ALLIED CHEMICAL'S S02 REDUCTION TO SULFUR PROCESS. A
HOT SIDE ELECTROSTATIC PRECIPITATOR PRECEEDS THE FGD SYSTEM. OF THE FOUR
ABSORBER TOUERS INSTALLED* THREE ARE NEEDED TO CART THE FULL LOAD. THE
COAL BURNED AT THIS UNIT HAS SULFUR AND ASH CONTENTS OF .81 AND 20X
RESPECTIVELY. THE SYSTEM OPERATES ON A CLOSED WATER LOOP WITH
RIVER WATER BEING USED AS MAKE-UP FOR LOSSES DUE TO EVAPORATION.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
RETROFIT 350.0 MW (GROSS)
350.0 MW (ESC)
COAL
.80 ZS
VELLNAN LO"D
DAVY POWERGAS
ENERGY CONSUMPTION: 4.62
STATUS 1 STARTUP 8/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS FGD
SYSTEM IS AN INTEGRATION OF THE WELLMAN LORD S02 RECOVERY PROCESS OF DAVY
POWERCAS/ALLIED CHEMICAL'S so2 REDUCTION TO SULFUR PROCESS. A HOT SIDE
ELECTROSTATIC PRECIPITATOR PRECEEDS THE FGD SYSTEM. THE SYSTEM INCLUDES
FOUR ABSORBER TOWERS, THREE OF WHICH ARE NECESSARY TO CARRY THE FULL
LOAD. THE WATER LOOP IS CLOSED WITH RIVER WATER BEING USED TO MAKE UP FOR
LOSSES DUE TO EVAPORATION. THE COAL BURNED AT THIS UNIT HAS SULFUR AND
ASH CONTENTS OF 0.81 AND 20X RESPECTIVELY.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
3
EN 534.0 MU (GROSS)
534.0 MW (ESC)
COAL
.80 ZS
WELLMAN LOUD
DAVY POWERGAS
ENERGY CONSUMPTION: «!
STATUS 2 STARTUP 9/79
A CONTRACT HAS BEEN AWARDED TO DAVY POWERGAS TO SUPPLY FOUR ABSORBER
TOUERS FOR REMOVAL OF S02 AT THIS NEW UNIT. ONE MODULE IS EXPECTED TO
BE OPERATIONAL BY SEPTEMBER 1979 WHICH WILL BRING THE UNIT INTO COMPLIANCE
WITH FEDERAL NSPS. THE REMAINING THREE MODULES SHOULD BE OPERATIONAL
BY JANUARY 1982 AT WHICH TIME THE UNIT WILL BE IN COMPLIANCE OF STATE
STANDARDS. POWER PLANT CONSTRUCTION IS BEHIND SCHEDULE BUT ABSORBER
CONSTRUCTION IS PROCEEDING AS PLANNED. IT IS POSSIBLE THAT THE FINAL
THREE ABSORBERS MAY BE IN AS EARLY AS JANUARY 1981.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
4
«EU 534.0 NW (GROSS)
534.0 MW (ESC)
COAL
.80 ZS
WELLMAN LORD
DAVT POWERGAS
ENERGY CONSUMPTION: Z
STATUS 2 STARTUP 1/82
DAVY POWERGAS HAS BEEN AWARDED A CONTRACT TO SUPPLY THE $02 REMOVAL
SYSTEM FOR THIS UNIT. THE PLANS INCLUDE A WELLMAN LORD $02 RECOVERY
PROCESS AS WELL AS AN UPSTREAM ELECTROSTATIC PRECIPITATOR FOR PRIMARY
PARTICULATE REMOVAL. FGD OPERATIONS ARE EXPECTED TO BEGIN AT THIS PLANT
IN JANUARY 1982.
SALT RIVER PROJECT
CORONADO
1
NEW 350.0 MW (GROSS)
280.0 MW (ESC)
COAL
1.00 ZS SUBBITUHINOUS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION! Z
STATUS 2 STARTUP 8/79
THIS NEW UNIT WILL BURN LOW SULFUR WESTERN COAL* A MAXIMUM OF 80Z OF THE
FLUE GAS WILL BE SCRUBBED TO MEET SULFUR DIOXIDE EMISSION REGULATIONS.
PULLMAN/KELLOGG MILL PROVIDE 2 WEIR HORIZONTAL SPRAY TOWERS UTILIZING
LIMESTONE SLURRY FOR $02 CONTROL. THE SYSTEM WILL UTILIZE RUBBER-LINED
SLURRY RECYCLE PUMPS, EACH RATED AT 98oo GPM. RIGIFLAKE-LINED SCRUBBER
MODULES. VERTICAL HEIL MIST ELIMINATORS AND A MINIMUM OF 20 PERCENT OF
THE FLUE GAS WILL BE PVPASSED FOR REHEAT. THE SLUDGE WILL BE PONDED.
STRUCTURAL WORK IS 9QZ COMPLETE.
25
-------
EP» UTILITT r&D SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SALT RIVER PROJECT
COR ON ADO
?
NEW 350.0 MW CGROSS)
280.0 *W (ESC)
COAL
1.03 XS SUB6ITUNINOUS
LIMESTONE
OULL'AN KELLOGG
ENERSY CONSUMPTION: X
STATUS 2 STARTUP 1/80
THIS NEW UNIT WILL BORN LOW SULFUR WESTERN COAL. A MAXIMUM OF SOX OF THE
FLUE 6AS HILL BE SCRUBBED TO MEET SULFUR DIOXIDE EMISSION REGULATIONS.
PULLHAN/KELL066 MILL PROVIDE 2 WEIR HORIZONTAL SPRAY TOWERS UTILIZING
LIMESTONE SLURRY FOR S02 CONTROL. THE SYSTEM WILL UTILIZE RUBBER-LINED
SLURRY RECTCLE PUMPS, EACH RATED AT 98oo BPH, RISIFLACE-LINEO SCRUBBER
MODULES. VERTICAL HEIL MIST ELIMINATORS AND A MINIMUM OF 20 PERCENT OF
THE FLUE 6AS WILL BE BYPASSED FOR REHEAT. THE SLUDGE WILL BE PONDED.
STRUCTURAL WORK IS 60S COMPLETE.
SALT RIVER PROJECT
COROHADO
?
«EW 350.0 HW (GROSS)
280.0 <*W (ESC)
COAL
1.03 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: X
STATUS 6 STARTUP 0/8?
THIS NEW UNIT WILL E>URN LOU SULFUR WESTERN COAL* EIGHTY PERCENT OF THE
GAS WILL BE SCRUBBED TO MEET SULFUR DIOXIDE EMISSION REGULATIONS.
UTILITY IS CURRENTLY CONSIDERING THE INSTALLATION OF TWO HORIZONTAL
SPRAY TOWERS EMPLOYING A LIMESTONE SCRUBBING SOLUTION TO REMOVE S02
FROM THE FLUE GAS. SCHEDULED COMMERCIAL OPERATION DATE IS 1987. PLANS
FOR AN EMISSION CONTROL SYSTEM HAVE NOT BEEN FINALIZED. SLUDGE WILL
PROBABLY BE PONDED.
SAN "I6UEL ELECTRIC COOP
SAN »I6UEL
1
-------
EPA UTILITY F60 SURVET: SECOND QUARTER 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTH CAROLINA PUBLIC SERVICE
MINY»H
2
NEW 280.0 NW (GROSS)
140.0 1W (ESC)
COAL
1.73 XS BITUMINOUS
LIMESTONE
9ABCOCK t UILCOK
ENERGY CONSUMPTION: 1.1*
STATUS 1 STARTUP 7/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A 1001 CAPACITY ESP
FOLLOWED BY A SOX CAPACITY LIMESTONE FGD SYSTEM. ONE F6D MODULE, CONSIST-
ING OF A VENTURI SCRUBBER AND TRAY TOWER ABSORBER. REMOVES 701 OF THE
INLET S02. REHEAT IS SUPPLIED BY FLUE 6AS BYPASS. THE SCRUBBING WASTES
ARE DISCHAR6ED TO AN ON-SITEt UNLINED DIKED POND. THE NO. 2 UNIT
COMMENCED INITIAL OPERATION IN JULY 1977.
SOUTH CAROLINA PUBLIC SERVICE
UINVAH
5
NEW 280.0 NW (GROSS)
260.0 «IW (ESC)
COAL
1.70 XS
LIMESTONE
3ABCOCK C WILCOX
ENERSV CONSUMPTION: 2.IX
STATUS 2 STARTUP 5/80
A CONTRACT HAS BEEN AWARDED TO BABCOCK t WILCOX FOR THE INSTALLATION
OF THE FGD SYSTEM ON THIS UNIT. PARTICULATE REMOVAL WILL BE PROVIDED
BY RESEARCH COTTRELL ESP'S. THE BOILER IS A COAL-FIRED DRY-BOTTOM UNIT
WHICH MILL BURN COAL WITH A 1.7X SULFUR CONTENT AND A HEAT VALUE OF
11,500 BTU/LB. THE GENERATING EQUIPMENT is BEING SUPPLIED BY RILEV
STOKER. 100X OF THE FLUE GAS WILL BE SCRUBBED. ALL FGD FOOTINGS
HAVE BEEN POURED AND TANK FABRICATION IS COMPLETE. DUCTWORK IS IN
PROGRESS.
SOUTH CAROLINA PUBLIC SERVICE
UINVAH
I
NEW 280.0 NW (GROSS)
280.0 HW (ESC)
COAL
1.70 XS BITUMINOUS
LIMESTONE
AMERICAN AIR FILTER
ENER6Y CONSUMPTION: 2.IX
STATUS 3 STARTUP 5/81
SOUTH CAROLINA PUBLIC SERVICE AWARDED A CONTRACT TO AMERICAN AIR
FILTER FOR THE INSTALLATION OF AN FGD SYSTEM ON WINYAH 4. PARTIC-
ULATE MATTER WILL BE CONTROLLED BY AN ESP. THE SYSTEM DESIGN IN-
CLUDES TWO LIMESTONE SLURRY SPRAY TOWERS AND AN INDIRECT STEAM COIL
REHEAT SYSTEM. THE UTILITY PLANS TO OPERATE THE UNIT WITH A CLOSED
WATER LOOP.
SOUTHERN ILLINOIS POWER COOP
NARION
4
NEW 184.0 NW (GROSS)
184.0 MW (ESC)
COAL
3.00 XS
LIMESTONE
9ABCOCK t WILCOX
ENERGY CONSUMPTION: X
STATUS 1 STARTUP 5/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED BOILER CONSISTS OF AN
ESP FOR PARTICULATE CONTROL FOLLOWED BY 2 SPRAY TOWERS FOR S02 CONTROL.
LIMESTONE SLURRY MILL BE USED AS THE SCRUBBING REAGENT. SIPC IS NOT
PLANNING TO UTILIZE FLUE GAS REHEAT AND IS CURRENTLY PLANNING ON A BRICK
LINING FOR THE STACK. SIPC INTENDS TO USE A LANDFILL WITH ASH
STABILIZATION FOR SLUDGE DISPOSAL.
SOUTHERN ILLINOIS POWER COOP
MARION
5
NEW 300.0 MW (GROSS)
300.0 MU (ESC)
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: !
STATUS 6 STARTUP 0/84
SOUTHERN ILLINOIS POWER COOP IS PLANNING A NEW COAL-FIRED UNIT FOR ITS
MARION STATION. MARION 5. THE FGD PROCESS HAS NOT BEEN DECIDED. THE UNIT
WILL FIRE 3.OX SULFUR COAL AND MAY START UP AS EARLY AS 1983. THE UTILITY
IS WAITING FOR THE FINALIZATION OF THE SO? REGULATIONS THEY WILL HAVE
TO MEET.
SOUTHERN INDIANA GAS t ELEC
».B. BROWN
1
NEW 265.0 1W (GROSS)
265.0 MW (ESC)
COAL
4.50 XS
DUAL ALKALI
FNC CORPORATION
ENERGY CONSUMPTION: 1.9X
STATUS 1 STARTUP 3/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE UTILITY HAS AWARDED A CONTRACT TO FMC FOR THE INSTALLATION OF A
DOUBLE ALKALI SCRUBBING SYSTEM UTILIZING SODA ASH AND LIME. THIS UNIT
IS A PART OF A NEW POWER STATION LOCATED IN WEST FRANKLIN* INDIANA.
THE SYSTEM HILL PRODUCE A FILTER CAKE WASTE PRODUCT WHICH WILL BE
DISPOSED OF IN AN ON-SlTE LANDFILL. THE PARTICULATE EMISSIONS WILL
BE CONTROLLED BY A BUELL-ENVIROTECH COLD-SIDE ESP.
27
-------
EPA UTILITY FGD SURVEYS SECOND QUARTER 1979
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTHERN MISSISSIPPI ELECTRIC
t.D. MORROW
1
EH 200.0 MW (GROSS)
124.0 NW CESC>
'COAL
1.30 ZS
LIMESTONE
RILET STDKER/ENVIRONEERING
ENEH6T CONSUMPTION: 5.SX
STATUS 1 STARTUP 8/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
PARTICULATES ARE CONTROLLED BY A H16H-EFFICIENC* ESP UPSTREAM
OF THE F6D SYSTEM. DESIGN S02 AND PARTICULATE REMOVAL EFFICIENCIES ARE
85 ANB 99.62. RESPECTIVELY. A HATER SPRAY HAS BEEN ADDED IN THE
BY-PASS DUCT TO PROTECT THE LINER FROM TEMPERATURE EXCURSION. SLUDGE BILL
BE STABILIZED WITH FLYASH AND DISPOSED OF ON-S1TE. INITIAL STARTUP HAS
BEGUN. HOWEVER DUE TO BOILER PROBLEMS NO OPERATING TIME HAS BEEN ACCUMU-
LATED. ACCEPTANCE TESTING IS EXPECTED IN NOVEMBER.
SOUTHERN MISSISSIPPI ELECTRIC
*.D. MORROW
Z
NEW 200.0 «W (GROSS)
124.0 HW (ESC)
COAL
1.30 SS
LIMESTONE
RILEY STOKER/ENVIRONEERING
ENERGY CONSUMPTION: 5.51
STATUS 1 STARTUP 6/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
A CONTRACT WAS AWARDED BY SME TO RILEY STOKER/ENVIRONEERING FOR THIS
F6D SYSTEM. PARTICULATES ARE CONTROLLED BY A HIGH-EFFICIENCY ESP
UPSTREAM OF THE FGD SYSTEM. DESIGN SULFUR DIOXIDE AND PARTICULATE
EFFICIENCIES ARE 85 AND 99.6 PERCENT. RESPECTIVELY. A WATER SPRAY HAS
BEEN ADDED IN THE BY-PASS DUCT TO PROTECT THE LINER FROM TEMPERATURE
EXCURSION. SLUDGE WILL BE STABILIZED WITH FLVASH AND DISPOSED ON THE
PLANT SITE. CONSTRUCTION OF THE WET LIMESTONE SCRUBBING SYSTEM IS NOW
COMPLETE.
SOUTHWESTERN ELECTRIC POWER
HENRY W. PERKEV
1
HEW 720.0 MW (GROSS)
720.0 NW (ESC)
COAL
.80 ZS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION. UOP
ENERGY CONSUMPTION: !
STATUS 3 STARTUP 2/84
A CONTRACT FOR TNE EMISSION CONTROL SYSTEM HAS BEEN AWARDED TO THE AIR
CORRECTION DIVISION OF UOP. THE SYSTEM DESIGN INCLUDES TWO COLD-SIDE
ESP'S FOR PARTICULATE REMOVAL UP-STREAM FROM ^ SPRAY TOWERS WHICH
UTILIZE LIMESTONE SLURRY FOR S02 CONTROL. SLUDGE DISPOSAL WILL BE HANDLED
BY «N IUCS SYSTEM. START-Up IS EXPECTED BY FEBRUARY 1984.
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
NEW 194.0 MW (GROSS)
194.0 MW (ESC)
COAL
3.50 ZS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 4.6Z
STATUS 1 STARTUP 4/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS NEW COAL-FIRED UNIT CONSISTS OF A
FOUR-FIELD HIGH EFFICIENCY ESP (99.61 DESIGN) AND 2 TURBULENT CONTACT
ABSORBER MODULES (80Z DESIGN) FOR THE CONTROL OF PARTICULATES AND S02.
BOTH THE ESP AND LIMESTONE FGD SYSTEM ARE SUPPLIED BY UOP. THE SCRUBBING
WASTES ARE DEWATERED BY A ROTARY DRUM VACUUM FILTER AND THE FILTER CAKE
IS HAULED AWAY TO A LANDFILL. INITIAL OPERATION OF THE FGD SYSTEM
OCCURRED IN APRIL 77. IN SEPT. 77. THE UNIT SUCCESSFULLY COMPLETED
COMPLIANCE TESTING.
SPRINGFIELD WATER* LIGHT t
DALLMAN
3
EH 205.0 «W (GROSS)
205.0 MW (ESC)
COAL
3.30 ZS
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: S.9t
STATUS 2 STARTUP 7/80
PWR A CONTRACT WAS AWARDED TO RESEARCH COTTRELL FOR THE INSTALLATION OF A
LIMESTONE FGD SYSTEM. REOUIRED SULFUR DIOXIDE REMOVAL EFFICIENCY IS 90
PERCENT. A SLUDGE DISPOSAL STRATEGY HAS NOT BEEN FINALIZED. BUT THE
UTILITY IS CONSIDERING EITHER PONDING OR LANDFILL. CONSTRUCTION OF THE
FGD SYSTEM FOUNDATIONS HAVE BEGUN. ALL SYSTEMS ARE ON SCHEDULE. THE
BOILER OPERATION WAS SCHEDULED TO COMMENCE IN JUNE 1978.
ST. JOE ZINC
G.F. WEATON
1
RETROFIT 60.0 MW (GROSS)
60.0 MW (ESC)
COAL
3.00 ZS
CITRATE
BUREAU OF NINES
ENERGY CONSUMPTIONS *
STATUS 2 STARTUP 7/79
CONSTRUCTION CONTINUES ON THE CITRATE PROCESS SCRUBBING SYSTEM WHICH WILL
CONTROL S02 EMISSIONS FROM A 60-MW COAL-FIRED POWER GENERATING UNIT AT
ST. JOE ZINC. THIS UNIT PROVIDES POWER FOR THE LOCAL UTILITY GRID.
FGD SYSTEM START-UP IS SCHEDULED FOR JULY 1979. THE RE6ENERABLE FGD
SYSTEM WILL PRODUCE ELEMENTAL SULFUR AS A BY-PRODUCT. ALL MAJOR CONSTRUC-
TION IS COMPLETE. WIRING AND PIPING WORK IS NOW BEING COMPLETED.
28
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TAMPA ELECTRIC
BIG BEND
4
NEW 450.0 KW (GROSS)
450.0 HW (ESC)
COAL
I.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***Mt
STATUS 6 STARTUP 3/85
TAMPA ELECTRIC HAS ANNOUNCED PLANS TO INSTALL AN F60 SYSTEM AT BIG BEND
4 WHICH IS SCHEDULED TO BEGIN OPERATIONS EARLY IN 1985. THE FGD PROCESS
HAS NOT VET BEEN SELECTED. PRIMARY PARTICULATE CONTROL HILL BE PROVIDED
6V AN ELECTROSTATIC PRECIPITATOR UPSTREAM OF THE FGD SYSTE". AN INDIRECT
(STEAM COIL> HOT AIR INJECTION REHEAT SYSTEM WILL BE INCLUDED AT THE
SCRUBBER OUTLET. DESIGN SULFUR DIOXIDE REMOVAL EFFICIENCY HILL BE
90 PERCENT
TENNESSEE VALLEY AUTHORITY
CUMBERLAND
RETROFIT 1300.0 «W (GROSS)
600.0 1W (ESC)
COAL
» XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 7/82
TVA IS INSTALLING A HEAVY-MEDIA COAL-CLEAN ING SYSTE* AND HAS AGREED TO
INSTALL A 600-"* F6D SYSTEM AT THE CUMBERLAND PLANT TO BRING IT INTO
COMPLIANCE WITH STATE AND FEDERAL S02 EMISSION LIMITS. THE TYPE OF
FGD SYSTEM CHOSEN HILL BE DETERMINED BY PROTOTYPE LEVEL EVALUATION OF
SEVERAL ADVANCED SCRUBBER CONCEPTS.
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE
1-10
RETROFIT 1450.0 KW (GROSS)
600.0 MW (ESC)
COAL
3.10 XS
1AGNESIU* OXIDE
TVA/UNITED ENGINEERS
ENERGY CONSUMPTION: **t
STATUS 5 STARTUP 0/82
TVA IS PLANNING TO RETROFIT A 600-MU MAGNESIUM OXIDE FGD SYSTEM AT THE
JOHNSONVILLE STEAM PLANT, A 1450-MW COAL-FIRED STATION. EN6INERING
ASSISTANCE WILL BE PROVIDED BY UNITED ENGINEERS. THIS PROJECT IS
6UDGETTED AT S185 MILLION. INCLUDING THE COST OF A NEW 600-FT. STACK.
TENNESSEE VALLEY AUTHORITY
PARADISE
1
RETROFIT 704.0 NW (CROSS)
704.0 MW (ESC)
COAL
XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 6/82
TVA IS REQUESTING/EVALUATING BID SPECIFICATIONS FOR TWO LIMESTONE SLURRY
FGD SYSTEMS WHICH WILL BE RETROFITTED ONTO TWO 704-MU HIGH SULFUR COAL-
FIRED BOILERS AT THIS STATION. THE F60 SYSTEMS WILL TREAT 1001 OF THE
FLUE EASES FROM BOTH UNITS. TVA HAS PROJECTED THE TOTAL COST OF THE
PARADISE FGD SYSTEMS TO BE APPROXIMATELY $220 MILLION (S170/KW). BID
REQUEST WAS COMPLETED BY MID-NOVEMBER AND EVALUATION IS NOM IN PROCESS.
BID EVALUATION IS EXPECTED TO BE COMPLETED BY JANUARY 1 AND A CONTRACT
SHOULD BE AWARDED SHORTLY THEREAFTER.
TENNESSEE VALLEY AUTHORITY
PARADISE
2
RETROFIT 704.0 «w (GROSS)
704.0 MW (ESC>
COAL
4.20 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****t
STATUS 3 STARTUP 3/82
TVA IS REQUESTING/EVALUATING BID SPECIFICATIONS FOR TWO LIMESTONE SLURRY
FGD SYSTEMS WHICH HILL BE RETROFITTED ONTO TWO 704-MW HIGH SULFUR COAL-
FIRED BOILERS AT THIS STATION. THE FGD SYSTEMS WILL TREAT 1001 OF THE
FLUE GASES FROM BOTH UNITS. TVA HAS PROJECTED THE TOTAL COST OF THE
PARADISE F60 SYSTEMS TO BE APPROXIMATELY S220 MILLION (S170/KW). BID
REQUEST bAS COMPLETED BY MID-NOVEMBER AND EVALUATION IS NOW IN PROCESS.
BID EVALUATION IS EXPECTED TO BE COMPLETED BY JANUARY 1 AND A CONTRACT
SHOULD BE AWARDED SHORTLY THEREAFTER.
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10A
RETROFIT 10.0 MW (GROSS)
10.0 MW (ESC)
COAL
2.90 XS BITUMINOUS
LIME/LIMESTONE
AIR CORRECTION DIVISION. UOP
ENERGY CONSUMPTION: X
STATUS 1 STARTUP 4/72
REFER TO THE BACKGROUND INFORMATION IN SECTION 3 OF THIS REPORT. THIS
TURBULENT CONTACT ABSORBER (TCA) LIME/LIMESTONE SCRUBBING SYSTEM HAS BEEN
OPERATIONAL SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY THE EPA WITH
TVA AS THE CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTEL CORP. OF SAN
FRANCISCO IS THE MAJOR CONTRACTOR. TEST DIRECTOR. AND REPORT WRITER.
TESTING CHEMICAL ADDITIVES FOR IMPROVING S02 REMOVAL EFFICIENCY
CONTINUED THROUGH OCTOBER AND NOVEMBER. BOTH VENTURI/SPRAY TOWER AND TCA
SYSTEMS WERE OPERATED ON LIMESTONE SLURRY WITH FLYASH LOADING.
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF FED SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TENNESSEE VALLEY AUTHORITY
SHAUWEE
108
RETROFIT 10.0 *w (GROSS)
10.0 «u (ESC)
COAL
2.90 XS BITUMINOUS
LIME/LIMESTONE
CHENICO
ENERGY CONSUMPTION: *!
STATUS 1 STARTUP 4/72
REFER TO SECTION J OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS
VENTUR1/SPRAY TOMER LIME/LIMESTONE SCRUBBING SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY THE EPA WITH TVA AS THE
CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTEL CORP. OF SAN FRANCISCO IS
THE MAJOR CONTRACTOR. TEST DIRECTOR, AND REPORT WRITER. TESTING KITH
CHEMICAL ADDITIVES FOR IMPROVING S02 REMOVAL EFFICIENCY CONTINUED
THROUGH OCTOBER AND NOVEMBER. BOTH VENTURI/SPRAY TONER AND TCA SYSTEMS
HERE OPERATED ON LIMESTONE SLURRY WITH HIGH FLTASH LOADING.
TENNESSEE VALLEY AUTHORITY
WIDOMS CREEK
7
RETROFIT 575.0 *w (GROSS)
575.0 «U (ESC)
COAL
3.73 ZS BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERSV CONSUMPTION: !
STATUS 2 STARTUP 10/80
TENNESSEE VALLEY AUTHORITY ANNOUNCED THAT A CONTRACT HAS BEEN AWARDED TO
COMBUSTION ENGINEERING FOR A LIMESTONE SLURRY SPRAT TOWER FGD SYSTEM. TH£
F6D SYSTEM WILL TREAT HIGH SULFUR COAL FLUE GAS. THE SPRAY TOWER ABSORBERS
WILL 8E CONSTRUCTED OF 317L STAINLESS STEEL. THE NUMBER 7 UNIT FIRES COAL
WITH THE SAME CHARACTERISTICS AS THE COAL FIRED IN UNIT 8. INITIAL
OPERATIONS ARE SCHEDULED FOR OCTOBER 1980. THE FGD SYSTEM IS CURRENTLY
UNDER CONSTRUCTION.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
I
RETROFIT 550.0 *w (GROSS)
550.0 *W (ESC)
COAL
3.70 XS
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION: X
STATUS 1 STARTUP 5/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS 550 MW COAL-FIRED POWER GENERATING
UNIT CONSISTS OF EXISTING ELECTROSTATIC PRECIPITATORS FOLLOWED BY FOUR
PARALLEL SCRUBBING TRAINS, EACH CAPABLE OF HANDLING 25 PERCENT OF THE
BOILER FLUE GAS FROM UNIT 8. EACH TRAIN INCLUDES A RECTANGULAR THROAT
VENTURI SCRUBBER AND A GRID-TOWER ABSORBER SUPPLIED BY POLVCON. THE GRID
TOWER CAN BE CONVERTED TO A MOBILE-BED TOWER IF GREATER S02 REMOVAL IS
REQUIRED.
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK
1
HEW 400.0 «W (GROSS)
400.0 *W (ESC)
COAL
1.06 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: X
STATUS 3 STARTUP 1/82
COMBUSTION ENGINEERING WAS AWARDED A CONTRACT TO DESIGN AND SUPPLY A
400-MW LIGNITE-FIRED BOILER, ESP, AND FGD SYSTEM AT GIBBONS CREEK STEAM
ELECTRIC STATION UNIT NO. 1. THE BOILER WILL BURN 1.0«X SULFUR LIGNITE.
FLUE GAS WILL BE CLEANED OF PARTICULATES BY A COLD-SIDE ESP (99.73X
EFFICIENCY). S02 WILL BE REMOVED BY 3 SPRAY TOWER MODULES UTILIZING A
LIMESTONE SLURRY (72.5 TO 87.5Z EFFICIENCY). A CONTRACT HAS BEEN AWARDED
TO IUCS FOR SLUDGE DISPOSAL. CONSTRUCTION IS TO BEGIN IN THE SPRING OF
1979. COMMERICAL START-UP IS SCHEDULED FOR JANUARY, 1982.
TEXAS POWER t
SANDOM
I
HEW
LIGHT
545.0 4W (GROSS)
382.0 MW (ESC)
COAL
1.60 ZS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: X
STATUS 2 STARTUP 7/80
COMBUSTION ENGINEERING HAS BEEN CHOSEN AS THE BOILER AND FGD VENDOR FOR
THIS UNIT. BOILER CONSTRUCTION BEGAN ON SEPTEMBER 9. 1977. PARTIcULATE
REMOVAL EQUIPMENT WILL BE LOCATED ON THE COLD-SIDE OF THE AIR HEATER.
SOME PORTION OF THE FLUE GAS WILL BYPASS THE SCRUBBER FOR REHEAT. THE
SPENT SLURRY WILL BE PONDED AND WATER RECYCLED.
THE UNIT IS NOW APPROXIMATELY 40Z COMPLETE.
TEXAS POWER t LIGHT
TWIN OAKS
1
«EW 750.0 «W (GROSS)
750.0 4W (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION! X
STATUS 5 STARTUP 8/84
THIS UNIT WILL BE JOINTLY OWNED BY TPtL AND ALCOA. BIDS ARE NOW BEING
EVALUATED FOR THIS NEW 750-MW (GROSS) UNIT. THE S02 CONTROL STRATEGY
WILL CONSIST OF A LIMESTONE FLUE GAS DESULFURIZATION SYSTEM. EXPECTED
START-UP IS AUGUST 1984.
30
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS POWER
THIN OAKS
2
EW
I LI6HT
750.0 MW (GROSS)
750.0 MW (ESC)
COAL
.73 XS LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERSY CONSUMPTION: **
STATUS 5 STARTUP 8/85
THIS UNIT HILL BE JOINTLY OWNED BY TPtL AND ALCOA. BIDS ARE NOW BEING
EVALUATED FOR THIS NEV 750-NW (CROSS) UNIT. THE S02 CONTROL STRATEGY
HILL CONSIST OF A LIMESTONE FLUE GAS OESUlFURI2ATION SYSTEM. EXPECTED
START-UP IS AUGUST 1984.
TEXAS UTILITIES
FOREST CROVE
1
HEW 750.0 MW (GROSS)
750.0 MU (ESC)
COAL
.80 ZS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: X
STATUS 5 STARTUP 0/81
TEXAS UTILITIES IS PLANNING A NEW 750-MU UNIT AT THE FOREST GROVE SITE.
TWO ESP'S WILL BE INSTALLED FOR PARTICULATE CONTROL. THE UTILITY IS
CURRENTLY REQUESTING BIDS FOR AN FGD SYSTEM. START-UP IS SCHEDULED FOR
LATE 1981. THE BOILER WILL BE SUPPLIED BY BABCOCK I WILCOX COMPANY.
THE DESIGN DOES NOT INCLUDE A STACK GAS REHEAT SYSTEM.
TEXAS UTILITIES
MARTIN LAKE
1
HEW 793.0 1W (GROSS)
595.0 MW (ESC)
COAL
.90 ZS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1.3Z
STATUS 1 STARTUP 4/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS NEW
793 MW UNIT FIRES TEXAS LIGNITE CONTAINING 0.9X SULFUR (AVG) AND 82 ASH
(AVG). THE UNIT IS EQUIPPED WITH AN EMISSION CONTROL SYSTEM WHICH
INCLUDES COLD-SIDE ESP'S AND A LIMESTONE FGD SYSTEM BOTH SUPPLIED BY
RESEARCH-COTTRELL. THE FGD SYSTEM CONSISTS OF 6 PACKED/SPRAY TOWER
ABSORBERS WHICH TREAT 7SX OF THE TOTAL BOILER FLUE GAS. THE REMAINING
FLUE CAS IS BYPASSED FOR REHEAT. TOTAL SO? REMOVAL EFFICIENCY IS 70.51.
THE FLUE CAS CLEANING HASTES ARE STABILIZED AND DISPOSED IN AN ON-SITE.
LANDFILL*
TEXAS UTILITIES
MARTIN LAKE
?
EH 793.0 «H (GROSS)
595.0 MH (ESC)
COAL
.90 ZS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1.31
STATUS 1 STARTUP 5/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THIS NEW
793 Mh UNIT FIRES TEXAS LIGNITE CONTAINING 0.9Z SULFUR (AVG) AND 82 ASH
(AVG). THE UNIT IS EQUIPPED WITH AN EMISSION CONTROL SYSTEM CONSISTING
OF C3LD-SIDE ESP'S AND A LIMESTONE FGD SYSTEM. BOTH SUPPLIED BY
RESEARCH-COTTRELL. THE FCD SYSTEM CONSISTS OF 6 PACKED/SPRAY TOWER
ABSORBERS WHICH TREAT 75Z OF THE TOTAL BOILER FLUE GAS. THE REMAINING
FLUE GAS IS BY-PASSED FOR REHEAT. TOTAL DESIGN S02 REMOVAL EFFICIENCY IS
70.51. THE FLUE GAS CLEANING HASTES ARE STABILIZED AND DISPOSED IN AN
ON-SITE LANDFILL.
TEXAS UTILITIES
MARTIN LAKE
5
NEW 793.0 MH (GROSS)
595.0 MH (ESC)
COAL
.90 ZS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 2/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS NEH 793-MW POHER GENERATING UNIT HILL FIRE TEXAS LIGNITE CONTAINING
0.9Z SULFUR (AV6) AND 8Z ASH (AVG). TO MEET FEDERAL NSPS, THE UNIT IS
EQUIPPED WITH AN EMISSION CONTROL SYSTEM CONSISTING OF COLD-SIDE ESP'S
AND A LIMESTONE FGD SYSTEM, BOTH SUPPLIED BY RESEARCH-COTTRELL. THE FCD
SYSTEM CONSISTS OF 6 PACKED/SPRAY TOMER ABSORBERS WHICH HILL TREAT 7SZ OF
THE TOTAL BOILER FLUE CAS. THE REMAINING GAS HILL BE BYPASSED FOR REHEAT.
TOTAL DESIGN S02 REMOVAL EFFICIENCY IS 70.SX THE FLUE GAS CLEANING
HASTES HILL BE STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
TEXAS UTILITIES
MARTIN LAKE
t
EH 750.0 KH (CROSS)
750.0 MH (ESC)
COAL
.90 ZS LIGNITE
LIMESTONE
RESEARCH COTTRELL
ENEMY CONSUMPTION: x
STATUS 3 STARTUP 0/85
THE CONTRACT FOR THIS FGD SYSTEM HAS BEEN AWARDED TO RESEARCH-COTTRELL.
THE BOILER IS NOH BEING ERECTED. START-UP HAS BEEN DELAYED TO EITHER
1985 OR 1986.
31
-------
EPA UTILITY FGD SURVET: SECOND QUARTER 1979
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS UTILITIES
KILL CREEK
1
NEW 750.0 NW (GROSS)
750.0 ** (ESC)
COAL
« tS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENEB6T CONSUMPTION: !
STATUS 6 STARTUP 0/65
TEXAS UTILITIES IS PLANNING TWO NEM 750-MW UNITS FOR THE UTILITY S
KILL CREEK SITE. THE UTIL1TT MILL INCORPORATE F6D SYSTEMS ON EACH UNIT
SO THAT S02 EMISSIONS WILL BE CONTROLLED TO APPROXIMATELY 1LB/MM BTU.
PARTICULATE NATTER WILL BE CONTROLLED BY ESP'S. START-UP FOR UNITS
1 AND2 ARE PROJECTED TO BE 1985 AND 1986 RESPECTIVELY.
TEXAS UTILITIES
'ILL CREEK
?
NEW 750.0 NW (GROSS)
750.0 NW (ESC)
COAL
XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION! X
STATUS 6 STARTUP 0/86
TEXAS UTILITIES IS PLANNING TWO NEW 750-NW UNITS FOR THE UTILITY'S
MILL CREEK SITE. THE UTILITY WILL INCORPORATE F6D SYSTEMS ON EACH UNIT
SO THAT S02 EMISSIONS MILL BE CONTROLLED TO APPROXIMATELY 1 LB/MM BTU.
PARTICULATE HATTER WILL BE CONTROLLED BY ESP'S. START-UP FOR UNITS
1 AND 2 ARE PROJECTED TO BE 1985 AND 1986 RESPECTIVELY.
TEXAS UTILITIES
NONTICEULO
J
EH 800.0 NW (GROSS)
800.0 NW (ESC)
COAL
1.50 >S LIGNITE
LIMESTONE
CHEMICO
ENERGY CONSUMPTION: X
STATUS 1 STARTUP 5/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE
EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A HIGH EFFICIENCY ESP
AND A LIMESTONE FGD SYSTEM. THE ESP (POLLUTION CONTROL-WALTHER> PROVIDES
PRIMARY PARTICULATE CONTROL (99.56X). THE FGD SYSTEM CONSISTS OF 3
LIMESTONE SCRUBBING SPRAY TOMERS THAT PROVIDE PRIMARY S02 CONTROL (74*).
THE FCD SYSTEM IS DESIGNED TO TREAT 3 MM ACFM OF FLUE GAS RESULTING FROM
COAL WITH 1.SX SULFUR, 18.91 ASH AND 0.04* CL. THE FLUE GAS CLEANING
WASTES ARE DISPOSED IN AN ON-SITE LINED POND.
UTAH POWER I LIGHT
HUNTER
1
MEW 400.0 NW (GROSS)
360.0 MW (ESC>
COAL
.55 ZS
LIME
CHEMICO
ENERGY CONSUMPTION: !
STATUS 1 STARTUP 5/79
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
A CONTRACT HAS BEEN AWARDED TO THE CHEHICO AIR POLLUTION DIVISION FOR A
PEBBLE LIME WET SCRUBBING SYSTEM FOR THIS NEW UNIT. THE SCRUBBING SYSTEM
IS DESIGNED TO OPERATE IN AN OPEN WATER LOOP MODE WITH AN S02 REMOVAL
EFFICIENCY OF 80 PERCENT FOR LOW SULFUR UTAH COAL. PRIMARY PARTICULATE
CONTROL IS PROVIDED BY AN ESP UPSTREAM OF THE SCRUBBERS. THE SLUDGE
IS STABILIZED WITH FLYASH AND DISPOSED OF ON THE PLANT SITE. THE
A-E DESIGN FIRM FOR THIS PROJECT IS STEARNS-R06ER.
UTAH POWER ( LIGHT
HUNTER
?
NEW 400.0 NW (GROSS)
360.0 NW (ESC)
COAL
.55 ZS
LIME
CHEMICO
ENERGY CONSUMPTION: X
STATUS 2 STARTUP 6/80
UTAH PIL AWARDED CHEMICO A CONTRACT TO SUPPLY A LIME FGD SYSTEM FOR HUNTER
2 DESIGNED TO OPERATE IN AN OPEN WATER LOOP MODE WITH AN S02 REMOVAL EF-
FICIENCY OF 80 PERCENT (FIRING LOW SULFUR UTAH COAL). PRIMARY PARTICULATE
CONTROL WILL BE PROVIDED BY AN ESP UP-STREAM OF THE SCRUBBERS. THE SLUDGE
WILL BE STABILIZED WITH FLYASH AND DISPOSED OF ON THE PLANT SITE. INITIAL
BOILER AND FGD SYSTEM START-UP IS SCHEDULED FOR JUNE 1980. THIS UNIT WILL
BE IDENTICAL TO UNIT 1. CONSTRUCTION ON THIS UNIT IS ABOUT 50Z COMPLETE.
UTAH POWER I LIGHT
NUNTIN6TON
1
NEW 430.0 NW (GROSS)
366.0 MW (ESC)
COAL
.55 ZS
LINE
CHE HI CO
ENERGY CONSUMPTION: 1.6Z
STATUS 1 STARTUP 5/78
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. CHEHICO WAS
THE SUPPLIER OF A LIME SCRUBBING SYSTEM FOR THIS NEW UNIT. PRIMARY
PARTICULATE REMOVAL IS PROVIDED BY AN ESP INSTALLED UPSTREAM OF THE WET
SCRUBBING SYSTEM. « DAMPER IS USED DURING OPERATION TO ALLOW BETWEEN 10
AND 20 PERCENT OF THE FLUE GAS TO BY-PASS THE FGD SYSTEM. DESIGN REMOVAL
EFFICIENCIES FOR S02 AND PARTICULATE ARE 80 AND 99.5 PERCENT
RESPECTIVELY. SLUDGE IS DEWATERED (60X SOLIDS) AND TRUCKED TO AN ON-SITE
LANDFILL. INITIAL OPERATIONS AT THIS UNIT BEGAN ON MAY 10, 1978.
32
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
WISCONSIN POWER I LIGHT
COLUNBIA
2
RETROFIT 527.0 *w (GROSS)
316.0 *W (ESC)
COAL
.BO ZS
LINE/ALKALINE FLVASH
CHENICO
ENER6T CONSUMPTION: *!
STATUS 3 STARTUP 1/82
A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR A LIME/FLVASH FCD SYSTEM. IT
HILL CONSIST OF TWO SPRAY MODULES WITH A HOT-SIDE ESP FOR PARTlCULATE
REMOVAL. A CLOSED LOOP WATER SYSTEM IS ANTICIPATED WITH FLYASH STABILI-
ZATION OF THE SLUDCE. A SLUBCE DISPOSAL POND LOCATED OFF-SITE IS BEING
CONSIDERED. THE FGD SYSTEM IS BEING DESIGNED TO TREAT 601 OF THE FLUE
GAS RESULTING FROM THE COMBUSTION OF LOW SULFUR COLSTRIP COAL. THE
REMAINING 4QX WILL BE BYPASSED FOR REHEAT.
33
-------
EPA UTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F60 SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - Mb
NET UNIT CENERATING CAPACITY W/F6D - Mk
EQUIVALENT SCRUBBED CAPACITY - 1*
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 2
AVERAGE CHLORIDE CONTENT - Z
FGD 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
PART 1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
* MATER LOOP
TYPE
FRESH MAK.E-UP WATER - LITER/S
* DISPOSAL
TYPE
- X
ALABAMA ELECTRIC COOP
TOMBI66EE
£
LEPOY
ALABAMA
255.0
235.0
179.0
( 11500 BTU/LP)
COAL
BITUMINOUS
267*0.
14.00
7.00
1.15
*******
MET SCRUBBING
LIMESTONE
PEA60DV PROCESS SYSTEMS
NEW
7.1
9/78
**/**
85.00
99. *0
.0
.0
OPEN
17.6
LINED POND
( 280 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL
S02 PART,
PER BOILER FGO CAP.
HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
PRObLEMS/SOLUTlONS/COMMENTS
672
744
720
START DATE 2/79 END DATE 4/79
THE UTILITY HAS REPORTED THAT NO UNUSUAL PROBLEMS HAVE OCCURRED.
5/79 SYSTEM
6/79 SYSTEM
PROBLEMS/SOLUTIONS/COMMENTS
744
720
START DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED WELL DURING MAY AND
JUNE MITH THE EXCEPTION THAT THE MIST ELIMINATORS HAD TO BE REPLACED.
THE MIST ELIMINATORS WERE DEFORMED DURING A TEMPERATURE EXCURSION.
34
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION I
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT N*ME
UNIT NUKBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLANT 6ENERATIN6 CAPACITY - HW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - F»
NET UNIT GENERATING CAPACITY WO/FGD - *U
EQUIVALENT SCRUBBED CAPACITY - HW
* 30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT M
STACK TOP DIAMETER M
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT KJ/KG
RANGE HEAT CONTENT - PTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - 1
AVERAGE SULFUR CONTENT X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MW
* ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FGD SYSTEM
SALEABLE PRODUCT/TMROWAWAY 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
* ABSORBER
NUMBER
TYPE
INITIAL START UP
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
BOILER LOAD/ABSORBER - X
L18UID RECIDCULATION RATE - LITER/S
L/6 RATIO - L/CU.M
S02 DESIGN REMOVAL EFFICIENCY - X
ALABAMA ELECTRIC COOP
TOMBIGBEE
3
LE»OY
ALABAMA
A
* ( L9/MM5TU)
516. ( 1.200 LB/MMBTU)
***** «
255.0
235.0
243.C
179.0
R1LEY STOKER
PULVERIZED COAL
BASE
6/70
4*9.72
143.9
122.
*******
COAL
BITUMINOUS
26749.
14.00
10-16
7.00
( 953000 ACFP)
( 291 F)
( 400 FT)
(.**.* FT)
( 11500 BTU/LF )
11000-12000
1.15
O.P-1.5
***** *
( TPH)
1
HOT SIDE
RESEARCH-COTTRELL
X 99.3
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
BURNS t MCDONNELL
FULL SCALE
NEW
- X 99.30
85.00
6/79
8/75
.0
.0
SIEVE TRAY TOWER
6/79
CARBON STEEL
316L SS
316 SS
35.0
1259.
9.4
85.0
(19980 6PM)
( 70.0 6AL/1000ACF)
35
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
ALABAMA ELECTRIC COOP TOMBIGBEE
(CONT.)
FANS
NUMBER
TYPE
CONSTRUCTION MATERIALS
* HIST ELIMINATOR
NUMBER
TYPE
MIST ELIMINATOR
NUMBER
TYPE
PUMPS
SERVICE
RECYCLE
MILL RECYCLE
SLURRY FEED
WASH HATER
WASTE SLURRY
SUPERNATE RETURN
TANKS
SERVICE
SLURRY RECYCLE
LIMESTONE SLURRY STORAGE
UASHUATER
* REHEITER
NUH9ER
* THICKENER
NUMBER
* MATER LOOP
TYPE
FRESH MAKEUP WATER ADDITION - LITERS/S
REAGENT PREPARATION EQUIPMENT
NUMBER OF BALL MILLS
fcALL MILL CAPACITY- H T/H
REAEENT PRODUCT - X SLURRY SOLIDS
* TREATMENT
DISPOSAL
NATURE
TYPE
LOCATION
TRANSPORTATION
ARE* - ACRES
ID, DIRECT COUPLED
CARBON STEEL
CHEVRON
3ULK ENTRAINMENT SEPARATOR
NUMBER
NUMBER
1
1
1
OPEN
17.6
1
9.1
35. 0
FINAL
LINED POND
ON SITE
PIPE
34.8
( 280 6P«)
( 10.0 TPH)
PERIOD MODULE AVAILABILITY OPERABILITT
PERFORMANCE DATA
RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/79 SYSTEM
PROBLE4S/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
THE FGD SYSTEM BEGAN OPERATION DURING JUNE. HOWEVER DUE TO THE RECENT
START-UP OF THE UNIT DATA IS NOT YET AVAILABLE.
36
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLAIT GENERATING CAPACITY - MW
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - PU
NET UNIT GENERATING CAPACITY WO/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 - KJ/K6
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
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - NU
ESP
NUMBER
SUPPLIER
F60 SYSTEM
SALEABLE PRODUCT/THROW 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 - S
INITIAL START-UP
* ABSORBER
NUMBER
TTPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
BOILER LOAD/ABSORBER - X
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
L/C RATIO - L/CU.M
PRESSURE DROP - KPA
ALLEGHENY POWER SYSTEM
PLEASANTS
1
BELMONT
WEST VIRGINIA
A
21.
516.
1250.0
625.0
625.0
C .050 LP/MMBTU)
( 1.200 LP/MMBTU)
519.0
******
BASE
0/79
1152.85
132.2
366.
*******
COAL
BITUMINOUS
27912.
********
««*
15.00
10-20
3.70
2-*.5
****
***
**«**
**.***
(2443000 ACFW)
< 270 F)
(1200 FT)
(*..* FT)
( 12000 BTU/LB)
11.000-13,300
<*** TPH)
1
AIR CORRECTION DIVISION* UOP
THROWAWAY PRODUCT
WET SCRUBBING
LIME
HG/2-6X
BABCOCK K WILCOX
UNITED ENGINEERS ( CONSTRUCTORS
UNITED ENGINEERS C CONSTRUCTORS
FULL-SCALE
NEW
- X 99.55
90.00
3/79
SPRAY TOWER
3/79
BABCOCK ( WILCOX
1
MILD CARBON STEEL
RUBBER
S.S.
21.0
242.10 ( 513030 ACFM)
132.2 ( 270 F)
7.4 ( 55.0 GAL/1000ACF)
1.2 ( 5.0 1N-H20)
37
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
ALLEGHENY POWER SYSTEM PLEASANTS
(CONT.)
REHEATER
TYPE
TEMPERATURE BOOST - C
WATER LOOP
TYPE
BYPASS
11.1
CLOSED
C 20 r>
- - ___.___._._ _..._... PERFORMANCE DATA - - -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM
4/79 SYSTEM
744
720
PROBLEMS/SOLUTIONS/COMMENTS
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-MODULE HAS BEEN REMOVED FROM SERVICE DUE TO HELD FAILURE ON THE AB-
SORBER DOUNCOHER.
5/79 SYSTEM
6/79 SYSTEM
PROBLEMS/SOLUTIONS/COMMENTS
744
720
START DATE 6/79 END DATE 6/79
THE UTILITY REPORTED THAT THE UNIT HAS 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 AUCUST.
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/F6D - MW
E8UIVALENT SCRUBBED CAPACITY - MW
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
«* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t
ABSORBER SPARE COMPONENTS INDEX
* MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* DISPOSAL
TYPE
ARIZONA ELECTRIC POWER COOP
APACHE
i
COCHISE
ARIZONA
195.0
175.0
195.0
COAL
BITUMINOUS
23260.
15.00
9.00
.55
******
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
4.1
8/78
1/79
85.00
99.50
.0
.0
( 10000 BTU/Lp)
OPEN
115.9
POND
( 1840 6PM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
502 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
672
744
720
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/7<>
COMPLIANCE TESTS WERE RUN ON THIS UNIT LAST NOVEMBER AND THE UNIT WAS
DECLARED COMMERCIAL IN FEBRUARY. THE F6D 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 F60 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.
5/79 SYSTEM 744
6/79 SYSTEM 720
39
-------
EPA UTIL1TT F6D SURVEY* SECOND QUARTER 1979
ARIZONA ELECTRIC POMER COOP APACHE
(COMT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITT RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
PROBLEHS/SOLUTIONS/COHNENTS
START DATE 6/79 END DATE 6/79
THE UTILITY REPORTED THAT THE UNIT ITSELF RAN HELL BUT WAS EXPERIENCING
FAILURE OF THE FRP REAGENT FEED PIPELINE. THE PIPING IS NOW BEING RE-
PLACED UITH CARBON STEEL.
to
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
t
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 - HU
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/F6D - Mb
NET UNIT GENERATING CAPACITY WO/FGD - MU
E8UIVALENT SCRUBBED CAPACITY - My
* 30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANEE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - I
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
RANGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - *
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - My
« ESP
NUM9ER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FGD SYSTEM
SALEABLE PRODUCT/THROUAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEy/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
soz DESIGN REMOVAL EFFICIENCY - t
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION COMPLETION
ABSORBER SPARE CAPACITY INDEX - t
ABS3RBER SPARE COMPONENT INDEX
* ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
SHELL LINER MATERIAL
NOZZLE TYPE
GAS FLOW - CU.M/S
ARIZONA ELECTRIC POWER COOP
APACHE
3
COCHISE
ARIZONA
B
( .100 LB/MNBTU)
( .800 LS/MMBTU)
34*.
590.0
195.0
175.0
183.0
195.0
RILEY STOKER
PULVERIZED COAL. DRY BOTTOM
3ASE
*« /
*** (** ACFM)
******* (* f)
122. ( 400 FT)
4.9 ( 16.2 FT)
COAL
BITUMINOUS
27260.
15.00
******
9.00
***
.55
0.5-0.8
***** **
* *
* * *** **
*****
( 10000 BTU/LB)
10000-11000
(*** TPH)
1
HOT SIDE
AIR CORRECTION DIVISION, UOP
- Z 99.6
THROWAWAT PRODUCT
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
3URNS t "CDONNELL
FULL-SCALE
NEW
- Z 99.50
85.00
4/79
6/79
4/79
.0
.0
PACKED TOWER
4/79
RESEARCH COTTRELL
1
MILD STEEL
GLASS-FLEX
316 SS
188.76
< 400000 ACFM)
41
-------
EPA UTILITY F6D SUPVEYt SECOND QUARTER 1979
ARIZONA ELECTRIC POWER COOP APACHE
6AS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
PRESSURE DROP - KPA
HIST ELIMINATOR
NUMBER
TYPE
CONFIGURATION
rtATER LOOP
TYPE
FRESH MAKEUP WATER ADDITION - LITERS/S
DISPOSAL
NATURE
TYPE
LOCATION
TRANSPORTATION
DIMENSIONS
AREA - ACRES
CAPACITY CU.M
* DISPOSAL
NATURE
TTPE
LOCATION
TRANSPORTATION
DIMENSIONS
AREA - ACRES
CAPACITY - CU.M
CCONT.)
132.2
1260.
1.5
4
CHEVRON
HORI70NTAL
OPEN
340.2
< 270 F)
(20000 6P")
t 6.0 IN-H20)
( 5400 6P-)
FINAL
POND
OFF-SITE ON LEASED LAND
PUMPED
22 ACRES X 18 FT DEEP
22.0
484308 ( 396.0 ACRE-FT)
FINAL
POND
OFF-SITE ON LEASED LAND
PUMPED
64 ACRES X 18 FT DEEP
64.0
1408896 ( 1152.0 ACRE-FT)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/79 SYSTEM
6/79 SYSTEM
744
720
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
UNIT *3 COMMENCED OPERATION DURING JUNE. THE UTILITY REPORTED THAT THE
START-UP HAS TYPICAL WITH NUMEROUS MINOR PROBLEMS.
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - KU
EQUIVALENT SCRUBBED CAPACITY MU
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
* 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 - I
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
ARIZONA PUBLIC SERVICE
CHOLLA
1
JOSEPH CITY
ARIZONA
119.0
115.C
119.0
COAL
BITUMINOUS
23609.
13.50
15.00
.50
.02
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
RETROFIT
7.4
10/73
12/73
92.00
80.00
.0
.0
< 10150 BTU/LP)
OPEN
7.6
( 120 6P«>
DISPOSAL
TYPE
POND
_ -PERFORMANCE DATA
PERI9D MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79 A
B
SYSTEM
88.2 88.1 85. 2
65.6 88.3 85.6
86.9 88.2 86.9 744 744 647
1/79
A
B
SYSTEM
99.2
100.0
99.6
99.1
100.0
99.6
99.2
1CO.O
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 PROB-
LEMS.
2/79
3/79
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
43
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
«RIZOM PUBLIC SERVICE CHOLLA
(CONT.)
------------------------------- . -------- PERFORMANCE 6 AT A ----------------------------------------
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
502 PART. HOURS HOURS HOURS FACTOR
PROBLE
-------
EPA UTILITY FGO SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY H/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEW/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
*« HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* DISPOSAL
TYPE
- 1
ARIZONA PUBLIC SERVICE
CHOLLA
2
JOSEPH CITY
ARIZONA
350.0
250.0
350.0
COAL
BITUMINOUS
23609.
13.50
15.00
.50
.02
UET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
*******
4/78
*/**
75.00
99.70
33.0
1.0
( 10150 BTU/LB)
OPEN
7.6
( 120 6P»)
POND
- ______.___.___ _- -PERFORMANCE DATA-
PERIOD MODULE AVAILABILITY OPERABILITY 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
* PROBLENS/SOLUTIONS/COMMENTS
744
744
672
744
720
744
720
START DATE 12/78 END DATE 6/79
OPERATION PARAMATERS ARE STILL UNAVAILABLE FOR THIS UNIT.
45
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOB OPERATIONAL FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NU*BER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/FGD - Mb
EBUIVALENT SCRUBBED CAPACITY - Ml*
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - t
AVERAGE CHLORIDE CONTENT - X
F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COM«ERCIAL START-UP DATE
SO? DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
* MATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
DISPOSAL
TYPE
- X
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
CANTON
ILLINOIS
(16.0
37? .0
416.0
( 10500 BTU/LB)
COAL
BITUMINOUS
24423.
9.12
18.00
3.30
.03
MET SCRUBBING
LIMESTONE
RILEV STOKER/ENVIRONEERING
NEK
2.9
9/76
8/7?
85.00
99.80
1.0
CLOSED
37.8
LINED POND
C 600 GPM)
. PERFORMANCE DAT*
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/78
A
B
C
0
SYSTEM
27.0
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
744 706 151 66.0
* PROBLEMS/SOLUTIONS/COMMENTS
>
START DATE 12/78 END DATE 12/78
ISOLATION DAMPER FAILURES AND SLURRY RECYCLE DISCHARGE VALVE FAILURES
OCCURRED DURING DECEMBER.
START DATE 12/78 END DATE 12/78
LIMESTONE MILL PROBLEMS AND PLUGGED LIMESTONE FEEDER HAMPERED SCRUBBER
OPERATIONS DURING DECEMBER.
START DATE 12/78 END DATE 12/78
FROZEN INSTRUMENT CONTROL LINES HERE A PROBLEM.
1/79
A
e
c
D
SYSTEM
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
744 738
46
-------
CENTRAL ILLINOIS LIGHT
EPA UTHITY FGD SURVET: SECOND QUARTER 1979
DUCK CREEK 1 (CONT.)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERAPILITY RELIABILITY UTILI7ATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
* PR06LEMS/SOLUTIONS/COMMENTS
START DATE 1/79 END DATE 1/79
FROZEN INSTRUMENT CONTROL LINES, RECYCLE TANK SUCTION LINES, MAIN MODULE
DRAIN LINES AND MIST ELIMINATOR DRAIN LINES MERE MAJOR PROBLEM AREAS
DURING JANUARY.
START DATE 1/79 END DATE 1/79
SLURRY RECYCLE VALVE PLU66A6E AND SLURRY TRANSFER PUMP FAILURE CONTRIBUTED
TO THE SYSTEM OUTA6E TIME.
2/79
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 5?3
0 80.5
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 2/79
RECYCLE PUMP SUCTION VALVE FAILURES AND A SLURRY TRANSFER PUMP FAILURE
CONTRIBUTED TO THE NON-OPERATION OF THE FGD SYSTEM.
START DATE 2/79 END DATE 2/79
FROZEN MIST ELIMINATOR DRAINS, ABSORBER DRAINS AND INSTRUMENT LINES WERE
A MAJOR PROBLEM DURING FEBRUARY.
3/79
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
70
PROBLENS/SOLUTIONS/COMMENTS
START DATE 3/79 END DATE 3/79
FREEZING PROBLEMS CONTINUED TO HAMPER F6D OPERATIONS DURING MARCH.
START DATE 3/79 END DATE 3/79
BROKEN HIST ELIMINATOR SPRAY LINES AND PLUGGED "1ST ELIMINATOR NOZZLES
HERE PROBLEM AREAS DURING MARCH.
START DATE 3/79 END DATE 3/79
RECYCLE PUMP FAILURES AND WASTE MATER PUMP FAILURES WERE EXPERIENCED
DURING MARCH.
START DATE 3/79 END DATE 3/79
PLUGGED SLURRY NOZZLES AND GENERAL INSTRUMENTATION PROBLEMS MERE REPORTED
BY THE UTILITY.
4/79
A
B
C
D
SYSTEM
100.0
84.3
06.5
21.3
73.0
71.9
50.5
B1.2
22.7
56.4 72.0
67.3
47.3
76.0
21.3
53.0
720 674
80
PROBLENS/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 WERE REPORTED BY THE UTILITY.
START DATE 4/79
END DATE 4/79
RECYCLE TANK MIXER FAILURES HERE EXPERIENCED DURING APRIL.
47
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
CENTRAL ILLINOIS LIGHT DUCK CREEK
(CONT.)
-- .... PERFORMANCE DATA ~
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
START DATE 4/79 END DATE 5/79
RECYCLE PUMP BELT AND BEARING FAILURES AND SLURRY SUPPLY LINE FAILURES
WERE REPORTED BY THE UTILITY.
5/79 A 95.7 37.4 1.3
11.7
11.1
1.3
51.* 8.5 7*4 197 63
PROBLE4S/SOLUTIONS/COMHENTS
START DATE 5/79 END DATE 5/79
HIST ELIMINATOR PUMP MALFUNCTIONS MERE REPORTED DURING MAY.
START DATE 5/79 END DATE 5/79
HILL SHAKER BASKET DRIVE MOTOR FAILURES WERE ENCOUNTERED.
A
B
C
D
SYSTEM
95.7
95.7
94.6
1.3
71.9
37.*
**. 2
41.8
5.0
32.1
-------
EPA UTILITY FGD SURVEY: SECOND 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 U/FGD
EQUIVALENT SCRUBBED CAPACITY - MU
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - X
COLUMBUS K SOUTHERN OHIO ELEC.
CONESVILLE
5
CONESVILLE
OHIO
411.0
375.0
411.0
COAL
BITUMINOUS
25237.
15.10
7.50
4.67
* *******
( 10850 BTU/LP)
* FGD 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 - X
ABSORBER SPARE COMPONENTS INDEX
WET SCRUBBING
LIKE
AIR CORRECTION DIVISION, UOP
NEW
3.9
1/77
2/77
8". 50
99.60
.0
.0
WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
OPEN
31.5
( 500 GPt)
** TREATMENT
TYPE
* DISPOSAL
TYPE
P07-0-TEC
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x 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
* PROBLE'S/SOLUTIONS/COMNENTS
START DATE
2/79 END DATE 2/79
THE SYSTEM DID NOT OPERATE DURING FEBRUARY BECAUSE OF SEVERE WINTER WEATHER
3/79
4/79
A
e
SYSTEM
A
B
SYSTEM
so.o
.0
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
PROBLE1S/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.
49
-------
EP» UTILITY F6D SURVEY: SECOND QUARTER 1979
COLU'BUS I SOUTHERN OHIO EL EC. CONESVILLE
(CONT.)
E»IOD NODULE AVAILABILITY
5/79 A
B
SYSTE"
OPERA8IL1TV
.0
.0
.0
PERFORMANCE DATA
RELIABILITY UTILIZATION
' .0
.0
.0
X REMOVAL PER BOILER F«D
S02 PART. HOURS HOURS HOURS
7*4 744 0
CAP.
FACTOR
* PROBLE4S/SOLUTIONS/CONNENTS
START DATE 5/79
START DATE
END DATE 5/79
REPAIRS WERE MADE TO THE SEAL BETWEEN THE THICKENER BASE AND SIDEWALL.
5/79 END DATE 5/79
THE FED SYSTEM HAS DOWN DURIN6 NAY FOR AN ANNUAL OUTAGE.
6/79
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
PRObLENS/SOLUTIONS/COMNENTS
START DATE 5/79 END DATE 6/79
PLUGGED PH LINES WERE A PROBLEM DURING HAY AND JUNE.
START DATE 5/79 END DATE 6/79
FLYASH CONVEYING PROBLENS RESULTED IN ABOUT 2 DAYS OUTAGE.
START DATE 6/79 END DATE 6/79
OUTLET DANPER PROBLEMS WERE REPORTED BY THE UTILITY.
50
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/F6D - PW
EQUIVALENT SCRUBBED CAPACITY - MW
FUEL DATA
FUEL TYPt
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
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
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
« HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
TREATMENT
TYPE
* DISPOSAL
TYPE
- X
COLUMBUS t SOUTHERN OHIO ELEC.
CONESVILLE
6
CONESVILLE
OHIO
411.0
175.0
411.0
( 10850 BTU/L6)
COAL
BITUMINOUS
25237.
15.10
7.50
4.67
MET SCRUBBING
LIME
AIR CORRECTION DIVISION, UOP
NEW
3.9
6/7?
*/**
89.50
99.60
.0
.0
OPEN
31.5
POZ-0-TEC
LANDFILL
C 500 GP»)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPEPAB1LITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
2/79 A
B
SYSTEM
.0
.0
.0
.0
.0
.0
.0
.0
.0
PROBLEMS/SOLUTIONS/COMMENTS
672
START DATE
3/79
A
B
SYSTEM
4/79 A
B
SYSTEM
5/79 A
B
SYSTEM
43.0
32.0
37.5
82.0
72.0
77.0
2/79 END DATE 2/79
THE FGD SYSTEM DID NOT OPERATE DURING FEBRUARY DUE TO SEVERE WINTER HEATHER
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
33.0
25.0
29.0
78.0
58.0
68.0
.0
.0
.0
744 664 216
720 711 489
744 0
51
-------
EPA UTILITY FGD SURVEY: SECOND CUARTER 1979
COLUMBUS I SOUTHERN OHIO ELEC. CONESVILLE 6
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - *U
NET UNIT GENERATING CAPACITY U/F6D - flu
EQUIVALENT SCRUBBED CAPACITY - HW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - t
AVERAGE CHLORIDE CONTENT - X
* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
MATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
* TREATMENT
TYPE
DISPOSAL
TYPE
DUQUESNE LIGHT
- X
1-4
ELPAMA
PENNSYLVANIA
510.0
475.0
510.0
COAL
*«*
26400.
21.00
**
2.20
**«
WET SCRUBBING
LIME
CHEMICO
RETROFIT
3.5
10/75
10/75
83.00
99.00
35.0
1.3
OPEN
POZ-0-TEC
LANDFILL
1 11350 BTU/LB)
(« 6P")
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER OILER F6D CAP.
S02 PART. HOURS IOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
PROBLEMS/SOLUTIONS/COMMENTS
672
74*
4/79 SYSTEM
5/79 SYSTEM
6/79
START DATE 2/79 END DATE 3/79
NO INFORMATION HAS REPORTED BY THE UTILITY FOR THIS REFOfT PERIOD.
720
744
720
SYSTEM
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 4/79 END DATE 6/79
NO INFORMATION WAS AVAILABLE FROM THE UTILITY FOR THI) PERIOD.
53
-------
EPA UTILITY'FbD SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
»LAHT NAME
1NIT NUMBER
ITY
TATE
OSS UNIT GENERATING CAPACITY - Mh
NT UNIT GENERATING CAPACITY W/FGD - *b
EUIVALENT SCRUBBED CAPACITY - *w
*FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
\VERA6E SULFUR CONTENT - X
VERA6E CHLORIDE CONTENT - X
?6 SYSTEM
6MERAL PROCESS TYPE
PKJCESS TYPE
SYTEH SUPPLIER
NE/RETROFIT
ENR6Y CONSUMPTION - X
IN71AL START-UP DATE
COftERCIAL START-UP DATE
S02DESI6N REMOVAL EFFICIENCY - X
PARICULATE DESIGN REMOVAL EFFICIENCY
ABSfcBER SPARE CAPACITY IKDEX - X
ABS(»eER SPARE COMPONENTS INDEX
HATER LOOP
TYPE
FRESHHAKE-UP HATER - LITER/S
TREATMfcT
TYPE
DISPOSAL
TYPE
- X
DUQUESNE LIGHT
PHILLIPS
tL-6
SOUTH HEIGHT
PENNSYLVANIA
410.0
377.0
410.0
COAL
BITUMINOUS
26400.
18.20
*****
2.20
**
WET SCRUBBING
LIME
CHEMICO
RETROFIT
2.4
7/73
*/
83.00
99.00
18.0
.6
OPEN
*
POZ-0-TEC
LANDFILL
( 11350 BTU/LB)
(*** 6PM)
, PERFORMANCE DATA
PERIOD NODULE AfclLABILITV OPERA6ILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
3/79
SYSTEM
SYSTEM
PROBLEMJ/SOLUTIONS/COHMENTS
672
744
S1ART DATE 2/79 END DATE 3/79
NO INFORMATION WAS REPORTED BY THE UTILITY FOR THIS REPORT PERIOD.
4/79
5/79
6/79
SYSTEM
SYSTEM
SYSTEM
PROBLEtS/SOLUTIONS/COMMENTS
STAR DATE
720
744
720
4/79 END DATE 6/79
NO INFORMATION WAS AVAILABLE FROM THE UTILITY FOR THIS PERIOD.
54
-------
EPA UTILITY FGD SURVEY: SECOND 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 W/F60 - Mb
EQUIVALENT SCRUBBED CAPACITY - MM
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - t
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
PARTICUtATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
MATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
* BYPRODUCT
IVPRODUCT NATURE
DISPOSITION
- X
( 12500 BTU/LB)
GULF POWER
SCHOLZ
1,2
SNEADS
FLORIDA
27.0
21.0
23.0
COAL
BITUMINOUS
29075.
11.00
5.00
2.50
»*»*
rfET SCRUBBING
LIMESTONE/THOROUGHBRED 121
CHIYODA INTERNATIONAL
RETROFIT
**««*
8/78
**/*
90.00
99.50
.6
CLOSED
*****
(*** 6PN)
GYPSUM
STACKED IN POND
. . PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
3/79
4/79
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
98.J
100.0
100.0
100.0
100.0
98. 4
100.0
100.0
672
744
720
672
744
720
661
744
720
5/79
6/79
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/79
ONE PUMP FAILURE CAUSING A 5 MINUTE OUTAGE HAS REPORTED BY THE UTILITY.
START DATE 4/79 END DATE 4/79
HIGH PARTICULATE LOADING TESTS HERE DONE IN APRIL. THE ESP WAS TOTALLY
SHUT DOWN. THE 502 REMOVAL WAS NOT AFFECTED BUT THE GYPSUM PRODUCT WAS
TEMPORARILY AFFECTED. HIGH CHLORIDE TESTS WERE ALSO PERFORMED BY ADDING
CALCIUM CHLORIDE TO THE SYSTEM. A RESULTANT CONCENTRATION OF 6000 PP"
CHLORIDE HAS FOUND IN THE UNDERFLOW. NO SIGNIFICANT SCALING WAS ENCOUNT-
ERED.
SYSTEM
SYSTEM
720
55
-------
F.PA UTILITY FGD SURVEY: SECOND QUARTER 1079
6ULF POWER SCHOLZ 1,2 (CONT.)
. PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 6/79
THE FGD SYSTEM OPERATED THROUGH THE 24TH OF HAY WHEN THE SYSTEM WAS RF-
MOVED FROM SERVICE BECAUSE THE EPRI STUDIES MERE COMPLETED.
JUNE:
AFTER SHUTDOWN THE UNIT HAS MODIFIED TO SIMULATE A SMALLER JET BUBBLER
REACTOR WITH THE SAME AMOUNT OF FLUE CAS. THIS HAS DONE 8V PLUGGING SOME
OF THE SPARGERS AND RISER TUBES. THE UNIT WAS OPERATED LIKE THIS FROM
JUNE 8 UNTIL JUNE 29 WITH RESULTS THAT INDICATED SLIGHTLY REDUCED REMOVAL
EFFICIENCIES BUT NOT OUT OF THE REALM OF COMPLIANCE. DURING THE 21 DAYS
OF OPERATION THE UNIT WAS DOWN ONLY ONCE FOR NINE HOURS FOR ROUTINE IN-
SPECTION.
DURING THE EPRI STUDY A TOTAL OF 4448 HOURS OF OPERATION WERE LOGGED WITH
A TOTAL OF 123.3 HOURS OF SHUTDOWN. THE AVERAGE AVAILABILITY FOR SI I
MONTHS WAS 99.53X.
ALL STUDIES ARE NOW OVER AND THE SYSTEM HAS BEEN TERMINATED.
56
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F60 SYSTEMS
COMPANY NAME
PLAIT NINE
UNIT NUMBER
CITY
STATE
GROSS UK IT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - MU
EQUIVALENT SCRUBBED CAPACITY - «U
FUEL DATA
, FUEL TYPE
FUEL 6RADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
soz DESIGN'REMOVAL EFFICIENCY -x
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
DISPOSAL
TYPE
- I
INDIANAPOLIS POhER ( LIGHT
PETERSBURG
7
PETERSBURG
INDIANA
532.0
515.0
532.0
( 10750 BTU/LP)
COAL
BITUMINOUS
25004.
* ****
«*** *
T.25
****«*
VET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEW
2.4
12/77
* /**
85.00
99.30
.6
CLOSED
55.6
P07-0-TEC
POND
( 882 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
672
* PROBLEHS/SOLUTIONS/COMMENTS
J
START DATE 2/79 END DATE 2/79
THE UTILIZATION FIGURES GIVEN BELOy ARE FOR THE PERIOD SEPTEMBER-DECEMBER
1978.
3/79 A
B
C
D
SYSTEM
31.2
30.0
48.0
48.0
39.0
744
715
* PROBLEMS/SOLUTIONS/COMMENTS
START DATE 1/79 END DATE 3/79
THE F6D SYSTEM MAS DOWN FROM JANUARY 1 TO MARCH 15 DUE TO SEVERE WINTER
VEATHER.
4/79 SYSTEM '22
57
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
INDIANAPOLIS POUER I LIGHT PETERSBURG
-------
EPA UTILITY FED SURVEY: SECOND QUARTER 1979
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/F6D MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 2
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 - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
* MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* TREATMENT
TYPE
* DISPOSAL
TYPE
KANStS CITY POWER » LIGHT
HAWTHORN
5
KANSAS CITY
MISSOURI
90.0
85.0
90.0
< 9800 BTU/LB)
COAL
BITUMINOUS
22?95.
11.00
*«»
.60
*»**«
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
11/72
»* /
70.00
99.00
.6
CLOSED
*** *
FLYASH STABILIZED
POND
. .. _ . ... -PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
PROBLEMS/SOLUTIONS/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
PR06LE1S/SOLUTIONS/COMMENTS
1P.1
720 1?0
130 9.0
START DATE 4/79 END DATE 4/79
THE BOILER WAS DOWN IN APRIL FOR 543 HOURS FOR TURBINE OVERHAUL.
5/79 SYSTEM 55.0 100.0
*» PRObLEKS/SOLUTIONS/COHMENTS
55.0
744 409
409 29.0
START DATE 5/79 END DATE 5/79
IN NAY THE OUTAGE TIME MAS DUE TO BOILER TUBE LEAKS.
6/79 SYSTEM
720 696
59
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
KANSAS CITT POWER t LIGHT HAWTHORN 3 (CONT.)
- _ -PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
PROeLEKS/SOLUTIONS/COftMENTS
START DATE 6/79 END DATE 6/79
THE ONLY COMMENT REPORTED BY THE UTILITY HAS THAT NO REAL PROBLEMS WERE
EXPERIENCED DURIN6 JUNE.
60
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOP OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY V/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - MW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - I
F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
* HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
* TREATMENT
TYPE
DISPOSAL
TYPE
KANSAS CITY POWER t LIGHT
HAWTHORN
4
KANSAS CITY
MISSOURI
90.0
85.0
90.0
( 9800 BTU/LB)
COAL
BITUMINOUS
22795.
11.00
*****
.60
***«
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
8/72
*/
70.00
99.00
.6
CLOSED
*
(*» 6PM)
FLVASH STABILIZED
POND
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
3/79
SYSTEM
SYSTEM
* PROBLEMS/SOLUTIONS/COMMENTS
672
744
START DATE 1/79 END DATE 3/79
OPERATING INFORMATION FOR UNIT 4 IS STILL NOT AVAILABLE.
4/79 SYSTEM 57.0 100.0
PROBLE1S/SOLUTIONS/COMMENTS
57.0
720 410
410 30.0
START DATE 4/79 END DATE 4/79
AN EXCITER FAILURE ON THE GENERATOR CAUSED THE APRIL OUTAGE TIME.
5/79 SYSTEM 94.0 100.0
PROBLE1S/SOLUTIONS/COMENTS
94.0
744
699
699 49.0
START DATE 5/79 END DATE 5/79
NAY OUTAGE TIME WAS FOR SCRUBBER CLEANING AND GENERAL MAINTENANCE.
6/79 SYSTEM 720 101
61
-------
EPA UTILITY F60 SURVEY: SECOND QUARTER 1979
(ANSAS CITY POWER K LIGHT HAWTHORN * (CONT.)
... ... . . PERFORMANCE OAT A -
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION s REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
PRObLEJS/SOLUTIONS/COflNENTS
START DATE 6/79 END DATE 6/79
THE ONLY REPORTED COPHENT FPOM THE UTILITY WAS THAT THE LOU BOILER HOURS
WERE THE RESULT OF A SCHEDULED BOILER OVERHAUL.
62
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NU1BER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - MH
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
** HATER LOOP
TYPE
FRESH MAKE-JP WATER - LITER/S
DISPOSAL
TYPE
- X
KANSAS CITY POWER t LIGHT
LA CVGNE
1
LA CVGNE
KANSAS
874.0
820.0
874.0
COAL
SUPBITUHINCUS
21913.
24.36
8.60
5.39
.03
MET SCRUBBING
LIMESTONE
BABCOCK t UILCOX
NEW
2.7
2/73
6/73
80.00
99.50
.6
( 9421 BTU/LP)
CLOSED
72.3
UNLINED POND
( 1148 6P»)
___» _ PERFORMANCE DATA
BERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER FGD
HOURS HOURS HOURS
CAP.
FACTOR
2/79 A
B
C
0
E
F
G
H
SYSTEM
3/79
A
B
C
0
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
95.7
93.4
95.2
672 342
744 314
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 3/79
NO MAJOR FGD SYSTEM PROBLEMS WERE REPORTED BY THE UTILITY FOR FEBRUARY OR
MARCH.
63
-------
EPA UTILITY F6» SURVEY: SECOND QUARTER 1979
(ANSIS CITY POWER t LIGHT LA CY6NE
(CONT.)
.....PERFORMANCE BATA
PERIOD MSDULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART,
PER BOILER F6D
HOURS HOURS HOURS
CAP.
FACTOR
START DATE
4/79
5/79
A
B
C
D
E
F
e
H
SYSTEM
A
B
C
D
E
F
6
H
SYSTE"
95.5
95.7
94.4
91.4
95.5
96.2
95.9
95.7
95.0
96.5
96.3
96.7
95.3
95.4
95.7
96.3
95.5
96.0
2/79 END DATE 3/79
THE UTILITY HAS REPORTED THAT MANY TUBE LEAKS AND CYCLONE LEAKS HERE
EXPERIENCED WITH THE BOILER.
720 636
744 476
PROBLE4S/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 5/79
THE UTILITY REPORTED THAT NO MAJOR F6D PROBLEMS HAD OCCURRED.
6/79 SYSTEM
« PROBLE*S/SOLUTIONS/COMMENTS
720
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.
64
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/FGD - Mb
EQUIVALENT SCRUBBED CAPACITY *U
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t
ABSORBER SPARE COMPONENTS INDEX
* HATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
* TREATMENT
TYPE
* DISPOSAL
TYPE
- X
KANSAS POWER K LIGHT
JEFFREY
1
WAME60
KANSAS
720.0
680.0
540.0
( 8125 BTU/LP)
COAL
******
18899.
5.60
30.00
.32
.01
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
NEW
*******
8/78
**/**
80.00
99.00
20.0
1.0
CLOSED
35.1
NONPROPRIETARV
POND
( 557 6P»)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
672
74*
720 0 0 .0
744 0 0 .0
PROBLEMS/SOLUTIONS/COMMENTS
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
* PROBLENS/SOLUTIONS/COMMENTS
START DATE
720
6/79 END DATE 6/79
THE UTILITY REPORTED THAT THE UNIT RETURNED TO SERVICE TNE FIRST KEEK OF
JUNE AND SUFFERED NO OPERATIONAL DIFFICULTIES SINCE RESTART.
65
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
* FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* TREATMENT
TYPE
DISPOSAL
TYPE
- Z
KANSAS POWER I LIGHT
LAWRENCE
4
LAWRENCE
KANSAS
125.0
115.0
125.0
( 10000 BTU/LB)
COAL
23260.
9.80
********
.55
.03
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
***** »
1/76
*/*
73.00
98.90
.0
.0
CLOSED
*******
(**«*
FORCED OXIDATION
POND
_ _ . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
Z REMOVAL
S02 PART.
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
3/79 SYSTEM
744
» PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 3/79
UNIT * EXPERIENCED A MOTOR FAILURE ON AN I.D. FAN DURING THE FEBRUARY-
MARCH PERIOD.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM
PROBLEHS/SOLUTIONS/COMHENTS
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.
66
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FCD SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
EPOSS USIT GENERATING CAPACITY - Mfc
NET UNIT GENERATING CAPACITY h/FGD - Mh
EQUIVALENT SCRUBBED CAPACITY MH
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO2 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
* HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
TREATMENT
TYPE
DISPOSAL
TYPE
KANSAS POME* fc LIGHT
LAHRENCE
5
LAURENCE
KANSAS
420.0
400.0
420.0
( 10000 8TU/LB)
COAL
*
23260.
9.80
***** **
.55
.03
HET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
******
11/71
/
52.00
9P.90
.0
.0
CLOSED
**
|****« 6PM)
FORCED OXIDATION
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
5/79 SYSTEM
* PROBLEMS/SOLUTIONS/COMMENTS
672
744
720
744
744
START DATE 5/79 END DATE 5/79
THE UNIT HAS BROUGHT DOHN TO 1/2 CAPACITY FOR A SCHEDULED 3 HEEK
OUTAGE TO REBUILD AN AIR PREHEATER FAN MOTOR.
6/79 SYSTEM
67
-------
?PA UTILITY FGD SURVEY: SECOND QUARTER 1979
CANSAS POWER I LIGHT LAWRENCE
(CONT.)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
« PROBLE4S/SOLUTIONS/COHMENTS
START DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT THE SYSTEM RAN WELL. THE ONLY F6D SYSTEM RELATED
OUTAGES WERE DUE TO MIXER FAILURE AND GENERAL MAINTENANCE.
68
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - MU
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - I
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEb/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t
ABSORBER SPARE COMPONENTS INDEX
* riATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* DISPOSAL
TYPE
- I
KENTUCKY UTILITIES
GREEN RIVER
1-3
CENTRAL CITY
KENTUCKY
64.0
60.0
64.0
COAL
BITUMINOUS
35586.
17.40
12.10
4.00
***** **
riET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
3.1
9/75
6/76
80.00
99.50
.0
.0
( 11000 BTU/Lp)
CLOSED
4.7
LINED POND
I 75 6PM)
. PERFORMANCE DATA
"ER100 MODULE AVAILABILITY OPERAPIL1TT RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM .0
* PROBLEMS/SOLUTIONS/COMMENTS
.0
.0
672
.0
START DATE 1/79 END DATE 2/79
THE PROBLEMS IN JANUARY AND FEBRUARY HERE A RESULT OF FREEZING UEATHEP.
3/79 SYSTEM 11.2 100.0
PROBLEMS/SOLUTIONS/COMMENTS
100.0
11.2
7*4 83 83
START DATE 3/79 END DATE 4/79
THE LOW OPERATIONAL HOURS FOR MARCH AND APRIL MERE DUE TO RECYCLE PUMP
PROBLEMS.
4/79 SYSTEM 18.2 100.0
5/79 SYSTEM
PR06LEMS/SOLUTIONS/COMMENTS
100.0
18.2
.0
720 131 131
744 0 0 .0
START DATE 5/79 END DATE 5/79
THE BOILER WAS TAKEN DOWN IN MAY FOR REPAIRS THAT ARE PROJECTED TO LAST
THROUGH THE END OF SEPTEMBER.
6/79 SYSTEM
.0
720
.0
69
-------
EPA UTILITY F6» SURVEY: SECOND QUARTER 1979
KENTUCKY UTILITIES GREEN RIVER 1-3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABXLITV RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
* PROBLEVS/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
THE UNIT REMAINED OUT OF SERVICE DURING JUNE FOR BOILER REPAIRS. IT is
NOT EXPECTED TO RETURN TO SERVICE UNTIL OCTOBER OR NOVEMBER.
ro
-------
EPA UTILITY
SURVEY: SECOND QUARTER 1979
SECTION 3
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/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - MW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
* 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
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
* HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
- X
LOUISVILLE 6*S » ELECTRIC
CANE RUN
4
LOUISVILLE
KENTUCKY
188.0
175.0
188.0
COAL
BITUMINOUS
2674
-------
UTILITT F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY k/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
TREATMENT
TYPE
* DISPOSAL
TYPE
K ELECTRIC
- X
LOUISVILLE GAS
CANE RUN
5
LOUISVILLE
KENTUCKY
190.0
180.0
190.0
COAL
BITUMINOUS
26749.
17.10
9.00
3.75
.04
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
1.«
12/77
5/79
85.00
99.00
.0
.0
( 11500 BTU/LE)
OPEN
»*«*
POZ-0-TEC
LINED POND
(*****
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 70.6
PROBLEMS/SOLUTIONS/COMMENTS
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/COMMENTS
57.5
49.6
744 596
720 360
428
357
START DATE 2/79 END DATE 4/79
SOME PROBLEMS WERE EXPERIENCED WITH DAMPERS AND THERE WERE PUMP FAILURES.
5/79 SYSTEM
6/79 SYSTEM
84.3
77.0
49.1
58.2
744 433
720 544
365
419
72
-------
EPA UTILITY FGO SURVEY: SECOND OUARTER 1979
LOUISVILLE 6AS I ELECTRIC CANE RUN 5 (CONT.)
» -. . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
* PROBLEIS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 6/79
THE ONLY PROBLEMS REPORTED BY THE UTILITY WERE SPRAY PUMP PACKIN6 FAILURES
AND HELDIN6 FAILURES ON THE REHEATER.
73
-------
FPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
OES16N AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PAfiTICULATE EMISSION LIMITATION - Nt/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - Mb
GROSS UNIT GENERATING CAPACITY - P"b
NET UNIT GENERATING CAPACITY W/FGD - fb
NET UNIT GENERATING CAPACITY bO/FGD - Mb
EQUIVALENT SCRUBBED CAPACITY - «b
90ILER 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 f
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANSE HEAT CONTENT - BTU/LE
AVERAGE ASH CONTENT - Z
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT Z
AVERAGE CHLORIDE CONTENT - X
RANSE CHLORIDE CONTENT X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - *b
* ESP
NUMBER
TYPE
PARTICULATE DESIGN REMOVAL EFFICIENCY
F6D SYSTEM
SALEABLE PRODUCT/THROMAWAV PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
SO2 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
CONTRACT AbARDEO
ABSORBER SPARE CAPACITY INDEX - S
ABSORBER SPARE COMPONENT INDEX
ABSORBER
NUM9ER
TYPE
INITIAL START UP
SUP»LIER
NUMBER OF STACES
BOILER LOADMESORBER - X
GAS TEMPERATURE - C
L/6 RATIO - L/CU.M
SUPERFICAL 6AS VELOCITY - M/SEC
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONTRATION - PPM
g ELECTRIC
( .116 LP/MMBTU)
( 1.200 LP/MMBTU)
LOUISVILLE GAS
CANE RUN
6
LOUISVILLE
KENTUCKY
A
50.
516.
"92.C
388.0
269.0
272.0
288.0
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
0/69
459.63 ( 974000 ACFM)
14E.9 ( 300 F)
15?. < 518 FT)
******* (** FT)
COAL
BITUMINOUS
25586.
17.10
15.5-24.5
9.00
£.0-10.75
4.80
3.5-6.J
.04
0.03-0.06
( 11000 BTU/LB)
10,400-11,900
(*« TPH)
COLD SIDE
- X 99.4
THROWAWAV PRODUCT
MET SCRUBBING
DUAL ALKALI
ADL/COMBUSTION EQUIP ASSOCIATE
FULL-SCALE DEMONSTRATION
RETROFIT
95.00
4/79
10/76
20.0
.3
TRAY TOWER
12/75
COMBUSTION EQUIPMENT ASSOCIATES
2
60.0
80.0 C 176 F)
1.3
2.7
3471
200
C 10.0 GAL/1000ACF)
C 9.0 FT/S)
74
-------
LOUISVILLE 6AS t ELECTRIC
EPA UTILITY F6D SURVEY: SECOND OUARTE* 1979
CANE RUN d (CONT.)
CENTRIFUGE
NUMBER
FANS
NUMBER
TYPE
CONSTRUCTION MATERIALS
* VACUUM FILTER
NUMBER
TYPE
CONSTRUCTION MATERIAL
OUTLET SOLIDS - X
VACUUM FILTER
NUMBER
TTPE
CONSTRUCTION MATERIAL
OUTLET SOLIDS - Z
NIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
* PUMPS
SERVICE
REACTOR PUMP
RECYCLE
RECYCLE [SPARE]
THICKENER HOLD TANK PUMP
THICKENER HOLD TANK PUMP CSPARE]
LIME SLURRY
LINE SLURRY CSPARE]
SODA ASH PU1P
S00» ASH PU4P CSPARE]
TANKS
SERVICE
PRIMARY REACTION TANK
SECONDARY REACTION TANK
FEED FORWARD TANK
FILTRATE SU4P
THICKENER HOLD TANK
THICKENER
NUMBER
CONSTRUCTION MATERIAL
DIA'ETER - »
OUTLET SOLIDS - X
HATER LOOP
TYPE
DISPOSAL
NATURE
TYPE
LOCATION
BOOSTER, CENTRIFUGAL
A441 CARBON STEEL
ROTARY-DRUM WITH WATER HASH
316 ss [FILTER DRUM], FRPUELT CLOTH}
63.0
1
ROTARY-DRUM WITH WATER WASH [SPARED
316 SS [FILTER DRUM], FRP [BELT CLOTH)
63.0
CHEVRON
POLYPROPYLENE
NUMBER
NUMBER
2
2
***
*
1
CONCRETE SHELL* CARBON STEEL INTERIOR, FLAKE DEI
38.1 C125 FT)
25.0
OPEN
FINAL
LINED POND
ON SITE
_ PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79 SYSTEM 43.3
PROBLEJS/SOLUTIONS/CONNENTS
37.9
62 475
237
START DATE 4/79 END DATE 4/79
THIS UNIT STARTED OPERATIN6 ON APRIL 4« 1979. COMPLIANCE TESTING IS
SCHEDULED FOR THE WEEK OF JUNE 3.
5/79 SYSTEM
21.5
14.7
744
506
109
75
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
LOUISVILLE CAS i ELECTRIC CANE RUN
(CONT.)
PERFORMANCE DATA
OERI9D NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
t REMOVAL
302 PART.
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
6/79 SYSTEM 12.3
PROBLEMS/SOLUTIONS/COMMENTS
10.3
720 601
START DATE 6/79 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 MIST ELIM-
INATORS. IT IS EXPECTED TO BE DOWN FOR A MONTH.
76
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION i
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - MH
EQUIVALENT SCRUBBED CAPACITY - Mh
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
* MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* TREATMENT
TYPE
DISPOSAL
TYPE
- X
LOUISVILLE GAS ft ELECTRIC
MILL CREEK
3
LOUISVILLE
KENTUCKY
442.0
420.0
442.0
COAL
BITUMINOUS
26749.
11.50
***
j.75
***
WET SCRUBBING
LIME
AMERICAN AIR FILTER
NEW
1.6
8/78
3/79
85.00
99.00
.3
( 11500 BTU/LE)
OPEN
9.4
( 150 6P»>
FLYASH/LIME STABILIZED
POND
_- __..._ PERFORMANCE DATA
ERXOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 18.0
3/79 SYSTEM 53.1
PROBLE1S/SOLUT10NS/COHMENTS
17.4
52.4
672 651
744 735
117
390
START DATE 3/79 END DATE 3/79
COMPLIANCE TESTING WAS PERFORMED DURING MARCH AND THE UNIT WAS DECLARED
COMMERCIAL.
4/79 'SYSTEM 63.6
PROBLE1S/SOLUTIONS/CONMENTS
44.4
720 503
320
START DATE 2/79 END DATE 4/79
THE ONLY PROBLEMS REPORTED WERE DAMPERS AND PUMP FAILURES.
5/79 SYSTEM
6/79 SYSTEM
97.8
51.9
64.7
47.9
744 492
720 665
481
345
77
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
LOUISVILLE 6AS t ELECTRIC HILL CREEK 3 (CONT.)
.. ...._ __......PERFORMANCE DATA -
ERIOO MODULE AVAILABILITY OPERABILITT RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
PROBLEMS/SOLUTIONS/COHNENTS
START DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT NO UNUSUAL OPERATING PROBLEMS MERE ENCOUNTERED.
78
-------
EPA UTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/F6D MW
EQUIVALENT SCRUBBED CAPACITY - MU
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTEXT - KJ/KG
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
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
** HATER LOOP
TYPE
FRESH MAKE-UP WATER - LJTER/S
TREATMENT
TYPE
* DISPOSAL
TYPE
LOUISVILLE GAS I ELECTRIC
PADDY'S RUN
6
LOUISVILLE
KENTUCKY
72.0
67.0
72.0
( 11500 BTU/LB)
COAL
«***
26749.
11.50
«*»****
2.50
****
UET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.8
4/73
»/*
90.00
99.10
.0
.0
CLOSED
7.1
( SO 6PM)
LIME STABILIZED
POND
_ . PERFORMANCE DATA
PERI3D NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/7? SYSTEM
3/79 SYSTEM
4/79 SYSTEM
100.0
100.0
100.0
.0
.0
.0
672
744
720
0
0
0
0
0
0
.0
.0
.0
5/79
6/79
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/79
THE UNIT WAS NOT OPERATED DURING THESE MONTHS BECAUSE OF LACK OF DEMAND.
SYSTEM 100.0
SYSTEM 100.0
PROBLEMS/SOLUTIONS/COMMENTS
.0
.0
744
720
0
0
0
0
.0
.0
START DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT THE UNIT DID NOT OPERATE DURING MAY OR JUNE DUE
TO INSUFFICIENT DEMAND.
79
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND. PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/F6D - MM
EQUIVALENT SCRUBBED CAPACITY - MM
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL STAHT-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
DISPOSAL
TYPE
- X
MINNKOTA POMER COOPERATIVE
MILTON R. YOUNG
2
CENTER
NORTH DAKOTA
440.0
40?.0
405.0
< 6SOO BTU/LB)
COAL
LIGNITE
15110.
6.50
38.00
.70
**»*
WET SCRUBBING
LIME/ALKALINE FLVASH
AOL/COMBUSTION EQUIP ASSOCIATE
NEW
1.6
9/77
6/78
85.00
99.60
.0
.0
OPEN
44.1
MINEFILL
( 700 6PM)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/79
A
B
SYSTEM
4.6
37.7
5.1
28.4
4.6
25.7
1488 1345
PROBLEftS/SOLUTIONS/COMMENTS
START DATE 12/78 END DATE 1/79
THE ABOVE 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-TOWER WAS OUT OF SERVICE TO REPAIR A BOOSTER FAN SERVO MECHANISM.
START DATE 12/78 END DATE 12/78
THE B-TOWER WAS OUT OF SERVICE DURING DECEMBER DUE TO PLUGGING OF THE
THICKENER UNDERFLOW BY RUBBER LINING. THE THICKENER HAS PUMPED OUT AND
REPAIRED.
START DATE 12/78 END DATE 1/79
THE B-TOWER WAS OUT OF SERVICE THROUGH JANUARY DUE TO A FAN MOTOR.
2/79 SYSTEM 672
80
-------
"INNKOTA POWER COOPERATIVE
ETA UTILITY F6D SURVEY: SECOND QUARTER 1979
'ILTON R. YOUNG 2 CCONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION I REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79
A
B
SYSTEM
PROBLEMS/SOLUTIONS/COMMENTS
1416 1034
START DATE
START DATE
START DATE
2/78 END DATE 3/78
THE ABOVE FIGURES ARE FOR THE PERIOD FEBRUARY THROUGH MARCH.
2/79 END DATE 3/79
A BOOSTER FAN MOTOR FIRE MAS EXPERIENCED.
2/79 END DATE 3/79
HOLES IN THE ABSORBER TflWER MERE REPAIRED.
4/79
5/79
STSTEM
A
B
SYSTEM
J.O
57.1
3.2
61.6
3.0
57.1
720
1464 1358
« PROBLEMS/SOLUTIONS/COMMENTS
START DATE
4/79 END DATE 5/7"
THE ABOVE FIGURES ARE FOR THE PERIOD APRIL THROUGH "AY.
6/79
A
B
SYSTEM
17.2
36.3
17.2
36.3
17.2
36.3
720 720
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
THE A-TOWER HAS 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 El-
CESSIVE AMOUNT OF HEAVY PARTICLES TO ENTER THE F6D SYSTEM RESULTING IN THE
PLUGGING OF SEVERAL LINES AND STOPPING THE THICKENER RAKE.
START DATE 6/79 END DATE 6/79
A TOWER WAS OUT OF SERVICE FOR WATER BALANCE PROBLEMS. TO UNPLUG BLEED LINE
FROM THE AbSORBER TOWER AND TROUBLES WITH THE VACUUM FILTERS. LIME «AS
USED FOR SEVERAL DAYS TO EASE THE HIGH SOLIDS PROBLEM.
B1
-------
?PA UTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mk
NET UNIT GENERATING CAPACITY W/FGD - "V
EQUIVALENT SCRUBBED CAPACITY »U
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - !
AVERAGE CHLORIDE CONTENT - X
F6D 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
MATER LOOP
TYPE
FRESH PARE-UP HATER - LITER/S
DISPOSAL
TYPE
- X
( 88*3 BTU/L6)
MONTANA POWER
COLSTRIP
1
COLSTRIP
MONTANA
360.0
332.0
360.0
COAL
SUBBITUMINOUS
20569.
8.60
23.90
.77
.01
WET SCRUBBING
LINE/ALKALINE FLTASH
AOL/COMBUSTION EQUIP ASSOCIATE
NEW
3.3
9/75
11/75
60.00
99.50
20.0
.5
CLOSED
23.3
POND
( 370 6PM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER F60 CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/78 SYSTEM 96.7
1/79 SYSTEM 97.6
2/79 SYSTEM 90.3
3/79 SYSTEM 97.3
4/79 SYSTEM
5/79 SYSTEM
6/79 SYSTEM
PR06LEMS/SOLUTIONS/COHMENTS
744
744
672
744
720
744
720
START DATE 4/79 END DATE 6/79
THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED WELL DURING THIS PERIOD
ALTHOUGH OPERATING PARAMETERS HERE NOT AVAILABLE.
82
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/F60 - MM
EQUIVALENT SCRUBBED CAPACITY - NW
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHL3RIDE CONTENT - X
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABS9RBER SPARE COMPONENTS INDEX
- X
* rfATEU LOOP
TYPE
FRESH MAKE-UP WATER
** DISPOSAL
TYPE
LITER/S
( 8843 BTU/Le)
MONTANA
COLSTRIP
c
COLSTRJP
MONTANA
T60.0
732.C
760.0
COAL
SUBBITUMINOUS
2056°.
P.60
27.90
.77
.01
WET SCRUBBING
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
NEW
3.3
5/76
10/7*
60.00
99.50
20.0
.5
CLOSED
22.3
POND
( 370 6P«)
PERFORMANCE DATA
»ERIDD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/73 SYSTEM 91.2
1/79 SYSTEM 94.3
2/79 SYSTEM 98.3
3/79 SYSTEM 94.3
4/79 SYSTEM
5/79 SYSTEM
6/79 SYSTEM
PROBLEMS/SOLUTIONS/COMMENTS
744
744
672
744
720
744
720
START DATE 4/79 END DATE 6/79
THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED WELL DURING THIS PERIOD
ALTHOUGH OPERATING PARAMETERS WERE NOT AVAILABLE.
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION I
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Ph
NET UNIT GENERATING CAPACITY W/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - *\t
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - T
AVERAGE SULFUR CONTENT - 2
AVERAGE CHLORIDE CONTENT - 2
«
* 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 - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
DISPOSAL
TYPE
( 12450 BTU/LP)
NEVADA POWER
REID GARDNER
1
MOAPA
NEVADA
125.0
110.0
12^.0
COAL
BITU"INOUS
28959.
£.00
****»*
.50
.05
WET SCRUBBING
SODIUM CARBONATE
ADL/COP&USTION EQUIP ASSOCIATE
RETROFIT
**«**
4/74
*/*
90.00
97.00
.0
.0
CLOSED
9.P
POND
( 155 6P»)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM 97.9 96.5
PRObLE'S/SOLUTIONS/COMNENTS
96.5
78.3
744 603 582
START DATE 3/79 END DATE 3/79
THE FGD SYSTEM WAS OFF TO UNPLUG VENTURI NOZZLES AND TO CLEAN SENSING
LINES. THE DOWNTIME WAS ABOUT 15 HOURS.
START DATE 3/79 END DATE 3/79
THE FED SYSTEM WAS OFF FOR ABOUT 146 HOURS FOR REPAIR OF BOILER TUBE
LEAKS.
4/79 SYSTEM 100.0 98.7
PROBLEMS/SOLUTIONS/COMMENTS
98.6
25.7
720 188 185
START DATE 4/79 END DATE 4/79
THE BOILER AND F6D SYSTEM WERE OFF FOR APPROXIMATELY 533 HOURS FOR SCHED-
ULED MAINTENANCE.
5/79 SYSTEM
99.8
74.4
74.4
27.5
744 Z75
84
-------
EPA UTILITY FED SURVET: SECOND QUARTEP 1979
NEVADA POWER REID GARDNER 1 (CONT.)
- » PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION I REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
* PROBLEIS/SOLUTIONS/COflRENTS
START DATE 5/79 END DATE 5/70
THE BOILER AND SCRUBBER HERE RETURNED TO SERVICE ON THE 22ND AFTER
MAINTENANCE.
START DATE 5/79 END DATE 5/79
THE BOILER WAS FORCED OUT OF SERVICE TO REPAIR A COAL LEAK ON THE *8
BURNER LINE.
6/79 STSTEB 97.7 95.1 95.2 84.7 720 6*1 610
PROBLEJS/SOLUTIONS/COHHENTS
START DATE 6/79 END DATE 6/79
A FEW DAYS OUTAGE TIME WAS REQUIRED TO REPAIR A BOILER TUBE LEAK.
START DATE 6/79 END DATE 6/79
OUTAGE TIME WAS REQUIRED TO UNPLUG A VENTURI LINE.
START DATE 6/79 END DATE 6/79
TRAY SPRAT VALVES WERE REPLACED DURING JUNE.
as
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F£D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - Mu
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
« FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABS9REER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
* WATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
* DISPOSAL
TYPE
( 12400 BTU/LB)
NEVADA POWER
REID GARDNER
2
MOAPA
NEVADA
125.0
110.0
12<.0
COAL
BITUMINOUS
28842.
8.00
***
.50
.05
WET SCRUBBING
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
RETROFIT
*******
4/7*
/*
90.00
97.00
.0
.0
CLOSED
9.8
POND
( 155 GPM)
-PERFORMANCE DATA
BERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTE" 9T.8 96.fr
* PRObLEIS/SOLUTIONS/COMMENTS
STACT DATE
96.6
69.2
744
686
665
3/79 END DATE 3/79
THE bOlLEP AND SCRUBBER HERE OFF FOR ABOUT TWO DAYS FOR REPAIR OF BOILER
TUBE LEAKS.
START DATE
3/79 END DATE 3/7<»
THE BOILER TRIPPED DUE TO HIGH FURNACE PRESSURE.
DObN SENSING LINES WERE CLEANED ON THE SCRUPBER.
4/75
SYSTEM 88.8
* PROBLEMS/SOLUTION
START DATE
95.9
96.0
BE.8
WHILE THE BOILER WAS
720 666 640
START CATE
4/7? END DATE 4/78
A HIGH PRESSURE ALARM ON THE SCRUBBER DUCT TRIPPED THE SCRUBBER OFF LINE.
THE SCRUBBER PRESSURE SENSING LINES WERE CLEANED. THIS OCCURRED TWICE
DURING THE MONTH OF APRIL.
4/76 END DATE 4/78
A CONTROL FOhER FAILURE OCCURRED CAUSING A SCRUBBER TRIP WHEN THE 10 KW
GENERATOR WAS PUT BACK IN SERVICE.
5/79 SYSTEP"
99.8
99.4
99.5
63.9
744
627
624
86
-------
NEVADA POUER
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
REID GARDNER 2 (CONT.)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION I REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
* PROBLEMS/SOLUTIONS/COMMENTS
6/79 SYSTEM
START DATE
START DATE
93.2
5/79 END DATE 5/79
THE BOILER HAS OUT OF SERVICE FOR ABOUT 5 DAYS TO REPAIR TUBE LEAKS.
5/79 END DATE 5/79
PRESSURE SENSING LINES ON THE SCRUEBER CONTROLS HERE CLEANED.
86.8
86.9
73.2
720 607
527
PROBLE'S/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
THE SCRUBBER WAS FORCED OUT OF SERVICE DUE TO VENTURI PUMP POUER LOSS.
START DATE 6/79 END DATE 6/79
SOME OUTAGE TIME HAS REQUIRED TO REPAIR VENTURI PUMP DISCHARGE VALVES.
START DATE 6/79 END DATE 6/79
SOME BOILER OUTAGE HAS REQUIRED DURING JUNE TO PEPAIR HIGH PRESSURE HEATER
TUBE LEAKS, TO HELD 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.
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL F60 SYSTEMS
COMPANY NAME
PLAUT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mh
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - MU
FUEL DATA
FUEL TYPE
FUEL CRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - £
AVERAGE MOISTURE CONTENT - 2
AVERAGE SULFUR CONTENT - J
AVERAGE CHLORIDE CONTENT - X
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
* WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
DISPOSAL
TYPE
NEVADA POVER
REID GARDNER
3
MOAPA
NEVADA
125.0
110.0
125.0
COAL
BITUMINOUS
28959. ( 12450 BTU/LP)
8.00
********
.50
.05
UET SCRUBBING
SODIUM CARBONATE
ADL/COM6USTION EQUIP ASSOCIATE
NEW
*******
6/76
7/76
85.00
99.00
.0
.0
CLOSED
9.8
POND
< 155 GP»)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
502 PART. HOURS HOURS HOURS FACTOR
3/79 SYSTEM 100.0 97.9
* PROBLEMS/SOLUTIONS/COMMENT?
100.C
67.7
744 246 241
START DATE 3/79 £ND DATE 3/79
THE BOILER AND FGD SYSTEM HERE OFF FOR ABOUT 2 DAYS TO REPAIR AND BALANCE
A BOILER I.D. FAN.
START D*TE 3/7? END DATE 3/79
THE BOILER AND FGD SYSTEM HERE OFF FOR ABOUT 19 DAT FOR SCHEDULED MAIN-
TENANCE.
4/79 SYSTEM 100.0 100.0
PROBLEMS/SOLUTIONS/COMMENTS
100.0
100.0
720 719 719
START DATE 4/79 END DATE 4/7"
NO OUTAGES HERE REPORTED FOF APRIL.
5/79 SYSTE"
98.7
97.7
97.7
97.5
744 742 725
88
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
EVA»A POWER REID GARDNER 3 (CONT.)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TV RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
PROBLEMS/SOLUTIONS/COMHENTS
START DATE 5/79 END DATE 5/79
THE SCRUBBER WAS INADVERTENTLY REMOVED FROM SERVICE FOR A FEU HOURS.
START DATE 5/79 END DATE 5/79
THE SCRUBBER PRESSURE SENSING LINES WERE CLEANED AFTER A BOILER TRIP
ON HI6H FURNACE PRESSURE.
6/79 SYSTEM 100.0 91.3 100.0 63.5 720 659 601
PBOBLE1S/SOLUTIONS/CONMENTS
START DATE 6/79 END DATE 6/79
SOME POILER OUTA6E WAS REQUIRED DURING JUNE TO REPAIR A BOILER TUBE LEAK.
START DATE 6/79 END DATE 6/79
THE SCRUBBER WAS OUT OF SERVICE WHILE REPAIRS WERE MADE ON THE FIRE WATER
SYSTEM.
89
-------
EPA UTILITY F6D SURVEY: SECOND 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 W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - Mb
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY IKDEX - t
ABSDRBER SPARE COMPONENTS INDEX
* rfATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
3VPRODUCT
BYPRODUCT NATURE
DISPOSITION
- X
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
GARY
INDIANA
115.0
115.0
115.0
COAL
******
25586.
********
11.00
3.50
*****
riET SCRUBBING
HELLMAN LORD
DAVY POWERGAS
RETROFIT
****
7/76
6/77
90.00
98.50
.0
.0
CLOSED
******
< 11000 BTU/LB)
(*«* 6PM)
ELEMENTAL SULFUR
PERFORMANCE DATA
ERIOD MODULE AV«ILA9ILITY OPEFABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
SYSTEM 7.0
PROBLEMS/SOLUTIONS/COPMENTS
1.0
1.0
72C
START DATE 2/79 END DATE 2/7°
THE boiLER OPERATED ON LOW SULFUR COAL FEBRUARY 1-12 AND HIGH SULFUR COAL
FEBRUARY 1i-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 2/7"
A POWER INTERRUPTION ON FEBRUARY 24 RESULTED IN LOSS OF SEAL WATER TO THE
EVA.PORATOR PUMP AND PACKING FAILURE. THE FGD SYSTEM REMAINED DOWN THROUGH
MARCH 2.
3/79
SYSTEM «7.0
PR06LEMS/SOLUTIONS/COMMENTS
START DATE
44.0
43.0
720
308
START DATE
3/79 END DATE 3/79
THE BOILER OPERATED ON HIGH SULFUR COAL DURING THE MONTH.
3/79 END DATE 3/79
THE FED SYSTEM WAS SHUT DOWN DUE TO HIGH LEAKAGE IN THE EVAPORATOR CIR-
90
-------
EPA.UTILITY FGD SURVEY: SECOND QUARTER 1979
10RTXERN INDIANA PUB SERVICE DEAN H. MITCHELL 11
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLAIT NAME
UNIT NU4BER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mh
NET UNIT GENERATING CAPACITY U/FGD - MW
EOUIVALENT SCRUBBED CAPACITY - MU
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT KJ/K6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
502 DESIGN REMOVAL EFFICIENCY - S
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
HATER LOOP
TYPE
FRESH MAKE-JP UATER - L1TER/S
« TREATMENT
TYPE
DISPOSAL
TYPE
- Z
NORTHERN STATES POWER
SHERBURNE
1
BECKER
MINNESOTA
740.0
700.0
7*0.0
( 8500 BTU/LB)
COAL
SU8BITUHINOUS
19771.
9.00
25.00
.80
.03
MET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
2.7
3/76
5/76
50.00
99.00
e.o
.9
CLOSED
*«***
FORCED OXIDATION
LINED POND
PERFORMANCE DATA
OERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
3/79
131
102
133
134
135
136
137
138
139
110
111
112
SYSTEM 89.0
131
132
133
134
135
136
137
78.0
73.0
70.0
76.0
50.0
91.0
92.0
92.0
75.0
77.0
66.0
93.0
61.0
£8.0
45.0
E6.0
94.0
71.0
91.0
7E.O
73.0
70.0
76.0
53.0
91.0
92.0
92.0
75.0
77.0
66.0
93.0
672 672 67.9
60.1
86.8
44.4
84.8
92.7
70.0
89. t
92
-------
NORTHERN STATES POWER
EPA UTILITY F6t> SURVEY: SECOND QUARTER 1979
SHERBURNE 1
-------
EPA UTILITY F6D SURVEY! SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
ttOSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY N/FGD - N«
EQUIVALENT SCRUBBED CAPACITY - MM
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHL3RIDE CONTENT - X
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL STAtT-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABS3RBER SPARE CAPACITY INDEX - t
ABSORBER SPARE COMPONENTS INDEX
KATE* LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
* TREATMENT
TYPE
* DISPOSAL
TYPE
NORTHERN STATES POWER
SHERBURNE
2
BECKER
MINNESOTA
7*0.0
700.0
740.0
C 8500 BTU/LB)
- X
COAL
SUBBITUMINOUS
19771.
9.00
25.00
.80
»***«
MET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEM
2.7
4/77
4/77
50.00
99.00
8.0
.9
OPEN
******* (**** 6PM)
FORCED OXIDATION
LINED POND
PERFORMANCE DATA
ERI3D MODULE AVAILABILITY OPEBABIL1TT RELIABILITY UTILIZATION
X REMOVAL
S02 PART,
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
2/79
231
232
234
235
206
237
238
239
210
211
212
SYSTEM
93.0
3/79 2D1
232
233
234
235
236
237
238
86.0
84.0
89.0
59.0
76.0
72.0
68.0
eo.o
75.0
92.0
65.0
£5.0
69.0
78.0
47.0
71.0
76.0
90.0
78.0
672 671
94
-------
10RTHERN STATES POWER
EPA UTILITY F60 SURVEY: SECOND OUARTER 1979
SHERBURNE 2 CCONT.>
.. PERFORMANCE DATA
ERI9D N9DULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION t REMOVAL PER BOILER F6D CAP.
$02 PART. HOURS HOURS HOURS FACTOR
4/79
5/7?
6/79
299
210
211
212
SYSTEM
50.0
85.0
57.0
86.0
91.0
PROBLE4S/SOLUTIONS/COMMENTS
7*4
744
SYSTEM
SYSTEM
START OATE
START OATE
99.0
95.0
2/79 END DATE 3/79
THE ONLY REAL PROBLEMS ENCOUNTERED DURING THIS PERIOD MERE PROBLEMS «ITH
WET COAL.
2/79 END DATE 3/79
THE RECYCLE PUMPS ARE BEING REPLACED WITH LARGER 8000 6PM WORTHIN6TON
PUMPS. DURIDG THIS PERIOD THE PUMPS HERE INSTALLED ON MODULES 204 AND
206.
720
744
717
263
PROBLEMS/SOLUTIONS/COMMENTS
STAIT DATE 5/79 END DATE 5/79
THE LOU BOILER HOURS IN NAY HERE DUE TO COMMENCEMENT OF THE ANNUAL BOILER
AND TURBINE INSPECTION.
START DATE 4/79 END DATE 5/79
ALL PIPING HAS BEEN CHANGED TO FIBERGLASS.
START DATE 5/79 END DATE 5/79
THE UTILITY rilLL NOW REPORT THE AVAILABILITY OF THE TOTAL SYSTEM ONLi.
SYSTEM 99.0
* PROBLE'S/SOLUTIONS/COMMENTS
START DATE
720
454
6/79 END DATE 6/79
THE ONLY PROBLEM REPORTED BY THE UTILITY WAS THE LOSS OF A BOILER SURGE
PUMP AFTER THE UNIT RESTARTED.
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL FCD SYSTEMS
COMPANY NAME
PLAWT NINE
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - "W
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTEKT - Z
F60 SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSJMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - S
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t
ABS3R9ER SPARE COMPONENTS INDEX
KATEP LOOP
TYPE
FRESH MAKE-JP HATER - LITER/S
TREATMENT
TYPE
DISPOSAL
TYpi
- Z
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
SHIPPINGPORT
PENNSYLVANIA
917.0
925.0
917.0
COAL
3ITUMINOUS
26749.
12.«0
7.00
3.00
**»***
WET SCRUBBING
LIME
CHEMICO
NEW
6.0
12/75
6/76
92.10
99.80
.0
.0
OPEN
*******
CALCILOX
LANDFILL
( 11500 BTU/LB)
(***
PERFORMANCE DATA
ERI3D MODULE AVAILABILITY OPEfABlLITT RELIABILITY UTILIZATION
Z REMOVAL PER BOILER FCD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
2/7?
3/79
4/79
5/7?
SYSTEM
SYSTEM
SYSTEK
SYSTEM
672
744
720
744
PR9BLEMS/SOLUTIONS/COKMENTS
START DATE 2/75 END DATE 5/7«
UNIT 1 IS CURRENTLY DOWN FOR BOILER OUTAGE.
START DATE 2/79 END DATE 5/79
SIX OF THE TWELVE FAN HOUSINGS HAVE BEEN CHANGED FROM CARBON STEEL TO
INCOLLOY 82S.
6/79 SYSTEM 92.0 4344
96
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
POWER BRUCE MANSFIELD 1 (CONT.)
- . . .........PERFORMANCE DATA-
ERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*» PROBLE4S/SOLUTIONS/COMHENTS
START DATE 1/79 END DATE 6/79
THE ABOVE 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 HERE A MAJOR PROBLEM AREA
DURING THE FIRST HALF OF 1979.
-------
:P* JTILITT FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT 6ENERAT1N6 CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - KW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
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 - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
rfATER LOOP
TYPE
FRESH MAKE-JP MATER - LITER/S
TREATMENT
TYPE
* DISPOSAL
TYPE
PENNSYLVANIA POKER
3RUCE "ANSF1ELO
Z
SHIPPINGPORT
PENNSYLVANIA
917.0
P25.0
917.0
COAL
9ITUMINOUS
26749.
12.90
7.00
3.00
*»***
rfET SCRUBBING
LIME
CHEMICO
NEW
6.0
7/77
10/77
92.10
99.80
.0
.0
OPEN
*******
CALCILOX
LANDFILL
( 11500 BTU/L9)
(****
PERFORMANCE DATA
9E»IDO NODULE AVAILABILITY OPEFABILITT RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79
3/79
4/73
SYSTEM
SYSTEM
SYSTEM
«* PRO£LE<&/SOLUTIONS/CC»MENTS
START DATE
672
744
720
1/79 END DATE 4/79
NO INFORMATION WAS REPORTED FOR THIS PERIOD BY THE UTILITY.
5/79
6/79
STSTEM
SYSTEM 85.8
PfiOBLEMS/SOLUTIONS/COMMENTS
744
4344
STA*T DATE 1/7t £ND DATE 6/79
THE ABOVE AVAILABILITY IS THE AVAILABILITY FOR JANUARY 1, 1979 THROUGH
BAY 31, 1975.
START DATE 1/79
END DATE 6/79
96
-------
EPA UTILITY F60 SURVEY: SECOND QUARTER 1979
PENNSYLVANIA POWER BRUCE MANSFIELD 2 (CONT.l
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
THE UTILITY REPORTED THAT SOME FAN PROBLEMS WERE RECENTLY ENCOUNTERED.
99
-------
SPA JTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Mu
NET UNIT GENERATING CAPACITY W/F6D - MH
EQUIVALENT SCRU9BED CAPACITY - MM
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 1
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLDRIDE CONTENT - Z
* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEM/RETROF1T
ENE»6Y CONSUMPTION - t
INITIAL STA«T-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - t
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABS3RBER SP«RE CAPACITY INDEX - t
ABSDRBER SPARE COMPONENTS INDEX
* rfATER LOOP
TYPE
FRESH PAKE-JP MATER - L1TER/S
3VPR3DUCT
»VP«ODUCT NATURE
DISPOSITION
- Z
PHILADELPHIA ELECTRIC
EDDVSTONE
1A
EDDYSTONE
PENNSYLVANIA
120.0
120.0
120.0
COAL
BITUMINOUS
31634.
9.*0
5.90
2.60
*
WET SCRUBBING
MAGNESIUM OXIDE
UNITED ENGINEERS
RETROFIT
****
9/75
9/75
90.00
99.00
.0
.0
( 13600 BTU/LB)
OPEN
SULFURIC ACID
( 132 6P«>
PERFORMANCE DATA
«ERI3D N3DULE AVAILABILITY OPERABILITr RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/7? SYSTEM 672
3/7? SYSTEM 74*
PRObLEMS/SOLUTIONS/COPRENTS
STA»T DATE 2/7<> END DATE 3/7«
NO INFORMATION WAS REPORTED FOR THIS REPORT PERIOD.
4/7? SYSTEM 720
5/7? SYSTE«I 744
6/7? SYSTEM 720
* PfiOtLEMS/SOLUTIONE/COMMENTS
STA«T DATE 6/79 END DATE 6/79
NO INFORMATION IS AVAILABLE FOR THIS PERIOD BUT SHOULD BE FOR THE NEXT
REPORT PERIOD.
130
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UHIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MU
EQUIVALENT SCRU3BED CAPACITY - MU
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABS9RBER SPARE CAPACITY INDEX - t
ABSORBED SPARE COMPONENTS INDEX
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
1
MATERFLOrf
NEW MEXICO
361.0
31*.0
361.0
- Z
COAL
******
18841.
22. 45
14.82
.80
*****
MET SCRUBBING
riELLNAN LORD
DAVY POUER6AS
RETROFIT
4.4
4/78
*/*
85. CO
99.50
33.0
1.0
( 8100 BTU/LB)
rfATER LOOP
TYPE
FRESH PAKE-UP VATER - LITER/S
9VPR9DUCT
iYPRODUCT NATURE
DISPOSITION
CLOSED
30.2
( 480 6P">
ELEMENTAL SULFUR
MARKETED
...._._.-._.._._____ -PERFORMANCE DATA
»E«I3D M3DULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
Z 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
720
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 1/79 END DATE 5/79
HOURS ARE NOT YET AVAILABLE BECAUSE THE UTILITY IS CONCENTRATING EFFORTS
ON OPERATION OF THIS NEU UNIT. THE UTILITY REPORTED THAT THE SCRUBBING
MODULES THEMSELVES ARE OPERATING FINE. ALSO THE CHEHICAL PLANT IS READY
AND THERE IS NO SYSTEM PLUGGING WHATSOEVER.
STA«T DATE 1/79 END DATE 5/79
THE MAJOR PROBLEM ENCOUNTERED MAS GYRATING FANS.
101
-------
SPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLA*T N«NE
UNIT NUMBER
CITY
STATE
CROSS U11T GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - HW
EQUIVALENT SCRUBBED CAPACITY - MU
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - i
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHL9RIDE CONTENT - X
FC» SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
soz DESIGN REMOVAL EFFICIENCY - t
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABS3R9ER SPARE CAPACITY IkDEX - I
ABS3RBER SPARE COMPONENTS INDEX
rfATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
BYPRODUCT
IVPRODUCT NATURE
DISPOSITION
- Z
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
rtATE'FLOU
NEW MEXICO
750.0
306.0
350.0
COAL
**
2093*.
22.45
14.82
.80
**
MET SCRUBBING
MELLMAN LORD
DAVY POUERGAS
RETROFIT
4.6
6/78
* */*
85.00
99.50
33.0
1.0
CLOSED
***«*
( 9000 BTU/LB)
(**.**
ELEMENTAL SULFUR AND SOD
MARKETED
. ..-PERFORMANCE DATA
ERI3D MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/7? SYSTEM
3/79 SYSTEM
4/79 SYSTEM
5/79 SYSTEM
672
744
720
720
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 1/79 END DATE 5/7«
HOURS ARE NOT YET AVAILABLE BECAUSE THE UTILITY IS CONCENTRATING EFFORTS
ON OPERATION OF THIS NE. UNIT. THE UTILITY REPORTED THAT THE SCRUBBING
MODULES THC'SELVES ARE OPERATING FINE. ALSO THE CHEMICAL PLANT IS READY
AND THERE IS NO SYSTEM PLUGGING WHATSOEVER.
START DATE 1/79 END DATE 5/79
THE M«JOR PROBLEM ENCOUNTERED WAS GYRATING FANS.
102
-------
EPA UTILITY FGO SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COM'ANV NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/F6D - "V
EQUIVALENT SCRUBBED CAPACITY - MW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - *
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - I
AVERAGE CHL3RIDE CONTENT - X
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEWSRETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
$02 DESIGN REMOVAL EFFICIENCY X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABS3R9ER SP«RE CAPACITY INDEX - I
ABS3R9ER SPARE COMPONENTS INDEX
rfATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
DISPOSAL
TYP5
- X
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
z
GEORGETOWN
SOUTH CAROLINA
280.0
258.0
UO.O
COAL
BITUMINOUS
26749.
1T.50
***
1.70
**»«*
WET SCRUBBING
LIMESTONE
3ABCOCK ! UILCOX
NEW
1.1
7/77
« /*
69.00
99.40
.0
.C
( 11500 8TU/LB)
OPEN
6.7
( 100 GPM)
POND
._._._._.> __. _ ... PERFORMANCE DATA
ERDD MDOULE AVAILABILITY OPERABILITT RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTE*
3/79 SYSTEM 96.6 96.4
*» PROBLEMS/SOLUTIONS/COMMENTS
START DATE
96.4
92.7
672
744
1361 1M3
START DATE
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.
2/79 END DATE 3/7«
OUTAGES WERE REQUIRED T3 REPAIR A HOLE IN THE FEED SLURRY LINE. TO INSPECT
THE MODULE FOR PLUG6AGE. AND BECAUSE OF A BOOSTER FAN TPIP.
2/79 END DATE 3/75
THE OPERATIN6 VALUES SHOWN ARE THE FIGURES OF FEBRUARY AND »ARCH 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 BUT REQUIRES CONTINUING MAINTENANCE TO KEEP IT OPERATING.
133
-------
cp* UTILITY F6D SURVEY: SECOND SUARTER 1979
SOUTH CAROLINA PJ6L1C SERVICE W1NYAH 2 (CONT.)
PERFORMANCE DATA
>E»130 M5DULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
START DATE A/79 END DATE 4/79
A MALFUNCTION OF THE RECIRCULATION TANK LEVEL INDICATOR RESULTED IN A LOM
LlfaUID LEVEL WHICH RESULTED IN FORCED OUTAGE.
5/7J S»STE« 9!.* 98.7 100.0 95.6 7*4 721 711 82.0
PROBLEIS/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 5/79
THE UTILITY REPORTED THAT THE S02 MONITOR SAMPLE PUMP REQUIRES MAINTENANCE
ALMOST EVERT 24 HOURS.
START DATE 5/79 END DATE 5/79
A EOILER OUTAGE ALLOWED TIME FOR CLEANING ABSORBER TRAYS. UNPLU66IN6 FOUR
NOZZLES, CLEANING SUMP BOTTOM. AND REPAIRING A SPRAY WASH VALVE.
6/79 SYSTEM 92.4 92.3 92.1 91.6 720 716 660 86.6
PROBLEMS/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
FOUR OUTAGES IN JUNE HERE DUE TO PLUGGED ABSORBER NOZZLES. THE PRIMARY
CAUSE APPEARED TO BE THAT A SCREEN IN ABSORBER SIDE OF THE SUMP BOTTO"
HAS LEFT OUT DURING THE PREVIOUS OUTAGE.
START DATE 6/79 END DATE 6/79
A HEAVY SCALE BUILD-UP IN THE SUMP BELOW THE VENTURI WAS NOTED.
START DATE 6/79 END DATE 6/79
THE UTILITY REPORTED THAT MGO TESTING HAS BEGUN. t
104
-------
EPA UTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/FGD - MU
NET UNIT GENERATING CAPACITY UO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - HW
SOUTHERN
MARION
t
MARION
ILLINOIS
A
***
******
270.0
184.0
160.0
*******
184.0
ILLINOIS POWER COOP
(**** LB/MMBTU)
(**** LB/MMBTU)
* 30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANEE HEAT CONTENT - BTU/IB
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
RANSE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MU
ESP
NUMBER
SUP»LIER
FGD SYSTEM
SALEABLE PRODUCT/THROUAUAV 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 - t
INITIAL START-UP
ABSORBER
NUM9ER
TYPE
INITIAL START UP
SUPPLIER
WATER LOOP
TYPE
« TREATMENT
TYPE
** DISPOSAL
NATURE
TYPE
- X
3ABCOCK t UILCOX
CYCLONE FIRED
BASE
0/78
»*****
****
******
*******
COAL
******
20934.
16.00
******
10.00
******
3.00
******
.01
***
72.6
184
(**«** I
(* f)
(*** FT)
(*** FT)
( 9000 BTU/LB)
******
( 80 TPH)
3APCOCK I WILCOX
THROUAUAT PRODUCT
riET SCRUBBING
LIMESTONE
BABCOCK I UILCOX
BURNS t MCDONNELL
BABCOCK t UILCOX
FULL-SCALE
NEW
99.60
89.40
5/79
SPRAY TOWER
10/78
BAPCOCK K UILCOX
OPEN
FLVASH STABILIZED
FINAL
LANDFILL
105
-------
EPA UTILITY rto SURVEY; SECOND QUARTER 1979
SOUTHERN ILLINOIS POWER COOP MARION * (CONT.)
^ PERFORMANCE DATA
»ERI3D N3DULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/7? SYSTEM 744
6/79 SYSTEM 720
PR06LE4S/SOLUTIONS/COMMENTS
STA4T DATE 5/79 END DATE 6/79
THE UTILITY REPORTED THAT THE UNIT BEGAN OPERATION IN HAY. HOWEVER THE
UNIT IS NOfc DOWN AND SUFFERED TWO PREVIOUS OUTAGES. THE PREVIOUS OUT-
AGES WERE DUE TO CENTRIFUGE AND THICKENER PROBLEMS. THE PRESENT OUTAGE
IS DUE TO EEARING FAILURES ON THE PU6 HILL AND IMPROPER FIT OF THE SLUDGE
CONVEYING 6ELT.
106
-------
EPA'UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL F60 SYSTEMS
COMPANY NAME
PLAIT NAME
UNIT NUMBER
CITY
STATE
REGULAT9RY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - M6/J
NET PLAIT GENERATING CAPACITY - MU
CROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/F6D - MU
NET UNIT GENERATING CAPACITY UO/F6D - HU
EQUIVALENT SCRUBBED CAPACITY - MU
* 30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.K/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANSE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANSE ASH C3NTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANSE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/M
FUEL FIRING RATE - MU
* ESP
NUMBER
TYPE
SUPPLIER
* FGD SYSTEM
SALEABLE PRODUCT/THROWAUAV PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEU/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
502 DESIGN REMOVAL EFFICIENCY - I
INITIAL START-UP
CONSTRUCTION INITIATION
CONTRACT AUARDED
STARTED REQUESTING BIDS
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENT INDEX
* ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
( .100 LB/MHBTU)
( 1.200 LB/MHBTU)
SOUTHERN INDIANA GAS t ELEC
A.B. BROUN
1
WEST FRANKLIN
INDIANA
A
43.
516.
250.0
265.0
250.0
255.0
265.0
3ABCOCK I UILCOX
PULVERIZED COAL. DRY BOTTOM
BASE
0/79
372.82 ( 790036 ACFM)
143.3 ( 290 F)
152. ( 498 FT)
*******
COAL
******
30261.
6.80
******
11.40
**
4.50
******
.05
»**
**
*****
(*** FT>
( 13010 BTU/LB)
******
( TPH)
COLD SIDE
3UELL-ENVIROTECH
THROUAUAY PRODUCT
UET SCRUBBING
DUAL ALKALI
FNC CORPORATION
3ROUN C ROOT
MID 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
j
62 HIGH X ?2 DIA.
CARBON STEEL
CEILCOTE
107
-------
EPA JTILITt F6D SURVEY: SECOND OUARTER 1979
SOUTHERN INDIANA GAS t ELEC ».B. BROUN
BOILER LOAD/ABSORBER - Z
GAS FLOW - CU.M/S
GAS TEMPERATURE C
$02 INLET C3NCENTRATION - PPM
SO2 OUTLET CONTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - I
FANS
NUH9ER
TYPE
SERVICE - MET/DRY
VACUUM FILTER
NUM3ER
TYPE
MIST ELIMINATOR
NUM9ER
TYPE
WASH SYSTEM
PUMPS
SERVICE
RECYCLE
RECYCLE CSPARE]
TANKS
SERVICE
REACTOR
SUREE TANK
THICKENER
NUM9ER
DIAMETER -
WATER LOOP
TYPE
* DISPOSAL
NATURE
TYPE
LOCATION
(CONT.)
60.0
237.84
145.0
2810
520
85.0
BOOSTER
DRV
ROTARY DRUM
2
CHEVRON
WASH ONCE/SHIFT
NUMBER
< 504000 ACFM)
< 293 F>
NUMBER
30.5
«100 FT)
UNDECIDED fCAN BE OPERATED EITHER WAV)
FINAL
LANDFILL
ON-SITE
....._ _ ... PERFORMANCE DATA
ERI3D H9DULE AVAILABILITY OPERABILlTV RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1179
4/7»
SYSTE*
SYSTEM
PROBLEMS/SOLUTIONS/COMMENTS
START DATE
744
720
3/79 END DATE 4/7°
THE FGD SYSTEM BEGAN OPERATIONS ON MARCH 18, 1979. NO OPERATIONAL DATA
ARE YET AVAILABLE.
5/79
6/7?
SYSTEM
SYSTEM
PROBLEMS/SOLUTIONS/COMHENTS
744
720
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 PROBLEMS AND FRP PIPING DESIGN.
108
-------
EPA UTILITY F6D SURVEY; SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLAIT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - Hh
NET UNIT GENERATING CAPACITY M/F6D - Mb
EQUIVALENT SCRUBBED CAPACITY - MW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHL3RIDE CONTENT - t
F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABS3RBER SPARE CAPACITY INDEX - S
ABS3RBER SPARE COMPONENTS INDEX
* KATE8 LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
TREATMENT
TYPE
DISPOSAL
TYPE
- I
SOUTHERN MISSISSIPPI ELECTRIC
R.D. MORROW
1
HATTISBUR6
MISSISSIPPI
200.0
180.0
COAL
*«*
27912. < 12000 BTU/L8)
s.OO
6.50
1.30
»*****
BET SCRUBBING
L1»ESTONE
RILEV STOKER/ENVIRONEERING
NEW
5.5
8/78
**/**
85.00
90.60
.0
.0
CLOSED
**« *
FLVASH STABILIZED
LANDFILL
. PERFORMANCE DATA
»ERI3D M3DULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/7? SYSTEM
3/7? SYSTEM
4/79 SYSTEM
672
74*
720
671
* PRObLEMS/SOLUTIONS/COMENTS
5/7? 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 DATE 4/79 END DATE 4/79
NO F6D SYSTEM RELATED PROBLEMS WERE REPORTED BY THE UTILITY FOR APRIL.
744
720
109
-------
EPA UTILITT FtD SURVEVt SECOND QUARTER 1979
SOUTHERN MISSISSIPPI ELECTRIC R.D. HORROH 1 (CONT.)
... ... ...-.-.-PERFORMANCE DATA
»ER19D MODULE AVULABILITT OPERABILITV RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGB CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
PROBLE4S/SOLUTIONS/COMMENTS
START DATE 5/79 END DATE 6/79
THE UTILITT REPORTED TH»T THE STSTEM OPERATED MOST OF MAY AND JUNE WJTH
NO MAJOR PROBLEMS.
7/79 SYSTEM 744
PROBLE4S/SOLUTIONS/COMMEMTS
START DATE 7/79 END DATE 7/79
DURIN6 THE FIRST WEEK OF JULY THE UNIT HAS REMOVED FROM SERVICE DUE TO
SEVERE PROBLEMS WITH THE F6D SYSTEM. THE UTILITY NOTED THAT ABOUT HALF
OF THE NODULE HEADERS HERE PLUGGED, HOLES HERE NOTED IN THE MODULE SHELL.
THE UPPER ROP BANK CORRODED AWAY FROM THE SHELL. AND EXTENSIVE PLU66IN6
OF THE MIST ELIMINATOR. LINER FAILURE AT THE OUTLET DUCTWORK WAS ALSO
EXPERIENCED. THE UTILITY PLANS TO REPLACE THE DUCTWORK WITH HASTALLOV.
THE FGD SYSTEM IS EXPECTED TO BE OFF LINE FOR SEVERAL MONTHS FOR REPAIRS
TO BE COMPLETED.
110
-------
EPA OTILITt FGD SURVEY: SECOND QUARTER 1979
SECTION 3
OESIEN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLAUT NAME
UNIT NUMBER
CITY
STATE
RE6ULAT3RY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLAMT GENERATING CAPACITY - MW
CROSS OMIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY V/F6D - ttw
NET UNIT GENERATING CAPACITY WO/F6C - MU
EQUIVALENT SCRUBBED CAPACITY - »U
30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE CAS FLOW - CU.M/S
FLUE CAS TEMPERATURE - C
STACK HEIGHT - It
STACK TOP DIAMETER - H
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANEE HEAT CONTENT - 3TU/LB
AVERAGE ASH CONTENT - X
RANSE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
RANSE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHL3RIDE CONTENT - X
RANSE CHLORIDE CONTENT - X
FUEL FIRING RATE - * T/H
FUEL FIRING RATE - «b
* ESP
NUH3ER
TYPE
SUPPLIER
* FGD SYSTEM
SALEABLE PR3DUCT/THROHAUAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEU/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - I
INITIAL START-UP
4BS04BER
INITIAL START UP
SUP'LIER
THEATER
TYPE
rfATER LOOP
TYPE
TREATMENT
TYPE
* D1SP3SAL
NATJRE
TYPE
SOUTHERN MISSISSIPPI ELECTRIC
R.D. MORROW
2
HATTISBURC
MISSISSIPPI
**
******
»»»**
300.0
180.0
191.0
124.0
RILEV STOKER
PULVERIZED COAL
3ASE
*/*
***
*******
124.
***
(**.*** L9/MMBTU)
(**»** LS/MMBTU)
(***** ICFM)
< F)
( 4G8 FT)
(***** FT>
COAL
******
27912.
?.00
*»«*
6.50
6-7
1.30
1 - 1.75
***** *
******
680.2
200
( 12000 BTU/LB)
******
C750 TPH)
HOT SIDE
3UELL ENVIRQTECH
THROWAUAY PRODUCT
WET SCRUBBING
LIMESTONE
RILEY STOKER/ENVIRONEERING
FULL-SCALE
NEW
- X 99.60
85. 00
6/79
6/79
RILEV STOKER
3VPASS
CLOSED
FLYASH STABILIZED
FINAL
LANDFILL
111
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SOUTHERN MISSISSIPPI ELECTRIC R.D. BORROW 2 (CONT.)
LOCATION ON-SITE
PERFORMANCE DATA
ERDD M5DULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
$02 PART. HOURS HOURS HOURS FACTOR
6/7? SYSTEM 720
PROBLE4S/SOLUTIONS/COMNENTS
STA»T DATE 6/79 END DATE 6/79
R.D. PORROb UNIT «2 BEGAN OPERATION IN THE LATTER PART OF JUNE. OPERA-
TIONAL DATA ARE NOT VET AVAILABLE.
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRU3BED CAPACITY - MU
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT KJ/K6
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHL3RIOE CONTENT - t
F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYP:
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - t
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t
ABS3R9ER SPARE COMPONENTS INDEX
WATER LOOP
TYPE
FRESH MAKE-JP HATER - LITER/S
* TREATMENT
TYPE
DISP9SAL
TYPE
- Z
SPRINGFIELD CITY UTILITIES
SOUTHWEST
t
SPRINGFIELD
MISSOURI
194.0
173.0
194.0
( 12500 BTU/LB)
COAL
BITUMINOUS
29075.
1T.00
«***
3.50
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEW
4.6
4/77
/*
80.00
99.70
.0
.0
CLOSED
19.8
NONPPOPRIETARY
LANDFILL
t 315 6PM)
PERFORMANCF DATA
»ERI3D N3DULE AVAILABILITY OPERABILITT RELIABILITY UTILIZATION I REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/7? S-1 25.0 .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
** PROtJLEMS/SOLUTIONS/COMMENTS
STA3T DATE 2/79 END DATE 2/79
THE S-1 MODULE EXPERIENCED PLUGGING PROBLEMS IN THE FIRST AND SECOND
STAGE DURING FEBRUARY AMD DID NOT OPERATE. DUE TO FLUE GAS LEAKAGE INTO TH
NODULE ACCESS COULD NOT BE OBTAINED TO CLEAN THE MODULE.
START DATE 2/79 END DATE 2/79
EXPANSION JOINT PROBLEMS AND BROKEN LINES HERE REPORTED.
STA»T DATE 2/79 END DATE 2/79
A LACK OF SCRUBBING PEDIUP DURING THE LATTER PART OF FEBRUARY WAS REPORTED
BY THE UTILITY.
START DATE 2/79
END DATE 2/79
THE S-2 MODULE PROBLEMS INCLUDED FROZEN VALVES AND LINES.
3/79 S-1
62.0
39.5
39.5
39.7
113
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SPRINGFIELD CITY UTILITIES SOUTHyEST
(CONT.)
PERFORMANCE DATA
ERI3D MODULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79
5/79
6/7?
S-2
SYSTEM
55. 0
58.5
U.O
26.P
14.0
26.8
13.7
26.2
744
730
195 52.8
PRDBLENS/SOLUTIONS/COMNENTS
STA9T DATE
START DATE
3/79 END DATE 3/79
THE MAJORITY OF MODULE S-1 DOWNTIME HAS DUE TO * BROKEN SUPERNATE LINE AND
MAKEUP CROSS TIE.
3/79 END DATE 3/79
THE UTILITY REPORTED THAT THE MODULE HAS UNABLE TO RUN FOR A THE DUE TO
A DESIGN PR03LEM WITH A 500 HP MOTOR.
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
IB.5
22. B
720 432
164
PROBLE'S/SOLUTIONS/COMMENTS
START DATE
START DATE
START DATE
4/79 END DATE 4/79
MODULE S-1 EXPERIENCED AN EXPANSION JOINT FAILURE ON THE I.D. F*N DIS-
CHAR6F.
4/79 END DATE 4/79
LOb DENSITY AT THE SLURRY HOLD TANK HAS A MAJOR PROBLEM.
4/79 END DATE 4/79
SOME PLU66INS OF THE FIRST STAGE OF THE S-2 NODULE UAS REPORTED BY THE
UTILITY.
S-1
S-2
SYSTE4
84.1
.0
42.1
77.5
.0
38.8
77.5
.0
48.5
67.0
.0
33.5
744 644
249
* PROBLENS/SOLUTIONS/COHNENTS
START DATE
5/79 END DATE 5/79
THE S-2 NODULE UAS NOT OPERATED DURING MAY DUE TO A BROKEN RECYCLE TANK
AGITATOR SHAFT. A NEK ONE HAS BEEN ORDERED. RUBBER LINING OF THE SHAFT
AND REPAIR OF DAMAGED LINING ON THE IMPELLER WILL BE DONE ON SITE.
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
*» PRO&LE4S/SOLUTIONS/COMMENTS
START DATE 6/79 END DATE 6/79
THE BROKEN AGITATOR SHAFT UAS REPLACED AND LINED DURING JUNE.
START DATE 6/79 END DATE 6/79
THt S-2 MODULE UAS OUT OF SERVICE ON THREE OCCASIONS DUE TO PLUGGA6E OF
THE FIRST AND SECOND STAGES. THE UTILITY REPORTED THAT UITH THE EXCEPTION
OF THE PLUGGING PROBLEM ONLY A FEU MINOR SHORT DURATION TRIPS UERE NOTED.
114
-------
EPA UTILITY FCO SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MM
EQUIVALENT SCRU9BED CAPACITY - MW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT Z
AVERAGE CHLORIDE CONTENT - Z
FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
riATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
VALLEY AUTHORITY
- Z
(**** BTU/LB)
TENNESSEE
SHAUNEE
10A
PADUCAH
KENTUCKY
10.0
10.0
10.0
COAL
BITUMINOUS
******
********
********
2.90
»*»***
VET SCRUBBING
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
RETROFIT
*«**
4/72
**/**
*******«
********
.0
CLOSED
*******
(**** 6PM)
.... PERFORMANCE DATA
»ERI3D MODULE AVAILABILITY OPEftABILITY RELIABILITY UTILIZATION
Z REMOVAL
502 PART,
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
0/79 'SYSTEM
PROBLE4S/SOLUTIONS/COMMENTS
START DATE 0/72 END DATE 6/79
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR SHAWNEE 108.
115
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLAUT NANE
UNIT NUMBER
CITY
STATE
CROSS UWIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - RU
* FUEL DATA
FUEL TYPE
FUEL 6RADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABS7RBER SPARE COMPONENTS INDEX
HATER LOOP
TYPE
FRESH MAKE-JP MATER - LITER/S
- X
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10B
PADUCAH
KENTUCKY
10.0
10.0
10.0
COAL
3ITUMINOUS
******
********
********
2.90
********
WET SCRUBBING
LIME/LIMESTONE
CHEMICO
RETROFIT
*******
4/72
»*/*
********
********
.0
CLOSED
*******
{«*** Bru/LB)
(*****
PERFORMANCE DATA
»E»I3D MDDULE AVAILABILITY OPERABILITT RELIABILITY UTILIZATION
X REMOVAL
502 PART.
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
2/79 SYSTEM
3/79 SYSTEM
672
744
PROBLEMS/SOLUTIONS/CCMMENTS
START DATE 2/79 END DATE 3/7"
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 UNDER CONTRACT WITH EPA. ACTUAL SAMPLING OF SLUR-
RIES AND CONDENSATES FROM THE SCRUBBER AND OXIDATION TANK OFF-GASES MAS
PERFORMED BY BATTELLE COLUMBUS LABORATORY. FOR THIS PURPOSE. THE TCA WAS
OPERATED WITH LIMESTONE/FLY*SH SLURRY AS A BASE CASE. AND THE VENTURI/
SPRAY TOWEfi riAS OPERATED WITH LI ME STONE/FLYASH SLURRY AND WITH ADIPIC
ACID ADDITIVE AND TUO-SCRUBBEP-LOOP FORCED OXIDATION.
A SERIES OF TESTS WAS CONDUCTED ON THE VENTURI/SPRAY TOMER STSTE" FROM
MID-FEBRUARY THROUGH THE END OF MARCH TO SIMULATE THE PLANNED TVA WIDOWS
CREEK UNIT 8 FULL-SCALE, TwO-SCRUPBER-LOOP FORCED-OXIDATION SCHEME.
SPECIAL WItOMS CREEK LIMESTONE (STONENAN) AND COAL (PITTSBURGH MIDWAY)
WERE USED AT SHAWNEE DURING THESE TESTS. NEAR COMPLETE SULFITE OXIDATION
WAS ACHIEVED AT OXIDATION TANK PH UP TO 6.0 AND AN AIR STOICHI0«ETRY AS
LOh AS 1.5 ATOMS OXYGEN/ "OLE S02 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 GPN.
A NEW LIME/ADIPIC ACID TEST BLOCK WITH AND WITHOUT FORCED OXIDATION
BEGAN IN EARLY FEBRUARY ON THE SINGLE-LOOP TCA SYSTEM USING FLUE GAS WITH
HIGH FLYASH LOADINGS. AT TCA INLET PH OF 7.0. 2400 TO 2900 PPM INLET S02,
L/6 OF 50 GAL/ MCF, AND 15 INCHES TOTAL STATIC 9ED HEIGHT OF 1-7/6 INCH
NITRILE FOAM SPHERES, S02 REMOVALS WERE 83, 93, AND 97 PERCENT WITH ZERO,
116
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
TENNESSEE VALLEY AUTHORITY SHAUNEE 10B CCONT.)
PERFOBHANCE DATA
ERIDD N3DULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION I REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
600, AND 1233 PPH ADIPIC ACID. RESPECTIVELY. WITHOUT FORCED OXIDATION.
S02 REMOVAL REMAINED HISH AT 91 PERCENT WITH 12?0 PPM ADIPIC ACID WHEN L/6
HAS REDUCED FROM SO TO 37 GAL/HCF. WHEN OXIDATION WAS FORCED WITH AfcOUT
1.E AIR STOICHIOMETRY. NEAR COMPLETE SULFITE OXIDATION WAS ACHIEVED AT
OXIDATION TANK PH UP TO ABOUT 5.5, AND 1200 PPX ADIPIC
ACID. S02 REMOVAL ABOVE "0 PERCENT WAS OBTAINED AT TCA INLET PH AS LOW
AS 5.0 WITH FORCED OXIDATION.
4/79 SYSTEM 720
5/79 SYSTEM 744
PROBLEJS/SOLUTIONS/COMNENTS
START DATE */79 END DATE 5/79
A SERIES OF BLEED STREAM OXIDATION TESTS USING LIMESTONE AND AOIPIC
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 9LEED RATES AND SUBSEQUENT-
LY HIGHER RESIDENCE TINES IN THE OXIDATION TANK. OR RECIRCULATION AT
LIQUOR BACK TO THE EFFLUENT HOLD TANK WHICH ARTIFICIALLY MAINTAINED A LOW
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 STOICHICHETRIC
RATIOS OF 1.7-2.0 ATOMS OXYGEN/HOLE S02 ABSORBED, AN UNUSUAL SET OF CON-
DITIONS WAS ENCOUNTERED DURING WHICH THE LIQUID SULFITE ION LEVEL IN-
CREASED TO A RANGE OF 800 TO 1700 PPM AND THE DEMAND FOR LIMESTONE TO
MAINTAIN THE SCRUBBER INLET PH AT 5.1 INCREASED TO A RANGE OF 1.8 TO 4.0
HOLES LIMESTONE/HOLE S02* ABSORBED. THE CAUSE HAS NOT TET BEEN DETERMINED
ALTHOUGH IT riAS 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 STH FOR * SCHEDULED 6 WEEK BOILER OUT-
AGE. DURING THIS PERIOD. THE VENTURI/SPRAV 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.
117
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLANT NINE
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
FCD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
$02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t
ABS3RBER SP4RE COMPONENTS INDEX
* DISPOSAL
TYPE
- X
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
BRIDGEPORT
ALABAMA
550.0
516.0
550.0
( 10000 BTU/LB)
COAL
***
23260.
25.00
10.00
3.70
»«**
WET SCRUBBING
LIMESTONE
TENNESSEE VALLEY AUTHORITY
RETROFIT
****«
5/77
1/78
80.00
99.50
.0
.0
POND
.. . PERFORMANCE DATA
PERI3D MODULE AVAILABILITY OPEFABILITV 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
CONSTRUCTION OF THE FORCED OXIDATION TEST WAS COMPLETED AND THE TESTING
HAS BEGUN ALTHOUGH NO RESULTS ARE VET AVAILABLE (THIS TESTING IS BEING
DONE ON ONE 9F THE FOUR MODULES).
START DATE 2/79 END DATE 3/79
THE UNIT OUTAGE UHICH BEGAN IN OCTOBER AND HAS SCHEDULED TO END IN FEB-
RUARY CONTINJED THROUGH MARCH BECAUSE AFTER A FEW START-UPS THERE
WERE BOILER AND TURBINE FAILURES.
4/79
5/79
6/79
SYSTEM
SYSTEM
SYSTEM
PROBLEMS/SOLUTIONS/COMMENTS
START DATE
720
744
720
4/79 END DATE 6/79
NO INFORMATION WAS AVAILABLE FOR THIS PERIOD.
118
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESI6M AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLAMT NAME
UNIT NUMBER
CITY
STATE
GROSS U1IT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/FGD - Mb
EQUIVALENT SCRU9BED CAPACITY - MU
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEV/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABS3RBEB SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
HATER LOOP
TYPE
FRESH MAKE-'JP WATER - LITER/S
TREATMENT
TYPE
* DISP3SAL
TYPE
TEXAS UTILITIES
MARTIN LAKE
1
TATUM
TEXAS
793.0
750.0
S9S.O
( 7380 BTU/LB)
COAL
LIGNITE
17166.
8.00
33.00
.90
***
MET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEW
1.3
4/77
10/78
**»*
99.40
.0
.0
CLOSED
34.6 < 550 6Pi)
FLYASH STABILIZED
LANDFILL
. . PERFORMANCE DATA
ERIJD MDDULE AVAILABILITY OPERASILITT RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/79 SYSTEM 672
3/79 SYSTEM 744
4/79 SYSTEM 720
PROBLEMS/SOLUTIONS/COMHENTS
START DATE 2/79 END DATE 4/79
UNIT 1 IS NO* 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 MOKC BETTER. HOWEVER. THEY STILL HAVE PROBLEMS WITH THE GUIL-
LOTINE DAMPERS FAILING TO SEAL WHEN THEY BECOME SCALED.
START DATE 2/79 END DATE 4/79
THERE HAVE 9EEN REPORTS OF TOWER LEAKS FROM LINER FAILURE BUT IT DOESN'T
SEEM TO BE SERIOUS.
5/79 SYSTEM
119
-------
EPA UTILITV F6B SURVEY: SECOND QUARTER 1979
TEIAS UTILITIES ' NARTIN LAKE 1 CCONT.)
. PERFORMANCE DATA ~
ERIOD NODULE AVAILABILITY OPERABXLITV RELIABILITT UTILIZATION I REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/79 SYSTEM 720
PROBLE4S/SOLUTIONS/CONMENTS
START DATE 4/79 END DATE 6/79
THE UNIT WAS IN OPERATION DURIN6 THIS PERIOD ALTHOUGH OPERATIONAL DATA
WERE NOT AVAILABLE.
1ZO
-------
EPA UTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLAUT NAME
UNIT NUMBER
CITY
STATE
GROSS UKIT SENERATIN6 CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - NW
FUEL DATA
FUEL TYPE
FUEL 6RADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASM CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - S
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABS9RBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
TREATMENT
TYPE
DISPOSAL
TYPE
- Z
TEXAS UTILITIES
MARTIN LAKE
2
UTUM
TEXAS
793.0
750.0
595.0
COAL
LIGNITE
17166.
8.00
33.00
.90
**
MET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
NEU
1.3
5/7E
t 7380 BTU/LB)
******
99.40
.0
.0
CLOSED
34.6
( 550 GPft)
FLYASH STABILIZED
LANDFILL
PERFORMANCE DATA
ERIDD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/7? SYSTEM 672
3/79 SYSTEM 74*
4/79 SYSTEM 720
* PROBLEMS/SOLUTIONS/COMMENTS
START DATE 2/79 END DATE 4/79
THERE HAVE BEEN REPORTS OF TOWER LEAKS FROM LINER FAILURE BUT IT DOESN'T
SEEM TO BE SERIOUS.
START DATE 2/79 END DATE 4/79
UNIT 2 IS NO* IN FULL OPERATION ALTHOUGH A SLUDGE DISPOSAL PROBLE* STILL
EXISTS.
START DATE 2/79 END DATE 4/79
THE UTILITY HAS REPLACED THE LOUVER DAMPERS talTH GUILLOTINE DAMPERS tfMICH
SEEN TO MOM BETTER. HOWEVER, THEY STILL HAVE PROBLEMS UITH THE GUIL-
LOTINE DAMPERS FAILING TO SEAL UHEN THEY BECOME SCALED.
5/79 SYSTEM 744
121
-------
:PA UTILITY FGD SUPWET: SECOND QUARTER 197*
TEXAS UTILITIES MARTIN LAKE
(CONT.)
--PERFORMANCE OATA
ERI3D N3DULE AVULA9ILITY OPERAPILITY RELIABILITY UTILIZATION
I REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/79 SYSTEH
PROBLE'S/SOLUTIONS/COMENTS
720
STA«T DATE */79 END DATE 6/79
THE UNIT HAS IN OPERATION DURING THIS PERIOD ALTHOUGH OPERATIONAL DATA
MERE NOT AVAILABLE.
132
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLAVT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - N6/J
$02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - Mw
GROSS U1IT GENERATING CAPACITY - Mh
NET UNIT 6ENERATING CAPACITY b/FGD - Mu
NET UNIT GENERATING CAPACITY WO/FEC - MU
EQUIVALENT SCRUBBED CAPACITY - KU
TEXAS UTILITIES
MARTIN LAKE
3
TATUM
TEXAS
A
43. (
516. (
3000.0
793.0
750.0
76C.O
595.0
.100 L'/MMBTU)
1.200 L9/MMBTU)
BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE 6A S FLOW - CU.fl/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - f
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANSE HEAT CONTENT - BTU/IB
AVEVAGE ASH CONTENT - 1
RANSE ASH CONTENT - X
AVE1A6E MOISTURE CONTENT - X
RANSE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANSE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANSE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RAT? - MW
* ESP
NUN3ER
TYPE
SUPPLIER
* F6D SYSTEM
SALEABLE PRDDUCT/THROWAKAV PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
INITIAL START-UP
ABS9RBER SPARE CAPACITY INDEX - I
ABS9RBER SPARE COMPONENT INDEX
ABSORBER
NUM9ER
TYPE
INITIAL STA4T UP
SUPPLIER
NUM3ER OF STAGES
&OILER LOAD/ABSORBER - X
CENTRIFUGE
NUH3ER
OUTLET SOLIDS - X
- X
COMBUSTION ENGINEERING
PULVERIZED COAL
3ASE
*/<
******** (****** HCFM)
16?.3 ( 335 F)
** (**** FT)
**** (** FT)
COAL
LIGNITE
17166.
s.co
5.6-13.2
33.00
29.0-37.9
.90
0.5-1.5
***** **
***
453.5
«*
< 7380 BTU/LP)
6972-789*
(500 TPH>
COLD SIDE
RESEARCH-COTTRELL
THPOWAUAY PRODUCT
WET SCRUBBING
LIMESTONE
RESEARCH COTTRELL
C.T. MAIN
FULL-SCALE
NEW
99.40
2/79
.0
.0
PACKFD TOWER
2/79
RESEARCH COTTRELL
T
12. ?
69.C
123
-------
EPA UTILITY F60 SURVEY: SECOND flUARTER 1979
TE«AS UTILITIES MARTIN LAKE
CCONT.)
MIST ELIMINATOR
NUNSER
TTPE
NUH9ER OF STAGES
SERVICE
QUENCHER FEED PUMP
SLURRY FEED
TANKS
SERVICE
ABS3RBER FEED TANKS
REHEATER
TYPE
THICCENER
NUNSER
TYPE
DIAMETER - «
OUTLET SOLIDS - X
TREATMENT
TYPE
DISPOSAL
NATURE
TTPE
LOCATION
TRAVSPORTATION
6
CHEVRON
2
NUMBER
*
**
NUMBER
3
BYPASS
GRAVITY
42.7
35. 0
(140 FT)
FLYASH STABILIZED
FINAL
LANDFILL
ON-SITE
RAIL
... .. ... -_______. -PERFORMANCE DATA-- ----- ......
ERIJD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79
4/79
SYSTEM
SYSTEM
PRDBLEIS/SOLUTIONS/COHNENTS
START DATE
3/79 END DATE 4/79
MARTIN LAKE UNIT 3 BECAME OPERATIONAL DURIN6 MARCH.
TAILS ARE YET AVAILABLE.
5/7?
6/7?
SYSTEM
SYSTEM
PROBLEVS/SOLUTIONS/CONNENTS
744
720
NO OPERATION DE-
744
720
STAIT DATE 4/79 END DATE 6/79
THE UNIT HAS IN OPERATION DURING THIS PERIOD ALTHOUGH OPERATIONAL DATA
HERE NOT AVAILABLE.
124
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COH^ANV NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS U1IT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - KW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
* rfATER LOOP
TYPE
FRESH MAKE-JP MATER - LITER/S
TREATMENT
TYPH
* DISPOSAL
TYPE
- Z
TEXAS UTILITIES
40NT1CELLO
$
n. PLEASANT
TEXAS
400.0
'50.0
HOO.O
COAL
LIGNITE
******
18.90
******
1.50
.04
WET SCRUBBING
LIMESTONE
CHEMICO
NEW
*******
s/78
10/78
7*.00
99.50
.0
.0
CLOSED
34.*
(*** BTU/LB)
( 546 6P«>
FLYASH STABILIZED
LANDFILL
-__ « .. . PERFORMANCE DATA
'ERIOD MDDULE AVAILABILITY OPERABILITT RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/7?
3/7?
4/79
SYSTEM
SYSTEM
SYSTEM
» PROBLEMS/SOLUTIONS/COMMENTS
START DATE
672
744
720
2/79 END 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 4/7°
5/79
6/79
SYSTEM
SYSTEM
SOME MINOR RECYCLE PUMP LINER PROBLEMS HAVE BEES REPORTED.
744
720
125
-------
EPA UTILITY F6D SURVEYr SECOND QUARTER 1979
TEKAS UTILITIES KONTICELLO
(CONT.)
PERFORMANCE DATA
ERI90 N9DULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER F60 CAP.
$02 PART. HOURS HOURS HOURS FACTOR
PROBLE1S/SOLUTIONS/COMENTS
START DATE 4/79 END DATE 6/79
THE UNIT HAS IN OPERATION DURING THIS PERIOD ALTHOUGH OPERATIONAL DATA
HERE NOT AVAILABLE.
1Z6
-------
EPA OTILITf FGD SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL F6D SYSTEMS
COMPANY NAME
PLAVT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - hC/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - Mk
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY UO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - RU
30ILER DATA
SUPPLIER
TYPS
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CJ.H/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER M
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANGE HEAT CONTENT - BTU/LG
AVERAGE ASH CONTENT - X
RANGE ASH C3NTENT - X
AVERAGE MOISTURE CONTENT - Z
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RAN6E SULFUR CONTENT - X
AVERAGE CHLDRIDE CONTENT - X
RANSE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MW
UTAH POWER t LIGHT
HUNTER
1
CASTLE DALE
UTAH
A
******
******
«***
400.0
400.0
*******
360.0
***
***
BASE
*/*
****
******
******
(«**** L9/MMBTU)
(**** LB/MNBTU)
COAL
******
2«075.
10.00
9-12
6.50
(***««« «CFM>
(«** r>
( FT)
(*«** FT)
( 12500 BTU/LB)
12*200 - 12,700
.55
***
***** **
**
***** **
«*
TPH>
ESP
NUMBER
SUPPLIER
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 - t
INITIAL START-UP
* ABSORBER
INITIAL START UP
SUPPLIER
* REHEATER
TYPE
* 4ATE1 LOOP
TYPE
TREATMENT
TYPE
DISPOSAL
NATURE
TYPE
3UELL/ENVIROTECH
THROWAWAY PRODUCT
WET SCRUBBING
LI"E
CHENICO
STEARNS-R06ER
FULL-SCALE
NEW
- X 99.50
80.00
5/79
5/79
CHEMICO
3YPASS
OPEN
FLVASH STABILIZED
FINAL
POND
127
-------
EPA VTILITT F6D SURVEV: SECOND QUARTER 1979
VTftN POMER t LI6HT HUNTER
LOCATION
ON-SITE
CCONT.}
.. _ PERFORMANCE DATA
»ERI9D NODULE AVULABILIT* OPERABILITf RELIABILITT UTILIZATION X REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR
5/79 STSTE*
* PROBLE4S/SOLUTIONS/COMMENTS
744
START DATE 5/79 END DATE 5/79
THE UNIT STARTED OPERATIONS ON NAT ?1. 1979. OPERATIONAL PARAMETERS ARE NO
YET AVAILABLE DUE TO THE RECENT OPERATING STATUS OF THE SYSTEM.
128
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FGD SYSTEMS
COMPANY NAME
PLAIT NAME
UNIT NUMBER
CITY
STATE
GROSS UVIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/FGD - Mb
EQUIVALENT SCRUBBED CAPACITY - MW
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - J
AVERAGE CHLORIDE CONTENT - X
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABS3RBER SPARE COMPONENTS INDEX
MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER'S
TREATMENT
TYPE
* DISPOSAL
TYPE
- X
UTAH POWER
HUNTINGTON
1
PRICE
UTAH
430.0
400.0
366.0
COAL
******
29075.
10.00
4.50
.55
*****
WET SCRUBBING
LIME
CHEMICO
NEW
1.6
5/78
** /**
80.00
99.50
2.5
.0
CLOSED
18.9
t LIGHT
( 12500 BTO/LB)
( 300 6P»>
FLYASH STABILIZED
LANDFILL
......... . . PERFORMANCE DAT*
ERI3D NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/79
4/79
SYSTEM
SYSTEM
STSTEM
* PROBLEMS/SOLUTIONS/COMENTS
START DATE
672
7* <.
720
2/79 END DATE 4/79
THE UTILITY REPORTED THAT THE PROBLEMS ENCOUNTERED DURING FEBRUARY
INCLUDED LINING FAILURE, PUMP PROBLEMS AND DAMPER PROBLEMS.
- *PR1L
START DATE 2/79
END DATE 4/7"
5/79
6/79
SYSTEM
SYSTEM
PROBLEMS HAVE BEEN EXPERIENCED WITH DAMPER MECHANISES CLOGGING.
744
744
129
-------
rPA UTILITY F6D SURVET: SECOND QUARTER 1979
UTAH POWER I L16HT HUNTINCTON 1 (CONT.)
_ _ PERFORMANCE DATA
'ERI3D N9DULE AVAILABILITY OPEPABILITf RELIABILITY UTILIZATION X REMOVAL PER BOILER F60 CAP.
S02 PART. HOURS HOURS HOURS FACTOR
PROBLE4S/SOLUTIONS/COMENTS
START DATE 2/79 END DATE 3/79
NO INFORMATION HAS REPORTED BY THE UTILITY FOR THIS REPORT PERIOD.
130
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 4
SUHMRY OF F6D SYSTEMS BY COMPANY
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT PLANNED
AWARDED
COMPANY NAME
ALABAMA ELECTRIC COOP
ALLEGHENY POWER SYSTEN
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 ( ELECTRIC
COLORADO UTE ELECTRIC ASSN.
COLUH3US I SOUTHERN OHIO ELEC.
COMMONWEALTH EDISON
COOPERATIVE POWER ASSOCIATION
D:LNARVA POWER I LIGHT
DUBUESNE LIGHT
EAST KENTUCKY POWER COOP
GENERAL PUBLIC UTILITIES
GULF "OWER
HDOSIER ENERGY
HOUSTON LIGHTING I POWER CO.
INDIANAPOLIS POWER K LIGHT
KANSAS CITY POWER 1 LIGHT
KANSAS POWER t LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LOUISVILLE GAS ( ELECTRIC
MIDDLE SOUTH JTILITIES
MINNESOTA POWER i LIGHT
MINNKOTA POWER COOPERATIVE
MONTANA POWER
NJSCATINE POWER t WATER
NEVADA POWER
NIAGARA MOHAWK POWER COOP
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
OTTER TAIL POWER
PACIFIC GAS fc ELECTRIC
PACIFIC POWER t LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
POTOMAC ELECTRIC POWER
POWER AUTHORITY OF NEW YORK
PUBLIC SERVICE OF INDIANA
PUBLIC SERVICE OF NEW MEXICO
SALT RIVER PROJECT
SAN MIGUEL ELECTRIC COOP
SEMINOLE ELECTRIC
SIKESTON BOARD OF NUNIC. UTIL.
SOUTH CAROLINA PUBLIC SERVICE
SOUTHERN ILLINOIS POWER COOP
SOUTHERN INDIANA GAS t FLEC
SOUTHERN MISSISSIPPI ELECTRIC
SOUTHWESTERN ELECTRIC POWER
S'RINSFIELD CITY UTILITIES
SPRINGFIELD WATER, LIGHT s PWR
ST. JOE ZINC
TAMPA ELECTRIC
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER t LIGHT
TEXAS UTILITIES
UTAH POWER I LIGHT
WISCONSIN POWER t LIGHT
NO.
2
3
2
e
1
5
2
2
1
1
1
2
t
1
2
1
2
1
2
1
2
1
2
5
4
1
1
13
6
1
1
4
1
13
1
5
1
i
2
1
T
4
1
1
1
4
3
1
2
1
3
2
1
2
1
1
1
1
1
0
ii
3
8
T
1
MW
158.
1338.
390.
2684.
670.
2680.
484.
?32.
617.
600.
650.
894.
1572.
450.
654.
180.
920.
500.
1600.
23.
882.
512.
1062.
1054.
1575.
64.
364.
3533.
5340.
475.
405.
2120.
160.
3125.
100.
1547.
2340.
440.
1600.
550.
2751.
844.
800.
700.
650.
1779.
840.
400.
1240.
235.
700.
464.
265.
24E.
720.
194.
205.
60.
450.
3753.
400.
1PB2.
5585.
1086.
J16.
NO.
2
1
2
2
0
0
0
1
0
0
0
0
2
0
0
0
2
0
0
1
0
0
1
3
3
1
0
5
0
0
1
2
0
3
0
1
2
0
0
0
2
1
0
0
0
2
0
0
0
0
1
1
1
2
0
1
0
0
0
3
0
0
4
2
0
MW
358.
519.
390.
469.
0.
0.
0.
416.
0.
0.
0.
0.
822.
0.
0.
0.
920.
0.
0.
23.
0.
0.
532.
1054.
1085.
64.
0.
1180.
0.
0.
405.
720.
0.
375.
0.
115.
1480.
0.
0.
0.
1874.
120.
0.
0.
0.
711.
0.
0.
0.
0.
140.
184.
265.
248.
0.
194.
0.
0.
0.
570.
0.
0.
2585.
726.
0.
NO.
0
1
0
4
1
2
2
0
1
0
1
2
0
1
2
1
0
1
0
0
2
0
1
0
1
0
0
3
0
1
0
0
0
0
0
0
0
1
0
1
1
0
0
0
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.
705.
670.
1200.
484.
0.
617.
0.
650.
894.
0.
450.
654.
180.
0.
500.
0.
0.
882.
0.
530.
0.
490.
0.
0.
1203.
0.
475.
0.
0.
0.
0.
0.
0.
0.
440.
0.
550.
917.
0.
0.
P.
0.
1068.
560.
400.
0.
235.
280.
0.
0.
0.
0.
0.
205.
60.
0.
575.
0.
382.
0.
360.
0.
NO.
0
0
0
2
0
2
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
2
0
0
1
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
1
0
0
0
1
0
0
0
0
2
1
0
1
0
1
MW
o.
0.
0.
1510.
0.
1040.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
364.
0.
0.
0.
0.
1490.
0.
0.
100.
0.
0.
0.
0.
0.
0.
0.
0.
0.
650.
0.
0.
0.
0.
0.
2PO.
0.
0.
0.
720.
0.
0.
0.
0.
1436 .
400.
0.
750.
0.
316.
NO.
0
1
0
3
0
1
3
1
3
1
0
3
2
0
0
0
0
0
2
0
0
1
D
0
0
0
3
2
6
0
3
3
1
7
0
4
1
3
2
0
0
5
1
1
3
3
1
0
2
3
0
1
3
3
3
0
0
3
1
2
9
2
3
3
3
MW
0.
300.
0.
0.
0.
440.
0.
416.
0.
600.
0.
0.
750.
0.
0.
0.
0.
0.
1600.
0.
0.
512.
P.
P.
P.
P.
c .
1150.
534P.
0.
0.
P.
160.
2750.
0.
1432.
160.
0.
1600.
C.
0.
724.
POP.
700.
C.
0.
2tC.
0.
1240.
P.
0.
30P.
0.
P.
p«
P.
P.
P.
45P.
12CO.
P.
225n.
P.
P.
TOTALS
162 71931.
55 18504.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SI6
AND CONSIDERING ONLY F6D SYSTEMS
42 17135. 16 8938. 49 27354.
NED. REQUESTIN6/EVALUTIN6 BIDS,
131
-------
EP* UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 5
SUMMARY Or FCD SYSTEMS BY SYSTEM SUPPLIER
TOTAL
SYSTEM SJPPLIER/PROCESS
4DL/CONBUSTION EBUIP ASSOCIATE
DUAL ALKALI
LIME
LIME/ALKALINE FLYASH
SODIUM CARBONATE
TOTAL -
IIR CORRECTION DIVISION, UOP
LIME
LIMESTONE
LIME/LIMESTONE
SODIUM CARBONATE
TOTAL -
AMERICAN AIR FILTER
LIME
LIMESTONE
TOTAL -
3ABCOCK t WILCOI
LIME
LIMESTONE
LIME/SPRAT DRYING
TOTAL -
9UELL/ENVIROTECH
DUAL ALKALI
TOTAL -
3UREAU OF MINES
CITRATE
TOTAL -
CHEMICO
LIME
LIMESTONE
LIME/ALKALINE FLTASH
LIME /LIMESTONE
TOTAL -
CHIYODA INTERNATIONAL
LIMESTONE/THOROUGHBRED 121
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLTASH
LIME /LIMESTONE
TOTAL -
»AVY POWER6AS
UELLHAN LORD
TOTAL -
FMC CORPORATION
DUAL ALKALI
TOTAL -
JOY MFC. CO* WESTERN PRECIPITA
LIME/SPRAY DRYING
TOTAL -
NO.
1
1
5
3
10
2
4
1
1
6
6
1
7
3
7
1
11
1
1
1
1
7
1
4
1
13
1
1
4
7
2
2
2
17
6
6
1
1
1
1
MW
288.
500.
2525.
375.
3688.
822.
1896.
10.
550.
3278.
1673.
280.
1953.
1688.
2477.
600.
4765.
617.
617.
60.
60.
3840.
800.
895.
10.
5545.
23.
23.
442.
2932.
1480.
654.
708.
6216.
2074.
2074.
265.
265.
440.
440.
OPERATIONAL
NO.
1
0
3
3
7
2
2
1
0
5
3
0
3
1
3
0
4
0
0
0
0
6
1
0
1
8
1
1
4
3
2
0
0
9
3
3
1
1
0
0
MW
288.
0.
1125.
375.
1788.
822.
726.
10.
0.
1558.
694.
0.
694.
519.
1198.
0.
1717.
0.
0.
0.
0.
3480.
800.
0.
10.
4290.
23.
23.
442.
1085.
1480.
0.
0.
3007.
826.
826.
265.
265.
0.
o.
CONSTRUCTION
NO.
0
1
0
0
1
0
1
0
1
2
3
0
3
2
3
0
5
1
1
1
1
1
0
3
0
4
0
0
0
3
0
2
2
7
3
3
0
0
0
0
HU
0.
500.
0.
0.
500.
0.
450.
0.
550.
1000.
979.
0.
979.
1169.
915.
0.
2084.
617.
617.
60.
60.
360.
0.
579.
0.
939.
0.
0.
0.
1447.
0.
654.
708.
2809.
1248.
1248.
0.
0.
0.
0.
CONTRACT
AWARDED
NO.
0
0
2
0
2
0
1
0
0
1
0
1
1
0
1
1
2
0
0
0
0
0
0
1
0
1
0
0
0
1
0
0
0
1
0
0
0
0
1
1
MW
3.
0.
1400.
0.
1400.
0.
720.
0.
0.
720.
0.
280.
280.
0.
364.
600.
964.
3.
0.
0.
0.
0.
0.
316.
0.
316.
0.
0.
0.
400.
0.
0.
0.
*oo.
o.
0.
0.
0.
440.
440.
-------
EPA UTIL1TT F6D SURVEY: SECOND QUARTER 1979
SECTION 5
SUMART OF FGD SYSTEMS BY SYSTEM SUPPLIER
TOTAL
STATUS
OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
SYSTEM SUPPLIER/PROCESS
MITSUBISHI INTERNATIONAL
LIMESTONE
TOTAL -
PEABODV PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
PULLMAN KELLOGG
LIME
LIMESTONE
TOTAL -
RESEARCH COTTRELL
LIMESTONE
TOTAL -
RILEY STDKER/ENVIRONEERING
LIMESTONE
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
LIME
MAGNESIUM OXIDE
TOTAL -
VENDOR NOT SELECTED
LIMESTONE
TOTAL -
HHEELABRftTOR-FRVE/R .1.
AQUEOUS CARBONATE/ SPRAY DRYING
TOTAL -
NO.
2
2
4
1
5
1
4
5
13
13
3
3
1
1
1
1
2
1
3
2
2
1
1
MU
882.
832.
1252.
475.
1727.
917.
1880.
2797.
5455.
5455.
664.
664.
100.
100.
550.
550.
1510.
120.
1630.
1408.
1408.
440.
440.
NO.
0
0
2
0
2
0
0
0
7
7
3
3
0
0
1
1
0
1
1
0
0
3
0
MU
0.
0.
358.
0.
358.
0.
0.
0.
2644.
2644.
664.
664.
0.
0.
550.
550.
0.
120.
120.
0.
0.
0.
0.
NO.
2
2
2
1
3
1
3
4
5
5
0
0
0
0
0
0
0
0
0
0
0
1
1
MU
882.
882.
894.
475.
1369.
917.
1230.
2147.
2061.
2061.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
440.
440.
NO.
0
0
0
0
0
0
1
1
1
1
0
0
1
1
0
0
2
0
2
2
2
0
0
NU
0.
0.
0.
0.
3.
0.
650.
650.
750.
750.
0.
0.
103.
100.
0.
0.
1513.
0.
1513.
UO?.
1409.
0.
3.
TOTAL -
113 44577.
55 18504.
42 17135.
16 8938.
133
-------
= PA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 6
SUMMARY OF F66 SYSTEMS BY PROCESS
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
PLANNED
PROCESS
NO.
NO.
MM
NO.
My
NO*
MM
NO.
ABUEOJS CARBOMATE
CITRATE
LIMESTO«E/THO*OUGHBRED 121
MIGNESJUM OXIDE
WfLLN»N LORD
1
1
1
5
6
100.
60.
23.
14*4.
2074.
0
0
1
1
3
0.
0.
23.
120.
826.
0
1
0
0
3
0.
60.
0.
0.
1248.
1
0
0
0
0
100.
0.
0.
0.
0.
0
0
0
4
0
0.
0.
0.
1324.
0.
SUBTOTAL - SALEABLE PRODUCT 14 3701.
ABUEOtlS CARB01ATE/SPRAY DRYIN6
DUAL 4LKALI
LIME
LIMESTONE
LIMESTONE/ALKALINE FLVASH
LIME/ALKALINE FLVASH
LINE/LIMESTONE
LIME/SPRAT DRYING
P40CESS NOT SELECTED
SDDIU1 CARBONATE
SUBTOTAL - THROMAMAY PRODUCT 148 68230.
969.
4 1308.
100.
50 17535.
38 15827.
15 8838.
4 1324.
1
t
26
59
2
12
5
2
34
4
440.
1170.
11392.
26884.
1480.
4549.
1328.
1040.
19022.
925.
0
2
16
22
2
3
2
0
0
3
0.
553.
5957.
8025.
1480.
1125.
20.
0.
0.
375.
1
1
8
19
0
6
2
0
0
1
440.
617.
3925.
7879.
0.
1708.
708.
0.
0.
550.
0
0
2
8
0
3
0
2
0
0
0.
0.
1510.
4572.
0.
1716.
0.
1040.
0.
0.
0
0
0
10
0
0
1
0
34
0
0.
0.
0.
6409.
0.
0.
600.
0.
19022.
0.
45 26030.
TOTALS 162 71931. 55 18504. 42 17135. 16 8938. 49 27354.
SALEABLE X OF TOTAL MM 55815
134
-------
EPA UTILITY FC0 SURVET: SECOND QUARTER 1979
SECTION 7
SUMMARY OF OPERATIONAL F6D SYSTEMS BT PROCESS AND UNIT
PROCESS/
UNIT NANE
DUAL ALKALI
A.B. BROWN
CANE RUN
LIME
9RUCE MANSFIELD
9RUCE MANSFIELD
CANE RUN
CANE RUN
CONESVILLE
CONESVILLE
ELRANA
6REEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTIN6TON
MILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS
LIMESTONE
APACHE
APACHE
CHOLLA
CHOLLA
»UCK CREEK
JEFFREY
LA CT6NE
LAURENCE
LAWRENCE
MARION
MARTIN LAKE
MARTI* LAKE
MARTIN LAKE
MONTICELLO
PETERSBURG
R.D. HORROW
(.0. HORROW
SOUTHWEST
TONBIGBEE
TOMBI6BEE
WIDOWS CREEK
rtlNVAH
LIMESTONE/ALKALINE FLYASH
SHERSURNE
SHERBURNE
LIMESTONE/THOROUGHBRED 121
SCHOLZ
LIME/ALKALINE FLYASH
COLSTRIP
COLSTRIP
MILTON R. YOUN6
UNIT NO.
1
6
1
2
4
5
5
6
-4
-3
3
6
1-6
1
2
3
1
2
1
1
1
4
5
4
1
2
3
3
3
1
2
1
2
3
e
2
1
2
1,2
1
2
2
CAPACITY
BH
265.
288.
553.
917.
917.
188.
190.
411.
411.
510.
64.
90.
90.
360.
366.
442.
72.
410.
519.
5957.
195.
195.
119.
350.
416.
540.
874.
125.
420.
1S4.
595.
595.
595.
800.
532.
124.
124.
194.
179.
179.
550.
140.
P025.
740.
740.
148Q.
23.
23.
360.
360.
405.
INITIAL
STARTUP
3/79
4/79
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
8/78
9/75
5/76
9/77
COMMERCIAL
STARTUP
O/ 0
O/ 0
6/76
10/77
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
O/ 0
e/78
O/ 0
6/73
O/ 0
O/ 0
O/ 0
10/78
O/ 0
O/ 0
10/78
O/ 0
O/ 0
O/ 0
O/ 0
O/ 0
O/ 0
1/78
01 0
5/76
4/77
O/ 0
11/75
10/76
6/78
1125.
135
-------
"A UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 7
SUMMARY OF OPERATIONAL F60 SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
LIVE/LIMESTONE
SHAHNEE
SHAUNEE
MAGNESIUM OXIDE
EDDVSTONE
SODIUM CARBONATE
REID GARDNER
EID GARDNER
REID GARDNER
VELLMAN LORD
DEAN H. MITCHELL
SAN JUAN
SAN JUAN
UNIT NO.
IDA
10B
1A
1
2
3
11
1
2
CAPACITY
MW
10.
10.
20.
120.
123.
125.
125.
125.
375.
115.
361.
350.
INITIAL
STARTUP
4/72
4/72
9/75
4/74
4/74
6/76
7/76
4/78
8/78
COMMERCIAL
STARTUP
O/ 0
O/ 0
9/75
O/ 0
O/ 0
7/76
6/77
O/ 0
O/ 0
826.
TOTAL
18504.
136
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION 8
SU4NARV OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL F66 SYSTEMS
PROCESS/
NIT NAME
THROVAUAV
UNIT NO STABILIZED UNSTABILIZED
-BYPRODUCT-
TYPE
DISPOSITION
DUAL ALKALI
«.B. BROUN
CANE RUN
LINE
3RUCE MANSFIELD
SRUCE MANSFIELD
CANE RUN
CANE RUN
CONESVILLE
CONESVILLE
ELRA4A
EREE* RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTIN6TON
JILL CREEK
PADDY'S *UN
PHILLIPS
PLEASANT*
LIMESTONE
APACHE
APACHE
CHOLLA
CHOLLA
DUCK CREEK
JEFFREY
LA CY6NE
LAWRENCE
LAWRENCE
4ARIDN
MARTIN LAKE
MARTIN LAKE
* All TIN LAKE
'ONTI CELLO
PETERSBURG
t»D. MORROW
«.D. MORROW
SOUTHWEST
TONBIGBEE
TONBIGBEE
UIDOtfS CREEK
4INVAH
LINESTONE/ALK ALINE
SHER9URNE
SHER3URNE
1
2
4
5
-4
-3
-6
2
3
1
2
1
1
1
4
s
4
1
2
3
3
3
1
2
1
2
3
8
2
FLYASH
1
2
1
2
4
5
5
6
1-4
1-3
3
4
1
1
3
6
1-6
1
LANDFILL
LANDFILL
LINED POND
LANDFILL
LANDFILL
LANDFILL
POND
POND
POND
LANDFILL
POND
POND
LANDFILL
LIHESTONE/THOROUGHBRED 121
SCHOLZ 1«2
LINE/ALKALI HE FLYASH
COLSTRIP 1
COLSTRIP 2
'ILT9N R. YOUN6 2
LIME/LIMESTONE
SHAWNEE 10A
SHAWIIEE 1DB
LANDFILL
LINED POND
LINED POND
LINED POND
POND
POND
POND
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
LANDFILL
LANDFILL
LANDFILL
LINED POND
LINED POND
LINED POND
LINED POND
POND
POND
POND
POND
LINED POND
UNLINED POND
POND
POND
GYPSUM
STACKED IN POND
POND
POND
flINEFILL
137
-------
EPA JTILITf F6D SURVEY: SECOND QUARTER 1979
SECTION fi
SU'NARV OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
ROCESS/
UNIT NAME
THROW*WAY
UNIT NO STABILIZED UNSTABILIZED
-BYPRODUCT-
TYPE
DISPOSITION
'AGNESIU4 OXIDE
EDDVSTONE
SODIUM CARBONATE
»EID GARDNER
»EID GARDNER
«EID GARDNER
'ELLVAN LORD
9EAN H. 'ITCHELL
SAN JUAN
SAN JUAN
1A
11
1
2
SULFURIC ACID
POND
POND
POND
POND
COAL MINE
ELEMENTAL SULFUR
ELEMENTAL SULFUR MARKETED
ELEMENTAL SULFUR AND MARKETED
13S
-------
EPA UTILITY F6D SURVEY: SECOND 9UARTER 1979
SECTION 9
SUMMARY OF F6B SYSTEMS IN OPERATION
COMPANY HAKE/
UNIT NAME UNIT NO.
ALABAMA ELECTRIC COOP
TOMBI6BEE 2
ALABAMA ELECTRIC COOP
TONBIGBEE 3
ALLEGHENY POtfER SYSTEM
PLEAS ANTS 1
ARIZ9NA 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
COLU'BUS t SOUTHERN OHIO ELEC.
CONESVILLE 5
COLUHBUS t SOUTHERN OHIO ELEC.
CONESVILLE 6
»UQUESNE LIGHT
ELRA4A 1-4
DUQUESNE LIGHT
PHILLIPS 1-6
BULF POWER
SCHOLZ 1.2
INDIANAPOLIS POWER t LIGHT
»ETE»SBUR6 3
KANSAS CITY POWER t LIGHT
HAWTHORN 3
KANSAS CITY POWER t LIGHT
HAWTHORN 4
KANSAS CITY POWER t LIGHT
LA CYGNE 1
KANSAS POWER K LIGHT
JEFFREY 1
KANSAS POWER t LIGHT
LAWRENCE 4
KANSAS POWER t LIGHT
LAWRENCE 5
KENTUCKY UTILITIES
6REE* RIVER 1-3
LOUISVILLE GAS » ELECTRIC
CANE RUN 4
LOUISVILLE GAS t ELECTRIC
CANE RUN 5
LOUISVILLE GAS I ELECTRIC
CANE RUN 6
NEW OR 1
RETROFIT
NEW
NEW
NEW
HEW
NEW
RETROFIT
NEW
NEW
HEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
CAPACITY
HW
179.0
179.0
519.0
195.0
195.0
119.0
S50.0
416.0
411.0
411.0
510.0
410.0
23.0
532.0
90.0
90.0
374.0
540.0
125.0
420.0
64.0
188.0
190.0
2BS.O
PROCESS/ !
SYSTEM SUPPLIER
LIMESTONE
PEA60DV PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
8A6COCK t WILCOI
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RILEY STOKER/ENVIRONEERING
LIME
AIR CORRECTION DIVISION, UOP
LIME
AIR CORRECTION DIVISION, UOP
LIME
CHEHICO
LIME
CHEHICO
LIMESTONE/THOROUGHBRED 121
CHIYODA INTERNATIONAL
LIMESTONE
AIP CORRECTION DIVISION. UOP
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
9ABCOCK C WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
DUAL ALKALI
ADL/COMBUSTION E8UIP ASSOCIATE
START-UP
DATE
9/78
6/79
3/79
8/78
6/79
10/73
4/78
9/76
1/77
6/7!
10/75
7/73
8/78
12/77
11/72
8/72
2/73
B/78
1/76
11/71
9/75
8/76
12/77
4/79
139
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 9
SUNHftRV OF FED SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
LOUISVILLE GAS I ELECTRIC
HILL CREEK 3
LOUISVILLE GAS t ELECTRIC
PADDY'S RUN 6
4INNKOTA POWER COOPERATIVE
4ILT9N R. YOUN6 2
MONTANA POWER
COLSTRIP 1
MONTANA POWER
COLSTRIP 2
NEVADA POWER
REID GARDNER 1
DEVADA POWER
REID GARDNER 2
NEVADA POWER
REID GARDNER 3
NORTHERN INDIANA PUB SERVICE
»EAN H. MITCHELL 11
NORTHERN STATES POKER
SHER9URNE 1
NORTHERN STATES POWER
SHER3URNE 2
PENNSYLVANIA POWER
3RUCE MANSFIELD 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
PHILADELPHIA ELECTRIC
EDDYSTONE 1A
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 2
SOUTH CAROL 11 A PUBLIC SERVICE
WINVAH 2
SOUTHERN ILLINOIS POWER COOP
4ARI9N 4
SOUTHERN INDIANA GAS t ELEC
A.B. BROWN 1
SOUTHERN MISSISSIPPI ELECTRIC
».D. MORROW 1
SOUTHERN MISSISSIPPI ELECTRIC
R.D. MORROW 2
SPRIV6FIELD CITY UTILITIES
SOUTHWEST 1
TENNESSEE VALLEY AUTHORITY
SHAMHEE 10A
TENNESSEE VALLEY AUTHORITY
NEW OR
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
CAPACITY
HW
442.0
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
184.0
265.0
124.0
124.0
194.0
10.0
10.0
PROCESS/
SYSTEM SUPPLIER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
LIME/ALKALINE FLVASN
ADL/COMBUSTION EBUIP ASSOCIATE
LIME/ALKALINE FLYASH
ADL/COMBUSTION EBUIP ASSOCIATE
LIME/ALKALINE FLVASH
ADL/COMBUSTION EBUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EBUIP ASSOCIATE
SODIUM CARBONATE
ADL/CONBUSTION EBUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
WELLMAN LORD
DAVY POWER6AS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME
CHEHICO
LIME
CHEMICO
MAGNESIUM OXIDE
UNITED ENGINEERS
WELLMAN LORD
DAVY POWER6AS
WELLMAN LORD
DAVY POWERGAS
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
BABCOCK t WILCOX
DUAL ALKALI
FMC CORPORATION
LIMESTONE
RILEY STOKER/ENVIRONEERING
LIMESTONE
RILEY STOKER/ENVIRONEERING
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
START-UP
DATE
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
5/79
3/79
8/78
6/79
4/77
4/72
4/7?
CHEMICO
140
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 9
SUMMARY Of FCD SYSTEMS IN OPERATION
COMPANY NAMES
UNIT NINE
NEW OR CAPACITY PROCESS/
UNIT NO. RETROFIT MW SYSTEM SUPPLIER
START-UP
OATE
TENNESSEE VALLEY AUTHORITY
I»OIIS CREEK 8
TEXAS UTILITIES
4ARTIN LAKE 1
TEXAS UTILITIES
NAMTIN LAKE 2
TEXAS UTILITIES
4ARTIN LAKE 3
TEXAS UTILITIES
40NTICELLO 3
UTAH POWER I LIGHT
HUNTER 1
UTAH POWER t LI6HT
HUNTINGTON 1
RETROFIT 550.0 LIMESTONE 5/77
TENNESSEE VALLEY AUTHORITY
NEW 595.0 LIMESTONE */77
RESEARCH COTTRELL
NEW 595.0 LIMESTONE 5/78
RESEARCH COTTRELL
NEW 595.0 LIMESTONE 2/79
RESEARCH COTTRELL
NEW 800.0 LIMESTONE 5/76
CHENICO
NEW 360.0 LIME 5/79
CHEMICO
NEW 366.0 LIME 5/78
CHEMICO
141
-------
PA JTILITT F60 SURVEY: SECOND QUARTER 1979
SECTION 10
SUMMARY OF FGO SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
ALLEGHENY POrfER SYSTEM
OLEASANTS l
ARIZONA PUBLIC SERVICE
CNOLLA 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZ9NA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
ASSOCIATED ELECTRIC COOP
THOMAS HILL 3
3 AS 11 ELECTRIC POWER COOP
LARAME RIVER 1
3ASIN ELECTRIC POWER COOP
LARA4IE RIVE« 2
316 RIVERS ELECTRIC
SREEH 1
916 RIVERS ELECTRIC
CREEH 2
CENTRAL ILLINOIS PUBLIC SERV
VEUTON 1
CINCINNATI 6AS t ELECTRIC
EAST BEND 2
COLORADO UTE ELECTRIC ASSN.
CRAI6 1
COLORADO UTE ELECTRIC ASSN.
CRA16 2
COMMONWEALTH EDISON
POUEtTON 51
COOPERATIVE "ODER ASSOCIATION
COAL CREEK 1
COOPERATIVE "OWER ASSOCIATION
COAL CREEK 2
DELMARVA POWER t LI6HT
DELAWARE CITY 1-3
EAST KENTUCKY POWER COOP
SPURLOCK 2
MOOSIER ENER6V
«ERO« 1
HOOSIER ENERGV
NERO* 2
INDIANAPOLIS POWER t LI6HT
PETERSBURG *
KANSAS POWER t LI6HT
JEFFREY 2
LOUISVILLE 6AS t ELECTRIC
NEW OR
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
CAPACITY
MW
51«.0
126.0
175.0
175.0
229.0
670.0
600.0
600.0
242.0
242.0
617.0
650.0
447.0
447.0
450.0
327.0
327.0
180.0
500.0
441.0
441.0
530.0
490.0
358.0
PROCESS/
SYSTEM SUPPLIER
LIME
BABCOCK C WILCOX
LIMESTONE
RESEARCH COTTRELL
LIME/ALKALINE FLYASH
CHEMICO
LIME/ALKALINE FLYASH
CHEMICO
LIME/ALKALINE FLYASH
CHEMICO
LIMESTONE
PULLMAN KELL066
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
RESEARCH COTTRELL
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
DUAL ALKALI
BUELL/ENVIROTECH
LIME
BABCOCK t WILCOX
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION. UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
UELLMAN LORD
DAVY POWER6AS
LIME
ADL/COMBUSTION E9UIP ASSOCIATE
LIMESTONE
MITSUBISHI INTERNATIONAL
LIMESTONE
MITSUBISHI INTERNATIONAL
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
COMBUSTION ENGINEERING
LIME/LIMESTONE
START-UP
DATE
9/80
6/80
0/79
0/79
0/79
1/82
4/80
10/80
10/79
6/80
11/79
10/81
8/79
11/79
11/79
7/79
10/80
4/80
10/80
4/81
1/82
10/83
6/80
4/81
COMBUSTION ENGINEERING
142
-------
EPA UTILITY F6P SURVET: SECOND QUARTER 1979
SECTION 10
SUMMARY OF F60 SYSTEMS UNDER CONSTRUCTION
COHPANV MAKE/
UNIT MAKE UNIT NO.
LOUISVILLE CAS I ELECTRIC
'ILL CREEK 2
LOUISVILLE CAS 1 ELECTRIC
JILL CREEK 4
MINNESOTA POWER I LI6HT
CLAY BOSUELL I
3TTEI TAIL POWER
COYOTE 1
PACIFIC POWER 1 LICHT
JIN 3RIDCER 4
PENNSYLVANIA POWER
9RUCE MANSFIELD 3
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 4
SALT RIVER PROJECT
CORONADO 1
SALT RIVER PROJECT
CORONADO 2
SAN NI6UEL ELECTRIC COOP
SAN NIGUEL 1
SIKESTON BOARD OF MUNIC. UTIL.
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
WINYAM 3
SPRINGFIELD WATER, LIGHT t PWR
9ALL1AN 3
ST. JOE ZINC
E.F. WEATON 1
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TEXAS POWER 1 LIGHT
SANDOW *
UTAH POWER t LIGHT
HIIMTPB 2
NEW OR 1
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
CAPACITY
MW
350.0
495.0
475.0
440.0
550.0
917.0
534.0
534.0
ZBO.O
280.0
(00.0
235.0
280.0
205.0
60.0
575.0
382. 0
360.0
PROCESS/ !
SYSTEM SUPPLIER
LINE/LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME/ALKALINE FLYASH
PEABODT PROCESS SYSTEMS
AQUEOUS CARBONATE/SPRAY DRYING
WHEEL ABRATOR-FRTE/ R.I.
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
LIME
PULLMAN KELLOGG
WELLMAN LORD
DAVY POWERGAS
WELLMAN LORD
DAVY POUERGAS
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
9A6COCK 1 W1LCOX
LIMESTONE
BABCOCK I WILCOX
LIMESTONE
BABCOCK 1 WILCOX
LIMESTONE
RESEARCH COTTRELL
CITRATE
BUREAU OF MINES
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
CHEMICO
START-UP
DATE
4/82
7/81
5/80
5/81
9/79
4/80
9/79
1/82
8/79
1/80
8/80
11/80
5/80
7/80
7/79
10/80
7/80
6/80
143
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION 11
SUMMARY OF CONTRACT AWARDED FGD SYSTEMS
COMPANY NAME/
UNIT NIME UNIT NO.
ARIZ9NA PUBLIC SERVICE
FOUR CORNERS 4
4RIZ9NA PUBLIC SERVICE
FOUR CORNERS 5
3ASI1 ELECTRIC POWER COOP
ANTELOPE VALLEY 1
3ASIV ELECTRIC POWER COOP
LARA1IE RIVE* 3
LAKELAND UTILITIES
4CINTOSH 3
MONTANA POWE*
COLSTRIP 3
MONTANA POWER
COLSTRIP 4
NIAGARA 40HA4K POWER COOP
CHARLES R. HUNTLEV 66
PUBLIC SERVICE OF INDIANA
SIBSDN 5
SOUTH CAROLINA PUBLIC SERVICE
WINY4H 4
SOUTHWESTERN ELECTRIC POWER
HENRY W. PERCEV 1
TENNESSEE VALLEY AUTHORITY
PARADISE 1
TENNESSEE VALLEY AUTHORITY
PARADISE 2
TEXAS «UNICI»AL POWER A6ENCY
SIBB9NS CREEC 1
TEXAS UTILITIES
NARTIN LAKE 4
rilSONSM POWER 1 LI6HT
MEW OR
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
CAPACITY
HW
755.0
755.0
440.0
600.0
364.0
700.0
700.0
100.0
650.0
380.0
720.0
704.0
704.0
400.0
750.0
316.0
PROCESS/
SYSTEM SUPPLIER
LIFE
UNITED ENGINEERS
LIME
UNITED ENGINEERS
LIME/SPRAY DRYING
JOY MFG. CO, WESTERN PRECIPITA
LIME/SPRAY DRYING
BABCOCK t UILCOX
LIMESTONE
BABCOCK t WILCOX
LINE/ALKALINE FLYASH
ADL/COMBUSTION E8UIP ASSOCIATE
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
AQUEOUS CARBONATE
ROCKWELL INTERNATIONAL
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
AIR CORRECTION DIVISION* UOP
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH COTTRELL
LIME/ALKALINE FLYASH
START-UP
DATE
0/82
0/82
11/81
4/82
10/81
7/80
7/81
0/82
0/82
5/81
2/84
6/82
3/82
1/82
0/85
1/82
CHEHICO
144
-------
EPA UTILITY FED SURVEY: SECOND QUARTER 1979
SECTION 12
SUMMARY OF PLANNED F6D SYSTEMS
COMPANY NAME/
UNIT N»HE
MEW OR CAPACITY PROCESS/
UNIT NO. RETROFIT MM SYSTEM SUPPLIER
START-OP
DATE
LETTER OF INTENT SIGNED
NEU
NORTHERN STATES POWER
SHER9URNE
PHILADELPHIA ELECTRIC
EDDYSTONE
860.0
IB
RETROFIT
REQUESTING/EVALUATING BIDS
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
HOUSTON LIGHTING t POWER CO.
W.A. PARISH 8
MIDDLE SOUTH UTILITIES
ARKA4SAS COAL 5
MIDDLE SOUTH UTILITIES
ARKANSAS COAL 6
MIDDLE SOUTH UTILITIES
LOUISIANA COAL 1
MIDDLE SOUTH UTILITIES
LOUISIANA COAL 2
MIDDLE SOUTH UTILITIES
MISSISSIPPI COAL 1
MIDDLE SOUTH UTILITIES
MISSISSIPPI COAL 2
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
NORTHERN INDIANA PUB SERVICE
SCHAHFER 18
SENI10LE ELECTRIC
SENIHOLE 1
SEMIKOLE ELECTRIC
SEMIHOLE 2
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE 1-10
TEXAS POWER t LIGHT
TWIN OAKS 1
TEXAS POWER t LIGHT
TWIN OAKS 2
TEXAS UTILITIES
FOREST GROVE 1
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
416.0
512.0
S90.0
890. 0
990.0
890.0
890.0
890.0
421.0
421.0
620.0
620.0
600.0
750.0
750.0
750.0
CONSIDERING FGD SYSTEMS
ALLEGHENY POWER SYSTEM
MITCHELL 3
3ASIH ELECTRIC POWER COOP
ANTELOPE VALLEY 2
CENTRAL MAINE POWER
SEARS ISLAND 1
COLUMBUS t SOUTHERN OHIO ELEC.
RETROFIT
NEW
NEW
NEW
300.0
440.0
600.0
375.0
LIMESTONE
COMBUSTION ENGINEERING
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
MAGNESIUM OXIDE
TVA/UNITED ENGINEERS
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME/LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
5/84
6/80
1/84
10/82
1/86
1/38
0/86
0/88
0/95
0/87
6/83
6/8>
6/83
6/85
0/82
8/84
3/85
8/82
11/83
11/87
0/83
US
-------
EPA UTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION 12
SUMARY Of PLANNED F6D SYSTEMS
COMPANY NAME/
UNIT NIKE UNIT NO.
COLUMBUS fc SDUTHERN OHIO ELEC.
»> os TON «
SENERAL PUBLIC UTILITIES
COHO 1
GENERAL PUBLIC UTILITIES
SEHARD 7
LOUISVILLE 6AS 1 ELECTRIC
TRIMBLE COUNTY 1
LOUISVILLE 6AS 1 ELECTRIC
TRIMBLE COUNTY 2
'USCATINE POrfER t HATER
*USC«TINE 9
NEVADA POWER
HARRY ALLEN 1
NEVADA POUER
MARRY ALLEN 2
NEVADA POUER
MARRY ALLEN 3
NEVADA POUER
MARRY ALLEN 4
NEVADA POUER
REID GARDNER 4
NEVADA POUER
EARNER VALLEY 1
NEVADA POUER
EARNER VALLEY 2
NORTHERN INDIANA PUB SERVICE
9A1LLY 7
NORTHERN INDIANA PUB SERVICE
9AILLV 8
PACIFIC GAS I ELECTRIC
FOSSIL 1
PACIFIC 6AS t ELECTRIC
FOSSIL 2
PHILADELPHIA ELECTRIC
CRON9V
PHILADELPHIA ELECTRIC
EDDVSTONE 2
POT01AC ELECTRIC POUER
DICKERSON 4
POUER AUTHORITY OF NEW YORK
ARTHUR KILL
SALT RIVER PROJECT
CORONADO 3
SOUTHERN ILLINOIS POWER COOP
4ARI9N 5
TAMPA ELECTRIC
NEU OR
RETROFIT
NEU
NEW
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
RETROFIT
RETROFIT
NEU
NEU
RETROFIT
RETROFIT
NEU
NEU
NEU
NEU
NEU
CAPACITY
MU
375.0
800.0
800.0
575.0
575.0
160.0
500.0
500.0
500.0
500.0
250.0
250.0
250.0
190.0
400.0
800.0
BOO.O
150.0
334.0
800.0
700.0
280.0
300.0
450.0
PROCESS/
SYSTEM SUPPLIER
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
MAGNESIUM OXIDE
UNITED ENGINEERS
MA6NESIUM OXIDE
UNITED ENGINEERS
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
START-UP
DATE
0/89
5/88
12/85
7/84
0/86
0/82
6/85
6/86
6/87
6/88
0/83
6/84
6/85
O/ 0
O/ 0
6/86
6/87
6/80
6/80
0/87
11/88
0/87
0/84
3/85
916 BEND
VENDOR NOT SELECTED
146
-------
EPA UTILITY F6D SURVEY: SECOND ttUARTER 1979
SECTION 12
SUMARY OF PLANNED F6D SYSTEMS
COMPANY NAME/ NEy OR CAPACITY PROCESS/ START-UP
UNIT NAME UNIT NO. RETROFIT NU SYSTEM SUPPLIER DATE
TENNESSEE VALLEY AUTHORITY RETROFIT 600.0 PROCESS NOT SELECTED 7/82
CUMBERLAND VENDOR NOT SELECTED
TEIAS UTILITIES NEW 750.0 PROCESS NOT SELECTED 0/85
4ILL CREEK 1 VENDOR NOT SELECTED
TEIAS UTILITIES NEU 750.0 PROCESS NOT SELECTED 0/86
HILL CREEK 2 VENDOR NOT SELECTED
147
-------
EPA UTILITT FCD SURVEY: SECOND QUARTER 1979
SECTION 13
TOTAL F6D UNITS AND CAPACITY fNH> INSTALLED BY YEAR
YEAR
1968
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
198*
1985
1986
1987
1988
UNDEFINED
MEM
NO.
1
3
8
8
3
6
8
10
13
22
23
10
19
6
7
10
6
7
5
20
ON LINE
NU
0.
420.
200.
1475.
250.
1971.
2069.
4674.
4736.
7242.
9117.
4918.
9326.
2636.
3871.
6181.
4405.
3870.
3780.
1240.
TERU
NO.
0
0
0
1
0
0
1
0
0
0
0
0
0
0
1
0
0
0
0
IINATED
My
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
250.
0.
0.
0.
3.
TOTA
NO.
1
4
12
19
22
28
35
45
58
80
103
113
132
138
144
154
160
167
172
L ON LINE
HW
0.
420.
620.
2095.
2345.
4316.
6385.
11059.
15795.
23037.
32154.
37072.
46398.
49034.
52655.
58S36.
63241.
67111.
70891.
146
-------
EPA UTILITY FC-D SURVEY: SECOND QUARTER 1979
SECTION U
DESIGN AND PERFORMANCE DATA FOR 3PERATIOHAL PARTICULATE SCRUBBERS
COMPANY NAPE
PLANT N«HE
UNIT NUMBER
CITT
STATE
RE6ULAT3RY CLASSIFICATION
PARTICULATE EMISSION LIMITATION S6/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - Mh
NET UNIT GENERATING CAPACITY W/FGD - Mb
NET UNIT GENERATING CAPACITY WO/FGD - HU
EQUIVALENT SCRUBBED CAPACITY - HW
.* 30ILER 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
COMMONWEALTH EDISON
rilLL COUNTY
1
ROMEOVILLE
ILLINOIS
»*****
( .000 LB/MMBTU)
( 1.800 LB/MMBTU)
0.
774.
1147.0
167.0
137.0
.0
.C
BABCOCK R UILCOX
WET BOTTOM. CYCLONE
CYCLIC
0/55
363.36 ( 770000 *CFM)
179.4 ( 355 F)
107. t 350 FT)
3.8 ( 12.4 FT)
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANSE HEAT CONTENT - BTU/LE
AVERAGE ASH CONTENT - Z
RANSE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
RANSE MOISTJRE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MU
COAL
******
22260.
7.40
3-16
«***
***** *
1.50
0.3 4.5
********
******
77.1
167
t 9570 BTU/LB)
9.100 - 10,500
< 85 TPH)
ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY - Z
FLUE EAS TEMPERATURE - C
PARTICULATE SCRUBBER
NUH9ER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
TYPE OF NOZZLES
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DR9P - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - 6/CU.P
PARTICULATE DESIGN REMOVAL EFFICIENCY - Z
1
COLD SIDE
WESTERN PRECIPITATION (JOY MANUFACTURING)
79.0
179.4 ( 355 ft
ADJUSTABLE THROAT VENTURI
BABCOCK t WILCOX
CARBON STEEL
PLASITE AND It ACCRETE
STAINLESS STEEL
181.7
179.4
365.4
2.4
2.2
36.6
.4
99.0
385000 ACFM)
355 F)
5800 6P»)
18.0 6AL/1000ACF)
9 IN-H20)
120.0 FT/S)
.16 GR/SCF)
149
-------
£P* UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION U
DESIGN AND PERFORNAKCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAPE
PLAUT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLA«T GENERATING CAPACITY - HW
GROSS U
-------
EPA UTILITY F60 SURVEY: SECOND 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 - NG/J
$02 EMISSION LIMITATION - N6/J
NET PLAMT GENERATING CAPACITY - MU
GROSS UKIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - MM
NET UNIT GENERATING CAPACITY VO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MU
30XLER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOU - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 1
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MU
PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL 6AS VELOCITY - M/S
PARTICULATE INLET LOAD - 6/CU.M
PARTICULATE OUTLET LOAD - 6/CU."
502 INLET CONCENTRATION - PPM
SOZ OUTLET CONCENTRATION - PPM
SOZ DESIGN REMOVAL EFFICIENCY - t
MINNESOTA POWER t LIGHT
AURORA
1
AURORA
MINNESOTA
*
( .000 L9/MHBTU)
(*« LB/MMBTU)
0.
**
116.0
*«*
58.0
.0
.0
COMBUSTION ENGINEERING
PULV. COAL. DRY BOTTOM, TANG. FIRED
««*
0/53
141.57 ( 300000 ACFM)
171.1 ( 340 F>
* (** FT)
**** ( FT)
COAL
SU6BITUMINOUS
20469.
9.00
*
26.70
*
1.37
( 8800 BTU/LB)
**
0.01-0.07
*
**
( TPH)
ELBAIR SPRAY-IMPINGEMENT
KREBS ENGINEERING
316 ELC STAINLESS STEEL
FLAKE-POLYESTER
100.0
137.4
171.1
1.1
.7
2.1
4.7
.1
800.000
500.000
37.0
( 291160 ACFM)
C 340 F)
< 8.3 GAL/1000ACF)
3 IN-H20)
7.0 FT/S)
2.06 6R/SCF)
.040 6R/SCF)
151
-------
:PA UTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITT
STATE
REGULAT3RY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - NGSJ
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - Mfc
NET UNIT GENERATING CAPACITY U/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGt - MU
EQUIVALENT SCRU9BEO CAPACITY = MU
30ILFR DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW CU.P/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - "
STACK TOP DIAMETER - M
FUEL DAT*
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANEE HEAT CONTENT - BTU/L6
AVERAGE ASH CONTENT - X
RANEE ASH C3NTENT - Z
AVERAGE MOISTURE CONTENT - t
RANEE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - Z
RANEE SULFU* CONTENT - Z
AVERAGE CHL3RIDE CONTENT - Z
RANEE CHLORIDE CONTENT - Z
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - My
* PARTICULATE SCRUBBER
NUN9ER
TYPE
SUP»LIER
SHELL MATERIAL
LINING MATERIAL
BOILER LOAD/SCRUBBER - Z
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - c
L/6 RATIO - LITER/CU.M
PRESSURE DRDP - KPA
SUPERFICIAL 6A$ VELOCITY - M/S
PARTICULATE INLET LOAD - 6/CU.M
PARTICULATE OUTLET LOAD - 6/CU."
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
< .000 LB/MHBTU)
(***. LB/MMBTU)
MINNESOTA POWER C LIGHT
AURORA
2
AURORA
MINNESOTA
**»»
0.
******
116.0
*****
58.0
.0
.0
COMBUSTION ENGINEERING
PULV. COAL. DRV BOTTOM, TANG. FIRED
******
0/53
141.57 ( 300000 ACFM)
171.1 < 3*0 F>
**»»* (* FT)
******* (*** FT)
COAL
SUBBITUMINOUS
20469.
9.00
*»*
26.70
******
1.37
******
********
0.01-0.07
*******
* **
( 8600 BTU/LB)
******
C««* TPH>
ELBAIR SPRAY-IMPINGEMENT
KREBS ENGINEERING
316 ELC STAINLESS STEEL
FLAKE-POLYESTER
100.0
137.4
171.1
1.1
.7
2.1
4.7
.1
800.000
500.000
37.0
( 29t160 ACFM)
< 340 F)
C 8.3 6AL/1000ACF)
3 IN-H20)
7.0 FT/S)
2.06 6R/SCF)
.040 6R/SCF)
-------
EPA UTILITY F6D SURVEY: SECOND QUARTEP 1979
SECTION 1t
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLAHT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NE/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MU
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/FGD - Mb
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER B
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT KJ/KG
RAN5E HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - I
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
RANSE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
RANSE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - I
RANSE CHLORIDE CONTENT - Z
FUEL FIRING RATE - M T /H
FUEL FIRING RATE - MW
MINNESOTA POWER ( LIGHT
CLAY BOSUELL
3
COHASSET
MINNESOTA
******
0. ( .000 LB/MMBTU)
** <« L9/MMBTU)
******
350.0
*******
.0
.0
COMBUSTION ENGINEERING
PULVERIZED COAL, TANGENT. FIRED, DRY BOTTOM
BASE
0/73
613.*7 (1300000 »CFM)
1Z7.3 ( 25* F)
****** (* FT)
»»«**» (*** FT)
COAL
SUBBITUMINOUS
19538.
9.00
******
26.00
******
.«»2
***
.01
***
****
*****
( 8400 BTU/LB)
****»
<* TPH)
* PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
INTERNAL MATERIAL
BOILER LOAD/SCRUBBER - Z
FLUE GAS TEMPERATURE - C
LIQUID REC1RCULATION RATE - LITER/S
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
1
SPRAY IMPINGEMENT
KREBS ENGINEERS
2
316L S.S.
316L S.S.
110.0
123.3
'14.*
1.1
.7
2.4
I 25* F)
(11340 GP")
( 8.3 6AL/1000ACF>
( 3 IN-H20)
( 8.0 FT/S)
153
-------
;P« JTILITT FGD SURVEY: SECOND BUARUR 1979
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAME
PL All T NAME
UNIT NUMBER
CITY
STATE
RE6JLAT3RV CLASSIFICATION
PART1CULATE EMISSION LIMITATION - ME/J
S02 EMISSION LIMITATION - NG/J
NET PLAUT GENERATING CAPACITY - MU
GROSS UYIT GENERATING CAPACITY - fc
NET UNIT GENERATING CAPACITY U/FGD - »b
NET UNIT GENERATING CAPACITY WO/F6D - NW
EQUIVALENT SCRUBBED CAPACITY - RU
* BOILER DATA
SUP»LIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.P/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANEE HEAT CONTENT - 9TU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CDNTENT - X
AVERAGE MOISTURE CONTENT - X
RANSE M01STJRE CONTENT - Z
AVERAGE SULFUR CONTENT - X
RAN5E SULFUR CONTENT - X
AVERAGE CHL3RIDE CONTENT - X
RANSE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MU
MECHANICAL COLLECTOR
NUM9ER
PARTICULATE SCRUBBER
TYPE
SUPPLIER
L/C RATIO LITER/CU.M
PRESSURE DROP - KPA
MONTANA-DAKOTA UTILITIES CO.
LEWIS S CLARK
*****
*****
**
0.
* **
*******
***
.0
.0
< .000 LB/MMPTU)
(**** L°/MMBTU)
***** *
* ***
***** *
* * /**
***
*******
**
COAL
LIGNITE
****
9.00
**
* «*»«**
**
.45
******
**
*****
*
*****
** ACFM)
( n
(«** FT)
(** FT)
(**«* BTU/LB)
******
(** TPH)
VENTURI-FLOODED DISC
RESEARCH COTTERELL
1.7 (13.0 6AL/1000ACF)
7.2 ( 1? IN-H20)
154
-------
EPA UTILITY FCD SURVEY: SECOND QUARTER 1979
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PART1CULATE SCRUPBERS
COMPANY NAME
PLAIT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - hG/J
NET PLAUT GENERATING CAPACITY - MW
CROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/FGD - »k
NET UNIT GENERATING CAPACITY UO/F6D - MW
EQUIVALENT SCRUBBED CAPACITY "W
* 30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOU > CU.P/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAWETER - M
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT KJ/KG
RANSE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANEE M01STJRE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFU1 CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANSE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MM
'ARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
SHELL MATERIAL
LINING MATERIAL
fLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LlftUID RECItCULATION RATE - LITER/S
L/G RATIO - LITER/CU."
PRESSURE DROP - KPA
PARTICULATE INLET LOAD - 6/CU.M
PART1CULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - t
PACIFIC POWER t LIGHT
DAVE JOHNSTON
(.
GLFNROCK
MVOMINC
.000 L?/*"?TU>
.500 L9/*MBTU)
0. <
215. <
^30.0
.0
,r
COMBUSTION ENGINEERING
PULVERIZED COAL .BALANCED DPAFT, TANG. FIRED
/*
707.P5
132.2
76.
COAL
SUBBITUMINOUS
172?2.
12.00
11500000 ACFPO
( 270 F)
( 250 FT)
(*«... FT)
( 7A30 BTU/LB)
26.00
***** *
.50
.C*
***** **
*****
(*** TPH)
VENTURI
CHEHICO
STEEL
POLYESTER-LINED STEEL
327.5
135.0
- X
1.3
2.5
9.2
99.7
459.000
40.0
694000 »CFM)
275 F)
6500 6PM)
9.4 GAL/1000ACF)
10 IN-H20)
4.00 6P/SCF)
155
-------
EPA JTILITT F6D SURWETi SECOND QUARTER 1«79
SECTION 1*
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITT
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLAIT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY W/F6D - MM
NET UNIT GENERATING CAPACITY VO/FGD - MU
EQUIVALENT SCRU9BE6 CAPACITY - MW
* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANEE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - Z
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - »U
POTOMAC ELECTRIC POWER
CHALK POINT
4
******
MARYLAND
***
0.
***»«
1892.0
630.0
630.0
.0
.0
******
******
9ASE
*/**
***
*******
******
***
OIL
***
*******
******
******
********
**»*
*»**
*****
*****
******
*****
*«*»
( .000 L9/MMBTU)
(««* L9/MMBTU)
(**« ACFM)
(**** F)
(***. FT)
(**** FT)
(***** BTU/LB)
**
(*** TPH)
156
-------
EPA UTILITY FGD SURVEY: SECOND QUARTER 1979
SECTION u
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PL AST NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
SO? EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MU
GROSS UMIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/FGD - Mu
NET UNIT GENERATING CAPACITY WO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MW
30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOU CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - *
STACK TOP DIAMETER - M
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANSE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - Z
RANGE ASH C3NTENT - Z
AVERAGE MOISTURE CONTENT - I
RANGE MOISTJRE CONTENT - X
AVERAGE SULFUR CONTENT - J
RANGE SULFUR CONTENT - X
AVERAGE CHLDRIDE CONTENT - X
RANSE CHLORIDE CONTENT - X
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MW
POTO'AC ELECTRIC POWER
DICKERSON
3
DICKERSON
MARYLAND
.000 LB/MMBTU)
1.600 LB/MMBTU)
0.
688.
548.0
190.0
181.0
.C
.0
COMBUSTION ENGINEERING
PULVERIZED COAL, DRY BOTTOM
9ASE
0/62
( 590000 ACFM)
( 259 F)
( 400 FT)
(«* FT)
278.42
126.1
122.
*******
COAL
*****
2721*.
14.00
******
********
*
2.00
******
*
*
67.1
*****
C 11700 BTU/LB)
******
< 74 TPH)
ESP
NUMBER
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
** PARTICULATE SCRUBBER
NUN3ER
TYPE
SUPPLIER
BOILER LOAD/SCRUBBER - Z
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - c
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
RESEARCH-COTTRELL
- X 94.0
1
ADJUSTABLE VENTURI
CHEMICO
50.0
139.2 < 295000 ACFM)
126.1 < 259 F)
2.7 (20.0 6AL/1000ACF)
?.7 < 11 IN-H20)
157
-------
= PA JTILITT FGO SURVEY: SECOND QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRU9BERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULAT9RY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - K6/J
SOi EMISSION LIMITATION - fiG/J
NET PLAIT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGD - MU
EQUIVALENT SCRU3BED CAPACITY - MU
30ILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW CU.W/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - «
STACK TOP DIA"ETER - M
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANiE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - Z
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
RANEE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
RANBE SULFU9 CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANEE CHLORIDE CONTENT - Z
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MM
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RANEE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - Z
RANEE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
RANEE HOISTJRE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
RANEE SULFU4 CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANEE CHLORIDE CONTENT - Z
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - MW
* ESP
NUM3ER
MECHANICAL COLLECTOR
NUM9ER
* PARTICULATE SCRUBBER
NUM3ER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
L/C RATIO - LITER/CU.M
PRESSURE DROP - KPA
PUBLIC SERVICE OF COLORADO
ARAPAHOE
4
DENVER
COLORADO
******
0.
******
****
****
112.0
.0
( .000 LB/MBBTU)
(***«* L9/MMBTU)
PULV. COAL. TOP FIRED
»*
0/55
245.39
148.9
******
*****
( 520000 ACFM)
( 300 F>
(*** FT)
(***** FT)
COAL
SUBBITUMINOUS
23725.
9.30
*«*
13.70
*****
.95
**
.01
*«
***
*****
COAL
***
23493.
12.50
»***
11.20
C 10200 BTU/LB)
»*»***
(** TPH)
( 10100 BTU/LB)
*
.65
*****
.01
**
*
*****
(*«* TPH>
2
TCA
UOP
3
CARBON STEEL
RUBBER
STAINLESS STEEL* PLASTIC SPHERES
7.5 (56.0 6AL/1000ACF)
3.0 < >? IN-H20)
15B
-------
EPA UTILITY FED SURVEY: SECOND QUARTER 1979
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
SUPERFICIAL GAS VELOCITY - M/S 7.4 ( 11.0 FT/S>
PARTICULATE INLET LOAD - 6/CU.f 1.8 ( .80 6R/SCF)
PARTICIPATE OUTLET LOAD - 6/CU." .0 < .020 6R/SCM
PARHCULATE DESIGN REMOVAL EFFICIENCY - t 91.0
S02 INLET CONCENTRATION - PPM 500.000
S02 OUTLET CONCENTRATION - PPM 350.000
S02 DESIGN REMOVAL EFFICIENCY - I 30.0
159
-------
EPA UTILITY F6D SURVEYj SECOND 8UARTE* 1979
SECTION 14
DESIGN AID PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAPE
PL Ait T N«NE
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - K6/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UMIT GENERATING CAPACITY - Mfc
NET UNIT GENERATING CAPACITY H/FGD - *«
NET UNIT GENERATING CAPACITY WO/F6D - Hit
EQUIVALENT SCRUBBED CAPACITY - "W
BOILER 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 -
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANEE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - Z
RANGE ASN CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
RANGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVE4A6E CHL3RIDE CONTENT - Z
RANEE CHLORIDE CONTENT - Z
fUEL FIRING RATE M T/H
FUEL FIRING RATE - «W
ESP
NUMBER
MECHANICAL COLLECTOR
NUMBER
PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUM9ER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
BOILER LOAD/SCRUBBER - Z
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 - 6/CU.ft
PARTICULATE OUTLET LOAD - G/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
302 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - I
( .000 L9/MMBTU)
(**.** L3/MMBTU)
PUBLIC SERVICE OF COLORADO
CHEROKEE
1
DENVER
COLORADO
******
0.
******
710.0
115.0
100.0
.0
.0
9ABCOCK t WILCOX
PULV. COAL. KET BOTTOM* TOP FIRED
******
0/57
245.39 ( 520000 ACFM)
146.1 ( 295 F)
****** {*»** FT)
******* (**** FT)
COAL
BITUMINOUS
23493.
12.50
******
11.30
******
.65
***
.01
**
.*«**
*****
( 10100 BTU/LB)
******
<* TPH)
- Z
1
TCA
AIR CORRECTION DIVISION, UOP
3
CARBON STEEL
RUBBER
STAINLESS STEEL. PLASTIC SPHERES
67.0
164.4
146.1
7.5
3.2
3.4
1.8
.0
97.0
500.000
420.000
16.0
348400 ACFM)
295 F)
56.0 6AL/1000ACF)
13 iN-HZO)
11.0 FT/S)
.80 GR/SCF)
.020 GR/SCF)
160
-------
EPA UTILITY FED SURVEY: SECOND QUARTER 1979
SECTION U
DESIGN AND PERFORMANCE D*TA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLANT NME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - NU
GROSS UNIT GENERATING CAPACITY - Mb
NET UNIT GENERATING CAPACITY U/FGD - »h
NET UNIT GENERATING CAPACITY U0/F6t - MW
EQUIVALENT SCRUBBED CAPACITY - *U
PUBLIC SERVICE
CHEROKEE
5
DENVER
COLORADO
******
0.
******
710.0
170.0
150.0
.0
.0
OF COLORADO
< .000 LB/MMBTU)
(**** LB/MNBTU)
« BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW CU.f/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - K
STACK TOP DIAMETER - M
* FUEL DATA
FUEL TYPE COAL
FUEL GRADE 3ITUMINOUS
AVERAGE HEAT CONTENT - KJ/KG 23493.
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 2 12.50
RANGE ASH CONTENT - t ****
AVERAGE MOISTURE CONTENT - t 11.30
RANSE MOISTURE CONTENT - I ******
AVERAGE SULFUR CONTENT - X .65
RANSE SULFUR CONTENT - X ***
AVERAGE CHLORIDE CONTENT - I .01
RANSE CHLORIDE CONTENT - I »
FUEL FIRING RATE - M T/H *««
FUEL FIRING RATE - MU **
* ESP
NUMBER
MECHANICAL COLLECTOR
NUN3ER
PARTICULATE SCRUBBER
NUM3ER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
BOILER LOAD/SCRUBBER I
FLUE GAS CAPACITY - CU.M/S
FLUF GAS TEMPERATURE - C
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD 6/CU.M
PARTICULATC OUTLET LOAD - 6/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY - I
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - I
BABCOCK t MILCOX
PULV. COALf WET BOTTOM* TOP FIRED
******
0/62
287.86 ( 610000 ACFM)
137.8 ( 280 F)
*«* (** FT)
******* (** FT)
< 10100 BTU/LB)
*****
(* TPH)
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 (56.0 GAL/1000ACF)
3.2 < 13 1N-H20)
.9
.0
95.0
500.000
420.000
16.0
11.0 FT/S)
.40 6R/SCF)
.020 6R/SCF)
161
-------
EPA JTILITT F6D SURVEY: SECOND 6UARTER 1979
SECTION U
DESIEN AND PERFORMANCE DATA FOR OPERATIONAL PARTICIPATE SCRUBBERS
COMPANY NAPE
PLANT NAME
UNIT NUMBER
CITY
STATE
REG'JLATDRT CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - NC/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY Mh
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/F6C MU
EQUIVALENT SCRUBBED CAPACITY "W
** BOILER 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 M
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/K6
RANEE HEAT CONTENT BTU/LE
AVERAGE ASH CONTENT - Z
RANSE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - Z
RANSE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
RANSE SULFUR CONTENT - Z
AVERAGE CHL3RIDE CONTENT - Z
RANSE CHLORIDE CONTENT - Z
FUEL FIRING RATE - M T/H
FUEL FIRING RATE - NW
PUBLIC SERVICE OF COLORADO
CHEROKEE
DENVER
COLORADO
.***
0.
< .000 LB/HMBTU)
(** LP/MMPTU)
710.0
37c.O
?50.0
.0
.0
COMBUSTION ENGINEERING
PULV. COAL. WET BOTTOM. TANG.
******
0/68
717.29 M520000 ACFM)
135.0 ( 275 F>
** (*«** FT)
******* (***** FT)
FIRED
COAL
BITUMINOUS
23493.
12.50
* *****
11.30
< 10100 BTU/LB)
**
.65
*
.01
***
*******
*****
(**« TPH)
* ESP
NUMBER
* MECHANICAL C3LLECTOR
NUMBER
"ARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
INTERNAL MATERIAL
L/C RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
PARTICULATE INLET LOAD - 6/CU.K
PARTICULATE OUTLET LOAD - 6/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - I
- Z
TCA
AIR CORRECTION DIVISION* UOP
3
CARBON STEEL
RUBBER
STAINLESS STEEL, PLASTIC SPHERES
7.5 (56.0 6AL/1000ACF)
7.2 < 13 IN-H20)
3.* ( 11.0 FT/S)
1.6 ( .70 6R/SCF)
.0 < .020 6R/SCF)
97.0
500.000
420.003
16.0
162
-------
EPA UTILITY F60 SURVEY: SECOND QUARTER 1979
SECTION u
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICULATE SCRUBBERS
COMPANY NAME
PLAIT NAME
UNIT NUMBER
CUT
STATE
RE6ULAT3RV CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NE/J
S02 EMISSION LIMITATION - KG/J
NET PLAtT GENERATING CAPACITY - MU
GROSS UMIT GENERATING CAPACITY *b
NET UNIT GENERATING, CAPACITY V/FGD - »"h
NET UNIT GESERATIKG CAPACITY WO/FGt = l»w
EflUIVALENT SCRUBBED CAP«CITY - »V
30ILSR DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATt
MAXIMUM BOILER FLUE GAS FLOW - CU.P/S
FLUE 6AS TEMPERATURE - C
STACK HEIGHT - '
STACK TOP DIAMETER M
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - KJ/KG
RAN&E HEAT CONTENT - BTU/LE
AVERAGE ASH CONTENT S
RANSE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - I
RAN5E MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - :
RAN5E SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RAN5E CHLORIDE CONTENT - X
FUEL FIRING RATE = M T/H
FUEL FIRING RATE - «W
PUPLIC SERVICE OF COLORADO
VALNONT
5
VALMONT
COLORADO
( .000 L?/"W9TU)
(**
273.8
166.0
166.C
.0
.C
COMBUSTION ENGINEERING
PULV. COAL. WET BOTTOM, TANG. FIRED
9ASE
0/64
436.98 < 926000 ACFP)
126.7 ( 260 F)
****** (** fT)
*** (* FT)
COAL
SUPBITUHINOUS
25121.
t .00
5.4-7.0
I'.OO
12.7-18.?
.60
( 10EOO BTU/LB)
******
(*** TPH)
ESP
TVPE
* MECHANICAL COLLECTOR
* PARTICULATE SCRUBBER
NUMBER
TTPE
NUMBER OF STAGES
SHELL MATERIAL
LINING "ATERIAL
INTERNAL MATERIAL
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
COLD SIDE
2
TCA
T
CARBON STEEL
RUPBER
S.S.
7.8
3.7
3.4
(S8.3 6AL/1000ACF)
( 15 IN-H20)
( 11.0 FT/S)
163
-------
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 po£eth4:ial 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 expr^s^> a,ll 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^'fiVe"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.
0 Installation of equipment, including foundations; steel
work for support, buildings, piping and ducting for
effluents, slurries, sludge, and make-up water, control
panels, instrumentation, insulation of ducting, buildings,
piping, and other equipment, painting and piling.
o 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 system,
costs are prorated to the boiler and
system.
A-9
-------
Indirect capital costs include the following elements:
0 Interest accrued on borrowed capital during construction.
0 Contractor's fee and expenses, including costs for
field labor payroll; field office supervision; person-
nel; construction offices; temporary roadways; railroad
trackage; maintenance and welding shops; parking lot;
communications; temporary piping and electrical and
sanitary facilities; safety security (fire, material,
medical, etc.); construction tools and rental equip-
ment; unloading and storage of materials; travel ex-
penses; permits; licenses; taxes; insurance; overhead;
legal liabilities; field testing of equipment; start-
up; and labor relations.
0 Engineering costs, including administrative, process,
project, and general; design and related functions for
specifications; bid analysis; special studies; cost
analysis; accounting; reports; consultant fees; pur-
chasing; procurement; travel expenses; living expenses;
expediting; inspection; safety; communications; model-
ing; pilot plant studies (if required because of pro-
cess design or application novelty); royalty payments
during construction; training of plant personnel; field
engineering; safety engineering; and consultant ser-
vices .
0 Legal expenses, including those for securing permits,
rights-of-way, etc.
0 Taxes, including sales, and excise taxes.
0 Insurance covering liability for equipment in transit
and at site; fire, casualty, injury, and death; damage
to property; delay; and noncompliance.
0 Allowance for start-up and shakedown includes the cost
associated with system start-up.
0 Spare parts including pumps, valves, controls, special
piping and fittings, instruments, spray nozzles, and
similar items.
Other capital costs include the following elements:
0 Land required for the FGD process, waste disposal, re-
generation facility, and storage.
0 Working capital, including the total amount of money
invested in raw materials and supplies in stock,
finished products in stock, and unfinished products
A-10
-------
in the process of being manufactured; accounts re-
ceivable; cash kept on hand for payment of operating
expenses such as salaries, wages, and raw materials
purchases; accounts payable; and taxes payable.
Annual cost of an FGD system includes the following direct,
fixed and overhead charges:
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.
° 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.
0 Overhead
Plant and administrative overhead is a business expense
that is not charged directly to a particular part of a
project, but is allocated to it. Overhead costs in-
clude administrative, safety, engineering, legal and
medical services; payroll; employee benefits; recrea-
tion; and public relations.
Table A-2 provides a summary of the means used to determine
the missing cost elements if the costs were not reported or
insufficient information prevented their actual determination.
The assumptions and cost bases for determining the capital and
annual costs of FGD systems were developed by the PEDCo staff
based upon previous economic studies conducted for the U.S. EPA
(Flue Gas Desulfurization Process Cost Assessment, May 1975;
Simplified Procedures for Estimating Flue Gas Desulfurization
System Costs, June 1976, EPA-600/2-76-150; Particulate and Sulfur
Dioxide Emission Control Costs for Large Coal-Fired Boilers,
March 1978, EPA-600/7-78-032).
A-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:
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
L0% 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
cSn?ingency 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
O
Partial indirect costs included.
Chemical fixation of sludge included in
capital cost.
Dry sludge disposal included in capital
cost.
Off-site landfill area included in
capital cost.
Sludge pond included in capital cost.
Additional sludge disposal capacity
added for life of system.
Stack included in capital cost.
Modifications to stack, ducts, and/or
fans included in capital cost.
Total regeneration facility cost included
in capital cost.
Partial regeneration facility cost in-
cluded in capital cost.
R & D costs included in capital cost.
Particulate precollection device (ESP,
fabric filter, venturi) prior to FGD
system required for proper operation of
SO. control system.
Particulate collection equipment (venturi
scrubber) is included in the FGD system.
Complete cost of all FGD equipment, the
labor and materials required for equip-
ment installation, and interconnecting
the system is included in the total
capital cost.
One or a number of direct cost items, or
the cost associated with one or a number
of direct cost items, are excluded from
the total capital cost.
Complete cost of all the indirect cost
elements, including interest during con-
struction, contractor's fees, engineer-
ing, legal expenses, taxes, insurance,
allowance for start-up, and spares, is
included in total capital cost.
One or a number of indirect cost items,
or the cost associated with one or a
number of indirect cost items, are ex-
cluded from the total capital cost.
The cost of a chemical fixation process
which stabilizes the flue gas cleaning
wastes prior to disposal is included in
the total capital cost.
The cost of a secondary dewatering or
treatment method, such as filtration, cen-
trifugation, or forced oxidation, which
ultimately produces a dry sludge cake
for final disposal, is included in the
total capital cost.
The cost of an off-site area used as a
landfill for flue gas cleaning wastes is
included in the total capital cost.
The cost of an on-site disposal area for
ponding of treated or untreated flue gas
cleaning wastes is included in the total
capital cost.
The cost of additional SO. waste disposal
capacity required for 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
N
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 ths 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 flu* gas
cleaning wastes that are handled by an
outside firm.
The cost of additional power-generating
capacity required to compensate for power
used by the PGD system.
A-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
ALL
NEU
RETROFIT
THROUAUAY PRODUCT
SALEAILE PRODUCT
LIMESTONE
LINE
LINE/ALKALINE FLYASH
SOIIUN CARBONATE
VELLNAN LORD
LIMESTONE/ALKALINE FLYASH
NAINESIUN OXIDE
RANGE
5.3-156.9
5.3-120.6
29.2-156.9
5.3-120.6
93.3-156.9
5.3- 99.5
29.2-120.6
85.9- OS. 9
42.9-113.6
127.9-156.9
47.9- 47.9
196.7-156.7
, I/KM-
AV6
77.0
71.4
B3.7
67.1
132.5
61.4
74.1
05.9
66.5
137.6
47.9
156.7
/
-REPO
DEV
36.9
30.0
42.7
29.2
23.5
27.6
29.7
.0
33.3
13.7
.0
.0
. .AMMIIAI
RANGE
.3- 14.9
.3- 14.3
2.1- 14.9
.3- 14.3
3.3- 14.9
1.6- 3.3
.3- 14.3
*«»«- .0
2.1- 2.1
14.9- 14.9
2.0- 2.0
MM- .0
NILLS/KUH
AV6 DEV
6.3
4.6
8.3
5.9
9.1
2.2
9.0
.0
2.1
14.9
2.0
.0
5.1
5.0
4.4
4.9
5.8
.8
4.S
.0
.0
.0
.0
.0
CAPITAL, $/KU
RANGE AV6
60.9-233.2 94.2
66.4-117.6 85.5
60.9-233.2 103.6
60.9-140.6 87.0
134.8-233.2 184.0
66.4-117.6 93.1
67.5-140.6 88.9
93.0- 93.0 93.0
60.9-107.9 76.6
134.8-134.8 134.8
71.5- 71.5 71.5
233.2-233.2 233.2
DEV
35.2
16.9
45.8
21.2
49.2
21.9
21.1
.0
22.2
.0
.0
.0
RANGE
2.7- 12.4
2.8- 8.7
2.7- 12.4
2.7- B.7
12.4- 12.4
2.9- 6.6
2.7- 8.7
5.2- 5.2
3.2- 4.4
12.4- 12.4
2.8- 2.8
- .0
HILLS/KUH
AVG DEV
5.5
5.2
5.8
5.2
12.4
5.0
6.0
5.2
3.6
12.4
2.8
.0
2.4
2.0
2.6
1.9
.0
1.4
2.0
.0
.6
.0
.0
.0
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION A-I
COSTS FOR OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
REPORTED
COST
ADJUSTED
STANDARDIZED
ADJUSTED
ALABAMA ELECTRIC COOP
TOHBICBEE
>
179.0 Nri CNET)
CAPACITY FACTOR, S
TOTAL CAPITAL. S/KWCVEAR)
TOTAL ANNUAL* HILLS/KWHCTEAR)
COST ELEMENTS
* 65
172.5<1978) **<
( o) **(
A.D
0)
0)
65
«(
0)
ALABAMA ELECTRIC COOP
T04BI6BEE
5
179.0 N* CNET)
CAPACITY FACTOR, S
TOTAL CAPITAL. S/KWCVEAR)
TOTAL ANNUAL. HILLS/KWHCVEAR)
COST ELEMENTS
65
69.5(1978) (
*( 0) *(
C.E.J
0)
0)
65
**(
*(
0)
0)
ARIZONA ELECTRIC POrfER COOP
APACHE
?
195.0 Ntf CNET)
CAPACITY FACTOR, t
TOTAL CAPITAL* S/KW(VEAR>
TOTAL ANNUAL. MILLS/KWHCVEAR)
COST ELEMENTS
44 65
35.9(1977) (
2.1(1978) *(
C.E.M.J.L.S,
U*W(V,Z
0)
0)
65
( Q)
*( 0)
ARIZONA ELECTRIC POWER COOP
tPACME
B
195.0 Ntf CNET)
CAPACITY FACTOR* t
TOTAL CAPITAL. S/KWCVEAR)
TOTAL ANNUAL* MILLS/KWHCTEAR)
COST ELEMENTS
44 65
31.8C7700) *(
2.1(1978) (
C*E.H.J,L,S,
U,H.Y,Z
65
0) C
0) *»(
0)
0)
CENTRAL ILLINOIS LI6HT
»UCK CREEK
1
416.0 Hrf CNET)
CAPACITY FACTOR, t
TOTAL CAPITAL. S/KWCVEAR)
TOTAL ANNUAL. HILLS/KUH(YEAR)
COST ELEMENTS
** 65
93.3(1978) **(
3.3(1976) *(
C.E,J,M
65
0) *«***«c 0)
0) *( 0)
COLUMBUS I SOUTHERN OHIO ELEC.
CONESVILLE
5
411.0 Ntf CNET)
CAPACITY FACTOR, S
TOTAL CAPITAL. S/KW(YEAR)
TOTAL ANNUAL. MILLS/KUH(VEAR)
COST ELEMENTS
48
55.5(1975)
5.8(1978)
65
70.7(1977)
7.4C1977)
65
70.7(1977)
7.4(1977)
B.C.J.M.S.U. C.E.J.M.S.U. C.E.J.PSS.U,
u.v
w.v
COLUMBUS t SOUTHERN OHIO ELEC.
CONESVILLE
&
411.0 Mtf (NET)
CAPACITY FACTOR* t
TOTAL CAPITAL. S/KWCYEAR)
TOTAL ANNUAL* NILLS/KWHCYEAR)
COST ELEMENTS
48 65 65
55.5(1978) 70.7(1977) C 0)
5.8(1978) ( 0) «**( 0)
B.C.J.M.S.U, C.E*J.M.S.U,
w.x.v w.v
UQUESNE LICHT
ELRA4A
1-4
510.0 Ntf (NET)
CAPACITY FACTOR* I
TOTAL CAPITAL. S/KU(YEAR>
TOTAL ANNUAL* MILLS/KWH(YEAR)
COST ELEMENTS
64 65 65
113.4(1976) 127.1(1977) 127.1(1977)
8.6(1977) 7.8(1977) 7.5(1977)
B*D,F,I*J*«( C.E.I.J.M.S, C.E.I.J,M.S.
T.V.X.Y U.V U.V
»il«UESNE LIGHT
HILL1PS
1-6
410.0 M» (NET)
CAPACITY FACTOR. S
TOTAL CAPITAL* S/KUCVEAR)
TOTAL ANNUAL. MILLS/KWH(TEAR)
COST ELEMENTS
70 65 65
106.9(1972) 140.6(1977) 140.6(1977)
7.8(1977) 8.6C1977) 8.2(1977)
B*D*F*I*J,«, C.E,I»J.M,S» C.E.I.J.M.S.
T,V,K*Y U.V U.V
INDIANAP3LIS POWER fLItHT
ETEISBUR6
5
532.0 MM (NET)
CAPACITY FACTOR* S
TOTAL CAPITAL, S/KWCYEAR) 99.5(1976)
TOTAL ANNUAL, MILLS/KWH(YEAR) ( 0)
COST ELEMENTS C,F,C*J*M
65
100.6(1977)
6.6(1977)
C.E.6.J.H.S,
U.W,Y
65
100.6(1977)
7.4C1977)
C.E.6.J.M.S.
u»w*v
INDICATES COST FI6URES NOT VET AVAILABLE
A- 20
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
UNIT DESCRIPTION
SECTION «-t
COSTS FOR OPERATIONAL F6D SYSTEMS
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
(ANSIS CITY POWER I LIGHT
HAWTHORN
5
90.0 Mrf (NET)
CAPACITY FACTOR, S 14 65 65
TOTAL CAPITAL, S/KW(VEAR) 29.2(1972) 87.2(1977) 87.2(1977)
TOTAL ANNUAL, NILLS/KWH(YEAR) 8.4(1977) 4.3(1977) 4.4(1977)
COST ELEMENTS B.»,F,T,X B.C,E,J,K,S, B,C.E,J,K,S,
U.U.X U,U,X
(ANSIS CITY POWER K LIGHT
1AWTHORN
I
90.0 Hri (NET)
CAPACITY FACTOR, S **
TOTAL CAPITAL, S/(U(YEAR) 29.2(1972)
TOTAL ANNUAL, N1LLS/KWH(VEAR) 8.4(1977)
COST ELEMENTS B,D,f,T,X
65
87.2(1977)
4.3(1977)
B.C,E,J,K.S,
U,M,X
65
87.2(1977)
4.4(1977)
B.C.E,J,K,S,
u,u,x
(ANSIS CITY POWER t LIGHT
LA CYGNE
i
874.0 Mrf (NET)
CAPACITY FACTOR, X 42 65 65
TOTAL CAPITAL. S/KW(VEAR) 53.6(1972) 68.0(1977) 68.0(1977)
TOTAL ANNUAL, «ILLS/KWH(YEAR) 1.3(1978) 3.8(1977) 3.9(1977)
COST ELEMENTS T C,E,J,K,S,U C,E.J,K,S,U
(ENTUCKY UTILITIES
5REEN RIVER
1-3
64.0 Nri (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(VEAR)
TOTAL ANNUAL, HILLS/KWH(YEAR)
COST ELEMENTS
16 65 65
70.3(1975) 77.5(1977) 77.5(1977)
14.3(1977) 2.7(1977) 5.2(1977)
B,C,E,J,S,U, C.E.J.S.U.W C,E,J,S,U,U
w
LOUISVILLE GAS I ELECTRIC
CANE RUN
t
188.0 MM (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, NILLS/KWM YE AR)
COST ELEMENTS
55 65 65
66.5(1975) 80.6(1977) 80.6(1977)
(1977) 5.8(1977) 6.2(1977)
C.E.H.J.O.T C.E.H.J.K.Q. C,E.H,J,K.Q,
S.U.W S.U.W
LOUISVILLE GAS K ELECTRIC
CANE RUN
5
190.0 Mri (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
* 65 65
62.4(1977) 67.5(1977) 67.5(1977)
*.****( 0) 5.6(1977) 5.6(1977)
C,E,H,J C.E.H,J,R,S. C,E,H,J,K,S,
u,w u.w
LOUISVILLE GAS I ELECTRIC
CANE RUN
*,
288.0 Mil (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(TEAR)
TOTAL ANNUAL, MILLS/KWH( YE AR)
COST ELEMENTS
...
57.9(1977)
3.2(1979)
C,E,H,N,S,V,
W
65
...... (
.... .. (
65
0) *.....( 0)
0) ««.«( 0)
LOUISVILLE GAS I ELECTRIC
ADOY'S RUN
S
72.0 Mrf (NET)
CAPACITY FACTOR* X
TOTAL CAPITAL, S/KW(VF.AR)
TOTAL ANNUAL, HILLS/KWH(YEAR)
COST ELEMENTS
... 65 65
52.8(1973) 76.4(1977) 76.4(1977)
......( 0) 6.5(1977) 6.4(1977)
C.E C.E.S.U.W C.E.S.U.W
INNCOTA POWER OOPERATIVE
'ILTON R. YOUNG
2
405.0 Mrt (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, »/CW(YEAR)
TOTAL ANNUAL, MILLS/KWH(VEAR)
COST ELEMENTS
... 65 65
85.9(1976) 93.0(1977) 93.0(1977)
*.«**( Q) 5.2(1977) 5.2(1977)
C.E.H.P C.E.H,N,P,S, C.E.H.M.P.S.
U.W U.W
MONTANA POWER
COLSTHIP
1
360.0 Mri (NET)
CAPACITY FACTOR, I
TOTAL CAPITAL, 8/KW(YEAR)
TOTAL ANNUAL, HILLS/KWH(YEAR)
COST ELEMENTS
76 65 65
77.1(1975) 77.2(1977) 77.2(1977)
.3C1977) 4.1(1977) 4.0(1977)
B,C,E,J,P,T C.E,J,K,P,S, C.E.J,K,P.S.
U.W U.W
INDICATES COST FIGURES NOT YET AVAILABLE
A- 21
-------
:PA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION A-1
COSTS FOR OPERATIONAL F6D SYSTEMS
BNIT DESCRIPTION
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
*ONT»NA POWER CAPACITY FACTOR* t 76 65
COLSTHIP TOTAL CAPITAL. S/KW(VEAR) 77.1(19751 77.3*1977)
? TOTAL ANNUAL. MILLS/KWH(VE AR) .3(1977) 4.1(1977)
360.0 Htf (NET) COST ELEMENTS
u.u
65
77.3(1977)
4.1(1977)
C t E *J .K.P.S.
u,w
VEVABA P9WER
(EID 6AR»NER
1
125.0 Nri (NET)
CAPACITY FACTOR. X
TOTAL CAPITAL, S/KW(VEAR)
TOTAL ANNUAL, MILLS/KWH(YEAP)
COST ELEMENTS
67 65 65
42.9(1973) 60.9(1977) 60.9(1977)
2.1(1977) 3.2(1977) 3.4(1977)
B,D.E,P,S,U, B.O.E.P.S.U, B,D,E,P,S.U,
U,X U,X U.X
NEVADA P3WER
»EID tARBNER
2
125.0 Ntf (NET)
CAPACITY FACTOR, t
TOTAL CAPITAL, S/KW(VEAR)
TOTAL ANNUAL, MILLS/KWH(VEAR)
COST ELEMENTS
67 65 65
42.9(1973) 60.9(1977) 60.9(1977)
2.1(1977) 3.2(1977) 3.4(1977)
B.D,E,P,S,U, B.D.E.P.S.U. B,D,E.P,S*U,
u,x u.x u.x
1EVADA P9WER
*EID GARBNER
J
125.0 MM (NET)
CAPACITY FACTOR, z
TOTAL CAPITAL, SSKW(VEAR)
TOTAL ANNUAL, NILLS/KWH(VEAR>
COST ELEMENTS
67 65 65
113.6(1975) 107.9(1977> 107.9(1977)
2.1(1977) 4.4(1977) 5.0(1977)
B.C.E.L.S.U, B.C,E,L,S,U, B,C,E.L.S.U,
U.X U.X U,X
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
115.0 Mtf (NET)
CAPACITY FACTOR, t
TOTAL CAPITAL, S/KW(VEAR>
TOTAL ANNUAL, MILLS/KUH(VEAR>
COST ELEMENTS
77 65 65
156.9(1976) 134.8(1977) 134.8(1977)
14.9(1976) 12.4(1977) 11.0(1977)
B,C,E,L,N,S, C,E.L,N,S,U, C,E,L,N,S,U,
u,w,x,z u.z w,z
NORTHERN STATES »OWER
SHER3URNE
1
740.0 M* (NET)
CAPACITY FACTOR, i
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, MILLS/KWH(VEAR)
COST ELEMENTS
73 65 65
47.9(1972) 71.5(1977) 71.5(1977)
2.0(1977) 2.8(1977) 3.3(1977)
B,C.J,S,U,X, C,E,J,K,S.U, C,E.J.K,S,U.
Z H M
NORTHERN STATES POWER
SHER3URNE
2
740.0 Mtf (NET)
CAPACITY FACTOR, I
TOTAL CAPITAL, S/KH(VEAfl>
TOTAL ANNUAL, NILLS/KWH(VEAR>
COST ELEMENTS
73 65 65
47.9(1972) 71.5(1977) 71.5(1977)
2.0(1977) 2.8(1977) 3.3(1977)
B,C,J,S,U,K, C.E.J.K.S.U, C,E,J.r,S*U,
Z W W
OENNSVLVtNIA POWER
BRUCE MAKSFIELD
1
917.0 Mtf (NET)
CAPACITY FACTOR, Z
TOTAL CAPITAL, S/KW(VEAR>
TOTAL ANNUAL, HILLS/KUH(VEAR)
COST ELEMENTS
40 65 65
120.6(1975) 102.1(1977) 102.1(1977)
14.3(1977) 8.7(1977) 10.8(1977)
B,C,E,«,I,L, C,E.C.I.M.S. C,E,G,I,M,S,
S,U,W,I U.W U,W
PENNSYLVANIA POWER
BtUCE NA«SFIELD
>
917.0 Mtf (NET)
CAPACITY FACTOR, Z
TOTAL CAPITAL, S/KW(VEAR)
TOTAL ANNUAL, MILLS/KWH(VEAR)
COST ELEMENTS
40 65 65
120.6(1975) 102.1(1977) 102.1(1977)
14.3(1977) 8.7(1977) 10.8(1977)
B,C,E,C,I,L, C,E,6,I.N,S. C,E,6,I,M,S*
S.U.W.X U.W U.W
PHILADELPHIA ELECTRIC
EDDVSTONE
1*
120.0 NH (NET)
CAPACITY FACTOR* Z
TOTAL CAPITAL, S/KW(VEAR>
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
65 65
156.7(1972) 233.2(1977) 233.2(1977)
***»»C1972) «****(1977) (1977)
D,F,N,P C.E.N.P C,E,N.P
INDICATES COST FI6URES NOT YET AVAILABLE
A- 22
-------
EPA UTILITY F6D SURVEY: SECOND QUARTER 1979
SECTION A-1
COSTS FOR OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
»UBLIC SERVICE OF NEW MEXICO
SAN JUAN
1
361.0 Mrf CNET)
COST DESCRIPTION
CAPACITY FACTOR. X
COST ELEMENTS
REPOPTED
***
A.C.E.N
ADJUSTED STANDARDIZED
ADJUSTED
65 65
UBLIC SERVICE OF NEW NfcllCO
SAN JUAN
>
350.0 flri (NET)
CAPACITY FACTOR, S
TOTAL CAPITAL. S/KW(VEAR>
TOTAL ANNUAL, KILLS/K«H
COST ELEMENTS
* 65
127.9(1977) ......<
*( g) ***.(
A.C.E.N
65
0) *( 0)
0) ( 0)
SOUTH CAROLINA PUBLIC SERVICE CAPACITY FACTOR, X
TOTAL CAPITAL. »/KW(YEAR)
TOTAL ANNUAL. MILLS/KUH(VEAR)
140.0 MM (NET)
COST ELEMENTS
80 65 65
47.4(1976) 66.4(1977) 6.4(19?7>
1.61 0) 2.9(1977) 3.2(1977)
C.F,J,B,S,V C.E.J.K.M.S, C,E,J,K.H,S,
u.w u.y
SOUTHERN INDIANA 6AS ( ELEC
«.B. BROtfN
1
265.0 Htf (NET)
CAPACITY FACTOR, X 65
TOTAL CAPITAL, S/KW(YEAR) 43.8(1979) *(
TOTAL ANNUAL, MILLS/KWH(YEAR) «»( 0) ****..(
COST ELEMENTS C.E.6
65
0) *( 0)
0) ( 0)
SOUTHERN MISSISSIPPI ELECTRIC
».D. HORROU
1
124.0 m (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KV(VEAR)
TOTAL ANNUAL, MILLS/K«H(YEAR)
COST ELEMENTS
65
232.5(1978) .....«(
I (j) **»(
65
0) »**( 0)
0) *< 0)
SOUTHERN MISSISSIPPI ELECTRIC
t.D. MOR90W
>
124.0 N« (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(VEAR>
TOTAL ANNUAL, MILLS/KWH(VEAR>
COST ELEMENTS
... 65
232.5(1978) (
65
0) ...»*.(
0) *(
0)
0)
SPRIH6FIELD CITY UTILITIES
SOUTHWEST
1
194.0 Mtf (NET)
CAPACITY FACTOR. X 65 65
TOTAL CAPITAL, $/*y(YEAR) 77.3(197*) 117.6(1977) 117.6(1977)
TOTAL ANNUAL, MILLS^KMH(YEAR) *( 0> 6.2(1977) 6.9(1977)
COST ELEMENTS C.F.H.J.P C.E.H.J.K.P. C.E.H.J.K.P,
S.U.W S,U,H
TENNESSEE VALLEY AUTHORITY
tflDOtfS CVEEK
9
550.0 Nrf (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KV(VEAR)
TOTAL ANNUAL, MILLS/KHH(YEAR)
COST ELEMENTS
60 65
98.1(1976) 113.1(1977)
3.0(1977) 5.3(1977)
B.C.E.P.R.T, C.E.J.S.U.W
U
65
113.1(1977)
5.1(1977)
C.E.J,S.U.W
INDICATES COST FIGURES WOT TET AVAILABLE
A- 23
-------
EP* UTILITY fGD SURVEY: SECOND QUARTER 1979
SECTION A-2
COSTS rOR NON-OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
MSI* ELECTRIC P3MER COOP
LARA4IE RIVER
t
630.0 Nrf (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL. S/KUrVEAR>
TOTAL ANNUAL, NILLS/KWHCTEAR)
COST ELEMENTS
65
68.2*1980) (
«*»( 0) <
C.E
0)
0)
65
*(
*C
0)
0)
JASIH ELECTRIC PDrfER COOP CAPACITY FACTOR, X
LARAME RIVER
?
600.0 N4 (NET>
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, MILLS/KWH( YE AR )
COST ELEMENTS
* 65
68.2(1980) (
*****( o) *(
C.E
65
0) **(
0) ***(
0)
0)
316 RIVERS ELECTRIC
SREEH
1
2(2.0 Nri (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KUCVEAR)
TOTAL ANNUAL, N1LLSSKHH(YEAR)
COST ELEMENTS
65
43.2(1976) **( 0)
****( 0) *( 0)
B,C
65
**( 0)
( 0)
30ST9N E»ISON
4VSTIC
i
.0 Mtf (NET)
CAPACITY FACTOR, I
TOTAL CAPITAL, S/KWCYEAR)
TOTAL ANNUAL, NXLLS/KVH(VEAR)
COST ELEMENTS
65
63.4(1972) (
3.0(1974) (
B,C,E,N,0
65
0) **(
0) *(
0)
0)
CENTRAL ILLINOIS PUBLIC SERV
«£UT3N
1
617.0 Mri (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, NILLS/KUH(YEAR)
COST ELEMENTS
* 65
189.0(1979) (
**( Q) *****»<
C.E,6
65
0) **(
0) **(
0)
0)
COLORADO UTE ELECTRIC ASSN.
CRAIB
1
447.0 Mtf (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
* 65
117.0(1979) *(
**»( 0) *(
B.D.E
65
0) »*(
0) ***(
0)
0)
COLORADO UTE ELECTRIC ASSN.
CRAIK
447.0 Htf (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(VEAR>
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
65
117.0(1979) (
***»*( o) **(
A,C
65
0) **«(
0) ***(
0)
0)
COMIONUEALTH EDISON
OHERTON
51
450.0 m (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS/KVH(YEAR>
COST ELEMENTS
117.7(1979) *..(
****( o) ****(
C,E.H,J
65
0) *(
0) ****(
0)
0)
COMMONWEALTH EDISON
tfILL COUHTY
1
.0 Hri (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(VEAR>
TOTAL ANNUAL, MILLS/KHH(VEAR)
COST ELEMENTS
49 65
113.0(197?) **(
13.1(1975) **(
B.C.E.G.J.X
65
0) «(
0) «(
0)
0)
DETROIT EDISON
ST. CLAIR
&
.0 Nri (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL. */KU(VEAR)
TOTAL ANNUAL, MILLS/KHH(YEAR>
COST ELEMENTS
65
80.3(1976) *(
9.6(1976) (
8,C,E,J.ft,X
65
0) »(
0) (
0)
0)
* INDICATES COST FIGURES NOT VET AVAILABLE
A- 24
-------
EPA UTILITV F6D SURVEY: SECOND QUARTER 1979
SECTION A-2
COSTS FOR NON-OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
(LL1WOIS POKER C9MPANY
HOOD RIVER
I
.0 MM CNET)
CAPACITY FACTOR, X
TOTAL CAPITAL, »/KM(YEAR)
TOTAL ANNUAL, "ILLS/KUHCYEAR)
COST ELEMENTS
65 65
82.5(1972) *..*< o>
......( 0) *( 0)
A,C,E,K,N.1
** *#»c
0)
0)
ACIFIC POWER t LIGHT
II« 3RIDGER
t
550.0 MM CNET)
CAPACITY FACTOR, X
TOTAL CAPITAL. S/KUCYEAR)
TOTAL ANNUAL, HlLLS/KUHC YE AR)
COST ELEMENTS
*
120
C,E,
.0<1979) -
J
65 65
OTOMC ELECTRIC POKER
MCKERS01
S
.0 MM (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, SAW(VEAR)
TOTAL ANNUAL, MILLS/KUHCYEAR)
COST ELEMENTS
65
68.0(1978) (
( Q) **(
»,C,E,M
65
0) *( 0)
0) ***( 0)
UBLIC SERVICE OF COLORADO
VALMONT
5
.0 MM (NET)
CAPACITY FACTOR* t
TOTAL CAPITAL, S/KU(VEAR)
TOTAL ANNUAL, »ILLS/KHH(YEAP)
COST ELEMENTS
65
87.0(197*) ( 0)
»*( 0) ( 0)
B.C.E.J
65
0)
0)
SALT RIVER PROJECT
COROHADO
t
280.0 MM (NET)
CAPACITY FACTOR, (
TOTAL CAPITAL, S/KU(YEAR>
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
65
98.0(1978) «< 0)
**«( 0) ( 0)
C.E
65
0>
0)
SALT RIVER PROJECT
COROHADO
2
290.0 MM (NET)
CAPACITY FACTOR, t
TOTAL CAPITAL, SSKU(VEAR)
TOTAL ANNUAL, NILLS/KUH(YEAR>
COST ELEMENTS
65 65
98.0(1978) *«( 0) <
****»( o) ( 0) *«**(
C.E
0)
0)
...... INDICATES COST FIGURES NOT YET AVAILABLE
A- Z5
-------
APPENDIX B
FGD PROCESS FLOW DIAGRAMS
THIS APPENDIX COMPRISES OPERATING FGD SYSTEMS
ARRANGED ALPHABETICALLY ACCORDING TO UTILITY
B-l
-------
aw CM
HOT Mill*
(WIT II
STUCK
Mun »i*
NPOTII
co
I
ro
MIUI i.e..
mav mm
(WIT II
tut
(Wit 1)
1 ll
*/
1
:
fctafc^"1"" 1
nHHrr ClIMIMTO* f
--"--^I
5»Ui 10MI 1
USOMCI |
"\ TT3
uumr
ro WIT )
Alabama Electric,
Simplified Process Flow Diagram for Tomblgbee 3
-------
SCRUBBED
GAS
w
U)
MATER
ISLURRYI
STORAGE
TANK
CT
;£
VACUUH WATER
RECOVERY 2
'SOLIDS
Louisville Gas
Dual Alkali FGD System:
and Electric, Cane Run 6
Simplified Process Flow Diagram
-------
LIME SILO
w
FLUE GAS
BY-PASS
FLUE GAS FROM
ELECTROSTATIC-
PRECIPITATOR
A
CLEAN GAS
TO STACK
WATER
SOLID TO
ON-SITE
LANDFILL
Southern Indiana Gas and Electric, A.B. Brown 1:
Dual Alkali FGD System: Simplified Process Flow Diagram
-------
W
Oi
\7
MAKEUP HATER
LIMESTONE
FEED BIN
(ONE IN USE
FOR TWO
BOILERS)
HIST ELIMINATOR
I PUMP
(ONE IN USE
ONE SPARE)
I MIST
ELIMINATOR!
(TANK (ONE I
LIN USE)^
WEIGH FEEDER
(ONE IN USE)
HUE
(ONE IN USE)
VENTURI SORBER
SCRUBBERTN
(ONE IN USE)
WET BALL MILL ... ..
(ONE IN USE) I T I C
MILL SLURRY **
TANK
(ONE IN
_
SLURRY STORAGE
TANK
rutftV^MTM **'
IN USE
(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
!(ONE IN USE
ONE SPARE)
Southern Mississippi Electric, R.D. Morrow
Simplified Process Flow Diagram
2:
-------
FM OUTICT OWWU
TOOT IM.CT MWFR
II
w tone*
PHIMMTHS-
<
tfl
I
SEN. UMCR.
e*ti Mm COOIIIK
*M> HOS( STMIMK
MOW WTt* TO
UIKSTOK MO
ASH I
RTIUM MTt*
(ttCTClt MAHI)
Texas Utilities,
Simplified Process Flow Diagram for One of the Three Identical
Martin Lake FGD Systems
-------
APPENDIX C
DEFINITIONS
C-l
-------
DEFINITIONS
Boiler Capacity Factor:
Boiler Utilization Parameters
Byproduct
Disposal
Efficiency:
Particulate Matter
SO.
FGD Viability Indexes
(kwh generation in year)/maxi-
mum continuous generating
capacity in kW x 8760 hr/yr .
Hours boiler operated/hours in
period, expressed as a percen-
tage.
The nature (e.g. elemental
sulfur, sulfuric acid) and
disposition (e.g. stockpile on
site, marketed) of the end
product produced by systems
that generate a saleable
product.
Disposal method for throwaway
product systems producing
sludge including: stabilized
or unstabilized sludge, inter-
im and final disposal sites
and disposal type (minefill,
landfill, etc.) as well as
disposal location.
The actual percentage of
particulate matter removed by
the emission control system
(mechanical collectors, ESP,
or fabric filter and FGD) from
the untreated flue gas.
The actual percentage of S02
removed from the flue gas by
the FGD system. Design
removal efficiency values are
presented for nonoperational
systems for which actual
removal data are not avail-
able.
Several parameters have been
developed to quantify the
viability of FGD system tech-
nology. Various terms such as
"availability," "reliability."
"operability," and "utiliza-
tion" are used to accurately
C-2
-------
Availability Index
Reliability Index
represent the operation of any
FGD system during a given
period. The above-mentioned
parameters are defined below
and discussed briefly. The
objectives of this discussion
are to make the reader aware
that several different defini-
tions are being used and to
select appropriate parameters
that can be used for reporting
purposes so that reasonably
consistent comparisons can be
made.
Hours the FGD system is avail-
able for operation (whether
operated or not) divided by
hours in period, expressed as
a percentage. This parameter
tends to overestimate the
viability of the FGD system
because it does not penalize
for election not to operate
the system when it could have
been operated. Boiler down-
time may tend to increase the
magnitude of the parameter
because FGD failures generally
cannot occur during such
periods.
Hours the FGD system was
operated divided by the hours
the FGD system was called upon
to operate, expressed as a
percentage. This parameter
has been developed in order
not to penalize the FGD system
for elected outages, e.g.,
periods when the FGD system
could have been run but was
not run because of chemical
shortages, lack of manpower,
short duration boiler opera-
tions, etc. The main problem
in using this formula is the
concise determination whether
or not the system was "called
upon to operate" during a
given time period. In addi-
tion, an undefined value can
C-3
-------
FGD Operability Index
FGD Utilization Index
End Product
Saleable
result when the FGD system is
not called upon to operate for
a given period (e.g., turbine
or boiler outage when FGD
system is available).
Hours the FGD system was
operated divided by boiler
operating hours in period,
expressed as a percentage.
This parameter indicates the
degree to which the FGD system
is actually used, relative to
boiler operating time. The
parameter is penalized when
options are exercised not to
use the FGD system in periods
when the system is operable.
In addition, an undefined
value can result when the FGD
system is not called upon to
operate for a given period
(e.g., turbine or boiler
outage when FGD system is
available).
Hours that the FGD system
operated divided by total
hours in period. This para-
meter is a relative stress
factor 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., infrequent boiler
operation will lower the value
of the parameter although the
FGD system may be highly
dependable in its particular
application).
The SO- removed from the flue
gas is recovered in a usable
or marketable form (e.g.,
sulfur, sulfuric acid, gypsum,
ammonium sulfate, sodium
sulfate).
C-4
-------
Energy Consumption, %
Throwaway The go2 removed from the flue
gas is not recovered in a
usable or marketable form and
resulting sulfur-bearing waste
products must be disposed in
an environmentally acceptable
fashion.
The percentage of gross unit
electrical generating capacity
consumed by the FGD system, as
defined by the following
equation:
[Net MW w/o FGD - Net MW w/FGD]/
Gross unit rating]
Equivalent Scrubbed Capacity (ESC) The effective scrubbed flue
gas in equivalent MW based on
the percent of flue gas scrubbed
by the FGD system.
FGD Status:
Category 1
Category 2
Category 3
Category 4
Category 5
Category 6
Operational - FGD system is in
service removing S0_.
Under Construction - ground
has been broken for installation
of FGD system, but FGD system
has not become operational.
Planned, Contract Awarded -
contract has been signed for
purchase of FGD system but
ground has not been broken for
installation.
Planned, Letter of Intent
Signed - letter of intent has
been signed, but legal con-
tract for purchase has not
been awarded.
Planned, Requesting/Evaluating
Bids - bid requests have been
released but no letter of
intent or contract has been
issued.
Considering only FGD Systems -
an FGD system is proposed as a
means to meet an S02 regulation.
C-5
-------
Category 7
Category 8
FGD Vendor
Fuel Characteristics
General Process Type
New
Process Additives
Process Type
Considering an FGD system as
well as alternative methods.
Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended
indefinite period of time.
A firm that fabricates and
supplies flue gas desulfuriza-
tion systems.
Type of fuel, average gross
heating value in Btu/lb.
average percent ash and
average percent sulfur content
for fuel as fired.
The manner in which the SO2
from the flue gas is collected,
e.g. wet scrubbing, spray
drying, dry adsorption.
FGD unit and boiler were
designed at the same time or
space for addition of an FGD
unit was jqe,served .when boiler
was constructed.
A chemical compound or element
which is added to the process
or normally found with the
main process reagent in small
quantities (e.g. Mg, adipic
acid) to promote improved
process operation (e.g. scale
reduction, increased SO2
removal efficiency).
Company name if process is
patented. Generic name if
several companies have similar
processes (e.g., Lime, Limestone,
Wellman Lord, Thoroughbred
121).
C-6
-------
Regulatory Class
Retrofit
Spare Capacity Index -%
Spare Component Index
Start-up Date
Total Controlled Capacity [TCC]
A. New boiler constructed
subject to Federal New
Source Performance Stan-
dards (NSPS), 8/17/71.
B. Existing boiler subject
to State Standard that is
more stringent than the
NSPS, 8/17/71.
C. Existing boiler subject
to State Standard that is
equal to or less stringent
than NSPS, 8/17/71.
D. Other (unknown, undeter-
mined) .
FGD unit will be/was added to
an existing boiler not specifi-
cally designed to accommodate
FGD unit.
The summation of the individual
component capacities(%) minus
100%.
The equipment spare capacity
index (%) divided by the indivi-
dual component capacity (%).
Date when initial S02 removal
began or is scheduled to
begin.
The gross rating (MW) of a
unit brought into compliance
with FGD, regardless of the
percent of flue gas treated at
the facility. In the case of
prototype and demonstration
FGD systems, this figure will
be identical to the Equivalent
Scrubbed Capacity rather than
the gross unit rating if the
system is not meant to bring
the facility into compliance
with SO- emission standards.
C-7
-------
Unit Name
Unit Rating
Gross
Net w/FGD
Net w/o FGD
Utility Name
Water Make-Up
Unit identification as it
appears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - or as indicated by
utility representative for
installations in planning
stages.
Operational - Maximum con-
tinuous gross generation
capacity in MW; Preoperational
- maximum continuous design
generation capacity in MW.
Gross unit rating less the
energy required to operate
ancillary station equipment,
inclusive of emission control
systems.
Gross unit rating less the
energy required to operate
ancillary station equipment/
exclusive of emission control
systems.
Name of corporation as it
appears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - as space permits.
Gallons per minute of make-up
water required per MW of
capacity.
C-8
-------
APPENDIX D
TABLE OF UNIT NOTATION
D-l
-------
TABLE OF UNIT NOTATION
O
ro
Classification
Area
Concentration
Flow
Heat Content
Length
L/C Ratio
Mass/Height
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
ft*
gr/scf
PP» c
lb/10* Btu
ft3/min
(actual)
gal/min
Ib/min
t/day
t/h
Btu/lb
ft
in
mi
gal/1000
(actual)
Ib
t
in. H20
F
ft1
Acre-ft
Survey Report
Notation
ACRE
SO. FT
GR/SCF
PPM
LB/MMBTU
ACFM
GPM
LB/MIN
TPD
TPH
BTU/LB
FT
IN
MI
GAL/1000ACF
LB
T
IN. H20
F
CU.F
ACRE-FT
ASTM/SI Unit
Square meter
Square meter
Grams per cubic meter
Parts per million
Nanograms per joule
Cubic meters per
second
Liters per second
Kilogram per second
Metric ton per day
Metric ton per hour
Kilo joule per
kilogram
Meter
Centimeter
Kilometer
Liters per cubic
meter
Kilogram
Megagram
Kilopascal
Degree Celsius
Cubic meter
Cubic meter
Symbol
M2
M
g/.3
ppm
ng/J
m3/.
liter/s
kg/s
M t/d
M t/h
J/g
m
cm
km
liter/m3
kg
Mg
kPa
C
m
Survey Report
Notation
SQ.M
SO.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/CO. M
KG
MG
a
CU-!M
CUrH
-------
TECHNICAL REPORT DATA
(rlcatc read Instruction* on ilic rcfcnt he fore l
EPA-600/7-79-022e
2.
3. RECIPIENT'S ACCESSION NO.
4. TITLE AND SUBTITLE
EPA Utility FGD Survey: April - June 1979
5 REPORT DATE
August 1979
6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
M. Smith, M. Melia, T. Roger
8 PERFORMING ORGANIZATION REPORT NO
PN 3470-1-C
PERFORMING ORGANIZATION NAME AND ADDRESS
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
10 PROGRAM ELEMENT NO
EHE624
11. CONTRACT/GRANT NO.
68-02-2603, Task 48
12. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
Quarterly; 4/79-6/79
14 SPONSORING AGENCY CODE
EPA/600/13
16. SUPPLEMENTARY NOTES--,. . ,»,,.
EPA Project Officers are N. Kaplan (IERL-RTP, MD-61, 919/541-2556)
and J.D. Herlihy (DSSE, 202/755-9137). EPA-600/7-78-051a thru -51d and EPA-600/7-79-
022a thru -022d are previous reports on this series.
t
STR
16. ABSTRACT
This report is the third in a series of four issues generated by a new computerized
data base system. This is an updated supplement to the December 1978 -January 1979
report (EPA-600/7-79-022c) and should be used in conjunction with it. This report
differs from those of the previous series in that the scope of design data for operatinj
FGD systems is vastly expanded, section formats are revised somewhat and a new section
includes operational particulate scrubbers. The report presents a survey of utility
flue gas desulfurization (FGD) systems in the U.S. It summarizes information con-
tributed by the utility industry, process suppliers, regulatory agencies, and con-
sulting engineering firms. Systems are tabulated alphabetically by development
status (operational, under construction, or in planning stages), utility company,
process supplier, process waste disposal practice and regulatory class. It presents
data on system design, fuel sulfur content, operating history, and actual performance.
It includes unit by unit dependability parameters and discusses problems and solutions
associated with the boilers and FGD systems. Process flow diagrams and FGD system
economic data are appended to the report.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS
:. 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
16. DISTRIBUTION STATEMENT
Unlimited
19. SECURITY CLASS (TMi Rtpor
Unclassified
20. SECURITY CLASS (TMtpage)
223
22. PRICE
MA Form 1220-1 (t-73)
m*
*U.S. GOVERNMENT PRINTING OFFICE: 1979- 640- 013 3911REGIONNO.4
------- |