ML20101E877

Monthly Operating Repts for Nov 1984

ML20101E877
Person / Time
Site:	Quad Cities
Issue date:	11/30/1984
From:	Kalivianakis N, Kimler D COMMONWEALTH EDISON CO., IOWA-ILLINOIS GAS & ELECTRIC
To:	NRC OFFICE OF ADMINISTRATION (ADM), NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
References
NUDOCS 8412260431
Download: ML20101E877 (21)

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l QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT NOVEMBER 1984 COMMONWEALTH EDIS0N C0tiPANY AND IOWA-ILLIN0IS GAS & ELECTd!C COMPANY i

NRCDOCKETNOS.50-254ANU50-265 LICENSE N05. DPR-29 AND DPR-30 k

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o-TABLE OF CONTENTS

-I.

Introduction II. Summary of Operating Experience A.

Unit One B.

Unit Two i

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 I

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 Infomation VIII. Glossary r

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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 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 liarch 21, 1972, respectively; pursuant to Docket Numbers 50-254 and 50-265.

The date of initial Reactor criticalities 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

!! arch 10,1973 for Unit Two.

This report was compiled by Becky Brown and Dave Kinler, telephone number 309-654-2241, extensions 127 and 192.

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SUMMARY

OF OPERATING EXPERIENCE A.

Unit One November 1-13: Unit One began the month holding load. On November 4, at 0130 hours0.0015 days <br />0.0361 hours <br />2.149471e-4 weeks <br />4.9465e-5 months <br />, load was dropped to 700 MWe for weekly Turbine tests. At 0730 hours0.00845 days <br />0.203 hours <br />0.00121 weeks <br />2.77765e-4 months <br />, the unit began a normal load increase to full power. On November 8, at 1355 hours0.0157 days <br />0.376 hours <br />0.00224 weeks <br />5.155775e-4 months <br />, load was dropped to 800 MWe for testing of the Economic Generation Control System. On November 9, at 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />, load was dropped to 680 MRe to perform weekly Turbine tests. At 0230 hours0.00266 days <br />0.0639 hours <br />3.80291e-4 weeks <br />8.7515e-5 months <br /> load was increased to 700 !!We to place the unit on ECC. The unit remained on ECC until November 13, at 1545 hours0.0179 days <br />0.429 hours <br />0.00255 weeks <br />5.878725e-4 months <br />.

November 14-30: On November 15, at 1840 hours0.0213 days <br />0.511 hours <br />0.00304 weeks <br />7.0012e-4 months <br />, load was dropped to 740 IIWe to place the unit in ECC. On November 17, at 2330 hours0.027 days <br />0.647 hours <br />0.00385 weeks <br />8.86565e-4 months <br />, the unit was off ECC and load was dropped to 70018h3 for weekly Turbine tests. 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 in ECC again.

On November 22, at 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />, load was dropped to 700 t!We for weekly Turbine tests. At 0100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> the unit was placed in EGC.

The unit remained in EGC until November 30.

B.

Unit Two November 1-11: Unit Two began the month increasing load 5 MWe/ hour to maximum load. On November 2, at 2150 hours0.0249 days <br />0.597 hours <br />0.00355 weeks <br />8.18075e-4 months <br />, load was dropped to 700 inh 3 for weekly Turbine tests. On November 3, at 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />, load was dropped to 200 MWe to repair the 2B Moisture Separator Drain Tank Valvo. At 2225 hours0.0258 days <br />0.618 hours <br />0.00368 weeks <br />8.466125e-4 months <br /> the unit began increasing load to full power. On November 11, at 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />, load was dropped to 700 MWe for weekly Turbine tests. At 0300 hours0.00347 days <br />0.0833 hours <br />4.960317e-4 weeks <br />1.1415e-4 months <br />.the unit began a normal load increase to full power.

November 12-30: On November 18, at 2315 hours0.0268 days <br />0.643 hours <br />0.00383 weeks <br />8.808575e-4 months <br />, load was dropped to 700 IIUe for weekly Turbine tests. At 0300 hours0.00347 days <br />0.0833 hours <br />4.960317e-4 weeks <br />1.1415e-4 months <br /> the unit began a normal load increase to full power. On November 22, at 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />, load was dropped to 700 !!We for weekly Turbine tests.

At 0205 hours0.00237 days <br />0.0569 hours <br />3.38955e-4 weeks <br />7.80025e-5 months <br /> the unit began a 5 IIWe/ hour ramp increase to full power.

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-III. ' PLANT OR PROCEDURE CHANGES. TESTS. EXPERIMENTS, AND SAFETY

.RELATED MAINTENANCE A.

Amendments to Facility License or Technical' Specifications

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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 following headings: Work Request Numbers, LER Numbers, Components, Cause of 11alfunctions, 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 l

W.R.

LER OF ON

. ACTION TAKEN.TO-(

NUMBER NUMBER COMPONENT MALFUNCT10N SAFE OPERAT10N PREVENT REPETIT10N-Q38968 1-2301-48 Valve; Unknown IIPCI remaind operable.

Inspected but no l

Troubleshoot &

problem was found.

Found No Problem l

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UNIT TWO MAINTENANCE

SUMMARY

CAUSE RESULTS & EFFECTS W.R.

LER OF ON '

ACTION TAKEN'TO NUMBER NUM8ER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION I

.Q37683 Repaired Operator Mounting bolts The Control Room NSO Removed operator to Stem Connection between the operator was still capable of

-maintenance shop --

on H0.2-1001-18A and valve yolk lining up a minimum repaired and're-installed.

Valve failed.

flow path for the RHR

. Pump.

i Q37859 Adjusted Limit Limit switches out Indication was not.

Adjusted limit' switches..

Switches on the of adjustment, accurate but, valve 2-1601-33D Valve operation was maintained, i

Q38214 Replaced CRD K-13 LER 84-10 corrective CRD K-13 did not Revised Procedure QGP 2-4.

38-51 S/N 3-186 action required this immediately insert Survey HCU Manual Valves-i With'S/N 1935 replacement.

completely. Core daily; list of corrective

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reactivity was under action in LER i

control and Reactor

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uas in SHUIDOWN.

i Q38474 Installed Neu

_ Relay coil wire had Relay failed safe.

Replaced relay with.a 1

j Relay 2-590 lamination better coil (Sentury '

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degradation causing Series). There is a L

i a short.

program in progress to retrofit all the~RPS 1

HEA-type relays with t

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this improved coil.

l Q35347 CRD L-9 Not De-Several K1 Relays Were capable of. moving Replaced K1 Relays, j

Select Uhen E-9 were found to be two CRD's; this j

was Selected dirty.

effected' manual operation only. Auto-l matic shutdoun was j

always available.

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

Unit Two 84-11 11-30-84 Unit 2 'B' Fuel Pool Honitor Tripped I

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

A.

Operating Data Report B.

Average Daily Unit Power Level C.

Unit Shutdowns and Power Reductions 9

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4 OPERATING DATA REPORT DOCKET NO.

50-254 UNIT ONE DATEDecember 4 COMPLETED BYDAVE KIMLER TELEPHONE 309-654-2241x192 OPERATING STATUS 0000 110184 1.

Reporting period:2400 113084 Gross hours in reporting period:

720 2.

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

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 720,0 4077,9 87633,5

6. Reactor reserve shutdown hours 0,0 0,0 3421,9

7. Hours generator on line 720,0 4028,2 84376,1

8. Unit reserve shutdown hours.

0,0 0,0 909.2 9.

Gross thermal energy generated (MWH) 1665199 9175174 174201880

10. Gross electrical energy generated (MWH) 549782 3035797 56294413

11. Net electrical energy generated (MWH) 529253 2888077 52494044

12. Reactor service factor 100,0 50,7 79,6

13. Reactor availability factor 100,0 50,7 82,7

1. 4. Unit service factor 100,0 50,1 76,6

15. Unit evollability factor 100,0 50,1 77,5 1

16. Unit capacity factor (Using MDC) 95,6 46.7 62,0

)

17. Unit capacity factor (Using Des.MWe) 93.2 45,5 60,4 l

10. Unit forced outage rate 0,0 1.1 6,0

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

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

• The MDC nay be lower than 769 MWe dering perleds of high opbient tenperatere det to the thernal perfarnance of the spray canal,

$UN0FflCIAL COMPANY NUMBERS ARE USED IN THIS REPORT L

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L OPERATING DATA REPORT l

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50-265 L

UNIT TWO DATEDecember 4 COMPLETED BYDAVE KIHLER TELEPHONE 309-654-2241x192 OPERATING STATUS 0000 110184 1.

Reporting period:2400 113084 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 Cunulative 5.

Number of hours reactor was critical 720.0 6429.6 84347.i 6.

Reactor reserve shutdown hours 0.0 0.0 2985.8 7.

Hours generator on line 720.0 6301.0 81510.8 8.

Unit reserve shutdown hours.

0.0 0.0 702.9 9.

Gross thermal energy generated (MWH) 1719081 14857745 170239833 l

10. Gross electrical energy generated (MWH) 560237 4797216 54232996

11. Net electrical energy generated (MWH) 540001 4581910 50915970 i

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12. Reactor service factor 100.0 0 0 u_

77.3

13. Reactor availability factor 100.0 80.0 00d

14. Unit service factor 100.0_

70.4 74.7

15. Unit availability factor 100.0 70.4 75.3

16. Unit capacity factor (Using MDC) 97.5 74.1 60.6

17. Unit capacity factor (Using Des.HWe) 95.1 72.2 59.1

10. Unit forced outage rate 0.0.

3.3 0,2 l

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

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20. If shutdown at end of report period,estinated date of startup NA tiht MDC my be lower than 769 MWe dering perleds of high onblent temperature due to the therm 1 performAct of the spray canal.

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APPENDIX B

. AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.

50-254 a

-UNIT ONE DATEDecember 4 s

COMPLETED BYDAVE KIMLER TELEPHONE 309-654-224ix192 MONTH November 1984 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)

(MWe-Net) 1.

794.6 17.

698.6

~2.

789.5 18, 700.8 3.

786.6 19, 772.5 4.

751.0 20.

698.6 5.

793.5 21.

779.6 6.

785.0 22.

697.5 7.

787.0 23.

706.0 8.

755.7 24, 689.5 9.

682.3 25, 717.6 10, 696.8 26.

697.4 Li, 707.6 27, 696.2 12, 710.4 28.

709.3 13, 715.7 29.

687.4

'l4.

769.5 30.

695.9 15.-

006.5 16.

669.0 INSTRUCTIONS On this fern,Ilst the everage delly init powr level in IWe-Net for each day in the reporting nenth.Cenpete to the neerest whole negewett.

TheM flgeres will be esed te plot a graph for eeth reporting nenth. Note that when notinen dependeble cepetite is sted for the net electrical reting of the init there ney be ecceslens when the delly everage power level exceeds th 1001 line (or the restricted power level line).,In sich cases,the everage delly enit power setpet sheet sheeld be festnoted to esplein the apperent onenelp u

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-i APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.

50-265 UNIT TWO DATEDecember 4 COMPLETED BYDAVE-KIMLER TELEPHONE 309-654-2241xi92 MONTH November 1984 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)

(MWe-Net) 1.

772.1 17.

777.7 2.

758.6 18.

756.8 3.

212.2 19, 796.4 4.

495.5 20, 774.5 5.

698.6 21.

785.8 6.

764,9 22, 713.7 7.

770.4 23.

783.9 8.

767.8 24, 782.9 9.

767.4 25.

785.4 10, 772.6 26, 785.7

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762.4 27.

789,3 12.

783.6 28.

789.3 13, 789.6 29.

787.8 14, 782.1 30.

781.5 15.,

825.0 16.

752,3 INSfRUCTIONS On this forn, list the aurage daily snit power level in PWe-Net for each day in the reporting nonth. Compute to the nearest whole negawatt.

These figsres Will be ssed te plot a graph for each reperting nonth. Note tMt when narinen dependcble capacity is ssed for the net electrical rating of the snit there not be occasiens when the hily overage power level escuds th 191% line (or the restricted power level line).,In sich cases,the overage daily snit power setput sheet should be festnoted to explain the apparent ansnaly

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M M

M M

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,M ID/5A APPENDIX D QTP 300-S13 UNIT SilUTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO.

050-254 August 1982 UNIT NAME Quad-Cities Unit 1 COMPLETED BY D. Kimler DATE December 5, 1984 REPORT MONTil NOVE!!BER 1984 TELEPil0NE 309-654-2241 N

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DURATION EVENT

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NO.

DATE (110URS)

REPORT NO.

CORRECTIVE ACTIONS /C0titlENTS ca 84-32 841104 S

0.0 B

5 IIA TURBIN Reduced load to perform weekly Turbine tests 84-33 841108 S

0.0 B

5 XX ZZZZZZ Reduced load to perform tests on Economic Generation Control System 84-34 841109 S

0.0 B

5 IIA TURBIN Reduced load to perform weekly Turbine tests 84-35 841115 S

0.0 B

5 XX ZZZZZZ Reduced load to place-the unit in ECC 84-36 341117 S

0.0 B

5 IIA TURBIN Reduced load to perform weekly Turbine tests 84-37 841122 S

0.0 B

5 IIA TURBIN Reduced load to perform weekly Turbine tests APPROVED AUG 1 G 1982 (final) ygg3g

E'"'S P""1 F"t P"*1 m

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M M

M M

M M

M M

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ID/5A APPENDIX D QTP 300-S13 UNIT S!!UTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO.

050-265 August 1982 UNIT NAME Quad-Cities Unit Tw COMPLETED BY D. Kimler DATE December 5, 1984 REPORT MONTil NOVEMBER 1984 TELEPlIONE 309-654-2241 N

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DURATION d

EVENT u

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DATE (liOURS)

REPORT NO.

CORRECTIVE ACTIONS / COMMENTS oo 84-53 841102 S

0.0 B

5 IIA TURBIN Reduced load to perform weekly Turbine tests 84-54 841103 S

0.0 B

5 CC VALVEX Reduced load to repair the 2B Moisture Separator Drain Tank Valve 84-55 841111 S

0.0 B

5 liA TURBIN Reduced load to perform weekly Turbine tests 84-56 841118 S

0.0 B

5 IIA TURBIN Reduced load to perform weekly Turbine tests 84-57 841122 S

0.0 B

5 IIA TURBIN Reduced load to perform weekly Turbine tests APPROVED AUG 1 G 1982 (final) y g, g 3 g

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l 1VI. UNIQUE REPORTING' REQUIREMENTS The following iteme n e included in this' report based on prior commitments.to the commission:

A.

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

B.

CONTROL R0D DRIVE ' SCRAM TIMING DATA FOR UNITS ONE-AND TWO There was no Control Rod Drive Scram Tining Data for Un!ts One.and Two for the reporting period.

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REFUELING INFORtfATION 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 Infonnation",

dated January 18, 1978.

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r, QTP 300-S32-l Rsvision 1 QUAD-CITIES REFUELitG.

March 1978 INFORMATION REQUEST ~

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1.

Unit:

Q1 Reload:

7 Cycle:

8 1-2-86 2.

Scheduled date for next refueling shutdown:

3 Scheduled date for restart following refueling:

4-2-86 4.

Will refueling or resumption of cperation thereaf ter require a technical specification change or other license amendment:

NOT AS YET DETERMINED.

5.

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

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information:

DECEMBER 19, 1985; IF LICENSING ACTION REQUIRED.

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6.

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

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

NONE PLANNED AT PRESENT TIME.

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The numbe of fuel assemblies.

a.

Number of assemblies in core:

724 b.

Number of assemblies in spent fuel pool:

2340 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 licensed storage:

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

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XPPROVED APR 2 01978 G3. CL C). S. R.

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QTP 300-S32 l

Rsvision 1 l

QUAD-CITIES REFUELING March 1978

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INFORMATION REQUEST F

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Unit:

2 Reload:

7 Cycle:

8 2.

Scheduled date for next refueling shutdown:

4-2-85

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3 Scheduled date for restart following refueling:

6-22-85 4.

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

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Not as yet determined.

c.

5 Scheduled date(s) for submitting proposed licensing action and supporting 9

Information:

5 January 18, 1985, if licensing action required.

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6.

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

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

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

Hone planned at present time.

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The number of fuel assemblies.

r a.

Number of assemblies in core:

724 a

b.

Number of assemblies in spent fuel pool:

0 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 4-in number of fuel assemblies:

a.

Licensed storage capacity for spent fuel:

3897 2

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Planned increase in licensed storage:

0 u

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

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spent fuel pool assuming the present licensed capacity:

2003 APPROVED b APR 2 01978 CD.C:.C).53.FR.

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VIII. GLOSSARY:

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

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

American' National Standards Institute APRM Average Power Range Monitor ATWS Anticipated Transient Without Scram Boiling Water Reactor BWR CRD Control Rod Drive EHC Electro-Hydraulic Control System E0F 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 Licensee Event Report LER LLRT Local Leak Rate Test LPCI Low Pressure Coolant Injection Mode of RHRS Local Power Range Monitor LPRM 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 National Institute for Occupational Safety and Health NIOSH 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 Residual Heat Removal System RHRS RPS Reactor Protection System RWM Rod Worth Minimizer.

SBGTS Standby Gas Treatment System SBLC Standby Liquid Control SDC Shutdown Cooling Mode of RHRS SDV Scram Discharge Volume SRM Source Range Monitor

-TBCCW Turbine Building Closed Cooling Water System TIP Traversing Incore Probe-TSC Technical Support Center

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O Commonwealth Edison Quad Cities Nucle:r P;wer St:ti:n 1

22710 206 Avenue North Cordova, Illinois C1242 Telephone 309/654-2241 NJK-84-367 December 3, 1984 Director, Office of Inspection & Enforcement United States Nuclear Regulatory Commi.ssion Washington, D. C.

20555 Attention:

Document Control Desk Gentlemen:

Enclosed for your infomation is the Monthly Perfomance Report covering the operation of Quad-Cities Nuclear Power Station, Units One and Two, during the month of November 1984.

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

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