ML20135G133

Monthly Operating Repts for Aug 1985

ML20135G133
Person / Time
Site:	Quad Cities
Issue date:	08/31/1985
From:	Kronich C, Tamlyn T COMMONWEALTH EDISON CO.
To:	NRC OFFICE OF ADMINISTRATION (ADM), NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
References
TKT-85-46, NUDOCS 8509180190
Download: ML20135G133 (28)

Text

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O QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT AUGUST 1985 COMMONWEALTH EDISON COMPANY AND t0WA-ILLIN0IS GAS & ELECTRIC COMPANY NRC DOCKET NOS. 50-254 AND 50-265 LICENSE NOS. DPR-29 AND DPR-30

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1 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 Speci.'ications 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 Information VIII.

Glossary

a s

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 Bolling Hater Reactors.

The

-l 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, j

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 generatioa of power began on February 18, 1973 for Unit One and March 10, 1973 for Unit Two.

This report was compiled by Becky Brown and Carol Kronich, telephone number 309-654-2241, extensions 127 and 193.

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SUMMARY

OF OPERATING EXPERIENCE A.

Unit One August 1-8 Unit One began the month of August holding load near full pover. On August 3, at 0345 hours0.00399 days <br />0.0958 hours <br />5.704365e-4 weeks <br />1.312725e-4 months <br />, the unit was placed on Economic Generation Control (EGC). EGC was tripped on August 4 at 0410 hours0.00475 days <br />0.114 hours <br />6.779101e-4 weeks <br />1.56005e-4 months <br /> and load was dropped to 700 MWe to perform Turbine surveillances. At 1000 hours0.0116 days <br />0.278 hours <br />0.00165 weeks <br />3.805e-4 months <br /> load began an increase to 750 MWe at 100 MWe/ hour. At 1045 hours0.0121 days <br />0.29 hours <br />0.00173 weeks <br />3.976225e-4 months <br /> the unit was placed back in EGC. At 2315 hours0.0268 days <br />0.643 hours <br />0.00383 weeks <br />8.808575e-4 months <br /> ECC was tripped. On August 5, at 0215 hours0.00249 days <br />0.0597 hours <br />3.554894e-4 weeks <br />8.18075e-5 months <br />, load began a decrease at 150 MWe/ hour to 625 MWe as per the Load Dispatcher. At 0500 hours0.00579 days <br />0.139 hours <br />8.267196e-4 weeks <br />1.9025e-4 months <br /> load was increased 100 MWe/ hour to 700 MWe and at 0600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br /> Joad began an increase at 5 MWe/ hour to: full power. Eight hundred sixteen MWe was reached and held at 2010 hours0.0233 days <br />0.558 hours <br />0.00332 weeks <br />7.64805e-4 months <br />.

August 9-15 On August 9, at 0010 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />, load was decreased at 100 MWe/ hour to 700 MWe and at 0045 hours5.208333e-4 days <br />0.0125 hours <br />7.440476e-5 weeks <br />1.71225e-5 months <br /> load continued a decrease at 100 FMe/ hour to 600 MWe for a rod p3ttern adjustment. At 0230 hours0.00266 days <br />0.0639 hours <br />3.80291e-4 weeks <br />8.7515e-5 months <br /> load was held at 600 MWe until 0500 hours0.00579 days <br />0.139 hours <br />8.267196e-4 weeks <br />1.9025e-4 months <br /> when load began a normal increase to full power.

Eight hundred eleven MWe were reached on August 10, at 2315 hours0.0268 days <br />0.643 hours <br />0.00383 weeks <br />8.808575e-4 months <br />, and held steady until August 14, at 0200 hours0.00231 days <br />0.0556 hours <br />3.306878e-4 weeks <br />7.61e-5 months <br /> when load began a decrease.

to 600 MWe as per the Load Dispatcher.

Six hundred MWe was reached at 0330 hours0.00382 days <br />0.0917 hours <br />5.456349e-4 weeks <br />1.25565e-4 months <br />. At 0535 hours0.00619 days <br />0.149 hours <br />8.845899e-4 weeks <br />2.035675e-4 months <br /> load began a normal increase to full power.

Eight hundred eleven MWe was reached at 1600 hours0.0185 days <br />0.444 hours <br />0.00265 weeks <br />6.088e-4 months <br />, and was held until August 15, at 0145 hours0.00168 days <br />0.0403 hours <br />2.397487e-4 weeks <br />5.51725e-5 months <br />, when load began a drop at 150 MWe/ hour to

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600 MWe as per the Load Dispatcher. At 0315 hours0.00365 days <br />0.0875 hours <br />5.208333e-4 weeks <br />1.198575e-4 months <br />, 600 MWe was reached and Fa.'.d until 0430 hours0.00498 days <br />0.119 hours <br />7.109788e-4 weeks <br />1.63615e-4 months <br />, when load began an increase at 100 MWe/ hour to 730 MWe. At 0550 hours0.00637 days <br />0.153 hours <br />9.093915e-4 weeks <br />2.09275e-4 months <br /> 730 MWe was reached and held until 0800 hours0.00926 days <br />0.222 hours <br />0.00132 weeks <br />3.044e-4 months <br />, when load was. increased 5 MWe/ hour. At 1400 hours0.0162 days <br />0.389 hours <br />0.00231 weeks <br />5.327e-4 months <br />, load was steady at 740 MWe. At 1930 hours0.0223 days <br />0.536 hours <br />0.00319 weeks <br />7.34365e-4 months <br /> load was decreased from 750 MWe to 650 MWe for rod pattern maneuvers. Load was holding steady at 650 MWe at 2015 hours0.0233 days <br />0.56 hours <br />0.00333 weeks <br />7.667075e-4 months <br />.

August 16-31 i

On August 16, at 0045 hours5.208333e-4 days <br />0.0125 hours <br />7.440476e-5 weeks <br />1.71225e-5 months <br />, load began a normal increase from 650 MWe

- to 813 MWe at 1800 hours0.0208 days <br />0.5 hours <br />0.00298 weeks <br />6.849e-4 months <br />. On August 17,'at 0100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br />, load was dropped to 800 MWe and the unit was placed on EGC. At 1614 hours0.0187 days <br />0.448 hours <br />0.00267 weeks <br />6.14127e-4 months <br /> EGC was tripped at 794 MWe and increased 5 MWe/ hour until a load of 809 MWe was reached at 2115 hours0.0245 days <br />0.588 hours <br />0.0035 weeks <br />8.047575e-4 months <br />. On August 18 at 1622 hours0.0188 days <br />0.451 hours <br />0.00268 weeks <br />6.17171e-4 months <br />, the unit was placed on EGC until' August 22, at 1250 hours0.0145 days <br />0.347 hours <br />0.00207 weeks <br />4.75625e-4 months <br />, when a GSEP Unusual Event was declared due to a RHR room cooler being taken out of service causing the 'B' loop of RHR to be inoperable. A normal shutdown was started by

. decreasing load 10 MWe/ hour.

The shutdown was terminated when the RHR

. room cooler was declared operable at 1545 hours0.0179 days <br />0.429 hours <br />0.00255 weeks <br />5.878725e-4 months <br />.. At 1605 hours0.0186 days <br />0.446 hours <br />0.00265 weeks <br />6.107025e-4 months <br /> load was p-v yryy rw-

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5 A.' Unit One IAugust 16-31 (continued) increased 20 MWu, and then 5 MWe/ hour.. At 1825 hours0.0211 days <br />0.507 hours <br />0.00302 weeks <br />6.944125e-4 months <br /> the unit was placed on EGC.; On August 24, at 0055 hours6.365741e-4 days <br />0.0153 hours <br />9.093915e-5 weeks <br />2.09275e-5 months <br />, the unit was taken off ECC and began a load drop at 150 MWe/ hour to 600 MWe for~a rod shuffle. At 0155 hours0.00179 days <br />0.0431 hours <br />2.562831e-4 weeks <br />5.89775e-5 months <br /> load was holding at:600 MWe, and at 0330 hours0.00382 days <br />0.0917 hours <br />5.456349e-4 weeks <br />1.25565e-4 months <br /> load beganLa normal increase to full. power. Eight hundred twenty-one MWe was reached on i

August 26, at 0015 hours1.736111e-4 days <br />0.00417 hours <br />2.480159e-5 weeks <br />5.7075e-6 months <br />, and was held steady until August 30 at 0840 hours0.00972 days <br />0.233 hours <br />0.00139 weeks <br />3.1962e-4 months <br /> when load was dropped to 800 MWe, and the unit was placed on EGC at j

0905 hours0.0105 days <br />0.251 hours <br />0.0015 weeks <br />3.443525e-4 months <br />. ECC was tripped at-1725 hours due-to a loss of condenser vacuum. Load was dropped to 525 MWe. At 1805 hours0.0209 days <br />0.501 hours <br />0.00298 weeks <br />6.868025e-4 months <br /> load began an increase to 750 MWe at 200 MWe/ hour. seven hundred fifty MWe was reached j

4 at 1905 hours0.022 days <br />0.529 hours <br />0.00315 weeks <br />7.248525e-4 months <br /> and at 1915 hours0.0222 days <br />0.532 hours <br />0.00317 weeks <br />7.286575e-4 months <br /> the unit was placed on EGC fcr the remainier of the month.

B.

Unit Two j

August 1-15 i

Unit Two began the month _on Economic Generation Control (EGC). On August 1, at 1105 hours0.0128 days <br />0.307 hours <br />0.00183 weeks <br />4.204525e-4 months <br />, EGC was tripped and load was increased 5 MWe/ hour to full power. :At 1135 hours0.0131 days <br />0.315 hours <br />0.00188 weeks <br />4.318675e-4 months <br />, 815 MWe was reached and held staady until j~

surveillances at 100 MWe/ hour. Seven hundred NWe was reached at 0150 August 3, at 0045 hours5.208333e-4 days <br />0.0125 hours <br />7.440476e-5 weeks <br />1.71225e-5 months <br />, when load was dropped to 700 MWe for Turbine i

hours, and was held until 0400 hours0.00463 days <br />0.111 hours <br />6.613757e-4 weeks <br />1.522e-4 months <br />, when load was dropped to 600 MWe at 200 MWe/ hour as per the Load Dispatcher. At 0430 hours0.00498 days <br />0.119 hours <br />7.109788e-4 weeks <br />1.63615e-4 months <br /> load was decreased further to minimum load at 50 MWe/ hour to 550 MWe, and then 150 MWe/ hour to minimum speed. At-0500 hours load was steady at 550 MWe. At 0630 hours0.00729 days <br />0.175 hours <br />0.00104 weeks <br />2.39715e-4 months <br /> load began a normal increase to 780 MWe, which was reached at 1530 hours0.0177 days <br />0.425 hours <br />0.00253 weeks <br />5.82165e-4 months <br /> i

and held steady. On August 5, at 1640 houra, load was increased at 50 MWe/ hour to full power. Eight hundred eighteen MWe was reached at 1750 i

hours and remained steady until August 7, at 0315 hours0.00365 days <br />0.0875 hours <br />5.208333e-4 weeks <br />1.198575e-4 months <br />, when load began a decrease at 100 MWe/ hour to 700 MWe as per the Load Dispatcher. At 0415 houre the load decrease wcs terminated, and at 0425 hours0.00492 days <br />0.118 hours <br />7.027116e-4 weeks <br />1.617125e-4 months <br /> load began an increase at 100 MWe/ hour to 800 MWe, then increase 5 MWe/ hour to j.

maximum power.

Eight hundred twelve MWe was reached at 0810 hours0.00938 days <br />0.225 hours <br />0.00134 weeks <br />3.08205e-4 months <br /> and 4

Ewas held steady until August 15, at 0025 hours2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br />.

l August 15-31 On August 15, at 0025 hours2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br />, the unit was placed on EGC. _On August 19, at 0630 hours0.00729 days <br />0.175 hours <br />0.00104 weeks <br />2.39715e-4 months <br />, the unit went off EGC as per the Load Dispatcher, and load was increased to maximum power at 5 MWe/ hour, and held until August 22, at 0220 hours0.00255 days <br />0.0611 hours <br />3.637566e-4 weeks <br />8.371e-5 months <br />, when load was dropped to 790 MWe and placed on EGC at'0236_

t hours..On August 25, at 0030 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />, EGC was tripped and load began a decrease at 100 MWe/ hour to 700 MWe for Turbine surveillances. Seven hundred MWe was reached at 0115 hours0.00133 days <br />0.0319 hours <br />1.901455e-4 weeks <br />4.37575e-5 months <br />. At 0245 hours0.00284 days <br />0.0681 hours <br />4.050926e-4 weeks <br />9.32225e-5 months <br /> load began a decrease at 100 MWe/ hour to 600 MWe for a Condensate Domineralizer change over. Six hundred MWe was reached at 0340 hours0.00394 days <br />0.0944 hours <br />5.621693e-4 weeks <br />1.2937e-4 months <br />, and at 0930 hours0.0108 days <br />0.258 hours <br />0.00154 weeks <br />3.53865e-4 months <br /> load

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Unit Two August 15-31 (continued) load began a normal increase to 800 MWe.

On August 27, at 0116 hours0.00134 days <br />0.0322 hours <br />1.917989e-4 weeks <br />4.4138e-5 months <br />, full power was reached and held ateady. At 0805 hours0.00932 days <br />0.224 hours <br />0.00133 weeks <br />3.063025e-4 months <br /> load was decreased at 100 MWe/ hour to 790 MWe in preparation for EGC. At 0830 hours0.00961 days <br />0.231 hours <br />0.00137 weeks <br />3.15815e-4 months <br /> 790 MWe was reached, and the unit was placed on ECC at 0847 hours0.0098 days <br />0.235 hours <br />0.0014 weeks <br />3.222835e-4 months <br />. On August 28, at 1803 hours0.0209 days <br />0.501 hours <br />0.00298 weeks <br />6.860415e-4 months <br />, EGC was tripped and load was decreased by 100 MWe/ hour to minimum speed for a Condensate pump change over. On August 29, at 0420 hours0.00486 days <br />0.117 hours <br />6.944444e-4 weeks <br />1.5981e-4 months <br />, load began a normal increase to full power.. On August 30, at 0915 hours0.0106 days <br />0.254 hours <br />0.00151 weeks <br />3.481575e-4 months <br />, 820 MWe was reached. AT 1132 hours0.0131 days <br />0.314 hours <br />0.00187 weeks <br />4.30726e-4 months <br /> the unit was placed on ECC and remained on EGC for the remainder of August.

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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.

UNIT 1

MAINTENANCE SUWARY l

l CAUSE RESULTS & EFFECTS

~~~

l W.R.

LER OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION Q42109 85-02 1-733-4; No. 4 Stuck Ball Valve.

No. 4 TIP Ball Valve.

No. 4 TIP Ball Valve was TIP Machine Ball due to lack of failed to close.

cleaned, lubricated, re-Valve lubrication.

Primary Containment installed, and tested isolation available, satisfactorily.

Q42846 1-3903 Unit 1 Electrical short Cooling water pump would Failed motor.was replaced.

Diesel Genera-in the pump motor not start.

1/2 Diesel New motor tested and declared tor Cooling windings due to Generator Cooling Water operable. Also, SEE Work Pump Motor excessive wear of Pump was available.

Request Q42760.

front bearings.

Q42896 1-1001-37B Stem nut locking Could not open valve.

Tightened the stem nut locking Failed to Open; nut came loose Declared GSEP Unusual nut and securing it, manual Torus Spray causing stem to Event and started trip lever adjusted, and Shutoff Valve bind which tripped shutdown.

bearings.

thermal loads.

Q42955 85-03 1/2-7503B Wiring problem -

Auto-start relay 595-Heater breaker replaced.

'B' Standby phase to ground 133 contacts were Auto-start relay replaced.

Gas Treatment short. Heater degraded, causing inter-Heater breaker did not mittent start failures.

energize.

4 Q43063 85-08 1-1001-65C Broken vent line 1B/lC RHR Service Water Replaced vent line with new RHR Service on pump sprayed Pump Vault partially piping.

Water Pump water on 1/2 filled with water.

Diesel Generator 1C pump tripped, 1B pump Cooling Water taken out of service and Pump motor and on 1/2 Diesel Generator Cooling

'B' RHR Service Water Pump taken out of service.

Water Pump.

Declared GSEP Unusual Event.

L.C.O. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> shutdown.

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0027H/0061Z L

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UNIT 1

MAINTENANCE SUWARY CAUSE RESULTS & EFFECTS W.R.

LER OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION

-Q43492 FIC 1-2340-1 HPCI Personnel error.

Turbine speed was still Reprimands issued where Flow Controller Flow controller governed by a potentio-cecessary.

in " MANUAL" had been left in meter. Therefore, HPCI MANUAL after Work flow was still available.

Request Q43492 was completed.

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0027H/0061Z-

UNIT 2

MAINTENANCE

SUMMARY

CAUSE RESULTS & EFFECTS W.R.

LER OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION Q41307 85-07 A0 2-8804 Very dirty (rusty)

Failed Local Leak Rate Cleaned the valve and seat Oxygen Analyzing valve internals.

Tests during Unit 2 surfaces.

Seat surfaces

-Valve Bad gasket material Refuel Outage.

were lapped.

across seat.

Q41308 85-07 A0 2-8801C Very dirty (rusty)

Failed Local Leak Rate Cleaned the valve and seat Oxygen Analysing valve internals.

Tests during Unit 2 surfaces. Seat surfaces Valve Bad gasket material Refuel Outage, were lapped, across seat.

Q41309 85-07 A0 2-8802C Very dirty (rusty)

Failed Local Leak Rate Cleaned the valve and seat Oxygen Analyzing valve internals.

Tests during Unit 2 surfaces. Seat surfaces Valve Bad gasket material Refuel Outage.

were lapped.

across seat.

Q41454 2-260-10A APRM Found seven bad Upscale alarm light Calibrated spare flow Flow Convertor resistors in and comparator alarm convertor, circuitry.

light could be reset with alarm condition.

Q41927 85-07 A0 2-1601-60 Old valve seat was Failed Local Leak Rate Replaced valve with a new Torus Exhaust worn out from use, Tests during Unit 2 valve.

Valve time, and heat.

Refuel Outage.

Q42341 85-07 A0 2-1601-24 Valve was dirty.

Failed Local Leak Rate Valve was replaced.

Vulcanized rubber Tests during Unit 2 seats were hard Refuel Outage.

and non-resilient.

Q42345 85-07 A0 2-1601-63 Valve was dirty.

Failed Local Leak Rate Valve was replaced.

Vulcanized rubber Tests during Unit 2 seats were hard Refuel Outage.

and non-resilient.

00?7H/0061Z

UNIT 2

MAINTENANCE

SUMMARY

CAUSE RESULTS & EFFECTS W.R.

LER OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION Q42494 85-013 2-6601 Unit 2 Governor While testir.g. the Diesel Governor compensating Diesel Generator compensating Generator tripped off.

mechanism adjusted and.

mechanism out of mechanically on overspeed. Diesel Generator tested.

adjustment due to Since 1/2 Diesel Generator normal operational was out of service, declared wear.

GSEP Unusual Event.

Q42979 2-1001-65C RHR Stress induced Leak developed in the vent Defective pipe nipple Service Water cracking.

line. Remaining A, B, and removed; rethreaded and Vent Line Vibration of D RHR Service Water Pumps-re-installed.

pump.

were operable.

0027H/0061Z

o.

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.l. and 6.6.5.2. of the Technical Specifications.

UNIT ONE Licensee Event Report Number Date Title of Occurrence 85-11 8-2-85 RCIC Trip From High 8-4-85 Exhaust Pressure 85-13 8-30-85 RCIC Turbine Trip I,

UNIT TWO

-Licensee Event Report Number Date Title of Occurrence 85-17 8-15-85 Cleanup System Shut-down 85-18 8-26-85 Low Condenser Vacuum Setpoint Drift i

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V.

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

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A.

Operating Data Report.

B.

Average Daily Unit Power Level C.

Unit Shutdowns and Power Reductions 1

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OPERATING DATA REPORT DOCKET NO.

50-254 UNIT ONE DATEAUGUSF 4 1985 COMPLETED BYCAROL L.

KRONICH TELEPHONE 309/654-2241X193 OPERATING STATUS 0000 080185 1.

Renorting period:2400 083185 Gross hours in. reporting period:

744 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.

Number of hours reactor was critical 744.0 5582.0 93904.4 6.

Reactor reserve shutdown hours 0.0 0.0 3421.9 7.

Hours generator on line 744.0 5524.4 90559.7 8.

Unit reserve shutdown hours.

0.0 0.0 909.2 9.

Gross thermal energy generated (MWH) 1782567 12988821 180735211

10. Gross electrical energy generated (MWH) 583218 4276786 61054237

11. Net electrical energy generated (MWH) 5.8519 4094621

.570503_23

12. Reactor service factor 100.0 95.7 80.5

13. Reactor ovallobility factor 100.0 95.7 83.4

14. Unit service factor 100.0 94.7 77.6

15. Unit ovallobility factor 100.0 94.7 78.4

16. Unit capac'ity factor (Using MDC) 97.6 91.3 63.6

17. Unit copocity factor (Using Des.MWe) 95.1.

89.0 62.0

18. Unit forced outoge rate 0.0 5.2 6.0

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

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

• The EC ncy be lower thcn 769 MWe during perisds of high cnblent temperature die 9e the thernal performarce of the spray ccnol.

$ UNOFFICIAL COMPANY NUMEERS ARE USED IN THIS REPORT l

i

i OPERATING DATA REPORT DOCKET NO.

50-?65 UNIT TWO DATEAUGUST 4 1985.. _

COM?LETED BYCAROL L. KRONIf['i TELEPHONE 309/654-2241Xi93 UPERATING STATUS 0000 080105 1,

R2corting perlod: 2400 003105 Gross hours in reporting period:

744 2,

Currenily cuthorized power level (MWt): 2511 Max. Depend capacity (MWe-Net)- 769% Design electrical rating ( HWe-rle t ). 789 3,

Power level to which restricted (if any)(MWe-Net): NA 4

Reccons for restriction (if any):

This Month Yr.to Date Cunulative S.

Number of hours reactor was critical 744,0 3719,8 G3625.8 6.

Reactor reserve shutdown hours 0,0 0,0 2985,8 7.

Hours generator on line 744.0 3647.9 85697.1 8.

Unit reserve shutdown hours.

0.0 01 702.9 9.

Gross thernal energy generated (MWH) 1796251 0445303 179964370

10. Gross electrical energy generated (MWH) 591690 2743479 57396090

11. Net electrical energy generated (MWH) 557159 2622199 53940184

12. Reactor service factor 100,0 63.8 76,6

13. Reactor availability factor 100.0 63.8 79,1

14. Unit service factor 100.0 62.6 74.0

15. Unit availability factor 100.0 62.6 74,6

16. Unit capacity factor (Using MDC) 97,4 50.5 60.6-

17. Unit capacity factor (Using Des.MWe) 94.9 57,0 59,1

18. Unit forced outage rate 0,0 5,0 8,3

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

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

___f_A

• The MDC my be leur then 769 MWe during periods of high entient terparature die to 'he ther. mal perfstecnce of the sorcy canal.

MCFFICIAL CCFfMf WM2ERS ARE USED IN THIS REPCkl L

APPENDIX B AVERAGE DAILY UNIT POWER LEVEL

~

DOCKET NO.

50-254 UNIT ONE j

DATEAUGUST 4~1985 COMPLETED BYCAROL L.

KRONICH-

[

i l

TELEPHONE 309/654-2241X193 i

MONTH-

'Aunust 1985 i-DAY. AVERAGE DAILY POWER LEVEL; DAY AVERAGE DAILY POWER LEVEL.

-(MWe-Net)

-(MWe-Net) 4 1.

791.5 17.

762.0 2.

763.9 18, 764.4

]

3.

760'.4 19.

i-738.0 4.-

713.1-20, 730.8

! ~

5, 740.4 21.

742.6 i

_6.

754.8 22. _ _

749.8 d

7.

803.2 23.

728.7' li-8.

758.0

124, 660.7

^

9.

688.7 25, 747.8

.10, 757.3 26.

760.9 ii.

770.1 27.

781.6 12.

797.1 28, 784.3 l

13.

773.5 29.

786.5 14, 729.1

.3 0.

749,4 15.

671.2

31..

750.0 i!-

16.

739.7 INSTRUCTIONS On this form > list the everage dcily vnit Dawer level in PWe-Net for ec:h d1y in the reperting Ponth.Compett te the etarest whole ee:twatt.

These figures will be used to plat c graph for ecch reparting nonth. Note that when scrimum dependable cepccits is osed for the cet electritc1 reting of the init there ray be occasions w'en the coily everage power level erceeds the 168% line (or the restricted power level line),.In such cases,the everage daily unit pner sitput sheet sheald be I

(citnoted ts ei;1cil the c;0crent cnon217 i

1 l

I I

r APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.

50-265 UNIT TWO DATEAUGUST 4 1985 COMPLETED BYCAROL L.

KRONICH TELEPHONE 309/654-2241X193 MONTH' Auq1st 1985 1

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

(Mue-Net) 1.

774.5 17, 757.9 2.

756.8 18, 760.4 3.

719.4 19.

764.0 4,

737.9 20.

773,7 5,

758.2 21, 774.1 6.

751.1 22, 752.6 7.

790.3 23.

734,7 8.

755.9 24.

745.2 i

9.

781.1 25.

656.7 10, 771.3 26.

728.5 ii.

765.8 27, 749.1 l

12, 792.4 28.

675.7 13, 765.5 29, 600.5 14, 763.2 30.

747.8 15, 731.9 31.

747.4 16, 744.1 INSTRUCTIONS On this forn, list the average daily snit power level in MWe-Net for each day in the reporting panth.Corpste to the i

nesrest whole regawatt.

These figures will be used to plat a graph for each reperting nonth. Note that when na:Inan dependable ccpacity is esed for the net elettrical rating of the snit there not be occasions when the daily average power level exceeds the 1991 line (or the restricted power level line),In sich cases,the average daily snit power setpst sheet shecid be j

footnoted to explain the cpparent animaly l

a

M M

M FRI M

M M

5M M

M M

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

050-254 August 1982 UNIT NAME Quad-Cities Unit 1 COMPLETED BY C. Kronich DATE September 10, 1985 REPORT MONTil AUGUST 1985 TELEPil0NE 309-654-2241 H

N w"

5 E$

g@w Aw Q

M LICENSEE O

m EVENT o"

DURATION g

g NO.

DATE (IlOURS) o REPORT NO.

CORRECTIVE ACTIONS / COMMENTS o

85-41 850804 S

0.0 B

5 HA TURBIN Reduced load to 700 MWe for weekly Turbine surveillances 85-42 850805 S

0.0 H

5 ZZ ZZZZZZ Reduced load to 650 MWo per Load Dispatcher 85-43 850809 S

0.0 H

5 RC CONROD Reduced load to 600 MWe for a rod pattern adj ustment 85-44 850814 S

0.0 H

5 ZZ ZZZZZZ Reduced load to 600 MWe per Load Dispatcher 85-45 850815 S

0.0 H

5 ZZ ZZZZZZ Reduced load to 600 MWe per Load Dispatcher 85-46 850815 S

0.0 H

5 RC CONROD Reduced load to 650 MWe for a rod pattern adjustment 85-47 850824 S

0.0 H

5 RC CONROD Reduced load to 600 MWe for a rod pattern adjustment 85-48 850830 S

0.0 H

5 HC HTEXCH Reduced load to 525 MWe due to loss of condenser vacuum APPROVED AUG 1 G 1982 (final) y c. o 3 g

M M

M P"JE M

M M

M M

MiM M

M p!Pg M

M 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 2 COMPLETED BY C. Kronich DATE September 10, 1985 REPORT MONTil AUGUST 1985 TELEPIIONE 309-654-2241 g

N R$

y$

=

m

=

h"x o

M LICENSEE us o go o

g DURATION d

EVENT o

w NO.

DATE (1100RS)

REPORT NO.

CORRECTIVE ACTIONS / COMMENTS ca 85-33 850803 S

0.0 B

5 HA TURBIN Reduced load to 700 MWe for weekly Turbine surveillances 85-34 850803 S

0.0 H

5 ZZ ZZZZZZ Reduced load to minimum per Load Dispatcher 85-35 850807 S

0.0 H

5 ZZ ZZZZZZ Reduced load to 700 MWe per Load Dispatcher 85-36 850825 S

0.0 B

5 HA TURBlN Reduced load to 700 MWe for weekly Turbine surveillances 85-37 850825 S

0.0 H

5 HG DEMINX Reduced load to 600 MWe for Condensate Demineralizer change-over 85-38 850828 S

0.0 H

5 HH PUMPXX Reduced load to minimum speed for Condensate pump change-over APPROVED AUG 1 G 1982 (final) y G.O d H

M M

M M

M M

M M

M M

M M

M M

ID/SA APPENDIX D QTP 300-S13 UNIT SHUTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO.

050-254 August 1982 UNIT NAME Quad-Cities Unit 1 COMPLETED BY C. Kronich MAY 1985 DATE September 9, 1985 REPORT MONTil TELEP110NE 309-654-2241 g

N w"

5 gm Ww Q

LICENSEE m@

w DURATION M

EVENT o"

u NO.

DATE (i!OURS)

REPORT NO.

CORRECTIVE ACTIONS / COMMENTS 85-27 850505 S

0.0 B*

5 HA TURBIN Reduced load to 700 MWe for weekly Turbine tests

• Item Cc rrected 1

APPROVED AUG 101982

- (final) ygg3g

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

050-254 August 1982 UNIT NAME Quad-Cities Unit 1 CORRECTED COPY COMPLETED BY C. Kronich DATE September 9, 1985 REPORT MONTil JULY 1985 TELEPil0NE 309-654-2241 5

e

~

Q 20 m

m

=

$x 0

0 N$

o$

M LICFASEE mo ga go g

DURATION M

EVENT o

m u

NO.

DATE (IIOURS)

REPJRT NO.

CORRECTIVE ACTIONS / COMMENTS o

85-34 850706 S

0.0 B*

5 HA TURBIN Reduced load to 700 MWe for weekly Turbine tests 85-42 850728 S

0.0 B*

5 HA TURBIN Reduced load to 700 MWe for weekly Turbine tests

• Item corrected APPROVED AUG 101982 a' (final) y g (j 3 g

ID/SA APPENDIX D QTP 300-S13 UNIT SIIUTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO.

050-265 AuRust 1982 ORREE COM UNIT NAME Quad-Cities Unit 2 COMPLETED BY C. Kronich DATE September 9, 1985 REPORT HONTil JULY 1985 TELEPil0NE 309-654-2241 H

N p

eb

=

m z

8 8

WW sa g"x M

LICENSEE mo g

ga o

<c DURATION EVENT o"

w NO.

DATE (IlOURS)

REPORT NO.

CORRECTIVE ACTIONS / COMMENTS ca 85-27 850707 5

0.0 B*

5 HA TURBIN Reduced load to 700 MWe for weekly Turbine tests 85-31 850720 S

0.0 B*

5 HA TURBIN Reduced load to 600 MWe for Turbine surveillances, and remained at 600 MWe for main transformer problems and tests 85-32 850727 S

0.0 B*

5 HA TURBIN Reduced load to 700 MWe for weekly Turbine tests APPROVED AUG 1 G 1982

.' (final) y.co3g

+.

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 There were no Main Steam Relief Valve Operations for the reporting period.

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.

i I

i 4

1 i

I n

,.,--e e

-,-- ~<_,..,

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.

QTP 300-S32 Rsvision 1 a

I QUAD-CITIES REFUELING March 1978 INFORMAT10N-REQUEST ~

1.

Unit:

Q1 Reload:

7 Cycle:

8 2.

Scheduled date for next refueling shutdown:

1-2-86 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:

NOT AS YET DETERMINED.

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

.L Information:

DECCiBER 19, 1985; IF LICENSING ACTION REQUIRED.

l 6.

Important licensing 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:

7 3

NONE PLANNED AT PRESENT TIME.

j-t.

v-t' 7

The number of fuel assemblies.

a.

Number of assemblies in core:

724 t.

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:

0 9

The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity: 2003 4PPROVED APR 2 01978 Q. C. O. S. R.

.___m_-_--

a 1

QTP 300-S32 Ravision 1 i

QUAD-CITIES REFUELING March 1978

--s INFORMATION REQUEST s,,

l.

Unit:

Q2 Reload:

7 Cycle:

8 2.

Scheduled date for next refueling shutdown:

10-6-86 3

Scheduled date for restart following refueling:

12-22-86 4.

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

Yes. A routine MAPLHGR amendment has been approved. as a preparatory change to allow a 10 CFR 50.59 review.

5.

Scheduled 'date(s) for submitting proposed IIcensing action and supporting Informa tion:

Not Applicable.

)

6.

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

' different fuel design or supplier, unreviewed design or performance analysis methods, significant changes in fuel ~ design, r.t: operating procedures:

)

b None planned at present time.

F'

).

.l 3.

1 i

7 The number of fuel assemblies.

a.

Number of assemblies in core:

724 L.

b.

Number of assemblies in spent fuel pool:

176 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 spent fuel pool assuming the present Ilcensed capacity: 2003

(

APPROVED APR 2.01978 Q.C.O.S.R.

,e p

o.

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 ATHS Anticipated Transient Without Scram BWR Boiling 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 Precondition 1ng Interim Operating Management Recommendations RBCCW 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 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 Build:ng Closed Cooling Water System TIP Traversing Incore Probe TSC Technical Support Center

Commonwealth Edison Quad Cities Nuclear Power Station 22710 206 Avenue North Cordova,lilinois 61242 Telephone 309/654-2241 TKT-85-46 September 3, 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 August 1985.

Respectfully, COMMONWEALTH EDISON COMPANY QUAD-CITIES NUCLEAR POWER STATION T. K. Tamlyn l

i Services Superintendent l

bb Enclosure l

f6%Y

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