fxEPA
Unned States
Environmental Protection
Agency
Industrial Environmental Research
Laboratorv
Research Triangle Park NC 2771 1
EPA-600 7-78-051 c
September 1978
EPA Utility
FGD Survey:
April-May 1978
nteragency
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-600/7-78-051c
September 1978
EPA Utility FGD Survey:
April-May 1978
by
B. Laseke, M. Melia, M. Smith, and W. Fischer
x
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
Contract No. 68-01-4147
Task No. 52
Program Element No. EHE624
EPA Project Officers:
N. Kaplan J.C. Herlihy
Industrial Environmental Research Laboratory Division of Stationary Source Enforcement
Office of Energy, Minerals, and Industry Office of Enforcement
Research Triangle Park, NC 27711 Washington, DC 20460
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Research and Development
Washington, DC 20460
-------
NOTICE
This report, (prepared by PEDCo Environmental, Inc.,
Cincinnati, Ohio, under EPA Contract No. 68-01-4147, Task No. 52)
is provided as an information transfer document. Data in this
report are supplied voluntarily by utility representatives; flue
gas desulfurization (FGD) system designers, vendors, and sup-
pliers; regulatory 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 five supplementary issues to
the December 1977 - January 1978 report. Supplementary issues
are cumulative, so that it is necessary only to retain the
latest issue and the December 1977 - January 1978 report (EPA-
600/7-78-051a).
^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 PGD Systems
Section 3 Performance Description of Operational FGD
Systems
Arizona Public Service
Cholla 1
Cholla 2
Columbus and Southern Ohio Electric
Conesville 5
Conesville 6
Duquesne Light
Elrama 1-4
Phillips 1-6
Indianapolis Power and Light
Petersburg 3
Kansas City Power and Light
Hawthorn 3
Hawthorn 4
La Cygne 1
Kansas Power and Light
Lawrence 4
Lawrence 5
Kentucky Utilities
Green River 1, 2, and 3
Louisville Gas and Electric
Cane Run 4
Cane Run 5
Paddys Run 6
Minnkota Power Cooperative
Milton R. Young 2
Montana Power
Colstrip 1
Colstrip 2
1
4
22
22
23
24
25
26
28
29
30
31
32
33
34
35
37
38
39
40
41
42
iii
-------
CONTENTS (cont inued)
Nevada Power
Reid Gardner 1 43
Reid Gardner 2 44
Reid Gardner 3 45
Northern Indiana Public Service
Dean H. Mitchell 11 46
Northern States Power
Sherburne County Station 1 48
Sherburne County Station 2 49
Pennsylvania Power
Bruce Mansfield 1 50
Bruce Mansfield 2 51
Philadelphia Electric
Eddystone 1A 52
Public Service Company of New Mexico
San Juan 1 53
South Carolina Public Service
Winyah 2 54
Springfield City Utilities
Southwest 1 55
Tennessee Valley Authority
Shawnee 10A 56
Shawnee 10B 57
Widows Creek 8 59
Texas Utilities
Martin Lake 1 61
Monticello 3 - 62
Utah Power and Light
Huntington 1 63
Section 4 Summary of PGD Systems by Company 64
Section 5 Summary of FGD Systems by Vendor 65
Section 6 Summary of New and Retrofit FGD Systems by
Process 67
Section 7 Summary of Operating FGD Systems by Process and
Generating Units 68
Section 8 Summary of Sludge Disposal Practices for
Operational FGD Systems 7Q
Section 9 Summary of FGD Systems by Process and Regulatory
Class * 71
Section 10 Summary of FGD Systems Under Construction 73
iv
-------
CONTENTS (continued)
Page
Section 11 Summary of Planned FGD Systems 75
Section 13 Total of FGD Megawatt Capacity by Year 78
Appendix A FGD Systems Economics A-l
Appendix B FGD Process Flow Diagrams B-l
Appendix C Definitions C-l
-------
TABLES
No. Page
I Number and Total MW of FGD Systems vii
II Summary of Changes: FGD Summary Report, April-May
1978 x
III Performance of Operational Units During April-May
Period xii
vi
-------
EXECUTIVE SUMMARY
This report is prepared every other month by PEDCo Environmental,
Inc., under a contract to the Industrial Environmental Research
Laboratory/RTF and the Division of Stationary Source Enforcement
of the U.S. Environmental Protection Agency. Table 1 summarizes
the current status of the FGD systems addressed in this 2-month
period.
Table I
NUMBER OF TOTAL MW OF FGD SYSTEMS
Status
Operational
Under construction
Planning:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only FGD systems
TOTAL
No. of
units
37
43
19
3
2
34
138
MW
12,862
17,177
10,606
892
855
16,552
58,944
Table II (page x) summarizes the individual units that changed
status during the reporting period.
The performance of the operating systems is summarized in Table
III (page adii). Other activity highlights during the months of
April and May are summarized below:
The present total power-generating capability of the electric
utility industry in the United States is approximately 532.4 GW
vii
-------
Of this total, approximately 250 Gw , representing 47 percent of
the total, is generated by coal. As indicated in Table I, 36
FGD-equipped coal-fired units, representing 12,112 MW of power
capability, are now in service. Thus, a little over 2 percent of
the total utility power-generating capacity and a little under 5
percent of the utility coal-fired capacity are controlled by FGD.
By 1986, the projected total power-generating capacity of the
electric utility industry in the United States will be approxi-
mately 812.7 GWa. This represents an increase of 53 percent over
the present total and includes retirements of older units (0.4
percent annual average based on year-end power-generation capabil-
ity) . Of the 1986 total, approximately 363.2 GWa*bfCr represent-
ing 45 percent of the total, will be generated by coal. As
indicated in Table I, 138 FGD-equipped coal-fired units, repre-
senting 58,944 MW of power capacity, are now scheduled for
operation by 1986. Thus, approximately 7 percent of the projec-
ted total generating capacity and 16 percent of the projected
coal-fired capacity will be controlled by FGD by the end of 1986.
HIGHLIGHTS: APRIL-MAY 1978
Arizona Public Service reported that Cholla 2 became operational
during the period. Compliance testing should be completed by
August 15 and commercial startup is expected in August 1978.
Cholla 1 demonstrated a total system reliability of 25 percent in
April.
A contract was awarded to Combustion Engineering for a lime FGD
system at Eastern Kentucky Power's 500 MW Spurlock 2 located near
Maysville, Kentucky. Spurlock 2 will utilize a 99.5 percent ESP
for particulate removal.
Hoosier Energy reported that construction began at Merom 1 and 2.
Construction was delayed at the two 490 MW units, which will
utilize limestone for SO2 removal, for most of the winter because
of bad weather.
Indianapolis Power and Light awarded a contract to Research
Cottrell to install a limestone FGD system with a designed SOo
removal efficiency of 80 percent at Petersburg 4. The 530 MW
unit is scheduled to start up in April 1982.
The FGD system at the La Cygne 1 generating station of Kansas
City Power and Light operated with an average availability of 91
percent for the period. Boiler hours were 620 and 543 for April
and May, respectively. Most of the FGD system general maintenance
and repairs were accomplished during boiler outages.
The Lawrence 5 unit of Kansas City Power and Light came back on-
line April 14 after the tie-in of the new two-module rod-deck
scrubber and spray tower absorber system was completed. The
system has operated without an outage since startup.
viii
-------
Montana Power reported that the Colstrip 1 and 2 were down for
the most of the spring because of scheduled overhauls.
Nevada Power reported that availabilities ranged from 97 to 100
percent for the report period for Reid Gardner 1, 2, and 3 while
reliabilities were between 96 and 100 percent.
The FGD systems at Sherburne 1 and 2 of Northern States Power
demonstrated total-system availabilities of 95 and 92 percent for
April. Total-system availabilities for May were 95 and 91 per-
cent for Units 1 and 2, respectively. During April new stainless
steel strainer screens were installed in two of the modules on
Sherburne 1, and Module 201 on Sherburne 2 was converted for use
with the new spray tower.
Philadelphia Electric reported that Eddystone 1A came back on-
line June 1. The unit had been down since December 22, 1977,
because of an extensive system modification.
South Carolina Public Service reported that construction began at
300 MW Winyah 3 on the limestone venturi/tray tower system, which
is similar to the operational system at Winyah 2 with particulate
removal affected by ESP's and a flue gas bypass system for re-
heat.
As part of a cooperative agreement between the U.S. EPA and the
U.S. Bureau of Mines (USBM), a demonstration regenerable citrate
FGD system is now being installed on a 50-MW coal-fired boiler at
the G.F. Wheaton Station of the St. Joseph Minerals Corporation
in Monaco, Pennsylvania. The citrate process, which has been
developed through two separate pilot plant programs conducted by
USBM and Pfizer Chemical Company, recovers the scrubbed sulfur
dioxide as elemental sulfur. Although the installation site is
an industrial facility, this system was added to the utility FGD
survey report because the G.F. Wheaton Station is interconnected
via a 25-MW interchange to the Duquesne Light Company (in addi-
tion to supplying the steam and electric load for smelting
operations at the plant).
The Texas Air Control Board reported that Texas Utilities 750-MW
Monticello Unit 3 became operational during the period; however,
as of yet the unit has not operated at greater than a 300-MW
load. The utility expects to be running at full load by the end
of August.
Initial operations began at Utah Power and Light's Huntington 1
unit. Commercial operation should start sometime in July.
ix
-------
Table II. SUMMARY OF CHANGES: FGD SUMMARY REPORT, APRIL-MAY 1978
PCD statue report
3-31-71
Arisen* Public Service
Cholla 2
Associated Blec. Coop
TttOMS Rill 3
Basin Blectrie Power Coop
Antelope Valley 2
Central Illinois Light
Duck Creek 2
Eastern Kentucky Power Coop
Spurloek 2
General Public Utilities
Seward 7
Gulf Power
Schols IB 4 2B
Hoosler Energy
Nsrof i
Hoosler Energy
Nero* 2
Indianapolis Power Light
Petersburg 4
Public Service of N.H.
San Juan 3
South Carolina Public Serv.
Winyah 3
Southern Illinois Power Coop.
Marlon S
Operational
No.
34
+1
MM
11.447
250
Under
construction
No.
42
-1
-1
+1
1
41
+1
-1
41
MN
17,«25
250
455
20
490
490
530
468
300
Contract
awarded
No.
17
+1
41
+1
-1
-1
+1
-I
MM
9,073
670
455
500
490
490
468
300
Letter of
Intent
No.
3
MM
892
Requesting/
eval. bids
No.
4
+ 1
-1
-1
MM
2,030
400
500
530
Considering
PGD
No.
32
-1
+1
+1
MM
15,307
400
800
300
Total
No.
132
41
*1
+1
+ 1
MN
56,374
670
800
20
300
-------
Table II. (cont'inued)
X
H-
PCD status report
Southwestern Electric Power
Henry N. Perkey 1
St. Joe Minerals Corp.
G.F. Heat on 1
Texas Power t Light
Sandov 4
Texas Utilities
Nonticello 3
Utah Power and Light
Huntinqton 1
Total e
Operational
No.
+ 1
+1
37
MW
750
415
12,862
Under
construction
No.
+1
1
-1
43
MW
60
750
415
17,177
Contract
awarded
No.
+1
19
MW
720
10,606
Letter of
intent
No.
3
MW
892
Requesting/
eval. bids
No.
-1
2
MW
545
855
Considering
PCD
No.
+1
34
MW
545
16,552
Total
No.
+1
+1
132
MW
720
60
58,944
-------
Table III. PERFORMANCE OF OPERATIONAL UNITS DURING APRIL-MAY PERIOD
Plant
Cholla 1
Cholla 2
COneaville 5
Coneeville 6
ElraM
Phillip*
Petersburg 3
Hawthorn 3
Hawthorn 4
La Cygne
Lawrence 4
Lawrence S
Green River
1,2, and 3
Cane Run 4
Cane Run 5
Paddya Run C
M. R. young 2
Coletrip 1
Coletrlp 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
D. H. Mitchell
IX
Sherburne 1
Sharburne 2
POD ayaten
deaign
capacity
115
250
400
400
510
410
530
140
100
20
125
400
64
171
113
65
450
360
360
125
125
125
115
710
710
PGO unit
on-line during
period
115
250
400
310
410
530
140
100
820
125
400
64
178
183
65
450
125
125
125
115
710
710
No
information
(or thia
period
Shutdown
throughout
period
400
200
360
360
PGD- aysten
availability,
t
Apr
66
76
40
91
41
100
100
97
0
95
92
May
S3
37
44
91
64
97
100
97
51
95
91
PCD eyete*
o per ability,
«
Apr
59
99
100
97
98
89
May
48
100
35
92
100
77
PCD ayateei
reliability,
%
Apr
85
82
99
100
100
97
0
May
48
98
96
100
96
50
PCD ayateei
utilisation,
%
Apr
59
41
47
75
44
87
0
Ma«
47
64
12
*
78
97
66
37
X
*
H-
(continued)
-------
Table III. (continued)
Plant
truce Hansfielc
I
Bruce Mansfield
i
EddystoM 1A
San Juan X
Winy ah 2
Southwest 1
Shawnee 10*
Shawnee 10B
Widows Creek 8
Martin Lake 1
tonticello 3
Huntington 1
Total
PCD ayatem
design
capacity
625
825
120
314
280
200
10
10
550
793
750
415
12,862
PCD unit
on-line during
period
314
280
200
10
10
550
793
750
415
9,772
NO
information
for this
period
825
825
1,650
Shutdown
throughout
period
120
1,440
FGD system
availability,
»
Apr
69
May
FGD system
o per ability,
»
Apr
83
May
FGD system
reliability,
»
Apr
67
May
FGD system
utilization ,
t
Apr
62
May
X
M-
-------
REFERENCES FOR EXECUTIVE SUMMARY
Sixth Biennial Survey of Power Equipment Requirements of
the U.S. Electric Utility Industry: 1977-1986, spon-
sored by the Power Equipment Div., National Electrical
Manufacturers Association.
Policy Testing Model for Electric Utilities, Exhibit
II-3, Developed by Temple, Barker, and Sloane, Inc.
12th Annual Power Engineering Survey, Power Engineering,
April 1978.
xiv
-------
EPA UTILITY FGO SURVEY: APRIL 1978 - HAY 1978
COMPANY NAME
SECTION 1
SUMMARY LIST UF FGO SYSTEMS
UNIT NAME
START UP DATE STATUS
REG
CLASS
ALABAMA ELECTRIC COOP
ALABAMA ELECTRIC CUOP
ALLEGHENY POWER SYSTtM
ALLEGHENY POWER SYSTtM
ARIZONA ELECTRIC POWER CUOP
ARIZONA ELECTRIC PUWE^ COOP
ARIZONA PUBLIC SERVICE
ARIZONA PUBLIC StRVICt
ARIZONA PUBLIC SERVICE
ARIZONA PUBLIC SERVICE
ARIZONA PUBLIC SERVICE
ARIZONA PUBLIC SERVICE
ARIZONA PUBLIC SERVICE
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC COOP
BASIN ELECTRIC POWER COOP
BASIN ELECTRIC POWER COOP
BASIN ELECTRIC POWER COOP
BASIN ELECTRIC POWER COOP
BASIN ELECTRIC POWER COOP
BIG RIVERS ELECTRIC
BIG RIVF.RS ELECTRIC
BRAZOS ELECTRIC POWER COOP
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CINCINNATI GAS ft ELECTRIC
COLORADO UTE ELECTRIC ASSN.
COLORADO UTE ELECTRIC ASSN.
COLUMBUS ft SOUTHERN OHIO ELEC.
COLUMBUS ft SOUTHERN OHIO ELEC.
COLUMBUS ft SOUTHERN OHIO ELEC.
COLUMBUS ft SOUTHERN OHIO ELEC.
COMMONWEALTH EDISON
COOPERATIVE POWER ASSOCIATION
COOPERATIVE POWER ASSOCIATION
UELMARVA POWER & LIGHT
DUOUESNE LIGHT
OUOUESNE LIGHT
EASTERN KENTUCKY POWER CUOP
GENERAL PUBLIC UTILITIES
GENERAL PUBLIC UTILITIES
GULF POWER
GULF POWER
GULF POWER
GULF POWER
HOOSIER ENERGY
HOOSIER ENERGY
INDIANAPOLIS POWER * LIGHT
INDIANAPOLIS POWER ft LIGHT
KANSAS CITY POWER ft LIGHT
KANSAS CITY POWER ft LIGHT
KANSAS CITY POWER & LIGHT
KANSAS POKIER ft LIGHT
KANSAS,POWER ft LIGHT
KANSAS POWER * LIGHT
KANSAS PUWER ft LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
TUMblbHEE £
TO«BIGBEE <
Plt«SANTS 1
PLtASANTS 2
AHACHE I
APALHE 3
CHOLLA 1
CHULLA 2
CHOLL* a
(UUH LOKNfcRS 1
FOUK CORNERS 2
FUUR CORNERS 3
FUUR CORNERS u
FOUR cowNtHs 5
THOMAS HILL 3
ANTfcLOPt VALLEY 1
ANTfcLOPE VALLEY 2
LARAM1E RIVER 1
LARAMIE RIVER I
LARAMIE RIVER 3
REID I
HEIU 3
SAN MIGUEL I
DUCK CRtEK 1
DUCK CREEn 2
NbWTON 1
SbARS ISLANO 1
EAST BEND 2
CRAIG 1
CRAIG 2
CONESVILLE 5
CONESVILLE b
POSTON 5
POSTON b
POWERTON si
COAL CREEK 1
COAL CREEK 2
OtLnANE CITY l, 2 ft J
ELHAMA POWER STATION
PHILLIPS POWER STATION
SPURLOCK 2
COHO 1
StWARO 7
CRIST a « s
CRIST b ft 7
LANSING SMITH 1 ft 2
SCHOLl NOS. IB & 2B
MEROM 1
MtROM 2
PETERSBURG 3
PETERSBURG a
HAWTHORN 3
HAWTHORN 4
LA CVGNE I
JtFFEKEY 1
JEFFEKEY 2
LAWRENCE a
LAWRENCE 5
GREEN RIVER 1.2 ft 3
MCINTUSH 3
7-78
b-79
3-79
3-80
8-78
a-79
10-73
b-78
b-80
0- 0
0- 0
0- 0
0- 0
0- 0
0-81
11-81
11-83
0-80
10-80
fl-82
12-79
12-80
b-80
8-78
1-82
11-79
ll-8b
1-81
3-79
3-79
1-77
4-78
0-83
o-as
3-79
2-79
11-79
6-80
10-75
7-73
3-80
5-67
5-84
0- 0
0-80
0-80
8-78
12-80
10-81
10-77
4-82
11-72
8-72
2-73
b-78
b-80
12-68
11-71
9-75
10-81
3
5
b
2
2
b
2
2
2
2
5
2
b
3
2
2
1
1
b
b
2
2
2
2
1
1
3
b
b
7
7
7
2
2
2
1
2
1
1
1
2
2
1
1
1
3
B
B
B
B
B
B
C
A
A
C
B
B
A
A
A
B
B
B
C
A
A
A
A
B
B
C
B
B
B
B
C
A
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
a. PLANNED - LETTER OF INTEST SIGNED
5. PLANNED - REQUESTiNG/tv«i_UATING BIDS
b. CUNSIDtHlNG ONLY FGD SYSTEMS
/. CUNSIOERING FGO SYSTEMS AS WELL AS ALTERNATIVE METHODS
A. BOILER CONSTRUCTED SUBJECT Tl) FEDERAL NSPS
B. BOILER SUBJECT TO STATt STANDAKh THAT 1i MORE STRINGENT THAN THE FEDERAL NSPS
C. BOILER SUBJECT TO STAIF STANDARD IHA! IS EQUAL TO OR LESS STRINGENT THAN NSPS
0. OTHER
E. REGULATORY CLASS UNKNUAN
-------
EP» UTILITY FGO SURVEY: APRIL 1976 - MAY 1978
COMPANY NAME
SECTION 1
SUMMARY LIST OF FGU SYSTEMS
UNIT NAHb
START UP DATE
REG
STATUS CLASS
LOUISVILLE GAS ELECTRIC
LOUISVILLE GAS ELECTRIC
LOUISVILLE GAS ELECTRIC
LOUISVILLE GAS ELECTRIC
LOUISVILLE GAS ELECTRIC
LOUISVILLE GAS ELECTRIC
LOUISVILLE GAS ELECTRIC
LOUISVILLE GAS ELECTRIC
MINNESOTA POKER & LIGHT
MINNKOTA POKER COOPERATIVE
MONTANA POKER
MONTANA POKER
MONTANA POKEH
MONTANA POKER
NEVADA POKER
NEVADA POKER
NEVAO* POKER
NEVADA POKER
NEVADA POKER
NEVADA POKER
NEVADA POKER
NEVADA POKER
NEVADA POKER
NEVADA POKER
NEK ENGLAND ELEC SYSTEM
NIAGARA MOHANK P0nf.fi CUOP
NORTHERN INDIANA PUR SERVICE
NORTHERN INDIANA PUB SERVICE
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POMEK
NORTHERN STATES POHER
NORTHERN STATES POKER
NORTHERN STATES POKER
OTTER TAIL POKER
PACIFIC GAS AND ELECTRIC
PACIFIC GAS AND ELECTRIC
PACIFIC POKER » LIGHT
PENNSYLVANIA POKER
PENNSYLVANIA POKER
PENNSYLVANIA POKER
PHILADELPHIA ELECTRIC
PHILADELPHIA ELECTRIC
PHILADELPHIA ELECTRIC
PHILADELPHIA ELECTRIC
POTOMAC ELECTRIC POKER
POKER AUTHORITY OF NEK YORK
PUBLIC SERVICE OF INDIANA
PUBLIC SERVICE OF NE« MEXICO
PUBLIC SERVICE OF NEK MEXICO
PUBLIC SERVICE OF NEK MEXICO
PUBLIC SERVICE OF NEK MEXICO
SALT HIVtR PROJECT
SALT RIVER PROJECT
SALT RIVER PROJECT
SIKESTON BOARD OF MUNIC. UTIL.
SOUTH CAROLINA PUBLIC SERVICE
SOUTH CAROLINA PUBLIC SERVICE
SOUTHERN ILLINOIS POKER COOP
SOUTHERN ILLINOIS POKER COUP
SOUTHERN INDIANA GAS * ELFC
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AHARDEU
CANE RUN a
CANE RUN b
CANE RUN 6
MILL CRtEK 1
MILL CREEK 2
MILL CREEK 3
"ILL CREEK a
PADDYS RUN »
CLAY BOSHELL 4
M1LTUN R. YUUNG 2
CULSTRIP 1
CULSTRIP 2
CULSTRIP 3
COLSTRIP 0
HARRY ALLEN 1
HARRY ALLEN 2
HARRY ALLEN 3
HARRY ALLEN 4
REtU GARDNER 1
REID GARDNER 2
REID GARDNER S
REID GARDNER 4
HARNER VALLEY 1
NARNER VALLEY 2
8RAYTON PUINT 3
CHARLES R. HUNTLEY b
BAILLY 7
BAILLY 8
DEAN H. MITCHELL 11
SHERBURNE i
SHERBURNE 2
SHEHBURNE 3
SHERRURNE 4
COYOTE 1
FOSSIL I
FOSSIL 2
JIM BRIDGER 4
BRUCE MANSFIELD 1
BRUCE MANSFIELD 2
BRUCE MANSFIELD 3
CRUMBY
EDOYSTONE 1A
EDDYSTONE IB
EDDYSIONE 2
D1CKERSON 4
ARTHUR KILL PLANT
GIBSON 5
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
SAN JUAN 4
CORUNADO 1
CURONADU 2
CURONADO 3
S1KESION POnER STATION
KINYAH 2
HINYAH 3
MARION «
MARION 5
A. B. BROnN 1
8-76
12-77
12-78
1-82
1-81
7-78
6-80
4-73
5-80
9-77
11-75
87-60
7-80
7-81
6-83
6-84
6-85
6-86
a-74
4-74
7-76
0- 0
6-82
6-83
0- 0
0-80
0- 0
0- 0
11-76
3-76
4-77
5-81
5-83
5-81
0-84
0-85
9-7<»
4-76
7-77
4-80
6-80
9-75
6-60
6-60
5-85
11-64
0-82
4-76
7-78
1-81
1-82
4-79
4-80
0-87
6-81
7-77
5-60
6-78
0-84
4-79
1
1
2
6
6
2
e
1
e
i
i
i
3
3
6
b
6
6
1
1
1
4
6
6
b
3
6
6
1
1
1
3
3
3
6
6
2
1
1
3
6
1
4
6
7
7
6
1
2
3
6
Z
2
6
2
1
2
2
6
2
C
C
C
C
C
B
B
B
B
B
B
B
B
B
B
B
B
B
B
B
D
B
A
B
B
8
B
B
B
B
4. PLANNED - LEITER OF INTENI SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
b. CONSIDERING ONLY FGO SYSTEMS
7. CONSIDERING FGO SYSTEMS AS WELL AS ALTERNATIVE METHODS
A. BOILER CONSTRUCTED SUBJECT 1U FEDERAL NSPS
B. BOILER SUBJECT TO STATE STANDARD 1HAT IS MORE STRINGENT THAN THE FEDERAL NSPS
C. BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
D. OTHER
E. REGULATORY CLASS UNKNOWN
-------
EPA UTILITY FGD SURVEY: APRIL 1978 - MAY ma
SECTION 1
SUMMARY LIST OF FGO SYSTEMS
COMPANY NAME
SOUTHERN MISSISSIPPI ELECTRIC
SOUTHERN MISSISSIPPI ELECTRIC
SOUTHWESTERN ELECTRIC POWER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD MATER LIGHT & PNR
ST. JOE MINERALS CORP.
TENNESSEE VALLEY AUTHORITY
TENNESSEE VALLEY AUTHORITY
TENNESSEE VALLEY AUTHORITY
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER S LIGHT
TEXAS POWER & LIGHT
TEXAS POWER ft LIGHT
TEXAS UTILITIES
TEXAS UTILITIES
TEXAS UTILITIES
TEXAS UTILITIES
TEXAS UTILITIES
TEXAS UTILITIES
UTAH POWER » LIGHT
UTAH POWER * LIGHT
VIRGINIA ELECTRIC » POWER
WISCONSIN POWER « LIGHT
UNIT NAME
R. D. MORROW 1
R. U. MORROW I
HENRY W. PERKEY
SOUTHWEST 1
DALLMAN 3
G. r. WEATON i
SHAwNEE 10A
ShAwNEE 10B
WIDOWS CREEK 7
WIDOWS CREEK 8
GIBBONS CREEK 1
SANUOW tt
TwIN OAKS 1
TWIN OAKS i
FOREST GROVE 1
MARTIN LAKE 1
MARTIN LAKE 2
MARTIN LAKE 3
MARTIN LAKE a
MUNTICELLO i
EMERY 1
HUNTINGTON 1
MT. STORM
COLUMBIA 2
START UP DATE
6-70
10-78
6-83
4-77
7-HO
10-7S
0-72
a-7<>
0- 0
5-77
1-82
7-00
8-83
9-ea
0-81
8-77
5-76
12-78
11-82
5-76
12-76
5-76
0- 0
1-80
NEG
STATUS CLASS
2
i
3
1
3
2
1
1
3
1
J
3
b
b
b
1
2
2
3
1
2
1
7
a
1. OPERATIONAL UNITS
2* UNITS UNDER CONSTRUCTION
* PLANNED - CONTRACT AWARDED
a. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
b. CONSIDERING ONLY FGD SYSTEMS
7. CONSIDERING FGD SYSTEMS AS NELL AS ALTERNATIVE METHODS
» BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
8« 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
°. OTHER
E« REGULATORY CLASS UNKNOWN
-------
EPA UTILITY F60 SURVEY: APRIL 1976 - MAY 1978
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
ALABAMA ELECTRIC COOP
TOMBI6BEE 2
aas MM - NEH
COAL 0.8 - 1.5 PERCENT SULFUR
PEABOOY ENGINEERING
LIMESTONE
STARTUP 7/78
PEABODY ENGINEERING HAS BEEN AHAkOED THE CONTRACT FOR THE INSTALLATION
OF A LIMESTONE FGD SYSTEM ON THIS UNIT. A HIGH-EFFICIENCY ESP MILL
BE INSTALLED UPSTREAM OF THE FGD SYSTEM TO PROVIDE PRIMARY
PARTICULATE CONTROL. THE FGO SYSTEM CONTAINS TMO SCRUBBING TRAINS,
TREATING APPROXIMATELY 70 PERCENT OF THE FLUE GAS FOR REMOVAL OF SULFUR
DIOXIDE. STACK GAS REHEAT MILL NOT BE REQUIRED. COST INFORMATION IS
REPORTED IN APPENDIX A. CURRENTLY, ERECTION OF THE SCRUBBING EQUIPMENT
IS NOW IN FINAL PHASE.
ALABAMA ELECTRIC COOP
TOMBIGBEE 3
225 MM » NEM
COAL 0.8 - 1.5 PERCENT SULFUR
PEABODY ENGINEERING
LIMESTONE
STARTUP 6/79
PEABUDY ENGINEERING HAS BEEN AMARDED THE CONTRACT FOR THE INSTALLATION
OF A LIMESTONE FGO SYSTEM UN THIS UNIT. A HIGH-EFFICIENCY ESP MILL
BE INSTALLED UPSTREAM OF THE FGD SYSTEM TO PROVIDE PRIMARY
PARTICULATE CONTROL. THE FGD SYSTEM CONSISTS OF TMO TRAINS, TOGETHER
TREATING APPROXIMATELY 70 PERCENT OF THE FLUE GAS FOR REMOVAL OF SULFUR
DIOXIDE. STACK GAS REHEAT MILL NOT BE REQUIRED. CONSTRUCTION ON THE UNIT 3
TURBINE AND BOILER HAS BEGUN AND IS JO TO 00 PERCENT COMPLETE.
ALLEGHENY POMES SYSTEM
PLEASANTS 1
625 MM - NEM
COAL 4.5 PERCENT SULFUR (MAX)
BABCOCK ft MILCOX
LIME
STARTUP 3/79
THE THREE PRINCIPAL OPERATING UTILITY COMPANIES OF THE ALLEGHENY POMER
SYSTEM ARE INSTALLING AN EMISSION CONTROL SYSTEM FOR THIS NEM COAL-FIRED
UNIT MHICH INCLUDES A HIGH EFFICIENCY ESP UPSTREAM OF FOUR TRAY TONERS
FOR THE CONTROL OF PARTICULATES AND SULFUR DIOXIDE. DESIGN REMOVAL
EFFICIENCIES FOR THIS EMISSION CONTROL SYSTEM ARE 99.5 AND 90 PERCENT
RESPECTIVELY. THE ORAVU CO. IS SUPPLYING THIOSORBIC LIME. THE CONSULTING
ENGINEERING FIRM IS UNITED ENGINEERS AND CONSTRUCTORS. CURRENTLY, EREC-
TION OF THE SCRUBBING EQUIPMENT IS IN PROGRESS.
ALLEGHENY POMER SYSTF-
PLEASANTS 2
625 MM - NEM
COAL a.5 PFHCENT SULFUR (MAI)
BABCOCK t MILCOX
LIME
STARTUP 3/80
THE THREE PRINCIPAL OPERATING UTILITY COMPANIES OF THE ALLEGHENY POMER
SYSTEM AKE INSTALLING AN EMISSION CONTROL SYSTEM FOR THIS NEM COAL-FIRED
UNIT MHICH 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 99.5 AND 90 PERCENT,
RESPECTIVELY. THE DRAVU CO. IS SUPPLYING THIOSORBIC LIME. THE CONSULTING
ENGINEERING FIRM IS UNITED ENGINEERS AND CONSTRUCTORS. CURRENTLY, FOUNDA-
TION HORK ON THE SCRUBbER PLANT IS IN PROGRESS.
ARIZONA ELECTRIC POMER COUP
APACHE 2
200 MM - NEM
COAL 0.5- 0.8 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP 8/78
AEPC HAS AMAROED A CONTRACT TO RESEARCH COTTRELL FOR A LIMESTONE FGD
SYSTEM. THE UNIT HILL FIRE BITUMINOUS COAL WITH A SULFUR CONTENT OF
0.5-0.61 AND ASH CONTENT OF 10.OX (HEATING VALUE - 10,000-11,OOOBTU/LB).
THERE is A aa ACRE SLUDGE POND AND A M ACRE ASH POND. PONDS MILL BE
UNLINED AND 10 FEET DEEP. THERE MILL BE NO REHEAT. CONSTRUCTION OF THE
SYSTEM IS NEARLY COMPLETE AND ALL FGO EQUIPMENT IS INSTALLED. SCRUBBER
LINING IS COMPLETE. THE PLASTIC GIRDERS SUPPORTING THE MIST ELIMINATORS
WERE REPLACED MlTH STEEL GIRDERS. ELECTRICAL MORK CONTINUES.
ARIZONA ELECTRIC POMER COUP
APACHE 3
200 MM - NEM
COAL 0.5- 0.8 PERCENT SULFUR
RESEARCH COTTHELL
LIMESTONE
STARTUP 4/79
STRUCTURAL STEELWORK FUR HOT-SIDE UOP ESP'S IS COMPLETE. STRUCTURE
ERECTION OF THE SCRUBBER-ABSORBER TONERS IS COMPLETE. EACH SCRUBBER CAN
HANDLE 400,000 ACFM d 270 F AND RECIRCULATE 20,000 GPM OF SLURRY. BOILER
CONSTRUCTION HAS BEGUN. THERE ARE CURRENTLY 2 PONDS MlTH A TOTAL OF 20-
YRS CAPACITY FOR THE DISPOSAL OF THE UNFIXATEO SLUDGE. 2 ADDITIONAL PONDS
ARE PLANNED PROVIDING AN ADDITIONAL 20 YRS OF DISPOSAL CAPABILITY. THERE
MILL BE NO REHEAT. BECAUSE OF THE HIGH COST OF THE UNIT 2 STACK LINER,
UNIT 3 MILL NOT USE THE cxLaooo MATERIAL USED IN UNIT a.
ARIZONA PUBLIC SERVICE
CHOLLA i
115 MM - RETROFIT
COAL 0.44-1 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP 10/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS LIMESTONE SCRUBBING SYSTEM HAS PLACED IN SERVICE IN OCTOBER 1973.
THE SCRUBBER PLANT CONSISTS OF TMO PARALLEL SCRUBBING TRAINS. PARTICU-
LATE CONTROL IS PROVIDED BY TMO FLOODEO-DISC SCRUBBERS. 302 CONTROL IS
PROVIDED BY ONE PACKED (HUNTERS PACKING) TOMER (A-3IOE). FLUE GAS CLEAN-
ING HASTES ARE DISCHARGED TO AN EXISTING FLY ASH POND. NO HATER IS RE-
CYCLED BACK FROM THE DISPOSAL POND. IN-LINE STEAM REHEATERS RAISE THE
GAS TEMPERATURE 40 F.
ARIZONA PUBLIC SERVICE
CHOLLA 2
250 MM - NEW
COAL 0.44-1 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP 6/78
THE CONTRACT FUR THIS MET LIMESTONE SCRUBBING SYSTEM HAS BEEN AMARDED
BY THE UTILITY TO RESEARCH-COTTRELL. THERE ARE MECHANICAL COLLECTORS FOR
PRIMARY PARTICULATE REMOVAL. ALL DESIGN AND ENGINEERING MORK HAS BEEN
COMPLETED. CONSTRUCTION OF THE UNIT IS NOW COMPLETE AND CAN BE CONSIDERED
OPERATIONAL. THE FGD SYSTEM CONSISTS OF FOUR PARALLEL FLOOOEO-DISC
AND PACKED TOMER ABSORBER TRAINS. THREE ARE REQUIRED FOR FULL LOAD
CAPACITY. INITIAL BOILER START-UP BEGAN FEBRUARY 1976. FULL COMMERCIAL
OPERATIONS SHOULD OCCUR BY AUGUST 1978.
-------
EPA utiLiir FGD SURVEY: APRIL 1970 - HAT 1979
stciION z
STATUS Of FGU SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
ARIZONA PUBLIC SERVICE
CHOLLA
-------
EPA UTILITY F6D SURVEY: APRIL 1978 - MAY 1978
SECTION 2
STATUS UF Ff,U SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
RASIN ELECTRIC POWER COUP
ANTELOPE VALLEY Z
455 MM - NEW
LIGNITE 0.68 PERCENT SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 11/8S
THt UTILITY IS CURRENTLY INVbSt I I.A 1 TNI. VARIOUS FGO PRUCFSStS FOR THIS
SECOND L1GNITF.-FIWEO U^ IT SCHEDULED AT THE NEW STATION LOCATED IN MERCER
COUNTY, NEAR BEULAH, NORTH DAKOTA. THIS NEw FACILITY HILL HE KNOnN AS
THt ANTELOPE VALLEY STATION AND KILL HE REUUlRfcD TO COMPLY HlTH STATE AIR
EMISSION STANDARDS VIA THE REST AVAILABLE TECHNOLOGY. START-UP IS NOW
SCHEDULED FOk NOVEMBE* 19B3. BIDS ARE EXPECTED TO GO OUT ThIS SUMMER.
BASIN ELECTRIC POMER COUP
LARAMIE RIVER I
570 MM - NEK
COAL 0.6 PERCENT SULFUR
RESEARCH COTTMELL
LIMESTONE
STARTUP a/80
RESEARCH-CUTTKELL IS CURRENTLY FABRICATING THE DUAL-LOOP LIMESTONE NET
SCRUBBERS. ON-SITE CONSTRUCTION COMMENCED IN JANUARY 1978. SLUDGE KILL BE
DEwATEREU TO fl« SOLIDS BEFOKE LANDFILL. THE SCRUBBERS HILL BE MADE OF
STAINLESS STEEL AND "ILL HANDLE 2.3 MM ACFM AT 286 F. L/G RATIO WILL BE
60. REFER TO APPENDIX A FUR COST INFtlRMA I ION. bS« HAS BEEN AWARDED
THE CONTRACT FOR Tn() EbP'S. CONSTRUCT IUN IS NOW 10 PERCENT COMPLETE.
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 2
570 MM - NEW
COAL 0.8 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP 10/60
RESEARCH-CUTTRELL IS CURRENTLY FABRICATING THE DUAL-LOOP LIMESTONE MET
SCRUBBERS. ON-SITE CONSTRUCTION COMMENCED IN JANUARY 197B. SLUDGE MILL BE
DENATERED TO *3t SOLIDS BEFORE LANDFILL. THE SCRUBBERS HILL BE MADE OF
STAINLESS STEEL AND WILL HANDLE
-------
EPA UTILITY FGO SURVEY: APRIL 1976 - MAY 1978
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
000 MM - NEM
COAL 2.5-J.O PERCENT SULFUR
VENOOH NOT SELECTED
LIMESTONE
STARTUP l/8c!
THE SCRUBBING UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN JANUARY 1982.
THE UTILITY HAS NOT YET SELECTED A SYSTEM SUPPLIER. A DECISION CONCFRNINU
THE STATUS OF THt BOILtR AND CONTROL STH»TEGY ftlLL 66 ANNOUNCED IN MID
1978. THE UTILITY «1LL USE tSP'S FOR PAHTICUL»T£ CONTROL AND EITHER
LIMESTONE OR DUAL ALKALI FOR Sl)2 SCRUBBING. THt UTILITY IS NO* IN THE
PROCESS UF TAKING BIOS.
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
575 MB - NEW
COAL 4.0 PFRCENT SULFUR
BUELL/ENVIROTECH
DOUBLE ALKALI
STARTUP 11/79
A CONTRACT HAS HbEN AWARDED HY CIPSCO TO BUELL/ENVIWOTECH fOH THE
INSTALLATION OF AN EMISSION CONTROL SYSTEM ON UNIT NO. 1. THfc KEY COM-
PONENTS OF THE EMISSION CONTROL bYSTE* INCLUDE: A HIGH-EFFICIENCY fcSPl
FOUR PRECOULERS. FOUR POLYSPHERE ABSURBERS, THREE THICKENERS, Two EX-
PERIMENTAL REHEAT SYSTEMS, AND THREE HORIZONTAL EXTRACTION FILTERS FOR
SLUDGE DEHATER1NG. APPHOX IMA TEL * «b PERCENT OF THE CONSTRUCTION WORK
AT THE PLANT HAS BEEN COMPLETED. THE FGU SYSTEM «ILL HAVE CEILCOTE-
LINEO ABSORBER MODULES.
CENTRAL MAINE POHER
SEARS ISLAND 1
600 MM - NEW
COAL SOURCE UNDETERMINED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 11/66
BECAUSE OF THE DISCOVERY OF A GEOLOGICAL FAULT ON SEARS ISLAND, THE
UTILITY HAS CANCELLED PLANS FOR A llbU-MW NUCLEAx POwER PLANT. A
600-MM COAL-FIRED UNIT IS NOW BEING PLANNED IN ITS PLACE. COMMERCIAL
OPERATION IS PROJECTED FOR NOVEMBER 1986. COMPLIANCE WITH 302 NSPS MILL
BE ACHIEVED BY INSTALLING AN FGD SYSTEM. LIME ANO LIMESTONE SCRUBBING
PROCESSES ARE BEING GIVEN PRIMARY CONSIDERATION. CURRENTLY, CMPCU HAS
FILED AN APPLICATION >vJTM THE STATE PUBLIC UTILITIES COMMISSION. AN EN-
VIRONMENTAL PERMIT APPLICATION HILL BE FRED WITHIN THE NEXT TWO YEARS.
CINCINNATI GAS t ELECTRIC
EAST BEND 2
600 MM - NEM
COAL
BABCOCK t WILCOX
LIME
STARTUP 1/81
A CONTRACT HAS BEEN CONDITIONALLY AWARDED (0 BIBCOCK AND WILCOX FOR A
COMMERCIAL LIME SCRUBBING SYSTEM. A COAL SOURCE MIS BEEN OBTAINED AND
HILL BE A MID-wESTERN COAL AND IS EXPECTED TO HAVE A HIGH SULFUR CONTENT.
THERE rilLL BE A DRY SLUDGE DISPOSAL. CONSTRUCTION PROBABLY MILL NOT
BEGIN UNTIL NEAR THE END OF 1976. COMMERCIAL START-UP DATE HAS BEEN
DELAYED ONE YEAR TO JANUARY 1901. THE A-E DESIGN FIRM IS SARGENT AND
LUNDY.
COLORADO UTE ELECTRIC ASSN.
CRAIG 1
450 MM - NEM
COAL 0.45 PERCENT SULFUR
PEABODY ENGINEERING
LIMESTONE
STARTUP 3/79
THE CONSTRUCTION OF THE LIMESTONE SLURRY SPRAY TOMER SCRUBBING SYSTEM
FOR SULFUR DIOXIDE REMOVAL FROM LOM-SULFUR COAL-FIRED BOILER FLUE GAS IS
NOW SOX COMPLETE. THE FOUNDATION IS COMPLETE AND THE SILOS ARE UP. PARTIC-
ULATE CONTROL WILL BE PROVIDED BY HOT-SIDE ESP'S UPSTREAM OF THE SCRUB-
BER PLANT. SLUDGE DISPOSAL is UNDECIDED. THERE WILL BE A STEAM COIL TYPE
STACK GAS REHEAT INCLUDED. REQUIRED PARUCULATE AND SULFUR DIOXIDE RE-
MOVAL EFFICIENCIES ARE 99.8 ANO 85 PERCENT, RESPECTIVELY. F6D SYSTEM _
START-UP IS SCHEDULED FOR SPRING 1979.
COLORADO UTE ELECTRIC ASSN.
CRAIG Z
450 MM - NEM
COAL 0.45 PERCENT SULFUR
PEABODY ENGINEERING
LIMESTONE
STARTUP 3/79
PEABUOY ENGINEERED SYSTEMS HAS BEEN AWARDED A CONTRACT TO DESIGN ANO
SUPPLY A LIMESTONE SLURRY SPRAY TOMER SCRUBBING SYSTEM FOR 302 REMOVAL
FROM LOM-SULFUR COAL-FIRED BOILER FLUE GAS FOR UNITS 1 AND 2. PARTICULATE
CONTROL WILL BE PROVIDED BY HOT-SIDE ESP'S UPSTREAM OF THE SCRUBBER
PLANT. SLUDGE MILL BE STABILIZED ANO HAULED TO A MINEFILL. THERE WILL BE
A STEAM COIL TYPE STACK GAS REHEATER INCLUDED. REQUIRED PARTICULATE AND
S02 REMOVAL EFFICIENCIES ARE 99.8 ANO 85 PERCENT, RESPECTIVELY. FGO
CONSTRUCTION IS NOW 30X COMPLETE.
COLUMBUS * SOUTHERN OHIO ELEC.
CONESVILLE 5
400 MM - NEM
COAL 4.5 - 4.9 PERCENT SULFUR
AIR CORRECTION DIVISION, UOP
LIME
STARTUP 1/77
REFER 10 SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION. THE
BOILER AND ESP MERE COMPLETED AND PLACED IN SERVICE IN SEPT. 1976.
THE B-SIDE MODULE BECAME AVAILABLE FOR SERVICE IN JANUARY 1977.
COMMERCIAL OPERATIONS WERE ACHIEVED ON FEBRUARY 13, 1977. THE EMISSION
CONTROL SYSTEM FUR THIS UNIT CONSISTS UF A COLD-SIDE ESP FOLLOMED BY
TWO TCA LIME SCRUBBING MODULES SUPPLIED BY UOP. DRAVO IS SUPPLYING THE
THIOSORBIC LIME SCRUBBING REAGENT. IUCS IS SUPPLYING THEIR POZ-0-TEC
SLUDGE STABILIZATION FACILITY.
COLUMHUS 8 SOUTHERN OHIO ELEC.
CONESVILLE 6
400 MM - NCM
COAL 4.5 - 4.9 PERCENT SULFUR
AIR CORRECIION DIVISION, UOP
i :ME
' '*RTUP 4/78
THE UTILITY SIGNED LUNG-TERM CONTRACTS WITH DRAVU FOR THE PURCHASE OF
THIOSORBIC LIME AND WITH lues FOR A SLUDGE FIXATION SYSTEM. CON-
STRUCTION OF THIS UNIT COMMENCED IN 1977 AND MAS COMPLETED IN JANUARY
1978. SIMILAR TO CONESVILLE NO.5, THIS MINE MOUTH PLANT BURNS COAL
WITH 17 PEnC.NT ASH CONTENT AND 4.5 TO 4.9 PERCENT SULFUR CONTENT.
THERE is AN ELECTROSTATIC PRECIPITATOR UPSTREAM OF THE FGD SYSTEM.
THE FGD SYSTEM INCLUDES TWO TCA MODULES FOR THE REMOVAL OF soz. THE A-E
DESIGN FIRM IS BLACK ANO VEATCH. THE UNIT BECAME OPERATIONAL IN JUNE 1978.
-------
EPA UTILITY FGD SURVEY: APRIL 1976 - MAT 1978
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
COLUMBUS ft SOUTHERN OHIO ELEC. THIS UNIT MILL BURN HIGH SULFUR OHIO CUAL (APPROXIMATELY 2.5 PERCENT
POSTON 5 SULFUR CONTENT). THE DESIGN OF THE EMISSION CONTROL STRATEGY HAS
375 MM - Nil NOT YET BEEN FINALIZED. THE PROCESS MILL EITHER BE LIME, LIMESTONE* OR
COAL 2.5 PERCENT SULFUR DOUBLE ALKALI.
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 0/83
COLUMBUS ft SOUTHERN OHIO ELEC. THIS UNIT "ILL BURN HIGH SULFUR COAL (APPROXIMATELY 2.5 PERCENT
POSTON 6 SULFUR CUNIENT). THE DESIGN OF THE EMISSION CONTROL STRATEGY
375 MW - NEM FOR THIS UNIT HAS NOT YET BEEN FINALIZED.
COAL 2.5 PERCENT SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 0/85
COMMONWEALTH EOISON
POMERTON 51
425 MM - RETROFIT
COAL 3.6 PERCENT SULFUR
AIR CORRECTION DIVISON, UUP
LIMESTONE
STARTUP 3/79
THE AIR CORRECTION DIVISION OF UOP MAS AWARDED THE CONTRACT FOR A MET
LIMESTONE SYSTEM THAT nILL BE BACKFIMED ONTO bOILER NO. 51. ONE OF TWO
IDENTICAL BOILtRS SUPPLYING STEAM TO AN t»50-Mw TURBINE-GENERATOR. THE
FGD SYSTEM IS DESIGNED TO TREAT FLUE GAS WHICH COMES FROM THE COMBUSTION
OF HIGH SULFUR CUAL (3.6 PERCENT SULFUR} 8.3 PERCENT ASH; 17.3 PERCENT
MOISTURE; 10,500 BTU/LB.) AND MEET 502 EMISSION STANDARDS OF 1.8 LB.
S02/MM BTU. CURRENTLY, EXCAVATION, BACKFILL, AND STRUCTURAL STEEL
ERECTION IS IN PROGRESS.
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
545 MW NEW
LIGNITE - 0.63 PERCENT SULFUR
COMBUSTION ENGINEERING
LIME
STARTUP 2/79
THIS UNIT IS UNDER THE COMBINED OWNERSHIP OF COOP POWER AND UNITED POMER.
THE CONTRACT FOR THIS SCRUBBING SYSTEM HAS BEEN AWARDED TO COMBUSTION
ENGINEERING FOR THE INSTALLATION OF LIME FGD SYSTEMS ON UNITS 1 AND 2
NOS. 1 ft 2 AT THIS STATION. THE SCRUBBING SYSTEM FOR EACH BOILER MILL
CONSIST OF FOUR SPRAY TOMER ABSORBER MODULES FOR 802 REMOVAL. ELECTRO-
STATIC PRECIPITATORS WILL BE INSTALLED UPSTREAM OF EACH SCRUBBING SYSTEM.
CONSTRUCTION BEGAN EARLY IN AUGUST 1977 AND THE UNIT IS NOW 70-75X COM-
PLETE. BAD WINTER WEATHER SLOWED CONSTRUCTION SLIGHTLY.
COOPERATIVE POWER ASSOCIATION THIS UNIT IS UNDER THE COMBINED OWNERSHIP OF COOP POWER AND UNITED POMER
COAL CREEK 2
545 MN - NEN
LIGNITE - 0.63 PERCENT SULFuR
COMBUSTION ENGINEERING
LIME
STARTUP li/79
THE CONTRACT FUR THIS SCRUBBING SYSTEM HAS BEEN AWARDED TO COMBUSTION
ENGINEERING FOR THE INSTALLATION OF LIME FGO SYSTEMS ON UNITS 1 AND 2
NOS. 1 » 2 AT THIS STATION. THE SCRUBBING SYSTEM FOR EACH BOILER MILL
CONSIST OF FOUR SPRAY TOMER ABSORBER MODULES FOR 302 REMOVAL. ELECTRO-
STATIC PRECIHITATORS WILL BE INSTALLED UPSTREAM OF EACH SCRUBBING SYSTEM.
CONSTRUCTION BEGAN IN AUGUST 1977 AND IS NOW QUX COMPLETE. THERE HAVE
BEEN MINOR DELAYS BUT START-UP IS STILL SCHEDULED FOR 11/79.
OELMARVA POMER ft LIGHT
DELMARE CITY 1, 2 ft 3
180 MM - RETROFIT
COKE 7-8 PERCENT SULFUR
DAVY POWERGAS
MELLMAN LORD
STARTUP 6/80
UELMARVA'S DELAWARE CITY PLANT HAS 0 BOILERS, 3 OF WHICH EACH HAVE STEAM
CAPACITIES OF bOUK LBS/HR. THE BOILERS GENERATE STEAM AS WELL AS ELECTRI-
CAL POWER FOR GETTY REFINING ft MARKETING. 7-8 X S COKE MILL BE BURNED IN
THE BOILERS (INSTEAD OF THE LOw-S CRUDE OIL NOW BURNED) MHEN THE CONTROL
SYSTEM GOES INTO OPERATION IN APRIL 1980. OELMARVA MILL USE VENTURI SCRUB-
BERS FOR PARTICULATE REMOVAL AND MELLMAN LORD FGD SYSTEMS AT EACH BOILER
GAS EXIT FOR S02 CONTROL. PARTICULATE AND SULFUR DIOXIDE REMOVAL EFFICIEN-
CIES ARE 90 AND 85-90 PERCENT RESPECTIVELY. CONSTRUCTION IS 6X COMPLETE.
DUOUESNE LIGHT REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
ELRAMA POMER STATION OPERATIONS ARE CONTINUING WITH THREE BOILERS COUPLED INTO THE FIVE-MODULE
510 MM - RETROFIT SCRUBBING SYSTEM. THE PLANT IS FIRING 1.8 - 2.2 PERCENT SULFUR COAL.
COAL l.B-2.2 PERCENT SULFUR SCRUBBING WASTES ARE CHEMICALLY FIXATED BY THE 1UCS SYSTEM AND LANOFILL-
CHEMICO ED. ESP'S AND MECHANICAL COLLECTORS ARE USED FOR PARTICULATE CONTROL.
LIME
STARTUP 10/7b
OUOUESNE LIGHT REFER 10 SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
PHILLIPS POMER STATION THIS SCRUBBING SYSTEM HAS BEEN IN SERVICE SINCE JULY 1973. ALL 6 BOILERS
4io MM - RETROUT *RE COUPLED INTO THE SCRUBBING SYSTEM. THE PLANT FIRES COAL MITH A HEAT-
COAL 1.8-2.2 PERCENT SULFUR ING VALUE OF 11,000 BTU/LB AND ASH AND SULFUR CONTENTS OF 21 PERCENT AND
CHEMICO 1.8 - i.Z PERCENT, RESPECTIVELY. DEMATERED SLUDGE FROM THE IUCS INTERIM
l-IME PROCESSING PLANT IS BEING HAULED TO AN OFF-SITE LANDFILL. THE SLUDGE
STARTUP 7/73 CONTAINS NU FIXATIVE.
-------
EPA UTILITY FGO SURVEY: APRIL I97a - MAT 1978
SECTION 2
STATUS OF FGU SYSTEMS
UNFT IDENTIFICATION
CURRENT STATUS
EASTERN KENTUCKY POWER COUP
SPURLOCK 2
500 MN - NErt
COAL
COMBUSTION ENGINEERING
LIME
STARTUP 3/80
THE SPURLUCK GENERATING PLANT IS LOCATED APHROXIMATELY 1 MILES BEST Of
MAYSVILLE, KENTUCKY. Tut) NE/t UNITS ARE SCHEDULED FOR THIS STATION. UNIT
NO. J B£G«N UPEWATION IN EA«LY StPT. UNIT 2 HILL BE CONTROLLED BY A 9<».5
PERCENT EFFICIENT ESP. THE UTILITY HAS COMPLETED SPECIFICATIONS FOR THE
SCRUBBING SYSTE*-'. MAKEUP rtATER "ILL COME FROM COOLING TOHER BLONDOnN. A
CONTRACT HAS BEE'J AWAROEU TO COMBUSTION ENGINEERENG TO SUPPLY A LIME
SYSTfcM.
GENERAL PUBLIC UTILITIES
COHO 1
800 MM - NEH
CO»U 3.5 PERCENT SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 5/87
STARTUP DATE CHANGED TO 5/87 FUR BOTH BOILER *ND DESULFURIZAT ION SYSTEM.
LIME AND LIMESTONE SCRUBBING ARE THE PRIMARY STRATEGIES BEIN6 CONSIDERED
FOR COMPLIANCE HlTM NEH SOURCE PERFORMANCE STANDARDS. NO DECISION MAS BEEN
MADE YfcT.
GENERAL PUBLIC UTILITIES
SEMARO 7
800 MH NEH
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 5/84
STARTUP DATE CHANGED TO 5/84 FOR BOTH BOILER AND DESULFURIZATION SYSTEM.
LIME AND LIMESTONE SCRUBBING ARE THE PRIMARY STRATEGIES BEING CONSIDERED
FOR COMPLIANCE WITH NEW SflURCF PERFORMANCE STANDARDS. NO DECISION HAS BEEN
MADE YfcT.
GULF POMER
CRIST 445
ISO MH - RETROFIT
VENDOR NOT SELECTED
PROCESS NOT SELECIEO
STARTUP O/ 0
EACH UNIT IS 75 MH. THE UTILITY IS STILL WAITING FOR A DECISION AN THE
EMISSION REGULATIONS THAT THEY HILL HAVE TO MEET.
6ULF POKER
CRIST b & 7
880 MN NEK
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 0/80
UNIT 6 TS 330 MH. UNIT 7 TS 500 MH. FGD MAY BE REQUIRED IN 1980.
NO DECISION HAS YET BEEN ANNOUNCED.
GULF POHER
LANSING SMITH i & z
305 MM - RETROFIT
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 0/80
UNIT NU. 1 IS 125 MH. UNIT NO. 2 IS 180 MH. THE UTILITY IS STILL HAITING
FOH A UECISION ON THE EMISSION REGULATIONS THAT THEY HILL HAVE TO MEET.
GULF POHER
SCHOLZ NOS. IB S 28
20 MH - RETROFIT
COAL 5.0 PERCENT SULFUR (MAX)
CHIYOOA INTERNATIONAL
LIMESTONE
STARTUP d/7tt
CHIYOOA INTERNATIONAL HILL BE SUPPLYING A 20 MN PROTOTYPE UNIT TO BEGIN
OPERATION AT THIS PLANT IN AUGUST 1978. THE CT-121 SYSTEM HILL INCLUDE A
NEHLY DEVELOPED JET BUBBLING REACTUR "HICH FEATURES A LARGE GAS-LIQUID
INTEKFAC1AL AREA AND PROVIDES PARTICULATE AS HELL AS S02 REMOVAL. MIST
ELIM1NAIION KILL HE PROVIDED BY A DOUBLE PASS VERTICAL CHEVRON. GYPSUM
nILL HE PRODUCED AND STACKED IN THE EXISTING POND. THE STACKING CAPABIL-
ITIES UF THE GYPSUM nILL BE TESTED ALONG WITH THE GROUND HATER NEAR
1HE STACK SITE. NO REHEAT HILL BE INCLUDED.
HOOSIER ENERGY
MEROM i
490 MH - NErf
CUAL 3.5 PERCENT SULFUR
MITSUBISHI INIERNAUONAL
LIMESTONE
STARTUP 12/80
HOUSIEh COUP HAS AHARDkO A CONTRACT TO MITSUBISHI INTERNATIONAL CORP. FOR
THO LIMESTUNt FGD SYSTEMS FOR MEKOM 1 AND 2. THE NEH 490 MH COAL-FIRED
UNITS ARK PLANNED FOR LOCATION IN SULLIVAN. INDIANA. THE FLUE GAS STREA' S
HlLl Ht CLEANED OF PARTICULATES HlTH ESP'S (99.41) AND OF SULFUR D10XI"
nITH GhlU-TOnEK ABSORBERS (90S). SLUDGE MILL BE STABILIZED AND STOCK
PILED. THF GROUND HAS BROKEN FOR CONSTRUCTION IN NOVEMBER 1977, BUT DUE
TO THE BAD HINTER HEATHER, CONSTRUCTION IS ONLY 5 PERCENT COMPLETE.
-------
EPA UTILITY FCO SURVEY: APRIL 1976 - MAT 197fl
UNIT IDENTIFICATION
SECTION 2
STATUS OF FGU SYSTEMS
CURRENT STATUS
HOOSIER ENERGY
MEROM 2
490 MM - NEM
COAL 3.5 PERCENT SULFUR
MITSUBISHI
LIMESTONE
STARTUP 10/81
HOOSIER COOP HAS AHARDEO » CONTRACT TU MITSUBISHI INTERNATIONAL COMP. FOR
TNU LIMESTONE F6U SVSTtMS FOR MEKOH 1 AND 2. THE NEK 490 Mw COAL-FIRED
UNITS ARE PLANNFU FOR LOCATlUN IN SULLIVAN, INUIANA. THE FLUE GAS STREAMS
MILL BE CLEANED OF PARTICIPATES WITH ESP'S (99.4X) AND OF SULFUR DIOXIDE
WITH GRIU-TOHER ABSUHBERS (9ox). SLUDGE HILL RE STABILIZED AND STOCK
PILED. THE GROUND MAS BROKEN FOR CONSTRUCTION IN NOVEMBER 1977, BUT DUE
10 THE BAD WINTER HEATHEN, CONSTRUCTION IS UNLY 5 PERCENT COMPLETE.
INDIANAPOLIS POnER & LIGHT
PETERSBURG J
530 MM - NEM
COAL 3.0-3.5 PERCENT SULFUK
UNIVERSAL OIL PRODUCTS
LIMESTONE
STARTUP 10/77
THt AlN CORRECTION DIVISION OF UOP SUPPLIED THt MET LIMESTONE SCRUBBING
SYSTtM AT THIS UNI I. THE UNIT BECAME OPERATIONAL ON DEC. 16,1977. AN ESP
PROVIDES PRIMARY PARTICULATE CONTROL. THE UNIT FIRES BITUMINOUS COAL MITH
A SULFUR CONTENT OF J.U-J.5X, AN ASH CONTENT OF 9-IOX, AND A HEAT CONTENT
OF 11,00V BTU/LB. AFTER BEING DOWN FOR PROBLEMS MITH THE FLY ASH SYSTEM,
THE UNIT CAME BACK ON LINE IN MID-APRIL. THE UNIT MENT BACK DOMN ON JUNE
16 MHEN THE MAIN POWER TRANSFORMER FAULTED.
INDIANAPOLIS POnER « LIGHT
PETERSBURG 4
530 MM - NEM
COAL 3.S PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP 4/82
INDIANAPOLIS PUMER » LIGHT AMAHDED A CONTRACT TO RESEARCH COTTRELL FOR A
LIMESTONE SCRUBBING SYSTEM. S02 REMOVAL EFFICIENCY MILL BE APPROXIMATELY
ao PERCENT. THIS NEM UNIT MILL FIRE HIGH-SULFUR SUBBITUMINOUS COAL MITH
A HEATING VALUE OF 11,1)00 BTu/LB AND ASH AND SULFUR CONTENTS OF 10
PERCENT AND 3.5 PERCENT, RESPECTIVELY. A CONTRACT HAS BEEN AWARDED TO
RESEARCH CUTTRELL FOR A LIMESTONE FGO SYSTEM. SLUDGE MILL BE OEMATERED
AND MIXED MITH FLYASH TO PRODUCE A DRY STABILIZED PRODUCT. PLANT CONSTRUC-
TION BEGAN IN DECEMBER 1977.
KANSAS CITY POWER ft LIGHT
HAMTHORN 3
140 MM - RETROFIT
COAL 0.5-3.5 PERCENT SULFUR
COMBUSTION ENGINEERING
LIME
STARTUP 11/72
REFER TO SECTION 3 OF THIS REPORT FOK ADDITIONAL INFORMATION.
THE SCRUBBER PLANT HAS BEEN CONVERTED FROM A LIMESTONE FURNACE INJECTION
AND TAIL-END SYSTEM TO A TAIL-END MET LIMF SYSTEM. LIME-BASED SCRUBBING
COMMENCED ON FEBRUARY 7, 1977. COMPLIANCE TESTING FOR KANSAS CITY PARTIC-
ULATE STANDARDS INDICATED THE NO.3 UNIT MAS NELL WITHIN THE 0.17 POUND
REGULATION. THE 2-MODULE SCRUBBER PLANT CAN ONLY BE BY-PASSED DURING
EMERGENCIES.
KANSAS CITY PONER » LIGHT
HAMTHORN 4
100 MM - RETROFIT
COAL 0.5-3.5 PERCENT SULFUR
COMBUSTION ENGINEERING
LIME
STARTUP 8/72
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE SCRUBBER PLANT HAS BEEN CONVERTED FROM A LIMESTONE FURNACE INJECTION
AND TAIL-END SYSTEM TO A TAIL-END MET LIME SYSTEM. OPERATION IN THE LIME
SCRUBBING MODE COMMENCED ON JANUARY 1, 1977. COMPLIANCE TESTING FOR KANSAS
CITY PARTICULATE REGULATIONS INDICATED THE UNIT is MEETING THE 0.17 POUND
REGULATION. THE 2-MOOULE SCRUBBER PLANT CAN ONLY BE BY-PASSED DURING
EMERGENCIES.
KANSAS CITY POWER * LIGHT
LA CVGNE 1
820 MM - NEM
COAL 5.0 PERCENT SULFUR
BABCOCK ft MILCOl
LIMESTONE
STARTUP 2/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS NEM COAL-FIRED POWER-GENERATING UNIT
CONSISTS OF EIGHT SCRUBBER MODULES FOR FLY ASH AND 302 REMOVAL. EACH
MODULE INCLUDES A VENTuRI SCRUBBER IN SERIES MITH A 2-STAGE IMPINGEMENT
PLATE ABSORBER. THE SCRUBBER PLANT IS AN INTEGRAL PART OF THE POMER-
GENERATING COMPLEX, ALLOWING NO FLUE GAS BYPASS. INITIAL OPERATIONS
COMMENCED IN FEB. 1973. COMMERCIAL SERVICE MAS ATTAINED BY JUNE 1973.
KANSAS POMFR ft LIGHT
JEFFEREY 1
680 MM - NED
COAL 0.30 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE
STARTUP 6/78
HAS PURCHASED A CUMBUSTION FNGINFERTNG AIR QUALITY CONTROL SYSTEM
FOR PARTICULATE AND S02 REMOVAL CONSISTING OF A COLD-SIDE ESP, 1.0. FANS.
BY-PASS CAPABILITY, AND SPRAY TOMERS. AN OVERFIRE AIR SYSTEM AT THE TAN-
GENTIAL FIRED PULVERIZED BURNERS MRL CONTROL NOX EMISSIONS. THE CLEANED
GASES WILL BE VENTED TU A 600 FT STACK. THE BOILER IS NOW OPERATIONAL AND
CONSTRUCTION UN THE FGD SYSTEM IS 991 COMPLETE. THE SCRUBBER SHOULD BE
ON LINE BY MID-JULY. SLUDGE DISPOSAL STRATEGY HAS NOT BEEN FINALIZED.
THIS UNIT WILL FIRE u.jx SULFUR ut ASH) WYOMING COAL.
KANSAS POWER ft LIGHT
JEFFEREY 2
680 MM - NEM
COAL 0.30 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE
STARTUP 6/80
KPftL HAS PURCHASED A COMBUSTION ENGINEERING AIR UUALITY CONTROL SYSTEM
FOR PARTICULATE ANU S02 REMOVAL CONSISTING UF A COLD-SIDE ESP, I.D. FANS,
BY-PASS CAPABILITY, AND SPRAY TOMERS. AN OVERFIRE AIR SYSTEM AT THE TAN-
GENTIAL FINED PULVERIZED BURNERS HILL CONTROL NOX EMISSIONS. THE CLEANED
GASES WILL BE VENTED TU A 600 FT STACK. CONSTRUCTION IS PROCEEDING ACCORD-
ING TO SCHEDULE. THE ESP'S ARE BEING INSTALLED. THE SLURRY HOLD TANKS AND
ABSORBERS ARE IN PLACE. SLUDGE DISPOSAL STRATEGY HAS NOT BEFN FINALIZED.
THIS UNIT HILL FIRE 0.11 SULFUR C6X ASH) NYOMING COAL.
10
-------
EPA UTILITY FGD SUHVfct: APH1L 1476 - MAY 1476
SECTION 2
STATUS OF FGl) STSTtMS
UNIT IDENTIFICATION
CURRENT STATUS
KANSAS POKER t LIGHT
LAWRENCE 4
135 MW - RETROFIT
COAL 0.5 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE
STARTUP 12/66
REFER TO SECTION 3 OF THIS REPOHT FOK ADDITIONAL INFORMATION.
THE NEh LIMESTONE FGD SYSTEM COVKENCEO OPERATIONS IN EAHLY JANUAKY 1977.
THE NEn SYSTEM REPLACED MAWBLE-BEP TOWERS *ITH SPRAY TOWELS. THERE N»VE
BEEN NO FORCED SCRUBBER OUTAGES REPORTED SIHCE START-UP. CONTINUOUS SOi
MONITORS HAVE RECORDED S02 REMOVAL kFFICIANCIES OF BETTER THAN 6SZ.
PARTICULATE REMOVAL IS RtPORTEO TO OE EXCELLENT, YIELDING NO VISIBLE
PLUME. THE PLANT IS FIRING COAL RATED AT 10,000 BTU/LB MTH A SULFUR
CONTENT OF O.SX.
KANSAS POWFR a LIGHT
LAWRENCE 5
400 MM - NEM
COAL O.S PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE
STARTUP 11/71
RFFFH TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMAT KiN. THF
ORIGINAL LIMESTONE INJECTION AND TAIL-END SCRUBBING SYSTEM HAS SHUT
DOnN ON MARCH 30 30 THAT THE NEK ROD-SCRUBBER AND SPRAY TOntH ABSORBER
SYSTtM COULD BE TIED INTO THE UNIT. THE NEK SYSTEM, WHICH INCLUDES TwO
MODULES, EACH CAPABLE OF HANDLING APPROXIMATELY 50 PERCENT OF THE TOTAL
BOILER FLUE GAS FLOW, CAME ON LINE ON APRIL 14, 1976. THE SYSTEM DESIGNER
AND SUPPLIER IS COMBUSTION ENGINEERING. THE UNIT FIRES LOft SULFUR WYOMING
COAL WITH A HEAT CONTENT OF 10,QUO BTU/LB.
KENTUCKY UTILITIES
GREEN RIVER 1,2 & 3
64 MM - RETROFIT
COAL 3.6 PERCENT SULFUR
AMERICAN AIR FILTER
LIME
STARTUP 9/75
LAKELAND UTILITIES
MCINTOSH 3
350 MM - NEM
COAL 2.6 PERCENT SULFUR
BABCOCK ft WILCOX
LIMESTONE
STARTUP 10/81
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 S03 (MOBILE
-BED CUNTACTUR) FRUM COAL-FIRED BOILER FLUE GAS. THE SCRUBBER MAS DESIGNED
AND SUPPLIED BY AAF. SLUDGE IS DISPOSED IN AN ON-SITE UNLINEO POND. THE
COAL BURNED HAS SULFUR AND ASH CONTENTS OF 3.6 AND 1« PERCENT RESPEC-
TIVELY. INITIAL STARTUP UCCUKRED IN SEPTEMBER 1975. COMMERCIAL OPERATION
COMMENCED IN JANUARY 1976.
THE CITY OF LAKELAND DEPARTMENT OF ELECTRIC AND WATER UTILITIES AWARDED A
CONTRACT TO B»w FON AN EMISSION CONTROL SYSTEM ON THE UTILITY'S NEW
350-MM POWER GENERATING UNIT, MCINTOSH 3. THE UNIT WILL UTILIZE COLD
SIDE ESP'S FOR PARTICULATE REMOVAL AND A LIMESTONE FGD SYSTEM. START-UP IS
SCHEDULED FOR OCTOBER 1981. A COAL SOURCE HAS NOT BEEN FINALIZED. CONSTRUC
TION SHOULD BEGIN IN SEPTEMBER 1978.
LOUISVILLE GAS » ELECTRIC
CANE RUN 4
178 MW - RETROFIT
COAL 3.5 - 4.0 PERCENT SULFUR
AMERICAN AIR FILTER
LIME
STARTUP 8/76
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE FGD SYSTEM RETROFITTED ON THIS BOILER MAS DESIGNED AND SUPPLIED BY
AMERICAN AIR FILTER AND MAS FIRST PLACED IN THE GAS PATH ON AUGUST 7,
1976. THE SYSTEM CONSISTS OF TWO PARALLEL MODULES WHICH INCLUDE MOBILE
BED CONTACTORS AND OPERATE WITH A CARBIDE LIME ADDITIVE. FOLLOWING A
NUMBER OF MAJOR SYSTEM MODIFICATIONS (CHEVRON-TYPE MIST ELIMINATOR, OIL
FIRED REHEAT, PLASITE DUCT LINER, HIGHER L/G), THE SYSTEM SUCCESSFULLY
PASSED COMPLIANCE TESTING (85X SU2 REMOVAL) ON AUGUST 3 AND 4, 1977.
LOUISVILLE GAS * ELECTRIC
CANE RUN S
183 MM - RETROFIT
COAL 3.5 - 4.0 PERCENT SULFUR
COMBUSTION ENGINEERING
LIME
STARTUP 12/77
REFER TO SECTION ^ OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE FGD SYSTEM FOR THIS UNIT HAS DESIGNED AND SUPPLIED BY COMBUSTION
ENGINEERING. IT CONSISTS OF TWO SPRAY TOMER ABSORBERS FOR FULL-LOAD 302
REMOVAL AND UTILIZES CARBIDE LIME AS THE SCRUBBING REAGENT. IN-LINE STEAM
REHEAT, A COMMUN REACTION TANK, AND A THICKENER FOR SOLIDS DEKATERING
ARE INCLUDED. AN EXISTING UPSTREAM ESP PROVIDES PRIMARY PARTICULATE CON-
TROL. THE FGD SYSTEM BEGAN INITIAL OPERATION IN DEC. '77 BUT THE COAL
STRIKE FORCED A PLANT SHUTDOWN. THE SYSTEM MAS RE-STARTED MARCH it, 1978.
LOUISVILLE GAS 1 ELECTRIC
CANE RUN 6
277 MM - RETROFIT
COAL 3.5 - 4.U PERCENT SULFUR
AOL/COMBUSTION EQUIP ASSOCIATE
DOUBLE ALKALI
STARTUP 12/76
LOUISVILLE GAS * ELECTRIC
MILL CREEK 1
330 MH - RETROFIT
COAL 3.5- 4.0 PERCENT SULFUR
VENDOR NOT SELECTED
THE CONTRACT FOR THIS FULL-SCALE DEMONSTRATION FGD SYSTEM HAS BEEN
AWARDED TO A.0.LITTLE/COMBUSTION EQUIPMENT ASSOC. FOR THE INSTALLATION
OF A DOUBLE ALKALI SYSTEM. THE FEDERAL EPA HILL SUBSIDIZE A MAXIMUM
S4.5 MM FOR OPERATION, RESEARCH AND DEVELOPMENT, AND REPORT WRITING FOR
A ONE-YEAR PERIOD FOLLOWING THE FIRST THREE MONTHS OF OPERATION (NOTEITHIS
SUBSIDY WILL NOT BE APPLIED FOR ANY CAPITAL EXPENDITURES). ENGINEERING
DESIGN MURK IS UNDERWAY. SITE PREPARATION, EXCAVATION AND FOUNDATION WORK
COMMENCED IN JULY. DUCTWORK TIE-IN IS COMPLETE.
A COMPLIANCE SCHEDULE HAS BEEN SUBMITTED TO THE JEFFERSON COUNTY AIR POL-
LUTION CONTROL DISTRICT WITH 1/82 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 HUN MILL BE OBTAINED BEFORE
THE UTILITY PROCEEDS WITH ADDITIONAL SYSTEM DESIGN HORK.
S.'-RTUP 1/82
11
-------
EPA UTILITY FSO SURVEY: APRIL 1976 - MAY 1978
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
LOUISVILLE GAS & ELECTRIC A COMPLUNCF SCHEDULE HAS BEtN SUBMITTED TO THE JEFFERSON COUNTY AIR POL-
MILL CREEK 2 LUTION CONTROL DISTRICT HITH 1/61 ESTABLISHED AS THE STARTUP DATE FOR AN
330 MM - RETROFIT FGD SYSTEM. OPERATING DATA ANU INFORMATION FROM THE FULL-SCALE SCRUBBER
COAL 3.5- 4.0 PERCENT SULFUR PLANT NOn IN SERVICE ON THE NO.a UNIT AT CANE RUN NILL BE OBTAINED BEFORE
VENDOR NOT SELECTED THt UTILITY PROCEEDS HITH ADDITIONAL SYSTEM DESIGN WORK.
LIME
STARTUP 1/61
LOUISVILLE GAS ft ELECTRIC BECAUSE PONER DEMAND HAS NOT COME UP AS RAPIDLY AS HAD BEEN EXPECTED,
MILL CREEK 3 UNIT SHUT-UP HAS BEEN MOVED BACK TO LATE JULY 1976. CONSTRUCTION ON
425 MM - NEW THIS NEH FACILITY'S F6U SYSTEM IS NEARING COMPLETION. THE SYSTEM IS DE-
COAL 3.5- 4.0 PERCENT SULFUR SIGNED AND SUPPLIED BY AMERICAN AIM FILTER AND MILL UTILIZE CARBIDE LIME
AMERICAN AIR FILTER AS THE ABSORBENT. FOUR MOBILE-BED ABSORBERS HILL TREAT THE FLUE GAS RE-
LIME SULTING FROM THE COMBUSTION OF HIGH SULFUR CUAL. THE SYSTEM HILL OPERATE
STARTUP 7/76 IN A CLOSED HATEH LOOP. THE SCRUBBING HASTE nILL BE STABILIZED WITH
FLYASH AND LIME.
LOUISVILLE GAS & ELECTRIC BECAUSE POHEH DEMAND HAS NOT COME UP AS RAPIDLY AS HAD BEEN EXPECTED,
MILL CREEK 4 UNIT S1AKT-UP HAS BEEN MOVED BACK TO JUNE I960. CONSTRUCTION OF THIS NEM
495 MM - NEM 495-MN CUAL-FIREO UNIT IS ON SCHEDULE. CURRENTLY. FOUNDATION MORK IS IN
COAL 3.5- 4.0 PERCENT SULFUR PROGRESS. THIS AAF SYSTEM MILL INCLUDE MOBILE-BED ABSORBERS TREATING
AMERICAN AIR FILTER HIGH SULFUR COAL FLUE GAS. THE SYSTEMS HATER LOOP NILL BE CLOSED. THE
LIME SLUDGE MILL BE STABILIZED HITH LIME AND FLYASH. STEAM REHEAT HILL PRO-
STARTUP 6/80 VIDE GAS TEMPERATURE ELEVATION OF THE SCRUBBED GASES PRIOR TO DISCHARGE
TO THE MAIN STACK.
LOUISVILLE GAS ft ELECTRIC
PADDYS RUN b
65 MM - RETROFIT
COAL 3.5 - 4.0 PERCENT SULFUR
COMBUSTION ENGINEERING
LIME
STARTUP 4/73
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS SCRUBBING SYSTEM HAS DESIGNED BY COMBUSTION ENGINEERING AND PLACED
IN SERVICE IN APRIL 1973. THE FGO SYSTEM CONSISTS OF TnO 2-STAGE MARBLE
BED ABSORBERS MHICH ARt DESIGNED TO USE CARBIDE LIME ADDITIVE AS THE
SCRUBBING REAGENT. PADDYS RUN NO. 6 IS A PEAK-LOAD UNIT THAT OPERATES
ONLY OUriING DEMAND PERIODS. AN EXTENSIVE EPA SCRUBBER/SLUDGE EVALUATION
STUDY HAS COMPLETED IN AUGUST 1977. THIS UNIT HILL BE RETIRED HHEN MILL
CREEK 3 COMES ON LINE.
MINNESOTA POMER » LIGHT
CLAY BOSMELL 4
500 MM - NEM
COAL 0.6 PERCENT SULFUR
PEABODY ENGINEERING
LIME/ALKALINE FLVASH
STARTUP 5/6U
MINNESOTA P ft L HAS AMARDEO A CONTRACT TO PEABODY ENGINEERING FOR A LIME/
ALKALINE FLYASH SCRUBBING SYSTEM. THE CONFIGURATION MILL BE VENTURI
SCRUBBERS FOLLOHEO BY SPRAY TOMERS. HOT SIDE ESP'S NILL BE USED FOR
PARTICULATE CONTROL. STACK GAS REHEAT BILL BE ACCOMPLISHED BY BYPASSING
5X OF FLUE GAS AROUND THE SCRUBBER. THE UNIT HILL FIRE SUB-BITUMINOUS
COLSTHIP COAL HITH A SULFUR CONTENT OF 0.8X, AND AN ASH CONTENT OF 9.OX
(HEATING VALUE - 6300 UTU/LB). MAKE-UP HATER SOURCE HILL BE THE RIVER AND
THE CLAY-LINED PUNO. CONSTRUCTION OF STRUCTURAL STEEL BEGAN APRIL It 1978.
MINNKOTA POHER COOPERATIVE REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
MILTON R. YOUNG z THIS LIME/ALKALINE FLVASH SCRUBBING SYSTEM HAS DESIGNED AND SUPPLIED BY
450 MM - NEM ADL/COMBUSTION EQUIPMENT ASSOCIATES. IT CONSISTS OF A COLO-SIDE ESP
LIGNITE 0.7 PERCENT SULFUR FOLLOMEO BY THO SPRAY TOnERS. MIST ELIMINATION IS PROVIDED BY A HASH
ADL/COMBUSTION EQUIP ASSOCIATE TRAY AND CHEVRON MIST ELIMINATOR. 15X FLUE GAS BYPASS PROVIDES STACK GAS
REHEAT. THE UNIT FIRES A LON-SULFUR NORTH DAKOTA LIGNITE HITH AN AVERAGE
ASH CONTENT OF A PERCENT, SULFUR CONTENT OF 0.7 PERCENT, AND HEAT CONTENT
OF 6500 BTU/LB. THE FLY ASH ALKALINITY IS USED AS THE PRIMARY 302 REAGENT.
LIME/ALKALINE FLYASH
STARTUP 9/77
MONTANA PONER REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
COLSTRIP i THIS FGD EQUIPPED UNIT HAS DECLARED COMMERCIAL IN NOVEMBER 1975. THE
360 MM - NEM SCRUBBING SYSTEM PROVIDES PARTICULATE AND 302 CONTROL HITH THREE SCRUB-
COAL 0.8 PERCENT SULFUR BEN MODULES. EACH MODULE CONSISTS OF A DUMNFLOH VENTURI SCRUBBER CENTER-
AOL/COMBUSTION EQUIP ASSOCIATE ED H1THIN AN UPFLOii SPRAY TOMER ABSORBER. EACH MODULE CAN TREAT 40X OF
LIME/ALKALINE FLYASH THE TOTAL BOILER FLUE GAS AND THE MODULES CANNOT BE BYPASSED. THE UN-
STARTUP 11/75 STABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED DISPOSAL POND. IN-LINE
STEAM REHEAT AND CLOSED MATER LOOP CAPABILITY ARE INCLUDED IN THE SYSTEM.
MONTANA PONER
COLSTRIP i
360 MM - NEN
COAL 0.8 PF.RCENT SULFUR
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THIS FGO EQUIPPED UNIT MAS DECLARED COMMERCIAL IN AUGUST 1976. THE
SCRUBBING SYSTEM PROVIDES PARTICULATE AND 302 CONTROL NITH THREE SCRUB-
BER MODULES. EACH MODULE CONSISTS OF A OOHNFLOH VENTURI SCRUBBER CENTER-
AOL/COMBUSTION EQUIP ASSOCIATE ED MlTHlN AN UPFLOM SPRAY TONER ABSORBER. EACH MODULE CAN TREAT 40X OF
LIME/ALKALINE FLYASH THE TOTAL BOILER FLUE GAS AND THE MODULES CANNOT BE BYPASSED. THE UN-
STABILIZED SLUDGt IS DISPOSED IN AN ON-SITE LINED DISPOSAL POND. IN-LINE
STEAH REHEAT AND CLOSED HATER LOOP CAPABILITY ARE INCLUDED IN THE SYSTEM.
STARTUP 67/60
12
-------
EPA UTILITY FGD SURVEY: APRIL 1S78 - MAT 1978
UNIT IDENTIFICATION
SECTION i.
STATUS OF FGU SYSTEMS
CURRENT STATUS
MONTANA POMER A CflNThACT FUR THE I NS T ALI. A I I ON OF TMM ADDITIONAL L IME / ALK AL I NE FLYASM
COLSTRIP 3 SCRUBBING bYSTEMb MAS BEEN ArtAWDfcO TO A.D. LITTLE/COMBUSTION EQUIPMENT
700 MM - NEM ASSOCIATES. THESE SYSTEMS WILL BE INSTALLED ON U*ITS NOS. 3 AND 4 OF
COAL 0.7 PERCENT SULFUR 1 HE COLSIWIP FUftEW STATION. COLSIRIP UNITS 1 AND Z ARE BOTH EQUIPPED
ADL/COMBUSTION EQUIP ASSOCIATE r. I IH OPFKATIONAL LIME/AL*AL1NE FL'ASH SCRUBBING SYSTEMS FOR THE REMOVAL
LIME/ALKALINE FLYASH
STARTUP 7/8U
OF PARTICIPATES AND bULFUR OIOXIUE.
MONTANA POMER
COLSTRIP 4
700 MM - NEM
COAL 0.7 PERCENT SULFUR
A CONTRACT FUR THE INSTALLATION UF TrtO AuDITIUNAL LIMt/ALKALI ME FLYASH
SCRUBBING SYSTEMS MAS BEEN AnAXDEO TO A.U. L 1 TTLt/COMBUST I UN EQUIPMENT
ASSOCIATES. THfcSt SYSTEMS KILL 8E INSTALLED UN UMTS NOS. 3 AND 0 OF
THE COLSTRIP PUMER STATIUN. CULSTRIP UNITS 1 AND i. ARE BOTH EQUIPPED
ADL/COMBUSTJON EQUIP ASSOCIATE MlTH OPERATIONAL L IME / ALK AL INE FLYASH SCRUBBING SYSTEMS FOR THE REMOVAL
LIME/ALKALINE FLYASH UF PARTKIILAIES AND SULFUR DIOXIDE.
STARTUP 7/81
NEVADA POWER
HARRY ALLEN 1
SOO MM - NEW
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP b/83
CONSIDERING HflT bIDE ESP IN CONJUNCTION WITH AN F60 SYSTEM. SPECIFICA-
TIONS HAVfc NUT YET BEEN PREPARED.
NEVADA PONER
HARRY ALLEN 8
SOO MW - Nfcrt
COAL
VENDOR NOT SELECTED
PROCESS NUT SELECTED
STARTUP 6/84
CUNS10ERl'
-------
EP* UTILITY F6D SURVEY: APRIL 1978 - MAY 1978
SECTIUN £
STATUS OF FGl) SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
NEVADA POMER
REFER TO SECTION 3 OF THIS REPORT FOH ADDITIONAL INFORMATION.
THIS UNIT IS A Nt* COAL-FIRED BOILER THAI IS EUUIPPEU nITH SUDIUM
CAHHONATt-BASFU(TRUN»)SCRimHINb SYSTEM HHICH INCORPORATES A TnIN
VAMIABLE-THRUAT vtHTUHl SC-VIIBBfW FULLOwFU BY A SEPARATOR IN SERIES WITH
ADL/COMBUSTION EQUIP ASSOCIATE A S INGLF.-S T AGt PERFOKATEU-PL»Tt *ASM TuwER. MECHANICAL COLLECTORS PROVIDE
SODIUM CARBONATE PRIMARY PAKTICUL ATE. CONtHOL. R£Ht»I IS PKUVIDEU 01 AN INDIRECT STEAM HOT
AIR REHEAT SYSTEM. WASTE DISPOSAL IS ON-SlTE CLAY-LINED POND.
DIRECT HUT MB HEHEAT SYSTEM. HASTE DISPOSAL IS UN-SITE CLAY-LINED POND.
REID GARDNER 3
125 MB - NEM
COAL 0.5 -1.0 PERCENT SULFUR
STARTUP 7/7b
NEVADA POMER
REID GARDNER a
125 MM - NEM
COAL 0-5- 1.0 PERCENT SULFUR
ADL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
STARTUP O/ U
NEVADA PUWEW COMPANY HAS SIGNED A LETTER OF INTENT WITH COMBUSTION EQUIP-
MENT ASSOCIATES FOR THE CONSTRUCTIUN OF AN FGD SYSTEM ON REID GARDNER NO.
«. CONSTMIJCT10N OF THE HOILFHt HUMEVER. H»S BEEN INDEFINITELY POSTPONED.
NEVADA POMFR
NARNER VALLEY 1
250 MM - NEM
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 6/62
SPECIFICATIONS AKE BEING PREPARED FOH A SCRUBBING SYSTEM. NEVADA POMER
HAS NO! YET ANNOUNCED PLANS FOR THIS UNIT'S EMISSION CONTROL STRATEGY.
NEVADA POMER
MARNER VALLEY 2
250 MM - NEM
COAL
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 6/83
SPECIFICATIONS AWE BEING PREPARED FOR A SCRUBBING SYSTEM. NEVADA POMER
HAS NOT YET ANNOUNCED PLANS FOR THIS UNIT'S EMISSION CONTROL STRATEGY.
NEM ENGLAND ELEC SYSTEM
BRAYTON POINT 3
650 MM - RETROFIT
FUEL OILr LOM SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP O/ 0
THE UTILITY IS CURRENTLY INVESTIGATING VARIOUS ADVANCED REGENERABLE
FLUE GAS DESULFUKIZATION 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. THE NO. 3 UNIT IS CURRENTLY
UPERATIONAL. FIRING LOM SULFUR FUEL UTL.
NIAGARA MQHAHK POMER COOP
CHARLES R. HUNTLEY b
100 MM - RETROFIT
COAL 2.5-4.5 PERCENT SULFUR
ATOMICS INTERNATIONAL
AQUEOUS CARBONATE
STARTUP 0/8U
A CONTRACT MAS AWARDED TO ATOMICS INTERNATIONAL FOR THE DESIGN AND IN-
STALLATION OF AN AUUEOUS CARBONATE FGD SYSTEM. THIS DEMONSTRATION SYSTEM
MILL PRODUCE END-PRODUCT SULFUR. FUNDS AKE BEING PROVIDED BY THE us EPA
ANU THE EMPIKE ST»IE ELECTRIC ENERGY RESEARCH CORP. THE DESIGN 302 RE-
MOVAL EFFICIENCY MILL BE 90 PERCENT. GROUND BREAKING FUR CONSTRUCTION HILL
BE IN LATE FALL 1978.
NORTHERN INDIANA PUB SERVICE
BAILLY 7
190 MM - RETROFIT
COAL 3 PERCENT SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP O/ 0
NORTHERN INDIANA PUBLIC SERVICE IS CURRENTLY CONSIDERING A LIME UR LIME-
STONE SCRUBBING UNIT FUR BAILLY 7 ANU 0. THEY ARE ALSO WAITING FOR
PERFORMANCE KESULTS OF THE MELLMAN LORD/ALLIED CHEMICAL UNIT IN SERVICE
AT DEAN H. MITCHELL 11. LUH SULFUR COAL MAY BE EMPLOYED TO COMPLY WITH
S02 EMISSION RtGULATIONS. APPLICABLE INDIANA SU2 REGULATIONS ARE STILL NOT
FIRMLY ESTABLISHED.
NORTHERN INDIANA PUB SERVICE
BAILLY 8
000 MM - RETROFIT
COAL 3 PERCENT SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP O/ 0
NORTHERN INDIANA PUBLIC SIRVICE IS CURRENTLY CONSIDERING A LIME OR LIME-
STONE SCRUBBING UNIT FUR BAILLY 7 AND 0. THEY ARE ALSO NAMING FOR
PERFORMANCE RESULTS OF THE WELLMAN LORD/ALLIED CHEMICAL UNIT IN SERVICE
AT DEAN H. MITCHELL 11. LON SULFUR CJ»L MAY BE EMPLOYED TO COMPLY KITH
so2 EMISSION REGULATIONS. APPLICABLE INDIANA 302 REGULATIONS ARE STILL NOT
FIRMLY ESTABLISHED.
-------
EPA UTILITY Fto SURVEY: APRIL 1978 - MAY i9?a
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
COMMENT STATUS
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
us MM - RETROFIT
CO*L 3.2-3.5 PERCENT SULFUR
OAVT POwERGAS/ALLIED CHEMICAL
WELLMAN LORD/ALLIED CHEMICAL
STARTUP 11/76
REFER TO SECTION 3 OF THIS RfcPORT F0« ADDITIONAL INFORMATION.
THIS FbD SYSTEM IS AN INTEGRATION OF THE rELLMAN-LORO 802 RECOVERY PROCESS
OFFERED BY DAVY POnERGAS AND THE S02 TO SULFUR REDUCTION PROCESS DE-
VELOPED UY ALLIED CHEMICAL. DAVY PUWERGAS is THE DESIGN AND CONSTRUCTION
FIRM AND ALLIED CHEMICAL is SYSTEM OPERATOR AND PRODUCT MARKETER.
PERFORMANCE TESTS WERE SUCCESSFULLY COMPLETED ON SEPTEMBER II, 1977. A
DEMONSTRATION YFAR COMMENCED ON SEPTEMBER 16, 1977.
NORTHERN STATES POWER
SHERBURNE 1
710 MM - NEW
COAL 0.6 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYAbH
STARTUP 3/76
REFER TO SECTION 1 OF THIS REPORT FOR ADDITIONAL INFORMATION.
FULL COMMERCIAL OPERATION OF THE SYSTEM BEGAN ON MAY 1. 19/b. THE SCRUB-
BING SYSTEM FOR THIS UNIT CONSISTS OF 12 MODULES. EACH SCRUBBING MODULE
INCORPORATES A VENTURI-ROD SECTION AND A MARBLE BED ABSORBER FOR PAR-
TICULA1E AND SULFUR DIOXIDE REMOVAL. A FORCED OXIDATION SYSUM CONVERTS
ALL THE CALCIUM SULF1TE TO SULFATE PRIOR TO DISCHARGE TO A CL»Y-LINED
SETTLING POND. STACK GAS REHEAT IS PROVIDED BY IN-LINE HUT HATER TUBES.
NORTHERN STATES PO/IER
SHERBURNE z
710 MM - NEW
COAL 0.8 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLY ASH
STARTUP a/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE SHERBURNE NU. 2 AIM UUALITY CONTROL SYSTEM IS IDENTICAL IN DESIGN TO
THE SYSTEM IN OPERATION ON THE NO. 1 UNIT AT THIS STATION. TWELVE 2-STAGE
PARTKULATE SCRUBBER (VENTURI-ROD SCRUBBER) AND SULFUR OIOIIDE ABSORBER
(MARBLE-BED ABSORBER) MODULES ARE PROVIDED FOR FLY ASH ANO 302 CONTROL.
ELEVEN MODULES ARE REQUIRED FOR FULL GENERATING CAPACITY OPERATIONS.
THE CALCIUM SULF1TE IS FORCIBLY OUDIZED TO SULFATE PRIOR TO DISCHARGE TO
THE DISPOSAL POND. STACK GAS REHEAT PROVIDED BY IN-LINE HOT nATER TUBES.
NORTHERN STATES POWER
SHERBURNE 3
S60 MW - NEW
COAL 0.0 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLY ASH
STARTUP 5/81
NORTHERN STATES POWER
SHERBURNE 4
860 MW - NEW
COAL 0.8 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLY ASH
STARTUP 5/83
OTTER TAIL POWER
COYOTE 1
400 MM - NEW
LIGNITE 0.9 PERCENT SULFUR
NHEELABRATOR-FRYE/A.I.
AQUEOUS CARBONATE
STARTUP 5/81
TWO ADDITIONAL COAL-FIRED POwER-GENEHATING UNITS ARE SCHEDULED TO BE IN-
STALLED AT NSP's SHERBURNE COUNTY GENERATING STATION IN BECKER MINNESOTA.
COMBUSTION ENGINEERING WAS AWARDED A CONTRACT FOR LIMESTONE SLURRY SPRAY
TOnER FGO SYSTEMS ON THE 860 Mn UNITS 3 & 4. THE 2- STAGE SCRUBBING SYSTEM
HILL REMOVE PARTKULATE (99.51) ft S02 (SOX). THE BOILER CONTRACT HAS BEEN
AWARDED TO BABCOCK AND WILCOX AND THE TURBINE HILL BE SUPPLIED BY GENERAL
ELECTRIC. CONSTRUCTION IS SCHEDULED TO COMMENCE DURING THE SUMMER OF '78.
COMMERCIAL START-UP DATES ARE NOW SCHEDULED FOR MAY 1981 ANO MAY 1983.
TNO ADDITIONAL COAL-FIRED POWER-GENERATING UNITS ARE SCHEDULED TO BE IN-
STALLED AT NSP'S SHERBURNE COUNTY GFNERATING STATION IN BECKER MINNESOTA.
COMBUSTION ENGINEERING WAS AWARDED A CONTRACT FOR LIMESTONE SLURRY SPRAY
TOwER FGU SYSTEMS ON THE 860 Mw UNITS 3 ft 4. THE 2-STAGE SCRUBBING SYSTEM
WILL REMOVE PARTICULATE (49.51) » 502 (BOX). THE BOILER CONTRACT HAS BEEN
ARE NOW SCHEDULED FOR MAY 1981 AND MAY 1983. THE BOILER CONTRACT HAS BEEN
AWARDED TO BABCOCK AND HlLCOX AND THE TURBINE "ILL BE SUPPLIED BY GENERAL
ELECTRIC.
THIS NEW COAL-FINED STATION IS JOINTLY OWNED BY FIVE UTILITIES. OTTER
TAIL PUWER is THE MAJOR OWNER AND CONSTRUCTOR. MONTANA-DAKOTA UTILITIES
IS THE FACILITY OPERATOR. THIS PLANNED UNIT WILL FIRE LOW SULFUR LIGNITE
FROM THE MERCER COUNTY AREA IN A B&W CYCLONE BOILER. THE CONTRACT
FOR THIS AQUEOUS CARBONATE/FABRIC FILTER SU2 SCRUBBER WAS AWARDED TO
WHEELABRATOR-FRYE AND ATOMICS INTERNATIONAL. THE DRY REMOVAL SYSTEM COM-
BINES AI'S AQUEOUS CARBONATE PROCESS IN A W-F FABRIC FILTER. PLANT CON-
STRUCTION BEGAN SEPT. 77. START-UP IS SET FUR MAY 81.
PACIFIC GAS ANO ELECTRIC
FOSSIL 1
800 MW - NEW
COAL 0.8 PERCENT SULFUR
VENDOR NOT SELECTED
LIMESTONE
STARTUP 0/84
PGftE ANNOUNCED PLANS TO BUILU TWO 800-Mh COAL-FIRED POWER GENERATING
UNITS IN NORTHERN CALIFORNIA. THE FIRST UNIT WILL BURN COAL WITH A HEAT-
ING VALUE OF 12000 BTU/LB, O.SX SULFUR AND 10X ASH CONTENTS. THE SECOND
UNIT WILL BURN COAL OF EUUAL OR BETTER QUALITY. THE EMISSION CONTROL
SYSTEM WILL CONSIST OF AN ESP OR BAGHOUSE AND A LIMESTONE FGD SYSTEM.
SLUDGE WILL BE DISPOSED OF IN A LANDFILL. START-UP DATES ARE 1984 AND 1985
FOR NOS. 1 ANO 2 RESPECTIVELY.
PACIFIC GAS ANO ELECTRIC
FOSSIL 2
800 MW - NEW
COAL 0.8 PERCENT SULFUR
VENDOR NOT SELECTED
LIMESTONE
STARTUP 0/85
PGftE ANNOUNCED PLANS TU BUILD Two ttOU-MW COAu-FIRED POWER GENERATING
UNITS IN NORTHERN CALIFORNIA. THE FIRST UNIT WILL BURN COAL WITH A HEAT-
ING VALUE OF 12000 BTU/LB, O.SX SULFUR AND 1UX ASH CONTENTS. THE SECOND
UNIT WILL BURN COAL OF EQUAL OR BETTER QUALITY. THE EMISSION CONTROL
SYSTEM WILL CONSIST OF AN ESP OR BAGHOuSE AND A LIMESTONE FGD SYSTEM.
SLUDGE WILL BE DISPOSED OF IN A LANDFILL. START-UP DATES ARE 1984 AND 1985
FOR NOS. 1 AND i RESPECTIVELY.
15
-------
EPA UTILITY F6D SURVEY! APRIL 1976 - MAY 1978
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
PACIFIC PO"ER * LIGHT
JIM BRIDGES 4
509 MM - NEN
COAL 0.56 PERCENT SULFUK(AVG.)
AIR CORRECTION DIVISION, UOP
SODIUM CARBONATE
STARTUP 9/79
THE AIR CORRECTION DIVISION OF UOP MAS AWARDED A CONTRACT FOR AN FGD
SYSTEM AT 1H1S NEM-509 Mn COAL-FIREO UNIT. THE FGO SYSTEM MILL CONSIST OF
PARALLEL TKAY TOnER ABSORBER MODULES, EACH TREATING ONE-THIRD OF THE
BOILER FLUE GAS AT FULL LOAD. AN ESP HILL PROVIDE PRIMARY PARTICULATE
CONTROL. A CEILCOTE-LINEO NET/DRY STACK IS INCLUDED IN THE SYSTEM. PPL'3
PILOT STUDY INSPECTION REVEALED SCALE FORMATION PROBLEMS. TESTS ARE BEING
CONDUCTED TO RESOLVE THIS PROBLEM. TU DATE, THE FOUNDATION IS IN AND
VESSEL ERECTION IS 22 PERCENT COMPLETE.
PENNSYLVANIA POHER
BRUCE MANSFIELD 1
625 MM - NEW
COAL 4.7 PERCENT SULFUR
CHEMICO
LIME
STARTUP 4/76
REFER 10 SECTION 3 OF THIS REPORT FOR ADOITONAL INFORMATION.
THIS EMISSION CONTROL SYSTEM HAS DESIGNED TO REMOVE FLYASH AND 302 FROM
3.35 MM ACFM OF FLUE GAS 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 MAS CERTIFIED FULL-LOAD COMMERCIAL IN JUNE 1976.
THE FGD SYSTEM HAS EXPERIENCED OPERATIONAL PROBLEMS SINCE IT HAS BEEN IN
SERVICE REQUIRING A NUMBER OF SYSTEM REPAIRS AND DESIGN MODIFICATINS.
PENNSYLVANIA PONER
BRUCE MANSFIELD 2
825 MM - NEN
COAL 4.7 PERCENT SULFUR
CHEMICO
LIME
STARTUP 7/77
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
1HIS EMISSION CONTROL SYSTEM nAS DESIGNED TO REMOVE FLYASH AND 302 FROM
3.35 MM ACFM OF FLUE GAS USING THIOSORBIC LIME AS A SCRUBBING ABSORBENT.
SIX SCRUBBING TRAINS, EACH INCLUDING TMO VENTUNI SCRUBBERS IN SERIES
ARRANGEMENT, ARE PROVIDED FOR FULL-LOAD OPERATION. THE INITIAL SHAKEDONN
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 POKER
BRUCE MANSFIELD 3
625 MM - NEN
COAL «.7 PERCENT SULFUR
PULLMAN KELLOGG
LINE
STARTUP 4/80
THE PULLMAN KELLOGG DIVISION OF PULLMAN INCORPORATED HAS BEEN AHAROEO
A CONTRACT FOR THE INSTALLATION OF AN FGD SYSTEM. THE EMISSION CONTROL
SYSTEM FOR THIS UNIT HILL CONSIST OF ESP'S UPSTREAM OF FIVE MEIR HORIZON-
TAL CRUSSFLOft MET SCRUBBING MODULES. CONSTRUCTION OF THE BOILER IS
CURRENTLY IN PROGRESS. UNIT START-UP MILL BE IN APRIL I960.
PHILADELPHIA ELECTRIC
CROMBY
150 MM - RETROFIT
COAL 2-4 PERCENT SULFUR
UNITED ENGINEERS / PECO
MAGNESIUM OXIDE
STARTUP 6/80
THE UTILITY PLANS TO RETROFIT ONE OF THE TMO BOILERS AT CROMBV MITH AN
FGO SYSTEM. HOHEVER, A FINAL DECISION HAS NOT BEEN MADE. THE SYSTEM
BEING GIVEN PRIMARY CONSIDERATION IS MAGNESIUM OXIDE. ENGINEERING DESIGN
MORK IS SCHEDULED TO COMMENCE SOON. TENTATIVE FGD SYSTEM START-UP IS
SCHEDULED FOR JUNE I960. CURRENTLY, PECO IS CONTINUING PROCESS EVALUATION
STUDIES AT THE EOOYSTONE EXPERIMENTAL UNIT.
PHILADELPHIA ELECTRIC
EDDYSTONE 1A
120 MM - RETROFIT
COAL 2.5 PERCENT SULFUR
UNITED ENGINEERS / PECO
MAGNESIUM OXIDE
STARTUP 9/75
REFER TO SECTION < OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION 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 SU2 ABSORBER MODULE IN SERIES
MITH 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 NEMARK, N.J.
THE REGENERATED MAGOX IS RETURNED TO THE PLANT FOR S02 SCRUBBING SERVICE.
PHILADELPHIA ELECTRIC
EODYSTONE IB
240 MM - RETROFIT
COAL 2.5 PERCENT SULFUR
UNITED ENGINEERS / PECO
MAGNESIUM UXIOE
STARTUP b/8U
THE INSTALLATION OF AN FGD SYSTEM ON THE BALANCE OF THE FLUE GAS FROM
THIS UNIT WILL FOLLOH PENDING THE OUTCOME OF THE PERFORMANCE OF THE EXPER-
IMENTAL SCRUBBING UNIT MHICH HAS BEEN INSTALLED AND CURRENTLY OPERATIONAL
ON THlb UNIT. CURRENTLY. 3 PARTICULATE SCRUBBERS ARE TREATING THE FULL
GAS LOAD FROM THIS UNIT.
PHILADELPHIA ELECTRIC
EOOYSTONE 2
336 MM - RETROFIT
COAL 2.4 PERCENT SULFUR
UNITED ENGINEERS / PECO
MAGNESIUM OXIDE
STARTUP 6/60
THE UTILITY IS AMAIUNb PERFORMANCE RESULTS FROM THE EXPERIMENTAL FGD
SVSTtM INSTALLED ON UNIT l AT THIS STATION BEFORE PROCEEDING MITH THE
DESIGN OF AN FGO SYSTEM FOR THIS COAL-FIRED BOILER. THE SYSTEM BEING
GIVEN PRIMARY CONSIDERATION IS MAGNESIUM OXIDE, DESIGNED JOINTLY BY
UNITED ENGINEERS AND PHILADELPHIA ELECTRIC. ENGINEERING DESIGN DORK IS
SCHEDULED TO COMMENCE SOON. TENTATIVE FGO SYSTEM START-UP IS SCHEDULED
FOR JUNE 1980.
16
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tP* UTILITY FGU SORVEY: APRIL 1978 - MAT 1978
sect ION i
STATUS UF FGU SYSTEMS
UNIT IDENTIFICATION
CUHWtNT STATUS
POTOMAC FLECTRTC PD«FR
OICKERSON a
800 MM - NEW
CO»L 2.0 PERCENT SULFUR
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 5/85
THFRF- ARF NO F|KM PIANS F lift INSTAIlATTnN OF AN FUD SYSTFu. STARTUP UATF
OF THF HUlLt* IS PLANNtO FOR 148b. THIS UNIT BILL HURN I PERCENT SULFUR
COM fllTM A nEATIMj VALUE OF 11.000
PONER AUTHORITY OF NEW YORK
ARTHUR KILL PLANT
700 MM - NEM
COAL - sx SULFUR - KEFUSE
VENDOR NOT SELECTED
PROCESS NUT SELECTED
STARTUP ll/8a
THt UTILITY IS CONSIDERING HUTH HFbFNFRAHLF AND LlMESTONF FGD PROCESSES.
F(-n TEL-lNOl.UbY I b HE 1Mb CONSIDERED FUR A FOSSIL FUEL BURNING UNIT WHICH
«ILL i-t-PLUY COAL Ab TMt PRIMARY MIEI. »NU OIL AS BACKUP. REFUSE WILL BE
PRUVlUtO AS A SUPPLFMFNTAL FUEL SUPPLY. THt PREFERRED PLANT SITE IS TH£
ARTHUR KILL FACILITY LOCATED ON STATEN ISLAND. THE PROJECT DESIGN ENGI-
NEERING FIRM IS 3AHGENT ANI) LU'
-------
EPA UTILITY FGO SURVEY: APRIL I97e - HAY 1978
SEC1ION 2
STATUS OF FGU SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
SALT RIVER PROJECT
CORONADO 2
350 MW - NEW
COAL 1.0 PERCENT SULFUH (MA»)
PULLMAN KELLOGG
LIMESTONE
STARTUP 0/80
THIS NbH UNIT HILL BURN LUM SULFUR MESTEHN COAL. A MAXIMUM OF BOX OF THE
FLUE GAS WILL BE SCRUBBED TU MEET SULFUH DIOXIDE EMISSION REGULATIONS.
PULLMAN/KfILOGG WILL PROVIDE 2 WEIR HORIZONTAL SPRAY TOHEH5 UTILIZING
LIMESTONE SLURRY FOR Su
-------
EP« UTILITY FGO SURVEY: APRIL 1978 - MAY 1978
SECTION I
STATUS OF FGO S'STEMS
UNIT IDENTIFICATION
Cl'KREM STATUS
SOUTHERN MISSISSIPPI ELECTRIC
R. o. MORROW i
180 MW - NEH
COAL 1.0 PERCENT SULFUR
RILEY STOKER / ENVIRONEERING
LIMESTONE
STARTUP 8/76
CONSTRUCTION OK THE r«ET LIMESTONt SCRUBBING SYSTEM IS 90 PtHCENT CUM-
PLkTE. PAR1ICULATE WILL BE CONTROLLED BY A HIGH-EFFICIENCY ESP UPSTREAM
OF THE SCRUBBING SYSTEM. DESIGN SULFUR DIUXlUt »ND PAHTICULATE RE^JVAL
EFFICIENCIES AWE 8b ANO 99.6 PERCENT, KESPECTIVtL*. A WA1ER SPRAY HAS
BEEN ADDED IN THE BY-PASS DUCT TU PHU'ECI IHE LINER FKUM TEMPERATURE
EXCURSION. SCRUBBER SLUDGE MLL Bt S1»HlLlZtU WITH FLYASn AND DISPOSED ON
THE PLANT SITE.
SOUTHERN MISSISSIPPI ELECTRIC
R. 0. MORROW i
160 MW - NEW
COAL 1.0 PERCENT SULFUR
RILEY STOKER / ENVIRONEER1NG
LIMESTONE
STARTUP 10/78
CONSTRUCTION Of THE nET LIMESTONE SCWUHhING SYSTEM IS NEAR1NG COMPLE-
TION. PARTICULARS HILL BE CONTROLLED BY * HIGH-EFFICIENCY ESP UPSTREAM
OF THE SCRUBBING SYSTEM. DESIGN SULFUR DIOXIDE AND PARTICULAR REMOVAL
EFFICIENCIES ARE 85 ANU 99.6 PERCENT, RESPECTIVELY. A WATER SPRAY HAS
BEEN ADDED IN IHE BY-PASS DUCT To PROTECT THE LINER FROM TEMPERATURE
EXCURSION. SCRUBBER SLUDGE MILL BE STABILIZED "I'M FLYASH AND DISPOSED ON
THE PLANT SITE.
SOUTHWESTERN ELECTRIC POWER
HENRY W. PERKEY 1
780 MM - NEM
LIGNITE
AIR CORRECTION DIVISION, UOP
LIMESTONE
STARTUP 6/83
A CONTRACT FOR THE EMISSION CONTROL SYSTEM HAS BEEN ANARUED TO THE AIR
CORREC1ION DIVISION OF UOP. THE UNIT nILL INCLUDE TMO COLD-SIDE ESP'S
FOR PARTICULATE REMOVAL AND A SPRAY TOwER STRATEGY UTILIZING A LIMESTONE
SLURRY FOR S02 CONTROL. START-UP IS EXPECTED BY JUNE 1983.
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
200 MH - NEW
COAL 3.5 PERCENT SULFUR
AIR CORRECTION DIVISION, UOP
LIMESTONE
STARTUP a/77
SPRINGFIELD WATER LIGHT X PnR
DALLMAN 3
190 MW - NEW
COAL 3.0-0.3 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP 7/80
REFER TO SECTION 3 OF THIS REPORT FOR ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS NEM COAL-FIRED UNIT CONSISTS OF A
FOUR-FIELD HIGH EFFICIENCY ESP (99.6X DESIGN) ANO Z TURBULENT CONTACT AB-
SORBER MODULES (80Z DESIGN) FOR THE CONTROL OF PARTICULATES AND 302. BOTH
THE ESP AND LIMESTONE FGD SYSTEM ARE SUPPLIED BY UOP. THE SCRUBBING
WASTES ARE DEWATEREO 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.
A CONTRACT HAS BEEN AWARDED TO RESEARCH COTTRELL FOR THE INSTALLATION OF
A LIMESTONE FGD SYSTEM. REQUIRED SULFUR DIOXIDE REMOVAL EFFICIENCY
IS 90 PERCENT. A SLUDGE DISPOSAL STRATEGY HAS NOT SEEN FINALIZED, BUT
THE UTILITY IS CONSIDERING EITHER PONDING OR LANDFILL. CONSTRUCTION OF
THE FGD SYSTEM SHOULD COMMENCE IN LATE 1978. FGD START-UP IS SCHEDULED
FOR JULY 1980. BOILER OPERATION IS SCHEDULED TO COMMENCE IN JUNE 1978.
ST. JOE MINERALS CORP.
G. F. NEATON 1
60 MH - RETROFIT
COAL 3.0 PERCENT SULFUR
BUREAU OF MINES
CITRATE
STARTUP 10/76
CONSTRUCTION CONTINUES ON THE CITRATE PROCESS SCRUBBING SYSTEM WHICH
WILL CONTROL 502 EMISSIONS FROM A 60-MH COAL-FIRED POWER GENERATING
UNIT AT ST. JOE MINERALS. THIS UNIT PROVIDES POWER FOR THE LOCAL UTILITY
GRID. FGD SYSTEM START-UP IS SCHEDULED FOR OCTOBER 1978. THE REGENERABLE
FGD SYSTEM WILL PRODUCE ELEMENTAL SULFUR AS A BY-PRODUCT.
TENNESSEE VALLEY AUTHORITY
SHAHNEE 10A
10 MW - RETROFIT
COAL 2.9 PERCENT SULFUR
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
STARTUP a/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 1978. 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 WHITER.
DURING THE REPORT PERIOD, OPERATIONS WERE CONCUCTED WITH MGO ADDITION TO
BOTH LIME AND LIMESTONE SLURRY CIRCULATING THROUGH THt UNIT.
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10B
10 MW - RETROFIT
COAL 2.9 PERCENT SULFUR
CHEMICO
LIME/LIMESTONE
STARTUP a/72
REFER 10 THE BACKGROUND INFORMATION IN SECTION 3 OF THIS REPURT. THIS
VENTURI/SPWAY TOwER LIME/LIMESTONE SCRUBBING SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL 1972. IH13 TEST PROGRAM IS FUNDED BY THE EPA WITH TVA AS THE
CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTtL CORP. OF SAN FRANCISCO IS
THE MAJOK CONTRACTOR, TEST DIRECTOR, AND REPORT WRITER. DURING THE REPORT
PERIOD, FORCED OXIDATION WAS EVALUATED ON FLY ASH-FREE FLUE GAS WITH
LIME AND LIMESTONE SLURRY AS THE SCRUBBING ACENT.
19
-------
EPA UTILITY F60 SURVEY: APRIL 1978 - MAY 1978
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
575 MN - RETROFIT
COAL 3.7 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE
STARTUP O/ 0
TENNESSEE VALLEY AUTHORITY ANNOUNCED THAT A CONTRACT HAS BEEN AWARDED TO
COMBUSTION ENGINEERING FOR A LIMESTONE SLURRY SPRAY TONER F6D SYSTEM. THE
FGO SYSTEM HILL TREAT HIGH SULFUR COAL FLUE GAS. THE SPRAY TOMER ABSORBERS
HILL BE CONSTRUCTED OF 3I7L STAINLESS STEEL. THE NO. 7 UNIT FIRES COAL
nlTH THE SAME CHARACTERISTICS AS THE COAL FIRED IN THE NO. 8 UNIT.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 8
550 MW - RETROFIT
COAL 3.7 PERCENT SULFUR
TENNESSEE VALLEY AUTHORITY
LIMESTONE
STARTUP 5/77
REFER 10 SECTION 3 OF THIS REPORT FOK ADDITIONAL INFORMATION.
THE EMISSION CONTROL SYSTEM FOR THIS 550-MN 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 b»S FRUM UNIT NO. 8. EACH TRAIN INCLUDES A RECTANGULAR^
THHOAT VENTUHI SCRUBBER AND A GRID-TONER ABSORBER SUPPLIED BY POLYGON.
THE GRID TUNER CAN BE CONVERTED TO A MOBILE-BED TOWER IF GREATER 302 RE-
MOVAL is REQUIRED.
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
400 MN - NEW
LIGNITE - 1.Ob PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE
STARTUP 1/82
COMBUSTION ENGINEERING HAS AWARDED A CONTRACT TO DESIGN AND SUPPLY
A 400-MW LIGNITE-FIRED BOILER. ESP. AND FGO SYSTEM AT GIBBONS CREEK
STEAM ELECTRIC STATION UNIT NO. 1. THE BOILER NILL BURN 1.06X SULFUR
LIGNITE. FLUE GAS nILL BE CLEANED OF PARTICULARS BY A COLD-SIDE ESP
(99.73X EFFICIENCY). SU2 WILL BE REMOVED BY 3 SPRAY TONER MODULES UTILIZ-
ING A LIMESTONE SLURRY (72.5 TU 87.5X EFFICIENCY). A CONTRACT HAS BEEN
AWARDED TO lues FOR SLUDGE DISPOSAL. COMMERCIAL START-UP HAS BEEN SET FOR
JANUARY 1982.
TEXAS POWEB » LIGHT
SANDON o
5«5 MW - NEW
LIGNITE
COMBUSTION ENGINEERING
LIMESTONE
STARTUP 7/80
COMBUSTION ENGINEERING HAS BEEN CHOSEN AS THE BOILER AND FGD VENDOR FOR
THIS UNIT. BOILER CONSTRUCTION BEGAN ON SEPTEMBER 9. 1977. PART1CULATE
REMOVAL EQUIPMENT WILL BE LOCATED ON THE COLD-SIDE OF THE AIR HEATER.
SOME PORTION OF FLUE GAS WILL BYPASS THE SCRUBBER FOR REHEAT. THE SPENT
SLURRY WILL BE PONDED AND HATE* RECYCLED. FGO CONSTRUCTION IS SCHEDULED
TO BEGIN NOVEMBER 1978.
TEXAS POWER i LIGHT
TNIN OAKS 1
750 MM - NEN
LIGNITE
VENDOR NOT SELECTED
LIMESTONE
STARTUP 8/83
THIS UNIT WILL BE JOINTLY OWNED BY TP&L AND ALCOA. A FIRM DECISION HAS
NOT BEEN MADE WHETHER TO INSTALL FGO FACILITIES. THIS IS PRIMARILY
DUE TO THE FACT THAT SUCH A DECISION IS NOT YET REQUIRED IN THE
UTILITIES PLANNING TIMETABLE.
TEXAS POWER t LIGHT
THIN OAKS 2
750 MN - NEN
LIGNITE
VENDOR NOT SELECTED
LIMESTONE
STARTUP 9/80
THIS UNIT WILL BE JOINTLY OWNED BY TP»L AND ALCOA. A FIRM DECISION HAS
NOT BEEN MADE WHETHER TO INSTALL FGO FACILITIES. THIS IS PRIMARILY
DUE TO THE FACT THAT SUCH A DECISION IS NOT YET REQUIRED IN THE
UTILITIES PLANNING TIMETABLE.
TEXAS UTILITIES
FOREST GROVE 1
750 MN - NEK
LIGNITE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
STARTUP 0/81
TEXAS UTILITIES REPORTED THAT A NEN 750-MN LIGNITE-FIRED UNIT IS IN
THE EARLY PLANNING STAGE FOR THE FOREST GROVE STATION IN ATHENS, TEXAS.
START-UP IS SCHEDULED FOR LATE 1981. THE BOILER NlLL BE SUPPLIED
BY THE BABCOCK t NILCOX COMPANY.
TEXAS UTILITIES
MARTIN LAKE 1
793 MN - NED
COAL 1.0 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP 8/77
THIS NEN 793-Mw POWER
o.9X SULFUR IAVG) ANU
UNIT HAS BEEN EQUIPPED
COLO-SIDE ESP'S ANU A
TRELL. THE FGD SYSTEM
TREAT 75* OF THE TOTAL
FOR REHEAT. TOTAL S02
WASTES AME STABILIZED
GENERATING UNIT FIRES TEXAS LIGNITE WHICH CONTAINS
8.OX ASH (AVG). IN ORDER TO MEET FEDERAL NSPS THE
WITH AN EMISSION CONTROL SYSTEM WHICH INCLUDES
LIMESTONE FGD SYSTEM BOTH SUPPLIED BY RESEARCH-COT-
CONSISTS OF 6 PACKED/SPRAY TONER ABSORBERS NHICH
BOILER FLUE GAS. THE REMAINING FLUE GAS IS BYPASSED
REMOVAL EFFICIENCY IS 70.5X. THE FLUE GAS CLEANING
AND DISPOSED IN AN ON-SITE, LINED POND.
20
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EPA UTILITY FGO SURVEY: APRIL 1976 - MAY 1978
SECIION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
CURRENT STATUS
TEXAS UTILITIES
MARTIN LAKE 2
793 MW - NEW
COAL 1.0 PERCENT SULFUR
RESEARCH COTTRELl
LIMESTONE
STARTUP 5/78
TEXAS UTILITIES
MARTIN LAKE 3
793 MM - NEW
COAL 1.0 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP 12/76
TEXAS UTILITIES
MARTIN LAKE «
793 MM - NEM
COAL 1.0 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE
STARTUP
THIS NEW 793-Mn POwER GENERATING UNII FINES TEXAS LIGNITE CONTAINING
0.9X SULFUR IAVG.) AND BX ASH (AVG.). TO MEET FEDERAL NSPS, THE UNIT WILL
BE EUHIPPEO isITH AN E*ISSIU'J CONTROL SYSTEM CONSISTING OF COLD-SIDE ESP'S
AMU A LIMESTONE FGI) SYSTEM, BOTH SUPPLIED BY RESEARCH-COTTRELL. THt FGO
bYSTtM CONSISTS UF b PACKED/SPRAY TOwER ABSORBERS WHICH WILL TREAT 75* OF
THE TOTAL BOILER FLUt UAS. THE REMAINING GAS WILL HE BYPASSED FOR REHEAT.
T01AL DESIGN S02 REMOVAL EFFICIENCY IS 70.bX. 1H£ FLUE GAS CLEANING WASTES
WILL HE STAB1LI7ED AND DISPOSED IN AN ON-SITE, LINED POND.
THIS NE* 793-Mn POwE* GENERATING UNIT «ILL FIRE TE«AS LIGNITE CONTAINING
o.9x SULFUR (AVG.) ANU R* ASM IAVG.). TO MEET FEDERAL NSPS, THE UNIT WILL
BE EQUIPPED rtlTH AN EMISSION CONTROL SYSTEM CONSISTING OF COLD-SIDE ESP'S
AND A LIMESTONE FGU SYSTEM, BOTH SUPPLIED BY RESEARCH-COTTRELL. THE FGD
SYSTEM CONSISTS UF 6 PACKED/SPRAY TOwER ABSORBERS WHICH nILL TREAT 75X OF
THE TUTAL BOILER FLUE GAS. THE REMAINING GAS WILL BE BYPASSED FOR REHEAT.
TOTAL DESIGN S02 REMOVAL EFFICIENCY IS 70.5*. THE FLUE GAS CLEANING WASTES
WILL HE STABILIZED AND DISPOSED IN AN ON-SIfE, LINED PQND.
THE CONTRACT FOR THIS FGD SYSTEM HAS BEEN AWARDED TO RESEARCH-COTTHELL.
THE BOILER IS NOW BEING ERECTED. START-UP IS SCHEDULED FOR THE FOURTH
OUARTKK UF 198,?.
TEXAS UTILITIES
MONTICELLO 3
750 MM - NEW
LIGNITE 1.5 PERCENT SULFUH
CHEMICO
LIMESTONE
STARTUP 5/76
UTAH POWER « LIGHT
EMERY 1
000 MM - NEW
COAL 0.5 PERCENT SULFUR
CHEMICO
LIME
STARTUP 12/78
UTAH POWER ft LIGHT
HUNTINGTON 1
ai5 M* - NEW
COAL O.S PERCENT SULFUR
CHEMICO
LIME
STARTUP 5/78
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A HIGH EFFICIENCY
tSP ANU A LIMESTONE FGD SYSTEM. IHE ESP IPOLLUTION CONTROL-WALTHER) IS
PROVIDED FUR PRIMARY PARTICULATE CONIROL C99.56X). THE FGO SYSTEM CONSISTS
OF LIMESTONE SCRUBBING SPRAY TOWERS (CHEMICO) AND WILL PROVIDE PRIMARY
302 CONTROL (7«X). THE FGO SYSTEM IS DESIGNED TO TREAT APPROXIMATELY 3MM
SCFM UF FLUE GAS RESULTING FROM COAL MTH 1.51 SULFUR, 18.SI ASH AND
U.O«X LL. IHE FLUE GAS CLEANING WASTES WILL bE STABILIZED AND DISPUSED IN
AN ON-SITE, LINED POND. FULL LOAD OPERATIONS ARE EXPECTED IN AUGUST '78.
A CONTRACT HAS BEEN AWARDED TO THE CHEMICO AIR POLLUTION DIVISION FOR
A PEBBLE LIME WEI SCRUBBING SYSTEM 0«4 THIS NEW UNIT. THE SCRUBBING
SYSTEM IS DESIGNED TO OPERATE IN AN OPEN NAUR LOOP MODE "ITH AN SU2
REMOVAL EFFICIENCY OF 60 PERCENT FOR LOW SULFUR UTAH COAL. PRIMARY
PARTICULATE CONTROL WILL BE PROVIDED BY AN ESP UPSTREAM OF THE SCRUBBERS.
THE SCRUBBER SLUDGE WILL BE STABILIZED WITH FLYASH AND DISPOSED UN THE
PLANT SITE. THE A-E DESIGN FIRM FOR THIS PROJECT IS STEARNS-ROGER.
CONSTRUCTION IS NOW APPRO*IMA 1 ELY 65X COMPLETE AT THIS UNIT.
A CONTRACT WAS AWARDED TO CHEMICO AIR POLLUTION DIVISION FOR A LIME
SCRUBBING SYSTEM ON THIS NEW UNIT. THE STATE OF UTAH REGULATIONS REQUIRE
THE BEST AVAILABLE AND MOST COST EFFECTIVE TECHNOLOGY FOR SULFUR DIOXIDE
REMOVAL. PRIMARY PARTICULATE REMOVAL WILL BE PROVIDED BY AN ESP INSTALLED
UPSTREAM OF THE wET SCRUBBING SYSTEM. CONSTRUCTION IS COMPLETE AND INITIAL
OPERATIONS BEGAN ON MAY 10, 1976. COMMERCIAL OPERATION IS EXPECTED TO
BEGIN IN JULY, 1978.
VIRGINIA ELECTRIC * POWER
MT. STORM
1107 MW - RETROFIT
COAL
VENDOR NOT SELECTED-
PROCESS NOT SELECTED
STARTUP O/ 0
THE UTILITY IS CURRENTLY WAITING FOR AN EPA DECISION REGARDING A WEST
VIRGINIA STATE EMISSION CONTROL PROPOSAL. PLANS FOR SULFUR DIOXIDE
CONTROL ARE TEMPORARILY AT A STANDSTILL PENDING THIS DECISION. NO CON-
STRUCTION UR STARTUP DATES HAVE BEEN ESTABLISHED.
WISCONSIN POWER a LIGHT
COLUMBIA 2
527 MM - NEW
COAL 0.8 PERCENT SULFUR
CHEMICO
LIME/ALKALINE FLYASH
STARTUP 1/80
A CONTRACT WILL SOON Bb AWARDED TO CHEMI-U FOR A LIME/FLYASH FGD SYS-
TEM. IT WILL CONSIST OF TWO SPRAY MODULES WITH A HOT-SIDE ESP FOR PAR-
TICULATE REMOVAL. A CLOSED LOOP «AT£R SYSTEM IS ANTICIPATED WITH FLYASH
STABILIZATION OF THE SLUDGE. A SLUDGE DISPOSAL POND LOCATED OFF-SITE IS
HEING CONSIDERED. THE FGD SYSTEM IS BEING DESIGNED TO TREAT 60X OF THE
FLUE GAS RESULIING FROM THE COMBUSTION OF LOW SULFUR COLSTRIP COAL. THE
Rt-MAINING 40X WILL BE BYPASSED FOR REHEAT. CURRENTLY, THE UTILITY IS
MAKING TESTS TO STUDY ALTERNATE S02 COMPLIANCE STRATEGIES.
21
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EPA UTILITY FGO SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
UTILITY NAME AHIIONA PUBLIC SERVICE
UNIT NAME CHOLLA 1
UNIT LOCATION JOSEPH CUT ARI/ONA
UNIT RATING 115 MN
FUEL CHARACTERISTICS COAL 0.44-1 PERCENT SULFUN
FGD VENDOR RESEARCH COITRELL
PROCESS LIMESTONE
NEM OR RETROFIT RETHOFI1
START UP DATE 10/73
EFFICIENCY:
PARTICIPATES (ACTUAL) 99.7 PERCENT
(DESIGN) 99.7 PERCENT
S02 (ACTUAL) 50-60 PERCENT
(DESIGN) 58.5 PERCENT
MATER MAKE UP OPEN LOOP 1.04 GPM/Mh
SLUDGE DISPOSAL EXISTING FLY ASH POND
OPERATING EXPERIENCE UPDATE:
RELIABILITY (X)
MONTH MODULE A MODULE B COMMENTS
JAN. 78 97 91 THE FLOODED DISC SCRUBBER TANK HEADER FOR SLURRY LIMESTONE MAS
REPAIRED AFTER BEING DAMAGED DURING THE OVERHAUL. THE BOILER
MAS OPERATED ONLY 135 HRS. DURING JANUARY AS THE OVERHAUL HAD
EXTENDED INTO THIS MONTH. THE A-SIDE AND B-SIDE SERVICE HOURS
MERE 131 AND 123 HOURS HESPECI IVELY.
FEB. 78 99 88 SOME MINOR LEAK REPAIRS AFTER THE OVERHAUL/CLEANING TOOK PLACE
DURING FEBRUARY. SERVICE HOURS MERE: BOILER = 642, A-SIDE =
636, B-SIDE = 564.
MAR. 78 74 70 ONE FORCED SHUTDOWN OCCURRED ON THE A-SIDE. SERVICE HOURS HERE:
BOILER = 744, A-S10E = 744, B-SIDE = 735.
APR. 78 100 70 A MINUH LEAK REPAIR MAS NECESSARY AFTER AN OVERHAUL/CLEANING.
SERVICE HOUHS MERE: BOILER = 720* A-SIDE = 667, B-SIDE = 720.
-------
EPA UTILITY fGD SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR UPERAT10NAL FGD SYSTEMS
UTILITY NAME ARIZONA PUBLIC SERVICE
UNIT NAME CHOLLA a
UNIT LOCATION JOSEPH CITY AKIZONA
UNIT RATING «J50 MM
FUEL CHARACTERISTICS COAL 0.44-1 PERCENT SULFUR
FGD VENDOR RESEARCH COTTRELL
PROCESS LIMESTONE
NEW OH RETROFIT NEW
START UP DATE 6/78
EFFICIENCY:
PARTICIPATES (ACTUAL)
(DESIGN) 99.7 PERCENT
S02 (ACTUAL)
(DESIGN) 75.0 PERCENT
NATER MAKE UP OPEN LOOP
SLUDGE DISPOSAL DIKED/LINED SOLAR EVAPORATION
OPERATING EXPERIENCE UPDATE:
APRIL-MAY 1978 - iHE SCRUBBER ON UNIT 2 IS NO it WORKING MOST OF THE TIME AND IS THEREFORE CONSIDERED
TO BE OPERATIONAL. SOME PROBLEMS HAVE OCCURRED WITH VIBRATIONS THROUGH THE SYSTEM. THE EPA HAS
GRANTED THE UTILITY AN EXTENSION FOR COMPLIANCE. THE COMPLIANCE TEST SHOULD BE COMPLETED BY AUGUST
15 WHICH IS THE DATE THAT HAS NOW BEEN SET FOR COMERCIAL START-UP.
-------
EPA UTILITY F60 SURVEY: APRIL 1976 - MAY 1976
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
COLUMBUS & SOUTHERN OHIU ELEC.
CONCSVILLE 5
CONESVILLE OHIO
400 MM
FUEL CHARACTERISTICS COAL 4.5 - 4.9 PERCtNT SULFUR
FGD VENDOR
PROCESS
NEM OR RETROFIT
START UP DATE
EFFICIENCY:
PARTICIPATES (ACTUAL)
AIR CORRECTION DIVISION, UOP
LIME
1/77
(DESIGN)
S02 (ACTUAL)
(DESIGN)
MATER MAKE UP
SLUDGE DISPOSAL
99.6 PERCENT
89.5 PERCENT
OPEN LOOP
PUMPED TO A LANDFILL
OPERATING EXPERIENCE UPDATE:
PERIOD
OPERATION TIME (HH)
BOILER A-SIDE B-SIDE
JAN. 76 0
ALL INDEX VALUES = 0 PERCENT
FEB. 76
ALL INDEX VALUES = 0 PERCENT
MAR. 76 379
AVAILABILITY (X) =
OPERABILITY (X) s
RELIABILITY (X) s
UTILIZATION (X) a
APR. 76 716
AVAILABILITY (X) s
OPERABILITY (X) s
RELIABILITY (X) =
UTILIZATION (X) 3
MAY 76 730
AVAILABILITY (X) =
OPERABILITY (X) s
RELIABILITY (X) 3
UTILIZATION (X) s
72
20
64
19
19
67
58
61
SB
52
05
45
44
60
20
54
16
16
65
59
63
59
54
50
51
49
COMMENTS
THE UNIT WAS SHUTDOWN FOR OVERHAUL THROUGH FEBRUARY AND
STARTED UP ON MARCH 16.
IMPURITIES IN LIME HAVE CAUSED PLUGGING PROBLEMS. PH
CONTROLS AND S02 ANALYSERS HAVE GIVEN SOME OPERATIONAL
PROBLEMS.
THE SYSTEM MAS DOMN DUE TO AN EXCESS OF FLOCCULANT
IN THE THICKENEK. THIS CAUSED A HIGH AMOUNT OF SOLIDS
IN THE OVERFLOW THAT RESULTED IN PLUGGING PROBLEMS IN
THE ABSORBER MODULES.
THE SYSTEM MAS TAKEN OUT OF SERVICE BECAUSE OF CONTINUED
PROBLEMS MlTH THE FLOCCULANT FEED SYSTEM. THE THICKENER
MAS EMPTIED TO RESTORE PROPER FLOCCULANT BALANCE.
FLOCCULANT MAS CLEANED OUT.
24
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EPA UTILITY FGO SURVEYS APRJL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION t-UH OPERATIONAL FGU SYSTEMS
UTILITY NAME COLUMBUS (I SOUTHERN OHIO ELtC.
UNIT NAME CONtSVlLLE b
UNIT LOCATIUN CONfcSVlLLE OHIO
UNIT RATING aOO MW
FUEL CHARACTERISTICS COAL «.5 - «.9 PEKCENT SULFUR
FGO VENDOR AIR CORHECTIUN DIVISION, UOP
PROCESS LIME
NEW OR RETROFIT NEW
START UP DATE 4/78
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN) 99.6 PERCENT
302 (ACTUAL)
(DESIGN) 89.5 PERCENT
MATER MAKE UP
SLUDGE DISPOSAL PUMPED TO LANDFILL
OPERATING EXPERIENCE UPDATE:
FEB. 78
MAR. 78
THE UNIT IS CURRENTLY IN A PKE-OPEKATIONAL PHASE. FULL COMMERCIAL OPERATION IS EXPECTED
AFTER INITIAL START-UP PROBLEMS HAVE BEEN CORRECTED.
APR. 78
MAY 78
THE UNIT IS STILL IN A PRE-OPERATIONAL PHASE. FULL COMMERCIAL OPERATIONS WILL START IN JUNE.
-------
EPA UTILITY FGO SURVEYS APRIL 1976 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGU SYSTEMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
DUOUESNE LIGHT
ELRAMA POWEK STATION
ELRAMA PENNSYLVANIA
510 MX
FUEL CHARACTERISTICS COAL 1.8-2.2 PERCENT SULFUR
FGD VENDOR
PROCESS
NEN OR RETROFIT
START UP DATE
EFFICIENCY:
PARTICIPATES (ACTUAL)
(DESIGN)
802 (ACTUAL)
(DESIGN)
MATER MAKE UP
SLUDGE DISPOSAL
CHEMICO
LIME
RETROFIT
10/75
99.0 PERCENT
99.0 PERCENT
bO.O PERCENT
03.0 PERCENT
OPEN LOOP
HAULAWAY TO OFF SITE LANDFILL
OPERATING EXPERIENCE UPDATE:
OPERATING HOURS
PERIOD BOILER SCRUBBER-ABSORBER VESSELS
101 201 301 401 501
JAN. 76 700 673 38 161 26
DURING THE PERIOD A N£M MQRMER RECYCLE PUMP IN-
STALLED IN NOVEMBER EXPERIENCED JACK SHAFT BEARING
PROBLEMS RESULTING IN THE REMOVAL OF TRAIN 501
FHOM SERVICE. BOILER NO. 4 MAS CONNECTED ADDING
AN ADDITIONAL 176 MM LOAD TO THE SYSTEM. THE
IUCS SLUDGE DISPOSAL FACILITY IS NOM IN SERVICE.
A LOW LOAD DEMAND AND THE COAL STRIKE HAVE
HAMPERED SCRUBBER OPERATIONS. THERE IS SOME
OUTAGE TIME SCHEDULED FOR MARCH.
FEB. 76
MAR. 76
204 277 0 107 121 THE SYSTEM HAS SHUTDOWN ON FEB. 11 DUE TO A COAL
00000 SHORTAGE. THE FOLLOWING REPAIRS HERE MADE DURING
THE OUTAGE WHICH CONTINUED THROUGH MARCH:
BOILER EXIT DAMPERS "EKE LINED WITH 316 S3 ON
AREAS OF HIGH EROSION CAUSED BY FLYASH IM-
PINGEMENT.
* EXPANSION JOINTS IN THE UPSTREAM DUCTWORK
MERE SHIELDED BY METAL PLATES WHICH MERE
WELDED AT ONE END.
* EXPANSION JOINTS IN THE DOWNSTREAM DUCTWORK
WERE COMPLETELY REPLACED.
THE DOWNSTREAM DUCTWORK MAS RELINED MITH
CEILCOTE.
MODULE 401 INTERNALS WERE CLEANED AND SOME
HOLES IN THE UPPER CONICAL REGION MERE RE-
PAIRED.
BOILERS 1, 2 AND 4 ARE NOW COMPLETELY CONNECTED
TO THE FGO SYSTEM. BOILER 3 IS UNDERGOING
AN EXTENSIVE OVERHAUL AND HILL BE CONNECTED TO
THE SYSTEM IN LATt APRIL.
26
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EP* UTILITY FGD SURVEY: APRIL l"»78 - MAY 1978
OUOUESNE LIGHT ELrtAMA POWER STATIUM
PERIOD BOILER SCRUBBEP-ABSORBER VESSELS
101 £01 301 401 501
APR. 78
MAY 78 BOILEH J IS STILL BtING OvEKHAULED. ALL F60 SYS-
TEM CONSTHUCTION IS COMPLETE AND COMPLIANCE TEST-
ING *ILL TAKE PLACE IN JULY WHEN UNIT 3 is PUT IN
SERVICE. THE PREL1MINAKT TESTING CONDUCTED DURING
THE PERIOD VERIFIED SYSTEM soa REMOVAL EFFICIENCY.
NO HOURS rtERE REPORTED DUE TO IRREGULAR SYSTEM
OPERATION OURING THE TESTING.
-------
EPA UTILITY F6D SURVEY: APRIL 1976 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
OUOUESNE LIGHT
PHILLIPS POWER STATION
SOUTH HEIGHT PENNSYLVANIA
aio MN
FUEL CHARACTERISTICS COAL 1.8-2.2 PERCENT SULFUR
FGO VENDOR
PROCESS
NEN OR RETROFIT
START UP DATE
EFFICIENCYl
PARTICIPATES (ACTUAL)
(DESIGN)
302 (ACTUAL)
(DESIGN)
MATER MAKE UP
SLUDGE DISPOSAL
CHEMICO
LIME
RETROFIT
7/73
99.0 PERCENT
99.0 PERCENT
60.0 PERCENT
63.0 PERCENT
OPEN LOOP
HAULAWAY TO OFF SITE LANDFILL
OPERATING EXPERIENCE UPDATE:
OPERATING HOURS
MONTH
JAN. 78
FEB. 78
BOILER
3
SCRUBBER-ABSORBER
101 201 301
627
571
401
484
209 267 16 152
AN OUTAGE OCCURRED BETWEEN JAN. b AND JAN. 6 WHEN THE STACK DRAIN LEAKS HERE REPAIRED BY
SANDBLASTING THE OUTER MALL AND REPLACING THE CARBON STEEL BANDS WITH STAINLESS STEEL BANDS.
THE SYSTEM MAS SHUTDOWN ON FEB. 11 DUE TU THE COAL SHORTAGE. THE OUTAGE CONTINUED THROUGH
MARCH AND THE SYSTEM IS SCHEDULED TO BE ON LINk BY APRIL IS. DURING THE OUTAGE THE FOLLOWING
REPAIRS AND MODIFICATIONS WERE MADE:
THE BOILER EXIT DAMPEkS WERE LINED WITH 316SS ON AREAS OF HIGH EROSION CAUSED BY
FLYASH IMPINGEMENT.
EXPANSION JOINTS ON THE INLET DUCTWORK WERE SHIELDED BY METAL PLATES WHICH MERE
WELDED AT ONE END.
NUMEROUS HOLES IN THE WET GAS DUCT WORK MERE REPAIRED AND THE DUCTS MERE RELINEO
WITH CEILCOTE.
THE THROAT DAMPERS WEKE CLEANED ON ALL THE SCRUBBERS.
INTERNAL MIST ELIMINATORS WERE CLEANED. THE EXTERNAL MIST ELIMINATORS* WHICH
ARE BADLY DETERIOWATED> MAY BE REPLACED.
THE STACK BRICKLINING WAS INSPECTED AND SOME BRICKS WERE REPLACED AT THE TOP UF THE
STACK.
CONSTRUCTION WORK ON ADDITIONAL EQUIPMENT SUCH AS THE THICKENER AND SILOS IS ALMOST COMPLETE.
IT MAS NOTED THAT THE CEILCOTE LINER CORULINE 505AR HAS HELD UP WELL OVER THREE YEARS ON
THE CONICAL APEX OF MODULE 401.
MAR. 76
APR. 76
MAY 76
THE FGO SYSTEM CAME BACK ON LINE AFTER THE COAL STRIKE IN LATE MARCH. IT IS NOT OPERATING
AT FULL LOAD BECAUSE THE NO. b BOILER IS STILL OUT AND SHOULD BE BACK ON LINE IN MID-JULY.
COMPLIANCE TESTS WILL TArE PLACE IN JULY. AFTER BOILER 6 IS BACK ON LINE, TO SEE IF THE
SYSTEM IS MEETING THE 63S S02 REMOVAL REQUIREMENT FOR 2X SULFUR COAL. THERE MERE NO HOURS
REPORTED FOR THIS PERIOD BECAUSE OF PRELIMINARY TESTING BEING CONDUCTED IN PREPARATION FOR
THE COMPLIANCE TESTS. SO FAH, TESTS INDICATE THAT THE SYSTEM WILL COMPLY MITM THE REQUIRED
STANDARDS.
26
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EPA UTILITY F6D SURVEY: APRIL 1978 - MAY 1976
SECTION 3
PERFORMANCE DESCRIPTION FOK OPERATIONAL FGD SYSTEMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
INDIANAPOLIS POWER & LIGHT
PETERSBURG 3
PETERSBURG INDIANA
530 MM
FUEL CHARACTERISTICS COAL 3.0-3.5 PERCENT SULFUR
FGO VENDOR
PROCESS
NEW OR RETROFIT
START UP DATE
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN)
302 (ACTUAL)
(DESIGN)
MATER MAKE UP
SLUDGE DISPOSAL
UNIVERSAL OIL PRODUCTS
LIMESTONE
NEW
10/77
99.3 PERCENT
eo.o PERCENT
CLOSED LOOP
IUCS SLUDGE STABILIZATION
OPERATING EXPERIENCE UPDATE:
DECEMBER-JANUARY 1976 - OPERATION OF ALL FOUR MODULES WAS INITIATED IN DECEMBER 1977. A SUCCESSFUL
24-HOUR RUN MAS COMPLETED ON DEC. 16 AND 17 WITH MODULES "B", "C* AND "0" IN OPERATION. "A* MODULE
HAD AN INOPERATIVE RECYCLE TANK AGITATOR. REPAIR OF THE AGITATOR HAS COMPLETED ON DEC. 22
AND MODULE A WAS PLACED IN INITIAL OPERATION. A 30-DAY RUN SCHEDULED TO BEGIN JAN. 11 WAS POST-
PONED UNTIL MID-MARCH PENDING RESOLUTION UF PROBLEMS ASSOCIATED WITH THE FLY ASH REMOVAL SYSTEM.
THE COLD HEATHER NECESSITATED THE ERECTION OF TEMPORARY ENCLOSURES AROUND SEGMENTS OF THE FSO SYSTEM
UNTIL THE INSTALLATION OF HEAT TRACING COULO BE COMPLETED.
FEBRUARY-MARCH 1978 - THF. MODULES DID NOT OPERATE DURING FEBRUARY AS REPAIRS WERE MADE TO LINES AND
VALVES DAMAGED BY FREEZE-UPS DURING THE WINTER. DURING MARCH SOME SCHEDULED REPAIRS
MERE MADE WHICH INCLUDED INSTRUMENTATION WORK, INSULATION INSTALLATION AND REPAIR OF A BROKEN PINION
GEAR ON THE THICKENER. SYSTEM START-UP IS STILL BEING DELAYED BY PROBLEMS WITH THE FLY ASH HANDLING
SYSTEM AND IS NOW EXPECTED TO BE IN MID-APRIL.
APRIL-MAY 1976 - THE UNIT CAME BACK ON LINE IN THE MIDDLE OF APRIL AFTER PROBLEMS WITH THE FLYASH
HANDLING SYSTEM WERE CORRECTED. THE SYSTEM OPERATED UNTIL THE MAIN POWER TRANSFORMER FAULTED,
CAUSING THE SYSTEM TO GO DOWN. THE OUTAGE LASTED UNTIL JUNE 16. PROBLEMS HAVE ALSO BEEN EXPERI-
ENCED WITH ALL CONTROL VALVES AND PIPING. THE VALVES HAD TO HE SENT BACK TO THE FACTORY FOR MODI-
FICATIONS.
29
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EPA UTILITY F60 SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
UTILITY NAME KANSAS CITY POMER A LIGHT
UNIT NAME HAWTHORN 3
UNIT LOCATION KANSAS CITY MISSUUKI
UNIT RATING 100 MW
FUEL CHARACTERISTICS COAL 0.5-3.5 PERCENT SULFUR
F60 VENDOR COMBUSTION ENGINEERING
PROCESS LIME
NEH OR RETROFIT RETROFIT
START UP DATE 11/78
EFFICIENCY:
PARTICULATES (ACTUAL) 99.0 PERCENT
(DESIGN) 99.0 PERCENT
808 (ACTUAL)
(DESIGN) 70.0 PERCENT
MATER MAKE UP OPEN LOOP 7.0 GPM/MW
SLUDGE DISPOSAL PLANT SITE DISPOSAL POND
OPERATING EXPERIENCE UPDATE:
FGD SYSTEM
MONTH PERIOD HRS. BOILER HRS. FGD SYSTEM HRS. AVAILABILITY (X)
FEB. 78 672 167 167 85
MAR. 78 700 406 406 56
DURING FEBRUARY THE UNIT MAS DUMN FOUR TIMES N1TH ECONOMIZER AND MATER MALL LEAKS (OUTAGE
TIME APROX. 500 HRS). A TMO MEEK OUTAGE MAS SCHEDULED DURING MARCH FOR SEASONAL MAINTENANCE.
MATER MALL LEAK REPAIR AS NELL AS ACID CLEANING OF THE BUILER CAUSED ADDITIONAL OUTAGE TIME
DURING THE LAST MEEK IN MAKCH.
APR. 78 780 546 820 76
MAY 78 744 403 003 48
AN AIR PREHEATER FIRE MAS DISCOVERED IN THE A MODULE ON MAY 18 CAUSING THAT MODULE TO BE
DOMN THE REST OF THE MONTH.
30
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EPA UTILITY FGD SUHVEr: APHR 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL F6D SYSTEMS
UTILITY NAME KANSAS CITY POWER ft LIGHT
UNIT NAME HAWTHORN 4
UNIT LOCATION KANSAS CITY MISSOURI
UNIT RATING 100 MW
FUEL CHARACTERISTICS COAL 0.5-3.5 PERCENT SULFUR
FGO VENDOR COMBUSTION ENGINEERING
PROCESS LIME
NEH OR RETROFIT RETROFIT
START UP DATE 8/72
EFFICIENCY!
PARTICULATES (ACTUAL) 99.0 PERCENT
(DESIGN) 99.0 PERCENT
302 (ACTUAL)
(DESIGN) 70.0 PERCENT
MATER MAKE UP OPEN LOOP 7.0 GPM/MH
SLUDGE DISPOSAL PLANT SITE DISPOSAL POND
OPERATING EXPERIENCE UPDATE:
FGO SYSTEM
MONTH PERIOD HRS. BOILER HRS. FGD SYSTEM HRS. AVAILABILITY (X)
FEB. 76 672 198 196 30
MAR. 76 744 471 471 63
THE UNIT MAS DOWN THREE TIMES DURING FEBRUARY FOR NON-SCRUBBER RELATED PROBLEMS. THO OTHEH
OUTAGES HERE THE RESULT OF A FUEL SAFETY TRIP PROBLEM AND GENERAL SCRUBBER MAINTENANCE. IN
MARCH THERE MERE THREE ECONOMIZER LEAK OUTAGES (APPOX. 231 HRS) AND THE SCRUBBER REQUIRED AN
ADDITIONAL 32 HRS OF OUTAGE TIME FOR MAINTENANCE.
APR. 76 720 286 40
MAY 76 744 421 44
FGD OUTAGE IN MAY MAS DUE TO V CLARIFIER PLUG-UP. APRIL OUTAGE TIME HAS SCHEDULED FOR
ROUTINE MAINTENANCE AND GENERAL CLEANING. SYSTEM HOURS HILL BE AVAILABLE FOR THE NEXT
REPORT.
31
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EPA UTILITY F60 SURVEY: APRIL 1978 - HAY 1978
SECTION i
PERFORMANCE DESCRIPTION FOH OPERATIONAL FGU SYSTEMS
UTILITY NAME KANSAS CITY POHER ft LIGHT
UNIT NAME LA CYGNE 1
UNIT LOCATION LA CYGNE KANSAS
UNIT RATING 620 MW
FUEL CHARACTERISTICS COAL 5.0 PERCENT SULFUR
FGO VENDOR BABCOCK ft HILCOX
PROCESS LIMESTONE
NEN OR RETROFIT NEW
START UP DATE 2/73
EFFICIENCY:
PARTICULATES (ACTUAL) 98.2 PERCENT
(DESIGN) 98.0 PERCENT
302 (ACTUAL) 80.1 PERCENT
(DESIGN) 76.0 PERCENT
HATER MAKE UP OPEN LOOP 1.4 GPM/MM
SLUDGE DISPOSAL PLANT SITE DISPOSAL POND
OPERATING EXPERIENCE UPDATE:
PERCENT AVAILABILITY-BV MODULE
MONTH BOILER HOURS ABCDEFGH AVERAGE
FEB. 78 578 92 93 95 9
-------
EPA UTILITY PUD SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
UTILITY NAME KANSAS POftEK 8 LIGHT
UNIT NAME LAWRENCE 4
UNIT LOCATION LAWRENCE KANSAS
UNIT DATING 12b Mw
FUEL CHARACTERISTICS COAL 0.5 PERCENT SULFUR
F6D VENDOR COMBUSTION ENGINEERING
PROCESS LIMESTONE
NEW OR RETROFIT RETROFIT
START UP DATE
EFFICIENCY:
PARTICULATES (ACTUAL) 99* PERCENT
(DESIGN) 98.9 PERCENT
802 (ACTUAL) 90+ PERCENT
(DESIGN) 73.0 PERCENT
WATER MAKE UP OPEN LOAD
SLUDGE DISPOSAL PLANT SITE DISPOSAL POND
OPERATING EXPERIENCE UPDATE:
FEB. 78 THE FGD SYSTEM OPERATED DURING THE REPORT PERIOD WITH NO MAJOR PROBLEMS. THE THICKENER
MAR. 78 UNDERFLOW LINE IS STILL FROZEN AND TWO 3 INCH DIAMETER FIRE HOSES ARE BEING USED TO PUMP
THE UNDERFLOW SOLIDS TO THE POND.
APR. 78
MAY 7A THE UTILTTY REPORTED THAT THE FGD SYSTEM AND THE BOILER RAN WITHOUT ANY OUTAGES DURING
THIS PERIOD.
33
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EPA UTILITY F60 SURVEY: APRIL 1978 - C»Y 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL f-GU SYSTEMS
UTILITY NAME KANSAS POHEK & LIGHT
UNIT NAME LAMKENCE 5
UNIT LOCATION LANKENCE KANSAS
UNIT RATING 400 MM
FUEL CHARACTERISTICS COAL o.s PERCENT SULFUR
FGO VENDOR COMBUSTION ENGINEERING
PROCESS LIMESTONE
NEW OR RETROFIT NEM
START UP DATE 11/71
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN) 98.9 PERCENT
S02 (ACTUAL)
(DESIGN) 52.0 PERCENT
HATER MAKE UP OPEN LOOP
SLUDGE DISPOSAL PLANT SITE DISPOSAL PUND
OPERATING EXPERIENCE UPDATE:
OPERATING HOURS
MONTHS BOILER FGO MODULES
FEB. 78
MAR. 78
THE ORIGINAL FGD SYSTEM MAS PULLED OFF LINE ON MARCH 30 SO THAT THE NEM SCRUBBER-ABSORBER
SYSTEM COULD BE TIED INTO THE GAS PATH. THIS NEM SYSTEM CONSISTS OF TWO MODULES EACH MITH A
ROD SECTION FOR PARTICULATE REMOVAL AND A SPRAY TOMER FOR SOI REMOVAL. THE CAPACITY IS 210 MM
EACH. INITIAL OPERATION SHOULD BEGIN bY THE FIRST OF MAY.
APR. 78
MAY 78
THE NEW UNIT WENT IN SERVICE ON APKIL 14 AND HAS RUN HELL WITH NO OUTAGES SINCE START-UP.
34
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EPA UTILITr FGO SURVEY: APRIL 1978 - MAt 19/8
SECTION 3
PERFORMANCE DESCRIPTION FOH OPERATIONAL FGU SYSTEMb
UTILITY NAME KENTUCKY UTILITIES
UNIT NAME GREEN RIVER 1,2 * 3
UNIT LOCATION CENTRAL CITY KENTUCKY
UNIT RATING 64 MM
FUEL CHARACTERISTICS COAL 3.8 PERCENT SULFUR
FGD VENDOR AMERICAN Alk FILTER
PROCESS LIME
NEW OR RETROFIT RETROFIT
START UP DATE 9/75
EFFICIENCY:
PARTICULATES (ACTUAL) 99.7 PERCENT
(DESIGN) 99.7 PERCENT
302 (ACTUAL) 80-90 PERCENT
(DESIGN) 80.0 PERCENT
HATER HAKE UP OPEN LOOP 1.20 GPM/MW
SLUDGE DISPOSAL PLANT SITE DISPOSAL POND
OPERATING- EXPERIENCE UPDATE:
TOTAL BOILER MODULE MODULE CALLED MR. MODULE
PERIOD PERIOD (HR) OPERATION (HR) AVAILABILITY (HR) TO OPERATE (HR) OPERATED
JAN. 78 744 537 722 537 170
AVAILABILITY = 97X
RELIABILITY = 32X
OPERABILITY = 32X
UTILIZATION = 23X
DURING THE MONTHS OF DECEMBER AND JANUARY NUMEROUS FHEEZE-UPS OCCURED. AS ONE COMPONENT
WAS THAWED ANOTHER WOULD FREEZE. THE ABSORBER nAS AVAILABLE FUR FGD OPEHATIONS BUT COULD NOT
BE UTILIZED BECAUSE THE SLURRY LINE TO THE PUNU FROZE. THE UMT WENT DOWN AFTER ABOUT 170
HOURS OF OPERATION IN JANUARY. BECAUSE OF EMERGENCY CONDITIONS THE UTILITY CHOSE TO CONCEN-
TRATE THEIR MAINTENANCE CREWS UN POWER GENERATION RATHER THAN FGD OPERATION. UNDER NOR-
MAL CONDITIONS THE RELATIVELY MINOR FGD SYSTEM PROBLEMS WOULD HAVE BEEN SOLVED MORE QUICKLY.
IN LIGHT OF THIS THE SYSTEM HAS BEEN CONSIDERED AVAILABLE THROUGHOUT MOST OF THE PERIOD CON-
CERNED.
FEB. 76 672 672 672 0 0
AVAILABILITY = 100X
RELIABILITY =
OPERABILITY =
UTILIZATION = OX
DURING THE FREEZE UP NUMEROUS GASKETS WERE TURN THROUGHOUT THE SYSTEM. THE SYSTEM WAS SHUT
DOWN- COMPLETELY FOH REPAIR WORK.
MAR. 78 744 669 744 0 0
AVAILABILITY = 100X
RELIABILITY =
OPERABILITY =
UTILIZATION = OX
REPAIR WORK WILL CONTINUE UNTIL LATE APRIL 78 «HEN THE SCRUBBER-ABSORBER SYSTEM IS EXPECTED
BACK ON LINE.
APR. 78 720 295 296 295 296
AVAILABILITY = 41X
RELIABILITY = 99X
OPERABILITY = 99X
UTILIZATION * 41X
35
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EPA UTILITY F60 SURVEY: APRIL 1978 - HAY 1978
KENTUCKY UTILITIES GREEN RIVEK 1,2 t 3
TOTAL BOILER MODULE MODULE CALLED HR. MODULE
PERIOD PERIOD (HR) OPEKAIION (HR> AVAILABILITY (HR) TO OPERATE (HR) OPERATED
MAY 78 744 470 474 473 474
AVAILABILITY i 64Z
RELIABILITY = 98X
OPERABILITY * 100X
UTILIZATION = 64X
THE UTILTY EXPERIENCED RECYCLE TANK SCREEN PROBLEMS OVER THE PERIOD.
36
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EPA UTILITY FGO SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION F0« OPERATIONAL f-GD SYSTEMS
UTILITY NAME LOUISVILLE GAS & ELECTRIC
UNIT NAME CANE RUN a
UNIT LOCATION LOUISVILLt KENTUCKY
UNIT RATING 178 MN
FUEL CHARACTERISTICS COAL 3.5 - <4.0 PERCENT SULFUR
FGO VENDOR AMERICAN AIR FILTER
PROCESS LIME
NEW OR RETROFIT RETROFIT
START UP DATE b/7b
EFFICIENCY:
PARTICULATES (ACTUAL) 99.0 PERCENT
(DESIGN) 99.0 PERCENT
S02 (ACTUAL) 86-89 PERCENT
(DESIGN) 05.0 PERCENT
MATER MAKE UP OPEN LOOP
SLUDGE DISPOSAL PLANT-SITE DISPOSAL POND
OPERATING EXPERIENCE UPDATE:
PERFORMANCE FACTORS (X)
PERIOD HOURS BOILER (HR) FGD SYSTEM (HR) OPERAUILITY UTILIZATION
FEB. 78 672 00 00
MAR. 78 744 249 34
THc UNIT MAS DOWN THE ENTIRE MONTH OF FEBRUARY DUE TO THE COAL SHORTAGE AND A LACK OF AVAIL-
ABLE LIME RESULTING FRUM THE SEVERE WINTER WEATHER. THE UNIT CAME BACK ON LINE MARCH 21
AFTER WHICH TIME THE FGD SYSTEM MAS ON LINE UUKING 95X OF THE BOILER HOURS THROUGH THE END OF
MARCH.
APR. 78 720 303 303 100 47
DURING APRIL THE BOILER WAS DOWN FUR REPAIRS. THE UTILITY REPORTED THAT THE AVAILABILITY
AND RELIABILITY WERE BUTH 100X.
MAY 78 744 3S2 115 35 12
THE BOILER WAS DUWN AGAIN IN MAY FUR REPAIRS. DURING THE BOILER OUTAGE A NUMBER OF MODIFICA-
TIONS WERE MADE TO THE OAMPEKS IN THE FEU SYSTEM. THE UTILITY REPORTED THAT THE FGD SYSTEM
HAS BEEN RUNNING WELL SINCE THE MODIFICATIONS TOOK PLACE. THE AVAILABILITY AND RELIABILITY
FOR MAY WERE 31 AND 35 PERCENT RESPECTIVELY.
37
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EPA UTILITY FGO SURVEYS APRIL 1970 - HAY 1976
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
LOUISVILLE GAS & ELECTRIC
CANE RUN 5
LOUISVILLE KENTUCKY
163 MM
FUEL CHARACTERISTICS COAL 3.5 - 4.0 PERCENT SULFUR
FGO VENDOR
PROCESS
NEM OR RETROFIT
START UP DATE
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN)
308 (ACTUAL)
(DESIGN)
MATER MAKE UP
SLUDGE DISPOSAL
COMBUSTION ENGINEERING
LIME
RETROFIT
12/77
99.0 PERCENT
B5.0 PERCENT
CLOSED LOOP
PLANT-SITE DISPOSAL HUNO
OPERATING EXPERIENCE UPDATE:
DECEMBER-JANUARY 1978 - OPERATION OF THE FGD SYSTEM AT CANE RUN 5 BEGAN ON DECEMBER 29. INITIAL
OPERATIONS MERE NOT CONTINUOUS. DURING OPERATION SOME OF THE CONTROLS MERE NOT NORKING PROPERLY
AND MODIFICATIONS MERE NECESSARY.
FEBRUARY-MARCH 1978 - THE PLANT REMAINED UFF LINE THROUGHOUT FEBRUARY AND THEN RE-STARTEO ON MARCH
24. THE BOILER OPERATED APPROXIMATELY 182 HOURS THROUGH THE END OF HAHCH MITH THE FGD SYSTEM
OPERATING APPROXIMATELY 91 HOURS. VARIOUS INITIAL START-UP PROBLEMS MERE STILL BEING ENCOUNTERED
CAUSING FGD SYSTEM OUTAGES.
APRIL-MAY 1978 - DURING APRIL THE BUILEK WAS ON LINE b69 HOURS, AND THE FGD SYSTEM OPERATED 648 OF
THOSE HOURS. DURING MAY THE BOILER AND FGO SYSTEM OPERATED 432 AND 3b4 HOURS, RESPECTIVELY. FGD
SYSTEM MODIFICATIONS HAVE BEEN TAKING PLACE IN PREPARATION FOR THE PERFORMANCE TESTS. THE ONLY
PROBLEM THAT OCCURRED DURING TESTING KAS A POOR JOB OF DATA GATHERING BY THE DATA CRENS. THEY DID
NOT ACCURATELY FOLLOW THE EPA TEST METHUOS. THE UTILITY IS CONFIDENT THAT THE UNIT MOULD HAVE
PASSED HAD THE CREN TAKEN THEIR DATA PROPERLY. THE UNIT IS NOW IN ITS PREOPERATIONAL PHASE.
38
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EPA UTILITY FGO SURVEY: APRIL 1978 - M*Y 1<)78
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTtMS
UTILITY NAME LOUISVILLE GAS & ELECTRIC
UNIT NAME PADOYS RUN b
UNIT LOCATION LOUISVILLE KENTUCKY
UNIT RATING 65 MM
FUEL CHARACTERISTICS COAL 3.5 - -4.0 PERCENT SULFUR
FGD VENDOR COMBUSTION ENGINEERING
PROCESS LIME
NEW OR RETROFIT RETROFIT
START UP DATE a/73
EFFICIENCY:
PARTICULATES (ACTUAL) 99.0 PERCENT
(OESIGNJ 99.0 PERCENT
308 (ACTUAL) 80-99 PERCENT
(DESIGN) 80.0 PERCENT
NATER MAKE UP OPEN LOOP 0.7 GPM/MW
SLUDGE DISPOSAL HAULAWAY TO BURROW PIT
OPERATING EXPERIENCE UPDATE:
SEP. 77
THROUGH
MAR. 78 NOT OPERATIONAL PADDY'S RUN NO. 6 UID NOT OPERATE THROUGH THIS PERIOD DUE TO A LACK
OF POWER REQUIREMENT.
NOTE: THIS UNIT MILL BE RETIRED WHEN THE MILL CREEK NO. 3 UNIT
BECOMES OPERATIONAL. WHICH IS SCHEDULED FOR JULY, 1978.
APR. 78
MAY 78 THIS PEAK LOAD UNIT WAS ONLY ON LINE A FEW HOURS DURING THE PERIOD.
NO PROBLEMS WERE REPORTED.
39
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EPA UTILITY FGD SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL F6D SYSTEMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
MINNKOT* POwEK COOPERATIVE
MILTON R. YOUNG 2
CENTER NORTH DAKOTA
450 MH
FUEL CHARACTERISTICS LIGNITE 0.7 PERCENT SULFUH
FGD VENDOR
PROCESS
NEM OR RETROFIT
START UP DATE
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN)
302 (ACTUAL)
(DESIGN)
WATER MAKE UP
SLUDGE DISPOSAL
AOL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALINE FLVASH
NEN
9/77
99.6 PERCENT
75.0 PERCENT
CLOSED LOOP
PLANT SITE/MINE FILL
OPERATING EXPERIENCE UPDATE:
FEBRUARY-MARCH 1978 BOTH THE BOILERS AND FGD SYSTEM CAME BACK ON LINE FEB. 21 AFTER COMPLETION
OF THE TURBINE REPAIRS. ONE SCRUBBER-ABSURBER FORCED DRAFT FAN HAD AN OIL LEAK AND A SHAFT ALIGN-
MENT PROBLEM. IT MAS TAKEN OFF THE LINE AND SHIPPED TO BUFFALO FORGE CO.'S PLANT FOR REPAIRS. THE
AFFECTED MODULE MAS DONN FROM FEB. 23 THROUGH APRIL 10, WHEN THE REPAIRED UNIT MAS RE-INSTALLED.
THE VACUUM FILTER ON THE SECOND SCRUBBER-ABSORBER WAS MALFUNCTIONING. ALLOWING LARGER SIZE
PARTICLES TO ESCAPE THE FILTER. THIS CAUSED THE ttUBBER LINING DOWNSTREAM TO PEEL WHICH, IN
TURN, CREATED A PLUGGING PROBLEM. E.I.M. COMANY ENGINEERS ARE PRESENTLY STUDYING THE PROBLEM
AND HOPE TO INCORPORATE MODIFICATIONS TO IMPROVE THE PERFORMANCE OF THE FILTERS. THE COMPLIANCE
TEST HAS AGAIN BEEN RESCHEDULED WITH THE EPA FOR THE END OF MAY.
APRIL-MAY 1978 - COMPLIANCE TESTING TOOK PLACE DURING THE WEEK OF JUNE 5. THE UTILITY IS CONFIDENT
THAT THE UNIT PERFORMED WELL AND WILL BE CERTIFIED. THE REPORT SHOULD BE AVAILABLE TO THE UTILITY
BY THE END OF JUNE. THE UNIT IS CURRENTLY DOWN WITH DAMPER PROBLEMS (DOWN ON THE 24TH OF JUNE).
APPARENTLY THE CHAINS THAT PULL THE GUILLOTINE DAMPERS WERE TOO WEAK. THEY ARE BEING REPLACED.
au
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EPA UTILITY FGO SURVEY: APRIL 1978 - MAY 1978
SECUUN 3
PERFORMANCE DESCRIPTION FOK OPERATIONAL FGO
UTILITY NAME MONTANA
UNIT NAME CULSTklf 1
UNIT LOCATION COLSTKIP MONTANA
UNIT RATING 360 MM
FUEL CHARACTERISTICS COAL 0.8 PERCENT SULFUR
F6D VENDOR ADL/CDMBUST ION tQUlP ASSOCIATt
PflOCESS L IMt/ALKALINE FLrASh
NEW OR RETROFIT Ntw
START UP OATE 11/75
EFFICIENCY:
PARTICULATES (ACIU*L) 99. S PfcRtENT
(OfcSIGN) 99.5 PtRCEuT
SOa (ACTUAL) /5.0 PERCENT
(DESIGN) 60.0 PERCENT
HATER MAKt UP CLOSED LdUP
SLUDGE DISPOSAL CL*r-LINED UIKEU POMD
OPERATING EXPERIENCE UPDATF:
FEB. 78
MAR. 78
NO INFORMATION WAS REPORTED BY THE UTILITY FUR THIS PERIOD.
APR. 78
MAY 78
THE UNIT rtAS DOWN f-OR MOST OF THt SPUING FUR A SCHEDULED OVERHAUL.
«1
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EPA UTILITY F60 SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOM OPERATIONAL FGO SYSTEMS
UTILITY NAME MONTANA POWER
UNIT NAME COLSTkIP I
UNIT LOCATION COLSTRIP MONTANA
UNIT RATING 360 MM
FUEL CHARACTERISTICS COAL 0.8 PERCENI SULFUR
FGO VENDOR AOL/COMBUSTION EQUIP ASSOCIATE
PROCESS LIME/ALKALINE FLYASH
NEW OR RETROFIT NEW
START UP DATE 87/60
EFFICIENCY:
PARTICULATES (ACTUAL) 99.5 PERCENT
(DESIGN) 99.5 PERCENT
308 (ACTUAL) 75.0 PERCENT
(DESIGN) 60.0 PERCENT
MATER MAKE UP CLOSED LOOP
SLUDGE DISPOSAL
OPERATING EXPERIENCE UPDATE:
JAN. 76
FEB. 76
MAR. 78
NO INFORMATION MAS REPORTED BY THE UTILITY FOR THIS PERIOD.
APR. 78
MAY 76
THE UNIT WAS DUWN FOR MOST OF THE SPRING FOR A SCHEDULED OVERHAUL.
-------
EHA UTILITY F&O SUKVtr: AHHU 1976 - M4T 19/6
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL F60 SYSTEMb
UTILITY NAME NEVADA POWER
UNIT NAME REID GARDNER 1
UNIT LOCATION MOAPA NEVADA
UNIT RATING 125 MW
FUEL CHARACTERISTICS CUAL 0.5 - 1.0 PERCENT SULFUR
FGD VENDOR ADL/COMBUST10N EQUIP ASSOCIATE
PROCESS SODIUM CARBONATE
NEW OR RETROFIT RETROFIT
START UP DATE 4/74
EFFICIENCY:
PART1CULATES (ACTUAL) 99+ PERCENT
(DESIGN) 99.0 PERCENT
302 (ACTUAL) 85-90 PERCENT
(DESIGN) 85.0 PERCENT
HATER MAKE UP OPEN LOOP 0.40 GPM/Mn
SLUDGE DISPOSAL SOLAR EVAPORATION POND
OPERATING EXPERIENCE UPDATE:
HR.
bOILER MODULE CALLED
TOTAL OPERATION AVAILABLE UPON TO UPERATION
PERIOD (HR.) (HR.) (HR.) OPERATE (HR.)
FEB. 78 672 389 654 309 292
AVAILABILITY = 971
RELIABILITY s 94*
OPERABILITY = 75X
UTILIZATION = 43X
THE SCRUBBER-ABSORBER SYSTEM WAS OFF-LINE FOR APPROXIMATELY 18 HOURS DURING FEBRUARY DUE TO
PLUGGED SENSING LINES AND A DUCT HI-LO PRESSURE TRIP. THE BOILER WENT OUT OF SLRVICE ON
UN FEBRUARY 17 FOR A THREE WEEK OUTAGE.
MAR. 78 744 355 207 355 207
AVAILABILITY = 28Z
RELIABILITY = 5BX
OPERABILITY = 58X
UTILIZATION = 28X
THE BOILER CAME BACK ON LINE MARCH 16 BUT PROBLEMS *ITH 1Ht GUILLOTINE SWITCHES DELAYED
START-UP OF THE FGD SYSTEM UNTIL MARCH 2
-------
EPA UTILITY FGO SURVEY: APRIL i97a - MAY 1973
SECTION 3
PERFORMANCE DESCRIPTION FOR UPtRATIONAL FGO SYSTEMS
UTILITY NAME NEVADA POWER
UNIT NAME REID GARDNER 2
UNIT LOCATION MOAPA NEVADA
UNIT RATING 12b MM
FUEL CHARACTERISTICS COAL O.b - 1.0 PEKCENT SULFUR
FGO VENDOR AOL/COMBUSTION EQUIP ASSOCIATE
PROCESS SODIUM CARBONATE
NEH OR RETROFIT RETROFIT
START UP DATE a/74
EFFICIENCY: "
PARTICULATES (ACTUAL) 99* PERCENT
(DESIGN) 99.0 PEKCENT
302 (ACTUAL) 85-90 PERCENT
(DESIGN) es.o PERCENT
MATER MAKE UP OPEN LOOP 0.40 GPM/MM
SLUDGE DISPOSAL SOLAR EVAPORATION PONO
OPERATING EXPERIENCE UPDATE:
HH.
BOILER MODULE CALLED
TOTAL OPERATION AVAILABLE UPON TO OPERATION
PERIOD (HR.) (HR.) (Mk.) OPERATE (HK.)
FEB. 78 672 636 625 632 585
AVAILABILITY « 931
RELIABILITY * 92X
OPERABILITY = 92X
UTILIZATION = 87X
FGD DOWNTIME DURING FEBRUARY HAS APPROXIMATELY 48 HOURS DUE TO A PLUGGED SENSING LINE AND
A OUCT HI-LO PRESSURE THIP. THE BOILER MAS OUT OF SERVICE 34 HOURS.
MAR. 78 744 672 726 614 595
AVAILABILITY = 981
RELIABILITY s 97X
OPERABILITY = 89X
UTILIZATION z 80X
THERE MAS ONLY ONE FURCEO FGD OUTAGE DURING MARCH MHICH LASTED APPROXIMATELY 18 HOURS. A
SCHEDULED BOILER OUTAGE AT THE BEGINNING OF THE MONTH TO REMOVE ASH BUILDUP MAS CANCELLED.
APR. 78 720 320 720 317 317
AVAILABILITY = 1001
RELIABILITY = 100X
OPERABILITY * 98X
UTILIZATION = 44X
THERE MAS UNE SCHEDULED BOILER OUTAGE MHICH LASTED ABOUT 403 HOURS.
MAY 78 744 726 743 72fc 724
AVAILABILITY = 1UOX
RELIABILITY f 100X
OPERABILITY = 100X
UTILIZATION = 97X
THE BOILER MAS OFF FOR APPROXIMATELY 18 HOURS FOR REPAIRS ON THE MILL SPOKES. THE 2A SEC.
BREAKER TRIPPED »NU CAUSED Afc UUTAbE OF ABUUT ONE HOUR.
44
-------
EPA UTILITY FGD SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGU SYSTEMS
UTILITY NAME NEVADA POwEk
UNIT NAME REID GARDNER 3
UNIT LOCATION MOAPA NEVADA
UNIT RATING 125 MW
FUEL CHARACTERISTICS COAL 0.5 - 1.0 PEKCtNt SULFUR
FGD VENDOR AQL/COMBUSTION tOUIP ASSOClATt
PROCESS SODIUM CAKBUNATE
NEN OR RETROFIT NEW
START UP DATE 7/76
EFFICIENCY!
PARTICULATES (ACTUAL) 99+ PERCENT
(DESIGN) 99.0 PERCENT
302 (ACTUAL) 85-90 PERCENT
(DESIGN) 85.0 PERCENT
HATER MAKE UP OPEN LOOP 0.40 GPM/MW
SLUDGE DISPOSAL SOLAR EVAPORATION POND
OPERATING EXPERIENCE UPDATE:
HR.
BOILER MODULE CALLED
TOTAL OPERATION AVAILABLE UPON TO OPERATION
PERIOD (HR.) (HR.J (HR.) OPERATE (HR.)
FEB. 78 672 619 6U2 618 588
AVAILABILITY = 96X
RELIABILITY = 95X
OPERABILITY = 95X
UTILIZATION = 88t
DURING FEBRUARY FAULTY WIRING CAUSED A HIGH VENTURI TEMPERATURE RESULTING IN AN INITIAL 16
HOUR FGO SYSTEM OUTAGE. THERE WAS A StCONU OUTAGE OF 13 HOURS TO CHECK THE VENTURI TEMPERA-
TURE INDICATOR. A THIRD OUTAGE MAS CAUSED BY PLUGGING OF THE MIX TANK WHICH MADE IT IMPOS-
SIBLE TO MIX CHEMICALS.
HAR. 78 744 741 724 738 718
AVAILABILITY = 97Z
RELIABILITY = 97X
OPERABILITY = 97X
UTILIZATION = 96X
THE MIX TANK PROBLfcM CUNIINUEO INTU MARCH CAUSING THt ONLY FGL> DOWNTIME FOR THE MONTH
(APRUX. 20 HUURS). A FURNACE Ml-LU HRfcSiURE TKlP CAUSED A BOILER OUTAGE OF 6 HOURS.
APR. 78 720 704 699 650 629
AVAILABILITY = 97X
RELIABILITY = 97X
OPERABILITY = 89X
UTILIZATION = 87X
THE Ff,D SYSTEM WAS DOWN APPROXIMATELY 21 HUURS FOR REPAIRS ON THE VENTURI EMERGENCY SPRAY
SYSTEM. THE HUILER WAS DUNN APPROXIMATELY 70 HOURS DURING APRIL.
MAY 78 744 646 724 514 494
AVAILABILITY = 97X
RELIABILITY = 96X
OPERAblLITY = 77X
UTILIZATION = 66X
THERE WAS A SCHEDULED OUTAGE OF <23U HUURS FOR BOILER MAINTENANCE* AND A FORCED OUTAGE OF
20 HUURS DUE Tu A FAULTY TEMPERATURE PROBE AT THE VENTURI.
45
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EPA UTILITY F6D SURVEY: APRIL 1978 - HAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
NORTHERN INDIANA PUB SEKVICE
DEAN H. MITCHtLL 11
GARY INDIANA
115 Ml»
FUEL CHARACTERISTICS COAL 3.2-3.5 PERCENT SULFUR
FGD VENDOR
PROCESS
NEN OR RETROFIT
START UP DATE
EFFICIENCY:
PARTICULATES (ACTUAL)
DAVY POwERGAS/ALLIED CHEMICAL
WELLMAN LURD/ALLItD CHEMICAL
RkTHOFIT
11/76
99.5 PERCENT
(DESIGN) 99.5 PERCENT
302 (ACTUAL) .91.0 PERCENT
(DESIGN) 90.0 PERCENT
HATER MAKE UP CLOSED LOOP
SLUDGE DISPOSAL ELEMENTAL SULFUR PRODUCT
OPERATING EXPERIENCE UPDATE:
MONTH
HOURS
IN PERIOD
HOURS
AVAILABLE
HOURS
CALLED ON
TO OPERATE
HOURS
OPERATED
AVAILABILITY RELIABILETY UTILIZATION
NOV. 77 720 531 596 428 74 72 90
THE FCD UNIT OPERATED FUR 16 CONSECUTIVE DAYS, AVERAGING 9UX S02 REMOVAL WITH 205 LUNG TONS OF
SULFUR RECOVERED. FGD OPERATION WAS INTERRUPTED UY A UNI' 11 BOILER TUBE LEAK AND RESUMPTION OF FGD
OPERATION HAS FURTHER DELAYED BY MAINTENANCE IN THE EVAPORATOR SECTION. MAINTENANCE MAS ALSO PER-
FORMED ON THE FLUE GAS ISOLATION DAMPER, FLUE GAS BOOSTER BLOWER, AND 302 REDUCTION SECTION.
DEC. 77 769 379 272 0 49 0 0
THE FGD SYSTEM HAS NOT OPERATED DURING THIS PERIOD DUE TO ABNORMAL BOILER OPERATING CONDITONS
RELATED TO HIGH SILICA LEVELS IN THt FEED WATER. THE HIGH SILICA LEVELS HSULTEO FROM HIGH MAKE-UP
HATER REQUIREMENTS DUE IN PART TO A HIGHER THAN NORMAL FGO PLANT USAGE, AS HELL AS UNIT 11 COAL FEED
PROBLEMS AND A PRECIPITATUR MALFUNCTION. MAINTENANCE WAS PERFORMED ON THE FG BOOSTER BLOWER AND
THE ABSORBER SOLUTION REGENERATION SECTION.
JAN. 78 720 576 0 0 80 0
THE FGD SYSTEM REMAINED DOHN THROUGHOUT JANUARY AS HIGH SILICA LEVELS IN THE UNIT 11 BOILER FEED
WATER PERSISTED. MAINTENANCE HAS PERt-uRMtn ON THE UNIT 11 PRECIPITATOR, THE FG BOOSTER BLOWER AND
THE FGD SYSTEM S02 COMPRESSOR.
FEB. 78 720 336 0 0 47 0
THE FGD SYSTEM HAS NOT OPERATED DUE TU ABNORMAL BUILEK OPERATING CONDITIONS RELATED TO HIGH SILICA
LEVELS IN THE BOILER FEED WATER, COUPLEU wITH UNIT 11 COAL FEED PROBLEMS, STOP VALVE PROBLEMS, PRE-
CIPITATOR MALFUNCTION AND A LEAKING BOILER TUBE AND WORK ON THE FLUE GAS ISOLATION DAMPER. MAIN-
TENANCE WAS ALSO PERFORMED ON THE Fli BOOSTER BLU"ER, THE EVAPORATOR CIRCULATING PUMP AND THE 802
SUPERHEATER PIPING.
MAR. 78 720 648 281 215 90 77 30
THE FGD SYSTEM OPERATED FUR TEN DAVb. OPERATION WAS INTERRUPTED BY SHUTDOWN OF THE UNIT 11 BOILER
FOR REPAIR OF COAL GRINDING MILLS AND PRECIPITATORS. PROPER CONDITIONS COULD NOT BE RE-ESTABLISHED
FOR RE-START OF FGD OPERATION BECAUSE OF COAL FEED ANU GRINDING PROBLEMS CAUSED BY EXTREMELY POOR
QUALITY COAL. MAINTENANCE WAS PERFORMED UN THE FG BOOSTER BLOWER AND OPERATING PROBLEMS HERE
ENCOUNTERED WITH THE FLUE GAS ISOLATION DAMPER.
46
-------
EPA UTILITY FGO SURVEY: APRIL 197fl - MAY 1978
HOURS
HOURS HOURS CALLtO UN HUUkS
MONTH IN PERIOD AVAILABLE TO OPEHATF OPERATED AVAILABILITY RELIABILITY UTILIZATION
APR. 78 730 0 288 0 0 u 0
THE F6 BOOSTER BLOWER HAS OUT OF SEKVICt FOR [HIS ENTIRE PERIUU FUR REBLADING. THE FGD SYSTEM MAS
INOPERABLE. A FAILURE OF THE FLUE GAS 1SULATION DAMPEN ALSO OCCURRED. A Nth SUPPLY OF HIGH SULFUR
COAL WAS OBTAINED AND SUCCESSFULLY TESTED ON UNIT II BOILER. THIS COAL IS EXPECTED TO ALLEVIATE
PAST DIFFICULTIES WITH THt COAL FEED AND GRINDING SYSTEM. MAINTENANCE HAS ALSO PERFORMED ON THE
BOILER ID FANS, COAL FEEDING AND GRINDING SYSTEM ANU THE FGD ABSORBER.
MAY 76 720 368 S29 £63 51 50 37
THE 302 RECOVERY PORTION OF THE FGD SYSTEM OPERATED FUR 26 DAYS. THE COMPLETE FGD SYSTEM OPERATED
FOR 11 DAYS. OPERATION MAS INTERRUPTED BY FAILURE OF THE FLUE bAi ISOLATION UAMPER, PROBLEMS WITH
WET COAL WHICH REUUIREO THAT THE UNIT 11 HOILER OPERATE ON LOw SULFUR COAL FOR A SHORT PFRIOD AND
PLU66ING OF AN ENTRAINMENT SEPARATOR IN ThE SU2 REDUCTION UNI1.
47
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EPA UTILITY FGO SURVEY: APRIL 1976 - HAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
UTILITY NAME NORTHERN STATES POWER
UNIT NAME SHERBURNE 1
UNIT LOCATION BECKER MINNESOTA
UNIT RATING 710 MN
FUEL CHARACTERISTICS COAL 0.6 PERCENT SULFUR
FGO VENDOR COMBUSTION ENGINEERING
PROCESS LIMESTONE/ALKALINE FLYASH
NEH OR RETROFIT NEW
START UP DATE 3//6
EFFICIENCY:
PARTICULATES (ACTUAL) 99+ PERCENT
(DESIGN) 99.0 PERCENT
302 (ACTUAL) 50-55 PERCENT
(DESIGN) 50.0 PERCENT
MATER MAKE UP OPEN LOOP 1.13 GPM/MW
SLUDGE DISPOSAL CLAY-LINED DISPOSAL POND
OPERATING EXPERIENCE UPDATE:
BOILER OPERATION TIME AND MODULE OPERABILITY (*)
BOILER
PERIOD MR. 101 102 103 104 105 lOb 107 106 109 110 HI 112
FEB. 76 636 0 93 92 89 74 85 89 88 76 86 86 87
TOTAL SYSTEM AVAILABILITY - 9£ PERCENT
MEGAWATT-HOURS GENERATED = 366,200
MODULE 101 HAS DOMN IN FEBRUARY FUR MODIFICATIONS TO THE SPRAY TOWER ABSORBER. A BULK
ENTRAINMENT SEPARATOR MAS INSTALLED ALONG MITH A KOCH WASH TRAY. SPRAY NOZZLES HERE
REPLACED. THE 2 IN. UIA. ss RODS IN THE PRIMARY CONTACTOR WERE REPLACED HITH 6 5/8 IN. DIA.
CERAMIC COATED C.S. RODS. THE CEKAMIC SLEEVES ARE 9/16IN. THICK. MODULES WHICH ARE SHOWING
AVAILABILITY OF LESS THAN ao PERCENT. ARE THOSE IN WHICH THE STRAINER MODIFICATIONS HERE
PERFORMED.
MAR. 76 676 71 63 64 69 90 83 62 89 97 71 79 90
TOTAL SYSTEM AVAILABILITY = 92 PERCENT
MEGAWATT-HOURS GENERATED = 423,220
STRAINER MODIFICATIONS CONTINUED THROUGH MAKCH AFFECTING THE AVAILABILITIES OF MODULES 101,
103, 107 AND 110.
APR. 76 713 92 67 87 44 81 65 91 86 92 91 87 52
TOTAL SYSTEM AVAILABILITY = 95 PERCENT
MEGAWATT-HOURS GENERATED = 464,520
THE REASON FOR LOW AVAILABILITY ON MODULE 104 AND 112 IN APRIL RESULTED FORM THE OUTAGE TIME
NECESSARY FOR THE INSTALLATION OF SI EEL STRAINER SCREENS.
MAY 78 635 61 86 85 86 89 64 62 83 82 71 67 79
TOTAL SYSTEM AVAILABILITY = 95 PEHCEM
MEGAWATT-HOURS GENEMAIED - 3eo,oio
THERE WERE NU MAJOR FbO RELATED OUTAGES DURING HAY.
46
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EPA UTILITY FGD SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION POM OPERATIONAL FGO SYSTEMS
UTILITY NAME NORTHERN STATtS POWER
UNIT NAME SHERBURNE 2
UNIT LOCATION BECKER MlNNtSUTA
UNIT RATING 710 MW
FUEL CHARACTERISTICS COAL O.tt REKCtNt SULFUR
FGO VENDOR COMBUSTION ENGINEERING
PROCESS LIMESTONE/ALKALINE FLY ASH
NEW OR RETROFIT NEW
START UP DATE a/77
EFFICIENCY:
PARTICULATES (ACTUAL) 50-55 PERCENT
(DESIGN) 99.0 PtRLENT
S02 (ACTUAL) 55.0 PERCENT
(DESIGN) 50.0 PERCENT
HATER MAKE UP OPEN LOOP 1.13 bPM/MW
SLUDGE DISPOSAL CLAY-LINED DISPOSAL POND
OPERATING EXPERIENCE UPDATE:
BOILER OPERATION TIME AND MODULE UPERABILITY (X)
BOILER
PERIOD HR. 201 202 203 204 205 206 207 208 209 210 211 212
FEB. 78 620 83 85 55 91 89 76 71 89 85 81 97 60
TOTAL S.STEM AVAILABILITY = 92 PERCENI
MEGAWATT-HOURS GENERATED = 367,080
MODULES 203 AND 212 HAVE LOW AVAILABILITY DUE TO STRAINER MODIFICATIONS.
MAR. 78 744 82 92 90 83 78 85 91 62 83 78 88 89
TOTAL SYSTEM AVAILABILITY = 97 PERCENT
MEGA 'ATT-HOURS GENERATED = 083,750
IN SPITE OF STRAINER MODIFICATIONS ON MUDULES 208 AND 210, THE SYSTEM GENERATED MAXIMUM
MEGAWATT-HOURS AND TIED THE HIGHEST RECORDED AVAILABILITY OF 97 PERCENT.
APR. 78 719 70 82 90 84 91 83 84 A6 78 90 67 85
TOTAL SYSTEM AVAILABILITY = 92 PERCENT
MEGAWATT-HOURS GENERATED = 436,420
DURING APRIL MODULE 201 WAS CONVERTED FUR USE WITH THE NEW SPHAY TOWER WHICH WAS INSTALLED.
MAY 78 120 97 94 80 90 90 89 90 92 28 91 78 14
TOTAL SYSTEM AVAILABILITY = 91 PERCENT
MEGAWATT-HOLTWS GENERATED = 70,070
THERE WERE LINER FAILURES CCEILCOTE) IN MOST OF THE MUDULES DURING MAY. THE LINERS HERE
REPAIRED BY THE CtlLCUIE COMPANY AT THEIR OWN EXPENSE. THE INLET SEAL STRIPS HERE ALSO
REPAIRED. THE UMIT WENT OUwN ON MAY 6 FOR THE FIRST YEAR BOILER AND TUWBINE INSPECTION AND
WAS DOWN FOR 1HE REMAINDER OF UE PERIOD.
49
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EPA UTILITY FGO SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
PENNSYLVANIA POnEK
BRUCE MANSFIELD 1
SHIPPINGPORT PENNSYLVANIA
825 MW
FUEL CHARACTERISTICS COAL 4.7 PERCENT SULFUR
FGD VENDOR
PROCESS
NEW OR RETROFIT
START UP DATE
EFFICIENCY!
PARTICULATES (ACTUAL)
(DESIGN)
302 (ACTUAL)
(DESIGN)
MATER MAKE UP
SLUDGE DISPOSAL
CHEMICO
LIME
NbW
a/76
99.9 PERCENT
99.8 PERCENT
95.0 PERCENT
92.1 PERCENT
OPEN LOOP
RESERVOIR LANDFILL
OPERATING EXPERIENCE UPDATE:
MONTH
BOILER
OPERATING HOURS
FGD MODULES
BCD
NOV. 77 720 682
FGO AVAILABILITY FACTOR X 95
FGD OPERABILITY FACTOR X 95
FGD UTILIZATION FACTOR X 95
713
99
99
99
657
91
91
91
TOTAL FGD LOST GENERATION FACTOR = 52.5
REMOVAL OF THE OLD COATING AND PRIMING OF THt t-LUE LINING IN FLUE IB IS PROCEEDING
SLOMER THAN ANTICIPATED. IT is EXPECTED THAT TOTAL NOKK ON THE FLUE MILL NOT BE COMPLETED
UNTIL FEBRUARY OR MARCH 1978.
DEC. 77 626 677 592 675 0 0
FGO AVAILABILITY FACTOR X 100 93 99 0 0
FGD OPERABILITY FACTOR X 100 94 100 0 0
FGD UTILIZATION FACTOR X 91 79 91 0 0
TOTAL FGO LOST GENERATION FACTOR r 61 X
SANDBLASTING OF UNIT 1-B FLUE IS NEARING COMPLETION.
CXL-2000.
THE FLUE MILL BE RELINED WITH P.P.P.
JAN. 78 331
FGO AVAILABILITY FACTOR X 100 0 100 000
FGD OPERABILITY FACTOR x 100 o 100 o o o
FGO UTILIZATION FACTOR 58 0 58 0 00
TOTAL FGD LOST GENERATION FACTOR = 60X
THERE MERE PROBLEMS WITH IB FAN nHICH NECCESITATED EXTENSIVE REPAIRS. LINING ABRASION AND
DISBONDMENT IN FAN CAUSED CORROSION OF UNDERLYING SUPPORT MFTAL. THE UNIT TRIPPED SEVERAL
TIMES DUE TO DIFFICULTIES IN BURNING HET STOCKPILE CUAL.
FEB. 78 514 534 410 551 000
FGD AVAILABILITY FACTOR X 79 61 82 0 0 0
FGD OPERABILITY FACTOR X 100 80 100 0 00
FGO UTILIZATION FACTOR X 79 61 82 0 0 0
TOTAL FGD LOST GENERATION FACTOR = 54X
EXTENSIVE REPAIRS TO IB 1.0. FAN AND THE EMERGENCY NEED FOR LOAD FROM THE PLANT DURING THE
COAL STRIKE TEMPORARILY OVERLOADED 1A AND 1C TRAINS. THE MIST ELIMINATOR MILL BE REPLACED ON
1C TRAIN AS A RESULT OF THIS. IB FLUE RELIN1NG CONTINUES.
SO
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EPA UTILITY FGD SURVfcr: APRIL 1>*78 - MAY
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGU SYbUMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
SHIPPINGPORT PENNSYLVANIA
625 MW
FUEL CHARACTERISTICS COAL 4.7 PERCENT SULFUR
FGD VENDOR
PROCESS
NEW OR RETROFIT
START UP DATE
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN)
SOZ (ACTUAL)
(DESIGN)
MATER MAKE UP
SLUDGE DISPOSAL
CHEMICO
LIME
NEW
7/77
99.9 PERCENT
99.8 PERCENT
95.0 PERCENT
92.1 PERCENT
OPEN LOOP
RESERVOIR LANDFILL
OPERATING EXPERIENCE UPDATE:
MONTH
BOILER
OPERATING HOURS
FGD MODULES
BCD
NOV. 77 581 596 564 533 331 304 246
FGD AVAILABILITY FACTOR X 100 96 68 47 55 47
FGD OPERABILITY FACTOR X 100 100 92 57 52 42
FGD UTILIZATION FACTOR X 83 61 74 46 42 34
TOTAL FGD LOST GENERATION FACTOR = 27X
PROBLEMS ASSOCIATED WITH THE STATION POWER TRANSFORMERS CAUSED LIMITATION IN LOAD ON UNIT 2.
THREE OF THE SIX STATION TRANSFORMERS FOR UNIT 2 WERE DESTROYED.
DEC. 77 607 469 639 618 640 513 565
FGO AVAILABILITY FACTOR X 74 99 96 100 69 99
FGD OPERABILITY FACTOR X 77 100 100 100 85 93
FGD UTILIZATION FACTOR X 63 86 63 66 69 76
TOTAL FGD LOST GENERATION FACTOR = 7.UX
COLD WEATHER CREATED SOME FREEZING PROBLEMS rtlTH PROCESS PIPING.
JAN. 76 391
FGD AVAILABILITY FACTOR X 95 100 96 94 99 99
FGD OPERABILITY FACTOR X 56 100 56 100 100 96
FGD UTILIZATION FACTOR X 31 76 29 70 64 50
TOTAL FGD LOST GENERATION FACTOR = 4.3X
UNIT TRIPPED SEVERAL TIMES DUE Tu DIFFICULTIES IN BURNING NET STOCKPILE COAL. BOILER
CONTROL VALVE PROBLEMS ("W" VALVE) COMPOUNDED START-UP ATTEMPT U.*FICULTIES. WHEN THE UNIT
MAS ON LINE DURING THIS MONTH, THE WET COAL ALSO PREVENTED FULL LOAD OPERATION UF
COAL MILLS.
FEB. 78 672 321 460 594 480 664 525
FGO AVAILABILITY FACTOR X 84 67 89 97 99 78
FGD OPERABILITY FACTOR X 46 68 88 71 99 78
FGD UTILIZATION FACTOR X 48 68 88 71 99 78
TOTAL FGD LOST GENERATION FACTOR = 16.6 X
MANY PROBLEMS OCCURRED WITH I.D. FAN COOLERS DUE TO INCLEMENT WEATHER.
51
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EP» UTILITY FGD SURVEY! APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
UTILITY NAME PHILADELPHIA ELECTRIC
UNIT NAME EDDYSTONE 1A
UNIT LOCATION EDDYSTONE PENNSYLVANIA
UNIT RATING 120 MH
FUEL CHARACTERISTICS COAL 2.5 PERCENT SULFUR
FGD VENDOR UNITED ENGINEERS f PECO
PROCESS MAGNESIUM OXIDE
NEN OR RETROFIT RETROFIT
START UP DATE 9/75
EFFICIENCY:
PARTICULATES (ACTUAL) 99.9 PERCENT
(DESIGN) 99.9 PERCENT
S02 (ACTUAL) 95-97 PERCENT
(DESIGN) 90.0 PERCENT
WATER MAKE UP OPEN LOOP 1.1 6PM/MM
SLU06E DISPOSAL ACID PLANT REGENERATION
OPERATING EXPERIENCE UPDATE:
FEB. 78 THE TURBINE OVERHAUL CONTINUED DURING THE REPORT PERIOD. DURING THE SHUTDOWN PERIOD IT
MAR. 78 MAS FOUND THAT SOME HIGH PRESSURE STEAM TUBES MERE CRACKED. SO UNIT MAINTENANCE HAS TAKEN
LONGER THAN EXPECTED. SOME MINOR FGO SYSTEM MODIFICATIONS HAVE BEEN INCORPORATED IN THE
COURSE OF THE SHUTDOWN PERIOD. START UP IS EXPECTED IN MID-APRIL 78.
APR. 78 THE UNIT JUST CAME BACK ON LINE JUNE 1 AFTER AN EXTENSIVE SYSTEM MODIFICATION OUTAGE
MAY 78 WHICH BEGAN DECEMBER 22. THE UNIT WAS EXPECTED BACK ON LINE IN MID-APRIL* BUT THERE MAS
A PROBLEM WITH A SUPER PRESSURE STEAM TURBINE.
52
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EPA UTILITY FGD SURVEY: APRIL 1978 - MAY 1976
SECTION 5
PERFORMANCE DESCRIPTION FUH OPERATIONAL FGO SYSTEMS
UTILITY NAMfc PUBLIC bEHVlCt UF Nbn MEXICO
UNIT NAME SAN JUAN 1
UNIT LOCATION WAIERFIOW NtW MEXICO
UNIT RATING 314 MW
FUEL CHARACTERISTICS CUAL 0.6 HEKCENT SULFUR
FGO VENDOR DAVY KOwEHGAS/ALL1ED CHEMICAL
PROCESS WELLMAN LORD
NEW OR RETROFIT NE"
START UP DATE «/76
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN) 99.B PtRCENT
302 (ACTUAL)
(DESIGN) 65.0 PbRCENT
MATER MAKE UP
SLUDGE DISPOSAL
OPERATING EXPERIENCE UPDATE:
FEBRUARY-MARCH 1976 - INITIAL S02 ABSORPTION AT SAN JUAN NO. 1 BEGAN UN APRIL 6, 1976. FULL COMMER-
CIAL OPERATION IS EXPECTED BY LATt JUNE. THE FGO SYSTEM IS CURRENTLY IN SERVICE WITH TwO OF THE
UNIT'S FOUR ABSORBER CELLS OPERATING CONTINUOUSLY. A THIRD CELL IS TO BE BROUGHT ON LINE LATER.
THREE CELLS WILL BE REQUIRED FOR FULL LUAD WITH A FOURTH INCLUDED FOR SPARE FGD CAPACITY. THE CUR-
RENT MODE IS TO KEEP 2 CELLS IN SERVICE AT ALL TIMES AND & OUT OF SERVICE. 2/3 OF THE FLUE GAS
IS BEING TREATED WHILE 1/3 IS BEING BYPASSED. THE UNIT IS IN COMPLIANCE AT PRESENT WITH HESPECT TO
S02 WITH ONLY 2 CELLS RUNNING BECAUSE THE BISULFITE CONCENTRATION HAS NOT YET BUILT UP IN THE ABSOR-
BENT LIQUOR. WHEN THE SYSTEM REACHES EOUILIBRIUM WITH RESPECT TO BISULFITE (18X BISULFITfc) THE UNIT
WILL BE READY TO BEGIN REGENERATING OPERATIONS. REGENERATION IS EXPECTED TO BEGIN BY APRIL 27.
COMPLIANCE TESTING MAY TAKE PLACE AS EAHLY AS THE FIRST WEEK OF MAY.
APRIL-MAY 1976 - OVER THE PERIOD THE UTILITY ACCUMULATED 22 DAYS OF DATA DURING WHICH THE BOILER
MAS DOWN FOR 7 HOURS AND THE ABSORBERS HERE DOWN FOR 28 HOURS (UNSCHEDULED). THE UNIT IS STILL NOT
STABILIZED SO USEFUL FIGURES FOR WATER KEUUIKEMENTS ARE UNAVAILABLE. THE CHEMICAL PLANT REMAINS IN
ITS START UP STAGE.
53
-------
EPA UTILITY FGO SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGU SYSTEMS
UTILITY NAME SOUTH CAROLINA PUBLIC SERVICE
UNIT NAME NINYAH i
UNIT LOCATION GEORGETOWN SOUTH CAROLINA
UNIT DATING £80 MM
FUEL CHARACTERISTICS COAL 1.0 PERCENT SULFUK
FGD VENDOR BABCOCK * M1LCOX
PROCESS LIMESTONE
NEM OR RETROFIT NEM
START UP DATE 7/77
EFFICIENCY:
PARTICULATES (ACTUAL) 99.a PERCENT
(DESIGN) 99.a PERCENT
308 (ACTUAL) 85.0 PERCENT
(DESIGN) t>9.0 PERCENT
MATER MAKE UP OPEN LOOP
SLUDGE DISPOSAL ON-SITE POND
OPERATING EXPERIENCE UPDATE:
FEB. 78 DURING THE FEB-MAR PERIOD THE FGD SYSTEM MAS BYPASSED ONCE FOR SEVERAL DAYS TO ALLOM
MAR. 78 SYSTEM CLEANING. THIS HAS IN PREPAKATION FOR TESTS THAI BABCOCK AND NlLCOX MILL SOON
BE PERFORMING* AND FOR MHICH THEY HAVE SET UP TEMPORARY ON-SITE LABORATORY FACILITIES.
OTHERMISEr THE SYSTEM RAN NELL DURING THE PERIOD WITH ONLY A FEN MINOR PLUGGING AND SPILL-
AGE PROBLEMS IN VARIOUS SLURRY LINES.
APR. 78 THE SYSTEM MAS OPERATIONAL FOR MOST OF THIS PERIOD. THE ONLY PROBLEM ENCOUNTERED MAS
MAY 78 MINOR SCALING. BUT IT DID NOT CAUSE AN OUTAGE. THE UTILITY DID NOT HAVE ANY PERFORMANCE
FACTORS TO REPORT FOR THIS PERIOD.
-------
EPA UTILITY F&O SURVtr: APRIL 1970 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOH OPERATIONAL FGU SYSTEMS
UTILITY NAME SPRINGFIELD CITY UTILITIES
UNIT NAME SOUTHWEST 1
UNIT LOCATION SPRINGFIELD MISSOURI
UNIT RATING 200 MW
FUEL CHARACTERISTICS COAL 3.5 PERCENT SULFUR
FGD VENDOR AIR CORRECTION DIVISION, UUP
PROCESS LIMESTONE
NEW OR RETROFIT NEW
START UP DATE 4/77
EFFICIENCY!
PARTICULATES (ACTUAL) 99.6 PERCENT
(DESIGN) 99.7 PERCENT
302 (ACTUAL) 92.0 PERCENT
(DESIGN) 60.0 PERCENT
MATER MAKE UP
SLUDGE DISPOSAL FILTER CAKE LANDFILL
OPERATING EXPERIENCE UPDATE:
FEB. 78
MAR. 78
THE ABSORBERS DID NOT OPERATE DUE TO AN tXPANSION JOINT FAILURE BETWEEN THE ID FAN AND
THE ABSORBERS. CURRENTLY, THE ABSORBERS ARE BbING BY-PASSED. THE FGD SYSTEM IS EXPECTED TO
BE BACK ON LINE BY THE ENO OF APRIL.
APR. 78
MAY 78
THE UNIT EXPERIENCED AN FRP LINER FAILURE AS WELL AS A POMP FAILURE DURING THE PERIOD.
CURRENTLY ONLY ONE SCROBBER-ABSORRER MODULE IS RUNNING. THE EXPANSION JOINT FAILURE
MENTIONED PREVIOUSLY WAS DIRECILY RELATED TO THE DAMPER FAILURE WHICH ALLOWED THE BOILER
TO CONTINUE PUMPING GAS TO THE SEALED OFF FGO SYSTEM.
-------
EPA UTILITY FGD SURVEY: APRIL 1478 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL F61) SYSTEMS
UTILITY NAME TENNESSEE VALLEY AU1HORITV
UNIT NAME SHAMNEE IDA
UNIT LOCATION PAOUCAH KENTUCKY
UNIT RATING 10 MN
FUEL CHARACTERISTICS COAL Z.9 PEkCENT SULFUR
F60 VENDOR AIR CORRECTION DIVISION, UOP
PROCESS LIME/LIMESTONE
NEM OR RETROFIT RETROFIT
START UP DATE 4/73
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN) EXPERIMENTALLY CONTROLLED
502 (ACTUAL)
(DESIGN) EXPERIMENTALLY CONTROLLED
MATER MAKE UP EXPERIMENTALLY CONTROLLED
SLUDGE DISPOSAL EXPERIMENTALLY CONTROLLED
OPERATING EXPERIENCE UPDATES
REFER TO OPERATING EXPERIENCE UPDATE FOR SHAMNEE NO. 108.
56
-------
EPA UTILITY FGD SiJkVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMb
UTILITY NAME TENNESSEE VALLEY A1J1HUH1TY
UNIT NAME ShAwNbE 10H
UNIT LOCATION PAOUCAH KENTUCKY
UNIT RATING 10 MW
FUEL CHARACTERISTICS COAL I T IONS, TMt OVERALL SU^ REMOVAL WAS 96 PERCENT AT
2300 PPM INLEI t>0«J ClINCENIRAl ION, COMPARED TO 86 PERCENT REMOVAL AT 1600 PPM INLET S02
WITHOUT MGO ADOITlOi. S0«? kEMUVAL MY VtNTURl ALONE WAS 30 PERCENT, ABOUT THE bAME AS THE
CASt wIlHUUI MC,I> ADD] II"'.. NtA» COMPLETE SULFITE OXIDAIIUN COULD BE ACHIEVED AT AN AIR
STOlCHlUMtIRIC RAIIO AS LO" AS l.< ATOMS OXYGEN/MOLE SU2 ABSORBED, IN THE SAME ORDER AS
THE CASE wIIHuIlT MGu ADDITION.
FORCED OXIDATION AAS ALSO cuNuucTto ON int LIMESTONE SLURRY BLEED STREAM FROM THE VENTURI/
SPRAY lUWER SYSItM. A SINGLE EFFLUENT HOLD TANK WAS USED FOR BOTH VENTURI AND SPRAY
TOWEH. MGO WAS ADOtD TO THE >FFl.UENT HOLD TANK To MAINTAIN AN EFFECTIVE MG*» ION CONCEN-
5/
-------
EPA UTILITY FGD SURVEY: APRIL 1976 HAY 1976
TRATION OF 5000 PPM. A SLURRY STREAM HAS TAKEN FROM THt SCRUBBER OUWNCOMER AND SENT TO
AN OXIDATION TANK INTO MHICH AIR WAS SPARGED. A RECYCLE STREAM OF ABOUT 30 GPM HAS SENT
BACK FROM THE OXIDATION TANK TO THE EFFLUENT HOLD TANK TO CONTROL PH IN THE OXIDATION TANK
AND TO PROVIDE GYPSUM SEEDS IN THE SCRUBBED SLURRY. FINAL SYSTEM BLEED MAS WITHDRAWN FROM
THE OXIDATION TANK. AT AN AVERAGE OXIDATION TANK PH OF b, SULFITE OXIDATION AVERAGED 98
PERCENT. FILTER CAKE SOLIDS CONTbNT HAS B5 PERCENT, SIMILAR TO THAT OBTAINED HITH TNO
SCRUBBER LOOP OPERATIONS. HOWEVER. THE SLURRY SOLIDS SETTLING HATE MAS ONLY ABOUT
0.4 CM/MIN, COMPARED TO ABOUT o.s CM/MIN f-OR THE IMO LOOP OPERATION. SETTLING RATE FOR
UNOXIDIIED SLURRY CONTAINING MAGNESIUM ION NORMALLY DID NOT EXCEED U.I CM/MIN HITH SO TO
60 PERCENT FILTER CAKL SOLIDS.
TCA CONTINOED TO OPERATE MllH MGO AUDITION rtlTH BOTH LIME AND LIMESTONE SCRUBBING. FLUE
GAS MITH HIGH FLY ASH LOADING MAS USEO. THt INTENT Of- IHtSE TESTS MAS TO CLARIFY SOME OF
THE INCONSISTENT RESULTS OBTAINED DURING EARLIER RUNS MADE IN APRIL-NOVEMBER 1976, DURING
WHICH SCRUBBER UOWNCOMER AIR LEAKAGE WAS SUSPECTED IN SOME OF THE TESTS. IN GENERAL,
TESTS RUNS MADE IN 1976 HAD HIGHER INLET bO£ CONCENTRATION, MOSTLY GREATER THAN 3000 PPM,
WHILE THE RECENT RUNS HAD ONLY ABOUT «J500 PPM. AT THE HIGHER INLET S0£ AND THE HIGHER
RESULTANT soa MAKE-PEK-PASS, THE 1976 TESTS OPERATED EIIHER UNSATURATED OR SUPERSATURATED
MITH RESPECT TO GYPSUM, DEPENDING ON THE SULFITE OXIDATION LEVEL. SEVERE GYPSUM SCALING
OCCURRED MHEN THE OPERATION HAS UNDER GYPSUM-SATURATED MODE. IN THE RECENT RUNS, OPERA-
TION HAS MOSTLY UNDER GYPSUM-SA1URAIEU MODE. HOWEVER, BECAUSE OF THE LOWER INLET S02 AND
LOWER so2 MAKE-PER-PASS. THE GYPSUM SATURATION LEVELS MERE NOT HIGH ENOUGH TO CAUSE ANY
SIGNIFICANT SCALING.
-------
EPA UtlLTTY FGI) SURVEY: APRIL 1978 - MAT 1978
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGU SYSTEMS
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
TENNESSEE VALLEY AU1HOR1TY
WIDOWS CRfcEK a
BRIDGEPORT ALABAMA
550 MW
FUEL CHARACTERISTICS COAL 3.7 PERCENT SULFUR
FGO VENDOR
PROCESS
NEW OR RETROFIT
START UP DATE
EFFICIENCY!
PARTICULATES (ACTUAL)
(DESIGN)
S02 (ACTUAL)
(DESIGN)
MATER MAKE UP
SLUDGE DISPOSAL
TENNESSEE VALLEY AUTHORITY
LIMESTONE
RETROFIT
5/77
99.5+ PERCENT
99.5 PERCENT
85-9<4 PERCENT
80.0 PERCENT
100-ACRE DIKED POND
OPERATING EXPERIENCE UPDATE:
MONTH BOILER A-SIDE
OPERATING HOURS
B-SIDE C-SIOE 0-SIOE
COMMENTS
171
aoi
370
310
THE OUTAGE TIME FOR TRAINS A AND B WAS REQUIR-
ED TO REPLACE THE RUBBER LINERS IN THE DOwN-
CUMER AREA WITH STAINLESS STEEL. THIS WILL BE
DONE TO THE REMAINING TnU TRAINS AS WELL.
FEB. 78 586
AVAILABILITY S5X
OPERABILITY = 5«X
RELIABILITY = 6IX
UTILIZATION = 47X
* THE UTILITY REPORTED THAT THEY CUULU NOT ACCURATELY DETERMINE RELIABILITY BECAUSE OF THEIR
INABILITY TO CALCULATE UNIT LOAD DEMAND UN A DAILY BASIS. GENERALLY, IT !S ASSUMMED THAT SYSTEM
FORCED OUTAGE HOURS PLUS THE HOURS FGU SYSTEM OPERATED WILL GIVE ROUGHLY THL HOURS THE SYSTEM WAS
CALLED UPON TO OPERATE. IN THIS WAY, RELlAdlLITr CAN BE CALCULATED INDIRECTLY. HOwEVER. IN THIS
CASEi TWO TRAINS AT A TIME HAVE BfcCTi DOWN ON A SCHEDULED OUTAGE FUR NECESSARY MODIFICATIONS. PART
OF THIS OUTAGE TIME LIMITED BOILER UPfcRATlON SO THAT THE UNIT COULD f«OT RUN AT FULL LOAD WHEN THERE
WAS A DEMAND FOR FULL LOAD. (-OR THIS CALCULATION IT WAS ASSUMMED THAT THERE WAS A DEMAND FOR FULL
LOAD DURING THE ENTIRE SCHEDULED UUlAfeE SO THAT ALL OF THE TRAINS WOULD HAVE BEEN CALLED THE ENTIRE
SCHEDULED OUTAGE, THE RESULT «AS A VERY CONSERV-'IVE ESTIMATE OF RELIABILITY WHERE HOUhS CALLED
= SYSTEM FORCED OUTAGE HOURS + SYSTEM SCHEOULEu OUTAGE + HOURS THE FGO SYSTEM OPERATED.
NOTE: THIS is A Ptoco ESTIMATE.
MAR. 78 h«4 585
AVAILABILITY = 601
OPERABILITY 66X
RELIABILITY = 59X *
UTILIZATION = 58X
3aa 199 5e3 TKAIN >j MAS nuT OF SERVICE MARCH i - MARCH 13
TO INSTALL STAINLESS STEEL IN THE ABSORBER AND
VENTURI l/u NCOMEH AREAS. STAINLESS STEEL
COVERS WERE . STALLED AROUND TWO EXPANSION
JOINTS ON TRAIN C, IN ORDER TO PREVENT FLUE
GAS LEAKAGE FROM 'HE EXPANSION JOINTS. A
STAINLESS STEEL PLA.l WAS WELDED OVER THE
ENTRY DllDK OPENINGS T(J TRAIN C OUTLET AND
BYPASS GUILLOTINE DAMPERS FOR THE PURPOSE
OF ELIMINATING GAS LEAKAGE. TRAIN C nAS OUT
OF SERVICE MARCH 14 - MARCH 89 TO INSTALL
STAINLESS STEEL IN THE ABSORBER AND VENTURI
nuwNCUMfcrt AREAS. SEVERAL LIFTER BARS ON THE
FEED AND DISCHARGE ENDS OF THE BALL MILL WERE
FOUND TO BE BADLY WORN. THE UTILITY HAS HAD
WEAR PROBLEMS WITH THE SLURRY SUMP PUMP
LINERS AT THE BALL MILL.
-------
EPA UTILITY F60 SURVEY! APRIL 1V78 - MAY 1976
MONTH BOILER A-SIOE B-SIDE C-SIOE D-SIOE
APR. 76 540 08U 460 b7b 275
AVAILABILITY = 691
OPERABILITY = 63X
RELIABILITY « 67Z
UTILAZATION = 62X
COMMENTS
AT THE BEGINNING OF THIS MONTH, DURING A BRIEF
INSPECTION OF THE SCRUBBER, SOLIDS DEPOSITION
NAS NOTICED IN THE ENTRAINMENT SEPARATOR
SECTION OF ALL TRAINS BECAUSE OF PLUGGING THAT
HAD OCCURRED IN SEVERAL OF THE ENTRAINMENT
SEPARATOR SPRAY NOZZLES. TRAIN 0 WAS NOT IN
OPERATION FOR 17 DAYS. DURING THIS PERIOD THE
ENTHAINMENT SEPERATOR HAS DISASSEMBLED BY
SECTIONS AND CLEANED. A STAINLESS STEEL LINER
WAS INSTALLED ON THE SLOPING AREAS OF THE
ABSORBER AND VENTURI. STAINLESS STEEL PLATES
MERE INSTALLED OVER THE ENTRY DOOR OPENINGS
TO TRAIN D INLET* OUTLET, AND BYPASS GUILLO-
TINE DAMPERS TO REDUCE GAS LEAKAGE FROM THE
ENTRY DOOR OPENINGS. STAINLESS STEEL COVERS
NERE INSTALLED AROUND THE FIVE EXPANSION
JOINTS ON TRAIN 0, TNO EXPANSION JOINTS ON
TRAIN A, AND UNE EXPANSION JOINT ON TRAIN 8,
TO REDUCE GAS LEAKAGE TO THE ATMOSPHERE.
THERE CONTINUES TO BE A HEAR PROBLEM HITH PUMP
LINERS AT THE BALL MILL. NO CAUSE OR SOLUTION
OF THE PROBLEM HAS BEEN ASCERTAINED A3 YET.
-------
EPA UTILITY FGO SURVEY: APRIL 1978 - MAY 1978
SECTION 3
PERFORMANCE OESCKIPTION F0« OPERATIONAL FGO SYSTEMS
UTILITY NAME TEXAS UTILITIES
UNIT NAME MARTIN LAKE I
UNIT LOCATION TATUM IEXAS
UNIT RATING 79j MW
FUEL CHARACTERISTICS COAU 1.0 HEKCEM SULFUR
FGO VENDOR RESEAKCH CUTTKELL
PROCESS LIMESTONE
NEW OR RETROFIT NEft
START UP DATE tt/77
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN) 99.« PERCENT
308 (ACTUAL)
(DESIGN) 70.5
MATER MAKE UP
SLUDGE DISPOSAL STABILI/ED/ON-S1 TE DISPOSAL
OPERATING EXPERIENCE UPDATE:
FEBRUARY-MARCH 1978 - CERTIFICATION «AS RECEIVED FROM THE EPA FOR THIS UNIT. THE BOILER AND
SCRUBBER-ABSORBER SYSTEM OPERATED THROUGHOUT THE PERIOD. THE UIILITY IS STILL HAVING SOME PROBLEMS
WITH THE SLURRY HANDLING SYSTEM, AND SOME FORCED OUTAGE TIME OCCURRED.
APBIL-MAY 197tt - NO INFORMATION WAS REPORTED BY THE UTILITY FOR THIS PERIOD.
61
-------
EPA UTILITY FGO SURVEY: APRIL 1470 - HAY 1976
SECTION 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL HH) SYSTEMS
UTILITY NAME TEXAS UTILITIES
UNIT NAME MONTICELLO 3
UNIT LOCATION Ml. PLEASANT TEXAS
UNIT RATING 750 MM
FUEL CHARACTERISTICS LIGNITE 1.5 PERCENT SULFUR
FGO VENDOK CHEMICO
PROCESS LIMESTONE
NEW OR RETROFIT NE"
START UP DATE 5/78
EFFICIENCY:
PARTICULATES (ACTUAL)
(DESIGN) 99.5 PERCENT
SOi (ACTUAL)
(DESIGN) 74.0 PERCENT
MATER MAKE UP CLOSED LOOP
SLUOCE DISPOSAL S I ABIL I ZED/ON-SITt DISPOSAL
OPERATING EXPERIENCE UPDATE:
APR. 76 THE TEXAS AIM CONTKOL BOARD REPORTED THAT THE TEXAS UTILITIES 750 MM MONTICELLU UNIT 3
MAY 76 BEGAN FGD OPERATIONS DURING THE REPORT PERIOD. AS OF YET THE UNIT HAS NOT RUN AT FULL LOAD
BUT IS EXPECTED TO BY THE END OF AUGUST.
-------
EPA UTILITY FGD SU»VEr: APRIL 1S78 - MAY 1978
SECTION 3
PERFORMANCE DESCRIPTION FUK UPtRATlUNAL FGl) SYSTEMb
UTILITY NAME UTAH PUwEW & LIGHT
UNIT NAME HUNTINGTON 1
UNIT LOCATION PHICE UTAH
UNIT RATING 415 MM
FUEL CHARACTERISTICS COAL 0.5 PERCENT SULFUR
FGD VENOOR CHEMICO
PROCESS LIME
NEW OR RETROFIT Nt"
START UP DATE 5/78
EFFICIENCY!
PARTICULATES (ACTUAL)
(DESIGN) 99.5 PERCENT
S02 (ACTUAL)
(DESIGN) 00.0 PERCENT
HATER MAKE UP CLOSED LOOP
SLUDGE DISPOSAL
OPERATING EXPERIENCE UPDATE:
APRIL-MAY 197B - INITIAL OPERATIONS BEGAN MAY 10 AT THIS PLANT. COMMERCIAL START-UP IS EXPECTED
SOMETIME IN JULY.
-------
EPA UTILITY FGO SURVEY: APRIL 1978 - HAY 1976
SECTION 4
SUMMARY OF FGU SYSTEMS BY COMPANY
UTILITY
ALABAMA ELECTRIC COOP
ALLEGHENY POWER SYSTEM
ARIZONA ELECTRIC POWER COOP
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC COUP
BASIN ELECTRIC PONER CUOP
BIG RIVERS ELECTRIC
BRAZOS ELECTRIC POWER COOP
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CINCINNATI GAS ft ELECTRIC
COLORADO UTE ELECTRIC ASSN.
COLUMBUS ft SOUTHERN OHIO ELEC.
COMMONWEALTH EDISON
COOPERATIVE PONER ASSOCIATION
UELMARVA POWER ft LIGHT
DUOUESNE LIGHT
EASTERN KENTUCKY POWER COUP
GENERAL PUBLIC UTILITIES
GULF POWER
HOOSIER ENERGY
INDIANAPOLIS POWER & LIGHT
KANSAS CITY POWER ft LIGHT
KANSAS POWER ft LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LOUISVILLE GAS ft ELECTRIC
MINNESOTA POWER ft LIGHT
MINNKOTA PONER COOPERATIVE
MONTANA POWER
NEVADA POWER
NEW ENGLAND ELEC SYSTEM
NIAGARA MOHANK POWER COOP
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
OTTER TAIL POWER
PACIFIC GAS AND ELECTRIC
PACIFIC POWER « LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
PUBLIC SERVICE OF INDIANA
PUBLIC SERVICE OF NEw MEXICO
SALT RIVER PROJECT
SIKESTON BUAHD OF MUNIC. UTIL.
SOUTH CAROLINA PUBLIC SERVICE
SOUTHERN ILLINOIS PONER COOP
SOUTHERN INDIANA GAS ft ELEC
SOUTHERN MISSISSIPPI ELECTRIC
SOUTHWESTERN ELECTRIC POWER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER LIGHT ft PftK
ST. JOE MINERALS CURH.
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER ft LIGHT
TEXAS UTILITIES
UTAH POWER ft LIGHT
WISCONSIN POWER ft LIUHI
TOTAL
NO MH
i
2
2
e
i
5
i
1
i
1
1
1
a
0
i
2
1
i
I
i
i
2
2
3
4
1
1
a
i
i
4
10
1
1
i
4
1
2
1
3
4
1
4
3
1
i.
2
1
2
1
1
1
1
4
1
3
6
i
1
4bO.
1250.
400.
26U4.
670.
26UO.
490.
400.
800.
575.
600.
600.
900.
1550.
425.
1090.
160.
920.
500.
1600.
20.
980.
1060.
1060.
1685.
64.
350.
2283.
500.
450.
2120.
3000.
650.
100.
705.
3140.
400.
1600.
509.
2475.
846.
650.
1560.
1050.
235.
580.
484.
250.
360.
720.
200.
190.
60.
1145.
400.
2045.
4672.
81S.
527.
OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
NO MW NO MW NO MW NO
0
0
0
2
0
0
0
0
0
0
0
0
0
2
0
0
0
2
0
0
0
0
i
3
2
1
0
3
0
1
2
3
0
0
1
2
0
0
0
2
1
0
1
0
0
1
0
0
0
0
1
0
0
3
0
0
2
1
0
0.
0.
0.
365.
0.
0.
0.
0.
0.
0.
0.
0.
0.
800.
0.
0.
0.
920.
0.
0.
0.
0.
530.
1060.
525.
64.
0.
426.
0.
450.
720.
375.
0.
0.
115.
1420.
0.
0.
0.
1650.
120.
0.
314.
0.
0.
280.
0.
0.
0.
0.
200.
0.
0.
570.
0.
0.
1543.
415.
0.
2
2
2
0
0
2
2
1
1
1
0
0
2
0
1
2
1
0
0
0
1
2
1
0
2
0
0
3
1
0
0
0
0
0
0
0
0
0
1
0
0
0
1
2
1
1
1
1
2
0
0
0
1
0
0
0
2
1
0
450.
1250.
400.
0.
0.
1140.
490.
400.
400.
575.
0.
0.
900.
0.
425.
1090.
180.
0.
0.
0.
20.
980.
530.
0.
1360.
0.
0.
1197.
SOO.
0.
0.
0.
0.
0.
0.
0.
0.
0.
509.
0.
0.
0.
306.
700.
235.
300.
184.
250.
360.
0.
0.
0.
60.
0.
0.
0.
1586.
400.
0.
0
0
0
1
1
0
0
0
0
0
0
1
0
0
0
0
0
0
1
0
0
0
0
0
0
0
1
0
0
0
2
0
0
1
0
2
1
0
0
1
0
0
1
0
0
0
0
0
0
1
0
1
0
1
1
1
1
0
0
0.
0.
0.
350.
670.
0.
0.
0.
0.
0.
0.
600.
0.
0.
0.
0.
0.
0.
500.
0.
0.
0.
0.
0.
0.
0.
350.
0.
0.
0.
1400.
0.
0.
100.
0.
1720.
400.
0.
0.
825.
0.
0.
466.
0.
0.
0.
0.
0.
0.
720.
0.
190.
0.
575.
400.
545.
793.
0.
0.
0
0
0
b
0
3
0
0
1
0
1
0
0
2
0
0
0
u
0
2
0
0
0
0
0
0
0
2
0
0
0
7
1
0
2
0
0
2
0
0
3
1
1
1
0
0
1
0
0
0
0
0
0
0
0
2
1
0
1
PLANNER
MN
0.
0.
0.
2089.
0.
1460.
0.
0.
400.
0.
600.
0.
0.
750.
0.
0.
0.
0.
0.
1600.
0.
0.
0.
0.
0.
0.
0.
660.
0.
0.
0.
2625.
650.
0.
590.
0.
0.
1600.
0.
0.
726.
650.
«72.
350.
0.
0.
300.
0.
0.
0.
0.
0.
0.
0.
0.
1500.
750.
0.
527.
TOTALS
138 58944. 37 12862. 43 17177. 19 10606. 39 18299.
NOTE - PLANNED SIATUS INCLUDES LETTER OF INTENT SIGNED, REOUESTING/EVALUTING BIDS,
AND CONSIDERING ONLY FGU SYSTEMS
64
-------
EPA UTILITY FGD SURVEY: APRIL 1978 - MAY 1978
StCIION 5
iUMMAkY UF Fiji) SYSIF.MS BY VENOUK
STATUS
TOTAL OPtWAUONAL CONSTRUCTION CONTKACT
AWAHDED
MANUFACTURER/PKOCFbS
AOL/COMBUSTION EQUIP ASbOCUTt
DOUBLE ALKALI
LIME/»LKALINt FLYASH
SODIUM CARBONATE
"TOTAL -
AIR CORRECTION DIVISION, UUP
LIME
LIME/LIMESTONE
LIMESTONE
SODIUM CARBONATE
TOTAL -
AIR CORRECTION DIVISON, UUP
LIMESTONE
TOTAL -
AMERICAN AIR FILTER
LIME
TOTAL -
ATOMICS INTERNATIONAL
AQUEOUS CARBONATE
TOTAL -
BABCOCK A WILCOX
LIME
LIMESTONE
TOTAL -
BUELL/ENVlROTtCH
DOUBLE ALKALI
TOTAL
BUREAU OF MINES
CITRATE
TOTAL
CHEMICO
LIME
LIME/LIMESTONE
LIMESTONE
TOTA
CHIYODA INTERNATIONAL
LIMESTONE
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTUNE/ALKALINE FLY ASH
LIMESTONE/ALKALINE FLYASH
TOTAL -
DAVY POWEKGAS
MELLMAN LORD
TOTAL -
DAVY POwEHGAS/ALLIED CHEMICAL
MELLMAN LORD
wtLLMAN LONG/ALLIED CHEMICAL
TOTAL -
NO.
1
5
3
9
d
1
2
1
b
I
1
b
b
1
1
3
7
IV
1
1
1
1
b
1
1
8
i
i
7
7
3
1
IB
i.
i
2
i
3
Mn
27/.
2b70.
37b.
3222.
800.
10.
S2u.
509.
2239.
425.
425.
Ib52.
Ib52.
10u.
100.
1050.
25b9.
4419.
575.
575.
60.
60.
3385.
10.
750.
4145.
20.
20.
2U/B.
3405.
2a30.
710.
8b23.
64B.
bUB.
020.
1 lb.
73-J.
Nil.
0
3
3
b
i
1
1
0
a
0
0
S
Z
0
0
0
2
2
0
0
0
0
5
1
1
7
0
0
a
i
1
1
8
0
0
1
1
2
MM
0.
1170.
3/b.
1-345.
800.
10.
200.
0.
1010.
0.
0.
242.
2«2.
0.
0.
0.
1100.
1100.
0.
0.
0.
0.
2985.
10.
7bO.
3745.
0.
0.
488.
525.
710.
710.
2433.
0.
0.
314.
115.
4«>9.
NO.
1
0
0
1
0
0
0
1
1
1
1
4
4
0
0
2
4
b
1
1
1
1
1
0
0
1
1
1
2
2
0
0
4
1
1
1
0
1
Mn
277.
0.
0.
27/.
0.
0.
0.
509.
509.
42b.
425.
1410.
1410.
0.
0.
1250.
1119.
23b9.
575.
575.
bO.
bO.
400.
0.
0.
400.
20.
20.
1090.
13bO.
0.
0.
2450.
180.
180.
30b.
0.
30b.
NO.
0
2
0
2
0
0
1
0
1
0
0
0
0
1
1
1
1
2
0
0
0
0
0
0
0
0
0
0
1
3
2
0
b
1
1
0
0
0
MN
0.
1400.
0.
1400.
0.
0.
720.
0.
720.
0.
0.
0.
0.
100.
100.
bOO.
350.
950.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
500.
1520.
1720.
0.
3740.
468.
468.
0.
0.
0.
b5
-------
EPA UTILITY F60 SORVEY: APRIL 1976 - MAY l«»7fl
StCUON 5
SUMMARY OF FbD STS1EMS HY VENDOR
TOTAL
MANUFACTURER/PROCESS
FMC CORPORATIUN
DOUBLE ALKALI
TOTAL -
MITSUBISHI
LIMESTONE
TOTAL -
MITSUBISHI INTERNATIONAL
LIMESTONE
TOTAL -
PEABOOY ENGINEERING
LIME/ALKALINE FLYASH
LIMESTONE
TOTAL -
PULLMAN KELLOGG
LIME
LIMESTONE
TOTAL -
RESEARCH COTTRELL
LIMESTONE
TOTAL -
RILEY STOKEH / ENVIRONEERING
LIMESTONE
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS / PECO
MAGNESIUM OXIDE
TOTAL -
UNIVERSAL OIL PRODUCTS
LIMESTONE
TOTAL -
MHEELABRATOR-FRYE/A.I.
AQUEOUS CARBONATE
TOTAL -
NO.
1
1
1
1
1
1
1
a
b
1
3
4
13
13
3
3
1
1
1
1
1
1
1
1
MM
250.
250.
490.
490.
490.
490.
bOO.
1350.
1850.
825.
1370.
2195.
6147.
6147.
760.
760.
550.
550.
120.
120.
530.
530.
400.
400.
OPERATIONAL
NO.
0
0
0
0
0
0
0
0
0
0
0
0
3
3
0
0
1
1
1
1
1
1
0
0
MW
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
1150.
1158.
0.
0.
550.
550.
120.
120.
530.
530.
0.
0.
CDNSTKUCTION
NO.
1
1
1
1
1
1
1
4
5
0
2
2
7
7
3
3
0
0
0
0
0
0
0
0
MM
250.
250.
49U.
490.
490.
49U.
500.
1350.
1850.
0.
700.
700.
3656.
3656.
760.
760.
0.
0.
0.
0.
0.
0.
0.
0.
CONTHACT
AMAHDED
NO.
0
0
0
0
0
0
0
0
0
1
1
2
3
3
0
0
0
0
0
0
0
0
1
1
MW
0.
0.
o.
0.
0.
0.
0.
0.
0.
825.
670.
1495.
1333.
1333.
0.
0.
0.
0.
0.
0.
0.
0.
400.
400.
99 40645.
37 12862.
43 17177.
19 10606.
66
-------
EHA UTILITY n,\, buwvtr: APRIL ls7» - MAY 1978
StCTIUN fa
VIKMARY OF Nt* AND WE TMOF I T FGU SYbTfcMS rtY PROCESS
NtW OK OPERATIONAL CUNSTkUC 1 ION
PROCESS RETROFIT
LIME
LIME/ALKALINE FLYASH
LIME/LIMESTONE
LIMESTONE
LIMESTONE/ALKALINE FLY ASH
LIMESTONE/ALKALINE FLYASH
SUBTOTAL - LIME/LIMESTONE
AQUEOUS CARBONATE
CITRATE
DOUBLE ALKALI
MAGNESIUM OXIDE
NOT SELECTED
SODIUM CARBONATE
WELLMAN LORD
NELLMAN LORD/ALLIED CHEMICAL
TOTALS
LIME/LIMESTONE X OF TOTAL MW
M
R
N
k
N
R
N
k
N
R
N
H
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
R
N
k
NO
5
8
3
0
u
-------
EP» UTILITY F60 SURVEY! APRIL 1976 - MAY 1978
SECTION 7
SUMMANY OF OPERATING FGO SYSTEMS BY
PROCESS AND GENERATING UNITS
PROCESS/GENERATING UNITS FGO/Mn STARTUP EXPERIENCE(MO.)
LIME
BRUCE MANSFIELD 1 825 4-76 25
BRUCE MANSFIELD 2 825 7-77 10
CANE RUN a 178 B-7b 21
CANE RUN 5 103 12-77 5
CONESVILLE 5 400 1-77 16
CONESVILLE 6 400 4-78 1
ELRAMA POMER STATION 510 10-75 31
GREEN RIVER 1.2 S3 64 9-75 32
HAWTHORN 3 140 11-72 66
HAHTHORN 4 100 8-72 69
HUNTINGTON 1 415 5-78 0
PADDYS RUN 6 65 4-73 61
PHILLIPS POMER STATION 410 7-73 58
4515. 395
LIME/ALKALINE FLYASH
COLSTRIP 1 360 11-75 30
COLSTRIP 2 360 87-60 134
MILTON R. YOUNG 2 4bO 9-77 0
1170. 172
LIME/LIMESTONE
SHANNEE 10A 10 4-72 73
SHANNEE 10B 10 4-72 73
20. 146
LIMESTONE
CHOLLA 1 115 10-73 55
CHOLLA 2 250 6-78 0
LA CY6NE 1 820 2-73 63
LAURENCE 4 125 12-68 113
LAURENCE 5 400 11-71 78
MARTIN LAKE 1 793 8-77 9
MONTICELLO 3 750 5-78 0
PETERSBURG 3 530 10-77 7
SOUTHWEST 1 200 4-77 13
WIDOWS CREEK 8 550 5-77 12
NINYAH 2 280 7-77 10
4813. 360
LIMESTONE/ALKALINE FLY ASH
SHERBURNE 2 710 4-77 13
710. 13
LIMESTONE/ALKALINE FLYASH
SHERBUMNE 1 710 3-76 26
710. 26
MAGNESIUM OXIDE
EDDYSTONE 1A 120 9-75 32
120. 32
SOUIUM CARBONATE
HEIO GARDNER 1 125 4-74 49
-------
EPA UTILITY FGD SURVEY: APRIL 1978 - MAY 1978
SECTION 7
SUMMAKY Oh OPERATING FGU SYS.UMS BY
PROCESS AND C-fcNtHATING UNITS
PHOCESS/bENEKAlING UNllS
REID GAUONtW
REID
STAKTUP EXPER IENCECMO.J
4-74
7-7b
19
Zi.
HELLMAN LUWD
SAN JUAN 1
311
511.
1-78
-------
EP» UTILITY FGD SURVEY: AHML 197» - M»T 1979
SECTION M
SUMMARY OF SLUDGE DISPOSAL HRACMChb KJH OPERATIONAL Flit) SYSTEMS
PROCESS/GENERATING ONII --SLUDbE-- --SLUOGfc-- -PONU ...p(jM0...
MAIlLIZtD UNSTA6ILI7tO LlNEU UNLINED
LIME
BRUCE MANSFIELD 1 825
BRUCE MANSFIELD 2 825
CANE RUN 4 1/6 176
CANE RUN 5 Id? 183
CONESVILLE 5 4UO 400
CONESVILLE 6 "00 400
ELRAMA PUWER STATION 510 510
GREEN RIVER 1,2 ft 3 64 64
HAWTHORN 3 14U 140
HAWTHORN 4 100 100
HUNTINGTON 1 415 415
PADDYS RUN 6 65 65
PHILLIPS POWER STATION 410 410
TOTAL 4211. 304. 0. 2865.
LIME/ALKALINE FLYASH
COLSTRIP 1 360 360
COLSTRIP 2 360 360
MILTON R. YOUNG 2 450
TOTAL 0. 1170. 360. 360.
LIMESTONE
CHOLLA 1 115 US
CHOLLA 2 250 250
LA CYGNE 1 8(fO 820
LAWRENCE 4 125 125
LAWRENCE 5 400 400
MARTIN LAKE 1 793 793
MONTICELLO 3 7bO 750
PETERSBURG 3 530 530
WIDOWS CREEK 8 550 550
WlNYAH 2 2ttO 280
TOTAL 2073. 2540. 1543. 3070.
LIMESTONE/ALKALINE FLY ASH
SHERBURNE 2 710 710
TOTAL 0. 710. 710. 0.
LIMESTONE/ALKALINE FLYASH
SHERBURNE 1 710 710
TOTAL 0. 710. 710. 0.
SODIUM CARBONATE
REID GARDNER 1 125
REID GARDNER 2 125
REID GARDNER 3 125
TOTAL 0. 3/5. 0. 0.
70
-------
EPA iMlLITT F&O SORVtY: APWR 197tt - MAY 1978
SECTION 9
SUMMARY OF FbO SYSTEMS BY HROCtSb ANU KE&ULATOKY CLASS
REGOLATuRY OPERATIONAL
PROCESS CLASS
LIMt
LIME/ALKALINE FLYASH
LIME/LIMESTONE
LIMESTONE
LIMESTONE/ALKALINE FLY ASH
LIMESTONE/ALKALINE FLYASH
SUBTOTAL - LIME/LIMESTONE
AQUEOUS CARBONATE
CITRATE
DOUBLE ALKALI
MAGNESIUM OXIDE
A
b
C
0
E
A
b
C
0
E
A
B
C
u
t
A
b
C
0
fc
A
b
C
o
E
A
b
C
0
b
A
b
C
0
t
A
b
C
0
t
A
b
C
0
E
A
b
C
0
E
A
b
C
U
E
NO.
1
10
2
U
0
2
1
0
0
0
0
0
2
0
0
5
4
2
0
0
0
1
0
0
0
0
1
0
0
0
8.
17.
b.
0.
0.
0
0
0
0
0
0
0
0
0
u
0
0
0
0
0
0
1
0
0
0
Mn
415
3971
129
0
0
720
450
u
U
U
u
u
2U
0
0
2554
690
1470
0
0
0
710
0
0
0
U
710
0
0
0
368B.
6731.
1519.
0.
0.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
120
0
u
0
CUNbTKUC T ION
NO.
7
t
0
0
0
1
0
0
0
0
0
u
0
0
0
la
10
2
0
0
0
0
0
0
0
0
0
0
0
0
22.
12.
2.
0.
0.
0
0
0
0
0
0
1
0
0
0
i.
1
0
0
0
0
0
0
u
0
Mn
i
-------
EPA UTILITY FGD SURVEY: APRIL 197» - MAY 19/a
SbCIION 9
SUMMARY OF FbO SYSTEMS BY PROCESS AND REGULATORY CLASS
REGULATORY OPERATIONAL
CONSTRUCTION
PKOCESS CLASS
NOT SELECTED
SODIUM CARBONATE
MELLMAN LORD
MELLMAN LORD/ALLIED CHEMICAL
TOTALS
LIME/STONE X OF TOTAL MW
A
B
L
0
E
A
U
C
0
fc
A
B
C
0
E
A
B
C
0
E
A
B
C
0
E
A
B
C
D
E
NO
0
0
0
0
0
3
0
0
0
0
0
1
0
0
0
0
0
1
0
0
11
19
7
0
0
. Mn
0
u
u
u
u
375
U
U
U
u
u
314
0
0
U
U
U
lib
U
0
. 1063.
. 7165.
. 1634.
0.
0.
91
94
93
U
U
NO
0
0
U
0
0
U
1
0
u
0
0
1
1
0
u
u
0
0
0
0
24
16
$
0
o
MN
U
U
U
U
0
0
509
0
U
0
0
306
180
U
U
U
U
0
U
U
. 9980.
. 6572.
. 625.
0.
0.
92
82
71
0
0
CONTRACT
PLANNED
AWARDED
NO.
U
U
0
0
0
U
0
0
0
0
0
1
0
0
0
0
u
u
0
0
9.
8.
2.
0.
0.
MM
0
U
0
0
0
0
0
0
0
0
0
468
0
U
0
0
0
0
0
0
4768.
5163.
675.
0.
0.
100
83
85
0
0
NO.
12
6
3
0
0
1
0
0
0
0
0
1
0
0
0
0
0
0
0
0
17.
19.
3.
0.
0.
MN
6400
3265
1240
0
0
125
0
U
U
0
0
472
0
0
0
0
0
0
0
0
8952.
8107.
1240.
0.
0.
27
45
0
0
0
TOTAL NO.
PLANTS
NO.
12
6
3
0
0
4
1
0
0
u
0
4
1
0
0
0
0
1
0
0
61.
62.
15.
0.
0.
MM
6400
3265
1240
0
0
500
509
0
U
0
0
1560
180
0
0
0
0
115
0
0
27763.
27007.
4174.
0.
0.
72
74
61
0
0
A. BOILER CONSTRUCTED SUBJtCI TO FbOERAL NSPS
B. BOILER SUBJECT 10 STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
C. BOILER SUBJECT 10 STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
0. OTHER
E. REGULATUHY CLASS UNKNOnN
72
-------
EPA UTILITY FGO SURVEY: APRIL 1978 - MAY 1978
SECTION 10
SUMMARY OF FGU SYSTEMS UNDER CONSTRUCTION
UTILITY COMPANY
POWER STATION
ALABAMA ELECTRIC COUP
TOMBIGBEE 2
ALABAMA ELECTRIC COOP
TOMBIGBEE 3
ALLEGHENY POWER SYSTEM
PLEASANTS 1
ALLEGHENY POWER SYSTEM
PLEASANTS 2
ARIZONA ELECTRIC POWER CUUI-
APACHE 2
ARIZONA ELECTRIC POWEH COUP
APACHE 3
BASIN ELECTRIC POwiR CUOP
LARAMIE RIVER 1
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 2
BIG RIVERS ELECTRIC
REID 2
BIG RIVERS ELECTRIC
REID 3
BRAZOS ELECTRIC POWER COUP
SAN MIGUEL 1
CENTRAL ILLINOIS LIGHT
OUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
COLORADO UTE ELECTRIC ASSN.
CRAIG :
COLORADO UTE ELECTRIC ASSN.
CRAIG 2
COMMONWEALTH EDISON
POWCR70N 51
COOPERATIVE POnER ASSOCIATION
CO..L CREEK 1
COOPERATIVE POWER ASSOCIATION
COAL CHEEK 2
DELMARVA POWER ft LIGHT
OELMARE CITY 1, £ ft 1
GULF POWER -
SCHOL£ NOS. IB ft 2b
HOOSIER ENERGY
MEROM 1
HOOSIER ENERGY
MEROM 2
INDIANAPOLIS POWER & LIGHT
PETERSBURG a
NEN UR
RETRUF IT
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
k
N
N
K
K
N
N
N
SUE OF FGU
UNIT (Mw)
225
225
625
6«!5
200
200
5/0
570
250
240
100
aoo
575
-------
EPA UTILITY FGO SURVEY: APRIL 1976 - MAY 1478
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
UTILITY COMPANY
POWER STATION
KANSAS POWER * LIGHT
JEFFEREY 1
KANSAS POKER ft LIGHT
JEFFEREY 2
LOUISVILLE GAS ft ELECTHIC
CANE RUN f>
LOUISVILLE GAS ft ELECTRIC
MILL CREEK 3
LOUISVILLE GAS ft ELECTRIC
MILL CREEK 4
MINNESOTA PONER ft LIGHT
CLAY BOSNELL a
PACIFIC POMER ft LIGHT
JIM BRIDGER a
PUBLIC SERVICE OF NEK MEXICO
SAN JUAN 2
SALT RIVER PROJECT
CORONAOO 1
SALT RIVER PROJECT
CORONADO 2
SIKESTON BOARD OF MUNIC. UTIL.
SIKESTON POWER STATION
SOUTH CAROLINA PUBLIC SERVICE
NINYAH 3
SOUTHERN ILLINOIS POwER COOP
MARION 4
SOUTHERN INDIANA GAS ft ELEC
A. B. BRONN 1
SOUTHERN MISSISSIPPI ELECTRIC
R. D. MORKOH 1
SOUTHERN MISSISSIPPI ELECTRIC
R. 0. MORROW 2
ST. JOE MINERALS CORP.
G. F. NEATON 1
TEXAS UTILITIES
MARTIN LAKE 2
TEXAS UTILITIES
MARTIN LAKE 3
UTAH PONER ft LIGHT
EMERY 1
NEW OR
RETROFIT
N
N
h
K
N
N
N
R
N
N
N
N
N
N
N
N
R
N
N
N
SIZE OF FGU
UNIT (MM)
600
bbO
877
425
495
500
509
306
350
350
235
3UO
180
250
180
180
60
793
793
400
PROCESS/VENDOR
STAKT-UP
DATE
COMBUSTION ENGINtEMING 6/78
LIMESTONfc
COMBUSTION ENGINEERING 6/so
LIMESTONE
ADL/COMBUSriUN EUU1P ASSOCIATE 12/76
DOUBLE ALKALI
AMERICAN AIR FILTER 7/76
LIME
AMERICAN AIR F1LTEH 6/80
LIME
PEABODV ENGINEERING 5/80
LIME/ALKALINE FLVASH
AIH CORRECTION DIVISION, UOP 9/79
SODIUM CARBONATE
DAVY POWERGAS/ALLIED CHEMICAL 7/78
WELLMAN LORD
PULLMAN KELLOGG 4/79
LIMESTONE
PULLMAN KELLUGb 4/60
LIMESTONE
BABCOCK ft NILCOX 6/81
LIMESTONE
BABCOCK ft WILCOX 5/80
LIMESTONE
BABCOCK ft NILCOX 6/76
LIMESTONE
FMC CORPORATION 4/79
DOUBLE ALKALI
RILEY STOKER / ENVIRONEERING 8/76
LIMESTONE
RILEY STOKER / ENVIRONEERING 10/78
LIMESTONE
BUREAU OF MINES 10/78
CITRATE
RESEARCH COTTRELL 5/76
LIMESTONE
RESEARCH COTTRELL 12/76
LIMESTONE
CHEMICO 12/78
LIME
74
-------
EPA UTILIH FGO SURVEY: APHR
- MAT
SECTION 11
SUMMARY OF PLANNED FGD
UTILITY COMPANY
POWER STATION
CONTRACTS AWARDED
ARIZONA PUBLIC SERVICE
CHOLLA 4
ASSOCIATED ELECTRIC COOP
THOMAS HILL 3
CINCINNATI GAS ft ELECTRIC
EAST BEND Z
EASTERN KENTUCKY POMER COOP
SPURLOCK a
LAKELAND UTILITIES
MCINTOSH 3
MONTANA POMER
COLSTRIP 3
MONTANA POWER
COLSTRIP 4
NIAGARA MOHAWK POWER COOP
CHARLES R. HONTLEY b
NORTHERN STATES POWER
SHERBURNE 3
NORTHERN STATES POWER
SHERBURNE 4
OTTER TAIL POWER
COYOTE \
PENNSYLVANIA POWER
BRUCE MANSFIELD &
PUBLIC SERVICE Of NEW MEXICO
SAN JUAN 3
SOUTHWESTERN ELECTRIC POWER
HENRY W. PERKEY 1
SPRINGFIELD WATER LIGHT & PwR
DALLMAN 3
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
TEXAS POWER » LIGHT
SANOOM 4
TEXAS UTILITIES
MARTIN LAKE 4
NEn OR
RETROFI T
N
N
N
N
N
N
fc
N
N
N
N
fc
N
K
N
N
N
SUE Df- 1-GD
UNIT IMft)
350
670
600
500
3bO
700
700
100
860
860
400
825
468
190
575
«u.
545
793
VtNDUR/PRUCESS
STAKT-UP
DATE
RESEARCH CUTTRELL
LIMt. STONE
PULLMAN HELLOGG
LIMESTONE
UABCUCK & NlLCOX
LIME
COMBUSTION ENGINEERING
LIME
dABCUCK & NILCUX
LIMESTONE
ADL/COMBUSTION EUUIP ASSOCIATE
LIME/ALKALINE FLYASH
AOL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALINt FLYASH
ATOMICS INTERNATIONAL
AUUEOUS CARBONATE
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLY ASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLY ASH
WHEELABRATOR-FRVE/A.I.
AQUEOUS CARBONATE
PULLMAN KELLOGG
LIME
DAVY POwERGAS
nELL'IAN LORD
AIR CORRECTION DIVISION, UUP
LIMESTONE
RESEARCH COTTRELL
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH COTIRELL
LIMESTONE
6/80
o/ei
1/81
3/su
10/81
7/80
7/81
0/80
5/81
5/83
5/81
4/80
1/81
6/83
7/80
u/ o
i/8£
7/so
LETTER OF INTENT SIGNED
NEVADA POWER
REID GARDNER 4
PHILADELPHIA ELECTRIC
EDDYSTONE IB
WISCONSIN POWER ft LIGHT
COLUMBIA 2
125 ADL/COMBUStION EUUIP ASSOCIATE O/ 0
SODIUM CARBONATE
240 UNITED ENGINEERS / PECO 6/8U
MAGNESIUM OXIOE
527 CHEMICU 1/80
LIME/ALKALINE FLYASH
75
-------
EPA UTILITY F60 SURVEY! APRIL 1976 - MAY 1978
UTILITY COMPANY
POMER STATION
SECTION 11
SUMMARY OF PLANNED FGD SYSTEMS
NEW OR SIZE OF F6D VENDOR/PROCESS
RETROFIT UNIT (MM)
START-UP
DATE
REQUESTING/EVALUATING BIDS
N
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 1
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
055
400
NOT SELECTED
LIME
NOT SELECTED
LIMESTONE
11/81
i/82
CONSIDERING FGD SYSTEM
ARIZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZONA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
ARIZONA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 2
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 3
CENTRAL MAINE POMER
SEARS ISLAND 1
COLUMBUS SOUTHERN OHIO ELEC.
POSTON 5
COLUMBUS ft SOUTHERN OHIO ELEC.
POSTON b
GENERAL PUBLIC UTILITIES
COHO 1
GENERAL PUBLIC UTILITIES
SEMARD 7
LOUISVILLE GAS ft ELECTRIC
MILL CREEK 1
LOUISVILLE GAS ft ELECTRIC
MILL CREEK 2
NEVADA POWER
HARRY ALLEN 1
NEVADA POMER
HARRY ALLEN 2
NEVADA POWER
HARRY ALLEN 3
NEVADA POMEH
HARRY ALLEN 4
NEVADA POWER
WARNER VALLEY 1
NEVADA POWER
WARNER VALLEY I
175 CHEMICO/APS
LIME/ALKALINE FLVASH
175 CHEMICO/APS
LIME/ALKALINE FLYASH
229 CHEMICO/APS
LIME/ALKALINE FLYASH
755 NOT SELECTED
NOT SELECTED
755 NOT SELECTED
NOT SELECTED
455 NOT SELECTED
NOT SELECTED
550 NOT SELECTED
NOT SELECTED
600 NOT SELECTED
NOT SELECTED
375 NOT SELECTED
NOT SELECTED
375 NOT SELECTED
NOT SELECTED
BOO NOT SELECTED
NOT SELECTED
800 NOT SELECTED
NOT SELECTED
330 NOT SELECTED
LIME
330 NOT SELECTED
LIME
500 NOT SELECTED
NOT SELECTED
500 NOT SELECTED
NOT SELECTED
500 NOT SELECTED
NOT SELECTED
500 NOT SELECTED
NOT SELECTED
250 NOT SELECTED
NOT SELECTED
250 NOT SELECTED
NOT SELECTED
O/ 0
O/ 0
O/ 0
O/ 0
O/ 0
11/63
4/82
11/66
0/83
0/85
5/87
5/84
1/82
1/81
6/63
6/84
6/85
6/66
6/62
6/63
76
-------
EPA UTILITY FGD SURVEY! APRIL 1978 - MAY '.978
SECTION 11
OF PLANNED tr,o
UTILITY COMPANY
POHEH STATION
NEW ENGLAND ELEC SYSTEM
BRAYTON POINT 3
NORTHERN INDIANA PUB SERVICE
BAILLY 7
NORTHERN INDIANA PUB SERVICE
BARLY 6
PACIFIC GAS AND ELECTRIC
FOSSIL 1
PACIFIC GAS AND ELECTRIC
FOSSIL 2
PHILADELPHIA ELECTRIC
CROMBY
PHILADELPHIA ELECTRIC
EODYSTONE 2
PUBLIC SERVICE OF INDIANA
GIBSON 5
PUBLIC SERVICE OF NEw MEXICO
SAN JUAN 4
SALT RIVER PROJECT
CORONADO 3
SOUTHERN ILLINOIS POHEH COOP
MARION 5
TEIAS POWER ft LIGHT
TWIN OAKS 1
TEXAS POWER ft LIGHT
TWIN OAKS 2
TEXAS UTILITIES ,
FOREST GROVE 1
NEW OK
RETROFIT
OF FGU
UNIT (MM)
650
VENUOW/PWOCtSS
NOT SELECTED
NOT SELECTED
190 N01 SELECTED
NOT SELECTED
-------
EPA UTILITT FGD SURVEY: APRIL 1970 - KAY 1970
SECTION 13
TOTAL FGO MEGAWATT CAPACITY BY YEAH
YEAR NO. UNITS MEGAWATTS
I960
I960
1971
1972
1973
1974
1975
1976
1977
1976
1979
I960
1981
1962
1963
1964
1905
1966
1967
UNDEFINED
1
1
1
4
4
2
4
5
10
20
13
23
12
9
7
5
3
2
2
10
360
125
400
260
1410
250
1054
1953
4921
7252
5399
9663
6306
4375
391«
3150
1675
11*1
1150
4029
TOTALS DISPLAYED DO NOT INCLUDE TERMINATED OR INACTIVE SYSTEMS.
76
-------
APPENDIX A
FGD SYSTEMS ECONOMICS
A-l
-------
INTRODUCTION
The cost of flue gas desulfurization (FGD) systems for the
control of sulfur dioxide emissions is an area of intense inter-
est and substantial controversy. As a result, many computer
models have recently been developed to estimate capital and
annual costs. As part of an effort by the U.S. Environmental
Protection Agency to provide meaningful economic data concerning
FGD systems, reported economic data have been incorporated into
the EPA Utility FGD Survey report. This information has appeared
as a separate appendix of the report since October 1976. Until
January 1978, this cost appendix consisted entirely of data
reported by the utilities with little or no interpretation pro-
vided by PEDCo Environmental, Inc. Beginning with the May 1978
report, the format and content of the cost appendix were revised
to include reported and adjusted costs for the operational FGD
systems.
The rationale for including adjusted as well as reported
costs stems primarily from the lack of comparability of the
reported costs. Many of the reported cost figures, both capital
and operating, are largely site-sensitive values that cannot be
accurately compared because they refer to different FGD battery
limits and different years in which the expenditures were made.
As a result, an analysis of the cost data was made for the opera-
tional units since these systems offer the potential of having
complete and accurate economic data. The adjustments were made
to provide comparable, accurate cost data for the sulfur dioxide
portion of the emission control system. This, in effect, will
eliminate much of the confusion that exists concerning the re-
ported data, and it will provide a common basis for the reported
costs.
A-2
-------
APPROACH
In March 1978, each utility having at least one operational
FGD system was given a cost form containing all available cost
information then in the PEDCo files. The utility was asked to
verify the data and fill in any missing information called for
on the form. A follow-up visit by the PEDCo Environmental staff
was arranged to assist in data acquisition and to insure com-
pleteness and reliability of information. Results of the cost
analysis were forwarded to each participating utility for final
review and comment.
The cost data were treated solely to establish the accurate
costs for FGD systems, on a common basis/ not to critique the
design or reasonableness of the costs reported by any utility.
Adjustments focused primarily on the following items:
0 All capital costs were adjusted to July 1, 1977, dol-
lars using the Chemical Engineering Index. All capital
costs, represented in dollars/kilowatt ($/kW), were
expressed in terms of gross megawatts (MW). Actual
costs were reported by utilities in dollar values for
years 1970 to 1980. These values are represented in
terms of the year of greatest capital expenditures.
0 Gross unit capacity was used to express all FGD capital
expenditures because the capital requirement of an FGD
system is dependent on actual boiler size before de-
rating for auxiliary and air quality control power
requirements.
0 Particulate control costs were deducted. Since the
purpose of the study was to estimate the incremental
cost for sul*1:.' dioxide control, ^articulate control
costs were deducted using either data contained in the
cost breakdowns or as a percentage of the total direct
cost (capital and annual). The percentage reduction
varied depending upon system design and operation.
A-3
-------
The capital costs associated with the modification or
installation of equipment not part of the FGD system
but needed for its proper functioning, were included
(e.g. - stack lining, modification to existing ductwork
or fans, etc.).
Indirect charges were adjusted to provide adequate
funds for engineering, field expenses, legal expenses/
insurance, interest during construction, allowance for
startup, taxes, and contingency.
All annual costs, represented in mills/kilowatt-hour
(mills/kWh), were expressed in terms of net megawatts
(MW).
Net unit capacity was used to express all FGD annual
expenditures because the annual cost requirement of an
FGD system is dependent on the actual amount of kilo-
watt-hours (kWh) produced by the unit after derating
for auxiliary and air quality control power require-
ments .
All annual costs were adjusted to a common capacity
factor (65 percent).
Replacement power costs were not included since only a
few utilities reported such costs and these were pre-
sented using a variety of methods.
Sludge disposal costs were adjusted to reflect the
costs of sulfur dioxide waste disposal only (i.e.,
excluding fly ash disposal) and to provide for disposal
over the anticipated lifetime of the FGD system. This
latter correction was necessary since several utilities
reported costs for sludge disposal capacity that would
last only a fraction of the FGD system life. The
adjustments were based on a land cost of $2000/acre
with a sludge depth of 50 ft in a clay-lined pond (clay
is assumed to be available at the site).
A 30-year life was assumed for all process and economic
considerations for all new systems that were installed
for the life of the unit. A 20-year life was assumed
for all process and economic considerations for retro-
A-4
-------
fit systems that were installed for the remaining por-
tion of the life of the unit.*
0 Regeneration and by-product recovery facility costs
were added for those regenerable systems not reporting
such costs.
To the extent possible, all cost adjustments were made using
the previous assumptions developed by PEDCo Environmental. When
cost data were inadequate, adjustments were made using process
design data in conjunction with the previous cost assumptions.
In some cases, no adjustments were possible because of in-
sufficient data.
* The use of a 30-year service life for new u.^its coincides with
the conclusion of the National Power Survey DJ. the Federal
Power Commission which recognized this value as reasonable for
steam-electric plants. A 20-year service life was assumed for
all retrofit units even if the remaining life of the units is
less than this value. Thus, two different rates are used and
should be noted when making comparisons between new and retro-
fit systems.
A-5
-------
DESCRIPTION OF COST ELEMENTS
Capital costs consist of direct costs, indirect costs, con-
tingency costs, and other capital costs. Direct costs include
the "bought-out" cost of the equipment, the cost of installation,
and site development. Indirect costs include interest during
construction, contractor's fees and expenses, engineering, legal
expenses, taxes, insurance, allowance for start-up and shake-
down, and spares. Contingency costs include those costs result-
ing from malfunctions, equipment alterations, and similar un-
foreseen sources. Other capital costs include the nondepreciable
items of land and working capital.
Annual costs consist of direct costs, fixed costs, and over-
head costs. Direct costs include the cost of raw materials,
utilities, operating labor and supervision, and maintenance and
repairs. Fixed costs include those of depreciation, interim
replacement, insurance, taxes, and interest on borrowed capital.
Overhead costs include those of plant and payroll expenses. The
various capital and annual cost components are discussed and
defined in greater detail in the following paragraphs.
The direct capital costs include the following elements:
0 Equipment required for the FGD system. Table A-l
provides a summary of the major process equipment used
in regenerable and nonregenerable systems.
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.
* Site development may include clearing and grading,
construction of access roads and walkways, establish-
ment of rail, barge, and/or truck facilities, and
parking facilities.
A-6
-------
TABLE A-l. MAJOR FGD SYSTEM EQUIPMENT SUMMARY
Category
Description
Material handling-
raw materials
Feed preparation-
raw materials
Sulfur dioxide
absorption
Flue gas reheat
Gas handling
Sludge disposal
Utilities
By-product
handling
Equipment for the handling and transfer of
raw materials includes unloading facilities,
conveyors, storage areas and silos, vibrators,
atmospheric emission control associated with
these facilities, and related accessories.
Equipment for the preparation of raw material
to produce a feed slurry consists of feed
weighers, crushers, grinders, classifiers,
ball mills, mixing tanks, pumps, agitators,
and related accessories.
Equipment for treating the flue gas includes
absorbers, mist eliminators, hold tanks,
agitators, circulating pumps, pond water re-
turn pumps, and related accessories.
Equipment required includes air, steam, or
hot water heaters, condensate tanks, pumps,
soot blowers, fans, fuel storage facilities,
gas bypass equipment, and related accessories.
Equipment to handle the boiler flue gas in-
cludes booster fans, ductwork, flue gas by-
pass system, turning vanes, supports, plat-
forms, and related accessories.
Nonregenerable FGD systems require solids/
water separation equipment such as clarifiers,
vacuum filters, centrifuges, sludge fixation
equipment, and related accessories.
Equipment to supply power and water to the
FGD equipment consists of switch-gear, break-
ers, transformers, piping, and related
accessories.
Equipment for processing the by-product of
regenerable F^D systems may include a rotary
kiln, fluid bed dryer, conveyor, storage silo,
vibrator, combustion equipment and oil stor-
age tanks, waste heat oilers, hammer mills,
evaporators, crystallizers, strippers, tanks,
agitators, pumps, compressors, sulfuric acid
absorber and cooling, mist eliminator, pumps,
acid coolers, tanks, etc.
(continued)
A-7
-------
TABLE A-l. (continued)
Category
Description
Regeneration
Purge treatment
Auxiliary
Equipment for regeneration of the absorbing
medium of an FGD system may consist of re-
actor vessels, material handling system,
storage, weigh feeder, conveyor, rotary kiln,
fluid bed calciner, dust collector, storage
silo, vibrator, combustion equipment and oil
storage tanks, waste heat boiler, hammer
mill, evaporators, crystallizers, strippers,
tanks, agitators, pumps, compressors, sul-
furic acid absorber and cooling, mist elimi-
nator, pumps, acid coolers, tanks, etc.
Equipment for the removal of purge material
(e.g. sodium sulfate) includes refrigeration,
pumps, tanks, crystallizer, centrifuge,
dryer.- dust collector, conveyors, storage,
and related equipment.
Equipment not directly related to the
FGD system, but which may require design or
modification to accommodate an FGD system
may include such items as existing fans,
ducts, or stack. If new fans, ducts, or
stacks are added to improve boiler perfor-
mance and accommodate the FGD systen, the
costs are prorated to the boiler and FGD
system.
A-8
-------
Indirect capital costs include the following elements:
e 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 syscem start-up.
° Spare parts including pumps, valves, controls, special
piping and fittings, instruments, spray nozzles, and
similar items.
Other capital costs include the following elements:
0 Land required for the FGD process, waste disposal, re-
generation facility, and storage.
0 Working capital, including the total amount of money
invested in raw materials and supplies in stock,
finished products in stock, and unfinished products
A-9
-------
in the process of being manufactured; accounts re-
ceivable; cash kept on hand for payment of operating
expenses such as salaries, wages, and raw materials
purchases; accounts payable; and taxes payable.
Annual cost of an FGD system includes the following direct,
fixed and overhead charges:
* 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-10
-------
Taxes, including franchise, excise, and property taxes
levied by a city, county, state, or Federal government.
Interest on borrowed funds.
0 Overhead
Plant and administrative overhead is a business expense
that is not charged directly to a particular part of a
project, but is allocated to it. Overhead costs in-
clude administrative, safety, engineering, legal and
medical services; payroll; employee benefits; recrea-
tion; and public relations.
Table A-2 provides a summary of the means used to determine
the missing cost elements if the costs were not reported or
insufficient information prevented their actual determination.
The assumptions and cost bases for determining the capital and
annual costs of FGD systems were developed by the PEDCo staff
based upon previous economic studies conducted for the U.S. EPA
(Flue Gas Desulfurization Process Cost Assessment, May 1975;
Simplified Procedures for Estimating Flue Gas Desulfurization
System Costs, June 1976, EPA-600/2-76-150; Particulate and Sulfur
Dioxide Emission Control Costs for Large Coal-Fired Boilers,
March 1978, EPA-600/7-78-032).
A-ll
-------
TABLE A-2. COST ELEMENT FACTORS
Category
Value
Indirect capital costs:
Interest during
construction
Field overhead
Contractor's fee and
expenses
Engineering
Taxes
Spares
Shakedown allowance
Other capital costs:
Contingency3
Direct annual costs:
Raw materials:
Fixation chemicals
Lime
Limestone
Magnesium oxide
Sodium carbonate
Salt cake (credit)
Sulfur (credit)
Sulfuric acid (credit)
Utilities:
Electricity
Water
Steam
Operating labor:
Direct labor
Supervision
10% of total direct capital costs
10% of total direct capital costs
5% of total direct capital costs
10% of total direct capital costs
2% of total direct capital costs
1% of total direct capital costs
5% of total direct capital costs
20% of total direct and indirect
capital costs
$2/ton
$40/ton
$10/ton
$150/ton
$80/ton
$50/ton
$65/ton
$25/ton
25 millsAWh
$0.20/103 gal
$0.BO/106 Btu
$ 8.50/man-hour
15% of direct labor costs
Contingency costs are used only when the cost data supplied are
incomplete (such as equipment costs or direct costs only) and a
contingency cost must be factored in to give an accurate estimate
of the total capital cost.
(continued) A-12
-------
TABLE A-2. (continued)
Category
Value
Maintenance:
Labor and materials
Supplies
Overhead:
Plant
Payroll
Fixed annual costs:
Depreciation
Interim replacement
Taxes
Insurance
Capital costs
4% of total direct capital costs
15% of labor and materials costs
50% of operation and maintenance costs
20% of operating labor costs
3.33% or 5% (new or retrofit)
0.7% or 0.35%
4%
0.3%
9%
Some system components have life spans less than the expected
service life of the system. Interim replacement is an allow-
ance factor used in estimating annual revenue requirements to
provide for the replacement of these short-lived items. An
average allowance of 0.35% of the total investment is normally
provided and used for systems with an expected service life of
20 years or less. A higher allowance of 0.70% of the total
investment is provided and used for systems with an expected
service life of 30 years or more.
A-13
-------
DEFINITION OF COST ELEMENTS
The costs displayed in Appendix A are accompanied by a
series of alphabetic characters summarizing data presented for
each FGD system. These relate to the cost elements described
earlier in this section and identify what has been included and
excluded for reported and adjusted capital and annual costs. The
alphabetic characters, along with their titles, are briefly de-
scribed in Table A-3.
A-14
-------
TABLE A-3. DESCRIPTION OF COST
Code
Title
Description
L
H
N
0
Particulate control (required for FGD pro-
cess) included in capital cost.
Particulate control (included in FGD
>rocess) included in capital cost.
Total direct capital costs included.
Partial direct capital costs included.
Total indirect capital costs included.
Partial indirect costs included.
Chemical fixation of sludge included in
capital cost.
Dry sludge disposal included in capital
cost.
Off-site landfill area included in
capital cost.
Sludge pond included in capital cost.
Additional sludge disposal capacity
added for life of system.
Stack included in capital cost.
Modifications to stack, ducts, and/or
fans included in capital cost.
Total regeneration facility ^ost included
in capital cost.
Partial regeneration facility cost in-
cluded in capital cost.
R 4 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-15
-------
TABLE A-3. (continued)
Code
Title
Description
H
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 & O programs.
Capital expenditures for reagent supply
exceeds the amount required for the period
of initial operation.
Complete cost of all raw materials,
utilities, operating labor and maintenance
and repairs is included in the total
annual cost.
One or a number of direct annual cost items,
or the cost associated with one or a number
of direct annual cost items, are excluded
from the total annual cost.
Complete cost of all fixed cost elements,.
including depreciation, interim replace-
ment, insurance, taxes, and interest, is
included in the total annual cost.
One or a number of fixed annual cost items,
or the cost associated with one or a
number of fixed annual cost items, are ex-
cluded from the total annual cost.
Plant and payroll overhead costs are in-
cluded in the total annual cost.
The cost of operating particulate collection
equipment included in the FGD system is in-
cluded in the total annual cost.
The treatment and disposal of flue gas
cleaning wastes that are handled by an
outside firm.
The cost of additional power-generating
capacity required to compensate for power
used by the FGD system.
A-16
-------
RESULTS OF COST ANALYSIS
The results of the operational FGD system survey are
summarized in Tables A-4 and A-5. Table A-4 summarizes the re-
ported and adjusted capital and annual costs for all the
operational FGD systems addressed in the survey. Table A-5 pro-
duces a summary of a categorical analysis of the reported and ad-
justed 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.
A-17
-------
TABLE A-4. REPORTED AND ADJUSTED CAPITAL AND ANNUAL
COSTS FOR ALL OPERATIONAL FGD SYSTEMS
Cholla 1
Conesville 5
Elrama 1-4
Phillips 1-6
Petersburg 3a
Hawthorn 3-4
La Cygne 1
Green River 1-3
Cane Run 4
Cane Run 5
Paddys Run 6
M.R. Young 2a
Colstrip 1-2
Reid Gardner 1-2
Reid Gardner 3
D.H. Mitchell 11
Sherburne 1-2
B. Mansfield 1-2
Eddystone LAd
Winyah 2
Southwest la
Widows Creek 8
Reported
Capital
$/kW
52.0
55.6
113.5
107.0
99.5
27.0
53.7
70.3
66.6
62.4
52.9
86.0
77.1
42.9
113.6
:
49.3
120.7
156.8
47.5
77.3
98.2
Annual
mills/kWh
2.19
4.71
5.31
7.83
8.40
1.70
14.35
2.75
0.27
2.10
2.10
1.99
13.18
1.61
3.00
Adjusted
Capital
$/kW
56.0
70.8
134.5
149.7
100.6
87.3
68.0
77.6
80.6
67.5
76.5
93.1
77.3
60.9
107.9
71.5
102.2
233.3
66.5
117.7
113.2
Annual
mills/kWh
2.58
7.42
8.59
9.54
6.56
4.09
3.78
5.24
8.64
5.56
6.51
5.55
4.06
3.20
4.38
2.77
7.67
2.92
6.17
5.28
a Annual costs were not reported by the utility for this system
because of the lack of meaningful data due to recent operating
status.
b Annual costs were not reported by the utility for this system
because of the lack of meaningful data due to peak load status
of unit.
c Reported and adjusted cost data are being assembled by project
participants.
d Annual cost data are being assembled by the utility.
A-18
-------
TABLE A-5. CATEGORICAL RESULTS OF THE REPORTED AND ADJUSTED
CAPITAL AND ANNUAL COSTS FOR OPERATIONAL FGD SYSTEMS
I
M
\D
All
Nrv
Retrofit
Nonregen-
erable
Regencrable
Lliwatone
Llmt
Alkaline/fly
aih/llBCStone
Alkaline fly
aah/11**
Sodlim
carbonate
Hagneeluai
oxide
Reported
Capital
Rar«c, J/kV
27.0-156.8
47.5-120.7
27.0-156.8
27.0-120.7
156.8
57. 5-99.5
27.0-120.7
49.)
77.1-86.0
42. 9-113. 6
156.8
Avg..
$A«
77.6
78.0
77.2
73.7
156.8
71.4
75.1
49.3
81.6
78.3
156.8
o
32.2
26.8
37.8
27.3
23.7
31.7
6.3
50.0
Annual
Range,
Illi/kVh
0.27-14.35
0.27-13.18
2.10-14.35
0.27-14.35
1.61-3.00
2.75-14.35
1.99
0.27
2.10
Avg..
tlla/kWh
4.77
3.65
5.74
4.77
2.13
8.08
1.99
0.27
2.10
0
4.32
4.41
4.28
4.32
0.64
4.34
Adjuated
Capital
Range, S/kV
56.0-233.3
66.5-117.7
56.0-233.3
56.0-149.7
233.3
56.0-117.7
67.5-149.7
71.5
77.3-93.1
60.9-107.9
2.33.3
*vg..
S/kU
95.8
87.6
103.4
89.0
233.)
87.0
94.1
71.5
85.2
84.4
233.3
O
40.1
18.9
52.5
25.4
26.7
29.3
11.2
33.2
Annual
Range,
Ula/kVh
2.S8-9.54
2.77-7 67
2.S8-9.54
2.58-9.54
7.58-6.56
4.09-9.54
2.77
4.06-5.55
3.20-4.38
Avg.,
Illa/kWh
5. S3
5.13
5.92
5.53
4.55
7.03
2.77
4.81
3.79
0
2.09
1.79
2.38
2.09
1.69
1.81
1.05
0.83
-------
EPA UTILITY FGD SURVEY: APRIL 1978 - MAY 197B
SECTION A-l FGD SYSTEM tCUNOMlCS: OPERATIONAL SYSTEMS
HEPOKTED AND ADJUSTED COSTS
ANNUAL - MILLS/KNH
UTILITY
STATION
UNIT(S)
FGD Mn
ELEMENTS
INCLUDED IN
CAPITAL AND
ANNUAL COSTS
TOTAL
CAPACITY CAPITAL
FACTOR S/KH IUIAL 01RECI H»EO
I (YEAR) (YEAR)
ARIZONA PUBLIC StKVltt
CHOLLA
1
b,C>t,StU,x ******«*** RtPUKltD »»
85 52.0 2.19
(1973) (1976)
C»E.I»*«S,U »» ADJUSTED »»*
.« 65 56.0 <>.5S .46 2.10
(1977) (1977)
COLUMBUS ft SOUTHERN OHIO tLtC.
CONESVlLLt
5
an B,C,J,M,T,X
,Y
C,E,J,M,S,U
********** REPORTED »**
51 55.6 4.71 4.71
(1975) (1977)
«*»* ADJUSTED »***
65 7U.0 7.42 5.06 2.36
(1977) (1977)
OUUUESNE LIGHT
ELRAMA POWER STATION
510 B,0,F,I,J,M
,T,V,X,Y
C,E.I,J,M,S
>U,Y
****** REPORTED **
64 115.5 5.31 <*.82 2.49
(1976) (1977)
*«»**«»* ADJUSTED »»
6-3 \il.t 7.61 3.36 4.4b
(1977) (1977)
DUOUESNE LIGHT
PHILLIPS POrtER STATION
410 6,D,F,1,J,H
C,E,I,J,M,S
,U,Y
*** REPORTED ****«
?U 106.9 7.S3 3.69 4.14
(1972) (1977)
»*««***»* ADJUSTED »»«***
bb 140.6 8.57 3.50 4.99
(1977) (1977)
INDIANAPOLIS POuER ft LIGHT
PETERSBURG
3
552 C,F,H,J,M
*«»**«* REPORTED **»*
9<*.S
(1976)
*********** ADJUSTED ««***»*»
6b 100.6 6.56 3.57 2.9V
(1977) (1977)
COST ELEMENTS
CAPITAL:
A - PARTICULATE CONTROL (REOUlKEO FOR FGD PROCESS) INCLUDED IN CAPITAL COST
b - ^ARTICULATE CONTROL (INCLUDED IN FGD PROCESS) INCLUDED IN CAPITAL COST
C - TOTAL DIRECT CAPITAL CUSIS I.VCLUUEu
0 - PARTIAL OlrtECT CAPITAL COS IS INCLUDED
b - IOTAL INDIRECT CAPITAL CUSfS INCLUDED
F - PARTIAL INDIRECT CAPITAL COSTS INCLUDED
G - CHEMICAL FIXATION UF SLUUGE iNCtuDtO IN CAPITAL COST
H - DRY SLUDGE DISPOSAL INCLUDED IN CAPITAL COST
1 - OFF-SITE LANDFILL ARM INCLUDED IN CAPITAL COST
j - SLUDGE POND INCLUDED IN LAPIIAL LOST
* - AOOITONAL SLUDGE DISPOSAL CAPACITY ADDED FUR LIFE UF SYSTEM
L - STACK INCLUDED IN CAPITAL COS)
M - MODIFICATIONS 10 STACK, uUC'S, AND/UK FANS INCLUDED IN CAPITAL COST
N - TOTAL REGENExAtION FACILITY COST INCLUDED IN CAPITAL COST
0 - PAHT1AL RtGtNEkATIUN FACILITY LUST INCLUDED IN CAPITAL CUSt
P - K 6 0 COSTS INCLUDED IN CAPITAL COST
d - COSTS UNDERWRITTEN BY SYSTEM SoPPLIEK INCLUDED If, CAPITAL COST
R - EXCESS REAGENT SUPPLY COSTS INCLUDED IN CAPITAL COST
ANNUAL:
S - TOTAL UIKECT ANNUAL C'tsTS INCLUDED
1 - PARTIAL DIrfFCT ANNUAL COSTS INCLUDED
U - TOTAL FKED ANNUAL COSTS INCLUDED
V - PARTIAL FIXED ANNiUL COSTS INCLUDED
H - OVERHEAD CUSTS INCLUDED IN TUTAL ANNUAL COSTS
X - PARTICULATE CONTKOL COSTS INCLUDED IiM DlKECT ANNUAL COSTS
V - SLUDGE DISPOSAL SERVICE LUSTS ICtlMRACT) INCLUDED IN DIRECT ANNUAL COSTS
i - KEPLACEMbNI ENERbY COSTS INCLUDED IN DIRECT ANrtUAL COSTS
A -20
-------
UTILITY
STATlUN
UNIT 15)
bECTIUN A-l FGD SYSTEM ECONOMICS: OPERATIONAL SYSTEMS
REPORTED AND ADJUSTED CObTS
ANNUAL -
ELEMENTS
INCLUDED IN
CAPITAL AND
FGD MW ANNUAL COSTS
TOTAL
CAPACITY CAPITAL
FACTOR */KW TOTAL DIRECT FIXED
X (YtAR) (YEAR)
KANSAS CMY PUWtR & LIGHT
HAWTHORN
3
110 B,U,F,T,X
8,C,E,J,K,S
>U,n.X
............ REPURTtU ...............
14 29.3 1.11
(H/2) (1977)
>»..«««««« ADJUSTED ««
6b 87.3 4.35 2.93 1.4........... ADJUSTED «......
feb B/.3 4.35 2.93
(1977) (19/7)
KANSAS CITY PUrtbR » LIGHT
LA CYGNt
1
B,C,E,J,S
C,E, J,K,S,U
6b
..... NEPUHTED ...«......«..
S3. 7 1.70 1.7u
(1972) (1977)
..... ADJUSTED «
be.U 3. /8 1.70 2.0tt
(1977) (1977)
KENTUCKY UTILITIES
GMEEN RIVER
1,2 A 3
64 R,C,E,JfS,U
,M
C,E,J,S,U,n
>..........* REPORTED .....«....»«.
16 70.3 14.3b 5.06 9.29
(1975) (1977)
............ ADJUSTED «
bb 77.6 b.24 2.71 2.53
(1977) (1977)
LOUISVILLE GAS A kLECIRIC
CANfc RUN
4
190 C,E,H,J,Q,T
C,E,H,J,K,0
.«..««...«.. REPORTED .«..»»..
bb t>6.6 2.75
(1975) (1977)
««»«««*»»» ADJUSTED «»
65 80.6 6.64 6.46 2.16
(1977) (1977)
COST ELEMENTS
CAPITAL:
A - PART1CULATE CONTROL (HtOUIHED FOR FGO PRUCtSb) INCLUDED IN CAPITAL COST
(J - PAMTICULATE CONTROL (INCLUDED IN Ft,n PROCESS) INCLUDtD IN CAPITAL COST
C - TOTAL DIRECT CAPITAL COSTS INCLUDED
0 - PARTIAL DIRECT CAPITAL CUSTS INCLUDED
£ - TOTAL INDIRECT CAPITAL CUSTS INCLUDED
F - PARTIAL INDIRECT CAPITAL CObTS INCLUDED
G - CHEMICAL FIXATION UF SLUDGE INCLUDED IN LAPITAL COST
H - DRY SLUDGE DISPOSAL INCLuOtD IN CAPITAL COST
1 - OFF-SITE LANDFILL ARtA INCLUDED IN CAPITAL CUST
J - SLUDGE POND INCLUDED IN CAPITAL COST
H - AODITONAL SLUDGE DISPOSAL CAPACITY ADDED F0<» LIFE Or SYSTEM
L - STACK INCLUDED IN CAPITAL COST
M - MODIFICATIONS TO STACK, DUCTS, AND/OR FANS INCLUDED IN CAPITAL COST
N TOTAL REGENERATION FACILITY COST INCLUDED IN C.°ITAL COST
0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
P R 4 D COSTS INCLUDED IN CAPITAL COST
0 - COSTS UNDERWRITTEN BY SYSTEM SUPPLIFR INCLUDED IN CAPITAL COST
R * EXCESS REAbtNT SUPPLY CUbTS INCLUDED IN CAPITAL COST
ANNUALS
3 - TOTAL DIRECT ANNUAL COSTS INCLUDED
T - PARTIAL DIRECT ANNUAL COSTS INCLUDtO
U - TOTAL FIXED ANNUAL COSTS INCLUDED
V - PARTIAL MXEU ANNUAL COSTS INCLUDED
N - OVERHEAD CUSTS INCLUDED IN TOTAL ANNUAL COSTS
X PAflTICULATE CONTROL COSTS INCLUDED IN. DIRECT ANNUAL COSTS
T - SLUDGE DISPOSAL SERVICE COSTS (CONTRACT) INCLUDED IN DIRECT ANNUAL COSTS
Z REPLACEMENT tNtRUY COSTS INCLUDED IN DIRECT ANNUAL COSTS
A -21
-------
EPA UTILITY FRO SURVEr: APRIL 1976 - MAY 1978
SECTION A-l FbD SYSTEM ECONOMICS: OPERATIONAL SYSTEMS
REPORTED AND ADJUSTED COSTS
UTILITY
STATION
UNIT(S)
ELEMENTS
INCLUDED IN
CAPITAL AND
FGD MM ANNUAL COSTS
TOTAL ANNUAL - MILLS/KwH
CAPACITY CAPITAL «
FACTOR */KM TOTAL OIRtCT HXED
X (YEAR) (YEAR)
LOUISVILLE GAS & ELECTRIC
CANE RUN
5
C,F,H,J
f U,M
*»**»**»* REPORTED ««»»»
62.a
(1977)
* ADJUSTED »**«
65 67.5 5.56 3.47 2.09
(1977) (1977)
LOUISVILLE GAS & ELECTRIC
PADDYS RUN
6
70 C,E
C,E,S,U,W
********* REPORTED **
52.9
(1913)
»»** ADJUSTED **********
6b 76.5 6.51 3.92 2.59
(1977) (1977)
MINNKOTA POWER COOPERATIVE
MILTON H. YOUNG
2
077 C,E,H,P
C.E,H,M,P,S
rU,W
**»******» REPORTED ****«
86.0
(1976)
*************** ADJUSTED **********»*
65 93.1 5.55 2.24 3.31
(1977) (1977)
MONTANA POWER
COLSTRIP
1
330 B,C,E,J.P,T
C.E.J,K.P,S
*»»»» REPORTED **«**«»
76 77.1 .27 .27
(1975) (1977)
»«**»»» ADJUSTED »»»***
65 77.3 4.06 1.51 2.5b
(1977) (1977)
MONTANA POKER
COLSTRIP
2
330 B,C,E,J,P,T
C.E,J.K,P,3
.U,N
********* REPORIED ««******
7b 77.1 .27 .27
(1975) (1977)
**** ADJUSTED **«***«*»**
65 7/.3 4.06 1.51 2.55
(1977) (1977)
CUST ELEMENTS
CAPITAL:
A - PAKTICULATE CONTROL (RfcOUlHEO FOR FGO PROCESS) INCLUDED IN CAPITAL CUST
B - HAMTICULATE CONTROL (INCLUDED IN FGD PKUCESS) INCLUDED IN CAPITAL COST
C - TOIAL 01KECT CAPITAL COS1S INCLUDED
0 - PARTIAL UlrtECT CAPITAL COSTS INCLUDED
E - TOTAL INDIRECT CAPITAL CUSTS INCLUDED
F - PARTIAL INDIRECT CAPITAL COSTS INCLUDED
G - CHEMICAL FIXATION UF SLUUGt INCLUDED IN CAPITAL COST
H - DRY SLUDGE DISPOSAL INCLUDED IH CAPITAL COST
I - OFF-SITE LANDFILL ARtA INCLUDED IN CAPITAL CUST
J - SLUOUE PUND INCLUDED IN CAPIIAL COST
K - AODI10NAL SLUDGE DISPOSAL CAPACITY AUDtO FUR LIFE UF SYSTEM
L - STACK INCLUDED IN CAPITAL COM
M - MODIFICATIONS TO STACK, DUCTb. AND/OK I-ANS INCLUDED IN CAPITAL COST
N - TOTAL KEbENEkATIUN FACILITY COS! INCLUDED IN CAPITAL COST
0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL CUST
P - H A D COSTS INCLUDED IN CAPITAL LOST
U - COSTS UNDERWRITTEN BY SVbTEM SUPPL1EH INCLUDED IN CAPITAL COST
K - EXCESS KtAbENT SUPPLY COSTS INCLUDED IN CAPITAL COST
ANNUAL:
S - TOTAL DIRECT ANNUAL COSTS INCLUDED
T PAMTIAL DIRECT ANNUAL COSTS INCLUDED
U IUIAL FIXED ANNUAC CUSIS INCLUDED
V PAMI1AL FIXED ANNUAL COSTS INCLUDED
H - UVERHEAD CUSTS INCLUDED IN TUTAL ANNUAL COSTS
X - FArtTlCULATt CUNTrtUC COSTS INCLUDED IN DIRECT ANNUAL COSTi
Y - SLUOUE DISPOSAL SERVICE COSTS ICuNTRACT) INCLUDED IN DIRECT ANNUAL COSTS
Z - REPLACEMENT kNERbV COSTS INCLUDED IN DIRECT ANNUAL CUSTS
A -22
-------
OTILITV
STAT ION
UNIT(b)
Eft JTTLIIY f(,n S.JHVEY: APRIL 197B - MAY 1978
St. MI.., A-I Ft.U SrSIE'4 tCUNU'MCS: Jr tHA [ I J,\ AL bYSTc^S
-M^i-lM' «,.|r AUJuSIFi) CObIS
ANNUAL - MILLS/KrtH
K,l;
t L c '' ^ N ) S
I..CL MM) IN
r AH I T AL A..O
TOTAL
CAPACITY CAPITAL
FaCTOH »/n,rt TOIAL OlRtCT t-IXEO
X (Yt«K) (YEAH)
NEVADA POrtFW
REID GARDNER
1
, n , K , P , S , u
n , C , I- , .1 , P , S
, U , l. , *
...... REPORTED *.****«
<4e!.9 - , s,n
> » A
n,r , t , J ,K,S
, u . .-. , x
bb
i***.. REPORTED *«*«
Oif.9 *«* RtPORTFD ****.****
113.b 2.10 1.30 .80
(1975) (1977)
>*** ADJUSTED **«
107.9 4.48 1.30 3.00
(19/7) (1977)
NORTHERN INDIANA PUH
DEAN H. MITCHtLL
11
HEPURTED «**
ADJUSTED *»»***«*
NORTHERN STATbS PUMER
SHERBORNE
l
p,c,r, ,j,s,u
i *»i
C f F , G, J . K , S
i«««*» REPORTED ***************
49.3 1.98 1.05 .93
(19/rf) (1977)
i««*«* ADJUSTED ***********
71.5 2.77 .75 2.0.J
(1977) (19/7)
CUSt tLtMfcNTS
CAPITAL:
A - PAHTlCULATt COMKOL (RtUUlKfcl) FOk FGD PHUCESS) INCLUDED IN CAPITAL CUST
b - PArtTICbLATt CONTKOL (iNCLUUhj IN FbO PKULeSb) INCLUOtt) IN CAPITAL COST
L - TOTAL UlKbLT CAPKAL CuSlS INCLUDED
U - PARTIAL OIKELl CAPITAL CUSTb TUCcHufcD
t - TOIAL INDIRECT CAPITAL cusis INCLUDED
f - PARTIAL INUIn'fcCT CAPITAL CUSTS TNCLUJEU
G - CHEMICAL FIXATION (Jt SLUUGt INCLUDtl) IN CAPIIAL COST
H - uRr b'LUnbE DISPOSAL INCLUDED IN CAPITAL CUST
1 - uFh-MIt LANDFILL *WK» I«.CLUi)Fu 1M CAPITAL CUSI
J - SLUDbF. PONI/ INLLUDEO U CAPIIAL COST
K - AOOIIOuAL SLUJut DISPOSAL C.APACIIY AJOtD FOX LIFfc OF bYSItM
L - STACK INCLUOtO IN CAPIIAL COST
M - MOOIFTCAIIONS 10 MAC*, D»CTS. AND/OK HANS INCLUDED IN CAPITAL COST
N - TOTAL HEtENCKAT I UN KACIL1TY LUST INCLUDED IN CAPITAL COST
0 PAKTIAL NEliEM-.Nd t InrJ FACIL1IY COST IiJCLUuEU IN CAPITAL COST
P - K & 0 COSTS INCLUDl.u IN CAPITAL LOST
U - tlloTs ONDEHrtRI1TLN MY bYb't" SdPPLitK INCLUDtD IK C*.MTAL COST
H - CXCE&S RtAbFNl SUPPLY UPj,TS INCLUOtU It, CAPITAL COST
ANNUAL:
b - IOIAL DIRE'.I ANNUAL COSTS i^CluOhD
I - PARTIAL ulrftLI ANNUAL COSIb INCLUDtO
U - TUIAL (-UED ANNUAL C^SIS [NCLUUHD
V - PARTIAL FIXEU ANNUAI TOS1S INCLUiiFn
H - OVERHEAD CllSIS I^TLULiEU IN TOTAL ANNUAL COSTS
X - r-Artl lCdi_ATt CONTROL COSTS INCLUOtO I* DlhECT ANNUAL COSTS
Y - SLUDbE OlSfOSAL SEKVICt CObIS (CONTRACT) INCLUuEU IN UlRtCT ANNUAL COSTS
i - WtPLACtMtNI LNtRl.Y CUSIS iNCLUUfi) IN ulRECT ANNUAL COSTS
A -^3
-------
EPA UTILITY F60 SURVEY: APRIL 1970 - MAY 1978
SECTION A-l FGO SYSTEM LCONOMICS: OPERATIONAL SYSTEMS
kEPUHTED AND ADJUSTED COSTS
ANNUAL - MILLS/KMH
UTILITY
STATION
UNIT(S)
FGU MM
ELtMENTS
INCLUDED IN
CAPITAL AND
ANNUAL COSTb
TOTAL
CAPACITY CAPITAL -
FACTOR 4/KW TOTAL DIRECT FIXED
X (YEAH) (YEAR)
NUHIHtKN SIAIbS
SHERBURNE
2
720 B,C,b,J,b,0
C,E.G,J,K.S
**»********** HEPUKlbU ********
75 19.3 1.9a 1.05 .93
(19/2) (1977)
t************* ADJUSTED *******
b5 71.5 2.77 .75 2.02
(1977) (1977)
PENNSYLVANIA PUnER
BRUCE MANSFIELD
1
917 B,C,E,G.I,L
,S,U.n,X
C,£,G,I.M,S
, U.rs
****** REPORTED ******
au 120.7 13.16 <*. OB 9.10
(1975) (1977)
******** ADJUSTED »»***
b5 102.2 7.67 0.50 3.I/
(1977) (1977)
PENNSYLVANIA POftEK
BRUCE MANSFIELD
2
917 B,C,E,G,I,L
,5,U,n,X
C,E.G,I,M,S
**»* REPORTED ***************
ao 120.7 13.16 4.06 9.10
(1975) (1977)
*********** ADJUSTED *****»**
bb 102.2 7.67 4.5V 3.17
(19/7) (1977)
PHILADELPHIA ELECTRIC
EDOYSIONE
1A
0,F,N,P
*************** REPORTED *******
iSb.B
(1972)
A************** ADJUSTED ********
235.3
(1977)
PUBLIC SERVICE UF NEM MtXICO
SAN JUAN
1
A.C.f.N
******* REPORTED *****
127.9
(1977)
A************* ADJUSTED ************
COST LLfcMtNTS
CAPITAL:
A - PART1CULATE CONTKOL (MtOUIxED FOk F&O PKoCfcSS) INCLUDED IN CAPITAL COST
B - PARTICULAR CONTROL (INCLUDED IN FkD PHUCESS) INCLUDED IN CAPITAL COST
C - TOTAL DIRECT CAPITAL CUSTS I.MCLUOEO
0 - PARTIAL UlRECT CAPITAL CUbTS INCLUDED
t - 10IAL INUliiECT CAPITAL COSlS INCLUDED
F - PARTIAL 1NDIKECT CAPITAL CUSIS InCLUJtO
e - CHEMICAL FIXATION UF SLUDGE INCLUDED i>« CAPITAL COST
H - U*
-------
EPA UTILITY FiiO SU&VFY:
btLTj(''< A-l Fl>t' bYSIH" tCummcs: 'vf *A T IU'»AL
«tPU-
ANNUAL - MILLS/K«H
t- I *tD
SOUTH CARULINA PUML1C StRVILE
WINYAH
i.
1"U C , c , J , " , S , v
h"5
11 .b
1.61 .He
(19//)
...... ADJUSTED .««..<
bo.b ci.92 l.U<»
(1977) (1977)
1 .««
SPRINUFIELU CITY uTILUUb
SOUTM*EST
1
c.e,H,J
, S , U , l,
(1971)
............... ADJUSTED «
hi 117.7 6.17 £.87
(1977) (1977)
J.JU
TENNESSEE VALLEY AUTHORITY
WIDOnb CREEK
6
H,Cfk',PfR.T
,U
C,F,J,S,U,n
96.a
(19/6)
a.
ADJUSTED
bb
(1977)
(1977)
1.4U
(1977)
3. 04
TEXAS UTILITTES
MUNTICELLO
3
750
KEPURTED *«»*««
(1976)
ADJUSTED ******.****
CUbt tLfcHEMS
CAPITAL:
A - PARTICULATE CONTHOL (HtUUlHtD ^OK FGD PKUCtSS) INCLUDED IN CAPITAL COST
b - PAKTICULATt CONTKOL (INCLUl)EO IN Fl,0 PKUCESS) INCLUDED IN CAPITAL COST
TOTAL DIKECT CAPITAL CUSTS INCLUDED
PARTIAL DIRECT CAPITAL CUSTS INCLUDED
TUIAL INDIRECT CAPITAL CuSIS INCLUDED
PARTIAL 1NDIKECT CAPITAL COSTS LNTLHaED
CHEMICAL FIXATION OF SLUURI- iNCLUHtn IN LAPITAL COST
DRY SLUDGE DISPOSAL INLLuUtO I,M CAPITAL COST
OFF-SHE LANDFILL ARtA INCLUDED IN CAPITAL COST
SLUOI.E POND INCLUOEO IN LAPIIAL LOST
AOOITONAL bLUOGE DISPOSAL CAPACI1Y ADOtO FUR LIFE OF SYSTEM
STACK INCLUDtO IN CAPITAL CUbT
MOOIFICATIUNS TU STACK, UUCTbf AMO/OH FANS INCLUDED IN CAPITAL Cl>ST
TOTAL SEGENEhATION FACILITY COST INCLUDED IN CAPITAL f«)ST
PARflAL KEGENEhAIIUN FACILITY COS1 INCLUDED IN CAPITAL ..'S!
R ft D COSTS INCLUDED IN CAPITAL CUbT
COSTS UNDERrtRlTTtN BY SYbTtM SUPPLIF.M INCLUDED IN CAPITAL CUST
._- . . *>».t«T*l /-fteT
U LU3IO Unucnnniiit.1* wi v.v..-
K - EXCESS REAGENT SUPPLY LObTS INCLUDED IN CAr»I!AL COST
ANNUAL:
S - TOTAL DIRECT ANNUAL COSTS INCLUDED
T - PARI1AL DIRECT ANNUAL LUbTS INCLiJOED
U - 10IAL FIxEu ANNUAL CUSTS iNCLUUfU
V - PARTIAL FIXEu ANNUAL CUSIS INCLUDEu
W - OVERHEAD CUSTS INCLUDED IN TOTAL ANNUAL COSTb
X - PAHTICULATE COMrtOL COSTS INCLUDED IN DIRECT ANNUAL COSTS
Y - SLUDGE DISPOSAL SEKVlCt COSTS ICONIRACT) IrtCLUuEO IN DIRECT ANNUAL COSTS
2 - HEPLACEMbNT ENERGY COSTS INCLUDED IN DIRECT ANNUAL COSTS
A -i>5
-------
EPA UTILITY FGO SURVEY! APRIL 1978 - HAY 1976
SECTION A-2 FbO SYSTEM ECONOMICS: NONQPERATIONAL SYSTEMS
REPORTED AND ADJUSTED COSTS
ANNUAL - MILLS/KNH
UTILITY
STATION
UNIT(S)
ELEMENTS
INCLUDED IN
CAPITAL AND
FGD HH ANNUAL COSTS
TOTAL
CAPACITY CAPITAL .--
FACTOR S/KN IUTAL DIRECT FIXED
X (YEAR) (YEAR)
ALABAMA ELECTRIC COUP
TUMBIGBfcE
2
255 c,t,j
****** REPORTED
69.5
(1978)
ALABAMA ELECTRIC COOP
TOMBIbBEE
3
255 C,E,J
******* REPORTED »
69. 5
(1976)
ARIZONA ELECTRIC PONEK COUP
APACHE
2
200 B,C
*** REPORTED «****
b.3
(1976)
ARIZONA ELECTRIC POMER COOP
APACHE
3
200 B,C
*** REPORTED »*
5.3
(1976)
BASIN ELECTRIC POnEH COUP
LARAMIE RIVER
1
SSO C,E
***** REPORTED **
60. Z
(1960)
BASIN ELECTRIC POMER COOP
LARAMIE DIVER
2
550 C,E
******** REPORTED ****
68.2
(I960)
BIG RIVERS ELECTRIC
REID
2
250 B,C
******* REPORTED
43.2
(1976)
BOSTON EDISON
MYSTIC
6
155 B,C,E,N,Q
******* REPORTED »
63.4 3.00
(1972) (1974)
COST ELEMENTS
CAPITAL:
A - PART1CULATE CONTROL IREUUIREU FOR FGD PROCESS) INCLUDED IN CAPITAL COST
B - PARTICULATE CONTROL (INCLUUED IN FtiO PrtOCESS) INCLUDED IN CAPITAL COST
C - TOTAL DIRECT CAPITAL COSTS INCLUDED
I) - PARTIAL DIRECT CAPITAL COSTS TNCLUOEO
E - IOIAL INUIKECT CAPITAL CuSTS INCLUUED
F - PARIIAL INDIRECT CAPITAL COSTS INCLUDED
& - CHEMICAL FIXATION OF SLUDGE INCLUDED IN CAPITAL COST
H - DRY SLUDbE DISPOSAL INCLUOtD IN CAPITAL COST
I - UFF-SIIE LANDFILL AREA INCLUDED IN CAPITAL COST
J - SLUDGE PUNU INCLUDED IN CAPITAL COST
K - AOOITONAL SLUDGE DISPOSAL CAPACITY ADDED FUK LIFE OF SYSTEM
L - at*CK INCLUDED IN CAPITAL COST
M - MUUlFICATIUNb TO STACK, DUCTS, AND/OM FANS INCLUDED IN CAPITAL COST
N - TOTAL KECiENfHATIUN FACILITY COST ImCcUUEO IN CAPITAL COST
0 - PARTIAL REGENERATION FACILITY COST INCLUDED IN CAPITAL COST
p - R * D cObTs INCLUDED IN CAPITAL COST
U - COSTS UNUEkhHllTbN BY bYSTfcM SUPPLIER INCLUDED IN CAPITAL COST
H - EXCESS HkAuENT SUPPLY CU&TS INCLUDED in CAPITAL COST
ANNUAL:
S - TOTAL DIRECT ANNUAL COSTS INCLUDED
T - PARTIAL OIRtLT ANNuAL CO&Ib INCLUDED
U - IOIAL FUEU ANNUAL CoSTS INCLtlOEO
V - PARTIAL FIXI-U ANNUAL COSTS INCLUDED
M - OVERHEAD CUSTS INCLUUED IN TOTAL ANNUAL COSTS
X - PARTICULATE CONTROL COSTS INCLUDED In DIRECT ANNUAL COSTS
1 - SLUDbE DISPOSAL SERVICE COSTS (CONTRACT) INCLUDED IN DIHbCT ANNUAL COSTS
i - REPLACEMENT tNERbY CUSIS INCLUDED IN DIRECT ANNUAL CUSTS
A -i»fc
-------
! UTlLItr M,l>
: APHJL 1978 - MAT 19/8
UTILIIY
STATION
UNIT(S)
-i "'(.!> .rSIFf tC
(r r .i» | > D 4,1. »|
' L c '' i- '. I S
Ii.n.ii'jFu p.
r IP ; T AI AI-M.I
* rt A M 11 A L L 0 j T J
TOTAL ANNUAL - MILI_S/K«H
CAPITAL -- ------- - ---
»/M« TOTAL DIRECT FIXED
(rtAH) (TEAS;
UTAH PDWFK & LIGHT
EMENY
2
95.3 i.31
(1978) (197b)
CENTRAL ILLINOIS PlIHLK
NtWTON
1
S/S C,',
REPORTED
119/9)
COLORADO UTt ELECTRIC AsbN
CrtAIG
1
RfcPoRTEU
III .0
(1979)
COLORADO UTE tLtCIMK Abbi.
CRAIG
A,C
.... REPORTED «
11 / . o
(1979)
«»*«**
COMMONWEALTH tOISDN
POWER ION
51
c.t.i.j
*«***.**»***** REPORTED
117.7
(1979)
COMMONWEALTH E01SUN
WILL COUNTY
1
Ib7 H,C.E,G,J,X
»**«.****» REPORTED
09 113.0 13.06
(197«>) (1975)
DETROIT EDISON
ST. CLAIR
6
Ibi H.C^.I.M.X
** REPORTED »«.
8U.3 9.60
(1976) (1976)
ILLINOIS PONER
MOOD KIVER
4
110 A,C.E,M,N
REPORTED
«e;.b
(1972)
COST
CAPITAL:
A -
ti -
L -
U -
E -
t -
G -
rl -
I -
J.~
K -
L -
M -
N -
0 -
COr*TrtOL IMtdOlKfn FJK FGu PROCESS) INCLOOFD IN CAPITAL COST
PAHTjCULATt CONTwOL (INfLUOEl) IN FbD PHUCEbS) INCLUDEO IH CAPITAL COST
IOTAL olntcT CAPITAL COSTS INCLUOEJ
PMvliAL Dl>JPr>LlEK 1NLLODEH IN CAPITAL COST
KtAOF.iT SUPPLY CObTJ INCLUDED lit LArMTAL COST
- K ft 0
ANNUAL:
S
T
0
IOIAL UIKtLT ANNUAL COSTb
PARTIAL L'JrfECr ANNi'AL CObTS INLLUOF.I)
i HAL FTXEU ANNUAL COSTS 1-CLiiOtu
- PARTIAL tlJiEl' ANNUAL CUS1S INCLODFO
- .iVtRMEAO ClIJTb [.JCLilDEO IN IdTAL ANNUAL COSTb
- PAKTlCULATt LPNTKOL CUSTb U-LI.uDtU IN UMECT ANNUAL COSTS
- sl^.." n?SH,,b«L bEKVlCt LOblb (CUNTRACT) INCLUDED IN DIRECT
- ^EPLACEMtM tNERbY COSTS I. CLUDEU IN OIRtCT ANNUAL COSTS
ANNUAL COSTS
A -27
-------
EPA UTILITY FfcO SUHVEYt APRIL 1976 - MAY 1978
SECTION A-2 F6D SYSTEM tCONOMICS: NONOPERATIONAL SYSTEMS
KEPUkTEO AND AOJUSIEU COSTS
UTILITY
STATION
UNIT(S)
fcLEMENIS
INCLUDED IN
CAPITAL AND
FCU Mm ANNUAL COSTS
TOTAL ANNUAL - MILLS/KMH
CAPACITY CAPITAL
FACTOR »/KH TOTAL DIRECT FIXED
I (YEAH) (YEAR)
LOUISVILLE GAS t ELECTRIC
CANE HUN
6
-------
SECTION A-«; Fi,D
FPA UIILII" F&D S.iRvE»: APRIL l-»7a - MAY J978
tFr teutonics: Mu\uF tWAT 1UNAL
AMI AUJUS1EH Ci'STb
UTILITY
STAI1UN
UN1I(b)
INCLUUFO IN
CAPITAL »i
-------
APPENDIX B
FGD PROCESS FLOW DIAGRAMS
THIS APPENDIX COMPRISES BOTH ACTIVE AND INACTIVE UNITS
ARRANGED ALPHABETICALLY ACCORDING TO UTILITY
"SUPPLEMENTAL EDITION"
CHANGES/ADDITIONS
B-l
-------
STACK
T
to
COAL SUPPLY'
FEEDER
PULVERIZER
I.D. FAN
STACK GAS
IR HEATER
DEMISTER
TACK GAS REHWTER
STACK'
GAS
SCRUBBER
Kansas Power and Light
Original Operational FGD System at Lawrence No. 4.
RECYCLE
WATER
-------
MtT[l F0»
'! ikUMTIIIC
\J
>
tcot«
UOITIft
TIMS'f
"**S
lit*
1
oiiuTK* wu> ir«o-
*oom« sTOMcr «CIICUI«TIO* two
TMI M) SOI I OS
/
/
/
ADOUm
Dilution
ibf
Il-o;
n.f»»'o«
lu
STMAGI
W
U)
O f
*^IO OlMf«
sctutirc
NDOVU
1
T
f
J
ADDITIVE
(FROM MILL)
/
i
0 STACK ,
B
1UE GAS
UR PREHt
OOITIVE
3
ITPAS
OUTLET OANPER
, ,' ' L
l^
R(f ~T «\ 1
»TER INLiTH 1
DAMPER \
4d
i
i
T
uL
MAKEUP
1 UATER ? ,
' T
' T'
ROD SCRUBBER {!»
SPRAT PUKP .I (
^^_
X
/J J pREHEATER
1 fg < PcuraTtn m mro
PN
B-E-S- ___^ MIST ELIMINATOR
ABSORBER STRAINER HASHER
/(TYP.)
/ STRAINER HASH
/ [ LINE (TTP )
^1 /' 1 ' ' Q 1
f|| |f ] ABSORBER'
EACTION :,
TANK :r Q
TRAINERS:
U
1 ADDITIVE l|lCOHMINUTO«
STORAGE TANK 1
EFFLUENT Q
I
__ "*" 1_ . TO PONO
-- ----- 1
Kansas Power and Light,
Lawrence No. 4 Operational FGD System
Simplified Process Flow Diagram
-------
STACK
da
COAL SUPPLY-
FEEDER
PULVERIZER
-I.D. FAN
FURNACE
F.D. FAN
TACK GAS REHEATER
STACK GAS
IR HEATER
DEMISTER
MARBLE BED
STACK
GAS
SCRUBBER
Kansas Power and Light
Original FGD System Installed at Lawrence No. 5:
Simplified Process Flow Diagram.
RECYCLE
WATER
-------
NAUR FOR
UNISTOM HURRTING
HOCPIR
, . PAOOITIVC DHUTKM
1ANI
1
l^-
THKkfNIR
tINOFRf inw PUMP',
TO
SFTTI ING
''' NI'
Kansas Power and Light,
Lawrence No. 5 Operational FGD System
Simplified Process Flow Diagram
-------
SCRUBBER INLET
TEST PORT LOCATION
W
PRECIPITATOR
INLET TEST
PORT LOCATION
SCRUBBER INLET
TEST PORT LOCATION
TOP OF STACK
ELEVATION 1645'
TEST PORT
ELEVATION 1516'
TOP OF OUTLET BREECHING
ELEVATION 1372'-2 3/8"
TOP OF BYPASS BREECHING
ELEVATION 1307'- 8 1/2*
'GRADE ELEVATION I»V
Springfield City Utilities, Southwest No. 1:
Simplified Process Diagram
-------
APPENDIX C
DEFINITIONS
C-l
-------
DEFINITIONS
Boiler Capacity Factor:
Boiler Utilization Parameter:
Efficiency:
Particulates
SO.
FGD Viability Indexes
(kWh generation in year)/
maximum continuous generating
capacity in kW x 8760 hr/yr).
Hours boiler operated/hours in
period, expressed as a percen-
tage.
The actual percentage of
particulates removed by the
emission control system (mech-
anical collectors, ESP. or
fabric filter and FGD) from
the untreated flue gas.
The actual percentage of SO-
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 available.
Several parameters have been
developed to quantify the
viability of FGD system tech-
nology. Various terms such as
"availability," "reliability,"
"operability," and "utilization1
are used to accurately repre-
sent the operation of any FGD
system during a given period.
The above-mentioned parameters
are defined below and dis-
cussed briefly. The objectives
of this discussion are to make
the reader aware that several
different definitions are
being used and to select
appropriate parameters that
can be used for reporting
purposes so that reasonably
consistent comparisons can be
made.
C-2
-------
DEFINITIONS
Availability Index
Reliability Index
FGD Operability Index
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 chemi-
cal shortages, lack of manpower,
short duration boiler operations,
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 addition,
an undefined value can result
when the FGD systeir. 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 opera-
ted 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
C-3
-------
FGD Utilization Index
FGD Status:
Category 1
Category 2
Category 3
operating time. The parameter
does not reflect the extent of
exertion on the FGD system,
that is, the magnitude of the
parameter has little or no
correlation with FGD system
operating time. Also, 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 parameter is
a relative stress factor for
the FGD system. It is not a
complete measure of FGD system
viability because the para-
meter can be strongly influ-
enced 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).
Operational - FGD system is in
service removing SO-.
Under Construction - ground
has been broken for installa-
tion of FGD system, but FGD
system has not become opera-
tional.
Planned, Contract Awarded -
contract has been signed for
purchase of FGD system but
ground has not been broken for
installation.
C-4
-------
Category 4
Category 5
Category 6
Category 7
Category 8
FGD Vendor
Fuel Characteristics
New
Nonregenerable
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 SO^ regula-
tion.
Considering an FGD system as
well as alternative methods.
Nonoperational - FGD system
has been in service in the
past but has been shut down
permanently or for an extended
indefinite period of time.
A firm which fabricates and
supplies FGD systems, most
notably the flue gas treating
and ancillary equipment.
Type of fuel, average gross
heating value in Btu/lb.
average percent ash and average
percent sulfur content for
fuel as fired.
FGD unit and boiler were
designed at the same time or
space for addition of an FGD
unit was reserved when boiler
was constructed.
The S0_ 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.
C-5
-------
Operational Experience
Process
Regulatory Class
Regenerable
Retrofit
Sludge Disposal
C-6
Summary of FGD status and
description of current month's
progress.
Company name if process is
patented. Generic name if
several companies have similar
processes.
A. New boiler constructed
subject to Federal New
Source Performance Stan-
dards.
B. Existing boiler subject
to State Standard that is
more stringent than the
Federal New Source Per-
formance Standard (NSPS).
C. Existing boiler subject
to State Standard that is
equal to or less strin-
gent than NSPS.
D. Other (unknown, undeter-
mined) .
The SO2 removed from the flue
gas is recovered in a usable
or marketable form (e.g.,
sulfur, sulfuric acid, gypsum,
ammonium sulfate, sodium
sulfate).
FGD unit must be added to an
existing boiler not specifi-
cally designed to accommodate
FGD unit.
Disposal method for nonregen-
erable systems producing
sludge including: lined
or unlined ponds, stabilized
or unstabilized sludge, and
on- or off-site disposal,
disposal type (minefill,
landfill, structural fill).
For the regenerable systems,
the form or method of sulfur
recovery is provided (e.g. -
molten elemental sulfur,
sulfuric acid plant).
-------
Start-up Date
Total FGD System Lost
Generation Factor
Unit Cost
Unit Location
Unit Name
Unit Rating
Date when initial S02 removal
began or is scheduled to
begin.
The total monthly lost genera-
tion hours due to FGD train
outages divided by the total
monthly expected generation if
the FGD trains would have been
available for operation,
expressed as a percentage.
Capital Cost in $/kW includ-
ing: SC>2 absorption and
regeneration system, S02
recovery system, solids dis-
posal, site improvements,
land, roads, tracks, substa-
tion, engineering costs,
contractors fee and interest
on capital during construc-
tion.
Annualized Cost in mills/kWh
including fixed and variable
costs. Fixed costs include:
interest on capital, deprecia-
tion, insurance, taxes, and
labor costs including over-
head. Variable costs include:
raw materials, utilities, and
maintenance.
City and State listed in
mailing address.
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; Preopera-
tional - maximum continuous
design generation capacity in
MW.
C-7
-------
Utility Name Name of corporation as it
appears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - as space permits.
Water Make-Up Gallons per minute of make-up
water required per MW of
capacity.
C-8
-------
TECHNICAL REPORT DATA
(Please read Inm-.tciiuns on the r<-\ i r:r '>. lore conirli tin^i
. REPORT NO
3 RECIPIENT S ACCESSION NO
.TITLE AND SUBTITLE
EPA Utility FGD Survey: April-May If 7>
7V.
5. REPOHT OATfc
September 1! 7t
6. PERFORMING ORGANIZATION CODE
. AUTHOR(S)
E.Laseke, M.Melia, M.Smith, and W.Fischer
8. PERFORMING ORGANIZATION REPORT NO.
. PERFORMING ORGANIZATION NAME AND ADDRESS
PEDCo Environmental, Inc.
114?f Chester Road
Cincinnati, Ohio 45246
10. PROGRAM ELEMENT NO
EHE624
11. CONTRACT/GRANT NO
68-01-4147, Task 52
12. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
Periodic; 3-7/78
14. SPONSORING AGENCY CODE
EPA/600/13
is. SUPPLEMENTARY NOTES E p A project officers are N.Kaplan (IERL-RTP. MD-61. 919/541-
2556) and J. C. Herlihy (DSSE, 202/755-8137).
16. ABSTRACT
^n upcjated supplement to EPA-600/78-051a and should be
used in conjunction with it. It presents a survey of utility flue gas desulfurization
(FGD) systems in the U.S. , summarizing information contributed by the utility indus-
try, process suppliers, regulatory agencies, and consulting engineering firms. Sys-
tems are tabulated alphabetically, by development status (operational, under constru-
ction, in planning stages t or terminated operations), by utility company, by process
supplier, by process, by waste disposal practice, and by regulatory class. It pre-
sents data on system design, fuel sulfur content, operating history, and actual per-
formance. It discusses problems and solutions associated with the boilers and FGD
systems. Process flow diagrams and FGD system economic data are appended to
the report.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
Pollution
Flue Gases
Desulfurization
Electric Utilities
Waste Disposal
Boilers
Maintenance
b.lDENTIFIERS/OPEN ENDED TERMS
Pollution Control
Stationary Sources
Utility Boilers
. COSATl 1 icId/Croup
13B
2 IB
07A,07D
15E
13A
13. DISTRIBUTION STATEMENT
Unlimited
19. SECURITY CLASS (This Report I
Unclassified
136
20 SECURITY CLASS (This page I
Unclassified
[22. PRICE
EPA Form 2220-1 (9-73)
c-;
------- |