ML20138H196

Monthly Performance Repts for Nov 1985

ML20138H196
Person / Time
Site:	Quad Cities
Issue date:	11/30/1985
From:	Tamlyn T COMMONWEALTH EDISON CO.
To:	NRC OFFICE OF ADMINISTRATION (ADM)
References
TKT-85-64, NUDOCS 8512170094
Download: ML20138H196 (22)

Text

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QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT NOVEMBER 1985 COMMONHEALTH EDISON COMPANY AND IONA-ILLINOIS GAS & ELECTRIC COMPANY NRC DOCKET NOS. 50-254 AND 50-265 LICENSE NOS. DPR-29 AND DPR-30 8512170094 e51130 DR ADOCK 050 24 5

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TABLE OF CONTENTS I.

Introduction II.

Summary of Operating Experience A.

Unit One B.

Unit Two III.

Plant or Procedure Changes, Tests, Experiments, 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 Rellef Valve Operations B.

Control Rod Drive Scram Timing Data VII.

Refueling Information VIII.

Glossary L

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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 l

Cordova, Illinois.

The Station is jointly owned by Commonwealth Edison Company and Iowa-Illinots Gas & Electric Company.

The Nuclear Steam Supply Systems are General Electric Company Bolling Water Reactors. The Architect / Engineer was Sargent & Lundy, Incorporated, and the primary construction contractor was United Engineers & Constructors. 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 i

Initial Reactor critica11ttes for Units One and Two, respectively were October 18, 1971, and April 26, 1972. Commercial generation of power began on February 18, 1973 for Unit One and March 10, 1973 for Unit Two.

This report was complied by Becky Brown and Carol Kronich, telephone number 309-654-2241, extensions 2240 and 2157.

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SUMMARY

OF OPERATING EXPERIENCE A.

Unit One November 1-14 Unit One began the month of November holding load at full power. On November 2, at 0155 hours0.00179 days <br />0.0431 hours <br />2.562831e-4 weeks <br />5.89775e-5 months <br />, the unit was placed on Economic Generation Control (EGC). On November 3, at 0020 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br />, the unit was taken off EGC and began a load drop to $50 MWe for Control Rod pattern adjustments.

At 0350 hours0.00405 days <br />0.0972 hours <br />5.787037e-4 weeks <br />1.33175e-4 months <br /> load began a normal increase to full power.

Eight hundred twenty-three MWe was reached on November 5 at 2345 hours0.0271 days <br />0.651 hours <br />0.00388 weeks <br />8.922725e-4 months <br />. Load remained steady until November 12, at 2200 hours0.0255 days <br />0.611 hours <br />0.00364 weeks <br />8.371e-4 months <br />, when load was dropped to approximately 570 MWe due to loss of number 2 Feedwater Heater string.

At 2250 hours0.026 days <br />0.625 hours <br />0.00372 weeks <br />8.56125e-4 months <br /> the unit began a normal increase to full power. At 0910 hours0.0105 days <br />0.253 hours <br />0.0015 weeks <br />3.46255e-4 months <br />, on November 13, 823 MWe was reached.

On November 14, at 0020 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br />, the unit was placed on EGC.

At 1610 hours0.0186 days <br />0.447 hours <br />0.00266 weeks <br />6.12605e-4 months <br /> EGC was tripped and the unit was brought to full power.

At 2000 hours0.0231 days <br />0.556 hours <br />0.00331 weeks <br />7.61e-4 months <br /> load began a drop in preparation for a scheduled unit shutdown for a Maintenance Outage.

November 15-30 On November 15, at 0458 hours0.0053 days <br />0.127 hours <br />7.572751e-4 weeks <br />1.74269e-4 months <br />, the unit was manually scrammed for the shutdown.

Start-up began on November 21, at 0600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br />. The Reactor went critical at 0755 hours0.00874 days <br />0.21 hours <br />0.00125 weeks <br />2.872775e-4 months <br />, and the unit was placed on line at 0138 hours0.0016 days <br />0.0383 hours <br />2.281746e-4 weeks <br />5.2509e-5 months <br />, on November 22.

At 0255 hours0.00295 days <br />0.0708 hours <br />4.21627e-4 weeks <br />9.70275e-5 months <br /> load was held at 135 MWe for a Safe Shutdown Pump Test. A normal start-up resumed at 0410 hours0.00475 days <br />0.114 hours <br />6.779101e-4 weeks <br />1.56005e-4 months <br />.

On November 24, at 1725 hours0.02 days <br />0.479 hours <br />0.00285 weeks <br />6.563625e-4 months <br />, load was approximately 700 MWe and a GSEP Unusual Event was declared due to the 1/2 Diesel Generator output breaker to Bus 13-1 being inoperable concurrently with the ID RHR Service Water Pump out of service. On November 25, at 1220 hours0.0141 days <br />0.339 hours <br />0.00202 weeks <br />4.6421e-4 months <br />, the unit came off line, and at 1230 hours0.0142 days <br />0.342 hours <br />0.00203 weeks <br />4.68015e-4 months <br /> the unit was manually scrammed for the shutdown.

On November 26, at 2335 hours0.027 days <br />0.649 hours <br />0.00386 weeks <br />8.884675e-4 months <br />, the Reactor went critical. The unit was placed on line at 0855 hours0.0099 days <br />0.238 hours <br />0.00141 weeks <br />3.253275e-4 months <br />, on November 27, and load was increased normally.

On November 30, at 1235 hours0.0143 days <br />0.343 hours <br />0.00204 weeks <br />4.699175e-4 months <br />, 823 MWe was reached. At 2058 hours0.0238 days <br />0.572 hours <br />0.0034 weeks <br />7.83069e-4 months <br /> load was dropped to 700 MWe for Turbine surveillances. Unit One ended the month of November at 700 MWe, prior to increasing load *o full power.

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' Unit Two November 1-7 Unit Two began the month of November holding load at 810 MWe.

On November 1, at 1210 hours0.014 days <br />0.336 hours <br />0.002 weeks <br />4.60405e-4 months <br />, load was dropped to 640 MWe for maintenance on the EHC pressure regulator. Load reached 700 MWe at 0700 hours0.0081 days <br />0.194 hours <br />0.00116 weeks <br />2.6635e-4 months <br />, and was held steady until November 4, at 1435 hours0.0166 days <br />0.399 hours <br />0.00237 weeks <br />5.460175e-4 months <br />, when the 2B Recirculation Motor-Generator was tripped due to an oil leak.

Load was dropped to restart the Motor-Generator Set.

At 1610 hours0.0186 days <br />0.447 hours <br />0.00266 weeks <br />6.12605e-4 months <br /> load reached 700 MWe and hcid steady. On November 5, at 1505 hours0.0174 days <br />0.418 hours <br />0.00249 weeks <br />5.726525e-4 months <br />, the unit under-went Control Rod pattern adjustments and continued to hold load at approximately 750 MWe.

On November 7, at 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />, a load drop to HOT STANDBY commenced at 150 MWe/ hour for maintenance on the EHC pressure regulator. At 0805 hours0.00932 days <br />0.224 hours <br />0.00133 weeks <br />3.063025e-4 months <br /> load was held at 60 MWe, At 0830 hours0.00961 days <br />0.231 hours <br />0.00137 weeks <br />3.15815e-4 months <br /> a normal unit shutdown commenced for further maintenance on the EHC pressure regulator and 2B Recirculation Pump seals. At 0833 hours0.00964 days <br />0.231 hours <br />0.00138 weeks <br />3.169565e-4 months <br /> the Turbine was tripped, and at 1022 hours0.0118 days <br />0.284 hours <br />0.00169 weeks <br />3.88871e-4 months <br /> the Reactor was manually scrammed.

November 8-30 On November 8, at 2325 hours0.0269 days <br />0.646 hours <br />0.00384 weeks <br />8.846625e-4 months <br />, the Reactor went critical. On November 9, at 0430 hours0.00498 days <br />0.119 hours <br />7.109788e-4 weeks <br />1.63615e-4 months <br />, Control Rods were stopped from being pulled and held for the Recirculation Pump seals. At 1450 hours0.0168 days <br />0.403 hours <br />0.0024 weeks <br />5.51725e-4 months <br /> a normal shutdown commenced due to the 2B Recirculation Pump seals. At 1510 hours0.0175 days <br />0.419 hours <br />0.0025 weeks <br />5.74555e-4 months <br /> the unit was manually scrammed. The unit remained shutdown until November 11, at 0415 hours0.0048 days <br />0.115 hours <br />6.861772e-4 weeks <br />1.579075e-4 months <br />, when a unit start-up began. The Reactor went critical at 0621 hours0.00719 days <br />0.173 hours <br />0.00103 weeks <br />2.362905e-4 months <br />, and the unit was placed on line at 1714 hours0.0198 days <br />0.476 hours <br />0.00283 weeks <br />6.52177e-4 months <br />, at 50 MWe.

A normal' unit start-up proceeded.

Eight hundred twenty-five MWe was reached on November 13 at 1200 hours0.0139 days <br />0.333 hours <br />0.00198 weeks <br />4.566e-4 months <br />. Load was held steady until November 16, at 0158 hours0.00183 days <br />0.0439 hours <br />2.612434e-4 weeks <br />6.0119e-5 months <br />, when the unit was placed on EGC.

On November 17, at 0015 hours1.736111e-4 days <br />0.00417 hours <br />2.480159e-5 weeks <br />5.7075e-6 months <br />, EGC was tripped for Turbine surveillances.

EGC operation resumed at 0042 hours4.861111e-4 days <br />0.0117 hours <br />6.944444e-5 weeks <br />1.5981e-5 months <br />. On Nove.3ber 18, at 1620 hours0.0188 days <br />0.45 hours <br />0.00268 weeks <br />6.1641e-4 months <br />, EGC was tripped and load held. The unit was placed on EGC at 1830 hours0.0212 days <br />0.508 hours <br />0.00303 weeks <br />6.96315e-4 months <br />.

On November 19, at 1520 hours0.0176 days <br />0.422 hours <br />0.00251 weeks <br />5.7836e-4 months <br />, EGC was tripped to perform surveillances.

At 1555 hours0.018 days <br />0.432 hours <br />0.00257 weeks <br />5.916775e-4 months <br /> load was increased to 800 MWe and continued at'5 MWe/ hour to full power.

Eight hundred twenty-five MWe was reached at 2105 hours0.0244 days <br />0.585 hours <br />0.00348 weeks <br />8.009525e-4 months <br />.

Load was held steady until November 30, at 1845 hours0.0214 days <br />0.513 hours <br />0.00305 weeks <br />7.020225e-4 months <br />, when load began a drop to 700 MWe for Turbine surveillances. At 2100 hours0.0243 days <br />0.583 hours <br />0.00347 weeks <br />7.9905e-4 months <br /> load began an increase to 805 MWe, At 2215 hours0.0256 days <br />0.615 hours <br />0.00366 weeks <br />8.428075e-4 months <br /> 805 MWe was reached and held for the remainder of November.

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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 Units One and Two during the reporting period. This summary includes the following: Work Request Numbers, Licensee Event Report Numbers, Components, Cause of Malfunctions, Results and Effects on Safe Operation, and Action Taken to Prevent Repetition.

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UNIT _ t_ MAINTENANCE SU WARY CAUSE RESULTS & EFFECTS W.R.

LER OF ON ACTION TAKEN TO NUEER NLABER COMPONENT MALFUNCT10N SAFE OPERATION PREVENT REPETIT10N Q45693 AD 1-1601-55 Extended use Valve became difficult 0-rings and diaphragm were Valve Solenoid caused diaphragm to close, replaced and valve was to harden.

tested satisfactorily.

4 0027H/0061Z a

UNIT 2

MAINTENANCE

SUMMARY

CAUSE RESULTS & EFFECTS W.R.

LER OF ON ACTION TAKEN TO NUREER NLABER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION Q41025 85-007 Check Valve 2-Damaged rubber Failed Local Leak Rate Valve was replaced; 2301-45 HPCI seat; bent stop Test.

tested satisfactorily.

Exhaust pin.

Q41492 85-007 Check Valve 2-Not determined.

Failed Local Leak Rate New O-rings installed ou 220-58A Inboard

Test, disc / seat assembly and on l

Feedwater seal ring.

Q41911 85-007 MO 2-220-2 Main Torque switch out Failed Local Leak Rate Adjusted torque switch to Steam Line of adjustment; Test.

close valve fully.

Drain Valve valve not fully closing.

142230 85-006 A0 2-203-2B Valve seating Failed Local Leak Rate Lapped main seat, replaced Main Steam Line surface wear due Test.

main disc, pilot seat, and Outboard to high pressure pilot disc. Retested Isolation Valve steam flow.

satisfactorily.

Q44320 2-5600-PS-1 EHC Setpoint drift Setpoint drifted low Replaced switch like-for-Fluid Pressure problem.

causing pressure trip to like.

Switch be too low (less than 900 psig). However, redundant switches were at proper setpoint.

Q45215 Diesel Generator No apparent Output breaker tripped; Investigated but no to Bus 24-1 problem found.

GSEP Unusual Event problem found (See Work Breaker (See Work Eequest declared because Request Q45643)

Q45643) containment cooling valves were out of service.

0027H/0061Z

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IV.

LICENSEE EVENT REPORTS l

The following is a tabular sunnary 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 6.6.8.2. of the Technical Specifications.

,l UNIT ONE Licensee Event i

Report Number Date Title of Occurrence 85-18 11-20-85 Fire Protection Program Discrepancies 4

85-19 11-25-85 Completion of Technical 4

Specification Required Shutdown UNIT TWO Licensee Event Report Number Date Title of Occurrence 1

There were no Licensee Event Reports for the reporting period.

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V.

DATA TABULATIONS The following data tabulations are presented in this report:

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Operating Data Report

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Average Daily Unit Power Level C.

Unit Shutdowns and Power Reductions i

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r OPERATING DATA REPORT DOCKET NO.

50-254 UNIT ONE DATERECEMBER 5 1985 COMPLETED BYCAROL L. KRONICH TELEPHONE (309)654-2241 OPERATING STATUS 0000 110185

1. Reporting period 2400 113085 Gross hours in reporting period 720

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

5. Hunber of hours reactor was critical 548.0 7594.9 95917.4

6. Reactor reserve shutdown hours 0.0 0.0 3421.9

7. Hours generator on line 510.8 7500.2 92535.5

8. Unit reserve shutdown hours.

0.0 0.0 909.2

9. Gross thernal energy generated (MWH) 1085560 17405217 193231607

10. Gross electrical energy generated (MWH) 361261 5762990

6254044j, ii. Het electrical energy generated (MWH) 344271 5515817 58471519

12. Reactor service factor 76.1 94.7 80.7

13. Reactor avo11ob111ty factor 76.1 94.7 83.6

14. Unit service factor 70.9 93.6 77.9

15. Unit avo11ob111ty factor 70.9 93.6 78.6

16. Unit capacity factor (Using MDC) 6_;&E 89.5 64.0

17. Unit capacity factor (Using Des.MWe) 60.6 87.2 62.4

10. Unit forced outage rate 8.0 4.4 5.9

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

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

• The iSC not be louer then 769 IRie dering perleds of high edlent tenperatore doe to the thernal perfernance et the spret tenel,

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T OPERATING DATA REPORT DOCKET NO.

50-265 UNIT TWO DATEDECEMBER 5 1985 COMPLETED BYCAROL L. KRONICH_

TELEPHONE (309)654-2241 OPERATING STATUS 0000 110185

1. Reporting period:2400 113085 Gross hours in reporting period:

720 2.

Currently authorized power level (MWt): 2511 Hox. 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 Cumulative 5.

Number of hours reactor was critical 643.8 5617.7 90523.7 6.

Reactor reserve shutdown hours 0.0 0.0 2985.8

7. Hours generator on line 615.3 5504.5

___0?553.6 8.

Unit reserve shutdown hours.

0.0 0.0 702.9 9.

Gross thermal energy generated (MWH) 1431114.

12777515 18429658%

10. Gross electrical energy generated (MWH) 471035 4167213 58820624 ii. Het electrical energy generated (NWH) 450064 3984138 55302123

12. Reactor service factor 89.4 70.1 76,8

13. Reactor avo11ob111ty factor 89.4 70.1 79.3

14. Unit service factor 85.5-68.7 74.2

15. Unit ovellability factor 85.5 68.7 74.8

16. Unit copocity factor (Using MDC) 81.3 64.6 61.0

17. Unit capacity factor (Using Des.MWe) 79.2 63.0 59.4 18!, Unit forced outage rote 14.5 5.4 0.2

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

20. If shutdown at end of report period, estimated date of stortup _____________

$The IWC not k lower then 769 IWe dering perleds of high enblent tenperatore det to the thernal perfernance of the sprer canel.

APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.

50-254 UNIT ONE DATEDECEMBER 5 1985 COMPLETED BYCAROL L.

KRONICH TELEPHONE (309)654-2241 i

NONTH November 1985 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (HWe-Net)

(HWe-Net) i.

805.7 17.

-9.4 2.

749.8 18.

-9.4 3.

569,8 19.

-10.0 4.

703.3 20.

-9.0 5.

727.7 21.

-11.9 6.

788.7 22, 262.7 j

7.

792.0 23.

544.7 8.

798.5 24.

605.9 9.

789.7 25.

154.4 10.

783.9 26.

-11.2 11.

801.2 27.

251.2 12.

774.9 28.

557,6 13.

773.0 29.

661.3 14.

713.6 30.

750.0 15, 21.1 16.

-9.9 INSTRUCTIONS On this forn,llst the enregt dell; init powr level in IRie-ilet for each det in the repsrting math. Compete to the neerest dele negemett.

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Then figeres will be esed to plot a graph for each reporting untk. liete that when notinen dependeble cepetite is used for the set electrical reting of the sait there not e eccesles.s den the dellt everage power leul exceeds the b

100I 11u (or the restricted power leul line),In sech caus,the everage dellt enit power setpet sheet should be f stnoted to esplein the apperent onenelp l

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APPENDIX D AVER AGE DAILY UNIT POWER LEVEL DOCKET NO.

50-265 UNIT TWO DATEDECEMBER 5 1985 COMPLETED BYCAROL L. KRONICH TELEPHONE (309)654-2241 MONTH November 1985 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)

(MWe-Net) 1.

712.3 17, 826.0 2,

652.0 10.

669.0 3.

667.0 19.

032.3 4.

679.4 20.

693.4 5.

686.3 21, 762.2 6.

700.5 22, 770.8 7.

91.6 23.

798.0 8.

-11.2 24.

747.0 9.

-13.6 25, 769.0 10.

-11.0 26.

767.6 11.

107.0 27.

767.5 12.

670.0 20.

776.0 13.

769.6 29.

755.7 14.

790.0 30.

756.2 15, 781.5 16.

754,2 INSTRUCTIONS On Cis fern, list the overop dell mit pwer level in leie-tiet for each der in the reporting Math. Compete to the t

neerest uhele negesett.

These figeres will be sud to plot a graph for tech reporting Math, hte that uhen monian dependable cepecito is esed for the net electrical reting of the onit there net be eccesions when the delly everage peer level exceeds the 100% line (or the restricted pwer lewl line),In noch cases,the everop dellt mit power setpet sheet shoold be l

feCeted to esplein the apparent enenely l

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ID/SA APPENDIX D QTP 300-S13 UNIT Sl!UTDOWNS AND IM'ER REDUCTIONS Revision 6 DOCKET NO. 050-254 August 1982 UNIT NAME Quad-Cities Unit One COMPLETED BY C. Kronich DATE December 9, 1985 REPORT IIONTil NOVEMBER 1985 TELEPl!ONE 309-654-2241 5

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w DURATION E

EVENT 5"

u NO.

DATE (IIOURS)

REPORT NO.

CORRECTIVE ACTIONS / COMMENTS cm 85-59 851103 S

0.0 H

5 RC CONROD Reduced load to 550 MWe for a Control Rod pattern adjustment 85-60 851112 F

0.0 A

5 CH HTEXCH Reduced load due to loss of number 2 Feedwater Heater string 85-61 851115 S

164.67 B

2 XX XXXXXX Unit shutdown for Maintenance Outage (Environmental Qualification) 85-62 851125 F

44.58 A

2 85-19 ZZ ZZZZZZ Unit shutdown due to 1/2 Diesel Generator inoperable, and ID RHR Service Water Pump out of service concurrently 85-63 851130 S

0.0 B

5 HA TURBIN Reduced load to 700 MWe for Turbine surveillances APPROVED AUG 1 G 1982 (final) ygg3g

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IE/5A APPENDIX D QTF 300-S13 UNIT SIIUTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO. 030-265 August 1982 UNIT NAtiE Quad-cities Unit Two COMPLETED BY C. Kronich DATE December 9, 1965 REPORT HONTH NOVEMBER 1985 TE! EPl!ONE 309-654-2241 a:

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NO.

DATE (HOURS)

REPORT NO.

CORRECTIVE AL110NS/COMMENTT o

t,o 85-47 851101 S

0.0 B

5 HA XT.'CGX

, Reduced load for maiatenance on EPC reessurd ie gulator 85-48 851104 F

0. 0 '

B 5

CB PUMPXX Tripped 2B Recirculation Motor-Generator Set due to oil leak 4

4 85-49 851107 S

38.87 B

2 HA XXXXXX Un f, t shutdow. for maintenance on EHC g

, pressure regulator ard 2B Recirculat. ion 851109 F

50.07 B

2 CB PUMPXX Pump seals. A forced shutdown occurred for further maintenance on the 28 Recirculation Pump. seals before the unit i

,')s was placed on line.

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85 50 851130 S

0.0 B

5 HA TURBIN deduceI load to 700 MWe for Turbine survei? lances APPROVED

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AUG 1 G 1982

-I-(final) yGudH b

VI.

UNIQUE REPORTING REQUIREMENTS The following items are included in this report based on prior commitments to the commission:

A.

Main Steam Relief Valve Operations Relief valve operations during the reporting period are summarized in the following table. The table includes information as to which relief valve was actuated, how it was actuated, and the circumstances resulting in its actuation.

Unit: One Date: November 21, 1985 Valve Actuated:

1-203-3A No. 6 Type of Actuation:

1 Manual Plant Conditions: Reactor Pressure - 920 psig Description of Events:

Surveillance, Technical Specification 4.5.D.l.9; Post-Maintenance, Environmental Qualification Work B.

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

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N VII. REFUELING INFORMATION The following information about future reloads at Quad-Cities Station was requested in a January 26, 1978, licensing memorandum (78-24) from D. E.

O'Brien to C. Reed, et al., titled "Dresden. Quad-Cities, and Zion Station--NRC Request for Refueling Information", dated January 18, 1978.

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QTP 300-$32 Revision 1 k

QUAD-CITIES REFUELING March 1978 s.,

INFORMATION REQUEST 1.

Unit:

Q1 Reload:

7 Cycle:

8 2.

Scheduled date for next refueling shutdown:

1-5-86 3

Scheduled date for restart following refueling:

4-2-86 4.

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

YES. A ROUTINE MAPLHGR AMENDMENT WILL BE SUBMITTED AS A PREPARATORY CHANGE TO ALLOW A 10 CFR 50.59 REVIEW OF THE RELOAD.

5 Scheduled date(s) for submitting proposed Itcensing action and supporting Information:

6.

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

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

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NONE PLANNED AT PRESENT TIME.

7 The number of fuel assembiles.

a.

Number of assemblies in core:

724 b.

Number of assemblies in spent fuel pool:

1678 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:

3657 b.

Planned increase in Ilcensed storage:

0 9

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

WPPROVED APR 2.01978 Q. c. o. S. R.

QTP 300-532 i

Revision 1 0.,

QUAD-CITIES REFUELING March 1978 2

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INFORMATION REQUEST l

1.

Unit:

Q2 Reload:

7 Cycle:

8 2.

Scheduled date for next refueIIng shutdown:

10-6-86 3

Scheduled date for restart following refueling:

12-22-86 l.

Will refueling or resumption of operation thereaf ter require a technisal i

specification change or other license amendment:

NOT AS YET DETERMINED.

5.

Scheduled date(s) for submitting proposed licensing action and supporting Information:

SEPTEMBER 19, 1986, IF REQUIRED.

6.

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

• different fuel design or suppIIer, unreviewed design or performance analysis methods, significant changes in fuel design, new operating procedures:

NONE PLANNED AT PRESENT TIME.

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The number of fuel assemblies.

a.

Number of assemblies in core:

724 b.

Number of assemblies In spent fuel pool:

838 8.

The present IIcensed 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:

3897 b.

Planned increase in licensed storage:

0 9

The projected date of the last refueling that can be discharged to the

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spent fuel pool assuming the present Ilcensed capacity: 2003 C

WPPROVED APR 2.01978 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:

ACAD/ CAM -

Atmospheric Containment Atmospheric Ollution/ Containment Atmospheric Monitoring ANSI American National Standards Institute APRM Average Power Range Monitor ATHS Anticipated Transient Without Scram BWR Bolling Water Reactor CRD Control Rod Drive EHC Electro-Hydraulic Control System EOF Emergency Operations Facility GSEP 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 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 Containment Isolation PCIOMR Preconditioning Interim Operating Management Recommendations RBCCH Reactor Building Closed Cooling Water System RBM Rod Block Monitor RCIC Reactor Core Isolation Cooling System RHRS Residual Heat Removal System RPS Reactor Protection System RWM Rod Horth Minimizer SBGTS Standby Gas Treatment System SBLC Standby Liquid Control SDC Shutdown Cooling Mode of RHRS SDV Scram Discharge Volume SRM Source Range Monitor TBCCH Turbine Building Closed Cooling Hater System TIP Traversing Incore Probe TSC Technical Support Center

o O 22710 206 Avenue North Commonwealth Edison Quad Cities Nuclear Power Station Cordova, Illinois 61242 Telephone 309/654-2241 TKT-85-64 December 2, 1985 Director, Office of Inspection & Enforcement United States Nuclear Regulatory Commission Washington, D. C.

20555 Attention: Document Control Desk Gentlemen:

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 November, 1985.

Respectfully, COMMONWEALTH EDISON COMPANY QUAD-CITIES NUCLEAR OWER STATION

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r T. K. Tamlyn Services Superintendent bb Enclosure

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