ML20067D306

Monthly Operating Repts for Nov 1982

ML20067D306
Person / Time
Site:	Quad Cities
Issue date:	12/01/1982
From:	Buss R COMMONWEALTH EDISON CO.
To:
Shared Package
ML20067D301	List: ML20067D299 ML20067D306
References
NUDOCS 8212130202
Download: ML20067D306 (21)

Text

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _____ .._ . _

4 4

QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT

. NOVEMBER 1982 C(NMONWEALTH EDISON COMPANY AND i IOWA-ILLINOIS CAS & ELECTRIC COMPANY NRC DOCKET NOS. 50-254 AND 50-265 LICENSE NOS, DPR-29 AND DPR-30 i

l 82121302O2 821201 PDR ADOCK 05000254 R PDR

TABLE OF CONTENTS

1. Introdit etion II. Summary of Operating Experience A. Unit One B. Unit Two III. Plant or Procedure Changes, Tests, Experheents, and Safety Related Maintenance A. knendments to Facility License or Technical Specifications B. Facility or Procedure Changes Requiring NRC. Approval C. Tests and Experiments Requiring NRC Approval D. Corrective Maintenance of Safety Related Equipment IV. Licensee Event Reports V. Data Tabulations A. Operating Data Report B. Average Daily Unit Power Level C. Unit Shutdowns and Power Reductions VI. Unique Reporting Requirements A. Main Steam Relief Valve Operations B. Control Rod Drive Scram Timing Data VII. Refueling Information VIII. Glossary i

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I. INTRODUCTION

. Quad-Cities Nuclear Power Station is composed of two Boiling Water Reactors, each with a Maximum Dependable Capacity of 769 MWe net, located in Cordova, Illinois. The Station is jointly owned by Commonwealth Edison Company and Iowa-Illinois Gas & Electric Company. The Nuclear Steam Supply Systems are General Electric Company Boiling Water Reactors. The Architect / Engineer was Sargent & Lundy, Incorporated, and the primary construction contractor was United Engineers & Constructors. The condenser cooling method is a closed cycle spray canal, and the Mississippi River is the condenser cooling water source. The plant is subject to license numbers DPR-29 and DPR-30, issued October 1,1971, and March 21, 1972, respectively, pursuant to Docket Numbers 50-254 and 50-265. The date of initial reactor criticalities for Units 1 and 2 respectively were October 18, 1971, and April 26, 1972.

Commercial generation of power began on February 18, 1973 for Unit 1 and March 10, 1973 for Unit 2.

This report was compiled by Becky Brown and Randall Buss, telephone number 309-654-2241, extensions 127 and 181.

II.

SUMMARY

OF OPERATING EXPERIENCE A. Unit One November 1-30: Unit One continued the End of Cycle Six Refueling Outage throughout the month.

B. Unit Two November 1-6: Unit Two began the month increasing load at 5 MWe/ hour following a load reduction on October 31 for a tripped 2B Recircula-tion Pump Motor-Generator Set. On November 2, 2B Recirculation Pump Motor-Generator Set tripped again on low oil pressure. Load was reduced to 350 MWe while repairs were made. On November 3, the unit began increasing load at 5 MWe/ hour to a maximum achievable load of 801 MWe on November 6.

November 7-19: At 0010 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />, on November 7, load was reduced at 200 MWe/ hour to 700 MWe for weekly Turbine testing. At 0141 hours0.00163 days <br />0.0392 hours <br />2.331349e-4 weeks <br />5.36505e-5 months <br />, the unit scrammed on an Average Power Range Monitor High-High signal due to a spurious control valve fast closure signal during the weekly Turbine test. The Reactor was made critical at 1000 hours0.0116 days <br />0.278 hours <br />0.00165 weeks <br />3.805e-4 months <br /> and the Generator was on line at 1308 hours0.0151 days <br />0.363 hours <br />0.00216 weeks <br />4.97694e-4 months <br />. The unit began increasing load at 1600 hours0.0185 days <br />0.444 hours <br />0.00265 weeks <br />6.088e-4 months <br /> at 100 MWe/ hour. Load was reduced twice, on November 9 and 12, at the request of the Load Dispatcher due to low system demand and once on November 14, for weekly Turbine testing; otherwise maintaining an average load of approximately 800 MWe.

November 20-30: On November 20, at 2130 hours0.0247 days <br />0.592 hours <br />0.00352 weeks <br />8.10465e-4 months <br />, the unit began decreasing load at 100 MWe/ hour to minimum Recirculation Pump speed for a control rod pattern adjustment. Load was being held at 425 MWe by 0130 hours0.0015 days <br />0.0361 hours <br />2.149471e-4 weeks <br />4.9465e-5 months <br /> on November 21 and began increasing load at 0730 hours0.00845 days <br />0.203 hours <br />0.00121 weeks <br />2.77765e-4 months <br /> to 811 MWe by November 23 On November 26, load was dropped to 665 MWe to backwash and precoat a Condensate Demineralizer. Load was increased to 815 MWe on November 27 Load was reduced on November 29 at the request of the Load Dispatcher due to low system demand. Load began increasing on November 30 from 425 MWe at 0415 hours0.0048 days <br />0.115 hours <br />6.861772e-4 weeks <br />1.579075e-4 months <br />.

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III. PLANT OR PROCEDURE CHANGES, TESTS, EXPERIMENTS, AND SAFETY RELATED MAINTENANCE A. Amendments to Facility License or Technical Specifications There were no amendments to Facility License or Technical Specifications for the reporting period.

B. Facility or Procedure Changes Requiring NRC Approval There were no facility or procedure changes requiring NRC approval for the reporting period.

C. Tests and Experiments Requiring NRC Approval There were no tests or experiments requiring NRC approval for the reporting period.

D. Corrective Maintenance of Safety Related Equipment The following represents a tabular summary of the safety related maintenance performed on Unit One and Unit Two during the reporting period. The' headings indicated in this summary include: Work Request Numbers, LER Numbers, Components, Cause of Malfunctions, Results and Effects on Safe Operation, and Action Taken to Prevent Repetition.

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UNIT ONE MAINTENANCE

SUMMARY

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CAUSE RESULTS & EFFECTS W.R.

LER OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT MALFUNCTION SAFE 0PERAT10N PREVENT REPETITION Q22472 82-26/03L M0-1-1001-37A The torque switch Valve 37A was found The torque switch was Torus Spray Header would not close the to leak in excess of adjusted & the leak injection Valve valve tight enough. the Tech Spec limit rate test failed. A i

during Local Leak Work Request was written Rate Testing. to inspect the valve internals.

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Q22164 82-26/03L l-220-62A Feed- The valve seating The "A" loop Feedwater The valve internals were water Check Valve surface was check valve, CV l-220- inspected and cleaned.

slightly corroded 62A failed to meet the The seat ring 0-ring and the 0-ring was Tech Spec requirements was replaced & the Local worn. of less than or equal. Leak Rate Test was to 10.36 SCFil during pe r fo rmed.

Local Leak Rate Testing.

Q22165 82-26/03L I-220-58A Feed- The valve seating The "A" loop Feedwater The valve internals were water Check Valve surface was check valve could not inspected and cleaned.

corroded and the be pressurized to the The seat ring 0-ring 0-ring was worn. required 48 psig during was replaced & the Local Local Leak Rate Testing. Leak Rate Test was pe r fo r med.

Q22291 Suppression The shaft packing The vacuum breaker The shaft packing and 0-Chamber Vacuum and 0-rings were valve stem packing was rings were replaced and Breaker 1-1601-31A worn. found to be leaking the Leak Rate Testing i during Local Leak Rate was performed.

Testing. The leakage

.l was within the Tech I Spec limits.

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UNIT TWO MAINTENANCE

SUMMARY

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l CAUSE RESULTS & EFFECTS W.R. LER OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION Q22338 02-19/03L "A" Recirc The valve operator The valve could not be The operator yoke was Pump Discharge came loose due to stroked. The Reactor bolted to the bonnet &

Valve 2-202-5A missing bonnet-to- was shutdown at the the valve was tested.

yoke bolts. time. The other valves in the containment were inspected.

Q22406 82-19/03L Recirc Pump The valve shaft was The valve could not be The threaded part of Discharge bent when the yoke stroked. The Reactor the stem was cut off & a Valve 2-202-5A came loose. was shutdown at the new piece was welded time, on. The valve was tested sa t i s fac to ri ly..

Q22709 82-23/03L IIPCI Turbine The oil pressure The HPCI Turbine The pressure switch was 2-2300-PSI switch was found to could not be reset. replaced & HPCI was be defective. tested satisfactorily.

Q20196 HPCI Pump Worn parts in the The thermals trip when The Limitorque operator Minimum Flow operator caused the attempting to open the and motor was replaced.

Valve MO-2-2301- motor to draw high valve.

14 amperes.

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4 IV . LICENSEE EVENT REPORTS The f ollowing is a tabular summary of all licensee event reports for Quad-Cities Units One and Two occurring during the reporting period,. pursuant to the reportable occurrence reporting requirements as set forth in sections 6.6.B.1 and 6.6.B.2. of the Technical Specifications.

UNIT ONE There were no Licensee Event Reports for the reporting period for Unit One.

l UNIT TWO Licensee Event Report Number Date Title of Occurrence 82-23/03L 11-04-82 HPCI Inoperable -

, Dirty Oil Pressure Switch I

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l V, DATA - TABUIATIONS The foIlowing data tabulations are presented in this report: i A,- Operating Data Report i B, Average Daily Unit Power Level C, Unit Shutdowns and Power Reductions I

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OPERATING DATA REPORT DOCKET NO. 50-254 ~ ~ ~

UNIT ONE DATEDecember Oi 1982

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CGMPLETED BYRondo11~D' Bus's~~~

TELEPHONE 309-654-2241x101 _ . _ - - . _ _

OPERATING STATUS 0000 110182

~i. Reporting' period 2400~ii3082 Gross hours'in reporting period:~~720~~-

2. Currently authorized power level (MWt): 2511 Max. Depend capacity ~~ ~ ~ ~ ~ ~ ~ ^ ^ ~ ~ ~ ~ ~ ~ ~ ~

(MWe-Net): 769* Design electricol"roting ( MWe-Ne t )~t ' 789

3. Power level to which restricted (if any)(MWe-Net): NA ,_ __ ._

4. Reasons for restriction (if any):

This Month ~Yr.to Do'te Cu'nulotive -

5. Number of hours reactor was critical _

0.0 5833.1 '74932.2

6. Reactor reserve shutdown hours 0.0 0.0 3421.9

7. Hours generator on line 0.0' ~ 5777.i~ ~~ 71908.6~

0. Unit reserve shutdown hours. 0.0 0.0 909.2 _

V. Gross thermal energy generated (MWH) _

0 11000483- 146058842

10. Gross electrical energy generated (MWH) 0 3533214~ ~47062147~-

Li. Het electrical energy generated (HWH) *-2045 3194639_ 43778723 _

12. Reactor service factor 0.0 72.8 81,0

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L3. Reactor availabillty factor 0.0 72.8 84.7 l

L4. Unit service factor 0.0 72.1 77.7 LS. Unit avullobility factor 0.0 72.1 78.7

16. Unit capacity factor (Using MDC) .4 51.8 61.5' L7. Unit capacity factor (Using Des.MWe) 4 50.5 60.0

18. Unit forced outage rate 0.0 1. 5, 6.7

19. Shutdowns scheduled over next 6 nonths (Type,Date,and Duration of each):

20. If shutdown at end of report period, estimated date o f s t or t u p _12-]j],-82______

• The MC not be lever than 769 Ne during periods of high enblent tenperatere due to the thernal perfernance of the sprey canal.

$ UNOFFICIAL. COMPANY NUMKRS ARE USED IN THIS REPORT

OPERATING DATA REPORT

'^~ ^ DOCKET NO . ~ ' ~ 50-265

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UNIT- _

TWO __ ..

DATEDecember Oi 1982

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TELEPHONE 309-654-2241xi8i OPERATING STATUS

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0000 110182 -

't . Reporting' period 2400~ii3082 dross .h ours in~ reporting period's ~720 ~~ ~~ ~

2.- currently authorized power level (MW't): 2511 Max. Depend capacity- ~ ~ ~ - ~ ~ ~ ~ ~ ~

( MWe'-Ne t ) : 769* Design' electrical ~roting(MWe-Net): ~ 7 89 ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~

3. Power level to which restricted (if ony)(MWe-Net): NA 4.' Reasons for restriction (if any):

- ~~ ~ ~

~ Th is~ M o'n th" ' Yr~it o Do~t e~ Cunulo't1~ve ~~'

5. Number of hours reactor was critical 711.'8 6667.6 71519.4

6. Reactor reserve shutdown hours 0.0 0.0 2985.8 708'.6^~

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7. Hours ~ generator on line ~

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~ 6 6 0 2 . 9_ ~~ ~ 68 8 4 4 '~ i ~~

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U. Unit reserve shutdown hours. 0.0 . .

0.0 702.9 . . . - - . .

9. Gross thernal energy generuted(MWH)- 1589387 14948541 142835624

~ 10 . Gross electrical energy' generated (MWH) 512650' ~ ~4761755 " ~'45467995 ~~~

11. Net elect.Acol energy generated (MWH) _ 479794 4526014 42650598

12. Reactor service factor 98.9 83.2 78.1

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~13.~ Reactor avo11ob111ty factor ~ 9 8 . 9_ '83.2 ~~~~

14. Unit _ service factor 98.4 _

82.4 75.1 1.5. Unit avo11ob111ty factor -

98.4 82.4 75.9-

16. Unit capacity factor (Using MDC) 86.7 73.4 ~- ~~~60;5, ~ '

17. Unit capacity factor (Using Des.MWe) 84.5 71.6 59.0 l __ ,

j 10. Unit forced outoge rate i.6 16.0_ 9.2 l

~19. Shutdowns scheduled over next 6 nonths (Type,Date,and' Durotion 'of each):~ ~ ~ ~ ~

l NA

20. If shutdown at end of report period,estinated date of startup

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l *The NDC not be lwer then 769 mit dering periods of high onblent tenperatsre dee to the thernal perfernence of the sprey canal.

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! *LMOFFICIN. CONMY RNOS ME USD IN THIS REPORT

APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-265

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'TWO ' ~ ~ ~ ~

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~ ' UNIT ~

4 DATEDecember di 1982 . _ - - - . _ __

- COMPLETED BYRondoll D Buss

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'TELEP HONE 309-654-2241 x i81"r~ ~~ ^~--

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HONTH November 1982 _.

DAY AVERAGE DAILY POWER LEVEL DAY' AVERAGE DAILY POWER LEVEL.

(MWe-Net) _

(MWe-Net)

1. 523.6 17, 761.5

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~ 408.~9'

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'8..

i ~760.9'~~~~~

3. 387.6 '

.e--p w- +m.,.

19. mowe

'764.5 L-N.w.imm.-

4. 582.5 20. 744.3

..S.-- 672~.9

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6. 742.9 22. 623.1

7. 236.9 23. 728.7

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612.'0'

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9. 658.0 25. 762.4 __ ,

10. 754.4 26. 748.9 -

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27. -

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11.

742.5'

12. 714.6 28. 758.8 -.

13. 769.5 29, 758.0

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L4. 694.0 30. 622.3

15. 754.8 ..- ._ .

16, 756.7 INSTRUCTIONS .

On this fern, list the estrege daily snit power lesel in IWe-Wet for each day in the reporting nenth. Compete to the nearest Whele negevett.

These figures Will be esed te plot a graph for each reporting nenth. Note that when notinen dependable capacite is esed for the net electrical rating of t%e snit there ney be accostens when the delly eseroge power lesel exceeds the illI line (or the restricted power leetl line),In sech cases,the estrege daily snit power setpet sheet sheeld be festnoted to explain the apperant onently

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APPENDIX B AVERAGE DAILY UNIT POWER LEVEL .

DOCKET NO. 50-254

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UNIT' ' 'ONE " "~

DATEDecember 01 1982 COMPLETED BYRondall D Boss

~ TELEPHONE 309-654-2241xi81^' ^ ~ ~ ~

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MONTH. .

November 1982 __ - . . . . ~ . - . - . - . . - . - - -

DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE-DAILY POWER, LEVEL (MWe-Net) - . - - . . - -

(MWe.-Ne t ) . . . - . . - . . - - . _ - -

1. -3.4 _

17. -3.5

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~-3.4~

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3. -2.8 _.. .

19. ..

-3.2 _ .. -

4. -3.i 20. ~ 3.3

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5;

~~ 21.

6. -2.0 -

22.

-2.3-

• / -2.6 23. -2.3

. . . . . . .. . . . . . . . --- .. - ~ . , - , - - . + , , . .

9. -2.3 -

25. -2.3 -. . - . -

10. -3,0 26.' -2.3

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'ii. '27' . ~ - ~ - 2 ~. 4 ~ ~ ~ ~ ~ ~

8 12 .~ -3.5 28. -2,3

13. -3.4 29. -2.3 _

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- ~ 14 . -3.0 ' ~ ~ ~ 3 0 '. ~ ~-2 . 3 ~ ^ '

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16. -3.1

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INSTRUCTIONS On this fern nearest whole, list the awrege dailt snit pwer level in Itie-liet for each det in the reporting nonth. Compete to the negeustt.

These figeres will be osed to plot a graph for each reporting nenth. Ilote that when notinen dependable cepetitt is .

i esed for the net electrical reting of the snit there not be occasions when the delly estrege power leul exceeds the

1941 line (or the restricted pwer level line).,In soch cases,the overage dolly snit power esti.et sheet sheeld be l festeeted to esplein the apperent enenely I

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APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-265

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' UNIT TWO

DATEDecember 01 1982 .. . - ..

COMPLETED bYRondoll-D Buss

~~ ~ TELEPHONE 309-654-2241 x 181~ ~ ~~ ~

HONTH November 1982 _ . .. ___ ..- . .- . - - . . . - - - . .

DAY AVERAGE DAILY POWER LEVEL DAY' AVERAGE DAILY POWER LEVEL

( MWe-Ne t ) _ . _ _ .

(MWe-Net)

i. __ 523.6 17. 761.5

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2.

~ ~ ~ -~

408.9 ^ ~ 'i 8 . "~760~.'9~~ ~ ~~

3. 387.6 19.

764.5 -.._ _ .

4. 582.5 ,

20, 744.3 5.

~ ~ ~ ~ ~ ~ ~

672.9 21. - ~ ~ 4 5 9 .' 0 ~ ~~ ~ ~~

4

6. 742.9 22, 623,i

7. 236.9 23. 728.7

'O. 612.O~ ~~24. - ~ ~ ~ " 7 61 .~ 8 ' ~ ~~ ~~ ~~~

9. 658.0 25. 762.4 ..

10, 754.4 26. 748,9

11. 742'.5 ~ 27. ~~725.~4 --~~~7

12. 714.6 28, 758.8 .

1. 3 . 769.5 29. 750.0 14, 694.0

30. - 622.3~ -

1.5 . 754.0 _. _

16. 756.7 INSTRUCTIONS .

On this forn, list the estrage delly snit power level in IWe-Met for each day in the reporting senth Compete to the nearest whole negowett.

These figeres will be esed to plot a graph for each reporting Math. Note that when notinen dependable copecite is used for the net electrical reting of the snit there ney be occasions when the daily estrage power level exceeds the '

illI line (or the restricted power level line),In sich cases,the average daily snit power setpet sheet sheeld be festnoted to explain the apparent onenely

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ID/5A APPENDIX D QTP 300-S13 UNIT SilUTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO. 050-2q4 August 1982 UNIT NAME Quad-Cities Unit One COMPLETED BY R. Buss DATE Decernber 1,1902 REPORT MONTil NOVEtiBER 1982 TELEPIIONE 309-654-2241 N $ H m = et x g

$ LICENSEE o

w DURATION @ gg EVENT $u o NO. DATE REPORT NO. u (110URS) o CORRECTIVE ACTIONS / COMMENTS o

82-85 820906 S 720.0 C 4 RC FUELXX Continuation of Cycle Six Refueling Outage APPROVED AUG 101982 (final) ygg3g

n n n n M M NJ"I m m x -,- M M M M M M M y ID/SA APPENDIX D QTP 300-S13 UNIT SilUTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO. 050-265 August 1982 UNIT NAME Quad-Cities Unit Two COMPLETED BY R. Buss DATE December 1, 1982 REPORT HONTil fl0VEMBER 1982 TELEPil0NE 309-654-2241 N $

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@ LICENSEE $$

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o ga g DURATION M EVENT $" o u

No. DATE (IlOURS) o REPORT NO. CORRECTIVE ACTIONS / COMMENTS o

82-83 821102 F 0.0 B 5 CB INSTRU Load reduced after 2B Recirculation Pump Motor-Generator Set tripped on low oil pressure switch trip 82-84 821107 s 0.0 8 5 llA XXXXXX Reduced load to perform weekly Turbine test 82-85 821107 F 11.5 A 3 HA RELAYX Reactor scram on Average Power Range lionitor liigh-High signal due to control valve closure during weekly Turbine test 82-86 821109 5 0.0 F 5 EA ZZZZZZ Load reduction requested by Load Dispatcher due to low system demand 82-87 821112 S 0.0 F 5 EA ZZZZZZ Load reduction requested by Load Dispatcher due to low system demand 82-88 821114 S 0.0 B 5 HA XXXXXX Reducad lead to perform weekly Turbine

( ' test APPROVED AUG 1 G 1982 (final) ggg3g j

M M M n M - F5B ET9 M M M M M M M M M M y o

ID/5A APPENDIX D QTP 300-S13 UNIT SilDTDOWNS .AND POWER REDUCTIONS Revision 6 DOCKET NO. 050-265 August 1982 UNIT NAME Quad-Cities Unit Two COMPLETED BY R. Buss December 1, 1982 DATE REPORT MONTil NOVEftBER 1982 TELEPil0NE 309-654-2241 N $ H m

5 SEE O

"w $m

@ Q M LICENSEE @ @

o w DURATION @ "g EVENT $u u NO. DATE (IIOURS) a REPORT NO. CORRECTIVE ACTIONS / COMMENTS a

82-89 821120 S 0.0 H 5 RB CONROD Load reduction for Control Rod Pattern adjustment 82-90 821126 F 0.0 B 5 HG DEhlNX Reduced load due to Condensate Demineralizer problems 82-91 G21129 5 0.0 F 5 EA ZZZZZZ Load reduction requested by Load Dispatcher due to low system demand APPROVED AUG 1 G 1982 (final) yCUSH

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• VI. UNIQUE REPOR1.NG REQUIREMENTS

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t The following items are included in this report based on prior f commitments to the commis.= ion: , - -

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A.

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MAIN STEAM RELIEF VALVE OPERATIONS

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f There were no Main Steam Relief Valve Operations for the -' \

reporting period.

B. CONTROL ROD DRIVE SCRAM TIMING DATA K)R UNITS ONE AND TWO 4 4

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There was no Control Rod Drive Scram Timing Data for Units One and Two for the reporting period.

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VII. - REFUELING INFORMATION l

Ths following information about future reloads at Quad-Cities i Station was requested in a January 26, 1978, licensing memorandum (73-24) from D. E. O'Brien to C. Reed, et al., titled "Dresden, j

Quad-Cities, .and Zion Station--NRC Request for Refueling Informa tion",

dated January 18, 1978..

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QUAD-CITIES REFUELING INFORMATION REQUEST March 1978

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1. Unit

1 Reload: 6 Cycle: 7 e 2. Scheduled date for next refueling shutdown: Sept 12, 1982

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3 Scheduled date for restart following refueling: Dec 4, 1982 -

t-

{ 4. Will refueling or resumption of operation thereafter require a technical specification change or other license amendment:

YES l 5 Scheduled date(s) for submitting proposed IIcensing action and supporting

{L . Information:

JULY 26, 1982 r-

6. !cpercent licensing con::!derations associated with refueling, e.g. , new or

, ' different fuel design or supplier, unreviewed design or performance analysis

, ./ methods, significant changes in fuel design, new operating procedures:

'IttPLEttENTATION OF TH'E ODYN TRANSIE';T ANALYSIS CODE AND RESULTS (fiCPR SCRAM TIME DEPENDENCE)

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7 The number of fuel assemblies.

a. Number of assemblies in core: 224 new/724 total after the

b. Number of assemblies in spent fuel pool: outage 1940

8. The present licensed spent fuel pool storage capacity and the size of any increase in licensed storage capacity that has been requested or is planned in number of fuel assemblies:

b a. Licensed storage capacity for spent fuel: 2920

b. Planned increase in licensed storage: 4636 new/7556 total a

9 The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity:

LOSS OF FULL CORE DISCHARGE CAPABILITY - 3/04 WPPROVED H LOSS OF RELOAD CORE DISCHARGE CAPABILITY - 2/86 APR 2.01978

, Q.C.O.S.R.

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QTP 300-S32 4" R2 vision 1 QUAD-CITIES REFUELING March 1978 ds , INFORMATION REQUEST o

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1. Unit

2 Reload: 6 Cycle: 7

2. Scheduled date for next refueling shutdown: Feb 27. 1983 3 Scheduled date for restart following refueling: April 23, 1983 -

r y 4. Will refueling or resumption of operation thereafter require a technical specification change or other license amendment:

P NO 5 Scheduled date(s) for submitting proposed IIcensing action and supporting

. Information:

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6. Important IIcensing considerations associated with refueling, e.g., new or

' different fuel design or supplier, unreviewed design or performance analysis

., / methods, significant changes in fuel design, new operating procedures:

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7 The number of fuel assemblies. -

a. Number of assemblies in core: 192 new/724 total

,, after the

b. Number of assemblies in spent fuel pool: outage 2132

8. The present licensed spent fuel pool storage capacity and the size of any increase in licensed storage capacity that has been requested or is planned

, in number of fuel assemblies: .

a. Licensed storage capacity for spent fuel: 2920

b. Planned increase In IIcensed storage: 4636 new/7556 total 9 The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity:

LOSS OF FULL CORE DISCHARGE CAPABILITY - 3/84 /V p> p FR () \/ E: E) v LDSS OF RELOAD CORE DISCHARGE CAPABILITY - 2/86 APR 2.01978

, CD.c:.C).53.Ft.

p VIII, GLOSSARY The following abbreviations which may have been used in the Monthly Report, are defined below:

ACAD/ CAM - Atmospheric Containment Atmospheric Dilution / Containment Atmospheric Monitoring ANSI -

American National Standards Institute APRM - Average Power Range Monitor ATWS -

Anticipated Transient Without Scram BWR - Boiling Water Reactor CRD - Control Rod Drive EHC -

Electro-Hydraulic Control System EOF -

Emergency Operations Facility CSEP - Generating Stations Emergency Plan HEPA - High-Efficiency Particulate Filter HPCI - High Pressure Coolant Injection System HRSS -

High Radiation Sampling System IPCLRT - Integrated Primary Containment Leak Rate Tes t IRM - Intermediate Range Monitor ISI - Inservice Inspection LER - Licensee Event Report LLRT - Local Leak Rate Test LPCI - Low Pressure Coolant Injection Mode of RHRS LPRM - Local Power Range Monitor MAPLHGR - Maximum Average Planar Linear Heat Generation Rate MCPR - Minimum Critical Power Ratio M FLCPR - Maximum Fraction Limiting Critical Power Ratio MPC - Maximum Permissible Concentration MSIV -

Main Steam Isolation Valve NIOSH - National Institute for Occupational Safety and Health PCI -

Primary Containment Isolation PCIOMR - Preconditioning Interim Operating Management Recommendations RBCCW - Reactor Building Closed Cooling Water System RBM -

Rod Block Monitor RCIC - Reactor Core Isolation Cooling System RRRS - Residual Heat Removal System RPS - Reactor Protection System RRM -

Rod Worth Minimizer SBGTS -

Standby Cas Treatment System SBLC - Standby Liquid Centrol SDC - Shutdown Cooling Mode of RHRS SDV - Scram Discharge Volume SRM - Source Range Monitor TBCCW - Turbine Building Closed Cooling Water System TIP - Traveling Incore Probe TSC - Technical Support Center