Text

Monthly Operating Repts for Apr 1986
	ML20205P674
Person / Time
Site:	Quad Cities
Issue date:	04/30/1986
From:	Kronich C, Robey R; COMMONWEALTH EDISON CO.
To:	; NRC OFFICE OF ADMINISTRATION (ADM), NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
References
	RAR-86-09, RAR-86-9, NUDOCS 8605210517
	Download: ML20205P674 (26)
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QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT 4

APRIL 1986 COMMONWEALTH EDISON COMPANY AND l

IONA-ILLINOIS GAS & ELECTRIC COMPANY NRC DOCKET NOS. 50-254 AND 50-265 LICENSE NOS. DPR-29 AND DPR-30 l

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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, Experiments, and Safety Related Maintenance 4

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 t

V.

Data Tabulations A.

Operating Data Report i

B.

Average Daily Unit Power Level C.

Unit Shutdowns and Power Reductions VI.

Unique Reporting Requirements 2

A.

Main Steam Relief Valve Operations B.

Control Rod Drive Scram Timing Data VII.

Refueling Information VIII.

Glossary i

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INTRODUCTION 4

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Quad-Cities Nuclear Power Station is composed of two Bolling Hater i

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 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 initial Reactor criticalities for Units One and Two, respectively were October l

18, 1971, and April 26, 1972. Commercial generation of power began on February 18, 1973 for Unit One and March 10, 1973 for Uni t Two.

This report was compiled by Becky Brown and Carol Kronich,. telephone i

number 309-654-2241, extensions 2240 and 2157.

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II.

SUMMARY

OF OPERATING EXPERIENCE A.

Unit One April 1-10 Unit One began the month of April shutdown for the end of Cycle Eight Refueling and Maintenance Outage. On April 4, at 0800 hours0.00926 days 0.222 hours 0.00132 weeks 3.044e-4 months , Reactor startup commenced. At 1013 hours0.0117 days 0.281 hours 0.00167 weeks 3.854465e-4 months the Reactor became critical. The startup was normal until April 5, at 0836 hours0.00968 days 0.232 hours 0.00138 weeks 3.18098e-4 months , when the Reactor scrammed on low Reactor water level due to a minimum flow control valve failure. At 1055 hours0.0122 days 0.293 hours 0.00174 weeks 4.014275e-4 months startup of the unit commenced. At 1254 hours0.0145 days 0.348 hours 0.00207 weeks 4.77147e-4 months the Reactor went critical. The Generator was synchronized and the unit was placed on-line on April 6, at 0248 hours0.00287 days 0.0689 hours 4.100529e-4 weeks 9.4364e-5 months . Load was increased to 200 MWe and held steady for hot scram timing. At 2130 hours0.0247 days 0.592 hours 0.00352 weeks 8.10465e-4 months the Turbine was tripped for a scheduled Turbine Overspeed Test. The unit returned on-line at 2206 hours0.0255 days 0.613 hours 0.00365 weeks 8.39383e-4 months .

The unit began an increase to 400 MWe on April 6, at 0830 hours0.00961 days 0.231 hours 0.00137 weeks 3.15815e-4 months . At 0910 hours0.0105 days 0.253 hours 0.0015 weeks 3.46255e-4 months load was held at 250 MWe for a Drywell entry to inspect the IRM's.

At 1045 hours0.0121 days 0.29 hours 0.00173 weeks 3.976225e-4 months load was dropped to 175 MWe for the actual Drywell I

entry. At 1500 hours0.0174 days 0.417 hours 0.00248 weeks 5.7075e-4 months a normal increase to full power began.

Full l

power was reached at approximately 0900 hours0.0104 days 0.25 hours 0.00149 weeks 3.4245e-4 months on April 10.

l April 11-30 Load was held at full power until April 13, at 0110 hours0.00127 days 0.0306 hours 1.818783e-4 weeks 4.1855e-5 months , when load was dropped to 700 MWe for MSIV surveillances. At 0330 hours0.00382 days 0.0917 hours 5.456349e-4 weeks 1.25565e-4 months load began a normal increase to full power. Load remained at full power until April 15, at 2145 hours0.0248 days 0.596 hours 0.00355 weeks 8.161725e-4 months , when load began a drop to 600 MWe for Gland Seal Exhauster System repairs. Load began an increase to full power on April 17, at 0445 hours0.00515 days 0.124 hours 7.357804e-4 weeks 1.693225e-4 months .

Full load was reached at 0235 hours0.00272 days 0.0653 hours 3.885582e-4 weeks 8.94175e-5 months on April 18.

Load was held at full power until April 20, at 0220 hours0.00255 days 0.0611 hours 3.637566e-4 weeks 8.371e-5 months , when the Load Dispatcher requested that the unit be brought down to 670 MWe, At 0810 hours0.00938 days 0.225 hours 0.00134 weeks 3.08205e-4 months the unit began an increase to 800 MWe, Eight hundred MWe was reached at 1700 hours0.0197 days 0.472 hours 0.00281 weeks 6.4685e-4 months and the unit was then placed on Economic Generation Control (EGC).

On April 21, at 0845 houis, the unit was taken off of EGC and load was increased to full power. At 1815 hours0.021 days 0.504 hours 0.003 weeks 6.906075e-4 months the unit returned to EGC operation.

ECC operation was tripped on April 22, at 0905 hours0.0105 days 0.251 hours 0.0015 weeks 3.443525e-4 months .

Load was then increased to full power. At 2235 hours0.0259 days 0.621 hours 0.0037 weeks 8.504175e-4 months the unit was i

returned to ECC operation. EGC operation continued until April 25, at I.

1305 hours0.0151 days 0.363 hours 0.00216 weeks 4.965525e-4 months . Load was held at approximately 800 MWe until 2200 hours0.0255 days 0.611 hours 0.00364 weeks 8.371e-4 months when the unit was returned to EGC operation. On April 27, at 0008 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , the unit was taken off of EGC for surveillances, and returned at 0050 hours5.787037e-4 days 0.0139 hours 8.267196e-5 weeks 1.9025e-5 months . At 0545 hours0.00631 days 0.151 hours 9.011243e-4 weeks 2.073725e-4 months the unit was taken off of ECC and load was dropped to 650 MWe at the request of the Load Dispatcher. At 0925 hours0.0107 days 0.257 hours 0.00153 weeks 3.519625e-4 months load began an increase to 750 MWe.

The unit returned to EGC operation at 1538 hours0.0178 days 0.427 hours 0.00254 weeks 5.85209e-4 months .

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II.

SUMMARY

OF OPERATING EXPERIENCE (cont.)

April 11-30 (cont.)

On April 28, at 0900 hours0.0104 days 0.25 hours 0.00149 weeks 3.4245e-4 months , the unit was taken off of EGC and load was increased to full power. Load was held steady until April 30, at 2356 hours0.0273 days 0.654 hours 0.0039 weeks 8.96458e-4 months , when a load drop test commenced. The load test continued through the end of April.

B.

Unit Two April 1-13 Unit Two began the month of April holding load at full power. On April 2, at 1345 hours0.0156 days 0.374 hours 0.00222 weeks 5.117725e-4 months , the unit was placed on EGC operation.

On April 3, at 0200 hours0.00231 days 0.0556 hours 3.306878e-4 weeks 7.61e-5 months , the unit was taken off of EGC, and load was dropped to 600 MWe to perform maintenance on the 2D3 heater. At 1000 hours0.0116 days 0.278 hours 0.00165 weeks 3.805e-4 months load began an increase to 750 MWe.

Load was held at 750 MWe for further heater problems, and at 1730 hours0.02 days 0.481 hours 0.00286 weeks 6.58265e-4 months increased to 800 MWe.

The unit was placed on EGC at 0945 hours0.0109 days 0.263 hours 0.00156 weeks 3.595725e-4 months on April 4.

EGC was tripped on April 5, at 0347 hours0.00402 days 0.0964 hours 5.737434e-4 weeks 1.320335e-4 months , for a surveillance. The unit returned to EGC operation at 0410 hours0.00475 days 0.114 hours 6.779101e-4 weeks 1.56005e-4 months . At 1655 hours0.0192 days 0.46 hours 0.00274 weeks 6.297275e-4 months EGC was tripped and the unit was held at 800 MWe until 1759 hours0.0204 days 0.489 hours 0.00291 weeks 6.692995e-4 months when the unit was returned to EGC operation.

EGC was tripped at 2330 hours0.027 days 0.647 hours 0.00385 weeks 8.86565e-4 months to perform a surveillance, and operation was resumed on April 6, at 0410 hours0.00475 days 0.114 hours 6.779101e-4 weeks 1.56005e-4 months .

On April 7, at 0218 hours0.00252 days 0.0606 hours 3.604497e-4 weeks 8.2949e-5 months , the unit was taken off of EGC to perform MSlV surveillances. At 0255 hours0.00295 days 0.0708 hours 4.21627e-4 weeks 9.70275e-5 months EGC operation resumed. At 0416 hours0.00481 days 0.116 hours 6.878307e-4 weeks 1.58288e-4 months the N

unit was taken off of EGC, and load was increased to 800 MWe, The unit returned to EGC operation at 1445 hours0.0167 days 0.401 hours 0.00239 weeks 5.498225e-4 months . At 1523 hours0.0176 days 0.423 hours 0.00252 weeks 5.795015e-4 months the unit was taken off of EGC and load was held at 800 MWe.

On April 8, at 0130 hours0.0015 days 0.0361 hours 2.149471e-4 weeks 4.9465e-5 months , load began a drop to 600 MWe to work on 'A' Moisture Separator Drain Tank 2D3 heater. Load was decreased to 450 MWe at 0320 hours0.0037 days 0.0889 hours 5.291005e-4 weeks 1.2176e-4 months , per the Load Dispatcher. At 0635 hours0.00735 days 0.176 hours 0.00105 weeks 2.416175e-4 months load was returned to 600 MWe.

At 1000 hours0.0116 days 0.278 hours 0.00165 weeks 3.805e-4 months load began an increase to 775 MWe, The unit was placed on ECC at 1225 hours0.0142 days 0.34 hours 0.00203 weeks 4.661125e-4 months . At 1448 hours0.0168 days 0.402 hours 0.00239 weeks 5.50964e-4 months the unit was taken off of EGC and load was increased to full power.

On April 9, at 0135 hours0.00156 days 0.0375 hours 2.232143e-4 weeks 5.13675e-5 months , load was dropped to 795 MWe as per the Load Dispatcher. Load was increased to full power at 1800 hours0.0208 days 0.5 hours 0.00298 weeks 6.849e-4 months . The unit was placed on EGC at 0950 hours0.011 days 0.264 hours 0.00157 weeks 3.61475e-4 months on April 10.

On April 12, at 0150 hours0.00174 days 0.0417 hours 2.480159e-4 weeks 5.7075e-5 months , the unit was taken off of EGC for surveillances.

EGC operation was returned at 0308 hours0.00356 days 0.0856 hours 5.092593e-4 weeks 1.17194e-4 months .

On April 13, at 1630 hours0.0189 days 0.453 hours 0.0027 weeks 6.20215e-4 months , the unit was taken off of EGC and load was increased to full power.

II.

SUMMARY

OF OPERATING EXPERIENCE (cont.)

April 14-30 Full load was held until April 16, at 1745 hours0.0202 days 0.485 hours 0.00289 weeks 6.639725e-4 months , when the unit was placed in EGC operation. The unit was taken off of ECC operation at 0025 hours2.893519e-4 days 0.00694 hours 4.133598e-5 weeks 9.5125e-6 months on April 18.

Load was then dropped to 400 MWe for control L

rod scram timing. At 1815 hours0.021 days 0.504 hours 0.003 weeks 6.906075e-4 months load began an increase to 750 MWe.

i AT 2330 hours0.027 days 0.647 hours 0.00385 weeks 8.86565e-4 months load was dropped to 700 MWe to perform Turbine surveillances.

On April 19, at 0220 hours0.00255 days 0.0611 hours 3.637566e-4 weeks 8.371e-5 months , load was increased and the unit was placed on ECC at 1300 hours0.015 days 0.361 hours 0.00215 weeks 4.9465e-4 months . The unit was taken off of ECC at 1357 hours0.0157 days 0.377 hours 0.00224 weeks 5.163385e-4 months on April 21.

Load was then increased to full power. The unit returned to EGC operation at 1755 hours0.0203 days 0.488 hours 0.0029 weeks 6.677775e-4 months .

On April 22, at 0905 hours0.0105 days 0.251 hours 0.0015 weeks 3.443525e-4 months , the unit was taken off of EGC and load was increased to full power. The unit returned to EGC operation at 2207 hours0.0255 days 0.613 hours 0.00365 weeks 8.397635e-4 months . The unit was taken off of ECC operation at 0430 hours0.00498 days 0.119 hours 7.109788e-4 weeks 1.63615e-4 months , on April 23.

AT 2355 hours0.0273 days 0.654 hours 0.00389 weeks 8.960775e-4 months the unit was returned to EGC operation.

C On April 24, at 0910 hours0.0105 days 0.253 hours 0.0015 weeks 3.46255e-4 months , the unit was taken off of EGC to changeover Condensate Pumps. The unit was returned to EGC operation at 0950 hours0.011 days 0.264 hours 0.00157 weeks 3.61475e-4 months .

On April 25, at 1310 hours0.0152 days 0.364 hours 0.00217 weeks 4.98455e-4 months , the unit was taken off of EGC, and load was increased to full power. AT 2210 hours0.0256 days 0.614 hours 0.00365 weeks 8.40905e-4 months the unit returned to EGC operation. EGC operation was tripped at 0045 hours5.208333e-4 days 0.0125 hours 7.440476e-5 weeks 1.71225e-5 months on April 26 to perform surveillances. At 0233 hours0.0027 days 0.0647 hours 3.852513e-4 weeks 8.86565e-5 months the unit was returned to EGC operation. EGC operation was tripped on April 27, at 0130 hours0.0015 days 0.0361 hours 2.149471e-4 weeks 4.9465e-5 months .

Load was dropped to 600 MWe as per the Load Dispatcher. At 0930 hours0.0108 days 0.258 hours 0.00154 weeks 3.53865e-4 months load began an increase to 725 MWe and the unit was placed on EGC at 1140 hours0.0132 days 0.317 hours 0.00188 weeks 4.3377e-4 months .

The unit remained on EGC until April 30, at 1508 hours0.0175 days 0.419 hours 0.00249 weeks 5.73794e-4 months , when load was increased to full power. The unit remained at full power for the remainder of the month of April.

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-III; PLANTORPROCEDURECHANGESI. TESTS, EXPERIMENTS,ANDSAFETY-RELATED MAINTENANCE J-4 A.

Amendme'nts to Facility Licena[e'or' Technical Specifications 1

1 ThSre were no Amendments to the Facility. License or Technical Specifications for the reporting period.

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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 to tests or experiments requirisig N.RC approval for the reporting period.

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D.

Corrective Maintenance of SaIkty Related Equipment' The foll'owing rdpresents a tabular summary of the major

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safety related.naintenance' performed on Units.1 and 2 during the reporting period. This summary includes the following: Work Kequest Nur.hers, Licensee Event. Report Numbers, Componentk, Cause of Malfunctions, Results and j

Effects on Safe Operation,'and Action Taken to Prevent Repetition.

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UNIT 1

MAINTENANCE

SUMMARY

CAUSE RESULTS & EFFECTS W.R.

LER OF ON ACTION TAKEN TO NulEER NUMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION Q48234 86-01 A0 1-1601-23 Valve disc was Failed Local Leak Rate Valve disc was adjusted Drywell Vent not sealing Test.

and tested satisfactorily.

Valve properly.

Q48509 86-01 A0 1-8801D Packing nut was Failed Local Leak Rate The packing nut was Oxygen out of adjust-Test.

adjusted and valve leak Analyzer ment. Possibly tested satisfactorily.

Valve allowed packing to leak around valve stem.

Q48558 36-01 A0 1-2001-4 Corrosion from Failed Local Leak Rate The valve disc was lapped Drywell Floor water in the Test.

(machined) to ensure a Drain Sump line affected smooth sealing surface.

Isolation the sealing Valve surface of the valve disc.

Q48744 1/2-6601 A bearing failure While testing, the 1/2 The complete turbocharger Diesel caused the turbo-Diesel Generator was replaced like-for-like.

Generator charger fan to suddenly dropped load Turbocharger vibrate against and tripped. The other the turbocharger Diesels were available, housing. This as were all safety systems, contact caused the fan blades to chip away, and the chips caused damage to several internal gears. Without the turbocharger fan operating, the Diesel lost power.

0027H/00612

UNIT 1

MAINTENANCE

SUMMARY

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CAUSE RESULTS & EFFECTS W.R.

LER OF ON ACTION TAK5N TO NUhEER NUMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION Q46708 1-1402-25B Core While attempting to The valve did not open, The thermal overloads Spray Discharge open the valve, the so the 'B' loop Core were reset, and the valve Valve breaker thermal Spray was inoperable, opened. Testing revealed overloads tripped All other safety no problems with the and'the valve did systems were available.

valve or the breaker over-net ^open.

loads.

Q47896 1-2599-23A ACAD Valve internals While testing, the The valve as disassembled, Check Valve were dirty. Valve valve would not open.

cleaned, and reassembled.

could not operate flowever, it failed in it then operated and was properly.

the closed, safety tested satisfactorily.

position.

Q48040 86-01 A0 1-8801D Valve stem packing Failed Local Leak Rate Repacked valve with new Oxygen Analyzer had lost its Test.

packing. Failed second Valve sealing property.

test. See Work Request Q48509.

Q49090 Relay 1-590-No apparent cause While testing the All characteristics of 102G for the relay MS1V's the relay was the relay were checked.

" chattering" energized. It immediately The control spring (continually started chattering. The adjusting screw, which was opening and relay's supply fuse was within limits, was closing) could pulled and the test adjusted to stop the be found.

stopped. The other 102E chattering.

relay channel was functioning, i

l 0027H/0061Z

UNIT 2

MAINTENANCE

SUMMARY

CAUSE RESULTS & EFFECTS W.R.

LER OF ON ACTION TAKEN TO NUREER NllMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION Q41926 85-06 2-1601-23 Dry-The valve's Failed Local Leak Rate Valve was replaced and well Exhaust seating surfaces Test.

tested successfully.

Butterfly were worn from Valve use, time, heat, etc.

Q48140 2-733 #4 The valve in-The valve took longer to The valve internals were TIP Valve ternals had close than allowed, cleaned. The TIP Drive corroded due to System now uses nitrogen moisture in the instead of air. Nitrogen air system which is moisture-free.

supplies the TIP Drive Purge System.

Q48176 2-733 #2 The valve in-The valve would not close The valve was replaced.

TIP Valve ternals had and after being cleaned, it The TIP Drive Purge corroded due to still took longer than System now uses moisture-moisture in the allowed to close.

free nitrogen.

air system which supplies the TIP Drive Purge System.

Q49108 86-06 2-1743

'A' The tripping set-The Radiation Monitor The tripping setpoint of Fuel Pool point had drifted tripped at a lower level.

the Radiation Monitor Radiation to a lower setting. This started the Standby was reset at the correct Monitor Gas Treatment System and

limit, isolated the Reactor Building Ventilation as designed.

0027H/0061Z --

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LICENSEE EVENT REPORTS 1

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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 6.6.8.2. of the Technical Specifications.

UNIT ONE Licensee Event Report Numbers Date Title of Occurrence 86-21 4-5-86 Reactor Scram - Low Flow Feedwater Regulator Valve Leakage UNIT TWO j

Licensee Event Report Numbers Date Title of Occurrence 86-05 4-4-86 Standby Gas Treatment J

Auto initiation From i

Hot Trash on Refuel Floor i

86-06 4-14-86 2A Fuel Pool Monitor Spikes High 86-07 4-9-86 Failure of 2B Core i

Spray Room Cooler i

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V.

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

A.

Operating Data Report 8.

Average Daily Unit Power Level C.

Unit Shutdowns and Power Reductions

l OPERATING DATA REPORT DOCKET NO.

50-254 UNIT ONE DATEMAY 5 1986 i

COMPLETED BYCAROL L KRONICH TELEPHONE (309) 654-2241 OPERATING STATUS 0000 040186 1.

Reporting peri ~d:2400 043086 Gross hours in reporting period:

719 o

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 632.5 752,5 97413,9 6.

Reactor reserve shutdown hours 0,0 0.0 3421,9 7.

Hours generator on line 595.6 715,6 93995.1 8.

Unit reserve shutdown hours, 0,0 0.0 909.2 9.

Gross thernal energy generated (MWH) 1340571 1581056 196546213

10. Gross electrical energy generated (MWH) 433782 514404 63633775

11. Net electrical energy generated (MWH) 412407 481632 59508165

12. Reactor service factor 88,0 26,1 79,5

13. Reactor ovallobility factor 88,0 26,1 82.3 14, Unit service factor 82.8 24,9 76,7

15. Unit availability factor 82.8 24,9 77,5 16, Unit capucity factor (Using MDC) 74.6 21,0 63.2

17. Unit capacity factor (Using Des.MWe) 72.7 21.2 61,6 18, Unit forced outage rote

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.6 5,9 19, Shutdowns scheduled over next 6 nonths (Type,Date,and Duration of each):

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20. If shutdown at end of report period, estimated date of startup NA SUN 0FFICIAL COMPANY NUMBERS ARE USED IN THIS REPORT

OPERATING DATA REPORT DOCKET NO.

50-265 UNIT TWO DATEMAY 5 1986 COMPLETED BYCAROL L KRONICH TELEPHONE (309) 654-2241 OPERATING STATUS l

0000 040186 1.

Reporting period:2400 043086 Gross hours in reporting period:

719 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.

Nunber of hours reactor was critical 719.0 2653.3 93921.0 6.

Reactor reserve shutdown hours 0.0 0.0 2985.0 7.

Hours generator on line 719,0 2628.0 90925.6 8.

Unit reserve shutdown hours.

0.0 0.0 702.9 9.

Gross thernal energy generated (MWH) 1685009 6227135 192336158 10, Gross electrical energy generated (MWH) 551703 2_049172

.61465954

11. Net electrical energy generated (MWH) 531072 1961945 57E'362 0 4

12. Reactor service factor 100.0 92.2 77.3

13. Reactor availability factor 100.0 92.2 79.7

14. Unit service factor 100.0 91.3 74.8

15. Unit availability factor 100.0 91.3 75.4

16. Unit capacity factor (Using MDC) 96.1 88.6 61.9

17. Unit capacity factor (Using Des.MWe) 93.6 86.4 60.3

18. Unit forced outnge rate 0.0 10 0.0

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

20. If shu tdown at end of report period,estinated date of startup NA

VNOFFICIAL COMPANY MJMBERS ARE USED IN THIS REPORT

APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.

50-254 UNIT ONE DATEMAY 5 1986 COMPLETED BYCAROL L KRONICH TELEPHONE (309) 654-2241 MONTH Apr11 1986 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)

(MWe-Net) 1.

-5.4 17, 721.5 2.

-5.1 10, 785.7 3.

-3.5 19.

754.5 4.

-8.0 20.

754.6 5.

-11.1 21, 771.4 6.

112.2 22, 775.6 7.

244.1 23.

730.0 8.

471.3 24.

754.4 9.

683.2 25, 753.5 10.

780.1 26, 757.4

11..

778.6 27.

690.9 12, 774.5 20, 760.4 13, 755.0 29.

709.0 14.

794.0 30.

783.0

15. _.,

700,6 16, 591.1 INSTRUCTIONS On this fern, list the overage daily snit power level in Ne-Net for each day in the reporting nonth Compete to the nearest whole negovatt.

These figures will be ssed to plot a graph for each reporting nonth. Note that wh n noxinen dependable capacitt is 9

used for the net electrical rottng of the unit there nay be occasions when the datly overage power level exceeds the 1HIline (or the restricted power level line),.In such cases,the everage daily snit power setpot sheet should be festnoted to explain the apparent onencly

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. APPENDIX B-

. AVERAGE DAILY. UNIT POWER' LEVEL.

DOCKET NO.-

50-265 UNIT TWO DATEMAY 5'i986 COMPLETED BYCAROL L KRONICH i

TELEPHONE (309) 654-2241 l

i-MONTH Apr11 1986 DAY AVERAGE DAILY POWER LEVEL DAY AVERACE DAILY POWER LEVEL (MWe-Net)

(MWe-Net) 1.

790.4 17.

722.1 l

2.

776.5 18, 478.3 j

3.

658.8 19, 736.2 f

4, 742.5 20.

736.2 S.

740.0 21.

'7 5 7, 4 -

6, 739.7 22, 766.8-i 7.

764.8 23.

742.9 8.

689.8 24, 734.0 9.

763.1 25, 751.3-I 10, 760.2 26, 745.2 i

11.

721.7 27.

652.7 I

12.

721.2 28.

725,4 13, 740.7 29.

735.3 1

14, 795.5 30, 759.5

t 15, 790.4 i

16, 702.7 i

INSTRUCTIONS j

- On this forn, list the overage daily snit power level in MWe-Net for each day in the reporting unth.Coopete to the neaeest whole nesowatt.

These figeres utfl be osed to plot a graph for each reperting unth. Note that when natium dependable capacite is used for the net electrical rating of the snit,In sich cases,the overage daily snit power estpet sheet shoeld be.t 1985 line (or the restricted power level line).

-footnoted to explain the apparent anemly

- ~

M M

P""'T P""1 M

M M

M P""I M

f 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 May 8, 1986 REPORT MONTil APRIL 1986 TELEPIIONE 309-654-2241 H

N w"

5 EE gw

$w o

Q d

LICENSEE m@

EVENT o"

H DURATION d

g Si g w

NO.

DATE (IIOURS)

"o REPORT NO.

CORRECTIVE ACTIONS / COMMENTS o

86-3 860404 F

22.8 A

3 86-21 CH VALVEX Reactor scram during startup on low Reactor water level due to minimum flow control valve failure 86-4 860406 S

0.0 B

5 HA ZZZZZZ Load dropped for Turbine Overspeed Test 86-5 860407 F

0.0 A

5 RA INSTRU Reduced load to 170 MWe for IRM inspection 86-6 860413 S

0.0 B

5 CD VALVEX Reduced load to 700 MWe for MSIV testing 86-7 860415 F

0.0 B

5 HD XXXXXX Reduced load to 600 MWe for Gland Seal Exhauster System repairs 86-8 860420 S

0.0 H

5 ZZ ZZZZZZ Reduced load to 670 MWe per Load Dispatcher 86-9 860427 S

0.0 H

5 ZZ ZZZZZZ Reduced load to 650 MWe per Load Dispatcher l

APPROVED AUG 1 G 1982

' (final) y G. O d H

m M

M M

M ID/5A APPENDIX D QTP 300-S13 UNIT SIIUTDOWNS AND POWER REDUCTIONS Revision 6

~

DOCKET NO.

050-265 August 1982 UNIT NAME Quad-Cities Unit 2 COMPLETED BY C. Kronich DATE May 8, 1986 REPORT MONTil APRIL 1986 TELEPil0NE 309-654-2241 5

g

~

m" 5

gw@

dw LICENSEE Q

O{d m

DURATION M

E EVENT o"

w u

NO.

DATE (IlOURS)

REPORT No.

CORRECTIVE ACTIONS / COMMENTS o

86-10 860403 S

0.0 B

5 CH HTEXCH Reduced load to 600 MWe for MSIV surveillance and out of service work on 2D3 heater 86-11 860408 S

0.0 B

5 CH HTEXCH Reduced load to work on

'A' Moisture Separator Drain Tank to 2D3 heater 86-12 860418 S

0.0 B

5 RC CONROD Reduced load to 400 MWe for required scram timing 86-13 860418 S

0.0 B

5 HA TURBIN Reduced load to 700 MWe to perform Turbine surveillances 86-14 860427 S

0.0 H

5 ZZ ZZZZZZ Reduced load to 600 MWe per Load Dispatcher APPROVED AUG 101982

_ (final) ygg3g

t 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 j

valve was actuated, how it was actuated, and the circumstances resulting in its actuation.

i Unit: One Date: April 5, 1986 i

Valves Actuated:

No. & Type of Actuation:

i 1-203-3A 1 - Manual 1-203-3B 1 - Manual 1-203-3C 1 - Manual i

1-203-3D 1 - Manual 1-203-3E 1 - Manual 1

Plant Conditions:

Reactor Pressure - 940 psig I

Description of Events:

Surveillance, Technical Specification 4.5.D.l.a Unit: Two h

Date: April 18, 1986 i

Valves Actuated:

No. & Type of Actuation:

2-203-3A 1 - Manual 2-203-3B 1 - Manual 2-203-3C 1 - Manual 2-203-3D 1 - Manual 3

2-203-3E 1 - Manual j

Plant Conditions:

Reactor Pressure - 948 psig Description of Events: Surveillance, Technical Specification 4.5.D.1.a 4

]

...,... _.. ~. _,

VI.

UNIQUE REPORTING REQUIREMENTS (cont.)

B.

Control Rod Drive Scram Timing Data for Units One and Two The basis for reporting this data to the Nuclear Regulatory Commission are specified in the surveillance requirements of Technical'Specifica-tion 4.3.C.1 and 4.3.C.2.

The-following table is a complete summary of Units One and Two Control Rod Drive Scram Timing for the reporting period. All scram timing was performed with Reactor pressure greater than 800 psig.

RESULTS OF SCRAM TIMING MEASUREMENTS PERF0fWED ON UNIT 1 & 2 CONTROL 1

R00 DRIVES, FROM 1-1-86 TO 12-31-86 AVERAGE TIME IN SEC0leS AT %

MAX. TIME INSERTED FROM FULLY WITIORAWN FOR 90%

INSERTION DESCRIPTION NIABER S

20 50 90 Technical Specification 3.3.C.1 &

DATE OF RODS 0.375 0.900 2.00 3.5 7 sec.

3.3.C.2 (Average Scram insertion Time) 4-6-86 177 0.29 0.68 1.46 2.58 2.95 Unit 1 Hot Scram Timing (J-10) l 4-18-86 88 0.30 0.66 1.41 2.49 3.08 Unit 2 Hot Scram Timing - A Sequence (H-11)

(

0027H/0061Z

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.

s QTP 300-S32 Revision 1 QUAD-CITIES REFUELING Narch 1978 INFORMATION REQUEST 1.

Unit:

Q1 Reload:

8 Cycle:

9 2.

Scheduled date for next refueling shutdown:

9-14-87 3

Scheduled date for restart following refueling:

12-21-87 4.

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

NOT AS YET DETERMINED.

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

AUGUST 21, 1987 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.

7 The number of fuel assembiles, a.

Number of assemblies in core:

724 b.

Number of assemblies in spent fuel pool:

1894 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 IIcensed 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 APPROVED APR 2 01978 Q.C.O.S.R.

l..

QTP 300-532 Revision 1 QUAD-CITIES REFUELING March 1978 INFORMATION REQUEST 1.

Unit:

Q2 Reload:

7 Cycle:

8 2.

Scheduled date for next refueling shutdown:

10-13-86 3

Scheduled date for restart following refueling:

1-19-87 4.

Will refueling or resumption of operation thereaf ter require a technical 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 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:

NONE PLANNED AT PRESENT TIME.

7 The number of fuel assemblies.

a.

Number of assemblies in core:

724 b.

Number of assemblies in spent fuel pool:

838 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:

Licensed storage capacity for spent fuel:

3897 a.

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 WPPROVED APR 2 01978 Q.C.O.S.R.

' ~

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

ACAD/ CAM -

Atmospheric Containment Atmospheric Dilution / Containment Atmospheric Monitoring ANSI American National Standards Institute APRM Average Power Range Monitor ATWS Anticipated Transient Without Scram BWR 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 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 Building Closed Cooling Water System TIP Traversing Incore Probe 1

TSC Technical Support Center

a Commonwealth Edison ouad Cities Nuclear Power Station 22710 206 Avenue North Cordova, Illinois 61242 Telephone 309/654-2241 RAR-86-09 May 1, 1986 Director, Office of Inspection & Enforcemeat United States Nuclear Regulatory Comm13sion Washington, D. C.

20555 Attention: Document Control Desk 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 April, 1986.

Respectfully, COMMONWEALTH EDISON COMPANY QUAD-CITIES NUCLEAR POWER STATION

$ b.

R. A. Robey Services Superintendent bb Enclosure i

' l

'

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