ML20081M357

Monthly Operating Repts for Oct 1983

ML20081M357
Person / Time
Site:	Quad Cities
Issue date:	10/31/1983
From:	Kalivianakis N, Misak A COMMONWEALTH EDISON CO.
To:	NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
References
NJK-83-394, NUDOCS 8311170229
Download: ML20081M357 (24)

Text

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QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERPORMANCE REPORT OCTOBER 1983 CCMMONWEALTH EDISON COMPANY AND IOWA-ILLINOIS GAS & ELECTRIC' COMPANY NRC DOCKET NOS, 50-254 AND 50-265 LICENSE NOS, DPR-29 AND DPR-30 l-l i

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8311170229 831031 34 PDR ADOCK 05000254-

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. TABLE OF CONTENTS i

I, Introduction

-II,- Summary of Operating Experience A. Unit One B, Unit Two -

III, Plant or Procedure Changes, Tests, Experhuents, and Safety Related Maintenance A. Amendments 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 Infonnation VIII, Glossary

r I. INTRODUCTION Quad-Cities Nuclear Power Station is composed of two Bolling 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 critica11tles 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 I 1 and March 10, 1973 for Unit 2.

l This report was complied by Becky Brown and Alex Misak,

. telephone number 309-654-2241, extensions 127 and 194.

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II,

SUMMARY

OF OPERATING EXPERIENCE A. UNIT ONE October 1-16: Unit One began the month operating at full power and I continued operating at this level throughout this period except for  :

three occasions. On October 2 and October 16, the unit dropped load i to 700 MWe for approximately two hours for weekly Turbine tests.

On October 9, the unit dropped load to 550 MWe for 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> for weekly Turbine tests, control valve and stop valve testing, MSIV 1 timing, and control rod pattern changes. On all three occasions, I normal load increases were initiated following completion of the 4 testing. l October 17-23: On October 18, at 0900 hours0.0104 days <br />0.25 hours <br />0.00149 weeks <br />3.4245e-4 months <br />, the unit dropped load I to 750 MWe in 18 minutes in preparation for a special Economic Generation Control (EGC) Xenon test. This load was maintained until 1040 hours0.012 days <br />0.289 hours <br />0.00172 weeks <br />3.9572e-4 months <br /> on October 19 when the unit increased load to 800 MWe in 30 minutes. The unit maintained a load of 800 MWe until 1340 hours0.0155 days <br />0.372 hours <br />0.00222 weeks <br />5.0987e-4 months <br /> when the unit dropped load to 750 MWe in 20 minutes and then dropped load to 650 MWe in 12 minutes as part of the EGC Xenon test. The unit maintained a load of 650 MWe until 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> on October 20 when the unit dropped load 50 MWe/ hour due to low Standby Liquid Control solution temperature. This load drop was terminated at 0150 hours0.00174 days <br />0.0417 hours <br />2.480159e-4 weeks <br />5.7075e-5 months <br /> with the unit at 550 MWe, and at 0205 hours0.00237 days <br />0.0569 hours <br />3.38955e-4 weeks <br />7.80025e-5 months <br />, the unit increased load to 650 MWe at 0300 hours0.00347 days <br />0.0833 hours <br />4.960317e-4 weeks <br />1.1415e-4 months <br />. At 0900 hours0.0104 days <br />0.25 hours <br />0.00149 weeks <br />3.4245e-4 months <br />, the unit increased load 100 MWe in 12 minutes as part of the EGC Xenon test. The unit maintained load at 750 MWe until 1630 hours0.0189 days <br />0.453 hours <br />0.0027 weeks <br />6.20215e-4 months <br /> on October 21 when a normal load increase to full power was initiated. The unit achieved full power at 2300 hours0.0266 days <br />0.639 hours <br />0.0038 weeks <br />8.7515e-4 months <br /> and maintained this load until 2l00 hours on October 23 when the unit dropped load to 700 MWe in 30 minutes for weekly Turbine tests. At 2310 hours0.0267 days <br />0.642 hours <br />0.00382 weeks <br />8.78955e-4 months <br />, the unit increased load 30 MWe in 30 minutes, and the load was maintained at 730 MWe as part of the EGC Xenon test.

October 24-31: On each day from October 25 to October 28, an identical load change pattern was initiated as part of the EGC Xenon test. At 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />, the unit dropped load to 530 MWe in one hour. This load was maintained until 0600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br /> when the unit increased load to 730 MWe in 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> on the 25 and 26, and 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> on the 27 and 28. At 1400 hours0.0162 days <br />0.389 hours <br />0.00231 weeks <br />5.327e-4 months <br /> on October 28, a normal load increase to full power was initiated, and full power was achieved at 2030 hours0.0235 days <br />0.564 hours <br />0.00336 weeks <br />7.72415e-4 months <br />. This load was maintained until 0305 hours0.00353 days <br />0.0847 hours <br />5.042989e-4 weeks <br />1.160525e-4 months <br /> on October 30 when the unit dropped load to 700 MWe for weekly Turbine tests. At 0410 hours0.00475 days <br />0.114 hours <br />6.779101e-4 weeks <br />1.56005e-4 months <br />, a normal load increase was initiated, and full power was achieved at 1100 hours0.0127 days <br />0.306 hours <br />0.00182 weeks <br />4.1855e-4 months <br /> and was maintained throughout the remainder of the month.

f B. UNIT TWO I Unit Two remained shutdown throughout the month for the End of i Cycle Six Refueling and Maintenance Outage. I l

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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 the 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 major safety related maintenance performed on Unit One and Unit Two during the reporting period. This summary includes the folle-'ng headings: Work Request Numbers, LER Numbers, Components, Cause of Hal functions, Resul ts and Effects on Safe Operation, and Action Taken to Prevent Repetition.

'l UNIT ONE' MAINTENANCE

SUMMARY

CAUSE RESULTS 6. EFFECTS

.W.R. LER OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT-REPETITION Q27743 M0-1-220-1 Main There were various The pressure seal The valve was machined Steamline Drain internal wear ring was blowing, and lapped, and the seal-Valve p robl ems. ring was replaced. The valve failed the post-maintenance LLRT & Work Request Q28584 was written.

Q28280 83-34/03L 1A Recirculation There was a short The. breaker was The cubicle was replaced Discharge Valve; in the cable with- burnt up and the but the logic test' failed.

1-202-5A,- in the Drywell, valve made in- Work Request Q28272 was Breaker was operable. The written to repai r the replaced with requi red sur- breaker, and Work Request 2-202-5A veillances were Q28302 was written to Breaker & Work performed to repai r the short.

Request Q28272 run with one was written to recirculation repai r Breaker, pump, and Work Request Q28302 was written when this did not solve the problem.

Q29025 83-38/03L M0-1-2301-3 The ' CLOSED' The valve would not The limit switch and Valve limit switch was consistently open torque swi tch were out of adjust- from the Control adjusted, and the valve ment. Room. Unit 1 HPCI was successfully, stroked.

was declared in-operable, and the required surveillances were performed.

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UNIT ONE MAINTENANCE

SUMMARY

CAUSE RESULTS & EFFECTS W.R. LER. OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT HALFUNCTION SAFE OPERATION PREVENT REPETITION Q29062 1-1705-2C Main The monitor was The 2C Main Steamline The 2C Main Steamline Steamline out of calibra- Radiation Monitor was Radiation Monitor was Radiation tion, reading more than 20 calibrated.

Mon i to r uni ts away f rom the other three monitors.

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UNIT Tuo MAINTENANCE

SUMMARY

CAUSE RESULTS & EFFECTS W.R. LER OF ON ACTION TAKEN TO

. NUMBER NUMBER COMPONENT MALFUNCT10N SAFE OPERAT10N -PREVENT REPETITION Q28583 2B Refuel Floor Failed Detector. _Downscale alarm kept The detector tube and Radiation coming up and re-' capacitors were replaced.

Monitor setting. The-calibration and functional test were' successfully performed.

Q28842 APRM/RBH Flow The dual trip unit While calibrating the Parts Q5, Q6, q8, and q9 Converter 2- circuitry was flow converter, i t was were replaced.

260-iOA failed. discovered that the trips would not reset.

Q29149 2B Fuel Pool The sensor was The monitor was The sensor was replaced.

Radiation erratic, spiking high and Monitor -

tripping the vent system.

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I IV , LICENSEE EVENT REPORTS The ' following 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 Licensee Event Report Number Date Title of Occurrence

'83-38/03L 10-6-83 M0 1-2301-3 Failed to Open 83-39/03L 10-9-83 1-1601-32F Vacuum Breaker Inoperable 83-40/03L 10-19-83 Various Surveillance Intervals Exceeded 83-41/03L- 10-19-83 Standby Liquid Control Concentration Out of Specifications 83-42/03L 10-24-83 1/2A Diesel Fire Pump inoperable 83-43/03L 10-24-83 1-1601-32C Drywell-Torus Vacuum Breaker inoperable 83-44/03L 10-26-83 PS 1-1622A Instrument Drift UNIT TWO 83-17/03L 9-24-83 RCIC Area High Temperature Switch Setpoint Drift 83-18/0lT 10-11-83 Linear Indication on Cleanup System Weld 83-20/01T- 10-27-83 Linear Indicat' ions on Recirculation System Welds Per 1.E.Bulletin 83-02 83-21/0lT 10-28-83 Linear Indications on Recirculation System Welds Per Confirmatory Order

.V, DATA TABUIATIONS The' fo11owing data tabulations are presented in this report:

'A, Operating Data Report B, . Average Daily Unit Power Level C, Unit Shutdowns. and Power Reductions i

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OPERATING DATA REPORT

. 4 DOCKET NO.- 50-254 1

UNIT ONE DATENovember 4

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COMPLETED BYAlex'Misak

, . TELEPHONE 109-654-2241x194 >

OPERATING. STATUS 0000 100183 1... Reporting period 2400 103183 Gross hours in' reporting period 745

12. Currently authorized power level (MWt): 2511 Hox. Depend capacity L(MWe-Net): 769* Design electrical roting'(MWe-Net): 789

3. Power level to which restricted (if any)(MWe-Net)

NA l4. Reasons for restriction (1ffany):

This Month Yr.to Date Cumulative

5. Number Jof hours' reactor was critical. 745.0 6935.2. 82106.4 i

. 6.: Reactor reserve shutdown hours 0 . 0. 0.0 3421.9 7.' Hours generator on line 745.0 6820.4 78907.-i

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!?, _8. Unit reserve shutdown hours. 0.0 0.0 909.2_

9. Gross thermal energy generated (MWH) 1749222 15442645 161655636 10.,. Gross electricalTenergy generated (MWH) 568852 5001153 52123034' ii.' Net electrical energy generated (MWH) 536885 4702018 -48530926

iSt.-- Reac t or service f ac t or 100.0 95.1 81.6

, 13. Reactor--ovollability factor 100.0 95.1 85.0

.14.. Unit service factor 100.0 93.5 7 :.4

" 15. Unit ovallobility facter 100.0 93.5 79.4

16. Unit capacity factor (Using MDC) 93.3 83.7 62.7

- l17. Unit capacit9 factor (Using Des.HWe) 90.9 81.6 61.1 118. Unit forced outage rate 0.0 2.1 6.3

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

20.-If shutdown ut end of' report period, estimated date of startup ___N,A_________

. Sine 10C nar be louer then 7W llie dering perleds of high entient tenparatore det

-te the thernal perfernance of the spret canal.

IIIINICIAL CWFAllt IWlOERS ARE UK9 Ill THIS REPORT i _4

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OPERATING DATA REPORT DOCKET NO. 50-265 UNIT TWO DATENovember 4 COMPLETED BYAlex Misok TELEPHONE 309-654-2241xi94 OPERATING STATUS 0000 100183

1. Reporting period:2400 103183 Gross hours in reporting periodt 745

2. Currently authorized power level (MWt): 2511 Max. Depend capacity (MWe-Net): 769* Design electrical roting (MWe-Net): 789

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

4. Reasons for restriction (if any):

This Month Yr.to Date Cunulative

5. Number of hours reactor was critical 0.0 5654.1 77917.5

6. Reactor reserve shutdown hours 0.0 0.0 2985.8

7. Hours generator on line 0.0 5621.7 75209.8

8. Unit reserve shutdown hours. 0.0 0.0 702.9

9. Gross thernal energy generated (MWH) 0 10790594 155382088

10. Gross electrical energy generated (MWH) 0 3398245 49435780

11. Het electrical energy generated (MWH) -3906 3153823 46337390

12. Reactor service factor 0.0 77.5 78.2

13. Reactor avo11ob111ty factor 0.0 77.5 81.2

14. Unit service factor 0.0 77.1 75.5

15. Unit avo11ob111ty factor 0.0 77.1 76.2

16. Unit capacity factor (Using MDC) .4 56.3 _

60.5

17. Unit copocity factor (Using Des.HWe) .4 54.9_ 58.9

18. Unit forced outage rote 0.0 1_.,8 8.6

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

-20. If shutdown at end of report period, estimated date o f s t a r t u p _1__8-84________

$lhe MDC not be lower than 769 FA ring perleds of high unbient tenperature due to the thernal perfernonce of t3+ 3 prop canol.

• Wl0FFICI AL COMPANY NUMBERS ARE USED 1H THIS REPORT L _ __--_ _ _ _ _ _ _ _ - . _ _ _ _ _ _ _ _ _

APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-254 UNIT ONE DATENovember 4 COMPLETED BYAlex Hisok TELEPHONE 309-654-2241x194 MONTH October 1983 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL '

(MWe-Net) (MWe-Net)

i. 725.3 17. 761.4 L2. 752.0 18. 720.7

3. 749.7 19, 663.0 l 4, 739.5 20. 669.5 l 5. 759.2 21. 708.6

6. 753.4 22, 751.5

7. 749.4 23, 738,0

8. 753.0 24. 683.7

9. 566.2 25. 626.7 10' . 655.7 26. 634.3 it. 746.2 27. 626.0

12. 749.9 28. 656.0 13, 749.8 29. 748.9

14. 772.7 30, 788.6 15, 757.8 31. 754.7

16. 751.4

' INSTRUCTIONS On this forn list the overage delly snit power level in MWe-Net for each day in the reperting nenth.Conpete to the stachele negeus,tt These fleeres will be osed to plot a graph for each reporting acnth. Note that when notinen citpendable capacite is esed for the net electrical rating of the salt t

'illt line (or the restricted power level linel.here ney beeverage In sich cases,the occasions when daily snit powerthe delly entput everage sheet power level exc she old be festnoted to explain the apparent enenelp

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APPENDIX B

AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-265 UNIT TWO DATENovember 4 COMPLETED BYAlex Hisak TELEPHONE 309-654-2241xi94 MONTH October 1983 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net)

1. -2,4 17. -2.3

2. -2.5 18. -2.4

'3. -2.5 19. -2.4

4. -2.3 20. -2.5

5. -2.1 21. -3.5

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-2.3 22. -3.8

7. -2,4 23. -3.5

8. -2.3 24. -3.5

9. -2.4 25. -3.2

10. -2.4 26. -3.0

11. -2,4 27. -4.3

.12 . -2.4 28. -4.4 l

j 13. -2.4 29. -4.4

! 14. -2.5 30. -4.2 l ' 15 . -2.3 31. -3.4

16. -2.3 INSTRUCTIONS On this forn list the overage dolly snit pewer level in l#le-Met for each dat in the reporting nenth.Conpete to the treseewhole neges,ett.

Thea fineres will be osed to plot a graph for each reporting nenth. Note that when noninen dependable copecit, is estd for the net electrical rating of the snit,there may be occasion when the daily overage pwer level exceeds the its! line (or the restricted

. feetnoted to esplein the opperen; e..enely power level line).In seth costs,the overage dolly enit pwer cetpet sheet s

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ID/SA APPENDIX D QTP 300-S13 UNIT SilUTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO. 050-254 August 1982 UNIT NAME Quad-Cities Unit One COMPLETED BY Alex Misak DATE November 7, 1983 REPORT HONTil OCTOBER 1983 TELEPil0NE 309-6s4-2241 m 8 g m = no x y

$ h h LICENSEE NO. DATE w DURATION d "g EVENT REPORT NO.

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(110URS) o CORRECTIVE ACTIONS /CONMENTS a

83-64 831002 s 0.0 B 5 ilA XXXXXX Reduced load to perform weekly Turbine tests 83-65 831009 s 0.0 B 5 HA XXXXXX Reduced load to perform weekly Turbine tests & tislV timing 83-66 831016 s 0.0 B 5 HA XXXXXX Reduced load to perform weekly Turbine tests 83-67 831018 s 0.0 C 5 RC FUELXX Reduced load for EGC Xenon Test 83-68 831019 s 0.0 6 5 RC FUELXX Reduced load for EGC Xenon Test 83-69 831020 F 0.0 D 5 RB ZZZZZZ Reduced load due to standby Liquid Control solution low temperature 83-70 831023 s 0.0 B 5 HA XXXXXX Reduced load to perform weekly Turbine tests 83-71 831025 s 0.0 B 5 RC FUELXX Reduced load for EGC Xenon Test 83-72 831026 s 0.0 B 5 RC FUELXX Reduced load for EGC Xenon Test APPROVED AUG 1 G 1982 (final) ygg3g

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n ID/5A APPENI)IX D QP 300-S13 UNIT SilUTDOWNS AND POWER REDUCT!ONS Revision 6 DOCKET NO. 050-254 August 1982 UNIT NAME Quad-Citles Unit One COMPI.ETED BY Alex itisak DATE November 7,1983 REPORT HONTil. OCTOBER 1983 TEl.EPil0NE 309-654-2241 m 5 g m 2 et# x o

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< 0"yM LICENSEE $$ y$

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v2 o gu gou w M "'

EVENT 0 u

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

83-73 831027 5 0.0 B 5 RC FUELXX Reduced load for EGC Xenon Test

83-74 831028 S 0.0 B 5 RC FUELXX Reduced load for EGC Xenon Test 83-75 831030 S 0.0 B 5 HA XXXXXX Reduced load to perform weekly Turbine tests APPROVED AUG 1 G 1982

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n n n n M - M M M M M M M M n n n p ID/SA APPENDIX D QTP 300-S13 UNIT SilHTDOWNS AND POWER REDilCTIONS Revision 6 DOCKET NO. 050-265 August 1982 UNIT NAME Quad-Cities Unit Two COMPI.ETED BY Alex Hisak DATE November 1, 1983 REPORT HONTil OCTOBER 1983 TEl.EPil0NE 309-654-2241 N $ H w" B $EO gm Sw

$ Q d LICENSEE m@ R@

w DURATION M EVENT $" @U u

NO. DATE (Il0URS) o REPORT NO. CORRECTIVE ACTIONS /CONNENTS o

83-66 830904 5 745.0 C 4 RC FUELXX Unit Two remains shutdown for End of Cycle Six Refueling and Maintenance e

I APPROVED AUG 1 G 1982

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VI, UNIQUE REPC . TING REQUIRIMENTS The following items are included in this report based on prior conmitments to the conmission:

A, MAIN STEAM RELIEF VALVE OPERATIONS There were no Main Steam Relief Valve Operations for the reporting period.

B. CONTROL ROD DRIVE SCRAM TIMING IRTA FOR UNITS ONE AND WO 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 The following information about future reloads at Quad-Cities Station as requested in a January 26, 1978, licensing memorandte (78-24) from D, E, O'Brien to C, Reed, et al. , titled "Dresden,

-Quad -Cities, and Zion Station--NRC Request for Refueling Infonnation",

dated January 18, 1978.

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QTP 300-S32

' Revision 1 1

QUAD-CITIES REFUELING tiarch 1979

( INFORMAT10N REQUEST

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L 1. Unit: Q1 Reload: 6 Cycle: 7

2. Scheduled date for next refueling shutdown: 9-6-82

?. Scheduled date'for restart following refueling: 12-18-82 .

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4. Will refueling or resumption of operation thereafter require a technical

' specification change or other IIcense amendment: Yes

5. Scheduled date(s) for submitting proposed licensing action and supporting

, . In forma tion: 8-19-82: Tech. Spec. changes submitted to the ITRC.

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:

a) All 7x7 fuel assemblies will be removed from the core.

. b) MAPLHGR curves for fuel types in the core are being extended to h0,000 IGD /ST.

c) MCPR limits vill be deternined by GE's ODYT co~puter code.

h' RA d) The vessel pressure safety limit is being modified to accommodate the potential for higher reactor pressures as i:alculated by CDY:I.

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7 The number of fuel assemblies.

a. Number of assemblies la core: 724 l b. Number of assemblies in spent fuel pool: 1730 n

d 8. The present licensed spent fuel pool storage capacity and the size of any l

Increase in licensed storage capacity that has been requested or is planned r.

In number of fuel assemblies:

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a. Licensed storage capacity for spent fuel: 3657

b. Planned increase in IIcensed storage: 0 l 9. The projected date of the last refueling that can be discharged to the F spent fuel pool assuming the present licensed capacity: 2003 m

L XPPROVED h APR 2 01978 Q.C.O.S.R.

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QTP 300-S32 Ravision 1 I

QUAD-CITIES REFUELING March 1978 INFORMATION REQUEST

1. Unit: Q2 Reload: 6 Cycle: 7

2. Scheduled date for next refueling shutdown: 9-5-83 3 Scheduled date for restart following refueling: 11-12-83

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

No, however, a change to the Technical Specifications- is being submitted o

(see below).

5. Schaduled date(s) for submitting proposed Itcensing action and supporting

? . Information:

June 14, 1983 (Scheduled)

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

' different fuel design or supplier, unreviewed design or performance analysis a methods, significant changes in fuel design, new operating procedures:

a) All new fuel assemblies will be of barrier design; MAPLHGR curves will be

_ re-labeled to include the barrier designation.

b) The use of Lmproved assumptions in the load reject without bypass analysis resulted in a much improved MCPR operating limit. Technical Specifications are being changed to provide this additional operating margin.

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7. The number of fuel assemblies. -

a. Number of assemblies in core: 0-L

b. Number of assemblies in spent fuel pool: 969

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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 l In number of fuel assemblies:

a. Licensed storage capacity for spent fusi: 3097 0

b. Planned increase in IIcensed storage:

9 The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity: 2003

- XPPROVED APR 2 01973 Q.C.O.S.R.

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

ACM9/ CAM -

Atmospheric Containnent Atmospheric Dilution / Containment Atmospheric Monitoring ANSI -

American National Standards Institute APRM -

Average Power Range Monitor ATWS -

Anticipated Transient Without Scras BWR -

Bolling Water Reactor CRD -

Control Rod Drive EHC -

Electro-Hydraulic Control System EOF -

Energency Operations Facility GSEP -

Generating Stations Emergency Plan HEPA -

High-Ef ficiency Particulate Filter HPCI -

High Pressure Coolant Injection System HRSS -

High Radiation Sampling System IPCLRT -

Integrated Primary Containment Leak Rate Test 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 MFLCPR -

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 Containnent Isolation

'PCIOMR -

Precondition 1ng Interim Operating Management Recommendations i RBCCW - Reactor Building Closed Cooling Water System l RBM -

Rod Block Monitor RCIC -

Reactor Core Isolation Cooling System RHRS - Residual Heat Removal System RPS - ' Reactor Protection System RRM -

Rod Worth MinimLzer Standby Gas Treatment System

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SBGTS -

l SBLC -

Standby Liquid Control SDC - Shutdown Cooling Mode of RHRS SUV ---

Scram Discharge Volume SRM -

Source Range Monitor TBCCW -

Turbine Building Closed Cooling Water System TIP -

Traversing Incore Probe

!- TSC -

Technical Support Center

/^NJOCommonwealth I Edison -

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Quad Citics Nuclett Power Stition g ) 22710 206 Avenue N:rth Corcova, Illinois 61242

\ Telephone 209/654-2241 l

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NJK-83-394 November 1, 1983 Director, Office of Inspection & Enforcenent United States Nuclear Regulatory Commission Washington, D, C, 20555 Attention: Document Control Desk Centlemen:

Enclosed for your information is the Monthly Performance Report covering the operation of Quad-Cities Nuclear Power Station, Units One and Two, during the month of October 1983.

Very truly yours, COMMONWEALTH EDISON COMPANY' QUAD-CITIES NUCLEAR POWER STATION l-N, J, Kallvianakis Station Superintendent bb Enclosu re i

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