SUMMARY REPORT •  FLUE GAS DESULFURIZATION SYSTEMS •  JANUARY - FEBRUARY 1976
Table
  1  Summary List of F6D Systems
  2  Status of FGD Systems
  3  Performance Description for Operational FGD Systems
  4  Number and Total MW of FGD Systems
  5  Summary of FGD Systems by Company
  6  Summary of FGD Systems by Vendor
  7  Summary of New and Retrofit FGD Systems by Process
  8  Summary of Operating FGD Systems by Process and Generating Units
  9  Summary of Sludge Disposal Practices for Operational FGD Systems
 10  Summary of FGD Systems by Process and Regulatory Class
 11  Summary of Operational FGD Systems
 12  Summary of FGD Systems Under Construction
 13  Summary of Planned FGD Systems
 14  Summary List of1 FGD Systems in the Early Planning Stages
 15  Status of FGD Systems in the Early Planning Stages
 16  FGD  System Operations That Have Been Terminated or  Shut Down Indefinitely
      Definitions
             Prepared by
 PEDCo-Environmental  Specialists,  Inc.
       Suite 13, Atkinson Square
        Cincinnati, Ohio  45246
                                     Page
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                                     203
               Prepared  for
 Division of Stationary  Source  Enforcement
                   and
Industrial Environmental  Research  Laboratory
   U.S.  ENVIRONMENTAL PROTECTION AGENCY
          Research Triangle  Park,
           North Carolina 27711
                                        Contract No.  68-02-1321
                                              Task No.  28

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          Table 1
SUMMARY LIST OF FGD SYSTEMS

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                                          TABLE  1
                              SUMMARY LIST  OF FGD  SYSTEMS
 FGD STATUS REPORT  03/76

 1.0. NUMBER  AND COMPANY  NAME
                                     UNIT NAME
                                                                        LOCATION
                                                            START UP DATE   STATUS
                                                      REG
                                                      CLASS
 9
10
   1 ALABAMA ELLC1RIC  COOP
   2 ALABAMA ELECTRIC  COOP
   3 ALLEGHENY POWER SYSTEM
   I* ALLEGHENY POWER SYSTEM
   5 ARIZONA ELECTRIC  POWER  COOP
   6 ARIZONA ELECTRIC  POWLR  COOP
   7 ARIZONA PUBLIC SERVICE
   6 ARIZONA PUbLlC SERVICE
     ARIZONA PUbLIC SLKVICE
     AKIZONA PUbLIC SERVICE
   11 ARIZONA PUBLIC SERVICE
   12 BASIN  ELECTRIC POWER  COOP
   13 BASIN  ELECTRIC POWER  COOP
   m BASIN  ELECIKIC POWER  COOP
   15 BASIN  ELECTRIC POWER  COOP
   16 EiASlN  ELECTH1C POWER  COOP
   17 CENTRAL ILLINOIS  LIGHT  CO.
   16 CENTRAL ILLINOIS  LIGHT  CO.
   19 CENTKAL ILLINOIS  LIGHT  CO.
   20 CENTRAL ILLINOIS  PUBLIC SEKV
   21 CINCINNATI  GAS £  ELECTRIC  CO.
   22 CINCINNATI  bftS &  ELECTKIC  (.0.
   23 COLUMBUS  &  SOUTHERN OHIO ELEC.
   2<* COLUMBUS  &  SOUTHERN OHIO ELEC.
   2b CULUf-iLtUS  &  SOUTHERN OHIO ELEC.
   26 COLUMBUS  £  SGUTHErtN OHIO ELEC.
   27 COMtiOUWEALTH EDISON
   26 COMNOiMWEALTH EDISON
   29 DETROIT EDISON
   30 UUQUESNE  LIGHT
   31 DUQUESNE  LIGHT
   32 GENERAL MOTORS
   33 GULF POWER  CO.
   ZH GULF POWER  CO.
   35 GULF POWER  CO.
TOMBIGBEE NO. 2
TUMU1GBEE NO. 3
PLEwSANTS NO. 1
PLEMSANTS NO. 2
APACHL NO 2
APALHE NO 3
ChOLLA NO 1
CHOLLA NO 2
FOUH CORNERS NO. H
FOUK CORNERS NO. 5A
FOUR CORNERS NO. SB
BEJLAH I\i0. 1
BtULAH NO. 2
MISSOURI BASIN NO 1
MISSOUK1 BASIN NO 2
MISSOURI BASIN NO 3
DUCK CREEK NO.l
DUCK CREEK NO.2
E.D.EDwAKDS NO.3
NLWTON NO.l
EAST E3END NO 2
MIAMI FONT NO 6
COULSVILLE NO 5
CUNCSVILLE NO 6
POSTON NO. 5
FUSION NO. 6
UILL COUNTY NO 1
PUWE.RTON NO. 51
ST.CLAIR NO 6
ELRAMA
PHILLIPS
CHEVROLET PARMA 1 2 3 &
SCHOL2 NO. 1A
SCHOLZ NO. 2A
SCHOLZ NOS. IB & 2B
JACKSON ALABAMA
JACKSON ALABAMA
BELLMONT W VIRGINIA
HELLMONT W VIRGINIA
COCHISE ARIZONA
COCHISE ARIZONA
JOSEPH CITY ARIZONA
JOSLPH CITY ARIZONA
FARMINGTOU NEW MEXICO
FAkMlNGTUN NEW MEXICO
FARMINbTON NEW MEXICO
BEULAH  NORTH DAKOTA
BEULAH  NORTH UAKOTA
WHEATLANO WYOMING
WHEATLAUO WYOMING
UHtATLAND WYOMING
CANTON ILLINOIS
CANTON ILLINOIS
BAKTONVILLE ILLINOIS
NEWTON ILLINOIS
RABBIT HASH KENTUCKY
NOKTH BEND OHIO
CONESVILLE OHIO
CONESVILLE OHIO
ATHLNS OHIO
ATHENS OHIO
ROftLOVILLE ILLINOIS
PEKIN  ILLINOIS
BELLE RIVER MICHIGAN
ELRAMA PENNSYLVANIA
SOUTH HEIGHT PENNSYLVANIA
PAKMA OHIO
CHATTAHOOCHEE  FLORIDA
CHATTAhOOCHEE  FLORIDA
CHATTAHOOCHEE  FLORIDA
1.  OPERATIONAL UNITS           "».
2.  UMTS UNDER CONSTRUCTION    5.
3.  PLANNED - CONTRACT AWARDED  6.
                                 PLANNED - LETTER OF  INTENT SIGNED
                                 PLANNED - REQUESTING/EVALUATING  BIDS
                                 CONSIDERING ONLY FGD SYSTEMS
A.  BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
B   BOILER SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
C.  BOILER SUBJECT To STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
0.  OTHER
E.  REGULATORY CLASS UNKNOWN
 3-78
 3-79
 3-79
 3-bO
 6-79
 6-79
10-73
 6-77
 0- 0
 2-76
 0- 0
 0-61
 0-61
 1-60
 6-60
 6-63
 6-7&
 1-61
 7-79
12-77
 1-60
 1-76
 6-76
 1-78
 0-ttl
 0-63
 2-72
12-79
 3-76
10-75
 7-73
 3-7H
 2-75
 2-76
 3-75
3
3
6
6

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                                         TABLE 1
                              SUMMARY LIST OF FGO SYSTEMS
 FGD STATUS REPORT  03/76

 I.D. NUMBER  AND COMPANY  NAME
   UNIT NAME
                                      LOCATION
                                                                                            START UP DATE   STATUS
                                                      REG
                                                      CLASS
   36  INDIANAPOLIS POWER  *  LIGHT  CO.
   37  KANSAS  CITY POWER i. LlbHT
   36  KANSAS  CITY POWER & LIGHT
   39  KANSAS  CITY POWER g LIGHT
   HO  KANSAS  POWER *  LIGHT
   41  KANSAS  POWER &  LIGHT
   HZ  KANSAS  POWER *  LIGHT
   43  KANSAS  POWLR X  LIGHT
   44  KENTUCKY  UTILITIES
   H5  KEY  WEST  UTILITY UOAKU
   46  LOUISVILLE GAS  & ELECTRIC
   47  LOUISVILLE GAS  & E.LECTKIC
   46  LOUISVILLE GAS  & LLECTHIC
   49  LOUISVILLE GAS  & ELECTRIC
   50  LOUISVILLE GAS  8 ELECTRIC
   51  LOUISVILLE GAS  & ELECTRIC
   52  LOUISVILLE GAS  & ELECTRIC
   53  LOUISVILLE GAS  & ELECTRIC
   54  M1NNKOTA  POWER  COOPERATIVE
   55  MONTANA POwER CO.
   56  MONTANA POWER CO.
   57  MONTANA POWER CO.
   56  MONTANA POWER CO.
   59  NEVADA  POWER
   60  NEVADA  POWER
   61  NEVADA  POWER
   62  NEVADA  POWER
   63  NEVADA  POWER
   64  NEVADA  POWER
   65  NEVADA  POWER
   66  NEVADA  POWER
   67  NEVADA  POWER
   66  NEVADA  POWER
   69  NEW ENGLAND  ELEC SYSTEM
   70  NORTHERN  INDIANA PUB SERVICE
              UNITS  1  AND 2
                                PETERSBURG NO 3
                                HAWTHORN NO 3
                                HAWTHORN NO 4
                                LA CYGNE NO 1
                                JLFFEKY NO. 1
                                JEFFERY NO. 2
                                LAWKENCE NO 4
                                LAWRENCE NO 5
                                GREEN RIVER
                                STOCK ISLAND PLANT
                                CANE RUN NO 4
                                CANE KUN NO 5
                                CANE KUN NO 6
                                MILL CREEK NO 1
                                MILL CREEK NO 2  ,
                                MILL CREEK NO 3
                                MILL CREEK NO 4
                                PADDYS RUN NO 6
                                MILTON R. YOUNG  NO.  2
                                COLSTRIP NO 1
                                COLSTRIP iMU 2
                                CULSTRIP NO.3
                                COL5.TRIP (MO.4
                                HArtKY ALLEN STATION  NO.  1
                                HARRY ALLEN STATION  NO.  2
                                HARKY ALLEN STATION  NO.  3
                                HARRY ALLEN STATION  NO.  4
                                REIU  GARDNER  NO  1
                                REIU  GARDNER  NO  2
                                REIU  GARDNER  NO  3
                                REID  GARDNER  NO  4
                                WARNER  VALLEY  STATION NO. 1
                                WARNER  VALLEY  STATION NO. 2
                                BRAYTON POINT  NO.3
                                BAILLY  NO.  7
PETERSBURG INDIANA
KANSAS CITY MISSOURI
KANSAS CITY MISSOURI
LA CYGNE KANSAS
ST MANY KANSAS
ST MARY KANSAS
LAWRENCE KANSAS
LAWRENCE KANSAS
CENTRAL CITY KENTUCKY
KEY WEST FLORIDA
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
CENTER NORTH DAKOTA
COLSTRIP MONTANA
coLSTRiH MONTANA
COLSTRIP MONTANA
COLSTRIP MONTANA
                                   E.  LAS VEGAS
                                   E.  LAS VEGAS
                                   E.  LAS VEGAS
                                   E.  LAS VEGAS
                                      NEVADA
                                HOAPA  NEVADA
                                HOAPA  NEVADA
                                MOAPA  NEVADA
                                ST. GEORGE  UTAH
                                ST. GEORGE  UTAH
                                SOMERSET MASSACHUSETTS
                                CHESTERTON INDIANA
1.  OPERATIONAL UNITS
2.  UNITS UNDER CONSTRUCTION
3.  PLANNED - CONTRACT AWARDED
I*.
C.
D.
E.
PLANNED - LETTER OF INTENT SIGNED
PLANNED > REQUESTING/EVALUATING BIDS
CONSIDERING ONLY FGD SYSTEMS
                            4.
                            5.
                            6.

BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
BOILEK SUBJECT TO STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
BOILER SUBJECT To STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
OTHER
REGULATORY CLASS UNKNOWN
 4-77
11-72
 6-72
 2-73
 6-76
 6-79
12-66
11-71
 9-75
10-72
 6-76
12-77
 9-76
 1-62
 1-61
 7-77
 7-79
 4-73
 6-77
10-75
 7-76
 7-60
 7-81
 6-62
 6-63
 6-64
 6-65
 4-74
12-73
 6-76
 0-  0
 6-61
 6-62
 0-  0
 0-  0
2
1
1
1
3
3
1
1
1
1
2
2
5
6
6
2
3
1
2
1
2
6
6
6
6
6
6
1
1
2
4
6
6
6
6
A
B
B
C
B
B
D
0
C
C
C
C
C
C
C
A
A
C
B
C
A
A
A
B
B
B
B
B
B
B
B
B
B
C
C
                                                                                                     PEDCo-ENVIRONMENTAL,

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                                          TABLE 1
                               SUMMARY LIST OF FGO SYSTEMS
  FGD STATUS REPORT 03/76

  I.D. NUMBER AMU COMPANY NAME
                                    UNIT NAME
                                       LOCATION
   START UP DATE   STATUS
                   REG
                   CLASS
   71 NORTHERN INDIANA PUD SERVICE
   72 NORTHERN INDIANA PUU SERVICE
   73 NORTHERN STATES POWER CO.
   7«» NORTHERN STATES POUER CO.
   75 PENNSYLVANIA POWER CO.
   76 PENNSYLVANIA POWER CO.
   77 PENNSYLVANIA POWER CO.
   76 PHILADELPHIA ELECTRIC CO.
   79 PHILADELPHIA ELECTRIC CO.
   80 PHILADELPHIA ELECTRIC CO.
   81 PHILADELPHIA ELECTRIC CO.
   82 PUBLIC SERVICE CO OF NEW MEX.
   83 PUBLIC SERVICE CO OF NEW MEX.
   84 PUBLIC SERVICE CO OF NEW MEX.
   85 PUBLIC SERVICE CO OF NEW MEX.
   86 PUBLIC SERVICE CO. OF COLORADO
   87 PUBLIC SERVICE INDIANA
   88 PUPLIC SERVICE INDIANA
   69 hICKENBACKER AFU
   90 S. CAROLINA PUB SERV AUTHORITY
   91 S. MISSISSIPPI ELEC PWK ASSOC
   92 S. MISSISSIPPI ELEC PWK ASSOC
   93 SOUTHLRN CALIFORNIA EDISON
   94 SOUTHERN CALIFORNIA EDISON
   95 SOUTHERN CALIFORNIA EDISON
   96 SOUTHERN CALIFORNIA EDISON
   97 SOUTHERN CALIFORNIA EDISON
   98 SOUTHERN CALIFORNIA EDISON
   99 SPRINGFIELO LITY UTILITIES
  100 TENNESSEE VALLEY AUTHORITY
  101 TENNESSEE VALLEY AUTHORITY
  102 TENNESSEE VALLEY AUTHORITY
  103 TEXAS UTILITIES CO.
  104 TEXAS UTILIT1F.S CO.
  105 TEXAS UTILITIES CO.
                                 BAILLY NO, 8
                                 MITCHELL NO 11
                                 SHERUURKE NO 1
                                 SHERliURNE NO 2
                                 BKUCE MANSFIELD NO* 1
                                 BKUCE MANSFIELD NO. 2
                                 BRUCE MANSFIELD NO. 3
                                 CROliBY
                                 EDIJYSTONE NO 1A
                                 EUDYSTOWE NO IB
                                 EUDYSTONE NO 2
                                 SAN JUAN NO. 1
                                 SAN JUAN NO. 2
                                 SAN JUAN NO. 3
                                 SAN JUAN NO. 4
                                 VALMONT NO. 5
                                 GIBSON NO. 3
                                 GIBSON NO. i»
                                 RICKENdACKER
                                 W1NYAH NO, 2
                                 R.D. MORROW NO.l
                                 R.O. MORROW NO.2
                                 KAIPAKOWITZ NO. 1
                                 KAIPAKOWITZ NO. 2
                                 KAIPAROWITZ NO. 3
                                 KAIPAHOWITZ NO. I*
                                 MOHAVE NO IB
                                 MOHAVE NO. 2
                                 SOUTHWEST NO. 1
                                 SHAWNEE N0.10A
                                 SHAWNEE NO.lOB
                                 WIDOWS CREEK NO 8
                                 MARTIN LAKE NO. i
                                 MARTIN LAKE NO. 2
                                 MARTIN LAKE NO. 3
                                CHESTERTON INDIANA
                                OAKY INDIANA
                                BECKER MINNESOTA
                                BECKER MINNESOTA
                                SHIPPINliPORT PENNSYLVANIA
                                SHIPPINGPORT PENNSYLVANIA
                                SH1HPINGPORT PENNSYLVANIA
                                PHOLNIXVILLE PENNSYLVANIA
                                EDDYSTONE PENNSYLVANIA
                                EUDYSTONE PENNSYLVANIA
                                EDDYSTONE PENNSYLVANIA
                                UATERFLOW NEW MEXICO
                                WATERFLOW NEW MEXICO
                                WATERFLOW NEW MEXICO
                                WATERFLOW NEW MEXICO
                                VALMONT COLORADO
                                GIbSON COUNTY INDIANA
                                GIBSON COUNTY INDIANA
                                COLUMBUS OHIO
                                GEORGETOWN SOUTH CAROLINA
                                HATTIESBURG MISSISSIPPI
                                HATTlESBURG MISSISSIPPI
                                UTAH   35 MI. NW OF PAGE
                                UTAH   35 MI. NW OF PAGE
                                UTAH   35 MI. NW OF PAGE
                                UTAH   35 MI. NW OF PAGE
                                LAUGHLiu NEVADA
                                LAUGHLIN NEVADA
                                SPK1NO.FIELU MISSOURI
                                PAUUCAH KENTUCKY
                                PADUCAH KENTUCKY
                                BRIDGEPORT ALABAMA
                                TATUM TEXAS
                                TATUM TEXAS
                                TATUM  REXAS
ARIZ
ARIZ
ARIZ
ARIZ
1.
2.
3.

A.
B.
C.
D.
E.
OPERATIONAL UNITS           4.
UNITS UNDER CONSTRUCTION    5.
PLANNED - CONTRACT AWARDED  b.
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
CONSIDERING ONLY FGD SYSTEMS
 0- 0
 4-76
 5-76
 5-77
 4-76
 4-77
 4-79
10-78
 9-75
10-78
10-78
 7-77
 7-77
 5-79
 5-61
10-74
 0-78
 0-79
 3-76
 5-77
11-77
 6-78
 0-82
 0-83
 0-64
 0-65
 6-77
 6-77
 7-76
 4-72
 4-72
 2-77
 9-76
 6-77
12-76
6
2
2
2
2
2
5
6
1
4
6
3
3
4
4
1
6
6
2
3
3
3
6
6
6
6
6
6
2
1
1
2
3
3
4
C
C
B
B
B
B
B
C
B
B
C
B
B
B
B
D
A
A
E
A
A
A
A
A
A
A
E
E
A
C
C
C
A
A
A
BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
BOILER SUBJECT To STATE STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
BOILER SUBJECT To STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
OTHER
REGULATORY CLASS UNKNOWN
                                                                                                     PEDCo-ENVIRONMENTAL

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                                        TABLE  1
                             SUMMARY  LIST  OF FGO  SYSTEMS
FGD STATUS REPORT 03/76

I.D. NUMBER AND COMPANY NAME
                                       UNIT NAME
                                                                         LOCATION
                                                                                               START UP DATE   STATUS
                                                                                    REG
                                                                                    CLASS
106 TEXAS UTILITIES CO..
107 UNITED POWER ASSOCIATION
106'UNITED POWER ASSOCIATION
109 UTAH POWER ft LIGHT CO.
                                    MAKTIN  LAKE  NO. t
                                    COAL  CREEK NO. 1
                                    COAL  CREEK NO. 2
                                    HUNTINGTON NO.l
                               TATUM  KEXAS
                               UNUEKWOOD  NORTH  DAKOTA
                               UNDERWOOD  NORTH  DAKOTA
                               PRICE UTAH
12-79
11-76
11-79
 6-77
5
5
A
A
A
E
1.  OPLKATIONM. UNITS
2.  UNITS UNDER CONSTRUCTION
3.  PLANNED - CONTKACT AWARDED
!'
I'.
D.
E.
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
CONSIDERING ONLY FGD SYSTEMS
                               5.
                               6.
     ln SUECO                             STRINGENT  THAN  THE  FEDERAL NSPS
   mill* SSK1S 10  UTE STANDARD THAT is EQUAL TO OR LESS STRINGENT  THAN NSPS
   OTHER
   REGULATORY CLASS UNKNOWN
                                                                                                    PEDCO- ENVIRONMENTAL
                                                            8

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       Table 2



STATUS OF FGD SYSTEMS

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 COMPANY
           TABLE 2
STATUS OF FtiU SYSTEMS DURING  03/76
 POWER STATION
                                                         CURRENT MONTH
I.D. NUMBER    1
ALABAMA ELECTRIC COOP
TOMBIGBEE NO. 2
  225  MM - NEW
COAL   0.8- 1.5 PERCENT SULFUR
PEABODY ENGINEERING
LIMESTONE SCRUBBING
STARTUP   3/78
    PEABOOY ENGINEERING WAS AWARDED CONTRACT TO INSTALL FGD SYSTEM ON
    TOM8IGBEE NO.2. SYSTEM WILL BE LIMESTONE SCRUBBING.
I.D. NUPBER    2
ALABAMA ELECTRIC COOP
TOMBIGBEE NO. 3
  225  MW - NEW
COAL   0.8- 1.5 PERCENT SULFUR
PEABOOY ENGINEERING
LIMESTONE SCRUBBING
STARTUP   3/79
    PEABODY ENGINEERING WAS AWARDED CONTRACT TO INSTALL FGD SYSTEM ON
    TOMBIGBEE NO.3. SYSTEM WILL BE LIMESTONE SCRUBBING.
I.D. NUMDER    3
ALLEGHENY POWER SYSTEM
PLEASANTS NO. 1
  625  MW - NEW
COAL   2.0- 5.0 PERCENT SULFUR
NOT SELECTED
LIME SCRUBBING
STARTUP   3/79
    THE THREE PRINCIPAL OPERATING UTILITY COMPANIES OF THE ALLEGHENY POWER
    SYSTEM HAVE CONCLUDED A LONG-TERM AGREEMENT WITH THE DRAVO LIMt CO. TO
    SUPPLY THIUSORBIC LIME FOR THE PLANNED Su2 SCRUBBERS AT PLEASANTS NOS. 1
    AND 2. THE SYSTEM SUPPLIER HAS NOT YET BLEN OFFICIALLY ANNOUNCED. THE
    GUARANTEED PARTICIPATE. AND S02 REMOVAL EFFICIENCIES FOR THIS EMISSION
    CONTROL SYSTEM ARE. 99.55 AND 90 PERCENT RESPECTIVELY
1.0. NUMBER    
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                                             TABLE 2
                                  STATUS OF FGU SYSTEMS DURING
 COMPANY

 POWER STATION

I.D. NUMltLR    f>
ARIZONA ELECTRIC POWER COOP
APACHE NO 3
  205  MW - NEW
COAL   O.b- 0.8 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE SCRUBBING
STARTUP   6/79

I.D. NUNbER    7
ARIZONA PUBLIC SERVICE
CHOLLA NO 1
  115  MW - RETROFIT
COAL   0.<*«*-! PERCENT SULFUR
RESEARCH COTTKELL
LIMESTONE SCRUBBING
STARTUP  10/73

I.D.  NUMbER     6
ARIZONA  PUBLIC  SERVICE
CHOLLA NU  2
  250  MW  -  NEW
COAL    0.«Ht-l PERCENT  SULFUR
RESEARCH COTTRELL
 LIMESTONE  SCRUBBING
 STARTUP   6/77               :  	[
                           03/76
                    CURRENT  MONTH

"rrTTPR~OF~INTENT~TO~INSTALL~AN FGD SYSTEM WAS ISSUEU TO RESEARCH COTTRELL,
 ENG!NEE«NG uEsIbi WORK is  PROCEEDING. GUARANTEED so2 AND PARTICULATE
 REMOVAL EFFICIENCIES ARE 50 AND 99.H PERCENT RESPECTIVELY.
                                         IN TABLE 3 OF J^u^^F ™IS
 crn «Y*TI.M HAS BLEW OPERATIONAL SINCE NOVEMBER 1973. RELIABILITY FOR
 MODULES' i AND B SS SS^ED IN EXCESS OF 90 ANO 83 ""CENT RESPECTIVELY
 SuRlNG THE PAST TEN OPERATING MONTHS. RELIABILITY FOR MODULES A AND B
 ?N JANUARY WAS 99 PERCENT. MODULE A WAS IN SERVICE 714.5 HRS. AND MODULE
 B fa5i.7 HRS. DURING THIS PERIOD.
                      ^SUBSTANTIALLY COMPLETE.  CONSTRUCTION  iS
 UNDERWAY
 I.D. NUMUER    9
 ARIZONA PUBLIC SERVICE
 FOUR CORNERS NO. "»
   755  MW - RETROFIT
 COAL. 0.7 - 0.758 SULFUR 
 NOT SELECTED
 NOT SELECTED
 STARTUP   O/ 0

 I.D. NUMBER   10
 ARIZONA PUBLIC SERVICE
 FOUR CORNERS NO. SA
   160  MW - RETROFIT
 COAL.  0.7 - 0.75. SULFUR  UVG)
 SCE
 LIME SCRUBBING
THIS
MAO?
           MW~UNIT~WILL''BE~CONTROLLED PENDING THE  OUTCOME OF  TESTS  TO  BE
          THE PROTOTYPE 160 -MW FGD MODULE NOW BEING INSTALLED ON UNIT  5.
 "THls"Ibo"Mw"sYSUN"HAs"BEEN"MOVEo"FKOM THE MOHAVE STATION OF SOUTHERN
  CALIFORNIA EDISON WHERE THE SYSTEM WAS PREVIOUSLY TESTED. THE SYSTEM

  TA  DTAlA trMwTNETr'THE'ENG^^^
  MMPLE?EO! ?H£ S?S?E; IT^TEO UP IN LATE FEBRUARY ANU THE UTILITY is
  CURRENTLY IN THE PROCESS OF CONDUCTING TESTS.
                                                                                                         PEDCo-ENVIRONMtNini.
                                                                11

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 COMPANY

 POWER STATION
           TABLE 2
STATUS OF F6D SYSTEMS DURING  03/76

                       CURKENT MONTH
1.0. NUMBER   11
ARIZONA PUBLIC SERVICE
FOUR CORNERS NO. SB
  595  NW - RETROFIT
COALt 0.7 - 0.75, SULFUR (AV6)
NOT SELECTED
NOT SELECTED
STARTUP .  O/ 0
    THE BALANCE OF THIS 755 MW UNIT MILL BE CONTROLLED PENDING THE OUTCOME
    OF TESTS TO BE MADE ON THE PROTOTYPE 160 MW FGD MODULE NOW BEING INSTALLED
    NO START-UP DATE HAS BEEN SCHEDULED.
I.D. NUMBER   12
BASIN ELLCTRIC POWER COOP
BEULAH NO. 1
  450  MW - NEW
COAL 1.0 PERCENT SuLFuR
NOT SELECTED
NOT SELECTED
STARTUP   0/81
                                                   THE UTILITY IS WOW
    INVESTIGATING VARIOUS FbU PROCESSES. THIS NEW STATION IS CURRENTLY CALLED
    THE BEULAH PROJECT AND WILL INCLUDE TWO NEW COAL-FIKED POWER-GENERATING
    BOILERS WHICH WILL BE REQUIRED TO COMPLY WITH AIR EMISSION STANDARDS VIA
    THE BEST AVAILABLE TECHNOLOGY.
I.D. NUMbER   13
BASfN ELECTRIC POWER COOP
BEULAH NO. 2
  450  Mn - NEW
COAL 1.0 PERCENT SuLFuR
NOT SELECTED
NOT SELECTED
STARTUP   0/81
                                                   THE UTILITY IS NOW
    INVESTIGATING VARIOUS FGD PROCESSES. THIS NEW STATION IS CURRENTLY CALLED
    THE. BEULAH PROJECT AND WILL INCLUDE TWO NEW COAL-FIRED POWER-GENEKATING
    BOILERS WHICH WILL BE REQUIRED TO COMPLY WITH AIR EMISSION STANDARDS VIA
    THE BEST AVAILABLE TECHNOLOGY.
I.D. NUMBER   14
BASIN ELLCTRIC POWER COOP
MISSOURI BASIN NO 1
  550  MW - NEW
COAL
NOT SELECTED
NOT SELECTED
STARTUP   1/80
    BECAUSE OF THE STRICT WYOMING EMISSION STANDARDS OF 0.2LBS PER MILLION
    BTUtLOU SULFUR COAL ALONE WILL NOT MEET STANDARDS.  BASIN ELECTRIC IS NOW
    INVESTIGATING VARIOUS FGD PROCESSES.
I.D. NUMBER   15
BASIN ELECTRIC POWER COOP
MISSOURI UASIN NO 2
  550  Mb - NEW
COAL
NOT SELECTED
NOT SELECTED
STARTUP   6/80
    BECAUSE OF THE STRICT WYOMING EMISSION STANDARDS OF 0.2LBS PER MILLION
    BTU.LOW SULFUR COAL ALONE WILL NOT MEET STANDARDS.  BASIN ELECTRIC IS NOW
    INVESTIGATING VARIOUS FGO PROCESSES.
                                                              12
                                                                      PEDCo-ENVIRONMENTAL

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 COMPANY
                                             TAULE 2
                                  STATUS OF FGD SYSTEMS DURING
                          03/76
 POWER STATION                                           CURRENT MONTH
I.D. NUMBER   16
BASIN ELECTRIC POWER COOP
MISSOURI UASIN NO  3
  550  MW - NEW
COAL
NOT SELECTED
NOT SELECTED
STARTUP   6/83
BECAUSE OF THE STRICT WYOMING EMISSION STANDARDS OF 0.2LBS PER MILLION
BTU.LOW SULFUR COAL ALONE WILL NOT MEET STANDARDS.  BASIN ELECTRIC IS NOW
INVESTIGATING VARIOUS FGD PROCESSES*
 I.D. NUMUER    17
 CENTRAL  ILLINOIS  LIGHT  CO.
 DUCK CKELK NO.l
   100  MW - i\EW
 COAL 2.5-3.0  PERCENT  SULFUR
 RILEY  STOrtER/ENVIRONEERING
 LIMESTONE SCRUBBING
 STARTUP   fa/76
THE UNIT IS NOW UNDER CONSTRUCTION AND IS SCHEDULED FOR COMPLETION IN
JUiME 1976. STATION CAPACITY IS HQOMW, BUT FLUE GAS FROM ONLY 100 MW
WILL BE TREATED INITIALLY.
.1.0.  NUMBER    18
 CENTRAL  ILLINOIS  LIGHT  CO.
 DUCK  CREEK NO.2
   i+OO MM  -  NEW
 COAL  2.5-3.0 PERCENT SULFUR
 NOT SELECTED
 LIMESTONE  SCRUBBING
 STARTUP    1/01
THIS PROPOSED LIMESTONE UNIT IS DUE TO BEGIN OPERATION JANUARY 1901
 1.0.  NUMJER   19
 CENTRAL ILLINOIS LIGHT CO.
 E.D.E.UWAKUS NO.3
   357  MW - RETROFIT
 COAL  2.5 PERCENT SULFUR
 NOT SELECTED
 NOT SELECTED
 STARTUP   7/79
                                       LOW SULFUR COAL TO BE USED FROM 6/76 UNTIL STARTUP.
 I.D. NUMbER   20
 CENTRAL ILLINOIS PUBLIC SERV
 NEWTON NU.l
   600  MW - NEW
 COAL 2.8-3.2 PERCENT SULFUR
 NOT SELECTED
 NOT SELECTED
 STARTUP  12/77
 THE  UTILITY  IS  NOW  IN  THE  PROCESS  OF EVALUATING  BIDS FOR LIME/LIMESTONE
 AND  DOUBLE ALKALI SCRUBBING.  A  DECISION  CONCERNING  THE  PARTICULAR PROCESS
 AND  VENDOR WILL BE  ANNOUNCED  SHORTLY.
                                                                                                   PEDCo-ENVIRONM&WTAt
                                                                 13

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 COMPANY
                                             TABLE 2
                                  STATUS OF FGD SYSTEMS DURING  03X76
 POWER STATION                                           CURRENT MONTH
1.0. NUPLiER   21
CINCINNATI GAS & ELECTRIC CO.
EAST OENU NO 2
  600  MM - NEW
COAL
NOT SELECTED
NOT SLLECTED
STARTUP  - 1/80
UTILITY WILL GO OUT FOR BIDS IN EARLY 1976. THE COMPANY IS PRESENTLY OB-
TAINING CONSTRUCTION AND OPERATIONG PERMITS. STARTUP DATE HAS BEEN MOVED
BACK TO JANUARY i960. THE COAL SOURCE FOR THIS UNIT HAS NOT YET BEEN SE-
LECTED.
I.D. NUMBER   22
CINCINNATI GAS S ELECTRIC CO.
MIAMI FOKT NO 8
  300  MW - NEW
COAL   1.3 PERCENT SULFUR
NOT SELECTED
LIME/LIMLSTONE SCABBING
STARTUP   1/78
THE UTILITY HAS SIGNED A CONTRACT FOR THE PURCHASE OF LOW SULFUR COAL
(APPROXIMATELY 1.3 PERCENT SULFUR). THE COAL BED FOR THE NO.8 UNIT IS NOW
IN THE PROCESS OF BEING REDESIGNED TO ACCEPT THE LOWER SULFUR COAL. CGSE
NOW PLANS TO INSTALL A LIME/LIMESTONE FGD UNIT TREATING 60 PERCENT OF THE
TOTAL bOO MW CAPACITY. NEW BIDS ARE NOW BEING REQUESTED AND ACCEPTED ON
THIS SMALLER UNIT.
I.D. NUMBER   23
COLUMBUS & SOUTHERN OHIO ELEC.
CONESVILLE NO 5
  HOO  M«l - NEW
COAL  4.5 - «t.9 PERCENT SULFUR
UNIVERSAL OIL PROUUCTS
LIME SCRUBBING
STARTUP   6/76
THE UTILITY SIGNED LONb-TERM CONTRACTS WITH DRAVO FOR THE PURCHASE OF
THIOSORBlC LIME ANH WITH IUCS FOR THE PURCHASE OF SLUDGE FIXATIVES. THE
BOILER ANU FGD SYSTEM ARE STILL UNOER CONSTRUCTION. THIS MINE MOUTH PLANT
PLANS TO BURN COAL WITH 17 PERCENT ASH CONTENT AND 4.5 TO 4.9 PERCENT
SULFUR CONTENT. AN ELECTROSTATIC PKECIPITATOR WILL BE INSTALLED UPSTREAM
OF THE FbD SYSTEM.
I.D. NUMbER   24
COLUMBUS & SOUTHERN OHIO ELEC.
CONESVILLL NO 6
  loo  MW - NEW
COAL  <*.£> - 4.9 PERCENT SULFUR
UNIVERSAL OIL PRODUCTS
LIME SCRL-HBING
STARTUP   1/78
THL UTILITY SIGNLD LONb-TERM CONTRACTS WITH DRAVO FOR THE PURCHASE OF
THIOSORBlC LIME AND WITH IUCS FOR THE PURCHASE OF SLUDGE FIXATIVES. CON-
STRUCTION ON THIS UNIT IS CURRENTLY SCHEDULED FOR 1977 WITH COMPLETION
EXPECTED BY JANUARY 1978. SIMILAR TO CONESVILLE NO.5, THIS MINE MOUTH
PLANT WILL BURN COAL WITH 17 PERCENT ASH CONTENT AND 4.5 TO 4.9 PERCENT
SULFUR CONTENT. AN ELECTROSTATIC PRECIPITATOR WILL BE INSTALLED UPSTREAM
OF THE FGD SYSTEM.
I.D. NUMBER   25
COLUMBUS & SOUTHERN OHIO ELEC.
POSTON NO. 5
  375  MW - NEW
COAL 2.5 PERCENT SULFUR
NOT SELECTED
NOT SELECTED
STARTUP   0/81
UNIT WILL BURN 2.5 PERCENT SULFUR OHIO COAL.
                                                                                                        PEDCo-ENVIRONMENT AL-
                                                                 14

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 COMPANY

 POWER STATION
           TABLE 2
STATUS OF FGO SYSTEMS DURING
       09/76

CURRENT MONTH
1.0. NUMBER   26
COLUMBUS H SOUTHERN OHIO ELEC.
POSTON NO. 6
  375  HW - NEW
COAL 2.5 PERCENT SULFUR
NOT SELECTED
NOT SELECTED
STARTUP   0/63
    UNIT WILL BURN 2.5 PERCENT SULFUR OHIO COAL.
I.D. NUMbLR   27
COMMONWEALTH EDISON
WILL COUNTY NO 1
  Ib7  MW - RLTROFIT
COAL - 9<*b3 BTU.   2.IK SULFUR
DAOCOCK & WILCOX
LIMESTONL SCRUBBING
STARTUP   2/72
    REFEK TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT.  THIS
    FGU SYSTEM HAS BLLN OPERATIONAL SINCE FEB. 1972. MOUULES A AND B WERE IN
    SEKVICE A TOTAL OF 3214 AND 2580 HhS. RESPECTIVELY DURING 1975, THUS AT-
    TAINING ANNUAL AVERAGL OPEKABlLlTlLS.OF 52 AND 12 PERCENT RESPECTIVELY.
    UNIT NO.l CAME DOWN FOK A BOILER. TURBINL AND GENERATOR OVERHAUL IN MID-
    OCTOBER 1975, RESULTING IN AN OUTAGE THAT LASTED FOR MORE THAN H MONTHS.
    SYSTLM RESTART IS CURRENTLY SCHEDULED FOR MID-MARCH 1976.
I.D. NUMBER   26
COMMONWEALTH EDISON
POWERTON HO. bl
  H25  Mw - RETROFIT
COAL 3.6 PERCENT SULFUR
UNIVERSAL OIL PRODUCTS
LIMESTONE SCRUBBING
STARTUP  12/79
    THE. CONTRACT FOR THIS FGD SYSTEM HAS BEEN AWARDED TO UNIVERSAL OIL
    PRODUCTS. THIS SYSTEM WILL BE A LIMESTONE CLOSED-LOOP SCRUBBING SYSTEM
    BACKFITTEO TO BOILER 51i  WHICH IS ONE OF TWO IDENTICAL BOILERS SUPPLYING
    STEAM TO AN 650 MW TURBINE-GENERATOR.
I.D. NUMBER   29
DETROIT EUISON
ST.CLAIR NO b
  160  MW - RETROFIT
COAL   3.7 PERCENT SULFUR
PEABOOY ENGINEERING
LIMESTONE SCRUBBING
STARTUP   3/76
    THE UTILITY REPORTED THAT THE FGD SYSTEM WAS DOWN THROUGHOUT THE ENTIRE
    REPORT PERIOD IN PREPARATION FOR AN UPCOMING 30 DAY VENDOR QUALIFICATION
    OPERATION TEST RUN.
I.D. NUMBER   30
DUQUESNE LIGHT
ELRAMA
  510  Mta - RETROFIT
COAL  1.0 - 2.8 PERCENT SULFUR
CHEMICO
LIME SCRUBBING
STARTUP  10/75
    THE FGO SYSTEM WAS PLACED IN SERVICE ON OCTOBER 26, 1975. INITIAL
    OPLRATION PROCEEDED WITH FLUE GAS FROM ONE BOILER BEING TREATED BY THE
    SCKUBBING SYSTEM. A SECOND BOILER WAS TIED INTO THE SYSTEM ON FEBRUARY «f,
    1976. TO DATE (JAN. 31,1976) •» OF THE 5 SCRUBBER VESSELS HAVE BEEN IN
    SERVICE IN VARIOUS COMBINATIONS FOK A TOTAL OF HH91 HRS. THE FIFTH VESSEL
    HAS NOT BEEN PLACED IN SEKVICE BECAUSE IT IS BEING REVISED FOR THE TRIAL
    INSTALLATION OF RUBBER-LINED RECYCLE PUMPS.
                                                               15
                                                                     PEDCo- ENVIRONMENTAL

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 COMPANY

 POWER STATION
           TABLE 2
STATUS OF FGD SYSTEMS L.UKING  03/76

                       CURRENT MONTH
I.D. NUMBER   31
OUOUESNE LIGHT
PHILLIPS
  «HO  MW - RETROFIT
COAL   1.0- 2.8 PERCENT SULFUR
CHEMICO
LIME SCRUBBING
STARTUP   7/73
    HEFEK TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS KEPURT.  THIS
    FGO SYSTEM HAS BLEW OPERATIONAL SINCE JULY 1974. THL UTILITY HAS RECENTLY
    TERMINATED A TWO AND A HALF MONTH TLST PROGRAM EMPLOYING THlOSORBlC LIME
    IN THE SINoLE STAGE. SCRUBBING MODULES. 1612 OPERATING HOURS WERE LOGGED
    BY ONE SCRUBBING TRAIN AND 1309 HOURS WERE LOGGED BY ANOTHER TRAIN. RE-
    SULTS INDICATE THAT THL .REQUIRED DEGREE OF S02 REMOVAL (63 PERCENT) CAN
    BE OUTAINED WITH SINGE STAliE SCRUBBING, EMPLOYING LIME WITH A MGO CON-
    TENT OF 6 TO 10 PERCEM.
I.D. NUMBER   32
GENERAL MOTORS
CHEVROLET PARMA 1 2 3 & H
   32  MW - RETROFIT
COAL   2.5 PERCENT SULFUR
KOCH
DOUBLE ALKALI
STARTUP   3/7<»
    REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
    FGU SYSTEM HAS BEEN OPERATIONAL SINCE MARCH 197t. SYSTEM OPERAUILITY HAS
    AVERAliCD OVER 59 PERCENT DURING THE PAST 6 MONTHS. SYSTEM OPERAUILITY WAS
    «»o PLRCLNT DURING THE REPORTING MONTHS. GM is CURRENTLY CONTINUING THEIR
    STUDY PROGRAM OF HIGH SOLIDS CARRYOVER IN THE SCRUBBING SOLUTION.
    PRLSENTLY THE COMPANY IS EVALUATING THE SETTLING OF SOLIDS IN THE SCRUB-
    BER SYSTEM CLARIFILR AND ANALYZING THE SOLIDS CONTENT OF THE CLARIFIER
    UNDERFLOW.
1.0. NUMBER   33
GULF POWER CO.
SCHOLZ NO. 1A
   20  MW - RETROFIT
COAL   3.0 PERCENT SULFUR
AOL/COMBUSTION EQUIP ASSOCIATE
DOUBLE ALKALI
STARTUP   2/75
    REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
    FGU SYSTEM HAS BEEN OPERATIONAL SINCE FEB. 1975. THE PROTOTYPE SYSTEM
    OPERATED A TOTAL OF H7W HRS. DURING 1975« TRANSLATING INTO AN ANNUAL
    AVLRAGL OPERAB1LITY OF 89 PERCENT. THL SYSTEM WAS DOWN THROUGHOUT THE RE-
    PORT PERIOD DUE TO A SCHEDULED PLANT BOILER OVERHAUL. SYSTEM RESTART IS
    SCHEDULED FOR MID-MARCH 1976. THE SYSTEM IS SCHEDULED TO RUN THROUGH TO
    JUNE 197b.
I.D. NUMbER   34
GULF POWER CO.
SCHOLZ NO. 2A
   20  Ml« - RETROFIT
COAL   3.0 PERCENT SULFUR
FOSTER WHEELER
ACTIVATED CARBON
STARTUP   2/7fa
    REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. SYSTEM
    MOUIFICATIONS AND PRE-STARTUP CHECKOUTS WERE COMPLETED. A SUCCESSFUL
    THREE DAY DRY RUN FOLLOWED. REINTRODUCTION OF FLUE GAS INTO THE SYSTEM
    COMMENCED IN FEBRUARY AND A FOUR MONTH TEST PROGRAM IS NOW IN PROGRESS.
    DURING THIS TEST PROGRAM S02. NOX. AND FLYASH REMOVAL PERFORMANCE. SYSTEM
    ECONOMICS ANU SYSTEM RELIABILITY WILL BE ANALYZED.
I.D. NUMbER   35
GULF POWER CO.
SCHOLZ NOS. IB * 2B
   23  MW - RETROFIT
COAL   3.0 PERCENT SULFUR
CHIYODA INTERNATIONAL
THOROUGHBRED 101
STARTUP  . 3/75
    REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF REPORT. THIS FGD
    SYSTEM HAS BEEN OPERATIONAL SINCE MARCH 1975. THE TOTAL SYSTEM OPEKABILI-
    TY» INCLUDING SYSTEM COMMISSIONING, EXTENDING FROM FEB. 11.197&, To
    DECEMBER 31, 1975, WAS 60 PERCENT. SYSTEM OPERABILITY FOR THE MONTH OF
    JANUARY 1976 EXCEEDED 66 PERCENT. THE SYSTEM DID NOT OPERATE DURING THE
    MONTH OF FEBRUARY.
                                                                                                        PEDCo-ENVIRONMENTAL
                                                              16

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 COMPANY

 POWER STATION
           TABLE 2
STATUS OF FGD SYSTEMS DURING  04X76

                       CURKENT MONTH
1.0. NUMBER   36
INDIANAPOLIS POWER & LIGHT CO.
PETERSOUKG NO 3
  530  Mm - NEW
COAL  3.U-3.5 PERCENT SULFUR
UNIVERSAL OIL PROUUCTS
LIMESTONE SCRUBBING
STARTUP  . 14/77
    UNIVERSAL OIL PRODUCTS HAS BEEN SELECTED To BUILD THE LIMESTONE SCRUBBING
    SYSTEM. THE ENTIRE 530MW UNIT WILL BE TREATED BY FOUR MODULES. CONSTRUC-
    TION HAS BEGUN ON ALL FOUR MODULES AND IS PROCEEDING ON SCHEDULE. WORK
    ON THE FOUNDATION AND INSTALLATION OF THE RECYCLE TANKS IS CURRENTLY IN
    PROGRESS.
I.D. NUMUER   37
KANSAS CITY POWER & LIGHT
HAWTHORN 140 3
  1«*0  Hta - RETROFIT
COAL   O.b- 3.0 PEhCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE INJECTION £WET SCRUB
STARTUP  11/72
    REFEK TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
    FGL) SYSTEM HAS BEEN OPERATIONAL SINCE NOVEMBER 1972. BOTH MODULES WERE
    DOWN THE ENTIRE MONTH OF JANUARY BECAUSE OF FKOZEN EQUIPMENT ANQ LINESi
    ANU A MANPOWER SHORTAGE. OPERABILlTY FOR MODULES A AND B DURING THE MONTH
    OF FEBRUARY WAS 37 AND 1 PLKCENT RESPECTIVELY.
I.D. NUMBER   38
KANSAS CITY POWER & LIGHT
HAWTHORN NO 4
  100  MW - RETROFIT
COAL   0.6- 3.0 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE INJECTION *W£T SCRUB
STARTUP   B/72
    REFER TO BACKGROUND INFORMATION-SECTION IN TABLE 3 OF'THIS REPORT. FGD
    SYSTEM HAS BEEN IN.OPERATION SINCE AUGUST 1972. BOTH MODULES WERE DOWN
    THE ENTIRE MONTH OF JANUARY BECAUSE OF FROZEN EQUIPMENT AND LINESi AND A
    MANPOWER SHORTAGE. OPERABILITY FOR MODULES A AND B WAS 0 AND 76 PERCENT
    RESPECTIVELY. MODULE A WAS INOPERATIVE ALL OF FEBRUARY BECAUSE OF THE
    CONTlNUTATION OF A PROBLEM WITH LOSS OF DRAFT THROUGH THE
    CONNECTING UUCTWORK.
I.D. NUMBER   39
KANSAS CITY POWER £ LIGHT
LA CYGNE NO 1
  620  MW - NEW
COAL   5.2 PERCENT SULFUR
BABCOCK £ WILCCX
LIMESTONE SCRUBBING
STARTUP   2/73
    REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
    FGU SYSTEM HAS BEEN OPERATIONAL SINCE FEB. 1973. THE ANNUAL AVERAGE
    AVAILABILITY FOR ALL 7 MODULES DURING 1975 WAS IN EXCESS OF 63 PERCENT
    (INCLUDING GENERATOR REPAIR OUTAGE TIME). THE UTILITY IS CURRENTLY PLAN-
    NING THE INSTALLATION OF AN EIGHTH MODULE, SCHEDULED TO BE PLACED IN
    SERVICE SOMETIME DURING THE SUMMER OF 1977.
I.D. NUMBER   HO
KANSAS POWER & LIGHT
JEFFERY NO. 1
  660  MW - NEW
COAL 0.32 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE SCRUBBING
STARTUP   6/76
    THE UTILITY HAS PURCHASED AN AIR QUALITY CONTROL SYSTEM FROM COMBUSTION
    ENGINEERING FOR PARTICIPATE AND S02 REMOVAL. THE SYSTEM WILL CONSIST OF
    AN ESP DOWNSTREAM OF THE AIR HEATER PLUS ID FANS AND SPRAY TOWERS. AN
    OVERFIRE AIK SYSTEM AT THE TANGENTIAL FIRED PULVERIZED BURNERS WILL CON-
    TROL THE NOX EMISSIONS. THE CLEANED GASES WILL BE VENTED TO A 600 FOOT
    STACK.
                                                                                                     PEDCO- ENVIRONMENTAL
                                                                17

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 COMPANY

 POWLR STATION
                                             TABLE. 2
                                  STATUS OF FGD SYSTEMS UUhING
                          03/76
                   CURKENT MONTH
i.u. NUMBER   41
KANSAS POWER S LIGHT
JEFFERY KO. 2
  600  MW - NEW
COAL 0.32 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE SCRUBBING
STARTUP   6/79
THE UTILITY HAS PURCHASED AN A1K QUALITY CONTROL SYSTEM FROM COMBUSTION
ENGINEERING FOR PARTICULAR AND S02 REMOVAL. THE SYSTEM WILL CONSIST OF
AN ESP UOWNSTREAi"i OF THE AIR MEATLR PLUS ID FANS ANU SPRAY TOWERS. AN
OVt-RFIRE AIR SYSTEM AT THE TANGENTIAL FIRED PULVERIZED BURNERS WILL CON-
TROL THE NOX EMISSIONS. THE CLEANED GASES WILL BE VENTED TO A 600 FOOT
STACK.
I.D. NUMUER   42
KANSAS POWER 8 LIGHT
LAWRENCE NO 4
  125  MW - RETROFIT
COAL 0.5 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONt INJECTION *U£T SCRUB
STARTUP  12/66
REFER TO BACKGROUND INFORMATION SECTION IN TABLE a OF THIS REPORT. THIS
FGu SYSTEM HAS BEEN OPERATIONAL SINCE DECEMBER 1966. THIS UNIT IS CUR-
RENTLY BURNING LOW SULFUR WYOMING COAL. THE OPERATION OF THE SCRUBBER HAS
BEEN MORE EFFICIENT AND ECONOMICAL FOR THIS COAL TYPE BECAUSE A LESSER
OEiiREE OF S02 REMOVAL IS REUUIRED FOR COMPLIANCE. THE UTILlTy PLANS TO
REPLACE THIS SCRUBbING SYSTEM WITH A VENTRI-ROO AND SPRAY TOWER SCRUBBING
SYSTLM.
I.D. NUMBER   43
KANSAS POWER * LIGHT
LAWRENCE NO 5
  400  Mw - NEW
COAL 0.5 PERCENT SuLFUR
COMHUSTIOU ENGINEERING
LIMESTONE INJECTION &WET SCRUB
STARTUP  11/71
REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
FGU SYSTEM HAS BEEN OPERATIONAL SINCE NOVEMBER 1971. THIS UNIT IS CUR-
RENTLY BURNING LOW SULFUR WYOMING COAL. THE OPERATlON OF THE SCRUBBER HAS
BEEN MORE EFFICIENT AND ECONOMICAL FOR THIS COAL TYPE BECAUSE A LESSER
DEbHEE OF S02 REMOVAL IS REQUIRED FOR COMPLIANCE. THE UTILITY PLANS TO
REPLACE THIS SCRUBBING SYSTEM WITH A VENTRI-ROD AND SPRAY TOWER SCRUBBING
SYSTEM.
I.D. NUMBER   44
KENTUCKY UTILITIES
GREEN RIVER   UNITS 1 AND
   64  MH - RETROFIT
COAL  3.6 PERCENT SULFuR
AMERICAN AIR FILTER
LIME SCRUBBING
STARTUP   9/75
REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
SYSTEM BECAME OPERATIONAL SEPTEMBER 13,1975. OPERATION IS CURRLNTLY
BEING CONDUCTED ON A HALF-LOAD BASIS BECAUSE OF A TURBINE REPAIR.
OPERATIONAL DATA AVAILABLE FOR THE HAST THREE MONTHS SHOWS THAT SYSTEM
AVAILABILITY. OPERABILITY AND UTILISATION HAVE AVERAGED 62, 39. AND 25
PERCENT RESPECTIVELY. SYSTEM OUTAGES HAVE RESULTED FROM MINOR MECHANICAL
STARTUP PROBLEMS AND COMPONENT CLEANOUTS. THE SYSTEM IS NOW BEING PRE-
PARED FOR AN EXTENDED RELIABILITY TEST PROGRAM.
 I.D. NUMBER   45
 KEY WEST UTILITY BOARD
 STOCK  ISLAND PLANT
   37  MW - NEW
 OIL    2.4 PERCENT SULFUR
 ZURN AIR SYSTEMS
 LIMESTONE SCRUBBING
 STARTUP  10/72
REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
FGO SYSTEM HAS BEEN OPERATIONAL SINCE OCTOBER 1972. THE FGD SYSTEM HAS
BEEN OUT OF SERVICE SINCE JANUARY 28.1975. MODIFICATIONS AND REPAIRS ARE
CURRENTLY IN PROGRESS. SYSTEM RESTART IS AT LEAST A MONTH AWAY. CHECKOUT
OF ALL SYSTEM MOTORS AND PUMPS MUST BE COMPLETED BEFORE STARTUP CAN
COMMENCE.
                                                                                                       PEDCo-ENVIRONMENTAL
                                                                18

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 COMPANY
                                             TABLE 2
                                  STATUS OF F6D SYSTEMS DURING
                          03/76
 POWER STATION
                                                         CURRENT MONTH
I.D. NUHBE.R   16
LOUISVILLE GAS & ELECTRIC
CANE RUN NO t
  178  MW - RETROFIT
COAL   3.5-I4.0S PERCENT SULFUR
AMERICAN AIR FILTER
LIME SCRUBBING
STARTUP   6/7fa
THE. UTILITY HAS SIGNLD A CONSENT AGKEEKENT WITH THE EPA FOR THE INSTAL-
LATION AND OPERATION OF FGD EQUIPMENT ON THIS UNIT BY JUNE 1,1976. THE
CONTRACT HAS UEEN AWARoEU TO AMERICAN AIR FILTER. THE SYSTEM WILL OPERATE
ON A CLOSED WATER LOOP AND THE SLUDGE WILL BE STABILIZED. THIS SYSTEM IS
PRESENTLY UNDER CONSTRUCTION.
I.D. NUMBER   «»7
LOUISVILLE GAS & ELECTRIC
CANE RUN NO 5
  163  PW - RETROFIT
COAL   3.5-4.U5 PERCENT SULFUR
COMBUSTION ENGINEERING
LIME SCRUBBING
STARTUP  12/77
THE UTILITY HAS SIGNED A CONSENT AGREEMENT WITH THE EPA FOR THE INSTAL-
LATION AND OPERATION OF FGD EQUIPMENT ON THIS UNIT BY DECEMBER 1,1977.
THE. CONTRACT FOR THIS LIME SCRUBBING SYSTEM HAS BEEN AWARDED TO
COMBUSTION ENGINEERING. THE UNIT IS PRESENTLY UNDER CONSTRUCTION.
I.D. NUMBER   <»8
LOUISVILLE GAS & ELECTRIC
CANE RUN NO 6
  277  MU - RETROFIT
COAL   3.5- f.O PERCENT SULFUR
NOT SELECTED
LIME SCRUBBING
STARTUP   9/70
THE UTILITY HAS SIGNED A CONSENT AGREEMENT WITH THE EPA FOR THE INSTAL-
LATION AND OPERATION OF FGD EQUIPMENT ON THIS UNIT BY SEPTEMBER 1,1978.
THE UNIT IS PRESENTLY OUT FOR BIDS.
I.U. NUMbER   49
LOUISVILLE GAS & ELECTRIC
MILL CREEK NO 1
  330  MW - RETROFIT
COAL   3.5- "*.0 PERCENT SULFUR
NOT SELECTED
LIME SCRUBBING
STARTUP   1/82
A COMPLIANCE SCHEDULE HAS BEEN SUBMITTED TO THE JEFFERSON COuNTY AIR POL-
LUTION CONTROL DISTRICT WITH 1/62 ESTABLISHED AS THE STARTUP DATE FOR AN
FGO SYSTEM.
I.D. NUMBER   50
LOUISVILLE GAS & ELECTRIC
MILL CREEK NO 2
  330  MW - RETROFIT
COAL   3.5- 4.0 PERCENT SULFUR
NOT SELECTED
LIME SCRUBBING
STARTUP   1/81
A COMPLIANCE SCHEDULE HAS BEEN SUBMITTED TO THE JEFFERSON COUNTY AIR POL-
LUTION CONTROL DISTRICT WITH 1/81 ESTABLISHED AS THE STARTUP DATE FOR AN
FGO SYSTEM.
                                                                                                         PEDCo- ENVIRONMENTAL
                                                               19

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 COMPANY
                                             TABLE 2
                                  STATUS OF FGD SYSTEMS uURING  03/76
 POWER STATION                              '             CURRENT MONTH
I.D. NUMULR   51
LOUISVILLE GAS X ELECTRIC
MILL CREEK NO 3
  i»25  MW - NEW
COAL   3.5- H.O PERCENT SULFUR
AMERICAN AIK FILTER
LIME SCRUBBING
STARTUP   7/77
THE UTILITY HAS SIGNLD A CONSENT AGREEMENT WITH THE LPA FOR TH£ INSTAL-
LATION AND OPERATION OF FGU EQUIPMENT OiM THIS POwEK GENERATING UNIT BY
JULY 1,1977. THIS NEW FACILITY WILL BE REQUIRED TO MEET FEDERAL NSPS FOR
THE LIMITATION OF S02 LMISSIONS. CONTRACT HAS bEEN AWARDED TO AMERICAN
AIK FILTER. THE SYSTEM WILL OPERATE ON A CLOSED WATER LOOP AND THE SLUDGE
WILL BE STABILIZED. CONSTRUCTION HAS BEGUN ON THE FGD SYSTEM.
I.D. NUMBER   52
LOUISVILLE GAS & ELECTRIC
MILL CREEK NO H
  <«25  MW - NEW
COAL   3.5- "».0 PERCENT SULFUR
AMERICAN AIR FILTER
LIME SCRUBBING
STARTUP   7/79
THE UTILITY HAS SIGNED A CONSENT AGREEMENT WITH THE LPA FOR THE INSTAL-
LATION AND OPERATION OF FGD EQUIPMENT ON THIS POWER GENERATING UNIT BY
JULY 1,1979. THIS NEW FACILITY WILL BE REQUIRED TO MEET FEDERAL NSPS FOR
THE LIMITATION OF S02 EMISSIONS. THE CONTRACT HAS BEEN AWARDED TO
AMERICAN AIR FILTER FOR A LIME SCRUBBING SYSTEM.
I.D. NUMBER   53
LOUISVILLE GAS & ELECTRIC
PADDYS RUN NO 6
   65  MW - RETROFIT
COAL  3.b-<».0 PERCENT SULFUR
COMBUSTION ENGINEERING
LIME SCRUbBlUt
STARTUP   
-------
 COMPANY

 POWER STATION
           TABLE 2
STATUS OF F60 SYSTEMS DURING
                                                                03/76
                                                         CUKKENT MONTH
I.D. NUMBER   56
MONTANA POWER CO.
COLSTRIP NO 2
  360  MM - NEW
COAL   O.B PERCENT SULFUR
COMBUSTION EQUIP. ASSOCIATES
LIME SCRUUBING
STARTUP   7/76
    THE FGD SYSTEM IS CURRENTLY UNDER CONSTRUCTION. TURBINE ROLL AND SYSTEM
    CHECKOUT HAS BEEN DELAYED A MONTH AND A HALF TO MID-JUNE 1976. NO DELAYS
    IN THE JULY 1976 STARTUP DATE ARE FORESEEN AT THE PRESENT TIME.
I.D. NUMIJER   57
MONTANA POWER CO.
COLSTKIP NO.3
  700  MW - NEW
COAL  0.7 PERCENT SULFUR
NOT SELECTED
NOT SELECTED
STARTUP   7/80
    THE UTILITY IS CURRENTLY WAITING FOR APPROVAL OF A CERTIFICATE TO
    CONSTRUCT BOILERS 3 AND <+ BEFORE PROCEEDING WITH ORDLRS TO INSTALL FGD
    SYSTEMS. THE FGD PROCESS BEING GIVEN PRIME CONSIDERATION FOR UNITS 3 AND
    4 IS THE CEA LIME SCRUBBING SYSTEM NOW OPERATING AND BEING INSTALLED ON
    UNITS 1 AND 2 RESPECTIVELY.
I.D. NUMBER   58
MONTANA POWER CO.
COLSTRIP NO.i*
  700  MW - NEW
COAL  0.7 PERCENT SULFUR
NOT SELECTED
NOT SELECTED
STARTUP   7/81
    THE UTILITY IS CURRENTLY WAITING FOK APPROVAL OF A CERTIFICATE TO
    CONSTRUCT BOILERS 3 AND H BEFORE PROCEEDING WITH ORDERS TO INSTALL FGD
    SYSTEMS.  THE FGD PROCESS BEING GIVEN PRIME CONSIDERATION FOR UNITS 3 AND
    <* IS THE  CEA LIME SCRUBBING SYSTEM NOW OPERATING AND BEING INSTALLED ON
    UNITS 1 AND 2 RESPECTIVELY.
I.D. NUMBER   59
NEVADA POWER
HARRY ALLEN STATION NO. 1
  500  MW - NEW
COAL
NOT SELECTED
NOT SELECTED
STARTUP   6/82
                                      CONSIDERING HOT SIDE ESP IN CONJUNCTION WITH AN FGD SYSTEM.
                                      TIONS HAVE NOT YET BEEN PREPARED.
                                                                 SPECIFICA-
I.D. NUMBER   60
NEVADA PUrfER
HARRY ALLEN STATION NO. 2
  500  MM - NEW
COAL
NOT SELECTED
NOT SELECTED
STARTUP   6/83
    CONSIDERING HOT  SIDE ESP IN CONJUNCTION WITH AN FGD SYSTEM.   SPECIFICA-
    TIONS HAVE NOT YET  BEEN PREPARED.
                                                                21
                                                                                                         PEDCo-ENVIRONMENTAL

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 COMPANY

 POWER STATION
           TABLE 2
STATUS OF FGD SYSTEMS DURING  03/76

                       CUKRENT MONTH
1.0. NUMBER   61
NEVADA POWER
HARRY ALLEN STATION NO. 3
  500  MW - NEW
COAL"
NOT SELECTED
NOT SELECTED
STARTUP   6/81
    CONSIDERING HOT SIDE ESP IN CONJUNCTION WITH AN FGD SYSTEM.  SPECIFICA-
    TIONS HAVE NOT YET BEEN PREPARED.
1.0. NUMBER   62
NEVADA POWER
HARRY ALLEN STATION NO. H
  500  MW - NEW
COAL
NOT SELECTED
NOT SELECTED
STARTUP   6/85
    CONSIDERING HOT SIDE ESP IN CONJUNCTION WITH AN FGD SYSTEM.
    TIONS HAVE NOT YET BEEN PREPARED.
                                                                                                   SPECIFICA-
I.D. NUMBER   63
NEVADA POWER
REID GARDNER NO 1
  125  Mh - RETROFIT
CO«L   0.5- 1.0 PERCENT SULFUR
COMBUSTION EQUIP. ASSOCIATES
SODIUM CAKBONATE SCRUBBING
STARTUP   t/7<»
    REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT.  THIS
    FGU SYSTEM HAS BEEN OPERATIONAL SINCE APRIL l97«t. THIS SYSTEM WAS ON-LINE
    186 HRS. IN JANUAKYt WHICH EQUATES INTO A 29 PLRCfNT OPERABILHY FACTOR.
    THKCE FORCED SCRUbBER OUTAGES OCCURRED DURING THIS PERIOD DUE TO REHEATER
    STLAM LEAKS, A VENTURI STRAINER COLLAPSE AND A FROZEN CARBONATE LINE.
    TOTAL OPERATING TIME LOGGED BY THIS SCRUBBING SYSTEM TO DATE IS 6
-------
 COMPANY

 POWER STATION
                                             TABLE 2
                                  STATUS OF FGO SYSTEMS DURING
                          03/76
                   CUKKENT MONTH
1.0. NUMbER   66
NEVAOA POWER
REID GARUNER NO 4
  125  Mh - NEW
COAL   0-5- 1.0 PERCENT SULFUR
COMBUSTION EQUIP. ASSOCIATES
SODIUM CARBONATE SCRUBBING
STARTUP '  O/ 0
NEVAOA POWER COMPANY HAS SIGNED A LETTER OF INTENT WITH COMBUSTION EQUIP-
MENT ASSOCIATES FOR THE CONSTRUCTION OF AN FGD SYSTEM ON REID GARDNER NO.

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 COMPANY

 POWER STATION
           TABLE: 2
STATUS OF FtiU SYSTEMS DURING  03/76

                       CURRENT MONTH
I.D. NUMbER   71
NORTHERN INDIANA PUB SERVICE
BAILLY NO. 8
 - 400  MW - RETROFIT
COAL 3 PEKCENT SULFUR
NOT SELECTED
NOT SELECTED
STARTUP   O/ 0
    CONSIDERING A LIME OR LIMESTONE SCRUBBING UNIT.  ALSO WAITING FOR PERFOR-
    MANCE OF UELLMAN LORD/ALLIED CHEMICAL UNIT UNDER CONSTRUCTION AT THEIR
    D. H. MITCHELL NO. 11 UNIT.  LOW SULFUR COAL MAY BE BURNED TO COMPLY WITH
    S02 EMISSION REGULATIONS.
I.D. NUMbER   72
NORTHERN INDIANA PUB SERVICE
MITCHELL NO 11
  115  MW - RETROFIT
COAL   3.2- 3.5 PERCENT SULFUR
DAVY POWEKGAS/ALLIED CHEMICAL
WELLMAN LORD/ALLIED CHEMICAL
STARTUP   1/76
    THE ENGINEERING AND CONSTRUCTION PHASES OF THE S02 EMISSION CONTROL
    SYSTEM AT THIS STATION WILL BE COWLETLD IN MARCH. PREPARATIONS FOR START
    UP AND OPERATION OF THE SYSTEM ARE NOW WELL ADVANCED. THE STARTUP DATE IS
    SET FOR APRIL I2t 1976. THL FGD SYSTEM IS AN INTEGRATION OF THL WELLMAN-
    LORD S02 RECOVERY PROCESS OF DAVY POwERGAS AND ALLIED CHEMICAL'S SQ2
    REDUCTION TO SULFUR PROCESS. DAVY HOWERGAS IS THE ENGINEER AND CONSTRUC-
    TOR OF THE ENTIRE FACILITY AND ALLIED CHEMICAL IS THE SYSTEM OPERATOR AND
    PRODUCT MARKETER.
1.0. NUMBER   73
NORTHERN STATES POWER CO.
SHERBURNt NO 1
  680  Mw - NEW
COAL 0.6 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE SCRUBBING
STARTUP   5/76
    FGD SYSTEM IS STILL UNDER CONSTRUCTION. PURCHASE ORDERS FOR SCRUBBERS
    WERE PLACED IN EARLY 1971. DESIGN MODIFICATIONS CAUSED EQUIPMENT DELIVERY
    DELAYS,HOWEVER THE OVERALL SCHEDULE HAS NOT BEEN UPSET. PROBLEMS ENCOUN-
    TERED bY THE UTILITY THUS FAR HAVE UEEN DUE TO OBTAINING SOME ELECTRICAL
    CONTROLS, A RELENT CONSTRUCTION STRIKE, AND A BOILER MODIFICATION INVOL-
    VING GREATER NEGATIVE PRESSURE TOLERANCE.  THE UTILITY IS NOW BEGINNING A
    PRELIMINARY SYSTEM CHECKOUT.BY PASSING AIR AND CLEAR WATER THROUGH THE
    FGD UNIT. A MAY STARTUP OF THIS SYTCM IS STILL ANTICIPATED.
I.D. NUMBER   71
NORTHERN STATES POWER CO.
SHERBURNE NO 2
  660  Mw - NEW
COAL 0.8 PERCENT SULFUR
COMBUSTION ENGINEERING
LIMESTONE SCRUBBING
STARTUP   5/77
    FGU SYSTEM UNDER CONSTRUCTION WITH NO MAJOR DELAYS.  PURCHASE ORDERS FOR
    SCRUBBERS WtlRE PLACED IN EARLY 1971.   RECENT SCRUBBER DESIGN CHANGES HAVE
    CAUSED EQUIPMENT DELIVERY DELAYS BUT  THE OVERALL SCHEDULE HAS NOT BEEN
    UPbET.  PRObLLMS HAVE ARISEN IN OBTAINING SOME ELECTRICAL CONTROLS.
    CONSTRUCTION IS bEHIND SCHEDULE AND SOME DELAY OF STARTUP DATE MAY BE EX-
    PECTED DUE TO RECENT STRIKE. THE EXTENT OF THE DELAY CANNOT BE DETERMINED
    AT THE PRESENT TIME.
I.D. NUMBER   75.
PENNSYLVANIA .POWER CO.
BRUCE MANSFIELD NO. 1
  635  MW - NEW
COAL   t.3 PEKCENT SULFUR
CHEMICO
LIME SCRUBBING
STARTUP   H/76
    THE UTILITY BEGAN A SHAKEDOWN AND DEBUGGING PHASE OF OPERATION FOR PART
    OF THE SYSTEM IN DECEMbEK 1975. CONSTRUCTION IS STILL IN PROGRESS ON THE
    REMAINING MODULES OF THIS SYSTEM. FULL COMMERCIAL STARTUP IS PRESENTLY
    PROJECTED FOR APRIL 1976.
                                                               24
                                                                                                              PEbCo-ENVIRONMENTAL

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 COMPANY

 POWER STATION
           TABLE 2
STATUS OF FGD SYSTEMS DURING  03/76

                       CURRENT MONTH
I.D. NUMBER   76
PENNSYLVANIA POWER CO.
BRUCE MANSFIELD NO. 2
  835  Mb • NEW
COAL   <*.3 PERCENT SULFUR
CHEMICO
LIME SCRUBBING
STARTUP • «»/77
    FGU SYSTEM UNDER CONSTRUCTION. BUT ENCOUNTERING LONG DELAYS IN MATERIAL
    DELIVERIES.  STARTUP DATE HAS BEEN DELAYED 1 YEAR UNTIL 4/77.
I.D. NUMbER   77
PENNSYLVANIA POWER CO.
BRUCE MANSFIELD NO. 3
  635  Mb - NEW
COAL   t.3 PERCENT SULFUR
NOT SELECTED
NOT SELECTED
STARTUP   <»/79
    FGD UNIT IS PLANNED. PRESENTLY REQUESTING AND EVALUATING BIDS.
I.D. NUMbER   76
PHILADELPHIA ELECTRIC CO.
CROMBY
  150  MW - RETROFIT
COAL   2-t PERCENT SULFUR
UNITED ENGINEERS
MAGNESIUM OXIDE SCRUBBING
STARTUP  10/70
    COMPANY PLAN TO RETROFIT ONE OF THE TWO BOILERS AT"CKOMbY BUT HAVE NOT
    MADE A FINAL DECISION ON THIS POINT.  THE FGD PROCESS SELECTED WILL VERY
    LIKELY BE AN MGO PROCESS DESIGNED JOINTLY BY UNITED ENGINEERS AND PHILA-
    DELPHIA ELECTRIC.  ENGINEERING DESIGN WORK IS SCHEDULED FOR JAN 76.
    STARTUP NOW SCHEDULED FOR OCT 76.
I.D. NUMBER   79
PHILADELPHIA ELECTRIC CO.
EODYSTONE NO 1A
  120  MW - RETROFIT
COAL   2.5 PERCENT SULFUR
UNITED ENGINEERS
MAGNESIUh OXIUE SCRUBBING
STARTUP   9/75
    THE S02 SCRUBBER HAS BEEN TEMPORARILY SHUTDOWN BECAUSE THE ACID PLANT RE-
    GENERATION FACILITY AT THE OLIN CHEMICAL SULFURIC ACID PLANT IN PAULSBORO
    NEW jEKbEY HAS PERMANENTLY CEASED OPERATIONS. CONSIDERATIONS A«E NOW
    BEH'Jfa GIVEN TO THE RELOCATION OF THL REGENERATION FACILITY. ONCE THIS DE-
    CISION is MADE A MINIMUM PERIOD OF six MONTHS WILL BE REQUIRED TO RELO-
    CATE THE REGENERATION FACILITY, THL PARTICULATE SCRUBBERS ARE CONTINUING
    TO OPERATE. THE UTILITY IS STILL EXPERIENCING PROBLEMS WITH THE FANS, RE-
    HEAT BURNERS, DAMPERS, AND EXPANSION JOINTS.
1.0. NUMbER   80
PHILADELPHIA ELECTRIC CO.
EDDYSTONE NO ID
  2tO  MW - RETROFIT
COAL 2.5 PERCENT SULFUR
UNITED ENGINEERS
MAGNESIUM OXIDE SCRUBBING
STARTUP  10/78
    THE RETROFITTING OF SECOND STAGE SCRUBBERS ON THE BALANCE OF THE FLUE GAS
    FROM EDDYSTONE 1 IS AWAITING PERFORMANCE OF THE EXISTING 2-STAGE UNIT
    WHICH IS TREATING ONE THIRD CF THE BOILER FLUE GAS.  THIS UNIT CONSISTS
    OF A AND B PARTICULATE SCRUBBING TRAINS, EACH ARE 120 MW.  CHECK VALVE
    FAILURE ON A TRAIN HAS BEEN CORRECTED.  FAN ON B TRAIN IS STILL AT THE
    FACTORY FOR REPAIR.
                                                                                                             PEDCo-ENVIRONMENTAL
                                                               25

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 COMPANY

 POWER STATION
                                             TABLE 2
                                  STATUS OF FGD SYSTEMS DURING
                          03/76
                   CURRENT MONTH
I.D. NUMbER   61
PHILADELPHIA ELECTRIC CO.
EODYSTONE NO 2
  336  MW - KETROFIT
  COAL   s.t PERCENT SULFUR
UNITED ENGINEERS
MAGNESIUM OXIPE SCKUBBING
STARTUP  10/78
COMPANY IS AWAITING PERFORMANCE OF FGD SYSTEM ON UNIT 1 BEFORE PROCEEDING
WITH DESIGN OF FGD SYSTEM ON THIS BOILER.  HOWEVER ENGINEERING PHASE IS
 TENTATIVELY PLANNED TO START IN JAN 76t AT WHICH TIME EVALUATION OF
DATA FROM UNIT 1 SHOULD BE COMPLETE.
I.D. NUMBER   82
PUBLIC SERVICE CO OF NEW HEX.
SAN JUAN MO. 1
  375  Mw - NEW
COAL   0.8 PERCENT SULFUR
DAVY POWERGAS/ALLIED CHEMICAL
WELLMAN LORD/ALLIED CHEMICAL
STARTUP   7/7?
THIS FGD SYSTEM IS AN INTEGRATION OF THE WELLMAN-LORD S02 RECOVERY PRO-
CESS OF DAVY POWLKGAS AND ALLIED CHEMICAL'S S02 REDUCTION TO SULFUR PRO-
CESS. OAVY POWERGAS IS THE ENGINELK AiJU CONSTRUCTOR OF THE FGD SYSTEM
WHILE ALLIED CHEMICAL WILL BE THE SYSTEM OPERATOR AND PRODUCT MARKETER.
CURRENTLY THE FGD PROJLCT IS. PROcEEDfNG ACCORDING TO PLAN WITH NO MAJOR
PROBLEMS. EQUIPMENT IS NOW BEING PROCURED. CONSTRUCTION IS SCHEDULED TO
BEGIN IN MARCH OK «PRIL OF 1976.
I.D. NUMBER   £3
PUBLIC SERVICE CO OF NEW HEX.
SAN JUAN NO. 2
  3"*0  PW - RETROFIT
COAL   0.8 PERCENT SULFUR
DAVY POWERGAS/ALLIED CHEMICAL
WELLMAN LORD/ALLIED CHEMICAL
STARTUP   7/77
THIS FGD SYSTEM IS AN INTEGRATION OF THE WELLMAN-LORU S02 RECOVERY PRO-
CESS OF OAVY POWERGAS AND ALLIED CHEMICAL'S S02 REDUCTION TO SULFUR PRO-
CESS. DAVY POWERGAS IS THE ENGINEER AND CONSTRUCTOR OF THE FGD SYSTEM
WHILE ALLIED CHEMICAL WILL OE THE SYSTEM OPERATOR ANU PRODUCT MARKETER.
CURRENTLY THE FGU PROJECT IS PROCEEDING ACCORDING TO PLAN WITH NO MAJOR
PROBLEMS. EQUIPMENT IS NOW BEING PROCURED. CONSTRUCTION IS SCHEDULED TO
BEGIN IN MARCH OR APRIL OF 1976.
1.0. NUMBER   84
PUBLIC SERVICE CO OF NEW MEX,
SAN JUAN NO. 3
  500  Mw - NEW
COAL 0.8 PERCENT SULFUR
DAVY POWERGAS
UELLMAN LORD
STARTUP   5/79
A LETTER OF INTENT HAS BEEN SIGNED WITH DAVY POWERGAS FOR A WELLMAN
LORD UNIT. THE PROJECTED STARTUP DATE OF THIS SYSTEM HAS BEEN DELAYED ONE
YEAR TO HAY 1979.
I.D. NUMBER   85
PUBLIC SERVICE CO OF NEW HEX.
SAN JUAN i'JO. t
  500  MM - NEW
COAL 0.8 PERCENT SULFUR
DAVY POWERGAS
WELLMAN LORD
STARTUP   5/61
A LETTER OF INTENT HAS BEEN SIGNED WITH OAVY POWERGAS FOR A WELLMAN
LORD UNIT. THE PROJECTED STARTUP DATE OF THIS SYSTEM HAS BEEN DELAYED ONE
YEAR TO MAY 1981.
                                                                  26
                                                                                                          PEDCo-£NVIRONMENTAL

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 COMPANY

 POWER STATION
           TABLE 2
STATUS OF FGD SYSTEMS DURING  03/76

                       CURRENT MONTH
I.Ot NUMBER   66
PUBLIC SERVICE CO. OF COLORADO
VALMONT NO. 5
   50  MW - RETROFIT
COAL  0.72 PENCENT SULFUR
UOP / PUB SERVICE OF COLORADO
LIMESTONE SCRUBBING
STARTUP . 10/Tt
    KEFEK TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
    SYSTEM HAS BEEN OPERATIONAL SINCE NOVEMBER 197"». THE FGD SYSTEM CURRENTLY
    OPERATIONAL AT THIS STATION IS AN EXPERIMENTAL UNIT, ORIGINALLY DESIGNED
    BY UNIVERSAL OIL PRODUCTS FOK PARTlCULATE REMOVAL ONLY. ONE OF THE TWO
    PARALLEL SCRUBBING MODULES WAS CONVERTED TO LIMESTONE SCRUBBING FOR
    EXPERIMENTAL PURPOSES ONLY.
I.D. NUMbER   87
PUBLIC SEKVICE INDIANA
GIBSON NO. 3
  650  Mb - NEW
COAL, 3.3% SULFUR
NOT SELECTED
NOT SELECTED
STARTUP   0/78
    BID EVALUATION IS UNDERWAY.
1.0. NUMbER   88
PUBLIC SERVICE INDIANA
GIBSON NO. H
  650  MW - NEW
COAL
NOT SELECTED
NOT SELECTED
STARTUP   0/79
    BID SPECIFICATIONS ARE BEING PREPARED.
I.D. NUMBER   89
RICKEMBACKER AFU
RICKENBACKER
   20  MU - RETROFIT
COAL   5.0 PEKCENT SULFUR
RESEARCH COTTRELL
LIME SCRUBBING
STARTUP   3/76
    CONSTRUCTION OF THE SYSTEM IS NOW VIRTUALLY COMPLETE. THE SYSTEM STARTUP
    DATE WAS SET BACK ONE MONTH DUE TO DELAYS OF SOME MATERIAL DELIVERIES.
    THE SYSTEM IS NOW SChEDULEU TO BE PLACED IN SERVICE IN MID-MARCH, 1976.
 I.D. NUMBER   90
 S. CAROLINA PUU SEKV AUTHORITY
 WINYAH NO. 2
  140  MW - NEW
 COAL  1.0 PERCENT SULFUR
 BABCOCK & WILCOX
 LIMESTONE SCRUBBING
 STARTUP   5/77
    THE CONTRACT HAS BEEN AWARDED TO B&W FOR CONSTRUCTION OF A LIMESTONE SYS-
    TEM TREATING 50 PERCENT OF THE GAS FLOW FROM A 280 MW BOILER. THIS UNIT
    WILL FIRE 1 PERCENT SULFUR COAL AND THE GUARANTEED REMOVAL EFFICIENCY IS
    69 PERCENT. DIFFERENT METHODS OF SLUDGE DISPOSAL ARE CURRENTLY BEING EX-
    AMINED BY THE UTILITY.
                                                                                                       PEDCo- ENVIRONMENTAL
                                                             27

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 COMPANY
                                             TABLE 2
                                  STATUS OF KGD SYSTEMS DURING
                          03/76
 POWER STATION                                           CURRENT MONTH
I.D. NUMBER   91
S. MISSISSIPPI ELEC PWR ASSOC
R.D. MORROW NO.l
  180  MW - NEW
COAL 1 PERCENT SULFUR
RILEY STOKEK/ENVIRONEERING
LIMESTONE SCRUBBING
STARTUP  11/77
THE CONTRACT FOR THIS LIMESTONE SYSTEM HAS BEEN AWARDED TO RILEY
STOKER/ENVIRONEERING. GUARANTEED S02 REMOVAL EFFICIENCY IS 85 PERCENT.
I.D. NUMbER   92
S. MISSISSIPPI ELEC PWR ASSOC
R.D. MORKOW NO.2
  180  MW - NEW
COAL 1 PERCENT SULFUR
RILEY STOKEK/ENVIRUNEERING
LlMLSTONt SCRUBBING
STARTUP   6/7B
THE CONTRACT FOR THIS LIMESTONE SYSTEM HAS BEEN AWARDED TO RILEY
.STOKER/ENVIRONEERING. GUARANTEED S02 REMOVAL EFFICIENCY IS 85 PERCENT.
I.D. NUMUER   93
SOUTHERN CALIFORNIA EDISON
KAIPAROvJITZ NO. 1
  750  MW - NEW
COAL lO.fiUOiBTUi 0.5S S
NOT SELECTED
LIME SCRUBBING
STARTUP   0/02
THIS NEW STATION  IS ANTICIPATED TO INCORPORATE FGD, BUT A SPECIFIC
PROCESS HAS NOT BEEN SELECTED. THE STARTUP DATE FOR THIS UNIT HAS BEEN
DELAYED ONE YEAR  PENDING THE ASSEMBLY ANU EVALUATION OF DATA FOR ENVIRO-
MENTAL CONSIDERATIONS AND SUBSEQUENT APPROVAL PROCESSES.
I.D. NUMDER   9«»
SOUTHERN CALIFORNIA EDISON
KAIPAROWITZ NO. 2
  750  MW - NEW
COAL 10.800.BTU* 0.5S S
NOT SELECTED
LIME SCRUBBING
STARTUP   0/83
 THIS  NEW  STATION  IS  ANTICIPATED TO  INCORPORATE FGD, BUT A SPECIFIC
 PROCESS HAS  NOT BELN SELECTED. THE  STARTUP DATE FOR THIS UNIT HAS BEEN
 DELAYED ONE  YEAR  PENDING  THE  ASSEMBLY  AND EVALUATION OF DATA FOR ENVIRO-
 MENTAL CONSIDERATIONS AND SUBSEQUENT APPROVAL PROCESSES.
 I.D. NUMuER    95
 SOUTHERN  CALIFORNIA  EDISON
 KAIPAROWITZ  NO. 3
   750   Mh -  NEW
 COAL 10.800.BTUt 0.5X  S
 NOT SELECTED
 LIME SCRUBBING
 STARTUP   0/8t
 THIS  NEW  STATION IS  ANTICIPATED  TO  INCORPORATE  FGD,  BUT  A  SPECIFIC
 PROCtSS HAS  NOT  BELN SELECTED. THE  STARTUP  DATE FOR  THIS UNIT  HAS BEEN
 DELAYED ONE  YEAR PENDING THE  ASSEMBLY  AND EVALUATION OF  DATA FOR ENVIRO-
 MENTAL CONSIDERATIONS AND SUBSEQUENT APPROVAL PROCESSES.
                                                                                                           PEDCo-ENVIRONMENTAL
                                                               28

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 COMPANY

 POWER STATION
           TABLE 2
STATUS OF FGU SYSTEMS OUKING  03/76

                       CUKKENT MONTH
I.D. NUMBER   96
SOUTHERN CALIFORNIA EDISON
KAIPAKOWITZ NO. H
  750  KM - NEW
COAL 10.800.BTUt 0.5K S
NOT SELECTED
LIME SCRUBBING
STARTUP '  0/85
    THIS NEW STATION IS ANTICIPATED TO INCORPORATE. FGO, bUT A SPECIFIC
    PROCESS HAS NOT BEEN SELECTED. THE STARTUP DATE FOR THIS UNIT HAS BEEN
    DELAYED ONE YEAR PENDING THE ASSEMBLY AND EVALUATION OF DATA FOR ENVIRO-
    MENTAL CONSIDERATIONS AND SUBSEQUENT APPROVAL PROCESSES.
I.D. NUMBER   97
SOUTHERN CALIFORNIA EDISON
MOHAVE NO IB
  620  MW - RETROFIT
COAL   0.5- 0.8 PERCENT SULFUR
NOT SELECTED
LIME/LIMESTONE SCRUBBING
STARTUP   6/77
    THE TOTAL CAPACITY OF BOILER IS 790 MW. EXISTING EXPERIMENTAL FGD MODULE
    WILL TREAT ONLY 170 «W.  FINAL SELECTION OF THE PROCESS HAS BEEN POST-
    PONED. SEE MOHAVE 1A.
I.D. NUNbtR   90
SOUTHERN CALIFORNIA EDISON
MOHAVE NO. 2
  790  MW - RETROFIT
COAL   0.5 TO 0.8 % SULFUR
NOT SELECTED
LIME/LIMESTONE SCRUBBING
STARTUP   6/77
    A PROTOTYPE 170 MW LIME SCRUBBING SYSTEM (HORIZONTAL MODULE) ON THIS UNIT
    WAS OPERATED FROM NOVEISBER 1973 UNTIL FEBRUARY 1975. AVAILABILITY FOR THE
    PERIOD 1/16/7H TO 2/9/75 AVERAGED 73.5».  THIS SYSTEM IS TO BE REINSTALL-
    ED Al THE FOUK CORNERS PLANT, OPERATED BY ARIZONA PUBLIC SERVICE.
I.D. hUP-iGLR   99
SPRINGFIELD CITY UTILITIES
SOUTHWEST NO. 1
  200  Mb - NLW
COAL 3.5 PERCLNT SULFUR
UNIVERSAL OIL PRODUCTS
LIMESTONE SCRUBBING
STARTUP   7/7b
    CONSTRUCTION ON THE BOILER AND FGD SySTEM IS CURRENTLY BEHIND SCHEDULE.
    COMPLETION IS NOW SCHEDULED FOR MID-SUMMER 1976. THE SCRUBBER. ESP, AND
    I.b. FANS ARE CURRENTLY BEING INSTALLED.
I.D. NUMBER  100
TENNESSEE VALLEY AUTHORITY
SHAWNCE NO.10A
   10  MW - RETROFIT
COAL 2.9 PERCENT SULFUR
UNIVERSAL OIL PRODUCTS
LIME/LIMESTONE SCRUBBING
STARTUP   1/72
    REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
    TURBULENT CONTACT ABSORBER(TCA) LIME/LIMESTONE SCRUBBING SYSTEM HAS BEEN
    OPERATIONAL SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY THE EPA.
    TVA IS THE CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTEL CORP. OF SAN
    FRANCISCO IS THE MAJOR CONTRACTOR, TEST DIRECTOR, AND REPORT WRITER.
                                                               29
                                                                                                           PEDCO- ENVIRONMENTAL

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 COMPANY

 POWER STATION
           TABLE 2
STATUS OF FGD SYSTEMS DURING  03/76

                       CURRENT MONTH
I.D. NUMBER  101
TENNESSEE. VALLEY AUTHORITY
SHAWMEE NU.10B
   10  MW - RETROFIT
COAL 2.9 PERCENT SULFUR
CHEMICO
LIME/LIMESTONE SCRUBBING
STARTUP   "1/72
    REFER TO BACKGROUND INFOKMATIION SECTION IN TABLE 3 OF THIS REPORT. THIS
    VEIMTURI/SPRAY TOWER LIME/LIMESTONE SCRUBBING SYSTEM HAS BELN OPERATIONAL
    SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY THE EPA. TVA IS THE
    CONSTRUCTOR AND FACILITY OPL'KATOR. THE BECHTEL CORP. OF SAN FRANCISCO IS
    THL MAJOR CONTRACTOR!TEST DIRECTOR. AND REPORT WRITER.
 I.D. NUMBER  102
 TENNESSEE VALLEY  AUTHORITY
 WIDOWS CKEEK NO 8
   550  Mw - RETROFIT
 COAL   3.7 PERCENT  SULFUR
 TENNESSEE VALLEY  AUTHORITY
 LIMESTONE SCRUBBING
 STARTUP   2/77
    CONTRACTS HAVE BEEN LET ON ALL MAJOR PKOCESS EQUIPMENT INCLUDING THE
    SCKUSBER, MIST ELIMINATOR. PIPING. INSTRUMENTATION, HOT AIR INJECTION
    SYSTLM AND AIR HEATER FANS. THE ID FANS ARE NOW BEING INSTALLED AS IS THE
    LIMESTONE CRUSHER. THE. LAST EQUIPMENT REQUISITION WILL BE COMPLETED BY
    JUNE 1976. THE SCHEDULED STARTUP DATE OF FEBRUARY 1977 IS STILL OPERA-
    TIVE.
•1.0.  NUMBER   103
 TEXAS UTILITIES CO.
 MARTIN LAKE  NO. 1
   793  MW  -  NEW
 COAL    1.0 PERCENT SULFUR
 RESEARCH COTTRELL
 LIMESTONE  SCRUBBING
 STARTUP   9/76
    NEW SYSTEM, ERECTING BOILER.  CONTRACT FOR FGD SYSTEM AWARDED.
    ENGINEERING DESIGN WORK IS PROCEEDING.  FABRICATION OF THE TOWER HAS
    BEEN COMPLETED.
 I.D.  NUMBER   101*
 TEXAS UTILITIES CO.
 MARTIN LAKE  NO. 2
   793  MW  -  NEW
 COAL    1.0 PERCENT  SULFUR
 RESEARCH COTTHELL
 LIMESTONE  SCRUBBING
 STARTUP   6/77
    NEW SYSTEM, ERECTING BOILER.  CONTRACT FOR FGD SYSTEM AWARDED.
    ENGINEERING DESIGN WORK IS PROCEEDING.  FABRICATION OF THE TOWER HAS
    BEEN COMPLETED.
 I.D.  NUMBER   105
 TEXAS UTILITIES CO.
 MARTIN LAKE  NO. 3
   793  MW  -  NLW
 COAL  1.0 PERCENT  SULFUR
 RESEARCH COTTRELL
 LIMESTONE  SCRUBBING
 STARTUP 12/75
    UTILITY HAS SIGNED A LETTER OF. INTENT WITH RESEARCH COTTRELL. THE BOILER
    IS CURRENTLY BEING ERECTED AT  THIS NEW FACILITY.
                                                                30
                                                                                                        PEDCo- ENVIRONMENTAL

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 COMPANY

 POWER STATION

1.0. NUMbER  106
TEXAS UTILITIES CO.
MARTIN LAKE NO. H
  793  Mta - NEW
COAL 1.0 PERCENT SULFUR
RESEARCH COTTRELL
LIMESTONE SCRUBBING
STARTUP  12/79

1.0. NUMBER  107
UNITED POWER ASSOCIATION
COAL CREEK NO. 1
  5<«5  MM - NEW
LIGNITE - 0.63 PERCENT SULFUR
NOT SELECTED
LIME/LIMESTONE
STARTUP  11/78

1.0. NUMBER  108
UNITED POWER ASSOCIATION
COAL CREEK NO. 2
  5
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                      Table 3



PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS
                         33

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PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING

 FUEL CHARACTERISTICS

 FGD VENDOR

 PROCESS

 NEW OR RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
   PARTICULATES


   S02


 WATER  MAKE  UP


  SLUUGE  DISPOSAL


  UNIT  COST
  OPERATIONAL
   EXPERIENCE
ARIZONA PUBLIC SERVICE

CHOLLA NO 1

JOSEPH CITY ARIZONA

 115 MW

COAL   O.HH-1 PERCENT SULFUR

RESEARCH COTTRELL

LlhESTONE SCRUBBING

RETROFIT

10/73

OPERATIONAL


99.7 PERCENT


65 PERCENT


733 GAL/LB  MOLE  S02  REMOVED


UNSTAB1LIZED  SLUDGE  UISPOSE.D IN UNLINED POND


S&7/KW  CAPITAL *  2.2  MILLS/KWH ANNUALIZEU


 KEFER  TO BACKGKOUNO  INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
 FGD SYSTEM HAS BEEN  OPLRATIONAL SINCE NOVEMbER i97*' ^LXWXLXTY FOR
 MODULES A AND B HAS  AVERAGED IN EXCESS OF 90 AND 83 PERCENT RESPECTIVELY
 XING T£E PAS? TEN  OPERATING MONTHS. ^LIABILITY FOR MODULES A AND B
 IN JANUARY WAS 99 PERCENT. MODULE A WAS IN SERVICE 71H.5 HRS. AND MODULE
 B 653.7 HRS.  DURING  THIS PERIOD.
                                                                                                  PEDCo-ENVIRONMENTAL
                                                             35

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                                                  BACKGROUND INFORMATION
                                                           ON
                                                  THE CHOLLA POWER PLANT

     THE CHOLLA POWER STATION IS LOCATED NEAR JOSEPH CITY. ARIZONA.  IT HAS ONE 115 MW COAL-FIRED BOILER IN SERVICE
AND TWO 250 MW UNITS UNDER CONSTRUCTION.
     UNIT 1 IS A DRY BOTTOM PULVERIZED COAL-FIRED UNIT DESIGNED BY COMBUSTION ENGINEERING.  THE COAL PRESENTLY BEING
BURNED HAS AN AVERAGE HEATING VALUE (DRY BASIS) OF 12,146 BTU/PER POUND AND ASH AND SULFUR CONTENTS OF 12.3 PERCENT
AND 0.44 PERCENT, RESPECTIVELY.
     THE FGD SYSTEM AT THE CHOLLA PLANT WAS MANUFACTURED BY RESEARCH-COTTRELL AND INSTALLATION WAS COMPLETED ON DECEMBER
3, 1973.  S02  REMOVAL EFFICIENCY IS REPORTED TO BE 85 PERCENT.
     THE FGD SYSTEM CONSISTS OF TWO SCRUBBING MODULES (A AND B).  EACH MODULE IS DESIGNED FOR 240,000 ACFM THROUGHPUT
AT 276°F, AND HANDLES 50 PERCENT OF THE BOILER'S FLUE GAS LOAD.  MODULE A HAS A VARIABLE THROAT FLOODED DISC SCRUBBER
(FDS) FOLLOWED BY A PACKED TOWER; MODULE B IS SIMILAR BUT THE TOWER IS NOT PACKED AND SLURRY IS NOT CIRCULATED THROUGH
IT.  EITHER ONE OR BOTH OF THE SCRUBBERS CAN BE BYPASSED.  GAS LEAKAGE AROUND EACH TRAIN IS ESTIMATED TO BE ABOUT 4.52
OF THE GAS BEING TREATED.  THE TOWER PACKING WHICH IS ABOUT 2 FEET THICK IS MADE OF POLYPROPYLENE CORRUGATED SHEETS
JOINED TOGETHER IN CRISS-CROSS PATTERNS SIMILAR TO HONEYCOMBS.  THE TOWER DEMISTERS ARE MADE OF POLYPROPYLENE AND THE
REHEATERS ARE SHELL AND TUBE TYPE AND CONSIST OF THREE TUBE BUNDLES.
     LIMESTONE FOR THE FGD SYSTEM IS PURCHASED IN GROUND FORM SUITABLE FOR SLURRYING.  THE MAIN SOURCE OF SUPPLY IS
FROM THE NELSON MINES OF U.S. LIMESTONE IN PEACH SPRINGS. NEAR KINGMAN, ARIZONA.
     THE PLANT DOES NOT HAVE A SLUDGE TREATMENT OR FIXATION SYSTEM.  THE SLUDGE IS PUMPED TO THE FLY ASH POND ON AN
INTERMITTENT BASIS USING A COMMON PIPING SYSTEM WITH THE FLY ASH.  NO POND WATER IS RECYCLED TO THE FGD SYSTEM.
PROBLEMS AND SOLUTIONS
     DECEMBER, 1973 TO APRIL 2, 1974 - DUE TO THE SIZE DIFFERENCE BETWEEN MAIN DUCT AND REHEATER TRANSITION DUCT, THE
GAS FLOW PRODUCED HARMONIC VIBRATIONS IN THE REHEATER.  THE VIBRATIONS WERE PARTIALLY DAMPED BY INSTALLATION OF BAFFLES,

                                                                                                    PEDCo-ENVIRONMENTAL

                                                            36

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CHOLLA POWER PLANT (continued)
ONE OF THE REHEATER TUBE BUNDLES WAS BADLY CORRODED BY ACID WHICH CONDENSED IN THE UNINSULATED DUCT UPSTREAM OF THE  REHEATERS.  THE TUBE
BUNDLE WAS REPLACED AND A BAFFLE WAS INSTALLED TO DIVERT CONDENSED ACID AWAY FROM REHEATER TUBES.   THE DUCT UPSTREAM OF  THE  REHEATER  WAS
ALSO INSULATED.  THE ACID CONDENSATION PROBLEM ONLY OCCURED IN THE MODULE WITH NO TOWER PACKING AND HENCE LOW SOg REMOVAL  EFFICIENCY.
     ANOTHER PROBLEM WAS DUE TO SOLIDS BUILD UP IN THE FDS STUFFING GLAND BOX AND ON TOP OF THE SPRAY DOME.  ALSO, SOME  LINES  PLUGGED
PARTICULARLY WHEN THE SYSTEM OPERATED AT LOW FLOW RATES, SOLIDS SETTLED OUT IN STANDBY PUMPS AND EXCESSIVE FAN VIBRATIONS  OCCURRED DUE
TO AN ACCUMULATION OF SCALE BUILD UP WHEN IT WAS IDLE.
     TO SOLVE PROBLEMS, PACKING GLAND POSITION WAS REVERSED (INSTALLED UPSIDE DOWN).  THE FAN WAS SANDBLASTED, THE PIPING  MODIFIED TO
ELIMINATE STAGNANT POCKETS, AND PUMPS WERE FLUSHED IMMEDIATELY AFTER REMOVAL FROM SERVICE.
     MORE RECENT PROBLEMS EXPERIENCED WITH THE UNIT ON CHOLLA 1 INCLUDE SIGNIFICANT CORROSION ATTACK IN THE VESSEL WALLS OF  THE FLOODED
DISC PARTICULATE SCRUBBER OR MODULE.  ACID CORROSION IN THE REHEATER HOUSING OF MODULE B IS ATTRIBUTED TO THE LACK OF PACKING  OR CIRCULATION
IN THAT MODULE.
                                                                      37

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RELIABILITY (X)
Month
Jan.
Feb.
Mar.
Apr.
May.
Jun.
Jul.
Aug.
Sept.
Oct.
Nov.
Dec.
Jan.
Feb.
Mar.
Apr.
May
Jun.
Module A
74
74
74
74
74
74
74
74
74
74
74
74
75
75
75
75
75
75
July. 75 •
Aug.
75
97
100
100
66
98
100
97
97
95
83
100 '
100
98
96

88
48
100
97
95
Module B
90
94
66
57
99
100
92
97
99
68
98;
100'
99
99

65
40
100
98
100
FGD SYSTEM RELIABILITY
    CHOLLA UNIT NO.  1

    COMMENTS
                          Annual boiler and FGD System overhaul,
                          Modules were both off-line for most of month for scheduled repairs and cleaning.
                          Substantial plugging of packing and mist eliminators was observed.
                          No problems reported.
                          Modules were shutdown  to  clean flow restrictions In flooded disc  reclrculation  lines.
                          Module A was down for  Inspection one time.
                                                                         PEDCo-ENVIRONMENTAL
                                                38

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                                                     FGD SYSTEM "RELIABILITY
                                                  CHOLLA UNIT NO. 1 (continued)

               RELIABILITY (X)
Month     Module A       Module B                                         COMMENTS
Sep> 75     98            97            Minor  outage due to flooded disc, lines.
Qct  „     84            55            outages  resulted from scheduled equipment overhauls and recoatlng of vessels.
Nov. 75    100            80            No major outages or problems occurred during the report period.  Minor problems
Dec  ?5    100           100            encountered during the month of December Included the rebuilding of a recycle
                                        pump and malfunctioning  of  the B-s1de reheater coil.
Jan  76     „            99            Module A operated  715  hours during  the  report month and Module B operated 654 hours.   Module
                                        A experienced some minor valve and  line plugging problems.  Module B operating hours were lower
                                        due to system requirements.
                                        *Note:  The reliability factors  displayed  for Modules A and B  are determined by computing
                                        the ratio of the number of hours the module operated to the number of hours the system
                                        was called upon to operate.
                                                                                                                         PEDCo-ENVIRONMENTAL

                                                                           39

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PERFORMANCE DESCRIPTION FOR OPERATIONAL F60 SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING

 FUEL CHARACTERISTICS

 FGO VENDOR

 PROCESS

 NEW OR RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
   PARTICULATES


   S02


 WATEK MAKE  UP


 SLUUGE DISPOSAL


 UNIT COST
  OPERATIONAL
   EXPERIENCE
 27

COMMONWEALTH EDISON

WILL COUNTY NO 1

ROMEOVILLE ILLINOIS

 167 MW

COAL - 9*63 8TU,   2.IX SULFUR

OABCOCK  ft WILCOX

LIMESTONE SCRUBBING

RETROFIT

 2/72

OPERATIONAL


96 PERCENT


82 PERCENT


 106 GAL/LB  MOLE  S02  REMOVED


  STABILIZED  SLUUGE DISPOSED IN  CLAY LINED POND


S96/KW  CAP.  W/NO  SLUDGE TREAT.fa.9 M1LLS/KWH AT 6bK BLR.  CAP.


 REFER  TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
 FGO SYSTLM HAS BEEN OPERATIONAL SINCE FEB. 1972. MODULES A AND B WERE IN
 SERVICE A TOTAL OF 3213 AND 2580 HRS. RESPECTIVELY DURING 1975, THUS AT-
 TAINING ANNUAL AVERAGE OPERABILITIES OF 52 AND -»2 PERCENT RESPECTIVELY.
 UNIT NO.l CAME DOWN FOR A BOILER, TURBINE AND AERATOR OVERHAUL IN MID-
 OCTOBER 1975. RESULTING IN AN OUTAGE THAT LASTED FOR MORE THAN * MONTHS.
 SYSTEM RESTART IS CURRENTLY SCHEDULED FOR MID-MARCH 1976.
                                                              40
                                                                                                        PEDCo.-ENVIRONMENTAL

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                                            BACKGROUND INFORMATION
                                                      ON
                                         THE WILL COUNTY POWER STATION
     IN 1970, COMMONWEALTH EDISON CONTRACTED WITH BECHTEL CORPORATION TO INVESTIGATE THE SULFUR REMOVAL  SYSTEMS  THEN
AVAILABLE HAVING A SUFFICIENT DEGREE OF DEVELOPMENT TO WARRANT A LARGE SCALE INSTALLATION ON WILL  COUNTY STATION'S  UNIT  #1.
     AFTER DECIDING UPON A WET SCRUBBER SYSTEM USING LIME OR LIMESTONE. A SPECIFICATION WAS THEN PREPARED BY  BECHTEL  AND
RELEASED FOR BID.  FROM THE NINE BIDDERS THAT WERE SOLICITED, SEVEN PROPOSALS WERE RECEIVED.  AFTER DETAILED  STUDY  AND
BID EVALUATION WITH SPECIAL CONSIDERATION OF THE PROJECT SCHEDULE,  BABCOCK AND WILCOX WAS GIVEN AUTHORIZATION,  IN  SEPTEMBER
1970, TO BEGIN THE DETAILED ENGINEERING FOR A LIMESTONE SLURRY SYSTEM.  THE PROJECT HAD A COMPLETION DEADLINE OF DECEMBER
31, 1971 WHICH WAS ESTABLISHED BY THE ILLINOIS COMMERCE COMMISSION  AS PART OF A RATE CASE.
     THE BABCOCK AND WILCOX DESIGNED PROCESS WAS GUARANTEED TO REMOVE 98% OF THE FLY ASH AND 76* OF THE  SULFUR DIOXIDE.   THESE
EFFICIENCIES WERE BASED ON A DUST INLET LOADING OF 1.355 GRAINS PER STANDARD CUBIC FOOT AT 70°F AND BURNING 4% SULFUR ILLINOIS
COAL.
     THE WILL COUNTY POWER STATION  IS LOCATED NEAR ROMEOVILLE,  ILLINOIS.  THE PLANT HAS FOUR ELECTRIC POWER GENERATING  UNITS
WITH A  TOTAL RATED CAPACITY OF 1147 MW.  ONLY UNIT #1  IS RETROFITTED WITH AN FGD SYSTEM.
     UNIT  #1 IS  A WET  BOTTOM COAL-FIRED BOILER AND PRODUCES  167 MW OF  ELECTRICITY.  THE BOILER WAS MANUFACTURED BY BABCOCK
AND WILCOX AND  WAS INSTALLED  IN  1955.   THE  PLANT  NOW  BURNS WESTERN COAL.  THE GROSS HEATING VALUE OF THE COAL IS ABOUT  9500
BTU/LB.   ITS AVERAGE SULFUR AND  ASH CONTENTS  ARE  1.3  PERCENT  AND 10  PERCENT  RESPECTIVELY.
     THE  WET LIMESTONE FLUE GAS  DESULFURIZATION  SYSTEM AT WILL  COUNTY  WAS PLACED  IN SERVICE ON  FEBRUARY  23, 1972.  THE  SYSTEM
CONSISTS  OF TWO FGD MODULES  (IDENTIFIED AS  A  AND  B).  LIMESTONE  HANDLING  AND  MILLING FACILITIES  AND  SLUDGE TREATMENT AND
STABILIZATION  UNIT.  S02  REMOVAL EFFICIENCY IS  REPORTED TO  BE 82 PERCENT.   SHORTLY  AFTER  STARTUP  AND DURING THE INITIAL
DEBUGGING STAGE, NUMEROUS PROBLEMS  WERE ENCOUNTERED.   THIS  PROMPTED  COMMONWEALTH  EDISON TO SHUT DOWN MODULE B IN MAY 1973 AND
TO CONCENTRATE ON SOLVING THE  PROBLEMS OF  MODULE A.   MODULE  B WAS  NOT RESTARTED UNTIL  MAY 1975.
                                                                                               PEDCo-ENVlKONMumL
                                                              41

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WILL COUNTY (continued)
     THE LIMESTONE GRINDING FACILITIES CONSISTS OF TWO WET BALL MILLS.  EACH  RATED AT  12  TONS  PER  HOUR  OF  LIMESTONE.   THE
LIMESTONE IS 97.5 PERCENT CALCIUM CARBONATE, AND CONTAINS 0.99 PERCENT  MAGNESIUM CARBONATE AND 0.48 PERCENT SILICA.   IT  IS
RECEIVED IN COARSE GROUND FORM (ABOUT 1/2 INCH OR LESS) AND IS FINELY GROUND TO 95 PERCENT THROUGH 320 MESH.
     THE SLUDGE FROM THE SYSTEM IS SENT TO A CLARIFIER.  THE 'OVERFLOW IS RETURNED TO  THE PROCESS  WHILE THE UNDERFLOW IS
STABILIZED BY MIXING IT WITH LIME AND FLY ASH.  ABOUT 200 LBS OF LIME AND 400 LBS OF  FLY ASH  ARE  USED  PER TON OF DRY SOLIDS
OF SLUDGE.  THE FIXED SLUDGE IS TRANSPORTED BY CONCRETE MIXING TRUCKS TO A SMALL POND ON SITE FOR SOLIDIFICATION.  THE
STABILIZED SLUDGE USUALLY SOLIDIFIES  IN ABOUT ONE WEEK AFTER WHICH IT IS HELD ON-SITE.
PROBLEMS AND SOLUTIONS
     1972  - DEMISTER PLUGGING WAS A CONSTANT PROBLEM, MAINLY BECAUSE OF HEAVY LIMESTONE ACCUMULATIONS  ON THE BOTTOM OF THE
DEMISTER AND PARTLY DUE TO  LOW WASH WATER PRESSURE CAUSED BY LEAKS IN THE POND RETURN BYPASS.  THESE PROBLEMS KEPT MODULES A
AND  B  OUT  OF SERVICE FOR SEVERAL DAYS EACH  MONTH  DURING MARCH, APRIL, JUNE AND JULY 1972.  THE MODULES WERE ALSO OUT OF
SERVICE  FROM SEPTEMBER  26 TO NOVEMBER 21, 1972,  DUE TO THE  BOILER BEING DOWN DURING THAT  PERIOD.
      IN  ORDER  TO  SOLVE  THE  DEMISTER PROBLEM, THE  SCRUBBERS'  SLURRY NOZZLES WERE  LOWERED AND THE SLURRY CIRCULATION SYSTEM WAS
LEFT OUT OF SERVICE TO  KEEP THE  DEMISTER  CLEAN.   SINCE THIS  DID NOT  IMPROVE THE  SITUATION, THE DEMISTER  ELEMENTS WERE HAND
WASHED.  THIS  SOLVED THE PROBLEM PARTIALLY,  BUT  ALSO  INCREASED THE VENTURI NOZZLE PROBLEM BECAUSE  THE BROKEN ELEMENTS FROM

THE  DEMISTER GOT  INTO  THE  SLURRY SYSTEM.
      DURING HIGH  GAS FLOW  RATES. THE  REHEATER  OF MODULE  B  VIBRATED EXCESSIVELY.   THEREFORE, MODULE  B WAS  TAKEN  OUT OF SERVICE
 IN APRIL TO CARRY OUT  REHEATER  MODIFICATIONS.   THESE  MODIFICATIONS INCLUDED  REBRACING OF  THE  REHEATER TUBES AND THE  INSTALLATION

 OF A BAFFLE  PLATE TO REDUCE THE VIBRATIONS.
      OTHER REASONS FOR THE'MODULES'  OUTAGES WERE, "EROSION AND PLUGGING  OF SPRAY  NOZZLES,  INTERNAL  AND EXTERNAL  BUILD  UP  OF
 DEPOSITS ON VENTURI  NOZZLES,  CORROSION, SULFITE BLINDING PROBLEMS AND  FAN'S  VIBRATIONS.
      1973 - DEMISTER PLUGGING CONTINUED TO  BE A PROBLEM.   FURTHERMORE,  THE  DEMISTER  ON  MODULE B  BROKE LOOSE  FROM ITS  MOUNTINGS
 AND THE RESULTANT CARRYOVER WASH WATER PLUGGED THE REHEATER.  THIS REHEATER ALSO EXPERIENCED  LEAKS DUE  TO CHLORIDE  PITTING
 CORROSION.  MODULE A WAS DOWN FROM APRIL 24 TO MAY 24. 1973. AND MODULE B WAS  DOWN  FROM APRIL TO DATE.   THERE  WAS  NO SCRUBBER


                                                                                                     PEDCo-ENVIRONMENTAL
                                                            42

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MILL COUNTY (continued)
OPERATION DURING AUGUST 27 TO SEPTEMBER 26. 1973.
     IN ORDER TO SOLVE THE OUTSTANDING DEMISTER AND REHEATER PROBLEMS, A CONSTANT UNDERSPRAY AND AN INTERMITTENT OVERSPRAY
WERE USED TO WASH ALL THE DEMISTER COMPARTMENTS OF MODULE A.  EXTRA NOZZLES WERE ADDED AND A CLEAN WATER SUPPLY WAS  MAINTAINED.
THE REHEATER UNIT HAS ALSO RETUBED.
     1974 - ONLY MODULE A OPERATED DURING THE YEAR.  PROBLEMS WERE MAINLY FREEZE UP TO VENTURI  THROAT DRIVE  MECHANISM,  TANK
SCREEN BLINDING, DUCT CORROSION AND VIBRATIONS.  LOSS OF BUILDING HEAT CAUSED EXTENSIVE DAMAGE  AND KEPT  THE  SYSTEM DOWN FOR
THE ENTIRE MONTH OF JANUARY 1974.
     1975 - ENTERING 1975 A-MODULE WAS OPERATIONAL AND B-MODULE WAS STILL UNDERGOING MODIFICATION.   DURING THE  FIRST QUARTER
OF 1975 THERE WERE 8 A-MODULE OUTAGES, WITH ONLY ONE BEING A FORCED OUTAGE DUE TO THE SPLITTING OF A SLURRY  VENTURI  SUPPLY
HOSE.   B-MODULE WAS RETURNED TO SERVICE ON MAY 20, 1975.  THE UTILITY DECIDED TO OPERATE THE SCRUBBER ON ILLINOIS HIGH  SULFUR
COAL.   UPON INCEPTION OF THIS PROGRAM A MULTITUDE OF PROBLEMS OCCURRED.   THESE OCCURRED IN THE  FORM OF LOWER PARTICULATE
REMOVAL EFFICIENCIES, HIGH SLURRY CARRYOVERS, DEMISTER PLUGGING, REHEATER COIL FOULING AND LEAKS.   MODULE A  WAS TAKEN OUT OF
SERVICE IN MID-JUNE FOR THE REMAINDER OF 1975.  BY MID-SEPTEMBER 1975 B-MODULE WAS TAKEN OUT OF SERVICE  DUE  TO  MASSIVE  SCALING
IN THE ABSORBER SYSTEM.   'FINALLY. UNIT #1  CAME DOKN FOR A BOILER, TURBINE AND SCRUBBER OVERHAUL IN  MID-OCTOBER  FOR AN OUTAGE
THAT LASTED MORE THAN 4 MONTHS.
     THE OPERA8ILITY FACTORS  FOR EACH MODULE AND THE CORRESPONDING COMMENTS FOR THE  REPORT PERIOD  ARE PRESENTED IN THE
FOLLOWING TABLE.
                                                                                                      PtDCo-ENVIKONMENUL
                                                      43

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                                            FGD SYSTEM AVAILABILITY
                                            WILL COUNTY UNIT NO. 1
   PERIOD	OPERABILITY (X)
Month/Year   Nodule A  Module B
Mar.  72        0
         35
Apr.  72
34
14
May.  72
70
32
Jun.  72
         31
July.  72
                79
         21
                                                                   COMMENTS
                       Module A down for repair and modification to demister wash piping
                       assembly.  During this period,  Module  B was  taken  out of service
                       every 2 or 3 days to hand wash  the  demister.  Other problems,
vibration of reheater tubes bundle, rapid erosion of scrubber
spray nozzles, pluggage of venturi nozzles.
Module A out of service for 6 days due to a  near repture of a
venturi pipe expansion joint.  Heavy buildup of solids on demister.
Module B out of service most of the time for similar repair to
venturi pipe expansion joint, and_for modification to reheater unit
and demister wash system.
A few week outage of Module B to rebrace the reheater unit, tp_
Install underspray nozzles on demister and to use  heavier screens
                       in the  sump.   Reheater  pluggiNb  caused  additional outages.      _ _
                       Both  Modules  were  out of  service  due  to  high  differential
                      _pressure  across  the  demisters.   Leakage  of pond  return  bypass
                       valve caused  demisters  pluggiNti.  Also  during  this period, repairs
                       were  made to  the rubber lining of scrubber A.

                       Plugging  of venturi  nozzles and  demister paused  Module  A to be down
                      _fgr..2 days for repairs.   Module  B was put of  service for 22 days to
                                                                                                      PEDCo- ENVIRONMENTAL
                                          	  -44-  --

-------
                                            WILL COUNTY UNIT NO.  1  (continued)
   PERIOD       OPERABILITY (X)
Month/Year    Module A   Module B
                                                                       COMMENTS
Sept. 72
Oct. 7r


Nov. 72

Dec. 72

Jan. 73
Feb. 73


Mar. 73
22

 0
22


65
           30
30

 0
24


11
Clean the demister and the reheater unit as well  as to  Install  overhead
spray nozzles, and to replace sections of the demister.   The  boiler  was
down for 2 days to repair the generator.
Boiler down Sept.  1-5 because of no demand.  I.D.  fan problem caused
unstable operation of the boiler most of the month.  Module A was  down
for modifications  to reheater unit and repairs to  reclrculatlon tank
screens.
Boiler and scrubbers were down.  Outstanding modifications which were made
Included installation of reheater baffle plates to dampen vibrations and
Installations of an experimental demister wash system.
Boiler problems which caused unstable operation kept both modules down
during this month.
Modules operated intermittently due to electrostatic predpitator testing
and miscellaneous instrument problems.
Both Modules were down for repairs and modifications.
Modules were out of service due to cracks  in the Inlet ductwork of the
booster fan.   Improper installation of demister caused plugging of Module B
reheater unit.
Module A was out of service for 5 days due to demister plugging.  Boiler
was down for 4 days of inspection.  Module B was down due to leaks from
reheater tubes.
                                                                                               PEDCo-ENVIRONMENTAL
                                                               45

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                                           MILL COUNTY UNIT NO.  I  (continued)
 PERIOD          OPERABILITY(X)
Month/Year    Module A   Module B
                                                                   COMMENTS
Apr. 73

Hay. 73
Jun. 73
Jul. 73
Jul. 73

Sep. 73

Oct. 73


Nov. 73


Dec. 73
 0
16
51
19
32
51
13

 0
 0
 0
 0
Persisting problems with demlster and deposits of calcium sulfate scale
on reheater tubes of Module A.
Both modules were out of service during this month.
Module B was kept down In order to concentrate on solving the problems
encountered In Module A.  Boiler related problems were responsible for
most of the outages of Module A.
Module A problems:  reheater tubes leaks and high fan vibrations.
More reheater tubes leaks on Module A attributed-to chloride corrosion
attack.
Modules were down.  During this month, Chicago Fly Ash Co. finished
cleaning and treating the northeast half of the sludge pond.
Module A tripped several times this month due to bad limit switches
in the bypass and block dampers.  Unit was also taken down to balance
the booster I.D. fan.
Routine inspection of Module A revealed some plugging.  Module was kept
down for cleaning and some modification work.   Poor gas distribution in
module suspected to contribute to demister problems.
Modules were down and the whole month was spent doing modifications
and maintenance, mostly to demlster,  venturi throats, pumps  and
Isolation valves.
                                                                                            PERCo- ENVIRONMENTAL
                                                           46

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                                           _WILL COUNTY UNIT NO. 1 (continued)
       PERIOD .....  OPERABILITV (*)
     Month/Year   Module A  Module B
     Jan.  74	0	0
     Feb.  74
     Mar.  74
21
	Apr.... 74	72 	0.	
                     93
     Jun.  74
55
                     96
                                                              COMMENTS
                              Modules were down due to freezing problem In the 10" 4400  ft.  line
                                                   between modules and pond.  Some damage to sump pumps occured.  Freezing
                                                   weather also caused damage to some Instruments.                 	
                            ..The frozen pond pipe line was thawed, reanchored and returned to
 service.   The Instruments damaged by freezing were also repaired.	
 Module A  kept down until  arrival of second stage demlster.        _
 Module A  was ready for service March 20 but was not returned to  	
 service till March 27 because boiler was down.
 Module A  continued to operate until April 19 (except for two short
.Inspection outages) for 23 .consecutive days.  Run was made on low	
                              sulfur coal.  Sump screens from Module B was substituted for damaged
                              one 1n Module A.
                              Module A operated for the whole month except.for_short outages for	
 Inspection.   A good portion of this run was made with high sulfur coal.
 Module A operated for about 300 hrs.  The system was off for 2 wks.
.to repair venturl throat, drive.	
                              Module A operated for the ihole month except for one Inspection outage
                                                  .and twice when boiler was down.  Modu.le._B_1s_Jc_ept_dqwn__unt1l...satisfactory
                                                  _9P.er.ai.1 on.of_Hodu,le A 1s achieved.	
                                                                                                          PEDCo-ENVIRONMENTAL
                                                               47

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                                           HILL COUNTY UNIT NO. 1  (continued)
  PERIOD       OPERABIUTY (X)
Month/Year  Module A  Module B
Aug. 74        91         0
                                                                   COMMENTS
Sep. 74
Oct. 74
Nov. 74
Dec. 74
Jan. 75
Feb. 75
Mar. 75
85
94
97
99
99
99
99
Module A was'down six times this month, three times due to boiler "no
demand" outages, twice to repair leaks 1n steam piping and once to
balance a rough fan.
Module A was off three times this month:  once to clean deposits
from the ventuM throat, once to fix a desuperheater leak, and once
because boiler was down.
Module A was down four times:  once because of boiler outages, once
for Inspection and twice to fix reheater leaks.
Module A was out of service three times:  twice  because of no demand
and once for inspection.
Module A was down twice:  once for Inspection and once for repair
of valve In spent liquor line to pond.
Module A was down twice:  once for Inspection and once for no
demand.  Modification of module B is continuing.
Module A was out of service twice this month, once for inspection and
once for no demand.  One small reheater leak In  a stainless steel  bundle
was blanked-off on-line.  During the inspection,  demister  underwash nozzles
were cleaned and a small section of demister was  replaced.  Inspection  showed
conditions inside the scrubber to be about the same as before.   Coal  burned  tht
month averaged less than 1% sulfur.  Modifications of Module B  is  continuing.
Chicago Fly Ash 1s treating material from the scrubber with portland  cement
and fly ash and dumping into the north half of the holding basin.
Module A was down four times:  twice for no demand, once for a  venturi
hose leak, once for an accidental 50-m1nute trip.
                                                             48
                                                                                                 PEDCo-ENVIRQNMENT£L

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                                             WILL COUNTY UNIT NO.1(continued)
PERIOD         OPERABILITY («)
Month       Module A  Module B                             Comments
Apr. 75       40         0          Sludge pond was overburdened by near-continuous operation of Module A so that the
                                    FGD system had to be shut down until sufficient water could evaporate from the pond.
                                    The following modifications were made.  Pump gland water flows were reduced from 10 to
                                    5  gpm.  Filter backwash was routed out of system.  Continuous demlster underspray was
                                    charged to Intermittent.
May. 75       84        37          The "A" Module remained out of service until May 5, when it was determined that there
                                    was enough freeboard In the pond to start operating.  During the month, there were two
                                    more outages, one for 45 minutes, the result of a damper trip, the other to clean
                                    underspray nozzles.
                                    The "B" Module was In service 10:20 A.M., May 20, for the first time since noon, April
                                    13, 1973.  The start-up which was routine, was delayed until the 20th because of two
                                    broken oil pumps on the recirc. tank mixers.  Since the start-up, "B" has been out of
                                    service twice, once for a venturl pump trip, and once for a recirc. tank level trip.
                                    The total outage time was only 1 hour, 40 minutes.
Jun. 75 .     '61        85          Module A sustained 5 outages during month.  Module Is presently out of service to
                                    install new demisters and to replace the reheater.  Module B was out of service 8 times
                                    during month.  Longest outage was for 95 hours to clean booster fan and demlster.  Booster
                                    fan vibrations caused a shutdown on June 30.
jul. 75        o        79          Module A cannot be returned to service unMl the new reheater, ordered 1n April, Is
                                    received and Installed.  Module B sustained four outages.  Reheater failures at 1000
                                    hours seem to be a result of vibration fatigue.  One minor steam header leak also occurred.
Aug. 75        0       100


                                                                                       PEDCo- ENVIRONMENTAL

                                                               49

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                                             WILL  COUNTY UNIT NO.  1  (continued)

                   OPERABILITY (%)
PERIOD
Month     Module A       Module B                                          COMMENTS
Sep. 75      0             63          Module A remained out of service all  month due to a delay on the new reheater order.
                                       Module B was down 3 times during September due to massive absorber scale, demlster and 1.0.
                                       booster fan cleaning, balancing I.D.,  booster fan and absorber pump screen plugging.   Total
                                       outage time was 238*40".
Oct. 75      0           100          On October 11, 1975, the Will  County  Unit No. 1 started its boiler, turbine and scrubber
                                       overhaul.  Module B experienced two minor outages during the 11 day period prior to the
                                       overhaul.  Module A was down during the  entire period waiting for a new reheater.
Nov. 75      0             0          During the month of November the boiler, turbine, and scrubber modules were out of service for a
                                       scheduled overhaul.  Major maintenance areas included:  module reheaters, pond return pump,
                                     t
                                     •  venturi spray nozzles, venturl  and  absorber modules, pump valves, and sumps.
Dec. 75      0             0          Module B reheater returned from manufacturer after repairs and revisions.  Scrubber reheaters could
                                       be installed and operating by  the end  of January.
Jan- 76                                The unit remained out of service during  the report period for completion of the boiler,  turbine,
Feb- 76      0             0          and scrubber overhaul which commenced  on October 11, 1975.  System restart Is now  scheduled for
                                       sometime In mid-March 1.976.
                                                                                                                            PEDCo- ENVIRONMENTAL

                                                                              50

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL F6D SYSTEMS  03/76
 IDENTIFICATION NO.     30
 UTILITY NAME          OUflUESNE LIGHT
 UNIT NAME             ELRAMA
 UNIT LOCATION         ELKAKA PENNSYLVANIA
 UNIT. RATING            510 MM
 FUEL CHARACTERISTICS  COAL  1.0 - 2.6 PERCENT SULFUR
 FGD VENDOR            CHEMICO
 PROCESS               LIME SCRUBBING
 NEW OR RETROFIT       RETROFIT
 START UP DATE         10/75
 FGD STATUS            OPERATIONAL
 EFFICIENCY,
  PARTICULATES

  S02
 WATER MAKE UP
 SLUDUE DISPOSAL
 UNIT COST
 OPERATIONAL           THE FGD SYSTEM WAS PLACED IN SERVICE ON OCTOBER 26. 1975. INITIAL
  EXPERIENCE           OPERATION PKOCEEUCD WITH FLUL GAS FKOM ONE BOILER BEING TREATED BY THE
                       SCRUBBING SYSTEM. A SECOND BOILER HAS TIED INTO THE SYSTEM ON FEBRUARY 
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                                                 BACKGROUND INFORMATION
                                                           ON
                                                  ELRAMA POWER STATION

     DUQUESNE LIGHT COMPANY, AN'INVESTOR-OWNED ELECTRIC UTILITY,  SERVES  ABOUT  ONE-HALF  MILLION  CUSTOMERS  IN  SOUTHWESTERN
PENNSYLVANIA AND HAS A NET GENERATING CAPABILITY OF APPROXIMATELY 2500 MW.   THIS  CAPABILITY  IS  GENERATED  BY  COMBUSTION
TURBINES IN SIMPLE AND COMBINED CYCLE .MODES,  BY NUCLEAR PLANTS,  AND BY COAL  FIRED POWER STATIONS.   THE  COMPANY  IS  SOLE
OWNER AND OPERATOR OF THREE COAL  FIRED  STATIONS. TWO OF WHICH HAVE BEEN  RETROFITTED  WITH WET  SCRUBBERS  USING LIME  AS  A
REAGENT.
     THE SCRUBBER FACILITY AT THE 494 MW ELRAMA STATION IS ALMOST IDENTICAL  TO THE PHILLIPS  STATION.  GIBBS  & HILL IS THE
ARCHITECT-ENGINEER AND CHEMICO SCRUBBERS HAVE BEEN INSTALLED WITHIN THE  SAME DESIGNATED BATTERY LIMITS.   MECHANICAL AND
ELECTRICAL DUST REMOVAL EQUIPMENT REMOVE MOST PARTICULATES FROM  THE BOILER  EMISSIONS, AND THE GAS  TO  AND  FROM THE  SCRUBBERS
IS HEADERED IN THE SAME WAY.  UNLIKE PHILLIPS, HOWEVER, THERE ARE FOUR BOILERS,  EACH WITH ITS OWN  TURBINE GENERATOR.  FIVE SIN-
GLE STAGE SCRUBBERS WERE INSTALLED, WITH THE  INTENTION THAT THE  KNOWLEDGE GAINED  FROM THE TEST  PROGRAM  AT PHILLIPS WOULD BE
APPLIED TO ELRAMA TO ENABLE COMPLIANCE  WITH AIR EMISSION REGULATIONS.
     THE FIRST ELRAMA SCRUBBED WAS NOT  PLACED IN SERVICE UNTIL OCTOBER 26,  1975.   IT HAD BEEN SCHEDULED FOR  AN  EARLIER
STARTUP DATE; HOWEVER, DUE TO THE SEVERITY AND NUMBER OF PROBLEMS ENCOUNTERED  AT  PHILLIPS,  IT WAS  NECESSARY  TO  DELAY  STARTUP
UNTIL MANY OF THE PROBLEMS AT PHILLIPS  WERE RESOLVED AND THE MODIFICATIONS  COULD  BE  INCORPORATED AT BOTH  STATIONS.
     BOILER NO. 2 WAS INITIALLY CONNECTED TO  THE SCRUBBING SYSTEM ON OCTOBER 26,  1975.   THIS  BOILER HAS AN EQUIVALENT CAPACITY
OF APPROXIMATELY 100 MW, AND THE  EMISSIONS ARE HANDLED BY ONE SCRUBBER.   IN  ORDER TO INSURE  RELIABILITY IN THE  CASE OF A
SCRUBBER MALFUNCTION, TWO SCRUBBERS ARE OPERATED AT PARTIAL LOAD TO PROTECT  THE  BOILER  AND  TURBINE GENERATOR AGAINST  A TRIP-OFF.
     THE BOILER OPERATED CONTINUOUSLY ON THE  SCRUBBER SYSTEM THROUGH JANUARY 1976.   TWO MINOR OUTAGES OCCURRED  DURING THIS
PERIOD, ONE BEING CAUSED BY INOPERATIVE THROAT DAMPERS AND THE OTHER INVOLVED  THE FAILURE OF  A  LIME FEEDER BELT.
     TWO BOILERS ARE THE MAXIMUM  NUMBER THAT  CAN BE TIED INTO THE SCRUBBING  SYSTEM,  PENDING  COMPLETION  OF ADDITIONAL  CONSTRUC-
TION.  TO DATE THE UTILITY HAS ENCOUNTERED THE USUAL NUMBER OF MINOR START  UP  PROBLEMS  AND  SOME MAJOR PROBLEMS  AS  WELL.
                                                                                                    PEDCo-ENVIRONMENTAL
                                                               52

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ELRAMA POWER STATION (continued)

THE MAJOR PROBLEMS HAVE BEEN FROZEN PIPES AND THICKENER PROBLEMS.   THE  LATTER  IS  A  HARDWARE  AND  DESIGN  PROBLEM ASSOCIATED WITH
RECIRCULATION OF THE SLUDGE WITHIN THE THICKENERS TO ATTAIN 30-40  PERCENT  SOLIDS  CONCENTRATION.
     THE SLUDGE BEING GENERATED AT THIS STATION IS TREATED BY THE  IUCS  METHOD,  WHICH EMPLOYS A VACUUM FILTER, THUS  IN-
CREASING THE SOLIDS IN THE UNDERFLOW TO 50 TO 60 PERCENT,  THEREFORE REQUIRING  LESSER AMOUNTS OF  DRY  FLY ASH TO BE MIXED
WITH THE SLUDGE.
                                                               53

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                                             Elrama Power Station
Period

Oct. 75
  To
Jan. 76
Feb. 76
        Operating Hours
 Boiler          Scrubber Vessels
12       1-     2     3     4
            1169  1508   976   838
                      Remarks

One boiler was connected to the scrubber system on October 26,
1975.  A second boiler was connected on February 4, 1976.   Four of
the scrubber vessels have been In service In various combinations,
the service hours to January 31, 1974 are posted 1n the ac-
companying table.  The fifth vessel  has not been 1n service
because it 1s being revised for the  trial Installation of  rubber-
lined recycle pumps.
                                                                                                         PEDCo-ENVlKONtotNTAL
                                                               54

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                   TABLE 3
PERFORMANCE DESCRIPTION FOK OPERATIONAL FGD SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY MAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING
  31

 DUUUESNE LIGHT

 PHILLIPS

 SOUTH HEIGHT  PENNSYLVANIA

  mo  MU
 FUEL CHARACTERISTICS  COAL   i.O- 2.8 PERCENT SULFUR
 FGD VENDOR

 PROCESS

 NEW OK RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
  PARTICIPATES
 CHEMICO

 LIME SCRUBBING

 RETKOFIT

  7/73

 OPERATIONAL
  SOS
 60 PERCENT
 UATCK MAKE UP
 SLUDGE DISPOSAL
  STABILIZED SLUDGE DISPOSED IN  UNLINEO POND
 UNIT COST
 OPERATIONAL
  EXPERIENCE
S6<4/KW CAPITAL * b.8 MIULS/KWH ANNUALIZEU


 KLFEH TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT.   THIS
 FGO SYSTLM HAS BEEN OPERATIONAL SINCE JULY 1973. THE UTILITY HAS RECENTLY
 TEKMIHATED A TWO AND A HALF MO*TH TEST PKOGKAf. EMPLOYING THIOSORBIC LlHE
 IN THE SINGLE STAGE SCRUBBING MODULES. 1812 OPERATING HOUKS WERE LOGGED
 BY ONE SCRUBBING TRAIN AND 1309 HOURS WERE LOGGED BY ..MOTHER TRAIN. RE-
 SULTS INDICATE THAT THE REQUIRED DEGREE OF S02 REMOVAL (63 PERCENT) CAN
 BE OBTAINED WITH SINGE STAGE SCRUBBING, EMPLOYING LIME WITH A NGO CON-
 TENT OF 6 TO 10 PERCENT.
                                                        55
                                                                                                         PEOCo- ENVIRONMENTAL

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                                            BACKGROUND INFORMATION
                                                      ON
                                            PHILLIPS POWER STATION

     THE PHILLIPS POWER STATION IS LOCATED ON THE OHIO RIVER ABOUT 20 MILES NORTHWEST  OF  PITTSBURGH.   THE  POWER STATION
CONSISTS OF SIX COAL-FIRED BOILERS HAVING A NET GENERATING CAPABILITY OF 307 MW.   THE  RESULTANT  FLUE  GASES ARE  DISCHARGED  TO
A COMMON HEADER, TO WHICH THE FGD MODULES ARE CONNECTED THROUGH ISOLATION VALVES.   THE BOILERS ARE  CURRENTLY  BURNING  COAL
WITH A HEATING VALUE OF 11,350 BTU PER POUND AND A SULFUR AND ASH CONTENT OF 2.2  AND 18.2 PERCENT RESPECTIVELY.
     THE FGD SYSTEM WHICH SUPPLEMENTS THE EXISTING MECHANICAL AND ELECTROSTATIC DUST COLLECTORS,  CONSISTS  OF  FOUR  TRAINS OF
WET VENTURI-TYPE SCRUBBERS WHICH HAVE BEEN INSTALLED AT A COST OF APPROXIMATELY $103/kW.   GIBBS  & HILL,  INC.,  WAS ENGAGED
AS THE A-E FIRM FOR THE ENTIRE PROJECT WITH THE BATTERY LIMITS OF THE CHEMICO CORPORATION CONFINED  TO THE  SCRUBBERS AND
ASSOCIATED PUMPS AND CONTROLS BETWEEN THE INLET HOT GAS DUCT MANIFOLD AND THE EXIT WET GAS HEADER (INCLUDING  THE REHEATER,
EXCLUDING THE NEW ID FANS).
     THE FOUR TRAINS ARE LOCATED DOWNSTREAM OF EXISTING IN SERIES MECHANICAL COLLECTORS AND ESP'S INSTALLED ON  EACH OF THE
SIX PULVERIZED COAL-FIRED BOILERS.  THREE OF THE TRAINS ARE SINGLE STAGE VENTURI  SCRUBBERS ORIGINALLY INTENDED  FOR PARTICULATE
REMOVAL.  THE FOURTH TRAIN IS A DUAL STAGE VENTURI SCRUBBER-ABSORBER AND IS THE PROTOTYPE FOR DETERMINING  THE FEASIBILITY  OF
TWO STAGE SCRUBBING FOR COMPLIANCE WITH S02 EMISSION LIMITS.
     EACH TRAIN IS EQUIPPED WITH A NEW WET-TYPE ID FAN.  A NEW COMMON DUCT DIRECTS EMISSIONS FROM AIR BOILERS TO THE  SCRUBBER
SYSTEM WHERE THEY CAN BE SENT TO ANY OR ALL OF THE TRAINS.  THE SCRUBBED GAS IS EXHAUSTED THROUGH A COMMON DUCT AND AN OIL-FIRED
REHEATER TO A NEW GROUND SUPPORTED STACK WHICH CONTAINS AN INNER ACID-RESISTANT BRICK STACK. •
     SLAKED QUICKLIME IS ADDED TO THE LOWER CONE OF EACH OF THE SCRUBBER VESSELS TO NEUTRALIZE  THE  RECIRCULATING LIQUOR,  WHICH.
IN SINGLE-STAGE SCRUBBING WITH HIGH CALCIUM LIME, REACTS WITH APPROXIMATELY 50 PERCENT OF THE S02 IN  THE FLUE GAS. A LIQUOR
BLEED FLOW OF APPROXIMATELY 4 PERCENT IS SENT TO ONE OR BOTH OF THE THICKENERS FOR SOLIDS REMOVAL.   THE OVERFLOW IS RETURNED
TO THE SYSTEM AND THE UNDERFLOW IS PIPED TO THE SLUDGE TREATMENT SYSTEM.  THE UNDERFLOW IS STABILIED  BY THE ADDITION  OF  200
POUNDS OF CALCILOX PER TON OF DRY SOLIDS IN THE SLUDGE.  THE FIXED SLUDGE IS TRANSPORTED TO EXPERIMENTAL PLASTIC LINED PONDS
                                                                                                     PEDCo-ENVIRONNltrtfAL
                                                              56

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 PHILLIPS POWER  STATION  (continued)
 LOCATED ABOUT ONE MILE  FROM THE STATION, WHERE THE MATERIAL SOLIDIFIES.
     THE FLUE GASES FROM THE BOILERS ARE ACCELERATED TO A HIGH VELOCITY IN THE SCRUBBER.  AT THE THROAT. THE GASES COLLIDE
 WITH THE SCRUBBING LIQUID ATOMIZING IT  INTO SMALL DROPLETS.  THE FLY ASH AND THE SULFUR DIOXIDE IN THE GAS ARE PICKED
 UP BY THE SLURRY DROPLETS AND EXIT AT THE BASE OF THE TOWER.  THE GAS THEN REVERSES DIRECTION AND FLOWS UP THOUGH THE MIST
 ELIMINATOR WHERE FINE DROPLETS ARE REMOVED BEFORE THE GAS LEAVES THE SCRUBBER.
     STARTUP OF A PORTION OF THE PHILLIPS SCRUBBER SYSTEM  BEGAN JULY, 1973.  SEVERAL PROBLEMS THEN DEVELOPED IN THE FORM
 OF EROSION PROBLEMS TO  THE FANS AND THE LIME FEED SYSTEM, CAUSING OUTAGES OF THE SCRUBBER SYSTEM, AND AFTER AN EXTENDED
 OUTAGE, THE SCRUBBER SYSTEM WAS RETURNED TO SERVICE IN MARCH. 1974.  THE SYSTEM HAS BEEN OPERATING CONTINUOUSLY SINCE THAT
 TIME WITH A VARYING NUMBER OF BOILERS CONNECTED TO THE SCRUBBER SYSTEM, AND -WITH A VARYING'NUMBER OF SCRUBBER TRAINS IN
 SERVICE.
     DETERMINATION OF THE AVAILABILITY OF THE PHILLIPS SCRUBBER HAS BEEN A DIFFICULT AFFAIR DUE TO THE NATURE OF THE
 SCRUBBER SYSTEM DESIGN.   UNTIL ALL BOILERS WERE CONNECTED TO THE SCRUBBERS, THERE WAS AT LEAST ONE SPARE TRAIN AND AS
 MUCH AS 100X SPARE SCRUBBER CAPACITY.   THEREFORE, HAVING A TRAIN OUT OF SERVICE FOR MAINTENANCE DID NOT REDUCE THE
 CAPABILITY OF THE SCRUBBER PLANT.   UNTIL ALL SIX BOILERS WERE CONNECTED, MEANINGFUL AVAILABILITY FACTORS WERE NOT AVAILABLE.
 ON MARCH 17, 1975, THE LAST BOILER WAS CONNECTED. AND ALL FOUR SCRUBBER TRAINS WERE REQUIRED TO BE IN SERVICE.   OPERATION
 IN THAT MODE CONTINUED UNTIL AUGUST 4, 1975  WHEN IT WAS  NECESSARY TO REMOVE THE NO. 6 BOILER FROM  THE SCRUBBER SYSTEM
 BECAUSE THE pH IN THE SYSTEM COULD NOT BE MAINTAINED  AND DEPOSITS  WERE BECOMING UNMANAGEABLE TO THE POINT  WHERE  SCRUBBER
OUTAGES WERE REDUCING THE STATION  GENERATING CAPABILITY.
                                                                                            PEDCO-ENVIRONMENTAL
                                                             57

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                                                     Phillips  Power Station
 Month
 Jul. 75
 Sep. 75
 Oct. 75
Nov. 75
Dec. 75
Jan. 76
      Boiler
    234
Operating  Hours
     5   6
Scrubber-Absorber
1A   IB    2    3   4
83 644 703  349 605 643 400
                       180  537  723
 Aug. 75     354 701 454  457  517 445 478    0    682 323 319
                        Remarks
Fourth  FGD  train and sixth  boiler were tied  in on March  17,  1975.
Particulate tests In May  showed outlet loadings of 0.04  lb/
million Btu.
The two-stage train has been  out of service  from June 19  for
general cleaning and to repair a leak in  the first-stage  scrubber.
Scrubber  unavailability has  forced returning Boiler No.  6  to the
scrubber  bypass gas path  in  order not to  lose boiler capacity.
Plugging  and  maintenance  problems have been  encountered  in
scrubbers.   An evaluation of  various recycle pumps 1s continuing.
As of  October,  1975, Phillips  initiated thiosorblc lime scrubbing  in their
single stage modules on an experimental basis.   The purpose of this pro-
gram is to study compliance feasibility, S02 removal efficiency, and the
quality of the  sludge generated by the single stage modules.
The utility concluded the thiosorblc line testing program which commenced
October 1, and  terminated in mid-December.  A total of four boilers were
coupled to the  scrubbing system during the run.   The utility is now in the
progress of analyzing the data generated during  the test run.  The  scrubbers
have been put back on regular  lime.  No unusual  problems were encountered
during the test run.
The two and a half month  test program with  thlosorbic lime  resulted
1n  1612 service hours on  one  train and 1309  hours on another train.
Results indicate that the required degree of SO- removal  (83 per-
cent) can  be  obtained with  an MgO content of 8-10 percent  in the
lime with  single stage scrubbing.
                          PEOCo-ENVIRONMENTAL
                                                               58

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                   TABLE 3
PERFORMANCE DESCRIPTION FUK OPERATIONAL FGD SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING
 32

GENERAL MOTORS

CHEVROLET PARMA 1 2 3 &

PARMA OHIO

  32 MU
 FUEL CHARACTERISTICS  COAL   2.5 PERCENT SULFUR
 FGD VENDOR

 PROCESS

 NEW OR RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
  PARTICULATES


  S02


 WATER MAKE UP


 SLUDGE DISPOSAL


 UNIT COST
KOCH

DOUBLE ALKALI

RETROFIT

 3/7H

OPERATIONAL
 OPERATIONAL
  EXPERIENCE
REFEK TO UACKGROuND-INFORMATION SECTION IN TABLE. 3 OF THIS REPORT. THIS
F&O SYSTEM HAS BELN OPERATIONAL SINCE MARCH 1974. SYSTEM OPERAB1LITY HAS
AVERAGED OVER b9 PERCENT DURING THE PAST f> MONTHS. SYSTEM OPERAB1LITY WAS

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                                                       BACKGROUND INFORMATION
                                                                ON
                                                   THE CHEVROLET PARMA STEAM PLANT

     THE CHEVROLET PARMA PLANT OF GENERAL MOTORS IS LOCATED  NEAR CLEVELAND, OHIO.  THE PLANT HAS FOUR SPREADER
STOKER BOILERS FIRED BY TRAVELING GRATES AND PRODUCES A TOTAL  RATED CAPACITY OF 32 MW.  THE BOILERS ARE RETROFITTED
WITH A SOLUBLE ALKALI FGD SYSTEM.  THE COAL BEING BURNED AT  THE PLANT CONTAINS ABOUT 2.5 PERCENT OF SULFUR.
     THE FGD SYSTEM WHOSE SIZE IS 32 MW, WAS DESIGNED BY KOCH  ENGINEERING AND WAS COMPLETELY INSTALLED ON FEBRUARY
28, 1974.  THE SYSTEM CONSISTS OF FOUR SCRUBBERS OPERATING IN  PARALLEL.  EACH SCRUBBER IS MADE OF THREE ABSORPTION
TRAYS AND A MESH MIST ELIMINATOR.  CONSTRUCTED OF ALL ELEMENTS ARE OF NO. 316L STAINLESS STEEL.
     SODA ASH, THE PRIMARY REACTANT OF THE SYSTEM, IS MIXED  WITH THE OVERFLOW FROM THE REACTOR CLARIFIER AND PUMPED
TO THE SCRUBBER SYSTEM.  CAUSTIC. SOLUTION IS REGENERATED BY  ADDING LIME SLURRY TO A PORTION OF THE ABOVE LIQUID
AFTER NEUTRALIZING IT WITH CaC03-  THIS REGENERATED CAUSTIC  SOLUTION ENTERS THE REACTOR CLARIFIER WHERE ADDITION
REACTION TAKES PLACE AND THE CALCIUM SULFITE AND OTHER SOLIDS  ARE PRECIPITATED.
     THE SOLIDS FROM THE CLARIFIER CONTAINING 20 PERCENT SOLIDS ARE PUMPED THROUGH A BLEND TANK TO A 500 SQUARE
FOOT ROTARY DRUM FILTER.  THE FILTER CAKE IS DEWATERED TO  50 PERCENT SOLIDS.
                            !
PROBLEMS AND SOLUTIONS      :
     THE INSTALLATION WAS STARTED UP ON FEBRUARY 28,  1974  AND  BY APRIL 31, 1974, IT OPERATED FOR 624 HOURS.  THERE
WERE TWO SCHEDULED SHUTDOWNS DURING THIS PERIOD FOR EQUIPMENT  INSPECTION.  THE SECOND SHUTDOWN REVEALED THAT SOLIDS
WERE NOT BEING DISCHARGED FROM THE PRIMARY CLARIFIER  RAPIDLY ENOUGH.  AS A RESULT, THE CLARIFIER RAKE JAMMED.  A
PIPING CHANGE WAS MADE TO BLEND THE CAUSTIC FEED IN WITH THE RECYCLE LIQUOR.  THIS HAS IMPROVED BUT NOT COMPLETELY
ELIMINATED THE PROBLEM.  NO PROBLEMS HAVE BEEN ENCOUNTERED WITH THE MESH MIST ELIMINATORS.  THE VACUUM FILTERS
CAUSED PROBLEMS DUE TO PREMATURE CAKE CRACKING NECESSITATING AN OPERATOR ON HAND DURING OPERATION.  G.M. ANTICIPATES
THAT THE CHANGE TO NYLON FROM POLYPROPYLENE WILL SOLVE THIS  PROBLEM.
                                                                                                PEDCo-ENVIRONMENTAL

                                                                   60

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CHEVROLET PARMA (continued)

     CAKE WASHING TO REDUCE SODIUM LOSSES MAS NOT INITIALLY  SUCCESSFUL  DUE TO THE TENDENCY OF THE SPRAY WATER TO
KNOCK THE CAKE OFF THE DRUM.  ALTERATIONS IN SPRAY PATTERN AND OTHER MEASURES HAVE NOW APPARENTLY SOLVED THIS
PROBLEM.
     THERE HAS BEEN NO EVIDENCE OF CORROSION OR ABRASION IN  THE  PUMPS OR PIPING.
     THE SYSTEM WAS SHUTDOWN FROM MAY 1  TO MAY 28, 1974  DUE  TO THE  UNEXPECTED BUILD-UP OF SOLIDS IN THE CLARIFIER
WITH SUBSEQUENT OVERFLOW INTO THE SCRUBBER.   THE PROBLEM WAS SOLVED BY  1)  USING A POLYMERIC FLOCCULATION AGENT TO
ATTAIN BETTER SETTLING AND 2)  WITHDRAWING SLUDGE FROM THE CLARIFIER AT MORE FREQUENT INTERVALS.  THE SYSTEM
AVAILABILITY TO THE BOILER HAS BEEN 87 PERCENT IN APRIL  1974,  LESS  THAN 10 PERCENT IN MAY AND 100 PERCENT IN JUNE,
JULY AND AUGUST 1974, AFTER THE SYSTEM WAS RESTARTED.  PLUGGING  BY  CaCO-j DEPOSITS IN THE OVERFLOW LINE BETWEEN THE
CLARIFIERS AND IN THE LINE FROM CLARIFIER #2 TO THE MIX  TANKS  HAS BEEN  A PROBLEM THAT HAS BEEN CORRECTED BY RELOCATING
A CHEMICAL FEED LINE AND REPLACING SOME  PIPING.   THE SYSTEM  WAS  DOWN THROUGHOUT THE MONTHS OF JULY AND AUGUST TO
REPLACE GRAVITY FLOW LINES WITH AN OPEN  FLUME THAT CAN BE EASILY CLEANED.
                                                                                              PEDCo-ENVIRONMENTAL

                                                                 61

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                                                       Chevrolet Parma
                    Operating hours
Month
Jun. 75
                   FGD system
                     2     3
                                                                  Qperab.nity  (X)
                                                                    Remarks
                                                Recent operation  has  been Intermittent  1n
                                                nature.  Tests  by manufacturing development
                                                and Chevrolet central  office to determine
                                                boiler outlet participate loading parameters
                                                have been conducted.  System was restarted  In
                                                May but had to  be shut down because of  plugged
                                                chemical feed line to  clarlfler.  System re-
                                                started about June 10  and had to be shut down
                                                because of similar plugging in another  part of
                                                the line.  Unit ran for about two weeks In  June.
Jul. 75
Aug. 75

 Sep. 75
 Oct. 75
2331*
00000000    Down for July to  August for revisions  to  system.
00000000    Replacing gravity flow lines with an open  flume.
                                                Will restart In September.
                                                FGD  System restarted September 8, 1975, operated during
      1848*                    79               this period at an availability factor of 80 percent.
                                               *Note:  The figures given for September and October
                                                represent the operation hours for the period of
                                                September 8 to November 9. Inclusive.
                                                                                            PEDCo-ENVIRONMENTAL
                                                                62

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                                            Chevrolet Parma (continued)
                    Operating hours
Month

Nov. 75
Dec. 75
2135
                  FGD System
                    2     3
1250
                        Availability (*)
                          23      4
                                                                  59
Jan. 76
Feb. 76
2997
                                        1196
                                            40
                   Remarks
The FGD System operated during the report
period with the exception of a scheduled
holiday shutdown (extending from 12/23 to
1/4).  The FGD System experienced some
problems with solids and solids carryover.
G.M. conducted stream tests during the
month of December in an effort to de-
termine if the solids carryover problem
is due to a high solids recirculation
rate.  The FGD system was down most of
December because of these tests.
The low operability factor was not due to
system unavailability but to the continuation
of a study program concenred with high solids
and solids carryover.   G.M.  is examining the
settling of solids in the system  clarifier as
a possible solution to the problem.   To date
the company has found the solids  concentra-
tion in the clarifier too high for efficient
system operation.   A.D.  Little is scheduled
to conduct tests on the system in April as
part of an EPA evaluation nf the
                                                           63
                                                                                  PEDCo-ENVIRONMENTAL

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL F60 SYSTEMS  03/76


 IDENTIFICATION NO.     33

 UTILITY NAME          GULF POWER CO.

 UNIT NAME             SCHOLZ NO. 1A

 UNIT LOCATION         CHATTAHOOCHEE  FLORIDA

 UNIT RATING             20 MM

 FUEL CHARACTERISTICS  COAL   3.0 PERCENT SULFUR

 FGO VENDOR            ADL/COMBUSTION EQUIP ASSOCIATE

 PROCESS               DOUBLE ALKALI

 NEW OK RETROFIT       RETROFIT

 START UP DATE          2/75

 FGO STATUS            OPERATIONAL

 EFFICIENCY,
  PARTICULATES


  S02


 WATER MAKE UP


 SLUDGE DISPOSAL


 UNIT COST


 OPERATIONAL            KEFEK  TO BACKGROUND  INFORMATION  SECTION  IN  TAULE  3  OF  THIS  REPORT.  THIS
  EXPERIENCE            FGO  SYSTfc.M HAS BEEN  OPERATIONAL  SINCE  FEB.  197&.  THE PROTOTYPE  SYSTEM
                       OPERATED A TOTAL  OF  <*7tt  HRS.  bURING 1975,  TRANSLATING INTO AN  ANNUAL
                       AVLKAGt  OPERAB1LITY  OF  89 PERCENT.  THE SYSTEM  WAS DOWN THROUGHOUT THE  RE-
                       PORT PERIOD DUE TO A SCHEDULED PLANT BOILER OVERHAUL.  SYSTEM RESTART IS
                       SCHEDULED FOR MID-MARCH 1976.  THE SYSTEM IS SCHEDULED  TO  RUN THROUGH TO
                       JUNE 1976.
                                                             64                                          PEDCO-.ENVIROPENTAL

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                                            BACKGROUND  INFORMATION
                                                     ON
                                         SCHOLZ  NO.  1A  -  DOUBLE  ALKALI

     THE SCHOLZ STEAM POWER PLANT OF GULF POWER  COMPANY IS LOCATED  IN  CHATTAHOOCHEE.  FLORIDA.   UNIT  NO.  1  IS A  COAL-FIRED
BOILER DESIGNED FOR NOMINAL LOAD OPERATIONS OF 40 MW AND  PEAK CAPACITY  OPERATION  OF  47.5  MW.   THIS UNIT  WAS SCHEDULED TO BURN
VARIOUS TEST COALS WHICH HAVE AN AVERAGE HEATING VALUE  OF 12,400 BTU/LB., 14 PERCENT  ASH  CONTENT  AND SULFUR RANGING  AS  HIGH
AS 5 PERCENT.
     A 20 MW PROTOTYPE DUAL ALKALI SYSTEM WAS JOINTLY DEVELOPED, DESIGNED AND INSTALLED BY COMBUSTION EQUIPMENT ASSOCIATES AND
ARTHUR D. LITTLE.
     THE PROTOTYPE SYSTEM AT THE SCHOLZ STEAM PLANT IS  INSTALLED ON BOILER NO.  1, A  BABCOCK &  WILCOX PULVERIZED COAL-FIRED
BOILER.  THE SYSTEM IS DESIGNED TO HANDLE 50 PERCENT OF >HE FLUE GAS FROM THE BOILER.  THE BOILER HAS BEEN RETROFITTED  WITH
A SECTIONALIZED, HIGH EFFICIENCY ESP CAPABLE OF 99.7X PARTICULATE REMOVAL.  THE ESP  CAN BE SELECTIVELY DE-ENERGIZED  FOR STUDY
OF PARTICULATE IMPACT ON THE FGD PROCESS OPERATION.
     THE PROTOTYPE UNIT INCORPORATES A HIGH DEGREE OF FLEXIBILITY FOR THE MAIN PURPOSE OF GENERATING DESIGN AND OPERATING
INFORMATION  FOR A WIDE VARIETY OF APPLICATIONS.   ALTHOUGH THE BASIC MODE OF THE SYSTEM OPERATION  IS  DUAL ALKALI WITH LIME
REGENERATION THE SYSTEM WAS DESIGNED TO ACCOMODATE LIMESTONE REGENERATION AND LIME/LIMESTONE COMBINATION REGENERATION.
     THE SYSTEM PROPER INCLUDES A VENTURI SCRUBBER AND AN ABSORPTION TOWER.  AN ADDITIONAL STORAGE SILO FOR  LIMESTONE,  A MIX
TANK. AND OTHER ASSORTED TANKS, PUMPS, CONTROLLERS AND PIPING ARE ALSO INCLUDED IN THE SYSTEM.
     THE PROTOTYPE SYSTEM WAS COMPLETED AND PUT IN OPERATION BY CEA/ADL  IN EARLY FEBRUARY 1975.  IN  MID-MAY  AN  EPA DUAL
ALKALI TEST  PROGRAM WAS INITIATED BY SOUTHERN SERVICES. CEA AND ADL.  THE SYSTEM WAS OPERATIONAL  THROUGH EARLY  JANUARY  1976,
WHEN THE BOILER WAS SHUT DOWN FOR A SCHEDULED OVERHAUL.  THE BOILER AND  PROTOTYPE SYSTEM ARE SCHEDULED TO BE  PLACED  BACK
IN SERVICE  EARLY MARCH 1976.
                                                                                                       PEDCO-ENVIRONMENTAL
                                                               65

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             Scholz  1A  -  Double Alkali
Ing  hours          FGD  system
 FGE
                   Boiler      FGD sysTem     OperabilUy  (%)                     Comments
                                                                 Unit  was  placed  1n  operation  Feb.  5,  1975,  and  operated
                                                                 through  to  July  18,  1975, When  the  system  was  shutdown
                                '2,600             83             for a two-month  period  for  modifications, repairs  and
                                                                 replacement parts. - The system was unavailable'to  the
                                                                 boiler for  a 491  hour period  because  of  necessary 'ao-
                                                                 justments and modifications required  for Initiation  of
                                                                 the formal  EPA test  program In mid-May.
Jul. 75                                                          The system  was shutdown from  mid-July'to mid-September.
  To                                                             Repairs  and revisions effected were  of a mechanical
Sep. 75                                                          nature,  Involving replacement parts  for  valves  that  had
                                                                 failed.
Sep. 75                                            44             The system  was put  back in  operation  on  September 'l6,
Oct. 75                                           100             1975. From mid-September to  mid-October, repairs  were
                                                                 made  to  the air  preheater and adjustments were  made  in the
                                                                 boiler operation, reducing  flue  gas  oxygen  levels  down to
                                                                 5-6 percent range.   The system operated  approximately 800
                                                                 hours during this period.
                         66

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                                Scholz 1A - Double Alkali (continued)

                        Operating hours         FGD system
   Period          BolleF      FGD system     OperablHty (%)                    Comments
Nov. 75             620           560               90           The system ran continuously for the remainder of the test
Dec. 75             732           732              100           period through January 2, 1976.  S02 levels during this
                                                                 period were In the 800 to 1700 ppm range.  The system
                                                                 operated in the concentrated mode throughout the remainder
                                                                 of the test period.  Covering the period from mid-
                                                                 September to January 2, 1976, the system operated a total
                                                                 of approximately 2,100 hours, equaling an- operabtlIty
                                                                 factor of 97 percent.
Jan. 76                                                          The FGD system and boiler were inoperative during the
Feb. 76                                                          report period due to a scheduled overhaul.
                                                                 System  restart is scheduled for mid-March 1976, with
                                                                 operation continuing to June 1976.  During this opera-
                                                                 ting period high sulfur coal will  be used at Scholz
                                                                 (3.5-4.0 percent), enabling evaluation of system per-
                                                                 formance on high sulfur coal application.
                                                           67

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT.RATING

 FUEL CHARACTERISTICS

 FGD VENDOR

 PROCESS

 NEW OK RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
  PARTICULATES
 34

GULF POWER CO.

SCHOLZ NO. 2A

CHATTAHOOCHEE  FLORIDA

  20 MM

COAL   3.0 PERCENT SULFUR

FOSTER WHEELER

ACTIVATED CARBON

RETROFIT

 2/76

OPERATIONAL
  S02
60 PERCENT
 WATER MAKE UP
 SLUDGE DISPOSAL
 UNIT COST
 OPERATIONAL
  EXPERIENCE
REFER 10 BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT.  SYSTEM
MODIFICATIONS ANU PKE-STARTUP CHECKOUTS WERE COMPLETED.  A SUCCESSFUL
THREE UAY DRY HUN FOLLOWED. REINTROOUCTION OF FLUE GAS INTO THE SYSTEM
COMMENCED IN FEBRUARY AND A FOUR MONTH TEST PROGRAM IS NOW IN PROGRESS.
DURING THIS TEST PROGRAM S02, NOX, AND FLYASH REMOVAL IERFORMANCEt  SYSTEM
ECONOMICS AND SYSTEM RELIABILITY WILL BE ANALYZED.
                                                             68
                                                                                 PEDCo- ENVIRONMENTAL

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                                                 BACKGROUND  INFORMATION
                                                          ON
                                               SCHOLZ  NO.  2A -  FWBF  SYSTEM

     IN JANUARY, 1973. THE SOUTHERN SERVICES COMPANY OF GULF POWER AWARDED  A  CONTRACT  TO  THE  FOSTER  WHEELER CORPORATION
TO BUILD A 20 MW PROTOTYPE DRY ADSORPTION SYSTEM FOR FLUE  GAS  DESULFURIZATION.   CONSTRUCTION  ON  THE  FOSTER WHEELER  PROCESS
STARTED FEB. 15, 1974 AT THE SCHOLZ STEAM POWER PLANT  LOCATED  IN CHATTACHOOCHEE.  FLA.   CONSTRUCTION  WAS  COMPLETED AND A
TESTING PROGRAM WAS INITIATED IN MAY, 1975.
     THE SYSTEM AT THE SCHOLZ PLANT CONSISTS OF A 20 MW ADSORBER SECTION AND  A  47.5 MW REGENERATION  AND  REDUCTION SECTION.
THE 20 MW ADSORBER IS DESIGNED TO ACCEPT HALF OF THE MAXIMUM FLUE GAS FLOW  FROM  UNIT NO.  2.   THE COAL  FIRED BOILER  IS RATED
AT 40 MW (NOMINAL) AND FIRES COAL WITH A HEATING VALUE OF  12,400 BTU/LB.  ASH CONTENT IS  14Z, AND SULFUR CONTENT RANGES
AS HIGH AS 5%.
     THE PROCESS CAN BE DIVIDED INTO THREE BASIC SECTIONS:  ADSORPTION,  REGENERATION AND  REDUCTION.
     THE PURPOSE OF THE ADSORPTION SECTION IS TO REMOVE SOg, AND NOX AND PARTICULATE MATTER ON THE FLUE  GAS WITH ACTIVATED
CHAR, CONVERTING THE CAPTURED POLLUTANTS TO SULFURIC ACID.  THE REGENERATION  SECTION PROVIDES CONTINUOUS ON-SITE REGENERA-
TION OF THE CHAR WHICH HAS BEEN LOADED WITH S02 IN THE FORM  OF H2S04-  THE CHAR  IS REGENERATED AND A LOW VOLUME  SOg RICH
OFF-GAS STREAM  IS FED FORWARD TO THE RESOX REACTOR WHICH REDUCES THE S02 STREAM  TO GASEOUS ELEMENTAL SULFUR WHICH  IS COLLECTED
AND STORED  IN AN INSULATED TANK.
     THE DEMONSTRATION UNIT HAS TWO ROWS OF MODULES, EACH ROW CONSISTING OF SIX  MODULES.   THE ADSORPTION SECTION  IS A TWO STAGE
DESIGN CONSISTING OF VERTICAL COLUMNS OF PARALLEL LOUVER BEDS WHICH SUPPORT AND CONTAIN THE ACTIVATED CHARCOAL.   SULFUR
DIOXIDE, OXYGEN. WATER VAPOR, AND THE OXIDES OF NITROGEN ARE ADSORBED BY THE  CAR PELLETS  FROM THE CROSS  FLOWING  FLUE GAS
AT 250 - 300° F.  THE S02 THEN  REACTS WITH 02 AND HgO  FORMING H2S04 WHICH  IS FIRMLY RETAINED IN THE INTERIOR  PORE  SYSTEM  OF  THE
CHAR PELLETS.   THE CHAR  IS THEN REGENERATED  IN THE  REGENERATOR VESSEL BY HEATING TO 1200°F. DRIVING OFF  THE  ENTRAINED GASES
AND REDUCING  SULFURIC ACID TO SOg.  THE  SOg-RICH GAS  IS THEN PASSED THROUGH A VESSEL CONTAINING CRUSHED  COAL  RESULTING  IN
REDUCTION  TO  GASEOUS  ELEMENTAL  SULFUR AND CARBON DIOXIDE.   THIS  LATTER  PROCESS IS  CARRIED OUT AT 1200° - 1500°F.
                                                                                                         PEDCO-ENVIRONMENTAL

                                                                69

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SCHOLZ NO. 2A - FUBF SYSTEM (continued)
     THE UNIT'S INITIAL SHAKE DOWN RUN ON FLUE GAS BEGAN  AUGUST  11.  1975  AND  PROCEEDED  ON A CONTINUOUS BASIS  FOR TEN DAYS.
THE REGENERATION SECTION WAS OPERATIONAL ABOUT 60X OF  THE TIME.   HOWEVER,  THE  RESOX  SECTION HAS  NOT  YET  BEEN  COUPLED INTO  FULL
SYSTEM OPERATION.   S02 REMOVAL WAS WELL  ABOVE EXPECTATIONS AND PRESSURE DROP  ACROSS  THE ADSORBER WAS WELL  BELOW DESIGN LEVELS.
THE SYSTEM WAS SHUTDOWN PENDING CORRECTION OF SEVERAL  OPERATING  PROBLEMS.  EQUIPMENT  MODIFICATIONS AND EVALUATION OF THE  INITIAL
OPERATING DATA.  OPERATION WAS RESUMED AGAIN  IN OCTOBER  1975, WHEN TWO CONSECUTIVE OPERATIONAL RUNS  WERE CONDUCTED ON THE
RESOX PORTION OF THE SYSTEM. PROCESSING  FRONT-END OFF-GAS AT  FULL OPERATING TEMPERATURES.  A MODIFICATIONS PROGRAM WAS
COMPLETED ON THIS  SYSTEM IN EARLY JANUARY L976.  REPRODUCTION  OF FLUE GAS INTO THE  INTEGRATED  SYSTEM COMMENCED IN FEBRUARY
1976.  THE SYSTEM  IS CURRENTLY OPERATING THROUGH A FOUR  MONTH TEST PROGRAM SPONSORED  BY SOUTHERN SERVICES  AND FOSTER WHEELER.
                                                                                                         PEDCo-ENVIRONMENTAL
                                                               70

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                                         FWBF  System Operating  History

                                                                                       Comments
                                                                 Initial  construction  of  the  system was completed and a  t
                                                                 three month commissioning period followed.  Various pieces
                                                                 of equipment  In the system were operated individually
                                                                 and then  in combinations to  simulate sub-system operation.
"9'                                                              Sub-system operations were integrated into section opera-
                                                                 tions and flue gas was passed through the adsorber and
                                                                 regenerator for a 10-day period beginning August 11.
                                                                 RESOX construction was incomplete at this time.
                                                                 Two consecutive operational  runs were conducted on the
                                                                 RESOX portion of the system on front-end process off-gas
                                                                 at full  operating temperatures.  This operational  period
                                                                 lasted 5 days.
                                                                A modifications program on the system commenced in late
                                                                August 1975 and continued through January,  with the
*"' ?6                                                          exception of the 5 day RESOX operation in October.
                                                                Modifications were completed and pre-startup testing
                                                                program  was conducted  in late January and early February.
                                                                A three-day continuous dry run was  successfully com-
                                                                pleted.   All  materials handling loops and RESOX loops
                                                                were  operated at full  operating temperatures and pres-
                                                                sures.   Following  this reintroduction of  flue  gas  into
                                                                the system commenced  and a  four month formal  test  program
                                                                conducted by Southern  Services and  Foster Wheeler  is now
                                                                in progress.


                                                                                                         PEDCo-ENVIRONMENTAL
                                                           71

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING

 FUEL CHARACTERISTICS

 FGD VENDOR

 PROCESS

 NEW OR RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
  PARTICULATES
 35

GULF POWER CO.

SCHULZ NOS. IB & 2B

CHATTAHOOCHEE  FLORIDA

  23 MW

COAL   3.0 PERCENT SULFUR

CHIYODA INTERNATIONAL

THOROUGHBRED 101

RETROFIT

 3/75

OPERATIONAL
  S02
90 PERCENT
 WATER MAKE UP
 SLUUGE DISPOSAL
 UNIT COST
 OPERATIONAL
  EXPERIENCE
REFLR TO BACKGKOuND INFORMATION SECTION IN TABLE 3 OF REPORT.  THIS  FGD
SYSTllM HAS BEEN OPERATIONAL SINCE MARCH 1975.  THE TOTAL SYSTEM OPERABILI.
TY. INCLUDING SYSTEM COMMISSIONING! EXTENDING  FROM FEB. 11.1975.  TO
DECEMBER 31. 197&. WAS 60 PERCENT. SYSTEM OPERABILITY FOR THE  MONTH OF
JANUARY 1976 EXCEEDED 66 PERCENT. THE SYSTEM DID NOT OPERATE DURING THE
MONTH OF FEBRUARY.
                                                           72
                                                                               PEDCo ENVIRONMENTAL

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                                                 BACKGROUND INFORMATION
                                                           ON
                                             SCHOLZ UNITS 1 AND 2 - CHIYODA

     THE SCHOLZ POWER PLANT IS LOCATED IN CKATTAHOOCHEE, FLORIDA, ABOUT 50 MILES WEST OF TALLAHASSEE.   THE FGD  SYSTEM  WAS
DESIGNED BY CHIYODA INTERNATIONAL CORP.  FOR TESTING AND PROCESS DEMONSTRATION ON A COAL-FIRED BOILER.   THE PORCESS  IS  IN USE
IN JAPAN. BUT ONLY ON OIL-FIRED AND GAS-FIRED BOILERS.
     THE SYSTEM CAN HANDLE ONE-HALF THE  LOAD (53.000 SCFM) FROM EITHER OF. TH1 47 MW BOILERS.   DESIGN  ABSORBER  INLET  SOg
CONCENTRATION IS 2250 PPM.  VARIOUS TEST COALS WITH SULFUR CONTENTS RANGING UP TO 5 PERCENT ARE  SCHEDULED  FOR BURNING.
     THE PARTICULATE LOADS FROM NEWLY INSTALLED ELECTROSTATIC PRECIPITATORS ON THE TWO UNITS  RANGE  FROM 0.02 TO 0.1
GR/SCF.  FLUE GAS FROM THE PRECIPITATORS IS QUENCHED WITH COOLING WATER TO REMOVE ADDITIONAL  FLY ASH  AND TO COOL THE
GAS BEFORE IT ENTERS THE S02 ABSORBER.
     S02 IS ABSORBED IN WATER AND CATALYTICALLY OXIDIZED WITH AIR TO FORM SULFURIC ACID.  THE DILUTE  ACID  IS RECIRCULATED
THROUGH THE ABSORBER.  A PORTION OF THE  ACID IS NEUTRALIZED WITH LIMESTONE TO PRODUCE GYPSUM  AS  A BY-PRODUCT.
     BREAK-IN TESTS WERE INITIATED IN FEBRUARY 1975.  DURING THESE TESTS SEVERAL MINOR PROBLEMS  WERE  ENCOUNTERED.  AFTER
THESE PROBLEMS WERE CORRECTEDiTHE SYSTEM WAS SUBJECTED  TO A SIX MONTH RELIABILITY TEST PROGRAM.
                                                                                                     PEDCo-ENVIRONMENTAL
                                                              73

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                                          Schloz IB and 2B - Chlyoda
                    Operating hours          FGD system
Month          BoilerFGD system        Operabilfty (%)                    Comments
                                                            This Is a pilot plant size demonstration unit.  Engineering
                                                            design began sept.  73.   Startup occurred In March 1975.   After
                                                            Initial operation for break-In tests, unit will  be shutdown
                                                            for Internal Inspection.   Reliability tests will  then followed.
                                                            starting June 1975.   Chemical  performance was satisfactory.
                                                            Emission terts have  not been performed.   Some pump and
                                                            Instrument failures  have  occurred.
Jun- 75                                          100        Unit has been out of service for minor repairs throughout
July 75                                            0        July.
Aug. 75
Sept. 75                                          45        Unit operated at a 95 percent  S02 removal  efficiency during
Oct. 75                                          100        this period.  Gulf Power  Is  attempting to upgrade this value
                                                            to  a higher efficiency  level.   Waste  water discharge from
                                                            this unit still  a problem area.
Nov. 75                                          100        Outage time was  less than one  hour  during November operation
                                                            due to a broken  flue gas  blower  inlet vane and repair of  a
                                                            plnhole 1n the prescrubber FRP lining.
Dec- 75                                           98        Scrubber outages during December resulted from continuing
                                                            repairs to a plnhole in the  precrubber FRP lining.
   » 76                                           66        The scrubbing system was  in  service 450  hours during this
                                                            month.   Outage time  was caused mainly by repairs  to cracks  in
                                                            the oxidizing tower.
   . 76                                            0        System inoperative;  down  for repairs.
                                                                                                   PEDCo-ENVIRONMENTAL
                                                           74

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                   TABLE 3
PERFORMANCE DESCRIPTION FuK OPERATIONAL FGD SYSTEMS  03/76
 IDENTIFICATION NO.


 UTILITY NAME


 UNIT NAME

 UNIT LOCATION


 UNIT RATING

 FUEL CHARACTERISTICS


 FGD VENDOR


 PROCESS


 NEW OR RETROFIT


 START UP DATE

 FGD STATUS

 EFFICIENCY,
  PARTICULATES



  S02
  37

 KANSAS  CITY  POWER  & LIGHT


 HAWTHORN NO  3


 KANSAS  CITY  MISSOURI


  140  MW

 COAL    0.6-  3.0  PERCENT  SULFUR


 COMBUSTION ENGINEERING


 LIMESTONE INJECTION SWET SCRUB


 RETROFIT


 11/72


 OPERATIONAL



 99 PERCENT



 70 PERCENT
 WATER MAKE UP
 SLUUGE DISPOSAL
 UNIT COST
 OPERATIONAL
  EXPERIENCE
 UNSTABILIZED SLUUGE UISPOSED IN UNLINED POND


$1V/KW CAPITAL*2.S MILS/KWH OP


 REFER TO BACKGKOUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT.  THIS
 F&O SYSTEM HAS BEEN OPERATIONAL SINCE NOVEMBER 1972. BOTH MODULES WERE
 DOWN THE ENTIRE MONTH OF JANUARY BECAUSE OF FROZEN EQUIPMENT AND LINES,
 AND A MANPOWER SHORTAGE. OPERAblLITY FOR MODULES A AND B DURING THE MONTH
 OF FEBRUARY WAS 37 AND 1 PERCENT RESPECTIVELY.
                                                           75
                                                                                                       PEDCo-ENVIRONMENTAL

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                                                       BACKGROUND  INFORMATION
                                                                ON
                                                THE  HAWTHORN  POWER  STATION:  UNIT #3

      THE  HAWTHORN  POWER  STATION  IS  LOCATED  ON  THE NORTH  BANK OF THE MISSOURI RIVER IN EAST KANSAS CITY, MISSOURI.  THE
 PLANT HAS FIVE  ELECTRIC  GENERATING  UNITS  WITH  A TOTAL  RATED  CAPACITY OF 980 Ml/.  ONLY UNITS #3 AND #4 ARE RETROFITTED
 WITH  FGD  SYSTEMS.
      BOILER  #3  IS  A  DRY-BOTTOM PULVERIZED-COAL-FIRED UNIT. MANUFACTURED BY COMBUSTION ENGINEERING AND INSTALLED IN EARLY
 1950.   THE PLANT BURNS TWO  GRADES OF  COAL:  THE COAL WITH HIGHER ASH CONTENT TYPICALLY CONTAINS 14 PERCENT ASH AND 3
 PERCENT SULFUR, WITH A HEAT CONTENT OF  11,400  BTU/LB;  THE LOWER ASH COAL HAS 11 PERCENT ASH, 0.6 PERCENT SULFUR, AND
 A  HEAT  CONTENT  OF  9800 BTU/LB.
      THE  BOILER'S  FGD SYSTEM OPERATES ON  LIMESTONE  FURNACE INJECTION FOLLOWED BY A FLUE GAS WET-SCRUBBING SYSTEM IN
 WHICH BOTH THE  SOg AND THE  FURNACE CALCINED LIMESTONE  ARE SCRUBBED AND ALLOWED TO REACT IN A REACTION TANK.
      THE  FGD SYSTEM CONSISTS OF TWO IDENTICAL  MODULES, EACH  CAPABLE OF TREATING 500,000 ACFM OF FLUE GAS AT  300'F.
 BYPASSING OF THE MODULES IS POSSIBLE THROUGH A SYSTEM  OF DUCTWORK AND DAMPERS AROUND EACH MODULE.   EACH MODULE CONSISTS
 OF A  GLASS MARBLE  BED, A CHEVRON TYPE FIBER GLASS DEMISTER AND A FINNED TUBE REHEATER.   THE DEMISTER WASH SYSTEM USES
 A  SET OF  EIGHT WATER LANCES THAT TURN ON AUTOMATICALLY TO WASH MUD FROM THE DEMISTERS WHENEVER THE  DAMPERS CLOSE.
     THE  SPENT LIMESTONE SLURRY FROM THE MODULES IS DISCHARGED INTO A CLARIFIER TANK, AND THE  UNDERFLOW IS PUMPED.  UNSTA-
 BILIZED, TO A 160-ACRE UNLINED POND, WHICH IS ALSO USED FOR DISPOSAL OF FLY ASH FROM THE  OTHER BOILERS.
 PROBLEMS AND SOLUTIONS
     THE MAJOR PROBLEMS ENCOUNTERED WITH THE TWO FGD SYSTEMS  ON UNITS #3 AND #4 AT  THE  HAWTHORN POWER STATION  HAVE  BEEN
 IDENTICAL.
     MAINTENANCE OF SOLIDS IN  THE REACTION TANKS IN  SUSPENSION  WAS  DIFFICULT AND CREATED  BUILD UP OF  MUD IN  THE  CORNERS
OF THE REACTION TANK.  THE PROBLEM WAS SOLVED BY ROUNDING OF  THE BOTTOM CORNERS, INSTALLATION  OF FRESH  WATER FLUSHING
                                                                                                      PEDCo-ENVIKUWttltNTAL
                                                              76

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HAWTHORN UNIT #3 (continued)
NOZZLES ON EACH WALL AND INCREASING THE HORSEPOWER OF THE TANK MIXERS.
     SEDIMENT BUILD UP WAS EXPERIENCED IN THE DRAIN POTS HORIZONTAL HEADERS.   ALSC DISLOCATION OF  THE  MARBLE  BED  DRAIN
POT COVERS AND THE LOSS OF MARBLES WAS A FREQUENT PROBLEM WHICH WAS SOLVED BY INSTALLATION "OF  NEW  STAINLESS STEEL  DRAIN-
POTS WITH EXPANDED METAL COVERS AND MODIFYING THE DRAIN PIPING.  OTHER  MODIFICATIONS  INCLUDED  THE  INSTALLATION OF  A  NEW
DEM1STER WASH SYSTEM TO CONTROL DEMISTER PLUGGING. CHANGING THE FLUSHING  SEQUENCE  WITHIN  THE WATER SEAL  TO ELIMINATE
BYPASS SEAL PLUGGING.  AND REPLACEMENT OF SPRAY NOZZLES.   THESE MODIFICATIONS  WERE  COMPLETED BY FEBRUARY  1974.
                                                                                                        PEDCo-ENVIRONMENTAL
                                                             77

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                                                       Hawthorn  #3
Month
Jul. 75
Aug. 75

Sept. 75


Oct. 75
Jan. 76
Feb. 76
358
180
503
          Operating hours
          Module 3*Module  3B
247
117
148
                                          247
 81
145
                           FGD  OperabHlty  (»)
                          Module  A   Module JB
69
65
              37
                                                   42
23
81
Nov. 75
Dec. 75
0
0
0
0
0
0
0
0
0
0
               Comments
3A - leak In city water line.  Plugged duct to
I.D. form.   Couldn't open outlet damper from
scrubber.
Last marbles 1n bed and sustained broken spray
header.
l.ost I.D. fan for half of boiler.  Carryover of
July problems.
Outage due  to cleaning and mechanical  repairs.  The
pots, covers, and marbles In the marble bed of module
3B were  replaced during this period.
Module 3A outage due largely to replacement of a re-
cycle pump  motor.  Boiler operation hours low due
to a scheduled boiler overhaul.
Boiler and  scrubbers shutdown during  the report
period for  a scheduled turbine overhaul.  The system
1s scheduled to go back on-line in January 1976.
System was  down all month because of frozen equipment
and lines and a manpower shortage due to a boiler
and turbine overhaul on another unit at this station.
Scrubber outages resulted from plugging in the
scrubber bed, which resulted from converting the bed
spray system from under-bed to over-bed.
                                                                78
                                                                                                           PEDCo- ENVIRONMENTAL

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                   TABLE 3
PERFORMANCE: DESCRIPTION FOR OPERATIONAL FGO SYSTEMS  os/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING

 FUEL CHARACTERISTICS

 FGO VENDOR

 PROCESS

 NEW OR RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
  PARTICULATES
  38

 KANSAS CITY POWER & LIGHT

 HAWTHORN NO 4

 KANSAS CITY MISSOURI

  100 MW

 COAL   0.6- 3.0 PERCENT SULFUR

 COMbUSTION ENGINEERING

 LIMESTONE INJECTION ftWET SCRUB

 RETROFIT
 OPERATIONAL


 99 PERCENT
  802
 70 PERCENT
 WATER MAKE UP
 SLUDGE DISPOSAL
 UNSTABILIZED SLUDGE DISPOSED IN UNLINED POND
 UNIT COST
S19/KW CAPITAL*2.2 MILS/KWH OP
 OPERATIONAL
  EXPERIENCE
 KEFLK TU brtCKGKUuHU INFORMATION SECTION IN TABLE 3 OF  THIS REPORT.  FGD
 SYSTLM HAS bEEN IN OPERATION SINCE AUGUST 1972.  BOTH MODULES WERE  DOWN
 THE LNTIKE MONTH OF JANUARY BECAUSE OF FROZEN EQUIPMENT AND LINES,  AND A
 MANPOWER SHORTAGE. OPERA8ILITY FOR MODULES A AND b WAS U AND 78 PERCENT
 RESPECTIVELY.  MOuULE A WAS INOPERATIVE ALL OF FEBRUARY 3ECAUSE OF  THE
 CONTINUTATION  OF A PROBLEM WITH LOSS OF DRAFT THROUGH  THE
 CONNECTING DUCTWORK.
                                                                                                     PEDCo- ENVIRONMENT^
                                                               79

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                                                 BACKGROUND INFORMATION
                                                           ON
                                          THE  HAWTHORN POWER STATION:   UNIT #4
      THE  HAWTHORN  POWER  STATION  IS  LOCATED ON  THE  NORTH BANK OF THE MISSOURI  RIVER IN EAST KANSAS CITY,__
 MISSOURI.   THE  PLANT  HAS  FIVE  ELECTRIC  GENERATING UNITS WITH A TOTAL RATED CAPACITY OF 980 MW.  ONLY UNITS..
 *3  AND  #4  ARE  RETROFITTED  WITH  FGD SYSTEMS.
      BOILER  #4 IS  A  BOTTOM PULVERIZED-COAL-FIRED UNIT MANUFACTURED BY COMBUSTION ENGINEERING AND INSTALLED..
 IN  EARLY  1950.   THE  PLANT BURNS TWO GRADES OF COAL:   THE COAL WITH HIGHER ASH CONTENT TYPICALLY CONTAINS	
 14  PERCENT  ASH  AND 3 PERCENT SULFUR, WITH A HEAT CONTENT OF 11,400 BTU/LB: THE LOWER ASH COAL HAS.11 PERCENT.
 ASH,  0.6  PERCENT SULFUR,  AND A HEAT CONTENT OF 9800  BTU/LB.              		
      ORIGINALLY THE FGD SYSTEM OPERATED ON FURNACE INJECTION OF LIMESTONE FOLLOWED BY FLUE GAS WET-SCRUBBJNG_.
 SYSTEM IN WHICH BOTH THE SOg AND THE FURNACE CALCINED LIMESTONE ARE SCRUBBED AND ALLOWED TO REACT IN A   	
JEACTION TANK.   BECAUSE.OF FURNACE TUBES PLUGGING^WHICH WAS ATTRIBUTED TO. LIMESTONE.INJECTION^THE SYSTEM	
 WAS CONVERTED IN 1972 TO TAILEND INJECTION, IN WHICH LIMESTONE IS INJECTED INTO THE GAS DUCT BETWEEN THE 	 	
 AIR HEATER AND THE SCRUBBER VESSEL.                                                                       .— .	
      THE FGD SYSTEM CONSISTS OF UO IDENTICAL MODULES, EACH CAPABLE OF TREATING 500,000 ACFM OF FLUE GAS	
 AT 300°F.   BYPASSING OF THE MODULES IS POSSIBLE THROUGH A SYSTEM OF DUCTWORK AND DAMPERS AROUND EACH MODULE.__.	...
 EACH MODULE CONSISTS OF A GLASS MARBLE BED, A CHEVRON TYPE FIBER GLASS DEMISTER AND A FINNED TUBE REHEATER..		_..
      THE DEMISTER WASH SYSTEM USES A SET OF EIGHT WATER LANCES.THAT TURN ON AUTOMATICALLY..!?.WASH MUD
 FROM THE DEMISTERS WHENEVER THE DAMPERS CLOSE.                                            .	
      THE SPENT LIMESTONE SLURRY FROM ALL MODULES IS DISCHARGED INTO A CLARIFIER TANK, AND THE UNDERFLOW		  	
 IS PUMPED. UNSTABILJZED,, J[0_A_liqr.ACROM>II[Ep_PpHp,JIHICH_IjL*LSQ .USEp_F_pR_DJlPOSAL_JF.^l.y_.ASH. F_R_OM_THE.	
 OTHER BOILERS.
                              l^                              jrH|..AVAI.LABJLJIY_FAnLO.R_F.OR_J.HE JiYSTEMS	
                                                          	PEDCo--ENVIRONMENTAL
                                                           80~ ~

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HAWTHORN UNIT #4 (Continued)
HAS BEEN LOW (IN THE RANGE OF 30X TO 40*).   AVAILABILITY OF THE F6D SYSTEM HAS LAGGED BECAUSE  OF  THE  MANY  PROBLEMS ATTRIBUTED
TO DRY LIMESTONE INJECTION.
OPERATING HISTORY
     APART FROM THOSE ENTAILED IN SWITCHING OF UNIT #4 FROM FURNACE INJECTION TO TAIL GAS INJECTION,  THE MAJOR  PROBLEMS  EN-
COUNTERED WITH THE FGD SYSTEM ON BOILERS #3 AND #4 AT THE HAWTHORN POWER STATION HAVE BEEN IDENTICAL.
     MAINTENANCE OF SOLIDS IN THE REACTION TANKS IN SUSPENSION WAS DIFFICULT AND CREATED BUILD UP OF  MUD  IN  THE CORNERS  OF
THE REACTION TANK.  THE PROBLEM WAS SOLVED BY ROUNDING OF THE BOTTOM CORNERS, INSTALLATION OF  FRESH WATER  FLUSHING NOZZLES
ON EACH WALL, AND INCREASING THE HORSEPOWER OF THE TANK MIXERS.
     IN LATE 1972, BECAUSE OF BOILER TUBE PLUGGING, WHICH WAS ATTRIBUTED TO FURNACE-LIMESTONE  INJECTION,  THE UNIT WAS  CONVERTED
TO A TAILEND LIMESTONE INJECTION SYSTEM.  SEDIMENT BUILD UP WAS EXPERIENCED IN THE DRAIN POTS  HORIZONTAL  HEADERS.  ALSO,
DISLOCATION OF THE MARBLE  BED DRAIN POT COVERS AND THE LOSS OF MARBLES WAS A FREQUENT PROBLEM  WHICH WAS SOLVED  BY  INSTALLATION
OF NEW STAINLESS STEEL DRAINPOTS WITH EXPANDED METAL COVERS, AND MODIFYING THE POTS DRAIN PIPING.  OTHER  MODIFICATIONS INCLUDED
THE INSTALLATION OF A NEW  DEMISTER WASH SYSTEM TO CONTROL DEMISTER PLUGGAGE, CHANGING THE FLUSHING SEQUENCE  WITHIN THE WATER
SEAL TO ELIMINATE BYPASS SEAL PLUGGING. AND REPLACEMENT OF SPRAY NOZZLES.  THESE MODIFICATIONS WERE COMPLETED BY APRIL 1974.
                                                              81                                      pEDCo- ENVIRONMENTAL

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                                                       Hawthorn 04
Month
Jul. 75

Aug. 75
Boiler
  518
Operating hours
        Module 1A
           41
              168
Module 4B
   128

   212
FGD
Roffu
   8
? Derating (%)
e A  ModuTe B
       25
Sep. 75
  395
          206
   210
  52
                                                    53
Oct. 75
  721
          429
                                           656
                                          60
                                                91
     Comments
Marble bed plugging and strainer problems
S me for 4B
Last half of boiler due to No. 4B I.D. fan
outage.  Shutdown both FGD module to Insure
not losing the whole unit.
New chemistry - attempting to run at 100Z
blowdown and near 0 percent solids.  Emphasis
on participate control.  Maintaining pH at 5
without limestone Injection.
Scrubber modules were returned to service on
Sept. 21 after replacement of the original I.D.
fan on the module 4B side.
New process design - marbles removed from
scrubber bed of Module A and replaced with a
stainless steel perforated bed.   The marbles
were removed due to Increased operational
difficulties caused by their presence.  Per-
furmance was very good resulting in Increased
availability and continuation of high particu-
late removal efficiency (97 percent).
Minor problem encountered in a boiler restric-
tion on the module 4A side somewhere between the
economizer and the inlet draft ductwork.resulting
            PEDCo-ENVIRONMENTAL
                                                             82

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                                                                  Hawthorn #4

                Operating hours                         FGD Qperabllltv IZ)
 Month         Boiler     Module 1A      Module 4B      Module A  Module B                 Comments
                                                                            1n decrease of gas velocity.   New chemistry process
                                                                            modification of running @ 1002 blowdown and 0.055
                                                                            solids Is still 1n progress (Initiated late
                                                                            August).   S02 removal  efficiency In the 50 to 60
                                                                            percent range.  KCPSL  Is presently concentrating
                                                                            heavily on participate emission control.
Nov> 75         720          0             713             0      '   99     Module 4A was Inoperative during the report period
                                                                            due to a  loss of draft through the ductwork from
                                                                            the economizer to the  air preheater.  This resulted
                                                                            In frequent reheater plugging, extensive  outage
                                                                            time,  and finally resulting in the utility bringing
                                                                            the system down for the entire report period.
Dec. 75         640          0             103             0         16     A boiler  outage of approximately 5 days duration
                                                                            occurred  In December due to a scheduled overhaul.
Jan- 76           0          0               0             00     The system was down all month because of  frozen
                                                                            equipment and lines and lack  of manpower  due  to a
                                                                            boiler and turbine overhaul  on another unit at this
                                                                            station.
Feb. 76         579          0             450             0         78     Module 4A was inoperative the entire month due to
                                                                            continuation of problems concering the loss of draft
                                                                            through the ductwork from the economizer  to the air
                                                                            preheater.  Module 4B  experienced problems 1n the
                                                                            of marble bed plugging and the loss of a  recycle
                                                                            pump.           PEDCo-ENVIRONMENTAL


                                                                 83

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                   TABLE 3
PERFORMANCE DESCRIPTION FOK OPERATIONAL FGD SYSTEMS  03/76
 IDENTIFICATION NO.


 UTILITY NAME


 UNIT HAME

 UNIT LOCATION

 UNIT RATING
  39

 KANSAS CITY POWER & LIGHT


 LA CY&NE NO 1

 LA CYGNE KANSAS

  620 MW
 FUEL CHARACTERISTICS  COAL   5.2 PERCENT SULFUR
 FGD VENDOR

 PROCESS

 NEW OR RETROFIT

 START UP UATE

 FGD STATUS

 EFFICIENCY,
  PARTICIPATES
 BABCOCK & UILCOX

 LIMESTONE SCRUBBING

 NEW

  2/73

 OPERATIONAL


 98 PERCENT
  S02
 72 PERCENT
 WATEK  MAKE  UP
 SLUUGE  DISPOSAL
 UNSTABILIZED SLUDGE DISPOSED IN UNLINED POND
 UNIT  COST
$H3/KW CAPITAL
 OPERATIONAL
  EXPERIENCE
 KEFEN TO BACKGKOUNO INFORMATION SECTION IN TABLE 3 OF  THIS REPORT.  THIS
 FGD SYSTEM HAS BEEN OPERATIONAL SINCE FEB. 1973. THE ANNUAL AVERAGE
 AVAILABILITY FOR ALL 7 MODULES DURING 1975 WAS IN EXCESS OF 63  PERCENT
 (INCLUDING GENEKATOR REPAIR OUTAGE TIME).  THE UTILITY  IS CURRENTLY  PLAN-
 NING THE INSTALLATION OF AN ElbHTH MODULE, SCHEDULED TO  BE PLACED IN
 SERVICE SOMETIME DURING THE SUMMER OF 1977.
                                                           84
                                                                                                    PEDCO- ENVIRONMENTAL

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                                             BACKGROUND  INFORMATION
                                                      ON
                                               LA  CYGNE  UNIT  NO.  1

      THE  LA  CYGNE  POWER  STATION  OF  KANSAS  CITY POWER AND  LIGHT COMPANY  IS A NEW STATION.  THE UNIT BEGAN COMMERCIAL OPERATION
 ON  JUNE  1. 1973, AS  A  JOINT  PROJECT  OF  KANSAS GAS  AND ELECTRIC COMPANY AND KANSAS CITY POWER ft LIGHT COMPANY.  THE STATION IS
 LOCATED ABOUT  55 MILES SOUTH OF  KANSAS CITY, IN LINN COUNTY, KANSAS.
      THE  ELECTRIC  POWER  GENERATING  FACILITIES CONSIST OF  ONE 820-MW COAL-FIRED BASE-LOAD BOILER WITH ASSOCIATED STEAM TURBINES
 AND ELECTRIC GENERATORS.  THE PLANT ALSO HAS THREE OIL-FIRED BOILERS, UScD PRIMARILY FOR STARTUP OF THE LARGE UNIT.  THEIR
 COMBINED  CAPACITY  IS  EQUIVALENT  TO  28 MW.
      THE  BOILER  AT  LA CYGNE, WHICH WAS DESIGNED BY BABCOCK AND WILCOX,  IS A DRY-BOTTOM. PULVERIZED COAL-FIRED CYCLONE UNIT.   THE
 COAL  BURNED  IS LOW  GRADE, SUB-BITUMINOUS WITH AN AS-FIRED HEATING VALUE OF 9000 to 9700 BTU/LB AND ASH AND SULFUR CONTENTS OF
 25  PERCENT AND 5 PERCENT, RESPECTIVELY.  THE POLLUTION CONTROL EQUIPMENT ON THIS BOILER, WHICH CONSISTS OF SEVEN FLUE GAS
 DESULFURIZATION  MODULES, WAS ALSO BUILT BY BABCOCK AND WILCOX AS AN INTEGRAL PART OF THE POWER GENERATING FACILITIES.
 BYPASSING OF THE BOILER'S FLUE GAS AROUND THE FGD SYSTEM  IS NOT POSSIBLE.
 PROBLEMS AND SOLUTIONS     j
     THE FGD INSTALLATION OF THE LA CYGNE BOILER NO.  1  HAS BEEN PLAGUED WITH NUMEROUS PROBLEMS SINCE  THE FIRST  TRIAL  OPERATION
 OF THE BOILER ON DECEMBER 26,  1972.   SOME OF THESE PROBLEMS,  SUCH AS THE VIBRATIONS OF  THE  INDUCED-DRAFT FANS AND THEIR
 SENSITIVITY TO IMBALANCE. APPEARED EVEN BEFORE  THE BOILER WAS FIRED.
     AS THESE FABRICATION PROBLEMS WERE CORRECTED AND THE FGD SYSTEM WAS IN  OPERATION.  TWO  OTHER TYPES OF PROBLEMS  BEGAN  TO
APPEAR.  THE  FIRST  CATEGORY OF PROBLEMS IS ASSOCIATED WITH THE  WET LIMESTONE PROCESS AND IT  INCLUDES  PLUGGING OF  THE  DEMISTER
AND STRAINERS.  WEARING OF SPRAY  NOZZLES.  AND CORROSION OF REHEATER TUBES.   THE SECOND CATEGORY OF PROBLEMS  MAY  BE UNIQUE  TO  THE
LACYGNE INSTALLATION;  IT INCLUDES THE  EFFECT OF THE  SCRUBBED  FLY  ASH ON THE  VISCOSITY AND FLOW CHARACTERISTICS  OF THE  RECIR-
CULATED SLURRY. WHICH  RESTRICTED MOBILITY OF THE  BALLS  IN THE TCA TOWER.
                                                                                                    PEDCo-ENVIRONMENTAL
                                                            85

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LA CYGNE UNIT NO. 1
     IN ATTEMPTING TO SOLVE THESE PROBLEMS,  IT WAS  RECOGNIZED  THAT  THE  FLY  ASH  CONTENT  OF  THE  FLUE  GAS  (DUE TO  LACK  OF
PRIMARY PARTICULATE CONTROLS) IS IN LARGE PART RESPONSIBLE  FOR THE  PROBLEMS IN  BOTH  CATEGORIES.   SEVERAL  MODIFICATIONS  HAVE
BEEN MADE TO ALLEVIATE THESE MOUNTING MECHANICAL PROBLEMS.   ONE MAJOR CHANGE  IS THE  REPLACEMENT  OF  THE  ORIGINAL TURBULENT
CONTACT ABSORBER'S FLOATING BED WITH SIEVE TRAYS.   ALSO IN  ORDER TO REDUCE  THE  EROSIVE  EFFECT  OF THE  FLY  ASH  AND THE LARGE
SCALE PARTICLES. AND TO EXTEND THE LIFE OF THE LIMESTONE SLURRY SPRAY NOZ'LES ON THE VENTURI SCRUBBERS, A HYDROCLONE WAS
INSTALLED IN THE SLURRY RECIRCULATION LINE OF EACH  MODULE TO CENTRIFUGALS  SEPARATE  AND REMOVE THESE  PARTICLES  FROM  THE
SYSTEM.
     THE CORROSION PROBLEMS ASSOCIATED WITH THE CONDENSATION OF ACID VAPORS FROM THE GAS ON THE  REHEATER  TUBE BUNDLES WERE
BROUGHT UNDER CONTROL BY THE INJECTION OF SLIP STREAMS OF HOT AIR P\OH  THE  BOILER'S  COMBUSTION AIR  HEATER IN  THE PATH OF  THE
SCRUBBED FLUE GASES AT THE INLET TO THE REHEATER UNITS.  THIS PRACTICE  HAS  CAUSED A  REDUCTION  IN THE  MAXIMUM  GENERATING
CAPACITY OF THE  BOILER DUE TO THE LIMITED AVAILABLE AIR FOR COAL COMBUSTION.
     BECAUSE THE FGD SYSTEM  INCLUDES NO SPARE MODULES AND IT CANNOT BE  BYPASSED, OUTPUT OF THE BOILER IS  TOTALLY CONTROLLED
BY  THE  PERFORMANCE AND AVAILABILITY OF THE FGD MODULES.  PRESENT PROCEDURES CALL FOR CLEANING  ONE MODULE  EACH NIGHT  ON A
ROTATIONAL  SCHEDULE AND KEEPING ALL MODULES AVAILABLE DURING THE DAYTIME PEAK PERIODS.   CLEANOUTS REQUIRE 3 MEN FOR  A PERIOD OF
10  to  12 HOURS.  RECENT JMODIFICATIONS  BY THE  UTILITY ON THE SCRUBBER INSTALLATION HAVE RESULTED IN PLANS  FOR PROLONGED OP-
ERATIONAL PERIODS, WITH MODULES  STAYING ON-LINE CONTINUOUSLY  FOR PERIODS UP TO 3 WEEKS.
                                                                                                      PEDCo- ENVIRONMENTAL
                                                         86

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                   FGD SYSTEM AVAILABILITY
                     LA CYGNE UNIT NO. 1
Month Boiler
Jan.
Feb.
Mar.
Apr.
May.
June
Jul.
Aug.
Sep.
Oct.
Nov.
Dec.
Jan.
Feb.
Mar.
Apr.
May.
Jun.
Jul.
Aug.
Sepjt
74
74
74
74
74
. 74
74
74
74
74
74
74
75
75
75
75
75
75
75 614
75 630
-.75.
Percent AvallabllIty-by module
A
49
66

67
69
92
75
90
69
90
90
;
•

82

95
88
78
75
78
B
32
68

70
83
84
80
90
88
71
71



96

85
85
90
88
84
C
44
59

75
78
83
80
73
73
60
60



90

94
84
90
87
84
D E F
87 23 37
76 52 100
Boiler Shutdown
88 74 100
85 78 84
90 82 83
81 85 79
81 81 78
76 83 89
61 84 85
61 84 85
Boiler Shutdown
Boiler Shutdown
Boiler Shutdown
76 93 92
5 Days of Operation
90 90 89
85 84 86
84 85 87
78 92 85
G
81
65

88
80
87
77
99
86
84
84



96

83
89
85
83
85 79. 78 74
Average
50
69

80
80
86
80
85
81
76
76



90

89
86
86
84
80
                                                                     Comments
                                             M. dule A and D are used for research tests.
                                             One module is shut down each evening for cleaning.
                                              System  shutdown  Oct.  16,  1975  due  to
                                              generator  and  I.D.  air  fan  problems.
                                              System  remained  Inoperative  throughout  the
                                              duration of  the  month.
                                                             PEOCo-ENVIRONMENTAL
                             87

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                                                 FGD SYSTEM AVAILABILITY
                                                   LA CYGNE UNIT NO.  1
                             Percent Availability by module
Month     Boiler hrs.    A     B     C     D     E     F     G     Average    	Comments
Oct. 75           '      66    77    46    74     72    73    65       68       The availability figures  given for the months of
Nov. 75                 93    90    80    93     96    89    94       91       October and  November do  not Include the outage
Dec. 75                 91    87    81    85     87    89    8/4       86       time accumulated from October 16 to November 13.
                                                                              Boiler outages  of 80. 50  and 11  hrs., totaling
                                                                              141  hrs.,  occurred during the month of December.
Note:  The 1974 figures are based on actual  operating hours  of each  module  over  boiler  hours.   During  reduced  boiler  load  opera-
tion, some of these modules were not needed  and were shut down, although  they  were  available.   Actual  availability was  therefore
somewhat higher than some of these figures Indicate.  The 1975 figures  are  based on the hours  the  module was  in  service or
available for service divided by the total hours In the month.
                                                                                               PEDCo-ENVIRONMENTAL

                                                             88

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                   TABLE 3
PERFORMANCE DESCRIPTION FOK OPERATIONAL F6D SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING

 FUEL CHARACTERISTICS

 FGD VENDOR

 PROCESS

 NEW OR RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY!
  PARTICIPATES
 H2

KANSAS POWER £ LIGHT

LAWRENCE NO 4

LAURENCE KANSAS

 125 MW

COAL 0.5 PERCENT SULFUR

COMBUSTION ENGINEERING

LIMESTONE INJECTION ftWCT SCRUB

RETROFIT

12/68

OPERATIONAL


99 PERCENT
  S02
75 PERCENT
 WATEK MAKE UP
 SLUUGE DISPOSAL
UNSTABILIZED SLUUGE DISPOSED IN UNLINED POND
 UNIT COST
 OPERATIONAL
  EXPERIENCE
REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
FGD SYSTEM HAS BEEN OPERATIONAL SINCE DECEMbER 1968. THIS UNIT Ii> CUR-
RENTLY BURNING LOW SULFUR WYOMING COAL. THE OPERATION OF THE SCRUBBER HAS
bEEN MORE EFFICIENT AND ECONOMICAL FOR THIS COAL TYPE BECAUSE A LESSER
DEGREE OF S02 REMOVAL IS REQUIRED FOR COMPLIANCE. THE UTILITY PLANS TO
KEPLACE THIS SCRUBBING SYSTEM WITH A VENTRI-ROU AND SPRAY TOWER SCRUBBING
SYSTEM.
                                                           89
                                                                                                  PEDCo-ENVIRONMtNTAL

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                                            BACKGROUND INFORMATION
                                                      ON
                                     THE LAURENCE  POWER STATION:  UNIT  #4

     LAURENCE POUER STATION'S UNIT #4 IS A CYCLIC  LOAD STEAM  BOILER  EQUIPPED  TO  BURN  COAL.  NATURAL GAS  SUPPLEMENTED WITH OIL
OR COMBINATION OF THESE THREE FUELS.   THE BOILER UAS  BUILT  BY COMBUSTION ENGINEERING  AND  PLACED  IN SERVICE  IN  1959.  THE
GENERATING CAPACITY VARIES FROM 125 MU TO 143  MU UITH THE TYPE OF FUEL  BEING  BURNED.   RETROFITTING WITH AN  FGD SYSTEM  IN
NOVEMBER 1968 HAS INTRODUCED ADDITIONAL PRESSURE DROP IN  THE  FLUE GAS SYSTEM  AND FURTHER  REDUCED  THE BOILER  CAPACITY TO 115 MU.
     PRESENTLY THE COAL AT THE LAURENCE POUER  PLANT  HAS A HEATING VALUE OF  12,000 BTU/LB  AND AN ASH AND SULFUR CONTENT
OF 12.0 PERCENT AND 3.8 PERCENT.   THE COMPANY  IS IN  THE PROCESS OF SWITCHING  TO  WYOMING COAL WHICH CONTAINS  FROM 0.4 TO 0.8
PERCENT.  THE COMPANY IS IN THE PROCESS OF SWITCHING  TO WYOMING COAL WHICH  CONTAINS FROM  0.4 TO 0.8 PERCENT  SULFUR AND 10  PER-
CENT SULFUR ASH AND HAS A GROSS HEATING VALUE  OF 10,000 BTU/LB.
     THE BOILER HAS TWO MODULES,  EACH DESIGNED TO  HANDLE  ROUGHLY  150,000 SCFM OF FLUE GAS AND  CONSISTS  OF A  SINGLE STAGE MARBLE
BED SCRUBBER FOLLOWED BY A CHEVRON TYPE DEMISTER AND  AN INDIRECT  C.S. REHEATER.   ORIGINALLY, BOTH MODULES WERE FITTED  UITH
BY-PASS DUCTS AND HYDRAULIC SEAL  DAMPERS, BUT  LATER  THEY  WERE REMOVED BECAUSE OF EXTENSIVE  CORROSION AND PLUGGING.
     THE PLANT HAS LIMESTONE.STORING AND MILLING FACILITIES.   THE LIMESTONE USED CONTAINS 93 PERCENT CALCIUM CARBONATE,
6 PERCENT SILICA AND 1  PERCENT MAGNESIUM CARBONATE.
     THE SPENT SLURRY FROM THE UNIT, ALONG UITH THE  SLURRY  FROM UNIT #5, IS SENT TO THREE INTERCONNECTED UNLINED SLUDGE DISPOSAL
PONDS OF 16, 28, AND 4  ACRES.  KANSAS RIVER WATER  IS  ADDED  TO THE 4  ACRE POND.   THE CLARIFIED  WATER FROM THIS  POND IS  RECYCLED.
THE SLUDGE IS NOT TREATED FURTHER AND IS REPORTED  TO  SET AND  SOLIDIFY  IN THE  PONDS.
PROBLEMS AND SOLUTIONS
     THE FGD SYSTEM ON  BOILER #4  HAD MANY PROBLEMS,  SOME OF WHICH WERE: THE  BUILD UP AND PLUGGING OF THE INLET DUCT WHERE
HOT GASES ENTERED THE SCRUBBERS.  ERROSION OF SCRUBBERS UALLS, CORROSION OF  SCRUBBERS  INTERNALS,  BUILD UP ON  ID FANS ROTORS AND
PLUGGING OF DRAIN LINES. MARBLE BEDS AND DEMISTERS.   THE S02  REMOVAL WAS QUITE LOW DUE TO OVERBURNING OF THE LIMESTONE AND THE
                                                                                                    PEDCo-ENVIRONMENTAL
                                                             90

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LAURENCE UNIT #4 (continued)
DROPOUT OF THE LIME WITH THE ASH IN THE BOTTOM OF THE SCRUBBER.
     THE SCRUBBERS WERE MODIFIED IN 1969 BY RAISING THE DEMISTER AND ADDING SOOT BLOWERS IN THE INLET DUCT AND  REHEATER
TO ALLEVIATE PLUGGING PROBLEMS.  NEW SPRAY NOZZLES WERE ALSO INSTALLED.   REHEATER PLUGGING WAS ELIMINATED BY  REPLACING
COPPER REHEAT COILS WITH A CARBON STEEL UNIT HAVING WIDELY SPACED FINS.
     THE MAJOR MODIFICATIONS IN 1970 WERE SANDBLASTING AND COATING OF THE INTE'.IOR OF THE SCRUBBERS,  REPLACEMENT OF
ALL INTERNAL STEEL PIPES WITH PLASTIC AND FIBER GLASS, AND REPLACEMENT OF STAINLESS STEEL DEMISTERS WITH ONE  MADE OF  FIBER-
GLASS.  SINCE THE DEMISTER PLUGGING WAS NOT COMPLETELY REDUCED,  MANUAL WASHI !G BECAME NECESSARY EVERY NIGHT TO  MAINTAIN
THE OUTPUT REQUIRED OF THE UNIT.
     THE MODIFICATIONS IN THE SUMMER OF 1972 ON THE BOILER'S TWO FGD MOPOLES INCLUDED ENLARGEMENT OF  THE CRYSTALLIZATION
TANK, INSTALLATION OF NEW PLASTIC SPRAY NOZZLES, AND NEW SLURRY  PUMPS AND STRAINERS AND NEW MULTIPLE  MIXERS IN  THE TANK.
     THE OUTSTANDING PROBLEMS REMAINING ARE CORROSION, UNSATISFACTORY DAMPER OPERATION, EXAPNSION JOINT FAILURE, DEMISTER
FOULING, RAPID SLURRY PUMP WEAR, AND VALVE FAILURE.  THE OPERATION OF THE FGD SYSTEM SINCE THE FALL OF 1973 HAS BEEN
THE MOST SUCCESSFUL TO DATE.
     THE OPERATION OF THE SCRUBBER SYSTEM ON THE WYOMING COAL HAS PROVED TO BE MORE EFFICIENT AND ECONOMICAL  DUE TO  THE  LESSER
DEGREE OF S02 REMOVAL REQUIRED FOR COMPLIANCE.  THE SCRUBBER SYSTEM IS STILL OPERATING IN THE HIGH SOLIDS MODE  AS AN  S02  AND
PARTICULATE REMOVAL SYSTEM.  NORMAL MANUAL CLEANING REQUIREMENTS HAVE BEEN REDUCED TO 2-4 HOUR SHIFTS PER SCRUBBER PER WEEK.
     IN 1974 THIS UNIT WAS AVAILABLE FOR OPERATION 343 DAYS.  FIFTY PERCENT OF THE FUEL CONSUMED WAS  COAL, 2  PERCENT  FUEL OIL
AND 48 PERCENT NATURAL GAS.  DURING 1975 THIS UNIT WAS AVAILABLE FOR OPERATING 333 DAYS.  SIXTY-FOUR  PERCENT  OF THE  FUEL  CON-
SUMED WAS COAL, 3 PERCENT FUEL OIL AND 33 PERCENT NATURAL GAS.
     BY 1977, THE TWO FGD MODULES WILL BE REPLACED BY TWO NEW C.E. UNITS EACH CONSISTING OF A VENTRI-ROD UNIT AND A
SPRAY CHAMBER.  A NEW ELECTROSTATIC PRECIPITATOR IS ALSO TO BE INSTALLED.
                                                                                                     PEDCo- ENVIRONMENTAL
                                                             91

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Month
Jul. 75
Aug. 75

Sep. 75
Oct. 75
Nov. 75
Dec. 75
Jan. 76
Feb. 76
             Operating hours
Boiler      Module A    HoWle  B
  Lawrence 04
  Availability
Module A  Module B
           Not logged
           Not logged

           Not logged
           Not logged
           Not logged
           Not logged
           Not logged
           Not logged
Comments
                      The FGD system has  operated  satisfactorily  for  over  one
                      year.   Availability 1s  reported  to  be  adequate  for  the
                      operation  of this  particular station.   Station  load  is
                      reduced to 50 percent  every  night.   Therefore,  one  of
                      the modules can be  taken  off-line for  nightly cleaning
                      or repair.   Wyoming coal  (0.5 percent  sulfur) Is  being
                      burned  1n  this boiler.  Some natural gas  has been
                      burned  since June  20.
                      Burned  coal 100 percent of time.  Need  to shut  each
                      module  down once per week for Inspection  and cleanup.  No
                      boiler  outages In  July  and Aug.
                      Present  projections  by  the  utility  call  for  this unit  to
                      be available  330  days during  1976.   The  fuel  consumption
                      split  will  be 80  percent  coal,  12 percent  natural  gas
                      and 8  percent fuel oil.   This  scrubber system is being
                      replace^ by the utility with  a  venturl rod-section  fol-
                      lowed  by a  spray  tower.
                                                                                                    PEDCo-ENVlRONMENTAL
                                                            92

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS  03/76
 IDENTIFICATION NO.


 UTILITY NAME


 UNIT NAME


 UNIT LOCATION


 UNIT RATING


 FUEL CHARACTERISTICS


 FGD VENDOR


 PROCESS


 NEW OR RETROFIT


 START UP DATE


 FGD STATUS


 EFFICIENCY,
  PARTICULATES
 «f3


KANSAS POWER * LIGHT


LAWRENCE NO 5


LAURENCE KANSAS


 tOO MW


COAL 0.5 PERCENT SULFUR


COMBUSTION ENGINEERING


LIMESTONE INJECTION MET SCRUB


NEW


11/71


OPERATIONAL



99 PERCENT
  S02
65 PERCENT
 WATER MAKE UP
 SLUDGE DISPOSAL
UNSTABILIZE.D SLUDGE DISPOSED IN UNLINED POND
 UNIT COST
 OPERATIONAL
  EXPERIENCE
REFEK TO BACKGROUND INFORMATION SECTION IN TABLE 6 OF THIS REPORT. THIS
FGD SYSTEM HAS BEEN OPERATIONAL SINCE NOVEMBER 1971. THIS UNIT IS CUR-
RENTLY BURNING LOW SULFUR WYOMING COAL. THE OPERATION OF THE SCRUBBER HAS
BEEN MORE EFFICIENT AND ECONOMICAL FOR THIS COAL TYPE BECAUSE A LESSER
DEGREE OF S02 REMOVAL IS REQUIRED FOR COMPLIANCE. THE UTILITY PLANS TO
REPLACE THIS SCRUBBING SYSTEM WITH A VENTRI-ROU AND SPRAY TOWER SCRUBBING
SYSTEM.
                                                          93
                                                                                 PEDCo-ENVIRONMENT

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            	BACKGROUND INFORMATION
              	                                     ON
 			THE ..LAWRENCE .POWER_STA.TIJ)N_ UNIT_£5_	
      THE  UNIT #5 AT LAWRENCE POWER STATION IS A CYCLIC LOAD STEAM BOILER AND..IS  EQUIPPED  TO..BURN .COAL,  NATURAL_.GAS_
.SUPPLEMENTED WITH OIL OR COMBINATION OF THESE THREE FUELS.  THE BOILER WHICH WAS  PLACED  IN  SERVICE  IN 1971  HAS A RA.TED.
.CAPACITY OF 400 MW WHEN BURNING COAL AND NATURAL GAS.
      PRESENTLY THE COAL AT THE LAWRENCE POWER PLANT HAS A HEATING VALUE OF 12.000  BTU/LB AND  AN. ASH AND SULFUR CONTENJ_
 OF  12.0 PERCENT AND 3.8 PERCENT.  THE COMPANY IS IN THE PROCESS OF SWITCHING TO WYOMING  COAL  WHICH CONTAINS FROM O.4..
 TO  0.8 PERCENT SULFUR AND 10 PERCENT ASH AND HAS A GROSS HEATING VALUE OF 10,000  BTU/LB.
      THE BOILER'S FGD SYSTEM WAS BUILT BY COMBUSTION ENGINEERING AND PLACED  IN SERVICE  IN  1971.   THE BOILER HAS EIGHT
 IDENTICAL MODULES, EACH DESIGNED TO HANDLE ROUGHLY 150,000 SCFM OF  FLUE GAS AND  CONSISTS  OF  A  SINGLE STAGE MARBLE BED. 	
 SCRUBBER FOLLOWED BY A CHEVRON TYPE DEMISTER AND AN INDIRECT C.S. REHEATER.  ALL  THE  MODULES ARE FITTED WITH BY-PASS 		
 DUCTS AND HYDRAULIC SEAL DAMPERS.  THE PLANT HAS LIMESTONE STORING  AND MILLING FACILITIES.   THE  LIMESTONE USED_CONTA1NJS	
 93  PERCENT CALCIUM CARBONATE, 6 PERCENT SILICA AND 1 PERCENT MAGNESIUM CARBONATE.                                    	
      THE SPENT SLURRY FROM THE UNIT ALONG WITH THE SLURRY FROM UNIT #4 IS SENT TO  THREE  INTERCONNECTED UNLINED SLUDGE.	
 DISPOSAL PONDS OF 16, 28, AND 4 ACRES.  COOLING TOWER SLOWDOWN SUPPLIES MAKE-UP  WATER TO  THE POND. SYSTEM.... CL.ARIFIE.Q	
 POND WATER IS RECYCLED.  THE SLUDGE IS NOT TREATED FURTHER AND IS REPORTED TO SET  AND SOLIDIFY IN THE PONDS.       		
 PROBLEMS AND SOLUTIONS                                                                                               . .	
      THE FGD SYSTEM ON BOILER #5 HAD SIMILAR PROBLEMS TO THOSE OF THE  FGD SYSTEM  ON  BOILER  #4.   AMONG THOSE PROBLEMS.
 WERE:   LOCALIZED CORROSION IN SOME EQUIPMENT, UNSATISFACTORY DAMPER OPERATION,  DEMISTER  FOULING,  EXPANSION JOINTS FAILURE	
 AND RAPID WEAR OF SLURRY RECIRCULATING PUMPS.  IN ADDITION TO THE ABOVE,  BOILER #5  IS  STILL  PLAGUED WITH POOR FLUE  	
 6AA. DISTRIBUTION TO JHE EI_GHT FGD. MJ)DULE_S._ WHICH , UNLIKE. THE _MOD_ULES. .ON_ BOILER_#4_,_ ALL_ARE_J_NJ.E_RC.ONNECTED TJL.O.NE..C.OMMQM	
J5TACK.            	                                                              	   ....               .   	
	THE FGD SYSTEM_AyAILABILITY_IS_REPORTEp TO. .BE..AD.EQUATE FOR THE..OP.ERAT.ION. OF..THIS..PARI.ICULAR. STATION,  STATION-	
                                                                                                   PEDCo-ENVIRONMENTAL

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LAWRENCE UNIT #5 (continued)
.OAO IS REDUCED TO 50 PERCENT  EVERY  NIGHT.   THEREFORE  AS  MANY  AS  FOUR MODULES  CAN  BE  SHUT DOWN FOR CLEANING AND REPAIR EACH
EVENING.
     THE OPERATION OF THE  SCRUBBER SYSTEM ON WYOMING COAL HAS  PROVED TO  BE MORE  EFFICIENT AND ECONOMICAL BECAUSE OF THE LESSER
1EGREE OF S02 REMOVAL REQUIRED.
     IN 1974 THE UNIT WAS  AVAILABLE  FOR  OPERATION  338  DAYS, 66 PERCENT OF THE  FUEL CONSUMED WAS NATURAL GAS, 27 PERCENT COAL
*ND 6 PERCENT FUEL OIL.  DURING  1975 THE UNIT WAS  AVAILABLE FOR OPERATION 352  DAYS WITH THE FUEL CONSUMPTION SPLIT BEING 45
'ERCENT NATURAL GAS.  42  PERCENT  COAL AND 13  PERCENT FUEL  OIL.
                                                                                                      PEDCo-ENVIRONMENTAL

                                                                  95

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                                                       Lawrence *5
Months
Boiler
Operating hours
      FGD modul'es
                                                                      Comments
Jul. 75
Aug. 75
Sep. 75
Oct. 75

Nov. 75
Dec. 75
Jan. 76
Feb. 76
           Not logged

           Not logged


           Not logged

           Not logged
                         Wyoming coal  1s being burned In  this  unit.   The FGD  system availability  1s
                         reported to be adequate for the  operation of this  station.   Station  load
                         Is reduced to SOX every night so that as many as four modules  can  be shut
                         down for cleaning and repair each evening.
                         FGO units were off-line for most of June for major rebuilding  of spray system
                         In all  modules.  Some oil  was burned  1n order to bypass  FGD modules  during
                         repair.
                         Burning oil and gas  1n July and  August.  No  FGO operation.

                         Employed gas  and oil  on a  part-time basis during September and October.
                         Boiler  outage occurred due to Inspection and turbine repair.   Slurry tank  screen
                         also required replacement.
                         Present projections by the utility for this unit calls for 330 days  of  operation
                         in 1976 with the fuel consumption split being 60 percent coal, 25  percent fuel
                         oil and 15 percent natural gas.   This unit will  be converted to a  venturl-rod  and
                         spray tower system, like Unit 4.
                                                         96
                                                                                                         PEDCo-ENVIRONMENTAL

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                   TABLE 9
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS  03/76
IDENTIFICATION NO.


UTILITY NAME


UNIT NAME

UNIT LOCAUON


UNIT RATING

FUEL CHARACTERISTICS


FGD VENDOR


PROCESS


NEW OR RETROFIT


START UP DATE


FGD STATUS

EFFICIENCY,
 PARTICULATES
                       KENTUCKY UTILITIES


                       GREEN RIVER   UNITS 1 AND 2


                       CENTRAL CITY KENTUCKY


                         6t MW


                       COAL  3.8 PERCENT SULFUR


                       AMERICAN AIR FILTER


                       LIME SCRUBBING


                       RETROFIT


                        9/75


                       OPERATIONAL



                       99.7 PERCENT
  S02
                      60 PERCENT GUARANTEE
 WATER MAKE UP
 SLUUbE DISPOSAL
 UNIT COST
 OPERATIONAL
  EXPERIENCE
                      REFER TO BACKGNOUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT.  THIS
                      SYSTEM BECAME OPERATIONAL SEPTEMBER 13il975. OPERATION IS CURRENTLY
                      BEING CONDUCTED ON A HALF-LOAD BASIS BECAUSE OF A TURBINE REPAIR.
                      OPERATIONAL DATA AVAILABLE FOR THE PAST THREE MONTHS SHOWS THAT SYSTEM
                      AVAILABILITY. OPCRABILITY AND UTILIZATION HAVE AVERAGED 62, 39, AND 25
                      PERCENT RESPECTIVELY. SYSTEM OUTAGES HAVE RESULTED FROM MINOR MECHANICAL
                      STARTUP PROBLEMS AND COMPONENT CLEANOUTS. THE SYSTEM IS NOW BEING  PRE-
                      PARED FOR AN EXTENDED RELIABILITY TEST PROGRAM.
                                                           97
                                                                                                      PEDCo-ENVIRONMENTAL

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                                                 BACKGROUND  INFORMATION
                                                          ON
                                                GREEN  RIVER  POWER  STATION

     THE GREEN RIVER POWER STATION OF THE KENTUCKY  UTILITIES COMPANY  IS  SITUATED ON GREEN RIVER. NEAR CENTRAL CITY,  IN
MUHLENBERG COUNTY. KENTUCKY.
     THE STATION CONSISTS OF  TWO POWER GENERATING UNITS  AND  FOUR  BOILERS.   THE  POWER  GENERATORS AT THIS  STATION ARE  PEAK LOAD
UNITS.  THE BOILERS PROVIDING STEAM TO THE GENERATORS  ARE NORMALLY OPERATIONAL  5 DAYS PER WEEK. WITH ONE  OR MORE OF  THE BOILERS
OFTEN OPERATING AT REDUCED CAPACITY.
     THE S02 AND PARTICULATE  CONTROL SYSTEM FOR BOILERS  1. 2 and  3 CONSISTS OF  MECHANICAL COLLECTORS AND  A  TAIL END  LIME
SCRUBBING SYSTEM.
     THE LIME SCRUBBING SYSTEM CONTRACT WAS AWARDED TO AMERICAN AIR FILTER IN JUNE  1973." CONSTRUCTION  WAS  COMPLETED AND THE
SYSTEM STARTED UP SEPTEMBER 13, 1975.  THE SYSTEM WAS  DESIGNED TO TREAT  THE FLUE GAS  FROM BOILERS  1. 2,  AND 3,  WHICH HAS A
COMBINED RATED CAPACITY OF 64 MW. WITH THE FUEL BURNED BEING PRIMARILY HIGH SULFUR  (3.5 TO  4.0 PERCENT)  WESTERN KENTUCKY COAL.
     THE FGD SYSTEM CONSISTS OFIONE SCRUBBER MODULE TO HANDLE  A MAXIMUM  OF 360,000  ACFM AT  300°F.  THE  FLUE GAS IS  DRAWN FROM
THE EXISTING BREECHING THROUGH A GUILLOTINE TYPE ISOLATION DAMPER AND DUCT SYSTEM  TO  THE SCRUBBER  FAN.   THE GASES  THEN  FLOW  TH
THROUGH AN ADJUSTABLE THROAT VENTURI SCRUBBER AND FLOODED ELBOW,  WHICH WAS PROVIDED PRIMARILY FOR  PARTICULATE  REMOVAL.   SOg
REMOVAL OCCURS BY REACTION WITH THE LIME SLURRY  IN THE MOBILE  BED CONTACTOR WHICH  CONSISTS  OF TEN  DIFFERENT COMPARTMENTALIZED
SECTIONS WITH OVERHEAD SLURRY SPRAYS AND UNDER-BED DAMPERS TO  ACCOMODATE GAS VOLUME TURNDOWN REQUIREMENTS.
      THE SLURRY/RECYCLE  SYSTEM CONSISTS  OF A PARTITIONED  REACTANT TANK WITH RECYCLE PUMPS FOR SUPPLYING THE CONTACTOR AND
VENTURI. A LIME  SLURRY SLAKING AND  FEED  SYSTEM,  AND A BLEED SYSTEM DISCHARGING TO  A SETTLING POND  WITH RETURN  WATER FROM THE
POND  TO BE USED  AS  PRIMARY MAKE-UP.
                                                                                                      PEDCo-ENVIRONMENTAL
                                                               98

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                                                 FGD SYSTEM AVAILABILITY
                                                GREEN RIVER NOS. 1 AND 2
         Total           ,  Boiler            Module
Period  period (hrs.)  operation (hrs.)  availability (hrs.)
Dec. 75
744
Availability = 74%
Reliability » 78%
Operabllity = 65%
Utilization • 35%

Jan. 76     744
Availability « 42%
Reliability « 14%
Operability = 11%
Utilization = 9%

Feb.  26    696
Availability = 70%
Reliability = 42%
Operabllity - 42%
Utilization = 30%
398
550
f Hrs. module
  called upon
  to operate
     331
                 572
                    312
                   456
                 499
                    486
                   499
Hrs. module
operated                Comments
  257      System became operational  September
           13, 1975, on a half-load basis due
           to a turbine overhaul.   The half-load
           mode throughout of operation con-
           tinued the report period.   The utility
           began logging operating  data as of
           December 1975.
   64      System was down a total  of 432 hours
           In January.   Major problems were
           failure of the recycle  pumps and feed
           tank agitator, thaw out  and repairs to
           numerous frozen lines,  and shutdown
           of sump pumps.
  211      The system was inoperative a total of
           210 hours during the month of Feb-
           ruary.  Mechanical problems included
           repairs to tank agitators, recycle
           pumps, reactant pumps.   Clean out of
           reactant pumps, slurry  pumps, slake
           tanks and mix-hold tank  contributed
           accounted for the remaining outage
           lime.
                                                                                                           PEDCO-ENVIRONMENTAL
                                                              99

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING

 FUEL CHARACTERISTICS

 FGO VENDOR

 PROCESS

 NEW OK RETROFIT

 START UP UATE

 FGD STATUS

 EFFICIENCY,
  PARTICULATES


  S02


 WATER HAKE UP


 SLUDGE: DISPOSAL
  H5

 KEY WEST UTILITY BOARD

 STOCK ISLAND PLANT

 KLY WEST FLORIDA

   37 MW

 OIL    2.4 PERCENT SULFUR

 ZURN AIR SYSTEMS

 LIMESTONE SCRUBBING

 NEW

 10/72

 OPERATIONAL


 90 PERCENT


 85 PERCENT-ESTIMATED


 MAKE. UP RATE ESTIMATED 100 GPM
                                 UNLINED POND
 UNIT COST
 OPERATIONAL
  EXPERIENCE
S 21.b/KW CAPITAL COST


 REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT.  THIS
 FGD SYSTEM HAS BEEN OPERATIONAL SINCE OCTOBER 1972. THE FGD SYSTEM  HAS
 BEEN OUT OF SEKVICE SINCE JANUARY 26,1975. MODIFICATIONS AND REPAIRS ARE
 CURRENTLY IN PROGRESS. SYSTEM RESTART IS AT LEAST A MONTH AWAY.  CHECKOUT
 OF ALL SYSTEM MOTORS AND PUMPS MUST BE COMPLETED BEFORE STARTUP  CAN
 COMMENCE.
                                                            100
                                                                                                         PEDCo-ENVlHONMtrtlftt

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                                                 BACKGROUND  INFORMATION
                                                          ON
                                                   STOCK  ISLAND  PLANT
     THE UTILITY BOARD OF THE CITY OF KEY WEST OPERATES  AN  OIL-FIRED  37  MW  POWER  PLANT  ON  STOCK  ISLAND, ADJACENT TO THE ISLAND
CITY OF KEY WEST.   THIS STEAM GENERATOR BURNS A HIGH SULFUR FUEL  OIL  (2.4  - 2.75X SULFUR)  GENERATING  210,000 CFM OF FLUE
GAS AT 390»F.  TO REMOVE THE SULFUR DIOXIDE FROM THE FLUE  GAS  A SCRUBBING  SYSTEM, CONSISTING  OF  TWO MODULES, HAS BEEN
DESIGNED BY ZURN AIR SYSTEMS AND EMPLOYS PULVERIZED CORAL  AND  SEAWATER.  THE CORAL IS  INITIALLY  GROUND TO  A FINE POWDER IN A
HAMMER-MILL CRUSHER AND THEN MIXED WITH SEAWATER TO FORM A DILUTE SLURRY AND TRANSFERRED TO THE  SCRUBBING  SYSTEM WHERE SULFUR .
DIOXIDE IS ABSORBED.  THE CLEANED GAS IS DISCHARGED TO ATMOSPHERE AND THE  SPENT SLURRY  IS  PUMPED TO A SETTLING  POND WHERE
THE SOLIDS SETTLE OUT.  THE CLARIFIED SEAWATER IS DISCHARGED INTO THE GULF.
     THE TWO SCRUBBER MODULES ARE DESIGNED TO HANDLE A COMBINED TOTAL OF 126,950 CFM AT 150'F.   THE FLUE  GASES  FROM THE BOILER
ARE DRAWN THROUGH THE INDUCED DRAFT FAN AND FORCED EITHER THROUGH THE BYPASS DUCT OR THROUGH  ONE OR BOTH  SCRUBBERS VIA THREE
SETS OF DAMPERS BETWEEN THE INDUCED DRAFT FAN AND THE STACK.  PRIOR TO ENTERING THE SCRUBBING SYSTEM  THE  GAS  IS COOLED FROM
360-F TO 160-F BY SEAWATER SPRAYS.  THIS INSURES PROTECTION OF THE FIBERGLASS COMPONENTS OF  THE  SCRUBBER  MODULES.  A  PRESSURE
DROP OF 12 TO 14" WATER GAUGE IS THE NORMAL OPERATING RANGE FOR THE SCRUBBERS.
     THE FGD SYSTEM WAS PLACED  IN OPERATION DURING OCTOBER, 1972.  THE SYSTEM WAS SHUT DOWN  ON JAN.  28,  1975  FOR REPAIR OF
THE BOILER FOUNDATION AND DUCTWORK BAFFLES.  SOME OTHER IMPORTANT MODIFICATIONS TO BE COMPLETED  ARE:   REPLACING SPRAY TREES
AND OTHER STAINLESS STEEL PARTS WITH MONEL;  MODIFICATION AND SEALING OF INLET DAMPERS; INDUCED  DRAFT FAN REPAIRS;  REPAIR OF
HOLES  IN HOPPER WALL  AND DUCT FLOOR.
                                                               101

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                                                      Stock Island
                    Operating hours          FGD system                               rnmnf»nt<
Month       Boner    	FfiD system       Availability   _	Conintents
                                                            FGD system was shut down on Jan.  28, 1975 due to ductwork baffle
                                                            damage.   Spray trees and other stainless steel parts have been
                                                            replaced with Monel.
J(jl  ?5                          00          FGO system Is still out of service, but reportedly will be
Au   75                          00          restarted In early October.  Boiler has been down since August
                                                            30 for I.D. fan repairs.
s    75                          00          FGD system 1s still out of service.  Date of system restart 1s
Qct> 75                          00          Indefinite at the present time.
Moy  ?5                          00          FGD system is still out of service.  The utility  Is in the process
Dec  75                          0               0          of replacing  the dampers and various system parts.  Date of system
                                                            restart  is still Indefinite.
Jan  76                          00          Repairs  to outlet damper have  been  completed.   All  the holes  in the
Feb  ?6                          00          hopper wall and ductwork have  been  patched.   New  spray trees  have
                                                            been  installed.  The utility  1s  still  in the  process of  repairing
                                                            the  inlet  damper.   The  system  will  not restart  for  at  least another
                                                            month pending checkout  of  all  pumps and motors.
                                                                                                      PEOCo-ENVIRONMENTAL

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING

 FUEL CHARACTERISTICS

 FGD VENDOR

 PROCESS

 NEW OK RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
  PARTICULATES


  S02


 WATER MAKE UP


 SLUDGE DISPOSAL


 UNIT COST
  OPERATIONAL
   EXPERIENCE
  53

 LOUISVILLE GAS  &  ELECTRIC

 PADDYS  RUN NO 6

 LOUISVILLE KENTUCKY

   65  MW

 COAL  3.5-4.0 PERCENT  SULFUR

 COMBUSTION ENGINEERING

 LIME  SCRUBBING

 RETROFIT

  t/73

 OPERATIONAL


 99.6  PERCENT


 90 PERCENT RANGE


 33 JGAL/LB MOLE  S02 REMOVED


 UNSTABILIZEO SLUDGE DISPOSED  IN UNLINED POND
S57/KW CAPITAL
                              &53/KM - 2.5 MILLS/KWH
 REFEK TO BACKGROUND INFORMATION SECTION IN TAbLfc. 3 OF THIS REPORT. THIS
 FGU SYSTEM HAS BEEN OPERATIONAL SINCE APRIL 1973. OPERABlLlTY WAS 100
 PERCENT IN JANUARY. S02 REMOVAL EFFICIENCY WAS 99 PERCENT DURING THIS
 OPt-KATING PERIOD. THL SYSTEM WAS SHUTDOWN IN EARLY FEBRUARY IN PREPARA-
 TION FOR THE EPA SCKUbBEH AND SLUDGE STUDY WHICH MAY COMMENCE IN JUNE OR
 JULY OF 1976. THE SCRUBBER WILL NOT BE OPERATED UNTIL THIS TIME UNLESS
 THE NEED ARISESIPEAK LOAD DEMAND).
                                                           103
                                                                                                        PEDCO- ENVIRONMENTAL

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                                             BACKGROUND  INFORMATION
                                                      ON
                                         THE  PADDY'S RUN POWER STATION
      PADDY'S  RUN ..POWERI  STATION  IS  LOCATED  IN  LOUISVILLE, KENTUCKY.  THE PLANT HAS SIX ELECTRIC POWER
.GENERATING  UNITS  WITH A TOTAL RATED  CAPACITY  OF 320 MW.  UNIT NO. 6 IS RETROFITTED WITH A CARBIDE LIME_
 BASE  FGD  SYSTEM.
      UNIT N0._6  IS A PEAK  LOAD  COAL-FIRED  BOILER.  THE BOILER WAS MANUFACTURED BY FOSTER WHEELER .AND.
 WAS  INSTALLED IN  1950.   IN  1973, THE  BOILER BURNED COAL WITH A GROSS HEATING VALUE OF 11,500 BFU/LB
 AND  AN  AVERAGE SULFUR AND  ASH CONTENT OF 3.7  PERCENT AND 13 PERCENT, RESPECTIVELY.
      THE  FGD  SYSTEM CONSISTS OF TWO  MODULES.   EACH HANDLES 175,000 ACFM OF 350»F FLUE GAS...EACH MODULE
 IS MADE UP  OF TWO STAGES OF 3 INCH MARBLE  BEDS FOLLOWED BY TWO STAGE CHEVRON TYPE DEMISTER.  THE GAS
 IS REHEATED BY DIRECT COMBUSTION OF  NATURAL GAS.  SOg REMOVAL EFFICIENCY IS REPORTED TO BE 80 PERCENT.
      THE  LIME USED CONTAINS 90  TO  92.0 PERCENT CALCIUM HYDROXIDE, 2.0 TO 2.5 PERCENT SILICA, 3.0 JO
                         i
 8.0  PERCENT CALCIUM CARBONATE,  AND 0.1  PERCENT MAGNESIUM OXIDE.
      THE  UNIT OPERATES  ON  A CLOSED LOOP MODE:  THE SOg IS ABSORBED IN THE TOWER'S MARBLE BED BY A SLURRY
 OF CALCIUM  SULFITE TO FORM  A MIXTURE  OF CALCIUM SULFITE/BISULFITE .  THE TOWER'S EFFLUENT IS CONVERTED
 IN THE  REACTION  TANK TO CALCIUM SULFITE BY THE ADDITION OF CALCIUM HYDROXIDE.  ONE-HALF OF THE REACTION
 TANK  EFFLUENT IS  RETURNED  TO THE SOg  TOWERS WHILE THE OTHER HALF  IS FED TO A CLARIFIER TANK.  THE CALCIUM.
_SULFITE CRYSTALS  PRECIPITATE WITH  THE AID  OF  A FLOCCULANT WHICH  IS ADDED AT THE RATE OF 4-7 PPM.  THE
 OVERFLOW  IS RETURNED TO THE REACTION  TANK  WHILE THE UNDERFLOW CONTAINING 22 TO 24 PERCENT SOLIDS IS
 STABILIZED  BY MIXING IT WITHJ.IME.   ABOUT  60  TO 100 POUNDS OF LIME ARE USED PER TON OF DRY SOLIDS_OF
 SLUDGE.  THE  FIXED SLUDGE  IS TRANSPORTED BY TRUCKS TO A 10-ACRE  OFF-SITE DUMP FOR USE AS LANDFILL.
                                                                                                    PEDCo-ENVJKONMtNTAL
                                                          MM-

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PADDY'S RUN (continued)

PROBLEMS AND SOLUTIONS
     DURING THE INITIAL 45 DAYS OF OPERATION ONLY ONE ABSORBER WAS PLACED IN SERVICE TO OBSERVE  THE  EQUIPMENT  AND  TO
DETERMINE THE MODIFICATIONS NEEDED FOR THE SYSTEM.  BEGINNING MAY 19,  1974.  THE SYSTEM WAS SHUT  DOWN FOR  A  MONTH TO
MAKE A NUMBER OF MODIFICATIONS. THE MOST SIGNIFICANT BEING THE INSTALLATION  OF EQUIPMENT FOR INJECTING  A  FLOCCULATING
AGENT INTO THE CLARIFIER TANK.   DURING THE PERIOD FROM JUNE 19 TO JULY 11. THE INCONSISTENT SIZING OF RECEIVED SLURRY
ADDITIVE MATERIAL CAUSED AN UPSET IN THE ADDITIVE CONTROL VALVES AND UNDUE PLUGGING OF SLURRY LINE STRAINERS.   THIS
PROBLEM WAS CORRECTED WITH THE  INSTALLATION OF A DISINTEGRATOR IN THE  SLURRY ADDITIVE SYSTEM. DURING AUGUST 19 TO
SEPTEMBER 5. THE UNIT WAS SHUT  DOWN TO ENLARGE THE CLARIFIER'S OVERFLOW SYSTEM.  OTHER OPERATIONAL-MODIFICATIONS-MADE WERE
LOWERING OF THE SLURRY. pH TO REMOVE SULFITE SCALING FORMED ON THE UPPER BED  PERFORATED SUPPORT PLATE AND  ON THE MARBLES.
     THE OPERABILITY FACTORS FOR. EACH MODULE ARE PRESENTED IN THE FOLLOWING  TABLE.
                                                                                                 PEDCo-ENVIRONMENTAL
                                                             105

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Month
April 73
May 73
June 73
July 73
Aug. 73
 Sept.  73
               OPERABILITY (%)
            Nodule A  Module B
              18
              11
              0.1
              21
              53
               85
65
21
64
                         72
FGD SYSTEM AVAILABILITY
PADDY'S RUN UNIT NO.  6

                           COMMENTS

  During this month,  only one module was operated at a time with frequent
  shutdowns for Inspection of equipment and minor repairs.
  Mode of operation In April  continued through May 19th., when the unit was
  shutdown to carryout a number of modifications.  The most significant
  modification was the installation of equipment for Injection of a
    "~                                                             s
  flocculating agent Into the clarifier tank.
  From June 19th to July llth, the operation was Intermittent due to
  mechanical problems with the slurry pumps.
  During a scheduled outage from July 12th through August 1st, several
  repairs were made to the lime slurry makeup system and disintegrator unit
  was  Installed in order to alleviate plugging problems in the strainers and
  the  slurry control valves.
  Between August 2nd and August 18th, the operation was continuous except
  for  brief  shutdown due to boiler related problem.  During the period
  between August 19th  and September 5th, the system was shut down to replace
  the  clarifler's  underflow line with one of larger diameter and to Install
  additional pump  capacity in  the  clarlfier's overflow system.
  The  unit  operated continuou-ly between September 6th and September 20th
  except  for 7  hr.  shutdown  to repair  a marble  bed support plate.  The  unit
  was  shutdown  during  the remaining days of the  month due  to trouble in  the
   boiler's  turbine generator.
                                                                                           PEDCo- ENVIRONMENTAL
                                                             106

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                                           PADDY'S RUN UNIT NO. 6 (continued)
         OPERABILITY (%)
Month   Module A Module B
Oct. 73
Nov. 73
Dec. 73
Jan. 74
through
Jun. 74
Jul. 74
Aug. 74
Sep. 74
Oct. 74
Nov. 74
through
Aug. 75
Sep. 75
Oct. 75
49
35
44
0


51
50
0
100
0


100
100
94
100
78
0


81
77
0
100
0


100
100
Nov.  75  100    100
Dec.  75   90     90
                              COMMENTS
The F6D system was In service through December 20th. 1973 after which the
boiler (and the scrubbers) were shutdown due to "no demand" from this
peaking load boiler.
Boiler 1s down because of "no demand"
                                           Boiler and FGD system resumed operation on July 10. 1974.
                                           Unit has been on and off frequently due to fluctuation In power demand.
                                           Boiler Is down because of "no demand".
                                           Boiler turned on specifically to perform limestone test runs on FGD system.
                                           Boiler 1s down because of "no demand"
Boiler and FGD system operational all of September and first two weeks 1n
October.  System outage during the last two weeks of October due primarily
to breeching 1n the boiler section.  Operability  for both modules during
the operational period was 100% (Based upon LG&E's Peak Load Determination).
SOg removal was reported to be in excess of 98%.
Boiler and scrubber system ran most of the report period on a Monday through
Friday basis.  Two minor outages occurred In December due to the malfunction  and
repair of the dual strainer switch shaft In the bottom of the scrubber module.
                                                                                                          PEDCo-ENVlRONMtNlrtl
                                                               107

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                                   PADDY'S RUN UNIT NO. 6 (continued)
 OPERABILITY (X)
Nodule A Module B
Month
Jan. 76  100    100
Feb. 76    0      0
                                                                               COMMENTS
                                     S02 removal  efficiency was  reported  to  be  99% during  the  month  of  January.   The
                                     system was shutdown In early February  In preparation  for  the  EPA scrubber/sludge
                                     study which  should  commence 1n  June  or  July  of this year.   The  scrubber  will
                                     not be operated  until  the  Initiation of the  study program unless the  peaking  load
                                     boiler Is  required  for power demands.   Some  general highlights  of  the scrubber/
                                     sludge study program are:
                                          0    6  month duration.
                                          0    1  scheduled  shutdown  for test modlf1ca1tons.
                                          0    Scrubber  will  run on  carbide  lime  and commercial  lime.
                                          0    Determination  of  minimum retention  times.
                                          •    Deliberate high chloride concentration operation.
                                          0    MgO Innoculatlon.
                                          8    Extensive sludge  study:  Fixation,  leachates, seasonal variations.
                            Note:   Since Paddy's  Run  No.  6  Is a  peak load boiler,  there were several
                                   occasions  1n July  and August  1974 when the boiler operated  for
                                   less  than  a  day.   During these  short boiler runs, the FGD
                                   system  was not turned on and  was  bypassed although 1t was avail-
                                   able.
                                                                                              PEDCo-ENVIRONMENTAL
                                                       108

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                   TABLE 3
PERFORMANCE DESCRIPTION FOK OPERATIONAL FGD SYSTEMS  03/76
 IDENTIFICATION NO.
 UTILITY NAME
 UNIT NAME
 UNIT LOCATION
 UNIT RATING
 FUEL CHARACTERISTICS
 F6D VENDOR
 PROCESS
 NEW OR RETROFIT
 START UP DATE
 F6D STATUS
 EFFICIENCY,
  PARTICULATES

  S02
 WATER HAKE UP

 SLUDGE DISPOSAL
  55
 MONTANA POWER CO.
 COLSTRIP NO 1
 COLSTRIP MONTANA
  360 MW
 COAL   0.8 PERCENT SULFUR
 COMBUSTION EQUIP.  ASSOCIATES
 LIME SCRUBBING
 NEW
 10/75
 OPERATIONAL
 UNIT COST
 OPERATIONAL
  EXPERIENCE
CAPITAL S50/KW

 CONSTRUCTION MAS COMPLETED BEHIND SCHEDULE. THE F6D SYSTEM STARTED UP AND
 PROCEEliLD THROUGH A SHAKEDOWN AND DEBUGGING OPERATION PHASE. THIS UNIT
 HAS COMMENCED FULL COMMERCIAL OPERATION AND IS CURRENTLY OPERATING AT
 FULL LOAD CAPACITY. OPERATING DATA ACCUMULATED TO DATE IS IN THE PROCESS
 OF BEING EVALUATED BY THE UTILITY FOR PRESENTATION TO STATE REGULATORY
 AGENCIES.
                                                           109
                                                                                                       PEDCo-ENVIRONMENTAL

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL F6D SYSTEMS  03/76
 IDENTIFICATION NO.
 UTILITY NAME
 UNIT NAME
 UNIT LOCATION
 UNIT RATING
 FUEL CHARACTERISTICS
 F6D VENDOR
 PROCESS
 NEW OK RETROFIT
 START UP DATE
 F6D STATUS
 EFFICIENCY*
  PARTICULATES
  63
 NEVADA POWER
 REID GAHDNER NO 1
 HOftPA NEVADA
  125 MW
 COAL   0.5- 1.0 PERCENT SULFUR
 COMBUSTION EQUIP. ASSOCIATES
 SODIUM CARBONATE SCRUBBING
 RETROFIT
  <*/7<*
 OPERATIONAL

 99 PERCENT
  S02
 85 PERCENT
 WATER MAKE UP
 SLUDGE DISPOSAL
 UNIT COST
 OPERATIONAL
  EXPERIENCE
 190 jGPM
SHt/KU CAPITAL (197H DOLLARS)  $600.000 ANNUAL COST
 REFER TO BACKGROUND INFORMATION SECTION IN TABLL 3 OF  THIS REPORT.   THIS
 FGD SYSTEM HAS BcEN OPERATIONAL SINCE APRIL 1971. THIS SYSTEM WAS ON-LINE
 Ittb hRS. IN JANUARY. WHICH EQUATES INTO A 29 PERCENT OPERABILITY  FACTOR.
 THREE FORCED SCRUBBER OUTAGES OCCURRED DURING THIS PERIOD DUE TO  REHEATER
 STEAM LEAKSt A VENTURI STRAINER COLLAPSE AND A FROZEN  CARBONATE LINE.
 TOTAL OPERATING TIME LOGGED BY THIS SCRUBBING SYSTEM TO DATE IS
 HRS.
                                                           no
                                                                                                   PEDCo-ENVIRONMENTAL

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                                            BACKGROUND INFORMATION
                                                     ON
                                            REID GARDNER UNIT NO.  1

     THE REID GARDNER POWER STATION IS LOCATED NEAR MOAPA,  NEVADA, ABOUT 50 MILES  NORTH  OF  LAS  VEGAS.  AT
PRESENT THE STATION HAS TWO ELECTRIC POWER GENERATING UNITS,  (REID GARDNER 1  AND 2)  EACH RATED  AT  125  MW.
BOTH UNITS ARE RETROFITTED WITH SODIUM CARBONATE BASED FLUE GAS DESULFURIZATION SYSTEMS. THE COAL  BURNED
AT THE PLANT HAS AN AVERAGE GROSS HEATING VALUE OF 12,450 BTU/LB,  AND ASH AND SULFUR CONTENTS OF 8  AND
0.5 PERCENT RESPECTIVELY.
     THE FGD SYSTEM ON REID GARDNER 1  WAS MANUFACTURED BY COMBUSTION EQUIPMENT ASSOCIATES AND PLACED
IN OPERATION DURING APRIL, 1974.  THE DESIGN OF THIS SYSTEM WAS BASED ON DATA GATHERED FROM THE OPERATION
OF AN 8000 ACFM PILOT PLANT WHICH OPERATED AT THE REID GARDNER POWER STATION DURING  1971 AND 1972.
     THE FGD SYSTEM CONSISTS OF A SINGLE MODULE, DESIGNED TO HANDLE 473,000 ACFM OF  GAS  AT  350'F.   EACH
MODULE IS MADE UP OF A TWIN VARIABLE THROAT VENTURI SCRUBBER FOLLOWED BY A SINGLE  STAGE  WASH TRAY.
BYPASSING OF EACH MODULE IS POSSIBLE THROUGH A GUILLOTINE TYPE BYPASS VALVE.  THE  PLANT  HAS A COMMON
TRONA (SODIUM CARBONATE ORE) STORAGE AND SAND REMOVAL PLANT WHICH SERVES BOTH FGD  MODULES ON REID  GARDNER
1 AND 2.  S02 REMOVAL EFFICIENCY IS REPORTED TO BE 85 PERCENT.
     IN THIS SODIUM CARBONATE PROCESS, THE HOT FLUE GAS FROM THE BOILER PASSES FIRST THROUGH AN EXISTING
MECHANICAL COLLECTOR  (MULTICYCLONE) WHERE ABOUT 75 PERCENT OF THE FLY ASH IS REMOVED.  ITS  PRESSURE IS
THEN BOOSTED BY AN I.D.  FAN BEFORE  IT SPLITS INTO TWO STREAMS AS  IT ENTERS THE TWIN THROAT VENTURI
SCRUBBER.  HERE THE HOT  FLUE GAS IS QUENCHED BY A SHOWER OF CIRCULATED SODIUM BASE LIQUOR.   THE GAS THEN
ENTERS THE WASH TRAY  AND BUBBLES THROUGH THE WATER ON THE  SIEVE TRAY.  THE SCRUBBER GAS WHICH IS  ESSENTIALLY
FREE OF  FLY ASH AND SULFUR DIOXIDE, PASSES THROUGH THE  RADIAL VANE MIST ELIMINATOR WHERE THE REMAINING
LIQUID  DROPLETS CARRIED  OVER WITH  THE GAS ARE TRAPPED AND  REMOVED.
     THE  EFFLUENT  FROM THE FGD  SYSTEM IS MADE UP  OF  TWO SOURCES:  THE SLIP STREAM OF SPENT LIQUOR DISCHARGED
 FROM THE  RECIRCULATION TANK, AND THE ALKALINE CLARIFIER UNDERFLOW WHICH SERVES TO NEUTRALIZE THE pH OF
THE COMBINED  LIQUOR  BEFORE  IT  IS DISCHARGED  TO  THE SLUDGE  SETTLING  PONDS.  THERE ARE TWO SLUDGE SETTLING

                                                                                      PEDCo-ENVIRONMENTAL

                                                     111

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 REID  GARDNER  UNIT  1  (CONTINUED)
 PONDS.  THE  SPENT LIQUOR  IS  PUMPED ONE OF THEM AT A TIME.  THE OVERFLOW FROM THIS POND IS PUMPED TO A
 LARGER  45 ACRE  POND  WHERE THE  BRINE  IS  EVAPORATED.  THE FGD SYSTEM OPERATES ON AN OPEN WATER LOOP WITH NO
 LIQUOR  RECYCLED TO THE MODULES FROM  THE PONDS.
'PROBLEMS AND  SOLUTIONS
      THE MAJOR  PROBLEM IN THE  OPERATION OF THE  FGD MODULES, HAS BEEN AND STILL IS THE LACK OF AN ADEQUATE
 SUPPLY  OF TRONA (SODIUM  CARBONATE ORE).  IN  ORDER TO SOLVE THIS PROBLEM, SODIUM CARBONATE BRINE HAS BEEN
 USED  TO SUPPLEMENT TRONA.   THE SYSTEM HAD THE USUAL START-UP PROBLEMS SUCH AS RUBBER LINERS ON RECIRCULATION
 LINES GETTING LOOSE  DUE  TO  POOR FABRICATION. FREEZE UP  OF  INSTRUMENTS AND ASH PLUGGING IN_CONTROL VALVE
 BYPASS  LINES.  OTHER MINOR  PROBLEMS  WERE LEAKAGE  IN THE MECHANICAL SEALS OF THE RECIRCULATIOK PUMPS.
 ALSO  MECHANICAL FAILURE  PROBLEMS WERE EXPERIENC£D WITH  THE GUILLOTINE TYPE BYPASS DAMPERS, WHICH WERE
 LATER CORRECTED WITH UPGRADED  REPLACEMENT PARTS.
      AS EXPECTED,  THIS SODIUM  BASED  FGD SYSTEM  HAS NOT  EXPERIENCED SUCH PROBLEMS AS EQUIPMENT SCALING.
 DEMISTER PLUGGING, CORROSION OR EROSION WHICH ARE USUALLY  ASSOCIATED WITH LIME/LIMESTONE  FGD SYSTEMS.
                                                                                          PEDCo-ENVIRONMENTAL
                                                       112

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                                                 Reid Gardner 1
Month
   Operating Hours
BoilerFGD system
            QperabiHtv (%}
Jul. 75


Aug. 75
Sep. 75

Oct. 75

Nov. 75
Dec. 75

Jan. 76
716
303
654
646
                           85X
559
106
394
186
77
35
60
29
                                                                             COMMENTS
During February the FGD system operated with 95 percent availability
on trona supplemented with soda ash.  January availability was only
about 65 percent because of frozen sodium carbonate feed lines.
Problems In February Included a two-day lack of chemicals.  No
significant problems occurred In March.  The unit ran April 1
through April 12 with 100Z availability.  The boiler was then  shutdown
for routine maintenance.  The system was placed back on line May 12.
Second performance test was passed.  Problems Included rubber-lined
pipe abrasion and routine mechanical problems.  Minor Instrumentation
problems.  High ash content, up to 20%, had no effect on emissions.

Four forced unit outages occurred, 3 of which were caused by scrubber
malfunctions.
Low operating time due to a scheduled boiler maintenance.  An  outage
also occurred due to the malfunction of a soda ash blower.
The utility reports system performance In terms of the operablHty Index.
Unit No.  1  operablllty was low for the month of November because of
delays 1n repair material delivery.
Three forced scrubber outages occurred during the month due to reheater
steam leaks, collapse of a venturl strainer, and a frozen carbonate line-
The system was shutdown for a 16 day period for completion of  piping con-
version.   This outage was not due to a scrubber malfunction.
                                                                                                      PEDCo-ENVlRCiWcUTAL
                                                           113

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS  03/76
 IDENTIFICATION NO.
 UTILITY NANC
 UNIT NAME
 UNIT LOCATION
 UNIT RATING
 FUEL CHARACTERISTICS
 FGD VENDOR
 PROCESS
 NEW OR RETROFIT
 START UP DATE
 FGD STATUS
 EFFICIENCY.
  PARTICIPATES

  S02
 WATER WAKE UP

 SLUDGE DISPOSAL

 UNIT COST
 OPERATIONAL
  EXPERIENCE
 61
NEVADA POWER
REIO GARDNER NO 2
HOAPA NEVADA
 125 MM
COAL   0.5- 1.0 PERCENT SULFUR
COMBUSTION EQUIP. ASSOCIATES
SODlun CARBONATE SCRUBBING
RETROFIT
12/7S
OPERATIONAL
REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT.  THIS
FGO SYSTEM HAS BEEN OPERATIONAL SINCE FEB. 1973. SYSTEM OPtRAQILlTY FOR
THE MONTH OF JANUARY EXCEEDED 66 PERCENT. DURING THE REPORT MONTH THE
BOILER WAS OUT OF SERVICE 3 DAYS. SCKUBOER OUTAGES WERE CAUSED BY FROZEN
CARBONATE LINESi PLUGGED PRESSURE SENSING LINES AND AN WERHAUL OF A TRAY
RECYCLE PUMP. TOTAL OPERATING TIME LOGGED BY THIS SCRUBBING SYSTEM TO
DATE IS 7369 HRS.
                                                         114
                                                                                PEDCo-ENVIRONWitttiftl.

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                                          BACKGROUND INFORMATION
                                                   ON
                                          REID GARDNER UNIT NO.  2

     THE REID GARDNtR POWER STATION IS LOCATED NEAR MOAPA,  NEVADA,  ABOUT  50 MILES  NORTH  OF  LAS  VEGAS.  AT
PRESENT THE STATION HAS TWO ELECTRIC POWER GENERATING UNITS, (REID  GARDNER 1  AND 2)  EACH RATED  AT  125  MW.
BOTH UNITS ARE RETROFITTED WITH SODIUM CARBONATE BASED FLUE GAS  DESULFURIZATION  SYSTEMS. THE COAL  BURNED
AT THE PLANT HAS AN AVERAGE GROSS HEATING VALUE OF 12,450 BTU/LB, AND ASH AND SULFUR CONTENTS OF 8  AND
0.5 PERCENT RESPECTIVELY.
     THE FGD SYSTEM ON REID GARDNER 1  WAS MANUFACTURED BY COMBUSTION EQUIPMENT ASSOCIATES AND PLACED
IN OPERATION DURING APRIL, 1974.  THE  DESIGN OF THIS SYSTEM WAS  BASED ON  DATA GATHERED FROM THE OPERATION
OF AN 8000 ACFM PILOT PLANT WHICH OPERATED AT THE REID GARDNER POWER STATION DURING  1971 AND 1972.
     THE FGD SYSTEM CONSISTS OF A SINGLE MODULE, DESIGNED TO HANDLE 473,000 ACFM OF  GAS  AT  350°F.   EACH
MODULE IS MADE UP OF A TWIN VARIABLE THROAT VENTURI SCRUBBER FOLLOWED BY  A SINGLE  STAGE  WASH TRAY.
BYPASSING OF EACH MODULE IS POSSIBLE THROUGH A GUILLOTINE TYPE BYPASS VALVE.  THE  PLANT  HAS A COMMON
TRONA (SODIUM CARBONATE ORE) STORAGE AND SAND REMOVAL PLANT WHICH  SERVES  BOTH FGD  MODULES ON REID  GARDNER
1 AND 2.  S02 REMOVAL EFFICIENCY IS REPORTED TO BE 85 PERCENT.
     IN THIS SODIUM CARBONATE PROCESS, THE HOT FLUE GAS FROM THE BOILER PASSES FIRST THROUGH AN EXISTING
MECHANICAL COLLECTOR (MULTICYCLONE) WHERE ABOUT 75 PERCENT OF THE  FLY ASH IS REMOVED.  ITS  PRESSURE IS
THEN BOOSTED BY AN I.D. FAN BEFORE  IT SPLITS INTO TWO STREAMS AS IT ENTERS THE TWIN  THROAT  VENTURI
SCRUBBER.  HERE THE HOT FLUE GAS IS QUENCHED BY A SHOWER OF CIRCULATED SODIUM BASE LIQUOR.   THE GAS THEN
ENTERS THE WASH TRAY AND BUBBLES THROUGH THE WATER ON THE SIEVE TRAY.  THE SCRUBBER  GAS  WHICH IS  ESSENTIALLY
FREE OF FLY ASH AND SULFUR DIOXIDE, PASSES THROUGH THE RADIAL VANE MIST ELIMINATOR WHERE THE REMAINING
LIQUID DROPLETS CARRIED OVER WITH THE GAS ARE TRAPPED AND REMOVED.
     THE  EFFLUENT  FROM THE FGD  SYSTEM IS MADE UP OF TWO SOURCES:  THE SLIP STREAM OF SPENT LIQUOR  DISCHARGED
FROM THE  RECIRCULATION TANK, AND THE ALKALINE CLARIFIER UNDERFLOW WHICH SERVES TO NEUTRALIZE THE  pH OF
THE COMBINED LIQUOR BEFORE IT  IS DISCHARGED TO THE SLUDGE SETTLING PONDS.  THERE ARE TWO SLUDGE SETTLING
                                                                                   PEDCo- ENVIRONMENTAL
                                                        115

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REID GARDNER UNIT NO.  2 (continued)

PONDS,  THE SPENT LIQUOR IS PUMPED ONE  OF  THEM  AT  A  TIME.   THE  OVERFLOW  FROM THIS POND  IS PUMPED TO A
LARGER  45 ACRE POND WHERE THE BRINE  IS EVAPORATED.   THE  FGD  SYSTEM  OPERATES ON AN OPEN WATER LOOP WITH NO
LIQUOR  RECYCLED TO THE MODULES FROM  THE PONDS.
PROBLEMS AND SOLUTIONS
     THE MAJOR PROBLEM IN THE OPERATION OF THE FGD  MODULES,  HAS  BEEN  AND  STILL  IS THE  LACK OF AN ADEQUATE
SUPPLY  OF TRONA (SODIUM CARBONATE ORE).  IN ORDER TO SOLVE THIS  PROBLEM,  SODIUM  CARBONATE BRINE HAS BEEN
USED TO SUPPLEMENT TRONA.  THE SYSTEM  HAD THE  USUAL START-UP PROBLEMS SUCH AS  RUBBER  LINERS ON RECIRCULATION
LINES GETTING LOOSE DUE TO POOR FABRICATION, FREEZE UP OF INSTRUMENTS AND ASH  PLUGGING IN CONTROL VALVE
BYPASS  LINES.  OTHER MINOR PROBLEMS  WERE LEAKAGE  IN THE  MECHANICAL  SEALS  OF THE .RECIRCULATION PUMPS.
ALSO MECHANICAL FAILURE PROBLEMS WERE  EXPERIENCED WITH THE GUILLOTINE TYPE BYPASS DAMPERS, WHICH WERE
LATER CORRECTED WITH UPGRADED REPLACEMENT PARTS.
     AS EXPECTED, THIS SODIUM BASED FGD SYSTEM HAS  NOT EXPERIENCED  SUCH PROBLEMS AS EQUIPMENT SCALING.
DEMISTER  PLUGGING, CORROSION OR EROSION WHICH ARE USUALLY ASSOCIATED WITH LIME/LIMESTONE  FGD  SYSTEMS.
                                                                                        PEDCo-ENVIRONMENTAL
                                                        116

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                                                      Reid Gardner 2
Month
Jul. 75
              Operating Hours
Bo Her   FGD system
             FGO System
            Operability (X)
                           85X
                                      COMMENTS
                             During February the FGD system operated with 90 percent availability on
                             trona supplemented with soda ash.  Problems Included a plugged recycle
                             line strainer, seal water filters and boiler controls.  Unit has now
                             restarted after shutdown for a five year turbine overhaul.
                             Second performance test  was passed.  Problems Included rubber-lined
                             pipe abrasion and routine mechanical problems.  Miner Instrumentation
                             problems.  High ash content, up to 20%, had no effect on emissions.
Aug. 75
Sep. 75

Oct. 75

Nov. 75
Dec. 75
Jan. 76
645
531
603
691
496
464
596
458
77
87
99
66
Three forced outages occurred due to strainer plugging, broken bucket
elevator, and worn out redrculatlon piping and rubber liner leakage.
Three forced outages occurred during the month of October due to pump
repair, Instrument plugging, and repair of piping leakage.
The utility reports system performance in terms of the operabllity Index.

Boiler was out of service a total of 3 days during the month.  Scrubber
outages were caused by frozen carbonate lines, plugged pressure sensing
lines, and overhaul of a tray recycle pump.
                                                                                                     PEDCo-ENVIRONMENT
                                                            117

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL F6D SYSTEMS  03/76


 IDENTIFICATION NO.     79

 UTILITY NAME          PHILADELPHIA ELECTRIC CO.

 UNIT NAME             EDDYSTUNE NO 1A

 UNIT LOCATION         EDDYSTONE PENNSYLVANIA

 UNIT RATING            120 MM

 FUEL CHARACTERISTICS  COAL   2.5 PERCENT SULFUR

 FGD VENDOR            UNITED ENGINEERS

 PROCESS               MAGNESIUM OXIDE SCRUBBING

 NEW OR RETROFIT       RETROFIT

 START UP OATE          9/75

 FGD STATUS            OPERATIONAL

 EFFICIENCY,
  PARTICULATES


  S02


 WATER MAKE UP


 SLUDGE DISPOSAL


 UNIT COST            $17  MILLION CAPITAL


 OPERATIONAL           THE S02 SCRUBBER HAS  BEEN  TEMPORARILY  SHUTDOWN BECAUSE  THE ACIO PLANT RE-
  EXPERIENCE           GENERATION FACILITY AT THE  OLIN  CHEMICAL  SULFUKIC ACID  PLANT  IN PAULSBORO
                       NEW JERSEY HAS  PERMANENTLY  CEASED  OPERATIONS. CONSIDERATIONS  ARE NOW
                       BEING GIVEN TO  THE RELOCATION  OF THE REGENERATION FACILITY. ONCE THIS DE-
                       CISION IS MADE  A MINIMUM PERIOD  OF SIX MONTHS WILL BE REQUIRED TO RELO-
                       CATE THE REGENERATION FACILITY.  THE PARTICULATE SCRUBBERS ARE CONTINUING
                       TO  OPERATE. THL UTILITY IS  STILL EXPERIENCING PROBLEMS  WITH THE FANS, RE-
                       HEAT BURNERS, DAMPERS. AND  EXPANSION JOINTS.
                                                          118
                                                                                                       PEDCo- ENVIRONMENTAL

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL F60 SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING

 FUEL CHARACTERISTICS

 FGD VENDOR

 PROCESS

 NEW OK RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
  PARTICULATES

  S02
 66

PUBLIC SERVICE CO. OF COLORADO

VALMONT NO. 5

VALMONT COLORADO

  50 MW

COAL  0.72 PERCENT SULFUR

UOP / PUb SERVICE OF COLORADO

LIMESTONE SCRUBBING

RETROFIT

10/7*

OPERATIONAL


 95 PERCENT


8S PERCENT
 WATER MAKE UP
 SLUDGE DISPOSAL
CLOSED LOOP
UNSTABILIZED SLUDGE DISPOSED IN LINED POND
 UNIT COST
 OPERATIONAL
  EXPERIENCE
REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
SYSTLM HAS BEEI4 OPERATIONAL SINCE NOVEMBER 1971. THE FGO SYSTEM CURRENTLY
OPERATIONAL AT THIS STATION IS AN EXPERIMENTAL UNIT, ORIGINALLY DESIGNED
BY UNIVERSAL OIL PRODUCTS FOR PAKTICULATE REMOVAL ONLY. ONE OF THE TWO
PARALLEL SCRUBBING MODULES WAS CONVERTED TO LIMESTONL SCRUBBING FOR
EXPERIMENTAL PURPOSES ONLY.
                                                           119
                                                                                                    PEDCo-ENVIRONMENTAL

-------
                                                  BACKGROUND  INFORMATION
                                                           ON
                                                       VALNONT  NO.  5

      THE VALMONT POWER STATION  OF  THE  PUBLIC  SERVICE  COMPANY OF  COLORADO  IS LOCATED  IN VALMONT. COLORADO, APPROXIMATELY  20
 MILES NORTH OF DENVER. COLORADO.   VALMONT  NO.  5  IS A  COAL-FIRED  UNIT WHICH OCCASIONALLY FIRES GAS A FEW MONTHS DURING THE
 YEAR.  THE  COAL GENERALLY  EMPLOYED IS  WYOMING  ROSEBUD WHICH HAS  AN AVERAGE GROSS HEATING VALUE OF 10,780 BTU/LB WITH ASH CONTENT
 IN  THE 6 TO 7  PERCENT  RANGE  AND SULFUR CONTENT LESS THAN  1 PERCENT.
      THE FGD SYSTEM  CURRENTLY BEING  TESTED AT  THIS STATION IS  AN EXPERIMENTAL UNIT ORIGINALLY DESIGNED BY UNIVERSAL OIL
 PRODUCTS FOR PARTICULATE REMOVAL ONLY.   THIS TCA  UNIT CONSISTS OF 2 PARALLEL MODULES WITH A COMBINED CAPABILITY OF TREATING
 APPROXIMATELY  50 PERCENT OF  THE TOTAL  FLUE GAS LOAD OR THE EQUIVALENT OF APPROXIMATELY 100 MW GENERATING CAPACITY (50 MM PER
 MODULE).  THIS SYSTEM  WAS  COMPLETED  AND  OPERATIONAL IN 1971 AND  RAN THROUGH TO OCTOBER 1974.  PARTICULATE REMOVAL EFFICIENCY
 WAS  MEASURED TO BE 95  PERCENT.  SOg REMOVAL EFFICIENCY WAS 45 PERCENT AND AVAILABILITY WAS APPROXIMATELY 70 PERCENT.  FREQUENT
 SCRUBBER OUTAGES WERE  CAUSED PRIMARILY  BY A SUPERSATURATED CALCIUM SULFATE CONDITION IN THE SCRUBBING LIQUOR.  IN ORDER TO
 MINIMIZE THE NUMBER  OF CLEAN OUTS  AND  TO RECTIFY  THE  SCALING PROBLEM A pH CONTROL PROGRAM WAS IMPLEMENTED FOR ONE OF THE
 SCRUBBING MODULES EMPLOYING  LIMESTONE  ADDITION TO THE SCRUBBING  LIQUOR.  THIS MODIFICATION WAS EXPECTED TO MINIMIZE
 SCALING,  DECREASE SCRUBBER OUTAGES FOR  CLEAN OUTS, AND INCREASE AVAILABILITY.   THE EXPECTED RESULTS DID NOT MATERIALIZE.
 SCALE BUILD-UP CONTINUED AND AVAILABILITY DECREASED.   RESULTS OBTAINED DURING THE pH CONTROL PROGRAM SHOWED PARTICULATE
 REMOVAL  EFFICIENCY AT  THE  95% LEVEL.   S02 REMOVAL EFFICIENCY INCREASED TO 85X AND AVAILABILITY DROPPED TO 70 PERCENT.   THE
 UNSTABILIZED SLUDGE  GENERATED DURING THIS OPERATION PHASE WAS PUMPED TO A LINED POND.  THE OPERATIONAL DATA GENERATED FROM
.THE  LIMESTONE  MODIFICATION PROGRAM IS  OF A PRELIMINARY NATURE BASED UPON RESULTS OBTAINED FROM THE FOUR AND A HALF MONTH
 TESTING  PROGRAM.
                                                             120

-------
                                                      Valmont No.  5

                 Operating hours                FGD System
Month         Boiler        FGD System       Operablllty (%)                         Comments
Sep. 75         0               0                  0             This facility has been Inactive since September  1.  1975
Oct. 75         0               0                  0             due to a turbine generator failure.   The  unit  Is  scheduled
                                                                 to go on line again sometime in December  1975.
Nov. 75         0               0                  0             This unit is still  Inactive due to a  boiler overhaul.  The
Dec. 75         0               0                  0             scrubber/absorber train is available  and  will  be  coupled  Into
                                                                 the system when the boiler goes back  on-line.
Jan. 76         0               0                  0             The boiler overhaul has been completed.   The unit is  available
Feb. 76         0               0                  0             In the particulate  removal mode only.  The limestone
                                                                 modification program Implemented for  one  of the  two scrubbing
                                                                 modules has been delayed by the utility for an Indefinite
                                                                 period.
                                                                 121

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGD SYSTEMS  03/76
 IDENTIFICATION NO.


 UTILITY NAME


 UNIT NAME


 UNIT LOCATION


 UNIT RATING


 FUEL CHARACTERISTICS


 FGD VLNDOR


 PROCESS


 NEW OR RETROFIT


 START UP DATE


 FGD STATUS


 EFFICIENCY,

  PARTICIPATES



  802



 WATER MAKE UP




 SLUDGE DISPOSAL



 UNIT COST
 OPERATIONAL
  EXPERIENCE
100


TENNESSEE. VALLLY AUTHORITY


SHAUNEE N0.10A


PADUCAH KENTUCKY


  10 MW


COAL 2.9 PERCENT SULFUR


UNIVERSAL OIL PRODUCTS


LIME/LIMESTONE SCRUBBING


RETROFIT


 V72


OPERATIONAL
REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT.  THIS
TUKBULENT CONTACT ABSOKtiER(TCA) LIME/LIMESTONE SCRUBBING SYSTEM HAS BEEN
OPERATIONAL SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY THE EPA.
TVA IS THE CONSTRUCTOR AND FACILITY OPERATOR. THE BECH1EL CORP. OF  SAN
FRANCISCO IS THE MAJOR CONTRACTOR, TEST DIRECTOR. AND KIPORT WRITER.
                                                             122
                                                                             PEDCo-ENVIRONMENTAL

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                   TABLE 3
PERFORMANCE DESCRIPTION FOR OPERATIONAL FGO SYSTEMS  03/76
 IDENTIFICATION NO.

 UTILITY NAME

 UNIT NAME

 UNIT LOCATION

 UNIT RATING

 FUEL CHARACTERISTICS

 FGD VENDOR

 PROCESS

 NEW OR RETROFIT

 START UP DATE

 FGD STATUS

 EFFICIENCY,
  PARTICULATES


  S02


 HATER MAKE UP


 SLUDGE DISPOSAL
101

TENNESSEE VALLEY AUTHORITY

SHAWNEE N0.10B

PADUCAH KENTUCKY

  10 MU

COAL 2.9 PERCENT SULFUR

CHEMICO

LIME/LIMESTONE SCRUBBING

RETROFIT

 V72

OPERATIONAL
 UNIT COST
 OPERATIONAL
  EXPERIENCE
REFER TO BACKGROUND INFORMATION SECTION IN TABLE 3 OF THIS REPORT. THIS
VENTURI/SPRAY TOWER LIME/LIMESTONE SCRUBBING SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL 1972. THIS TEST PROGRAM IS FUNDED BY THE EPA. TVA IS THE
CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTEL CORP. OF SAN FRANCISCO IS
THE MAJOR CONTRACTOR*TEST DIRECTOR, AND REPORT WRITER.
                                                            123
                                                                                                        PEDCo-ENVIRONMENTAL

-------
                                                 BACKGROUND  INFORMATION
                                                          ON
                                             SHAUNEE  NOS.  10A,  10B,  AND  IOC

     IN JUNE, 1968, THE EPA INITIATED A PROGRAM TO TEST PROTOTYPE      LIME AND  LIMESTONE  WET  SCRUBBING  SYSTEMS  FOR  THE  REMOVAL
OF SULFUR DIOXIDE AND PARTICULATES FROM COAL-FIRED BOILER  FLUE  GASES.  THE PROGRAM  WAS  INITIATED  AND  CARRIED  OUT  IN A TEST
FACILITY WHICH WAS INCORPORATED INTO THE FLUE GAS DUCT  WORK  OF  UNIT  NO.  10,  A  COAL-FIRED  BOILER AT  THE  TVA  SHAWNEE  POWER
STATION, PADUCAH, KENTUCKY.  TVA IS THE CONSTRUCTOR AND FACILITY OPERATOR AND  THE BECHTEL CORP. IS  THE  MAJOR  CONTRACTOR.  TEST
DIRECTOR, AND REPORT WRITER.
     THE TEST FACILITY CONSISTS OF THREE PARALLEL SCRUBBER SYSTEMS OF  PROTOTYPE SIZE  TREATING PART  OF THE  FLUE  GAS  FROM THE
BOILER.  EACH SCRUBBER TRAIN IS CAPABLE OF TREATING APPROXIMATELY  30,000 ACFM  OR THE  EQUIVALENT OF  APPROXIMATELY  10 MW  OF
POWER PLANT GENERATING CAPACITY.
     THE THREE PARALLEL WET SCRUBBER SYSTEMS SELECTED FOR THE TEST PROJECT  WERE:  1)  A  VENTURI WITH A SPRAY TOWER AFTER
ABSORBER; 2) A TURBULENT CONTACT ABSORBER (TCA) AND 3)  A MARBLE-BED ABSORBER.   THE  VENTURI SYSTEM,  MANUFACTURED BY  CHEMICAL
CONSTRUCTION CO., CONTAINS AN ADJUSTABLE THROAT THAT PERMITS CONTROL AND VARIATION  OF PRESSURE DROP UNDER  A WIDE  RANGE  OF FLOW
CONDITIONS.  THE TCA UNIT MANUFACTURED BY UNIVERSAL OIL PRODUCTS, EMPLOYS A FLUIDIZED BED OF  LOW  DENSITY PLASTIC  SPHERES  THAT
ARE FREE TO MOVE BETWEEN RETURNING GRIDS.  THE MARBLE-BED ABSORBER, SUPPLIED BY COMBUSTION ENGINEERING  CO., USES  A PACKING
OF 3/4  INCH GLASS MARBLE SPHERES AND A TURBULENT LAYER OF LIQUID AND GAS ABOVE THE  MARBLE LAYER TO ENHANCE MASS TRANSFER.
     IN  JUNE 1974, THE EPA, THROUGH  ITS OFFICE OF RESEARCH AND DEVELOPMENT AND INDUSTRIAL ENVIRONMENTAL RESEARCH  LABORATORY
INITIATED A THREE-YEAR ADVANCED TEST PROGRAM AT THE SHAWNEE FACILITY.   THE MAJOR GOALS ESTABLISHED FOR  THE ADVANCED PROGRAM
ARE:   (1) CONTINUATION OF  LONG-TERM  TESTING, EMPHASIZING RELIABLE OPERATION OF MIST ELIMINATION SYSTEMS AT INCREASED GAS
VELOCITY.  (2)  INVESTIGATION OF  ADVANCED PROCESS AND EQUIPMENT DESIGN VARIATIONS FOR IMPROVING SYSTEM RELIABILITY  AND PROCESS
ECONOMICS, AND  (3) TO  PERFORM  LONG-TERM RELIABILITY TESTING ON  PROMISING PROCESS AND EQUIPMENT DESIGN VARIATIONS.
     THE TWO PARALLEL  SCRUBBING SYSTESM OPERATING DURING THE ADVANCED PROGRAM ARE THE VENTURI/SPRAY TOWER SYSTEM AND THE
TCA UNIT.  OPERATION OF  THE MARBLE-BED ABSORBER UNIT HAS BEEN PERMANENTLY DISCONTINUED.

                                                                                                   PEDCO-ENV1RONMENTAL

                                                                124

-------
SHAWNEE NOS. 10A, 10B, and IOC (continued)
     EACH OF THE ABOVE TWO SYSTEMS CONTAINS ITS OWN SLURRY HANDLING FACILITIES AND IS CAPABLE OF TREATING  APPROXIMATELY  30,000
ACFM OF GAS AT 300°F CONTAINING 1800 TO 4000 PPM OF S02 AND 2 TO 4 GRAINS/SCF OF PARTICULATES.   BOILER NO.  1  NORMALLY  BURNS
A HIGH-SULFUR BITUMINOUS COAL.
     FROM JUNE 1974 TO JANUARY 1976. THE MIST ELIMINATION AND LIMESTONE UTILIZATION TESTS WERE  CONDUCTED AT THE  SHAWNEE
FACILITY.  DURING THIS TEST PERIOD THE VENTURI/SPRAY TOWER SYSTEM WAS OPERATED ON BOTH LIME  AND LIMESTONE  AND THE  TCA  SYSTEM
WITH LIMESTONE.   TESTING WAS PERFORMED UNDER A CLOSED LIQUOR LOOP OPERATION MODE.  DURING THIS  PERIOD  THE  SLURRY SOLIDS  CON-
TAINED APPROXIMATELY 40.TO 50 WEIGHT PERCENT FLY ASH BECAUSE OF RELATIVELY  HIGH GAS INLET PARTICULATE  LOADING.  THIS TESTING
PROGRAM IS SCHEDULED TO RUN THROUGH TO JUNE 1977.
                                                                                                   PEDCo-ENVIRONMENTAL
                                                            125

-------
                                                Shawnee Nos.  10A and 10B

                      FGD System Operating Hours
Test Run Period                       FGD System
Month                10A      10B     operability (X)                            Comments.
Sep. 75                                                     This 1s an experimental  EPA-funded system.   Currently proceeding
Oct. 75'                                                    with the test program.   Tow absorber modules are currently opera-
                                                            tional  (10 MW each)  with the marble-bed absorber still  Inoperative
                                                            (since  July, 1973).   Currently, experiments are related to mist
                                                            eliminator section.
Nov. 75                                                     Recent  testing at Shawnee has shown that the chevron mist elim-
Oec. 75                                                     Inators 1n both the spray tower ari'd the TCA can be kept free of
                                                            solids  build-up at high  alkali  utilization  (greater than 90 percent)
                                                            using only Intermittent  washing with available raw water.  This high
                                                            Utilization 1s normally  achieved with lime  and has been achieved
                                                            with limestone at (1) reduced scrubber Inlet slurry pH (about 5.2)
                                                            and (2) with the use of  three effluent tanks in series to simulate a
                                                            plug-flow reactor.
                                                            Presently, testing Is continuing to determine the effects of process
                                                            variables on mist eliminator performance and on limestone utiliza-
                                                            tion.  Future plans Include:  (1) factorial 'testing with lime and
                                                            limestone to determine the effects of process variables on SO- re-
                                                            moval for the scrubber systems, and (2) testing the oxidation of
                                                            sludge  to gypsum in the  venturi/spray tower system using air
                                                            sparging of an acidified slurry bleed stream.
Jan 76                                                      Presently, the utility and the contractor are continuing with the
Feb. 76                                                     advanced test program being conducted at this facility.  The high-
                                                            lights  of this program are:

                                                                                                        PEDCo-ENVIRONMENTAL
                                                               126                	

-------
Shawnee Nos. 10A and 10B (continued)
                                                                      Evaluate scrubber operablllty  during  variable  load
                                                                      operation
                                                                      Continuation  of  long-term  reliability  testing
                                                                      Investigation of methods for Improving waste solids
                                                                      separation
                                                                      Continuation  of  sludge oxidation and sludge fixation
                                                                      study programs
                                                                      Evaluation of  system performance at reduced fly ash
                                                                      loadings
                                                                      Determination of  the practical  upper limits of S02 removal
                                                                      efficiency
                                                                      Magnesium ion addition to the scrubbing slurry
                                                                      Characterization  of all stack gas emission components
                                                                      Evaluation of materials of construction of all  scrubber
                                                                      and plant related components.
                                                                      Development of a design and cost analysis computer
                                                                      program for full  scale lime/limestone systems.
                                                             127
                                                                                                       PEDCo- ENVIRONMENTAL

-------
              Table 4
NUMBER AND TOTAL MW OF FGD SYSTEMS
               129

-------
               TABLE 4
NUMBER AND TOTAL MW OF FGO SYSTEMS

      STATUS                    NO.OF      MW
                                UNITS
   OPCKATIONAL                    23       3««»8.

   UNDER CONSTRUCTION             20       7256.

   PLANNING
     CONTRACT AWARDED             It       5861.

     LETTER OF INTENT     "        9       3771.

     REQUESTING/EVALUATING BIDS    6       3102.

     CONSIDERING ONLY FGD SYSTEMS 37      19253.

     TOTAL                       109      13091.
                                                                                              PEDCO-ENVIRONMENTAL
                                                     I O I

-------
             Table 5
SUMMARY OF FGD SYSTEMS BY COMPANY
                   133

-------
                                         TABLE 5
                                SUMMARY OF FGD SYSTEMS BY COMPANY
         UTILITY

ALABAMA ELECTRIC COOP
ALLEGHENY POWER SYSTLM
ARIZONA ELECTRIC POWER COOP
ARIZONA PUBLIC SERVICE
BASIN ELECTRIC POWEK COOP
CENTRAL ILLINOIS LIGHT CO.
CENTRAL ILLINOIS PUBLIC SERV
CINCINNATI GAS 8 ELECTRIC CO.
COLUMBUS 8 SOUTHERN OHIO ELEC.
COMMONWEALTH EDISUN
DETROIT EDISON
DUQUESNE LIGHT
GENERAL MOTOKS
GULF POWER CO.
INDIANAPOLIS POWEK £ LIGHT CO.
KANSAS CITY POWER & LIGHT
KANSAS POWEK & LIGHT
KENTUCKY UTILITIES
KEY WEST UTILITY BOARD
LOUISVILLE GAS 8 ELECTRIC
MINNKOTA POWER COOPERATIVE
MONTANA POWER CO,
NEVADA POWEK
NEW ENGLAND ELEC SYSTEM
NORTHERN INDIANA PUt3 SERVICE
NORTHERN STATES POWER CO.
PENNSYLVANIA POWLH CO.
PHILADELPHIA ELECTRIC CO.
PUBLIC SERVICE co OF NEW P.EX.
PUBLIC SERVICE CO. OF COLORADO
PUBLIC SERVICE INDIANA
RICKENBACKER AFB
S. CAROLINA PUR SERV AUTHORITY
S. MISSISSIPPI ELEC PWR ASSOC
SOUTHERN CALIFORNIA EDISON
SPRINGFIELD CITY UTILITIES
TENNESSEE VALLEY AUTHORITY
TEXAS UTILITIES CO.
UNITED POWER ASSOCIATION
UTAH POWER & LIGHT CO.
TOTAL


NO.
2
2
2
5
5
3
1
2
4
2
1
2
1
3
1
3
4
1
1
8
1
4
10
1
3
2
3
4
4
1
2
1
1
2
6
1
3
4
2
1

OPERATIONAL

	 . 	 STATUS 	
i*wi«0 i n%/«* I • w*«
CONTRACT
AWARDED
MW
45U.
1250.
405.
1875.
2550.
857.
600.
900.
1550.
542.
180.
920.
32.
63.
530.
1060.
1885.
64.
37.
2213.
450.
2120.
3000.
650.
705.
1360.
2505.
846.
1715.
50.
1300.
20.
140.
360.
4410.
200.
570.
3172.
1090.
415.
NO.
0
0
0
1
0
0
0
0
0
1
0
2
1
3
0
3
2
1
1
1
0
1
2
0
0
0
0
1
0
1
0
0
0
0
0
0
2
0
0
0
MW
0.
0.
0.
115.
0.
0.
0.
0.
0.
167.
0.
920.
32.
63.
0.
1060.
525.
64.
37.
65.
0.
360.
250.
0.
0.
0.
0.
120.
0.
SO.
0.
0.
0.
0.
0.
0.
20.
0.
0.
0.
NO.
• o
0
0
2
0
1
0
0
1
0
1
0
0
0
1
0
0
0
0
3
1
1
1
0
1
2
2
0
0
0
0
1
0
0
0
1
1
0
0
0
MW
0.
0.
0.
410.
0.
100.
0.
0.
400.
leo".
u.
0.
0.
530.
0.
0.
0.
0.
786.
450.
360.
125.
0.
115.
1360.
1670.
0.
0.
0.
0.
20.
0.
0.
0.
200.
550.
0.
0.
0.
NO.
2
0
0
0
0
0
0
0
1
0
0
0
0
0
0
2
0
0
1
0
0
0
0
0
0
0
0
2
0
0
0
1
2
0
0
0
2
0
0
Mb
450.
0.
0.
0.
0.
0.
0.
0.
400.
425.
0.
0.
0.
0.
0.
0.
1360.
0.
0.
425.
0.
0.
0.
0.
0.
0.
0.
' U.
715.
0.
0.
0.
140.
360.
0.
0.
0.
1586.
0.
0.

LETTER OF REQUESTING/
INTENT
NO.
0
0
2
0
0
0
0
0
0
. °
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
1
2
0
0
0
0
0
0
0
0
2
0
1
MW
0.
0.
405.
0.
0.
0.
0.
0.
°?

o!
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
125.
0.
0.
' 0.
0.
240.
1000.
0.
0.
0.
0.
0.
0.
0.
0.
1586.
0.
415.
CVAL. BIDS
NO.
0
0
0
0
0
0
1
1
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
2
0
MW
0.
0.
0.
0.
0.
0.
600.
300.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
277.
0.
0.
0.
0.
0.
0.
835.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
1090.
0.
CONSIDERING
FGD
NO.
0
2
0
2
5
2
0
1
2
0
0
0
o
0
0
o
0
0
0
2
o
2
6
1
2
0
0
2
0
0
2
0
0
0
6
0
o
0
0
0
SYSTEMS
MW
0.
1250.
0.
1350.
2550.
757.
0.
600.
750.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
660.
0.
1400.
2500.
650.
590.
0.
0.
486.
0.
0.
1300.
0.
0.
0.
4410.
0.
0.
0.
0.
0.
   TOTALS
                                   109  43091.   23   3848.    20   7256.    14   5861.
3771.
                                                                                                          3102.    37   19253.
                                                                                                        PEOCo-ENVIRONMENTAL
                                                            135

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             Table 6
SUMMARY OF FGD SYSTEMS BY VENDOR
                   137

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           TAULE  6
SUMKARY OF FGO  SYSTEMS DY VLNUOR



TOTAL OPERATK
MANUFACTURER/PROCESS NO.
ADL/COMBUSTION EQUIP ASSOCIATE
DOUBLE ALKALI J
TOTAL. ADL/COKBUSTION EQUIP ASS 1
AMERICAN AIK FILTER
LIME SCRUBBING 3
TOTAL, AMERICAN AIR FILTER 3
BABCOCK 8 WILCOX
LIMESTONE SCRUBBING 2
TOTAL, BABCOCK & WILCOX 2
CHEMICO
LIME SCRUBBING 7
LIME/LIMESTONE SCRUBBING 1
TOTAL, CHEMICO 5
CHIYODA INTERNATIONAL
THOROUGHBRED 101 *
TOTAL, CHIYODA INTERNATIONAL 1
COMBUSTION ENGINEERING
LIME SCRUBBING ;:
LIMESTONE INJECTION XwET SCRUB '*
LIMESTONE SCRUBBING 2
TOTAL, COMBUSTION ENGINEERING a
COMBUSTION EQUIP. ASSOCIATES
LIME SCRUBBING *
SODIUM CARBONATE SCRUBBING 3
TOTAL, COMBUSTION EQUIP. ASSOCI 6
DAVY POWERGAS/ALLIED CHEMICAL
WELLMAN LORD/ALLIED CHEMICAL 1
TOTAL, DAVY POWERGAS/ALLIED CHE 1
FOSTER WHEELER
ACTIVATED CARBON 1
TOTAL, FOSTER WHEELER 1
KOCH
DOUBLE ALKALI *
TAT 111 . KOCH l
MW
20.
20.
667.
667.
967.
967.
2590.
10.
2600.
23.
23.
2<*8.
765.
1360.
2373.
1170.
375.
1515.
115.
115.
20.
20.
32.
32.
NO.
1
1
1
1
2
2
2
1
3
1
1
1
0
5
1
2
3
0
0
1
1
1
1
•STATUS
)NAL C
MW
20.
20.
6H.
6 ENVIRONMENTAL

-------
           TABLE 6
SUMMARY OF FGU SYSTEMS  BY  VENDOR




TOTAL OPERATI
MANUFACTURER/PROCESS
PEABODY ENGINEERING
LIMESTONE SCRUBBING
TOTALt PEABODY ENGINEERING
RESEARCH COTTKELL
LIME SCRUBBING
LIMESTONE SCRUBBING
TOTAL. RESEARCH COTTRELL
RILEY STOKER/ENVIRONEERING
LIMESTONE SCRUBBING
TOTALt RILEY STOKER/ENVIRONEERI
SCE
LIME SCRUBBING
TOTALt SCE
TENNESSEE VALLEY AUTHORITY
LIMESTONE SCRUBBING
TOTAL. TENNESSEE VALLEY AUTHOR!
UNITED ENGINEERS
MAGNESIUM OXIDE SCRUUBING
TOTAL. UNITED ENGINEERS
UNIVERSAL OIL PRODUCTS
LIME SCRUBBING
LIME/LIMESTONE SCRUBBING
LIMESTONE SCRUBBING
TOTAL. UNIVERSAL OIL PRODUCTS
UOP / PUB SERVICE OF COLORADO
LIMESTONE SCRUBBING
TOTALt UOP / PUB SERVICE OF COL
ZURN AIR SYSTEMS
LIMESTONE SCRUBBING
TOTALt ZURN AIR SYSTEMS
NO.

1
1

1
2
3

1
1
1
1

1
1

1
1

1
1
2
4

1
1

1
1
MU

160.
160.

20.
365.
365.

100.
100.
160.
160.

550.
550.

120.
120.

too.
10.
730.
11HO.

50.
50.

37.
37.
NO.

0
0

0
1
1

0
0
0
0

0
0

1
1

0
1
0
1

1
1

1
1
-STATU!
ONAL <
nw

0.
0.

0.
115.
115.

0.
0.
0.
0.

0.
0..

120.
120.

0.
10.
0.
10.

50.
50.

37.
37.


CONSTRUCTION
NO.

1
1

1
1
2

1
1
1
1

1
1

0
0

1
0
2
3

0
0

0
0
MU

180.
160.

20.
250.
270.

100.
100.
160.
160.

550.
550.

0.
0.

too.
0.
730.
1130.

0.
0.

0.
0.
           11104.
23  3646.
                                 20  7256.
                                     140
                                                                                 PEDCb- ENVIRONMENTAL

-------
                      Table 7



SUMMARY OF NEW AND RETROFIT FGD SYSTEMS BY PROCESS
                            141

-------
                                                   TABLE 7
                                 SUMMARY OF NEW AND RETROFIT FGD SYSTEMS  BY  PROCESS

                                         MM CAPACITY(NO. OF PLANTS)
            PROCESS

LIME SCRUBBING
LIME/LIMESTONE SCRUBBING
 (PROCESS NOT SELECTED)


LIMESTONE SCRUBBING
  SUBTOTAL - LIME/LIMESTONE
ACTIVATED CARBON
DOUBLE ALKALI
MAGNESIUM OXIDE SCRUBBING
 NOT  SELECTED
 REGENERABLE  NOT  SELECTED
 SODIUM  CARBONATE  SCRUBBING
 THOROUGHBRED 101
 WELLMAN LORD
 UELLMAN LORD/ALLIED CHEMICAL
           TOTALS
   LIME/LIMESTONE * OF TOTAL MW
NEW OR OPERATIONAL
RETROFIT
NO. MW
N 1 360
R 4 1049
N
R
N
R
N
R
N
R
N
R
N
R
R
N
R
N
R

R
N
R
N
R
N
R
W N
R
U
2
3
6
4.
12.
0
1
0
2
0
1
0
0
0
0
0
2
o
1
o
0
0
0
4
19


0
20
1257
697
1617.
1766.
0
20
0
52
0
120
0
0
0
0
0
250
0
23
0
0
0
0
. 1617.
. 2231.
100
79
CONSTRUCTION
NO. MW
6 3305
4 b41
0
0
6
2
12.
6.
0
0
o
0
0
0
0
0
0
0
1
0
o
0
0
0
0
1
13.
7.


0
0
2440
730
5745.
1271.
0
0
0
0
0
0
0
0
0
0
125
0
0
0
0
0
0
115
5670.
1366.
96
92


CONTRACT
AWARDED
NO. MW
2 625
0 0
0
0
9
1
11.
1.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
1
12.
2.


0
0
3696
<*25
4721.
425.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
375
340
5096.
765.
93
56


LETTER OF
INTENT
NO. MW
1 415 ....
0 0
0
0
4
0
5.
0.
0
0
0
0
0
1
0
0
0
0
1
0
0
0
2
0
0
0
6.
1.


0
0
1991
0
2406.
0.
0
0
0
0
0
240
0
0
0
0
125
0
0
0
1000
0
0
0
3531.
240.
66
o"
LANNEO-
REOUE
EVAL.
NO.
0
1
3
0
0
0
3.
1.
0
0
0
0
0
0
2
0
0
0
0
0
0
0
0
0
0
0
5.
1.



.STING/
BIDS
nw
0
277
1190 -
0
0
0
1390.
277.
0
0
0
0
0
0
1435
0
0
0
0
0
0
0 '
0
0
0
0
2625.
277.
49
100


CONSIDERING
FGD SYSTEM
NO. MW
6 4250
2 660
0
2
1
0
7.
4.
0
0
0
0
0
2
16
5
0
1
0
0
0
0
0
0
0
0
25.
12.


0
1410
400
0
4650.
2070.
0
.0
0
0
0
466
9100
2297
0
650
0
0
0
0
0
0
0
0
13750.
5503.
34
38
• TOTAL NO.
OF PLANTS
NO. MW
16 9155
11 2b27
3
4
23
9
42.
24.
0
1
0
2
0
4
20
5
0
1
2
2
0
1
2
0
1
2
67.
42.
PEDCo-


1190
1430
9984
1652
20529.
5609.
0
20
0
52
0
846
10535
2297
0
650
250
250
0
23
1000
0
375

32669.
10402.
ENVlftONMtl
63
56
                                                              143

-------
                             Table 8



SUMMARY OF OPERATING FGD SYSTEMS BY PROCESS AND GENERATING UNITS
                                   145

-------
                      TADLE 8
           SUMMARY OF OPERATING FGD SYSTEMS BY
           PROCESS AND GENERATING UNITS AS OF 03/76
  PROCESS/GENERATING UNITS
FGU/MU  STARTUP  EXPERIENCED.)
        ACTIVATED CARBON

SCHOLZ NO. 2A
   20

  20.
 2-76
        DOUBLE ALKALI

CHEVROLET PARMA 1 2 3 ft
SCHOLZ NO. 1A
   32
   20
                                     52,
 3-7*
 2-75
 2
-------
                      TABLE: a
           SUMMARY OF OPERATING FGD SYSTEMS BY
           PROCESS AND GENERATING UNI IS AS OF 03/76
  PROCESS/GENERATING UNITS         FGD/MU  STARTUP   EXPERIENCE(MO.)





WILL COUNTY NO 1                     167     2-72               H9


                                   1954,              .       395



        MAGNESIUM OXIDE SCRUBBING


EDOYSTONE NO 1A                      120     9-75                6


                                    120.                        6



        SODIUM CARBONATE SCRUBBING


REID GARDNER NO 1                    125     *-7*               23
REID GARDNER NO 2                    125    12-73               27


                                    250.                  v    50



        THOROUGHBRED 101


SCHOLZ NOS. IB ft 2B                   23     3-75               12
                                  ••••••    '                 »•••

                                     23.                       12
                                                            148                                          PEDCO-ENVIRONMENIAL

-------
                             Table 9



SUMMARY OF SLUDGE DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
                                   149

-------
                            TADLE 9
        SUMMAKY OF SLUDGE DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS AS OF  03/76
PROCESS/GENEKATING UNIT
.-SLUDGE-
STABILIZED
  —SLUDGE—
UNSTABILIZED
                                                                    —POND—
                                                                      LINED
	POND	
 UNLINED
      LIME SCRUBBING

PADDYS RUN NO 6
PHILLIPS

      TOTAL
       410

       410.
                        65
                                                            65,
                                          65
                                         410

                                         475.
      LIMESTONE SCRUBBING

HAWTHORN NO 3
HAWTHORN NO 4
LAWRENCE NO 4
LAWKENCE NO 5
CHOLLA NO 1
LA CYGNE NO 1
STOCK ISLAND PLANT
VALMONT NO. 5
WILL COUNTY NO 1

      TOTAL
       167

       167.
                       140
                       100
                       125
                       400
                       115
                       620

                        50
                                                          1750.
                          50
                         167

                         217.
                                         140
                                         100
                                         125
                                         400
                                         115
                                         820
                                         37
                                                                                          1737.
                                                        151
                                                                                                    PEDCo-ENVIRONMENTAL

-------
                       Table 10



SUMMARY OF F6D SYSTEMS BY PROCESS AND REGULATORY CLASS
                              153

-------
                                                   TABLE 10
                                 SUMMARY OF FGD SYSTEMS BY PROCESS  AND REGULATORY  CLASS

                                         MW CAPACZTYiNO. OF  PLANTS)
            PROCESS

LIME SCRUBBING
LIME/LIMESTONE SCRUBBING
 (PROCESS NOT SELECTED)
LIMESTONE SCRUBBING
  SUBTOTAL - LIME/LIMESTONE
REGULATORY OPERATIONAL
CLASS
NO.
A 0
B 2
C 9
0 0
E 0
A ' 0
B 0
C 2
0 0
E 0
A U
B 3
C 3
D 3
E 0
A 0.
B 5.
c a.
D 3.
E 0.
CONSTRUCTION
CONTRACT
AWARDED
MW
0
920
469
0
0
0
0
20
0
0
0
355
1021
575
0
0.
1275.
1533.
575.
0.
NO.
2
5
2
0
1
0
0
• 0
0
0
3
3
1
0
1
5.
6.
3.
0.
2.
MW
765
2660
361
0
20
0
0
0
0
0
630
1610
5t>0
0
160
1615.
4290.
911.
0.
200.
NU.
1
1
0
0
0
0
0
0
0
0
7
2
1
0
0
6.
3.
1.
0.
0.
MW
425
400
0
0
0
0
0
0
0
0
2536
136Q
425
0
0
2561.
1760.
425.
0.
0.
LETTER OF REQUESTING/
INTENT
NO.
0
0
0
0
1
. 0
0
0
0
0
2
2
"0
0
0
2.
2.
0.
0.
1.
MW
0
0
0
0
415
0
0
0
0
0
1566
405
0
0
0
1566.
405.
0.
0.
415.
EVAL.
NO.
0
0
1
0
0
2
0
0
1
0
0
0
0
0
0
2.
0.
1.
1.
0.
i BIDS
MW
0
0
277
0
0
1D90
0
0
300
0
0
0
0
0
0
1090.
0.
277.
300.
0.
CONSIDERING
IUTAL NU.
OF PLANTS
FGD SYSTEM
NO.
6
0
2
0
0
0
0
0
0
2
1
0
0
0
0
7.
0.
2.
0.
2.
MW
4250
0
660
0
0
0
0
0
0
1410
400
0
0
0
0
4650.
0.
660.
0.
1410.
NO.
9
8
6
0
2
2
0
2
1
2
13
10
5
3
1
24.
16.
15.
4.
5.
MW
5460
4000
1767
0
435
1090
0
20
300
1410
5352
3730
1999
575
160
11902.
7730.
3606.
675.
2025.
  A.  BOILER CONSfKUCTEO SUBJECT TO FEDERAL NSPS
  B.  BOILER SUBJECT TO STAT£ STANDARD THAT IS MORE STRINGENT THAN THE FEDERAL NSPS
  C.  BOILER SUBJECT TO STATE STANDARD THAT ZS EQUAL TO OR LESS STRINGENT THAN NSPS
  0.  OTHER
  E.  REGULATORY CLASS UNKNOWN
                                                                                                             PEDCo-ENVIRONMENTAL
                                                              155

-------
                                SUMMARY OF FGO SYSTEMS  BY  PROCESS AND REGULATORY CLASS

                                        MM CAPACITYJNO.  OF PLANTS)
            PROCESS

ACTIVATED CARBON
DOUBLE ALKALI
MAGNESIUM OXIDE SCRUBBING
NOT SELECTED
REGENERABLE NOT SELECTED
Bi Aikkirn .-------.-•
REGULATORY OPERATIONAL
CLASS
NO. MM
A 0 0
BOO
C 1 20
D 0 0
EDO
A 0
B 1
C 1
D(i
V
E 0
A 0
B 1
CM
V
D 0
E 0
A U
B 0
C 0
D 0
E 0
An
w
B 0
C 0
D G
E 0
0
32
20
o
0
0
120
o
0
0
0
0
o
0
0
o
0
0
0
0
CONSTRUCTION
NO. MW
0 0
0 0
0 0
0 0
0 0
0
0
0
o
0
0
0
o
0
0
0
0
0
0
0
o
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
CONTRACT
AWARDED
NO. MW
0 0
0 0
0 0
0 0
0 0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
LETTER OF REQUESTING/
INTENT EVAL. BIDS
NO. MW NO. MM
00 00
00 00
00 00
00 00
00 00
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
2
-------
                                         TABLE 10

                          SUMMARY OF FGD SYSTEMS BY PROCESS AND REGULATORY CLASS
                                 MU CAPACITY(NO. OF PLANTS)
          PROCESS



SODIUM CARBONATE SCRUBBING
THOROUGHBRED 101
UELLMAN LORD
UELLMAN LORD/ALLIED CHEMICAL
         TOTALS
  LIME/STONE » OF TOTAL MW

REGULATORY OPERATIONAL CONSTRUCTION
CLASS
NO. MW NO. MU
A U 0 00
B 2 250 1 125.
COO 00
Dn o 0 0
E

B
c

E
A
B

o
E
A •
B
c
Q
E
A
B
C
D
E
A
B
C
D
E
0

0
1
Q
0
0
o
o
o
0
0
0
o
o
0
0
9
11
3
0

0
o
0
23
o
0
0
o
o
o
0
0
0
0
o
0 .
0.
. 1677.
. 1596.
575.
0.
0
76
V6
100
0
0
0
0
0
o
0
0
0
o
0
0
0
0
1
0
0
5
9
4
0
2

0
0
0
0
0
0
0
0
0
0
0
0
0
115
0
0
. 1615.
. 4415.
. 1026.
0.
. 200.
100
97
89
0
100
CONTRACT
AWARDED
NO. MW
0 0
0 0
0 0
0 0
0
0
0
0
0
0
0
0
0
0
0
0
2
0
0
0
8.
5.
1.
0.
0.

0
0
0
0
0
0
0
0
0
0
0
0
715
0
0
0
2961.
2475.
425.
0.
0.
100
71
100
0
0
LETTER OF REQUESTING/
INTENT EVAL. BADS
NO. MW NO. MW
00 00
1 125 00
00 00
00 00
0
0
0
0
0
0
0
2
0
0
0
0
0
0
0
0
2.
6.
0.
0.
1.

0
0
0
0
0
0
0
1000
0
0
0
0
0
0
0
0
1586.
1770.
0.
0.
HIS.
100
23
0
0
100
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
3.
1.
1.
1.
0.

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1690.
835.
277.
300.
0.
64
0
100
100
0
CONSIDERING
FGD SYSTEM
NO. MW
0 0
0 0
0 0
0 0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
12.
15.
8.
0.
. 2.

0
0
0
0
0
0
0
0
0
0
0
0
o •
0
0
0
7950.
7150.
2743.
0.
1410.
56
0
21
0
100
TOTAL NO.
OF PLANTS
NO. MW
0 0
4 500
0 0
0 0
0
0
0
1
0
0
0
2
0
0
0
0
2
1
0
0
30.
45.
25.
4.
5.

D
0
0
23
0
0
0
1000
0
0
0
0
715
115
0
0
15802.
18322.
6067.
675.
2025.
75
42
63
100
100
  i:  s;g SS^T?. w«aj2°ss sru •™»««^«'«jSi -B
  C.  BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS

  0.  OTHER
  C.  REGULATORY CLASS UNKNOWN
                                                                                    PEDCo-ENVIRONMENTAL
                                                  157

-------
             Table 11



SUMMARY OF OPERATIONAL FGD SYSTEMS
                    159

-------
                      TABLE  11
            SUMMARY OF OPERATIONAL F6D SYSTEMS AS OF 03/76
       UTILITY COMPANY
        POWER STATION
 NEW OR   SIZE OF F60  PROCESS/VENDOR
RETROFIT   UNIT 
 FUEL CHARACTERISTICS
                                HO/YR
ARIZONA PUBLIC SERVICE
CHOLLA NO 1

COMMONWEALTH EDISON
WILL COUNTY NO 1

DUQUESNE LIGHT
PHILLIPS

OUOUESr'E LIGHT
ELKAMA

GENERAL MOTORS
CHEVROLET PARMA 12341

GULF POWER CO.
SCHOLZ NO. 1A

GULF POWER CO.
SCHOLZ NO. 2A

GULF POWER CO.
SCHOLZ NOS. IB & 28

KANSAS CITY POWER & LIGHT
HAWTHORN NO 3

KANSAS CITY POWER ft LIGHT
HAWTHORN NO 4

KANSAS CITY POWER & LIGHT
LA CYGNE NO 1

KANSAS POWER & LIGHT
LAWRENCE NO 4

KANSAS POWER & LIGHT
LAWRENCE NO 5

KENTUCKY UTILITIES
GREEN RIVER   UNITS 1 AND 2

KEY WEST UTILITY BOARD
STOCK ISLAND PLANT
R
R
R
R
R
R
R
R
R
R
N
R
N
R
N
115
167
mo
510
32
20
20
23
140
100
620
125
too
64
37
                      RESEARCH COTTRELL
                      LIMESTONE SCRUBBING

                      BABCOCK & WILCOX
                      LIMESTONE SCRUBBING

                      CHEMICO
                      LIME SCRUBBING

                      CHEMICO
                      LIME SCRUBBING

                      KOCH
                      DOUBLE. ALKALI

                      ADL/COMBUSTION EQUIP ASSOCIATE
                      DOUBLE ALKALI

                      FOSTER WHEELER
                      ACTIVATED CARBON

                      CHIYODA INTERNATIONAL
                      THOROUGHBRED 101

                      COMBUSTION ENGINEERING
                      LIMESTONE INJECTION SWET SCRUB

                      COMBUSTION ENGINEERING
                      LIMESTONE INJECTION &WET SCRUB

                      BABCOCK & WILCOX
                      LIMESTONE SCRUBBING

                      COMBUSTION ENGINEERING
                      LIMESTONE INJECTION 4WET SCRUB

                      COMBUSTION ENGINEERING
                      LIMESTONE INJECTION 4WET SCRUB

                      AMERICAN AIR FILTER
                      LIME SCRUBBING

                      ZURN AIR SYSTEMS
                      LIMESTONE SCRUBBING
COAL   0.44-1 PERCENT SULFUR    10/73
COAL - 9463 BTUt   2.1% SULFUR   2/72
COAL •  i.o- 2.6 PERCENT SULFUR   7/73
COAL  i.o - 2.8 PERCENT SULFUR  10/75
COAL   2.5 PERCENT SULFUR
COAL   3.0 PERCENT SULFUR
COAL   3.0 PERCENT SULFUR
COAL   3.0 PERCENT SULFUR
 3/74
                                 2/75
                                 2/76
                                 3/75
COAL   o.b- 3.0 PERCENT SULFUR  11/72
COAL   0.6- 3.0 PERCENT SULFUR   8/72
COAL   5.2 PERCENT SULFUR
COAL 0.5 PERCENT SULFUR
COAL 0*5 PERCENT SULFUR
COAL  3.6 PERCENT SULFUR
OIL    2.4 PERCENT SULFUR
 2/73


12/68


11/71


 9/75


10/72
                                                              161
                                                                                                      PEDCo- ENVIRONMENTAL

-------
                      TABLE 11
            SUMMARY OF OPERATIONAL FGD SYSTEMS AS OF 03/76
       UTILITY COMPANY
        POWER STATION
 NEW OR   SIZE OF FGD  PROCESS/VENDOR
RETROFIT   UNIT 
                                                                                       FUEL  CHARACTERISTICS
                                                                                      MO/YR
LOUISVILLE GAS ft ELECTRIC           R
PADDYS RUN NO 6

MONTANA POWER CO.                   N
COLSTRIP NO 1

NEVADA POWER                        R
REID GAKDNER NO 2

NEVADA POWER                        R
REID GAKDNER NO 1

PHILADELPHIA ELECTRIC CO.           R
EDDYSTONE NO 1A

PUDLIC SERVICE CO. OF COLORADO      R
VALMONT NO. s

TENNESSEE VALLEY AUTHORITY          R
SHAWNEE N0.10A

TENNESSEE VALLEY AUTHORITY          R
SHAWNEE N0.10B
              65      COMBUSTION ENGINEERING
                      LIME SCRUBBING

             360      COMBUSTION EQUIP. ASSOCIATES
                      LIME SCRUBBING

             125      COMBUSTION EQUIP. ASSOCIATES
                      SODIUM CAKBONATE SCRUBBING

             125      COMBUSTION EQUIP. ASSOCIATES
                      SODIUM CARBONATE SCRUBBING

             120      UNITED ENGINEERS
                      MAGNESIUM OXIDE SCRUBBING

              50      UOP / PUB SERVICE OF COLORADO
                      LIMESTONE SCRUBBING

              10      UNIVERSAL OIL PRODUCTS
                      LIME/LIMESTONE SCRUBBING

              10      CHEMICO
                      LIME/LIMESTONE SCRUBBING
                                                                                      COAL   3.5-4.0  PERCENT  SULFUR      4/73
COAL   0.8 PERCENT SULFUR
10/75
COAL   o.s- i.o PERCENT SULFUR  12/73
COAL   o.s- itO PERCENT SULFUR   4/74
COAL   2.5 PERCENT SULFUR        9/75
COAL  0.72 PERCENT SULFUR       10/74
COAL 2.9 PERCENT SULFUR          4/72
COAL 2.9 PERCENT SULFUR          4/72
                                                                                                         PEDCo-ENVIRONMENTAL
                                                             162

-------
                Table 12
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
                      163

-------
                      TABLE 12
            SUMMARY OF FGO SYSTEMS UNDER CONSTRUCTION AS OF 03/76
       UTILITY COMPANY
        POWEH STATION
 NEW OR   SIZE OF FGO  PROCESS/VENDOR
RETROFIT   UNIT 
 FULL CHARACTERISTICS
MO/YR
ARIZONA PUBLIC SERVICE
FOUR COKNEKS NO. 5A

ARIZONA PUBLIC SERVICE
CHOLLA NO 2

CENTRAL ILLINOIS LIGHT CO.
OUCK CREEK NO.l

COLUMBUS ft SOUTHERN OHIO ELEC.
CONESVILLE NO 5

DETROIT EDISON
ST.CLAIR NO 6

INDIANAPOLIS POWER fc LIGHT CO.
-PETERSBURG NO 3

LOUISVILLE GAS S ELECTRIC
CANE RUN NO 4

LOUISVILLE GAS & ELECTRIC
CANE RUN NO 5

LOUISVILLE GAS ft ELECTRIC
MILL CREEK NO 3

MIMNKOTA POWER COOPERATIVE
MILTON R. YOUNG NO. 2

MONTANA POWER CO.
COLSTKIP NO 2

NEVADA POWER
REID GARDNER NO 3

NORTHERN INDIANA PUB SERVICE
MITCHELL NO 11

NORTHERN STATES POWER CO.
SHERBURfcE NO 1

NORTHERN STATES POWER CO.
SHERBURNE NO 2
R
N
N
N
R
N
R
R
N
N
N
N
R
N
N
160
250
100
HOD
180
S30
176
183
425
450
360
125
115
600
680
                      SCE
                      LIME SCKUBUING

                      RESEARCH COTTRELL
                      L1MLS10NE SCRUBBING

                      RILEY STOKER/ENVIRONEERING
                      LIMESTONE SCRUBBING

                      UNIVERSAL OIL PRODUCTS
                      LIME SCRUBBING

                      PEABODY ENGINEERING
                      LIMESTONE SCRUBBING

                      UNIVERSAL OIL PRODUCTS
                      LIMESTONE SCRUBBING

                      AMERICAN AIR FILTER
                      LIME SCRUBBING

                      COMBUSTION ENGINEERING
                      LIME SCRUBBING

                      AMERICAN AIR FILTER
                      LIME SCRUBBING

                      COMBUSTION EQUIP. ASSOCIATES
                      LIME SCRUBBING

                      COMBUSTION EQUIP. ASSOCIATES
                      LIME SCRUBBING

                      COMBUSTION EQUIP. ASSOCIATES
                      SODIUM CARBONATE SCRUBBING

                      DAVY POWERGAS/ALLIEO CHEMICAL
                      WELLMAN LORD/ALLILD CHEMICAL

                      COMBUSTION ENGINEERING
                      LIMESTONE SCRUBBING

                      COMBUSTION ENGINEERING
                      LIMESTONE SCRUBBING
COALf 0.7 - 0.75. SULFUR (AVG)   2/76
COAL   0.44-1 PERCENT SULFUR     6/77
COAL 2.5-3.0 PERCENT SULFUR
 6/76
COAL  4.5 - 4.9 PERCENT SULFUR   6/76
COAL   3.7 PERCENT SULFUR
 3/76
COAL  3.0-3.5 PERCENT SULFUR     4/77
COAL   3.5-4.05 PERCENT SULFUR   6/76
COAL   3.5-4.05 PERCENT SULFUR  12/77
COAL   3.5- 4.0 PERCENT SULFUR   7/77
LIGNITE - 6.500 8TU. 0.78 S      8/77
COAL   0.8 PERCENT SULFUR        7/76
COAL   0.5- 1.0 PERCENT SULFUR   6/76
COAL   3.2- 3.5 PERCENT SULFUR   4/76
COAL 0*8 PERCENT SULFUR
COAL 0.6 PERCENT SULFUR
 5/76
 5/77
                                                                                                        PEDCo-ENVIRONMENTAL
                                                            165

-------
                      TABLE 12
            SUMWARY OF FGD SYSTEMS UNDER CONSTRUCTION AS  OF  03/76
       UTILITY COMPANY           NEW OR   SIZE OF F60
        POWER STATION           RETROFIT   UNIT (MM)
 PKOCtSS/VENDOR
                                                                                       FUEL  CHARACTERISTICS            MO/YR
PENNSYLVANIA POWEK CO.              N        835
BRUCE MANSFIELD NO. 1

PENNSYLVANIA POWER CO.              N        835
BRUCE MANSFIELD NO. 2

RICKENBACKER AFB                    R         20
RICKENBACKER

SPRINGFIELD CITY UTILITIES          N        200
SOUTHWEST NO. 1

TENNESSEE VALLEY AUTHORITY          R        550
WIDOWS CREEK NO 8
CHEMICO
LIME SCRUBBING

CHEMICO
LIME SCRUBBING

RESEARCH COTTRELL
LIME SCRUBBING

UNIVERSAL OIL PRODUCTS
LIMESTONE SCRUBBING

TENNESSEE VALLEY AUTHORITY
LIMESTONE SCRUBBING
                                                                                      COAL    t.3  PERCENT  SULFUR         4/76
COAL   H.3 PERCENT SULFUR        4/77
COAL   5.0 PERCENT SULFUR        3/76
COAL 3.5 PERCENT SULFUR          7/76
COAL   3*7 PERCENT SULFUR        2/77
                                                                                                        PEDCo-ENVIRONMENlAl
                                                            166

-------
           Table 13
SUMMARY OF PLANNED FGD SYSTEMS
            167

-------
                   TABLE: is
            SUMMARY OF PLANNED FGO SYSTEMS AS OF 03/76
       UTILITY COMPANY
        POWER STATION
 NEW OR   SIZE OF FGO  VENDOR/PROCESS
RETROFIT   UNIT 
-------
                   TABLE 13
            SUMMARY OF PLANNED FGD SYSTEMS AS OF 03/7fe
       UTILITY COMPANY

        POWER STATION
 NEW OR   SIZE OF FGD  VENDOR/PROCESS
RETROFIT   UNIT 
 FUEL  CHARACTERISTICS
MO/YR
NEVADA POWER
REID GARDNER NO 4

PHILADELPHIA ELECTRIC CO.
CDDYSTONE NO IB

ARIZONA ELECTRIC POWER COOP
APACHE NO 3

ARIZONA ELECTRIC POWER COOP
APACHE NO 2

TEXAS UTILITIES CO.
MARTIN LAKE NO. 3

TEXAS UTILITIES CO.
MARTIN LAKE NO. 4

UTAH POWER £ LIGHT CO.
HUNTINGTUN NO.l

PUBLIC SERVICE co OF NEW MEX.
SAN JUAN NO. 4
            REQUESTING/EVALUATING BIDS


PENNSYLVANIA POWER CO.
BRUCE MANSFIELD NO. 3


LOUISVILLE GAS & ELECTRIC
CANE RUN MO 6

CINCINNATI GAS & ELECTRIC CO.
MIAMI FORT NO 6

CENTRAL ILLINOIS PUBLIC SERV
NEWTON NO.l


UNITED POWER ASSOCIATION
COAL CREEK NO. 1


UNITED POWER ASSOCIATION
COAL CREEK NO. 2
N
R
N
N
N
N
N
N
:os
N
R
N
N
N
N
125
240
205
200
793
793
415
500
835
277
300
600
545
545
COMBUSTION EQUIP. ASSOCI/
SODIUM CARBONATE SCRUBBIK
UNITED ENGINEERS
MAGNESIUM OXIDE STUBBING
RESEARCH COTTRELL
LIMES10NE SCRUBBING
RESEARCH COTTRELL
LIMLSTONE SCRUBBING
RESEARCH COTTRELL
LIMESTONE SCRUBBING
RESEARCH COTTRELL
LIMESTONE SCRUBBING
CHEMICO
LIME SCRUBBING
DAVY POWERGAS
WELLMAN LORD
NOT SELECTED
NOT SELECTED
NOT SELECTED
LIME SCRUBblNG
NOT SELECTED
LIME/LIMESTONE SCRUBBING
NOT SELECTED
NOT SELECTED
NOT SELECTED
LIME/LIMESTONE
NOT SELECTED
                                                                                      COAL    o-b-  i.o PERCENT  SULFUR    o/  o
                                                      COAL 2.5  PERCENT  SULFUR
                                10/78
                                                      COAL   o.s-  o.a  PERCENT  SULFUR    6/79
                                                      COAL  0.5-  0*8  PERCENT  SULFUR     6/79
                                                      COAL 1.0 PERCENT  SULFUR          12/78
                                                      COAL 1.0 PERCENT SULFUR         12/79
                                                      COAL  0.5 PERCENT SULFUR          6/77
                                                      COAL 0.8 PERCENT  SULFUR          5/81
                                                      COAL   4.3 PERCENT SULFUR        4/79
                                                      COAL   3.5- 4.0 PERCENT SULFUR   9/78
                                                      COAL   1.3 PERCENT SULFUR
                                 1/78
                                                      COAL 2.8-3.2 PERCENT SULFUR     12/77
                                                      LIGNITE - 0.63 PERCENT SULFUR   11/78
                                                      LIGNITE - 0.64 PERCENT SULFUR   11/79
                      LIME/LIMESTONE
            CONSIDERING FGD SYSTEM
LOUISVILLE GAS g ELECTRIC
MILL CREEK NO 1
             330      NOT SELECTED
                      LIME SCRUBBING
COAL   3.5- 4.0 PERCENT SULFUR   1/82
                                                          170
                                                                                                         PEDGo-ENVIRONMENTAL

-------
                   TABLE 13
            SUMMARY OF PLANNED FGO SYSTEMS AS OF 03/76
       UTILITY COMPANY
        POWER STATION
 NEW OK   SIZE OF FGD  VENDOR/PROCESS
RETROFIT   UNIT CMW>
  FUEL  CHARACTERISTICS
MO/YR
LOUISVILLE GAS & ELECTRIC
MILL CREEK NO 2

CINCINNATI GAS & ELECTRIC CO*
EAST BEND NO 2

CENTRAL ILLINOIS LIGHT CO.
E.D.EDWARDS NO.3

CENTRAL ILLINOIS LIGHT CO.
DUCK CREEK NO.2

BASIN ELECTRIC POWER COOP
BCULAH NO. 1

NEVADA POWER
HARRY ALLEN STATION NO. 
-------
            SUMHAKY OF PLANNED FGD  SYSTEMS  AS  OF  03/76
       UTILITY COMPANY
        POWER STATION
 NEW OR   SIZE OF FGD  VENDOR/PROCESS
RETROFIT   UNIT (MW)
                                                                                      FUEL CHARACTERISTICS
                                                                                     MO/YR
ARIZONA PUBLIC SERVICE
FOUR CORNERS NO. 1

NORTHERN INDIANA PUB SERVICE
BAILLY NO. 8

ALLEGHENY POWER SYSTEM
PLEASANTS NO. 1

PHILADELPHIA ELECTRIC CO.
CROMBY

NORTHERN INDIANA PUB SERVICE
BAILLY NO. 7

NEW ENGLAND ELEC SYSTEM
BRAYTON POINT NO.3

ALLEGHENY POWER SYSTEM
PLEASANTS NO. 2

BASIN  ELECTRIC  POWER COOP
MISSOURI  BASIN  NO 1

BASIN  ELECTRIC  POwER COOP
MISSOURI  BASIN  NO 3

NEVADA POWER
WARNER VALLEY STATION  NO.  2

NEVADA POWER
WARNER VALLEY STATION  NO.  1

PHILADELPHIA  ELECTRIC  CO.
EDDYSTONE NO  2

 ARIZONA PUBLIC SERVICE
 FOUR CORNERS NO.  5B

 SOUTHERN CALIFORNIA EDISON
 KAIPAROWITZ NO. 3

 PUBLIC SERVICE INDIANA
 GXBSON NO. H
R

R

N

R

R

R

N

N

N

N

N

R

R

N

N

755

«fOO

625

150

190

650

625

550

550

250

250

336

595

750

650

NOT SELECTED
NOT SELECTED
NOT SELECTED
NOT SELECTED
NOT SELECTED
LIME SCRUUUING
UNITED ENGINEERS
MAGNESIUM OXIDE SCRUBBING
NOT SELECTED
NOT SELECTED
NOT SELECTED
REGENEKABLE NOT SELECTED
NOT SELECTED
LIME SCRUBBING
NOT SELECTED
NOT SELECTED
NOT SELECTED
NOT SELECTED
NOT SELECTED
NOT SELECTED
NOT SELECTED
NOT SELECTED
UNITED ENGINEERS
MAGNESIUM OXIDE SCRUBBING
NOT SELECTED
NOT SELECTED
NOT SELECTED
LIME SCRUBBING
NOT SELECTED
NOT SELECTED
COALt 0.7 - 0.73* &ULFUN (AVbl

COAL 3 PERCENT SULFUR

COAL 2.0- 5.0 PERCENT SULFUR

COAL 2-H PERCENT SULFUR

COAL 3 PERCENT SULFUR

COAL 3.0 PERCENT SULFUR

COAL 2.0- 5.0 PERCENT SULFUR

COAL

COAL

COAL

COAL

COAL 2.4 PERCENT SULFUR

COAL, 0.7 - 0.75. SULFUR (AVG)

COAL 10,600, BTU, 0.5X S

COAL

u/ u

O/ 0

3/79

10/78

O/ 0

O/ 0

3/80

1/60

6/83

6/62

6/81

10/78

O/ 0

0/84

0/79

                                                          172
                                                                                                            PEDCo- ENVIRONMENTAL

-------
            SUMMARY OF PLANNED FGD SYSTEMS AS OF 03/76
       UTILITY COMPANY
        POWER STATION
PUBLIC SERVICE INDIANA
GIBSON NO. 3

SOUTHERN CALIFORNIA EDISON
KAIPAROWITZ NO. 2

SOUTHERN CALIFORNIA EDISON
MOHAVE NO. 2

SOUTHERN CALIFORNIA EDISON
MOHAVE NO IB

SOUTHERN CALIFORNIA EDISON
KAIPAROWITZ NO. •*

SOUTHERN CALIFORNIA EDISON
KAIPAROWITZ NO. 1
 NEW OR   SIZE OF FGD  VENDOR/PROCESS
RETROFIT   UNIT 
    N        650      NOT SELECTED
                      NOT SELECTED

    N        750      NOT SELECTED
                      LIME SCKUbBING

    R        790      NOT SELECTED
                      LIME/LIMESTONE SCRUBBING

    R        620      NOT SELECTED
                      LIME/LIMESTONE SCRUBBING

    N        750      NOT SELECTED
                      LIME SCRUBBING

    N        750      NOT SELECTED
                      LIME SCRUBBING
                                                                                       FUEL CHARACTERISTICS           MO/YR
                                                                                      COAL. 3.3» SULFUR                0/78
COAL 10.800.BTU. 0.58 S          0/63
COAL   0.5 TO 0.8 X SULFUR       6/77
COAL   0.5- 0.8 PERCENT SULFUR   6/77
COAL 10.800.BTUi 0.58 S
COAL 10.800.BTU. 0.5* S
                                 0/85
                                 0/82
                                                            173
                                                                                                          PEDCo-ENVIRONMENTAL

-------
                        Table 14
SUMMARY LIST OF FGD SYSTEMS IN THE EARLY PLANNING STAGES
                             175

-------
                                        TABLE 11*
             SUMMARY LIST OF FGD SYSTEMS IN THE EARLY PLANNING STAGES

FGD STATUS REPORT 03/76
I.D. NUMBER AND COMPANY NAME          UNIT NAME
                                                                           LOCATION
                                                            START UP DATE   STATUS
                                                                 REG
                                                                 CLASS
    1 UAYTOlM POM£R AND LIGHT CO.
    2 DAYTON POWEK AND LIGHT CO.
    3 GENERAL PUBLIC UTILITIES
    if GENERAL PUBLIC UTILITIES
    5 UULF POWEH CO.
    6 GULF POWER CO.
    7 GULF POWEK CU.
    6 KENTUCKY UTILITIES
    9 POTOHftC ELECTRIC & POWER
   10 POTOMAC ELECTRIC & POWER
   11 POTOMAC ELECTK1C & POWER
   12 POTOMAC ELECTRIC & POWER
   13 POWER AUTHORITY OF NEW YORK
   lit SALT RIVE« PROJECT
   is SALT RIVER PROJECT
   16 SALT RIVEK PROJECT
   17 SPRINGFIELD WATER LIGHT  POWER
   16 TEXAS POWER AND LIGHT CO.
   19 TEXAS POWER AND LIGHT CO.
   20 VIRGINIA ELECTRIC AND POWER CO
KILLEN NO 1
K1LLEN NO 2
CUHO NO.l
SEWAKD NO.7
CKIST NO. t AND NO.
CRIST NO. 6 AND NO.
LANDING SMITH NO. 1
GHENT
CHALK POINT NO. H
DICKERSON NO H
HUKtoANTOWN NO.l
MOR&ANTOWN NO.2
ARTHUR KILL
NAVAJO NO 1
NAVAJO NO 2
NAVAJO NO 3
DALLMAN NO 3
TWIN OAKS NO. 1
TWIN OAKS NO. 2
MT. STORM
           WRIGHTSVILLE OHIO                   1-83       7
           WRIbHTSVILLE OHIO                   1-61       7
           ERIE PENNSYLVANIA            '       5-67       7
           SEWAKD PENNSYLVANIA                 5-64       7
5          PEMSACOLA FLORIDA                   0-78       7
7          PEIVSACOLA FLORIDA                   0-60       7
AND NO. 2  PANAMA CITY FLORIDA                 0-80       7
           GHEitfT KENTUCKY                      1-77       7
           PKINCC GEORGE COUNTY MARYLAND       6-76       7
           DICKEKSON MARYLAND                  5-82       7
           NEWUUKG MARYLAND                    6-79       7
           NEWUUKG hARYLAUD                    6-79       7
           STATEN ISLAND NEW YORK              7-60       7
           PAGE ARUONA                        0-0       7
           PAGE ARIZONA                   .0-0       7
           PAGE ARIZONA    '                   0-07
           SPRINGFIELD ILLINOIS                6-79       7
           ROBERTSON COUNTY  TEXAS             6-60       7
           ROBERTSON COUNTY  TEXAS             9-81       7
           «T. STORM WEST VIRGINIA             0-0       7
                                                                                                                           D
                                                                                                                           D
                                                                                                                           A
                                                                                                                           A
                                                                                                                           B
                                                                                                                           6
                                                                                                                           B
                                                                                                                           E
                                                                                                                           D
                                                                                                                           D
                                                                                                                           C
                                                                                                                           C
                                                                                                                           B
                                                                                                                           D
                                                                                                                           D
                                                                                                                           D
                                                                                                                           A
                                                                                                                           A
                                                                                                                           A
                                                                                                                           C
7. CONSIDERING FGO SYSTEM AS WELL AS ALTERNATIVE METHODS

A.  BOILER CONSTRUCTED SUBJECT TO FEDERAL NSPS
B.  BOILER SUBJECT TO STATE STANDARD THAT is MORE STRINGENT THAN THE FEDERAL NSPS
C.  BOILER SUBJECT TO STATE STANDARD THAT IS EQUAL TO OR LESS STRINGENT THAN NSPS
D.  OTHER
C.  REGULATORY CLASS UNKNOWN
                                                          177
                                                                                                         PEDCO-ENVIRONMENTAL

-------
                     Table 15
STATUS OF FGD SYSTEMS IN THE EARLY PLANNING STAGES
                           179

-------
 COMPANY

 POWER STATION
                     TABLE 15
STATUS OF FGD SYSTEMS IN THE EARLY PLANNING STAGES DURING

                                 CUKKENT MONTH
                                                                                   03/76
I.D. NUMBER    1
DAYTON POWER AND LIGHT CO.
KILLEN NO 1
  600  MM - NEW
COAL
NOT SELECTED
LIMESTONE SCRUBBING
STARTUP'   1/83
              SITE PREPARATION IS UNDERWAY.  COMPANY IS INVESTIGATING LONG TEKM SUPPLY
              OF LOW SULFUR COAL FOK COMPLIANCE WITH REGULATIONS WITHOUT INSTALLING FGD
              SYSTtM. UECISION OH THIS MATTER IS DUE MID 1976. SPACE HAS BEEN RESERVED
              IN THE PLANT LAYOUT FOR FGD SYSTEM IF NEEDED. KILLEN NO.l NOW SCHEDULED
              FOR STARTUP AFTER KILLEN NO.2.
I.D. NUMBER    2
DAYTON POWER AND LIGHT CO.
KILLEN NO 2
  600  MW - NEW
COAL
NOT SELECTED
LIMESTONE SCRUBBING
STARTUP   1/61
              SITE PREPARATION IS UNDERWAY.  COMPANY IS INVESTIGATING LONG TERM SUPPLY
              OF LOW SULFUR COAL FOR COMPLIANCE WITH REGULATIONS WITHOUT INSTALLING FGD
              SYSTEM. DECISION ON THIS MATTER IS DUE MID 1976. SPACE HAS BEEN RESERVED
              IN THE PLANT LAYOUT FOR FGD SYSTEM IF NEEDED.
I.D. NUMBER    3
GENERAL PUBLIC UTILITIES
COHO NO.l
  600  MW - NEW
COAL
NOT SELECTED
NOT SELECTED
STARTUP   5/67
              STARTUP DATE CHANGED TO 5/67 FOR BOTH BOILER AND FGD SYSTEM.  LIME, LIME-
              STONE SCRUBBINGt AND COAL DESULFuRI^ATION ARC THE PRIMARY PROCESSES BEING
              CONSIDERED.  NO DECISION HAS BEEN MADE YET.
I.D. NUMBER    
-------
 COMPANY

 POWER STATION
                     TABLE 15
STATUS OF fGO SYSTEMS IN THE EARLY PLANNING STAGES DURING  03/76

                                 CURRENT MONTH
I.D. NUMBER    £
GULF POWEK CO.
CRIST NO. 6 AND NO. 7
  820  Mk - RETROFIT

NOT SELECTED
NOT SELECTED
STARTUP   0/flO
              UNIT (, IS 320 HW.   UNIT  7 IS  500  Mb.
1.0. NUMBER    7
GULF POUER CO.
LANSING SMITH NO. 1 AND NO.
  305  MW - RETROFIT
COAL
NOT SELECTED
MOT SELECTED
STARTUP   0/80
              UNIT  NO.  1 IS  125  nw.   UNIT  NO.  2  IS  180 MU.   IF  SCRUBBERS  ARC  SELECTED*
              THEY  WILL BE REQUIRED  IN  1979  AND  1980  ON  THE  RESPECTIVE  UNITS.
I.D. NUMBER    a
KENTUCKY UTILITIES
GHENT
  510  MW - NEW
COAL   3-K PERCENT SULFUR
NOT SELECTED
LIME SCRUBBING
STARTUP   1/77
              IN THE  EARLY  PLANNING  STAGE.  COMPANY  ALSO HAS-AN  EXISTING 510 MW UNIT
              AND UNDECIDED ON  WHICH UNIT TO  INSTALL  THE FGO  SYSTEM.
1.0. NUMBER    9
POTOMAC EUECTKIC & POWER
CHALK POINT NO. H
  630  HW - NEW
OIL
NOT SELECTED
NOT SELECTED
STARTUP   b/76
              AWAITING  PERFORMANCE  RESULTS FROM MGO UNIT ON OICKERSON NO. 3  (MONTGOMERY
              COUNTY).   UNIT  WILL HAVE  PEABODY-LURGI 2-STAGE VENTURI SCRUBBERS FOR PAR-
              TICULATE  CONTROL.  COMPANY  MAY ELECT NOT TO  INSTALL FGO SYSTEM  IF USE OF
              LOU  SULFUR OIL  IS  CONTINUED.  BOILER START-UP SCHEDULED FOR LATE 1976.
I.D. NUMBER   10
POTOMAC ELECTRIC & POWER
DICKERSON NO t
  600  nw - NEW
COAL   2.0 PERCENT SULFUR
NOT SELECTED
NOT SELECTED
STARTUP   5/82
              THLRE  ARE  NO  FIRM  PLANS  FOR  INSTALLATION OF FGO SYSTEM.
              BOILER IS  PLANNED  FOR  1982.
STARTUP DATE OF
                                                              182
                                                                                    PEOCo-ENVJRONMENTAL

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  COMPANY

  POWER  STATION
                     TABLE 15
STATUS OF FGD SYSTEMS IN THE EARLY PLANNING STAGES DURING  03/76

                                 CURRENT MONTH
 I.D.  NUMBER    11
 POTOMAC  LLECTRIC  &  POWER
 MORGANTOhN NO.l
   56B MW -  RETROFIT
 COAL
 NOT SELECTED
 NOT SELECTED
 STARTUP   6/79
              THLRE ARE NO FIRM PLANS FOR INSTALLATION OF FGD SYSTEM.
              COMPANY PLANS TO EVALUATE ALL COMMERCIALLY AVAILABLE SOg CONTROL METHODS
              INCLUDING COAL GASIFICATION AND USE. OF LOW SULFUR COAL.  COMPANY IS ALSO
              AWAITING RESULTS OF MGO SYSTEM OPERATION AT THE OICKERSON PLANT. DECISION
              EXPECTED WITHIN A YEAR.
 I.D. NUMBER    12
 POTOMAC ELECTRIC £ POWER
 MORGANTOWN NO.2
   558  MW - RETROFIT
 COAL
 NOT SELECTED
 NOT SELECTED
 STARTUP   6/79
              THERE ARE NO FIRM PLANS FOR INSTALLATION OF FGD SYSTEM.
              COMPANY PLANS TO EVALUATE ALL COMMERCIALLY AVAILABLE  S02 CONTROL  METHODS
              INCLUDING COAL GASIFICATION AND USE  OF LOW SULFUR COAL.   COMPANY  IS ALSO
              AWAITING RESULTS OF MGO SYSTEM OPERATION AT THE DICKERSON PLANT.  DECISION
              EXPECTED WITHIN A YEAR.
I.D, NUMBER    13
POWER AUTHORITY OF NEW YORK
ARTHUR KILL
  700  MM - NEW
COAL - 3% SULFUR - REFUSE
NOT SELECTED
NOT SELECTED
STARTUP   7/80
              THt UTILITY IS  CONSIDERING  BOTH  REGENERABLC  AND  LIMESTONE  SCRUBBING
              PROCESSES.  FGD  IS  BEING  CONSIDERED  FOR  A  FOSSIL  FUEL  BURNING  UNIT  WHICH
              MAY EMPLOY  REFUSE  OR  COAL.  THE PREFERRED  INSTALLATION SITE IS THE  ARTHUR
              KILL FACILITY LOCATED ON STATEN  ISLAND. THE  PROJECT DESIGN ENGINEERS ARC
              SARGENT  AND LUNDY.
I.D. NUMtiER   m
SALT RIVLR PROJECT
NAVAJO NO 1
  750  I"!U - RETROFIT
COAL   0.45 PERCENT SULFUR
NOT SELECTED
LIME/LIMESTONE SCRUBBING
STARTUP   O/ 0
              THE  UTILITY  IS  PRESENTLY  INVESTIGATING  THE  USE  OF  LOW  SULFUR COAL AND
              DESULFURIZATION PROCESSES.  A  DEFINITIVE DECISION WILL  BE MADE PENDING
              COMPLETION OF THL  SRP/EPA STUDY. NO  SPECIFIC  STARTUP DATE HAS YET BEEN
              SPECIFIED.
I.D. NUMBER   15
SALT RIVER PROJECT
NAVAJO NO 2
  750  MW - RETROFIT
COAL   0.45 PERCENT SULFUR
NOT SELECTED
LIME/LIMESTONE SCRUBBING
STARTUP   O/ 0
              THE UTILITY  IS PRESENTLY  INVESTIGATING THE USE OF LOW SULFUR COAL AND
              DESULFURIZATION PROCESSES. A DEFINITIVE DECISION WILL BE MADE PENDING
              COMPLETION OF THE SRP/tPA STUDY. NO SPECIFIC STARTUP DATE HAS YET BEEN
              SPECIFIED.
                                                              183
                                                                                                              PEDCo- ENVIRONMENTAL

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 COMPANY

 POWER STATION
                                             TABLE 15
                        STATUS OF FGD SYSTEMS IN THE EARLY PLANNING STAGES DURING
                                             03/76
                   CURRENT MONTH
I.D. NUMBER   16
SALT RIVER PROJECT
NAVAJO NO 3
  750  MW - RETROFIT
COAL   0.«»J> PERCENT SULFUR
NOT SELECTED
LIME/LIMESTONE SCRUBBING
STARTUP   O/ 0

I.D. NUMUER   17
SPRINGFIELD WATER LIGHT  POWER
DALLMAN NO 3
  190  MW - NEW
COAL   3.0- 4.3 PERCENT SULFUR
NOT SELECTED
NOT SELECTED
STARTUP   6/79

I.D. DUMBER   16
TEXAS POWER AND LIGHT CO.
TWIN OAKS NO. 1
  750  MW - NEW
LIGNITE
NOT SELECTED
NOT SELECTED
STARTUP   6/60

I.D. NUMBER   19
TEXAS POUER AND LIGHT CO.
TWIN OAKS NO. 2
  750  MW - NEW
LIGNITE
NOT SELECTED
NOT SELECTED
STARTUP   9/61

I.D. NUM6ER ' 20
VIRGINIA  ELECTRIC AND POWER  CO
MT.  STORM
  11H7  MW - RETROFIT
COAL
NOT SELECTED
NOT SELECTED
STARTUP    O/  0
 THE. UTILITY  IS PRESENTLY  INVESTIGATING THE USE OF LOW SULFUR COAL  AND
 DESULFUH1ZATION PROCESSES. A DEFINITIVE DECISION WILL BE MADE PENDING
 COMPLETION OF THE  SRP/EPA STUDY. NO  SPECIFIC STARTUP DATE HAS YET  BEEN
 SPECIFIED.
 FGO  SYSTEM  IS  UNUER  CONSIDERATION  WITH BOTH REGENERABLE  AND  LIMESTONE
 SCRUBBING BEING  CONSIDERED.   BECAUSE  OF  SPACE  LIMITATIONS A  REGENERABLE
 SYSTEM  IS THE  LIKELY CHOICE.   THE  COMPANY  IS ALSO  CONSIDERING  COMPLIANCE
 THROUGH BURNING  OF LOW  SULFUR WESTERN COAL.
"THIS UNIT WILL BE JOINTLY  OWNED-BY .TP«L  AND  ALCOA.
 NOT BEEN MADE WHETHER TO INSTALL FGO FACILITIES.
A FIRM DECISION HAS
"THIS'UNIT WILL BE JOINTLY OWNED BY TP»L AND ALCOA.
 NOT BEEN MADE WHETHER TO INSTALL FGD FACILITIES.
A FIRM DECISION HAS
 THE UTILITY IS PRESENTLY CONSIUERENG BOTH DESULFURIZATION AND THE USE OF
 LOW SULFUR COAL. A DESULFURIZATION SYSTEM WOULD TREAT 69 PERCENT OF THE
 FLUE GAS FROM THREE BOILERS. CONSTRUCTION AND STARTUP DATES ARE CON-
 SIDERED INDEFINITE AT THIS TIME.
                                                               184
                                                                                                            PEDCo-ENVIRONMENTAL

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                                 Table 16
F6D SYSTEM OPERATIONS  THAT HAVE BEEN TERMINATED  OR  SHUT DOWN INDEFINITELY
                                  185

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                   Table 16
TERMINATED OPERATIONAL F6D SYSTEMS 2/76
 IDENTIFICATION NO.
 UTILITY NAME
 UNIT NAME
 UNIT LOCATION
 UNIT RATING
 FUEL CHARACTERISTICS
 F6D VENDOR
 PROCESS
 NEW OR RETROFIT
 START UP DATE
 F6D STATUS
 EFFICIENCY.
  PARTICULATES

  S02
 WATER MAKE UP
 SLUDGE DISPOSAL
 UNIT COST
  OPERATIONAL
   EXPERIENCE
   1
BOSTON EDISON
MYSTIC NO 6
EVERETT MASSACHUSETTS
  150 MW
OIL    2.5 PERCENT SULFUR
CHEMICO
MAGNESIUM OXIDE  SCRUBBING
RETROFIT
  4/72
OPERATIONAL

50 PERCENT

90 PERCENT
S32/KW CAPITAL + CALCINATION

 AVERAGE FGD SYSTEM AVAILABILITY FACTORS - APRIL 72 TO MAY 73.  17*.
 JUNE 73 TO DEC. 73. *6X.  JAN. 7* TO JUNE 7H.  60%.  JUNE 7*.  60K.
 THE FGD SYSTEM HAS .BEEN SHUT DOWN INDEFINITELY SINCE JUNE 7*.
                                                                                                 PEDCo-ENVlfcONMENTAL
                                                              187

-------
                                                      BACKGROUND  INFORMATION
                                                               ON
                                               THE  MYSTIC  POWER STATION.  UNIT  NO.  6

     THE MAGNESIUM OXIDE FGD SYSTEM AT BOSTON EDISON CONSISTS  OF  A  CHENICO  SINGLE-STAGE. VENTURI  SCRUBBER.  THE SCRUBBER UNIT
IS CONSTRUCTED OF CARBON STEEL WITH A SPRAY APPLIED POLYESTER  LINING.   THE  SCRUBBER  TREATS  440,000 ACFM OF 300°F  FLUE GAS CON-
TAINING S02 CONCENTRATION OF 1410 PPM.  S02 REMOVAL EFFICIENCY IS REPORTED  TO  BE 90  PERCENT.
     THE MgO PROCESS IS A REGENERABLE PROCESS.   THE SCRUBBER CAPTURES  S02 BY FORMATION  OF MAGNESIUM  SULFITE.  THIS PRODUCT
SLURRY IS THEN FILTERED AND DRIED.   THE DRY MATERIAL IS  THEN CALCINED  AT  HIGH  TEMPERATURES  TO  DRIVE  OFF THE S02 AND REGENERATE
MgO.  THE S02 STREAM IS THEN PROCESSED IN A SULFURIC ACID  PLANT OT  MAKE 98  PERCENT ACID.
PROBLEMS AND SOLUTIONS
     FROM THE INITIAL START-UP IN APRIL 1972 TO MAY 1973,  THE  SCRUBBER OPERATED INTERMITTENTLY DUE TO MECHANICAL  DIFFICULTIES.
THE MAJOR PROBLEM BEING THE DESIGN  AND OPERATION OF MgSOj  CRYSTAL DRYER.  REDEISGN AND  FUEL CHANGE APPEAR TO HAVE SOLVED THESE
PROBLEMS.  STACK AND PUMP PROBLEMS  OCCURRED DURING  THE USE OF  REGENERATED MgO.  SCALE WAS FORMED IN  THE MgO SLURRY PIPING DUE
TO OVERHEATING OF THE SLURRY DURING ACTIVATION  OF THE STEAM FREEZE  PROTECTION  SYSTEM.   IN 1974,  THE  SYSTEM OPERATION WAS
LIMITED BY BOILER UNAVILABILITY.   SINCE FEBRUARY 1974, AVAILABILITY TO THE  BOILER  HAS BEEN  INCREASED.  THE SYSTEM HAS BEEN
SHUTDOWN INDEFINITELY SINCE JUNE  1974 WHEN EPA  FUNDS EXPIRED FOR  THE CALCINING PORTION  OF'THIS OPERATION.
     THE AVAILABILITY FACTORS FOR THE SYSTEM SINCE  START-UP. ARE  PRESENTED  IN  THE  FOLLOWING TABLE.
                                                                                                     PEDCo-ENVIRONMENTAL
                                                            188

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Month Availability (X)
Apr.
May
June
Jul.
Aug.
Sep.
Oct.
Nov.
Dec.
Jan.
Feb.
Mar.
Apr.
Nay.
Jun.
72 to
73
. 73
73
73
73
73
73
73
74
74
74
74
74
74
17

68
61

38
60
26
13
28
25
87
81
57
80
                                               FGD SYSTEM AVAILABILITY
                                                  MYSTIC UNIT NO. 6

                                                    Comments
                                     The module operate Intermittently due to mechanical  difficulties.   One major problem
                                     being the design and operation of the magnesium sulflte crystals dryer.
                                     The boiler was down for the.annual  overhaul  outage.   System availability  decreased
                                     during the last quarter of the year due to heavy erosion/corrosion  attach which  was
                                     experienced 1n the liquor redrculatlon pumps and centrifuge.
                                     Systems availability was limited by boiler related problems  which  caused  frequent
                                     shutdowns'  In January and February.
                                     572 availability due to 2 weeks acid plant outage.   Not  due  to  FGD  system  failure.
                                     Demonstration program was completed and FGD system  was shut  down.   EPA  funding of
                                     MgSOj calcination has expired.-  There are no definite plans  for restarting of this  unit.
Average Availability (Jan - June, 1974) • 59.7 Percent.
                                                                                     PEDCo-ENVIRONMENTAL
                                                         189

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                            Table 16
  T-ERMINATED  OPERATIONAL FGD SYSTEMS .2/76
IDENTIFICATION NO.
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
                     OAIRYLAND POWER COOP
                     ALMA STATION
                     AI."A WISCONSIN
                        80 «**
FUEL CHARACTERISTICS  COAL   3.0- 3.5 PERCENT SULFUR
F60 VENDOR
PROCESS
NEW OR RETROFIT
START UP DATE
F6D STATUS
EFFICIENCY.
 PARTICIPATES

 S02
                      FOSTER WHEELER
                      LIME  INJECTION
                      RETROFIT
                       6/71
                      OPERATIONAL
                      83 PERCENT
WATER MAKE UP
SLUDGE DISPOSAL
UNIT COST
 •SS5SS
  EXPERIENCE
                                  ORU
                      SINCE 1971      t  UESTERN LOU  SULFUR COAL.  THE TEST SHOWED ABOUT SOI
                      S02 REMOVAL EFFICIENCY.  BUT PRECIPITATOR PERFORMANCE WAS ADVERSELY
                      AFFECTED.  THE FGD PROJECT HAS  BEEN SHUT DOWN INDEFINITELY SINCE
                      AUGUST 1974, AND THERE ARE NO PLANS FOR FUTURE OPERATION.
                                                                                                      PEDCo-ENVIRONMENTAL
                                                        190

-------
                     Table 16
TERMINATED OPERATIONAL FGO SYSTEMS 2/76
  IDENTIFICATION  NO,

  UTILITY  NAME
  UNIT  NAME
  UNIT  LOCATION
  UNIT  RATING
ILLINOIS POWER

WOOD RIVER NO  EXCHANGER LEAKS HAVE BEEN ENCOUNTERED, AND AN
 EVALUATION IS NOW BEING MADE TO DETERMINE WHETHER TO REPLACE  THE  HEAT
 Ett^cE? OR TO REPAIR IT. THE SYSTEM is SHUT DOWN INDEFINITELY AT
 PRESENT.
                                                                                                          PEDCo-ENVIRONMENTAL
                                                           191

-------
                                                 BACKGROUND  INFORMATION
                                                          ON
                                                    WOOD  RIVER  NO.  4

     THE WOOD RIVER NO. 4 BOILER IS LOCATED  NEAR EAST  ALTON, ILLINOIS. NORTH  OF  ST.  LOUIS.   THE  BOILER  HAS A  RATED
CAPACITY OF 110 MW.  IT IS RETROFITTED WITH  CATALYTIC  OXIDATION FGD SYSTEM  WHICH IS  DESIGNED BY  MONSANTO  ENVIRO-
CHEM SYSTEMS.  THE SYSTEM TREATS THE FLUE GAS FROM THE HIGH  EFFICIENCY ELECTROSTATIC PRECIPITATOR.
     IN THIS SYSTEM. THE FLUE GAS IS HEATED  TO A TEMPERATURE OF 850»F AND  IS  PASSED  THROUGH  A VANADIUM  PENTOXIDE
FIXED BED CATALYTIC CONVERTER WHERE SOg IS OXIDIZED TO S03.   THE GAS THEN  FLOWS  THROUGH AN ACID  ABSORPTION TOWER
WHERE THE SULFUR TRIOXIDE IN THE GAS CONVERTS TO SULFURIC ACID.  AN ACID MIST ELIMINATOR ENSURES THE REMOVAL  OF ENTRAINED
ACID MIST FROM THE GAS STREAM.  THE CLEANED GAS IS DISCHARGED TO THE  STACK AND THE PRODUCT ACID  IS  COOLED AND STORED
IN TANKS.
PROBLEMS AND SOLUTIONS
     SINCE COMPLETION OF THE SYSTEM IN JULY OF 1972. A SERIES OF MECHANICAL DIFFICULTIES HAS OCCURRED AND MODIFICATIONS
HAVE BEEN EFFECTED.  DURING JULY OF 1973. AN ACCEPTANCE TEST WAS CONDUCTED TO ESTABLISH THE  SPECIFIED 85  PERCENT
SULFUR  DIOXIDE REMOVAL, WHILE PRODUCING AN ACID PRODUCT OF REQUIRED CONCENTRATION OF 77.7 PERCENT.   BOTH  OF  THESE
SPECIFICATIONS WERE MET DURING THAT TEST.
     LONG TERM OPERATION OF THE SYSTEM HAS BEEN DELAYED DUE TO DELAYED DELIVERY OF EQUIPMENT FOR A PLANNED  SYSTEM
MODIFICATION OF CONVERTING THE REHEATER  BURNERS FROM NATURAL GAS TO FUEL OIL.  SEVERAL MAJOR PROBLEMS INCLUDE FROZEN
DAMPERS ON  REHEAT  BURNERS. CRACKS  IN  THE TEFLON LINER ON THE ACID  PUMP'S DISCHARGE HEADER. CRACKS IN THE  REHEAT DUCTING.
FALL OF REFRACTORY BRICKS FROM THE  REHEATER  BURNER  DOME AND THE NEED FOR REINFORCEMENT OF THE STRUCTURE SUPPORTING
THE HIGH TEMPERATURE FLUE GAS DUST  TO THE CATALYTIC CONVERTER.  MOST OF THESE PROBLEMS HAVE BEEN CORRECTED.   AT THE
PRESENT TIME  ILLINOIS  POWER AND  EPA ARE  DETERMINING HOW TO  CORRECT LEAKING ACID COOLERS.  PATCHING ATTEMPTS HAVE
BEEN UNSUCCESSFUL.  REPAIR OR REPLACEMENT OF THE  COOLERS  IS EXPECTED TO TAKE  SEVERAL MONTHS.
                                                                                                   PEDCo- ENVIRONMENTAL
                                                        192

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                          OPERATING  LOG
                   CATALYTIC OXIDATION SYSTEM
              WOOD  RIVER  NO. 4  -  ILLINOIS POWER CO.

                                              SYSTEM OPERATING
  DATE                                              HOURS
 9-4-72                                               12
 9-5-72                                               24
 9-6-72                                               24
 9-7-72                                                2
 9-10-72                                               6
 9-11-72                                               2
 9-12-72                                              16
 9-13-72                                              24
 9-14-72                                              24
 9-15-72                                              24
 9-16-72                                              24
 9-17-72                                              24
 9-18-72                                              24
 9-19-72                                               3   ,
 9-24-72                                              17
10-6-72                                               12
10-7-72                                               24
10-8-72                                               24
10-9-72                                               24
10-10-72                                              18
10-12-72                                              16
10-13-72                                              20
                                                                             PEDCo-ENVIRONMENTAL
                                I ,7
-------
OPERATING LOG (continued)
                             DATE
                            10-14-72
                            10-30-72
                            10-31-72
                             7-21-73
                             7-22-73
                             7-23-73
                             7-24-73
                             7-25-73
                             7-26-73
                             7-27-73
                             7-28-73
                             7-29-73
                             TOTAL
SYSTEM OPERATING
     HOURS
       16
       24
       16
       18
       24
       18
       24
       14
       13
       19
       19
       _£
      602 HOURS
                                                            194
                                                                                                     PEDCo-ENVIRONMENTAL

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                  Table 16
  TERMINATED OPERATIONAL FGD SYSTEMS 2/76
IDENTIFICATION NO.

UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
 POTOMAC ELECTRIC ft POWER'

 DICKERSON NO 3

 OICKERSON MARYLAND

   93 MW
FUEL CHARACTERISTICS  COAL   2.0 PERCENT SULFUR
FGD VENDOR

PROCESS

NEW OR RETROFIT

START UP DATE

FGD STATUS

EFFICIENCY!
 PARTICULATES
 CHEMICO

 MAGNESIUM OXIDE SCRUBBING

 RETROFIT

  9/73

 OPERATIONAL
 502
 90 PERCENT
WATER MAKE UP
SLUDGE DISPOSAL
UNIT COST
OPERATIONAL
 EXPERIENCE
S70/KW CAPITAL
 REFER TO BACKGROUND INFORMATION SECTION IN TABLE 16 OF  THIS  REPORT. THIS
 FGD SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER 1973.  THE UNIT HAS BEEN
 TERMINATED AS AN S02 SCRUBBER. HOWEVERtIT WILL CONTINUE  TO  OPERATE AS A
 PARTICULATE SCRUBBER.
                                                                                                         PEDCo-tftvmONMENTAL
                                                          195

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                                                                    BACKGROUND INFORMATION
                                                                             ON
                                                                        DICKERSON NO. 3

     THE DICKERSON STATION OF POTOMAC ELECTRIC POWER CO.  (PEPCO) IS LOCATED ON THE POTOMAC RIVER OUTSIDE THE TOWN OF DICKERSON.  MARYLAND,
ABOUT 30 MILES NORTHWEST OF WASHINGTON,  D.C.   THE  STATION CURRENTLY HAS THREE ELECTRIC GENERATORS EACH RATED AT 190 MW.   UNIT NO.  3  IS  A
DRY BOTTOM COAL-FIRED BOILER THAT WAS DESIGNED BY  COMBUSTION ENGINEERING AND INSTALLED IN 1962.  THE COAL PRESENTLY BURNED HAS AN  AVERAGE
GROSS HEATING VALUE OF 11,700 BTU/LB, AVERAGE ASH  AND  SULFUR CONTENTS ARE 14 AND 2 PERCENT, RESPECTIVELY.  THE BOILER IS FITTED  WITH AN
ELECTROSTATIC PRECIPITATOR DESIGNED AND  INSTALLED  BY RESEARCH - COTTRELL IN 1962.  THE FGD SYSTEM INSTALLED EMPLOYS THE  CHEMICO-BASIC
MAGNESIUM OXIDE SCRUBBING PROCESS.  THE  RETROFIT SYSTEM HANDLES APPROXIMATELY 5W OF THE EXHAUST GAS FROM THE 190 MW NO. 3 UNIT.
     THE FGD SYSTEM CONSISTS OF A SINGLE, TWO-STAGE SCRUBBER/ABSORBER WHICH INCORPORATES AN ADJUSTABLE THROAT VENTURI SCURBBER FOR PARTICU-
LATE REMOVAL AND A SECOND STAGE ABSORBER USING A FIXED VENTURI CONFIGURATION TO REMOVE SULFUR DIOXIDE.  THE LIQUOR STREAMS FOR BOTH STAGES
ARE SEPARATE AND OPERATE IN A CLOSED LOOP MODE. UNTIL  MID-1975 MAGNESIUM SULFITE GENERATED WAS TRANSFERRED TO AN EPA FINANCED FACILITY  AT
THE ESSEX CHEMICAL COMPANY SULFURIC ACID MANUFACTURING PLANT  IN RUMFORD, RHODE ISLAND, WHERE MAGNESIUM OXIDE WAS REGENERATED AND SOg FROM
THE REGENERATION PROCESS WAS CONVERTED TO SULFURIC ACID.  THE RUMFORD FACILITY HAS SINCE BEEN CLOSED DOWN.
     SYSTEM CONSTRUCTION WAS COMPLETED IN AUGUST AND STARTED  UP IN SEPTEMBER 1973.   INTERMITTENT OPERATIONS FOR SHAKEDOWN PURPOSES PROCEEDED
THROUGH JANUARY,1974  , WITH THE LONGEST CONTINUOUS RUN DURING THIS OPERATION PHASE BEING 271 HOURS.  THE SYSTEM WAS AGAIN RESTARTED FROM
JULY 1974 THROUGH DECEMBER 1974, AND AGAIN AUGUST  11,  1975  FOR APPROXIMATELY 87 HRS.
     FGD UNIT OUTAGES WERE PRIMARILY CAUSED BY PIPE AND PUMP  CORROSION  PROBLEMS AND  MAJOR TURBINE OVERHAUL OF THE BOILER.  HOWEVER. PARTICULATE
AND S02 REMOVAL EFFICIENCY GUARANTEES HAVE BEEN COORROBERATED DURING OPERATIONAL  PHASES.
     THE REMAINING SUPPLY OF MAGNESIUM OXIDE, ABOUT 100 TONS  (10  DAYS). HAS BEEN  DEPLETED AND THE DICKERSON UNIT HAS BEEN TERMINATED AS AN S02
SCRUBBER.
                                                                                                                         PEDCo-ENVIRONMENTAL
                                                                              196

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                  Table  16
 TERMINATED OPERATIONAL  FGD SYSTEMS 2/76
IDENTIFICATION NO.

UTILITY NAME

UNIT NAME

UNIT LOCATION

UNIT RATING
SOUTHERN CALIFORNIA EDISON

MOHAVE NO 1A

LAUGHLIN NEVADA

 170 MW
FUEL CHARACTERISTICS  COAL   0.5- 0.8 PERCENT SULFUR
FGD VENDOR

PROCESS

NEW OR RETROFIT

START UP DATE

FGD STATUS
EFFICIENCY.
 PARTICULATES

 S02

WATER MAKE UP

SLUDGE DISPOSAL
UNIVERSAL OIL PRODUCTS

LIMESTONE SCRUBBING

RETROFIT
OPERATIONAL
 UNIT  COST
 OPERATIONAL
  EXPERIENCE
 THIS  EXPERIMENTAL MODULE  STARTED UP OCT. 31.  197* AND OPERATED WITH AN
 AVAILABILITY  OF  60.4»  THROUGH FOUR MONTHS OF  TESTING.  TESTS HAVE BEEN
 COMPLETED,  AND THE FGD SYSTEM WAS SHUT DOWN INDEFINITELY ON JULY 2. 1975.
 NEVADA ASSEMBLY  BILL NO.  708 HAS PLACED A 2-YEAR MORATORIUM ON THE
 ENFORCEMENT OF THE COMPLIANCE SCHEDULE FOR THIS STATION.  FURTHER FGO
 ACTIVITIES  WILL  BE DEPENDENT ON FUTURE LEGISLATION.
                                                                                                     PEOCo-
                                                              197

-------
                                             Mohave No.  1A -  Vertical  Module
               Operating hours     F6D System
                 	B system    availability     	Comments
F6E
                       234            46            FGD outages  -  station  request,  36  hours;  Inspection, 55 hrs. fix
                                                    sphere migration  problem,  333 hrs;  other  outages,  31 hrs.
Dec. 74   606          237            39            FGD OUTAGES  -  station  request,  140  hrs; fix  sphere migration problem,
                                                    197 hrs;  Inspection  and  sphere  redistribution,  45  hrs/repa1r trap  -
                                                    out try leakage,  120 hrs;  booster  fan  false  trip,  5  hrs.
Jan. 75   514          402            78            FGD OUTAGES  -  station  request,  38  hrs  - generator  down. 158 hrs;
                                                    Inspection and nozzle  cleaning. 35  hrs; booster fan  trips. 30  hrs;  Install
                                                    slurry piping  strains, 9 hrs; Inspection  and presaturatlon repair,  72  hrs.
Feb. 75   480          401            84            FGD OUTAGES  -  Modify and repair presaturator slurry  nozzles, 37  hrs;
                                                    unplug thickener  underflow piping,  46  hrs;  generator down, 188 hrs.
                                                                                                  PEOCo- ENVIRONMENTAL
                                                               198

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               Table 16
TERMINATED OPERATIONAL FGD SYSTEMS  12/75
IDENTIFICATION NO.          6
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
FUEL CHARACTERISTICS
FGD VENDOR
PROCESS
NEW OR RETROFIT
START UP  DATE
FGD STATUS
 EFFICIENCY.
  PARTICULATES
  so2
 MATER MAKE  UP
 SLUDGE DISPOSAL
 UNIT  COST
 OPERATIONAL
  EXPERIENCE
SOUTHERN CALIFORNIA EDISON
MOHAVE NO. 2A
LAUGHLIN NEVADA
160 MW
COAL   0.5- 0.8 PERCENT SULFUR
SCE/ STEARNS ROGER
LIME SCRUBBING
RETROFIT
11/73
OPERATIONAL


90  PERCENT
370 GAL/LB MOLE S02  REMOVED
STABILIZED SLUDGE  DISPOSED  IN  UNLINED  POND
 SINCE STARTUP  OF  FORMAL  TEST  PROGRAM  ON  JANUARY  16, W74,AND  UP TO  DECEMBER 20, W74, THIS EXPERIMENTAL
 HORIZONTAL MODULE OPERATED  5280 HRS.  WITH  AN  OVERALL  AVAILABILITY  OF  77.4 PERCENT. S02 REMOVAL
 EFFICIENCY WAS 90 IN FLUE GAS TO SIMULATE  CONDITIONS  FROM  COMBUSTION  OF  HIGH  SULFUR COAL.  THIS FGD
 IVSTFM OPERATED FROM NOVEMBER 1973  UNTIL FEBRUARY  1975.  FGD PLANS AT THIS STATION WILL BE BASED
 oJ INFORMATION THAT INCLUDES  OPERATIONAL DATA THAT HAVE  BEEN OBTAINED DURING  THE  FGD TEST PROGRAMS
 AT THE HOHAVE  STATION?  THE PHOTOTYPE SYSTEM  AT  MOHAVE  IS  NOW BEING DISMANTLED AND IS BEING SHIPPED
 TO THE FOUR CORNERS PLANT.  OPERATED BY ARIZONA PUBLIC.SERVICE. FOR INSTALLATION.
                                                                                                      PEDCO-ENV1RONMENTAL
                                                                  199

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                                       BACKGROUND  INFORMATION
                                                 ON
                                   MOHAVE  POWER  STATION UNIT NO. 2A
      THE MOHAVE POWER STATION IS LOCATED ABOUT  TWO MILES  FROM LAUGHLIN,  IN  CLARK COUNTY.  NEVADA.   AT
 PRESENT, MOHAVE HAS TWO 790 MW RATED CAPACITY COAL FIRED  BOILERS.   THE-COAL BEING BURNED  HAS AN  AVERAGE
 HEATING VALUE OF 9250 BTU PER POUND AND ASH AND SULFUR CONTENTS OF 10 AND 0.40 PERCENT RESPECTIVELY.   	
 UNIT 2 AT MOHAVE IS RETROFITTED WITH A 160 MW CAPACITY LIME BASE FGD SYSTEM.
      THE SCRUBBER WHICH IS A HORIZONTAL MODULE, WAS DESIGNED BY SOUTHERN CALIFORNIA EDISON.   ITS INITIAL
 START-UP WAS IN NOVEMBER 1973.  THE SYSTEM TREATS ABOUT 420,000 ACFM, WHICH IS 20 PERCENT OF THE TOTAL   	
 FLUE GAS FROM THE BOILER.  THE SYSTEM WHICH  IS A CLOSED-LOOP SYSTEM; HAS A SCRUBBER WITH FOUR COUNTER-
 CURRENT STAGES.  THIS  SCRUBBER  IS MADE UP OF A DEMISTER AND AN  INDIRECT HEAT EXCHANGER.
      PARI OF JHE SLURRY__FROM_TH_E_SYSTEM  IS THICKENED  IN A CLARIFIER AND PUMPED TO A LINED DISPOSAL P.ON_D_,	
 WHERE  IT IS  ALLOWED  TO SETTLE.  SUPERNATANT  WATER  FROM THE POND IS  RECIRCULATED TO THE SCRUBBERS.

 PROBLEMS AND SOLUTIONS
       NO MAJOR  PROBLEMS WERE  ENCOUNTERED  DURING THE OPERATION.   THE  MINOR ONES  MENTIONED  ARE  PLUGGAGE  IN    	
" THE  LIME SLAKER, A SLIGHT  SCALE BUILD  UP ON  THE  DEMISTERS  AND  FAN  VIBRATIONS.   IN ORDER  TO  SOLVE  THE
 ABOVE  PROBLEMS, THE  MAKE  UP  WATER  SOURCE WAS CHANGED, THE  CONTINUOUS  SPRAY WASH  WAS CHANGED TO  DELUGE
_ INTE_RMITTE_NT_ SPRAY,_TH_E  DE_MISTER WAS REINFORCED  AND  REALIGNMENT OF FAN  WAS CORRECTED.  OTHER PROBLEMS  	
"WERE DAMAGE TO ONE OF'THE"SHUT OFF VALVES, PLUGGAGE  OF THE CLARIFIER OUTLET DUE  TO ACCIDENTAL DROP OF A

  HARD HAT AND EROSION DAMAGE  OF PIPES.
       THE OVERALL AVAILABILITY OF THE SYSTEM FROM JANUARY 16, 1974 TO DECEMBER 20, 1974 HAS  BEEN 77.4 PERCENT.
                                                                                                PEDCo-ENVIRONMENTAL
                                                       200

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                  Table 16
  TERMINATED OPERATIONAL FGD SYSTEMS  2/76

                       7
IDENTIFICATION NO.
UTILITY NAME
UNIT NAME
UNIT LOCATION
UNIT RATING
                      TENNESSEE VALLEY AUTHORITY

                      SHAMNEE NO. 10.C

                      PAOUCAH KENTUCKY

                        10 MW
FUEL CHARACTERISTICS  COAL 2.9 PERCENT'.SULFUR
FGD VENDOR

PROCESS

NEW OR RETROFIT

START UP DATE

FGD STATUS

EFFICIENCY,
 PARTICULATES


 S02


WATER MAKE UP


SLUDGE DISPOSAL


UNIT COST
                      TENNESSEE VALLEY AUTHORITY

                      LIME/LIMESTONE SCRUBBING

                      RETROFIT

                       H/72

                      OPERATIONAL
OPERATIONAL
 EXPERIENCE
                      REFER TO BACKGKOUND INFORMATION SECTION IN TABLE 16 OF THIS KEPOKT.  THIS
                      FGU SYSTEM HAS litlEN OPERATIONAL SINCE APRIL. 1972.  THIS MARBLE-BED AB-
                      SORBER,  MANUFACTURED BY COMBUSTION ENGINEERING CO.,  WAS DISCONTINUED
                      EARLY IN THE TEST PROGRAM BECAUSE OF CONTINUED OPERATING PROBLEMS WITH
                      NOZZLE FAILURE AND SUBSEQUENT PLUGGING OF THE MARBLE BED.  THIS SYSTEM
                      BECAME OPERATIONAL IN APRIL 1972 AND WAS PERMANENTLY TERMINATED IN
                      JULY 1973.
                                                                                                         PEDCo- ENVIRONMENTAL
                                                               201

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                                                 BACKGROUND  INFORMATION
                                                          ON
                                             SHAWNEE  NOS.  IDA,  10B.  AND  IOC
     IN JUNE. 1968. THE EPA INITIATED A PROGRAM TO TEST  PROTOTYPE  WET  LIME  AND  LIMESTONE  SCRUBBING  SYSTEMS  FOR  THE  REMOVAL
OF SULFUR DIOXIDE AND PARTICULATES FROM FLUE GAS.   THE PROGRAM WAS INITIATED  AND  CARRIED  OUT  IN  A TEST  FACILITY WHICH  WAS
INCORPORATED INTO THE FLUE GAS DUCT WORK OF UNIT NO.  10. A COAL-FIRED  BOILER  AT THE  TVA SHAWNEE  POWER STATION.  PADUCAH.
KENTUCKY.  TVA IS THE CONSTRUCTOR AND FACILITY OPERATOR  AND THE BECHTEL CORP.  IS  THE MAJOR CONTRACTOR AND TEST  DIRECTOR.
     THE TEST FACILITY CONSISTS OF THREE PARALLEL SCRUBBER SYSTEMS OF  PROTOTYPE SIZE TREATING PART  OF THE FLUE  GAS  FROM  THE
BOILER.  EACH SCRUBBER TRAIN IS CAPABLE OF TREATING APPROXIMATELY  30.000 ACFM OR  THE EQUIVALENT  OF  APPROXIMATELY 10 MW OF
POWER PLANT GENERATING CAPACITY.
     THE THREE PARALLEL WET SCRUBBER SYSTEMS SELECTED FOR THE TEST PROJECT WERE:   1) A VENTURI WITH A  SPRAY TOWER AFTER
ABSORBER; 2) A TURBULENT CONTACT ABSORBER  (TCA) AND 3) A MARBLE-BED ABSORBER.  THE VENTURI SYSTEM.  MANUFACTURED BY  CHEMICAL
CONSTRUCTION CO.,  CONTAINS AN ADJUSTABLE THROAT THAT PERMITS CONTROL AND VARIATION OF PRESSURE DROP UNDER  A WIDE RANGE OF  FLOW
CONDITIONS.  THE TCA UNIT MANUFACTURED BY  UNIVERSAL OIL PRODUCTS.  EMPLOYS A FLUIDIZED BED OF LOW DENSITY PLASTIC SPHERES THAT
ARE  FREE TO MOVE BETWEEN RETURNING GRIDS.   THE MARBLE-BED ABSORBER. SUPPLIED BY COMBUSTION ENGINEERING CO.. USES A PACKING   ,
OF 3/4  INCH  GLASS  MARBLE SPHERES AND A TURBULENT  LAYER  OF LIQUID  AND GAS ABOVE THE MARBLE LAYER TO ENHANCE MASS TRANSFER.
     THE TEST  FACILITY WAS DESIGNED  SO THAT MODIFICATIONS AND  VARIATIONS OF SCRUBBER  INTERNALS AND PIPING CONFIGURATIONS COULD
BE READILY  EMPLOYED  FOR  EACH  SCRUBBER  SYSTEM.   EACH SYSTEM  IS  CAPABLE  OF TREATING APPROXIMATELY 30.000 ACFM OF  FLUE GAS AT
300'F  CONTAINING 1800  TO  4000 PPM  OF S02 AND  2  TO 5 GRAINS/SCF OF PARTICULATES.  TESTING  OF THE TCA AND THE VENTURI SPRAY
TOWER  IS CURRENTLY IN  PROGRESS;  OPERATION  OF  THE  MARBLE-BED ABSORBER UNIT  HAS  BEEN  PERMANENTLY  DISCONTINUED.
                                                                  202

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DEFINITIONS
          203

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                                         DEFINITIONS
Boiler Capacity Factor
Boiler Utilization Parameter
Efficiency,
   Particulates
(kWh generation in year)/(maximum continuous generating
capacity in kW x 8760 hr/yr).
   SO,
FGD Availability Factor
FGD Reliability Factor
FGD Operability Factor
FGD Utilization Factor
FGD Status
   Category 1

   Category 2
    Category  3
Hours boiler operated/hours in period,
percentage.
expressed as a
Operational - The actual percentage of particulates re-
moved by the FGD system and the particulate control de-
vices from the untreated flue gas.  All others - The
design efficiency (percentage) of particulate removed by
the FGD system and the particulate control devices.

Operational - The actual percentage of S02 removed from
the flue gas.  All others - The design efficiency.

Hours the FGD system was available for operation  (whether
operated or not)/hours in period, expressed as a percentage,

Hours the FGD system operated/hours FGD system was called
upon to operate, expressed as a percentage.

Hours the FGD system was operated/boiler operating hours
in period, expressed as a percentage.

Hours FGD system operated/hours in period, expressed as
a percentage.


Operational - Unit has been or is in  service removing SO2.

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.
                                        205

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   Category 4



   Category 5



   Category 6


   Category 7


FGD Vendor


Fuel Characteristics



Identification Number


New



Operational Experience




Process
     DEFINITIONS

Planned, Letter of Intent Signed - Letter of intent has
been signed, but legal contract 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 SO2 regulation.

Considering an FGD system as well as alternative methods
 (Tables 14, 15).

Vendor with a signed contract, letter of intent or strong
commitment because of test unit or past purchases.

Type of fuel, average gross heating value in Btu/lb,
average percent ash and average percent sulfur content
for fuel as fired.

Number  of unit in the alphabetical listing in Tables 1,
2, 3 or Tables 14, 15.

FGD unit and boiler were designed at the same time or
space for addition of an FGD unit was reserved when
boiler  was constructed.

Operational - Brief summary of FGD system operation
since start-up and description of current month's per-
formance.  All others - Comments regarding stage of con-
struction, etc.

Company name if process is patented.  Generic name if
several companies have similar processes.
                                       206

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Regulatory Class
Retrofit


Sludge Disposal



Start-up Date



Unit Cost
     DEFINITIONS

A.   New boiler constructed subject to Federal New Source
     Performance Standards.

B.   Existing boiler subject to State Standard that is
     more stringent than the Federal New Source Perform-
     ance Standard (NSPS).

C.   Existing boiler subject to State Standard that is
     equal to or less stringent than NSPS.

D.   Other.

E.   Unknown.

FGD unit must be added to an existing boiler not
specifically designed to accommodate FGD unit.

Comments on disposal method for those units generating
sludge including: lined or unlined ponds, stabilized or
unstabilized sludge, and on- or off-site disposal.

Operational - Date when S02 removal began.  All others -
Date when S02 removal is scheduled to begin.  Generally
this will be the start-up date of the boiler.

Capital Cost in $/kW including: SC<2 absorption and regen-
eration system, SO2 recovery system, solids disposal,
site improvements, land, roads, tracks, substation, engi-
neering costs, contractors fee and interest on capital
during construction.

Annualized Cost in mills/kWh including fixed and variable
costs.  Fixed costs include: interest on capital, deprecia-
tion, insurance, taxes, and labor costs including overhead.
Variable costs include: raw materials, utilities, and
maintenance.
                                        207

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                                        DEFINITIONS

Unit Location                      City and State listed in mailing address.

Unit Name                          Unit identification as it appears in Electrical World -
                                   Direction of Electrical Utilities, McGraw-Hill - Current
                                   Edition - or as indicated by utility representative for
                                   installations in planning stages.

Unit Rating                        Operational - Maximum continuous gross generation capacity
                                   in MW? Preoperational - maximum continuous design genera-
                                   tion capacity in MW

Utility Name                       Name of corporation as it appears in Electrical World -
                                   Directory of Electrical Utilities, McGraw-Hill - Current
                                   Edition - as space permits.

Water Make-Up                      Gallons per minute of make-up water required per MW of
                                   capacity.
                                         208

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