ML20214D611
| ML20214D611 | |
| Person / Time | |
|---|---|
| Site: | Quad Cities  |
| Issue date: | 04/30/1987 |
| From: | Robey R, Schmidt A COMMONWEALTH EDISON CO. |
| To: | NRC, NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM) |
| References | |
| 0027H, 0061Z, 27H, 61Z, RAR-87-23, NUDOCS 8705210396 | |
| Download: ML20214D611 (26) | |
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4 QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT APRIL, 1987 COMMONNEALTH EDISON COMPANY AND IONA-ILLINOIS GAS &' ELECTRIC COMPANY NRC DOCKET NOS. 50-254 AND 50-265 LICENSE NOS. DPR-29 AND OPR-30 t
0027H/0061Z
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8705210396 870430
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_ TABLE OF_ CONTENTS I.
Introduction
't II.
Summary cf Operating Experience A.
Unit One B.
Unit Two III.
Plant or Procedure Chanqes, Tests, Experiments, and Safety Related Maintenance-
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-A. : Amendments to Facility License or Technical Specifications B.
Facility or Procedure Changes Requiring NRC Approval C.
Tests and Experiments Requiring NRC Approval D.
Corrective Maintenance of Safety Related Equipment IV.
. Licensee Event Reports V.
Data Tabulations A.
Operating Data Report B.
Average Daily Unit Power Level C.
Unit Shutdowns and Power Reductions
-VI.
Unique Reporting Requirements A.
Main Steam Relief Valve Operations
'B.
Control Rod Drive Scram Timing Data VII.
Refueling Information VIII.
. Glossary f
0027H/0061Z
I.
IKfR000CTION 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 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 18, 1971, and April 26, 1972. Commercial generation of power began on February 18, 1973 for Unit One and March 10, 1973 for Unit Two.
This. report was compiled by Lynne Deelsnyder and Kurt Schmidt, telephone number 309-654-2241, extensient 2240 and 2147.
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II. -
SUMMARY
OF OPERATING EXPERIENCE A.c. Unit l'-
LApril-1-15 The. month of April' began with' Unit'One holding full load. At 0710'on Apriin1Lload was reduced from'825 MWe to.775.to allow for control rod movement. Beginning at 0800, load was increased at 5.MWe per hour Juntil full load was reached at 1300.' Full load was held _until April'3 at 0030 when load was-reduced for surveillances and control rod maneuvers to 700 MWe at 0140.',Following the rod maneuvers, load was increased from 734 to 790 MWe beginning at 0222.'
790 MWe was reached at 0245 and
- from there load was increased to full at 5 MWe per hour. At 0905 full cload was reached and held until.1903. At 1345, the High Pressure-Coolant Injection (HPCI) system was declared -inoperat,1ve following a failed surveillance. At 1903, a-load reduction was begun to
- facilitate surveillances required by the HPCI inoperative-condition. At_1955 HPCI was tested and declared operable, the load reduction was stopped-
'at 757 MWe. -At 2010 load was' increased from 757 to 790'and at 2022 power' ascension'to' full was started at 5 MWe/hr.
Full load.was reached -
LatLO440 on' April 4 and held until 1800 when load was' reduced to 800 for:EGC. The unit was operated in EGC from.1818 until 2230 when load was reduced for. Main Steam Isolation Valve (MSIV) timing. The. load reduction was completed at 0030 on April 5.
The load was held at 600 MWe-until 0700 when a load increase to 770 MWe was started.
770 MWe was reached at 0808,'the ascent to full power continued at 5 MWe/hr.
At.1120, load was increased.from 785 to 800 and the 5 MWe/hr increase was resumed. Full load was reached at 1900, and held until 1203 on
. April'6 when load was reduced for EGC.
The unit.ran in EGC with only brief interruptions from 1225 April 6 until 0853 on April 8.
ECC was shut off and load increased slowly to full by 1040.
Full load was held until 1728, when load was reduced for EGC operation at 1748.
EGC was run until 0620 on April 10.
The unit was taken out of EGC and load increased to full by 1030 and held until 0035 on April 11.
The unit was operated in EGC from 0050 until 1940 when it was tripped for a reserve emergency and load held at 800 until 2120 when the unit was returned to EGC.
On April 12, ECC was off from_0126 to 0307 for turbine surveillances. The unit came out of EGC at 0816 on April 13, load was increased to 800 MWe by 0830 and then at 5 MWe/hr to full by 1330.
Full load was held until 0010 on April 15 with a slight reducticn for control rod maneuvering at 0421 on April 14.
On April 15, the unit was placed in EGC at 0025 and run until 1700 when load was reduced sharply in order to effect repairs on the C3 feedwater heater emergency drain valve. At 1930 load was at 418 MWe and was held near this load until 0328 on April 16.
0027H/0061Z g
April 16-30 At 0000 on April 16, the unit was holding reduced load while maintenance was in progress on feedwater heater valves. At 0328 a load increase was. begun, continuing until 0945 when load was held at 630 MWe to allow completion of work on the C3 feedwater heater valve. At 1145 a slow load increase (5 MWe/hr) was started and continued until 0830 on April 18 when full load was finally reached.
Full load was held until 2235 when it was reduced for EGC operation beginning at 2300. The unit was out of EGC from 0125 to 0230 and from 1950 to 2127 on April 19 for turbine surveillance and control-rod maneuvering respectively. The unit was taken out.of EGC at 0700 on April 20 and increased to full load by 1200.
Full load was held until 0050 on April 22 when load was reduced for EGC operation.
EGC operated from 0125 to 0605 when the unit was brought
'back to full load by 0630.
Full load was held until 0015 on April 23 and then reduced for EGC. - The unit ran in EGC with only minor inter-ruptions from 0053 on April 23 until 0805 on April 27.
The unit was brought to full load by 1045 and held until 0335 on April 28.
The unit was run in EGC from 0400 to 0718 and then increased back to full load by 0725. Full load was held until 0025 on April 29.
EGC was operated from 0040 to 0705. Load was increased to full and held until 0100 on April 30.
The unit ran'in EGC from 0137 to 1414 and finished the month holding 804 MWe load.
B.
Unit 2 April 1-15 The month of April began with unit two holding full load. At 1610 load was reduced for EGC.
EGC was operated from 1635 until 0104 on April 2 when it was shut off for a turbine surveillance until 0219 and then operated until 0810. The unit was brought up to full load by 0820 and held.until 2130 on April 3.
Power was reduced to accommodate vacuum leak testing of the main condenser using helium gas leak detection equipment. Load was held at'400 MWe from 0040 to 0630 on April 4.
A load increase was then begun with the unit reaching full load at 1300.
Full load was held for the rest of April 4, for April 5 and until 0130 on April 6.
Load was reduced at the request of the Chicago load dis-patcher.
Load was held at 700 MWe from 0230 to 0500. Load was increased to 805 MWe at 0550. At 0820, rod withdrawals increased load to 825 MWe which was held until 1150 when load was reduced for EGC. The unit ran on EGC with only brief interruptions from 1210 on April 6 until 0713 cnt April 8.
At 0713 the unit was increased to full load which was held until 1725. Load was reduced and the unit operated in EGC from 1749 until 0010 on April 9.
EGC was off from 0010 to 0111 for a turbine surveillance and again briefly at 0426 due to a data transmission line problem. The unit' operated in EGC the remainder of April 9 and until 0625 on April 10.
The unit was raised to full load by 0714 and held load until 0030 on April 11 when it was reduced for EGC. The unit was placed in EGC at 0045, at 1938 ECC tripped but load was held at 810 until 2120 when the unit was returned u
to EGC. The unit was taken out of EGC at 0025 on April 12 and load reduced to allow for equipment changes,-i.e. Main Condenser flow reversal. feedwater pump switching and cycling of cire water pumps.
Load was held at 445 MWe from 0255 to 0600. A load increase was then begun and full load reached at 1005. On April 13 at 0820 a' rapid load reduction was started due to a problem with a feedwater pump.
Investigation of the pump problem concluded that it was not as urgent as initially believed so load reduction was stopped at 0835 at 744 MWe and a return to full load begun.
Full-load was reached at 0930 and held until 1730 when it was then dropped for work on the feedwater pump. Load was held at 425 MWe from 1925 until 0040 on April 14.
Load was then raised to 600 by 0200, and to 770 by 0355. A planned slow increase to full load _was modified by a power drop caused by rod.
maneuvers at 0910 and 0925. Following the rod movements the load increase continued and full power was reached at 1107. Full load was held until 1410 on April 15 when it was reduced for EGC.
The unit operated in EGC from 1435 until 0015 on April 16.
April 16-30 At 0015 on April 16 the unit was taken off EGC and load reduced for a turbine surveillance. The unit was placed back in EGC at 0157 and operated until 0605. The unit was raised to full load by 0650 and held load until 0005 on April 17.
The unit wac operated continuously in EGC from 0031 on_ April 17 until 0130 on April 20 with two brief, routine exceptions. At 0130 on April 20, EGC was tripped for a pressure regulator test after which the unit was raised to full load.
Full load was held from 0310 on April 20 until 2105 on April 22.
Load was reduced and the unit placed in EGC. On April 23 EGC was off_from 0015 to 0215 for turbine surveillance, from 1435 to 1444 for rod maneuvering and from 1635 to 1637 because of an input failure trip. On April 24 EGC tripped twice due to input failures once at 0255 to 0300 and again from 0530 to 0531. At 1022 the unit was taken out of EGC and load raised to full to do core flow calibrations. At 1940 load was reduced and at 1952 the unit placed in EGC where it ran until 2305 on April 25.
At that time the unit was taken off EGC and load reduced to facilitate scheduled surveillances. At 0100 on April 26, 600 MWe was reached and held during MSlV closure time testing. At 0215 it was determined that 3 of the MSIV's had closed too fast and a load reduction was started. At 0230, a GSEP unusual event was declared due to the fail valve timing surveil-lance, and the load drop was accelerated. At 0330 the valve timing was repeated and all valves tested satisfactorily. At 0340 it was decided that the load drop should continue in order to adjust the valves which had previously failed. At 0400 the GSEP unusual event was terminated.
At 0510, 212 MWe was reached and held durin the adjustment of the MSIV's.
g At 0723 load was further decreased to 175 Mt. to avoid exceeding a core power density limitation.
175 MWe was held from 0750 to 1050 when the MSIV adjustments were completed. At 1204, withdrawal of control. rods was begun to restore normal rod positions. The control rod movements were complete at 1440 and the load increase continued using recirculation l
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iflow. At 1920 load was reduced at the request of the Chicago-load dispatchei
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- and held at 700 MWe from_1931 until the next morning at 0535 on April 27.
Load was increased to fu11 by 0728 until'1434 when. control rod maneu-vering caused a slight power reduction.- Full load was re-established at 1439 and held from then~until 0210 on April 30.
Load was reduced and the unit placed in EGC at 0225 where it operated for the rest of the day.
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'III.
PLANT OR PROCEDURE CHANGES TESTS, EXPERIMENTS, AND SAFETY
.RELATED MAINTENANCE A.. Amendments to Facility License or Technicai Specifications There were no Amendments to the Facility License or Technical Specifications for the reporting period.
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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 4
related maintenance performed on Units One and Two during the reporting period. This summary includes the following: Work Request Numbers, Licensee Event Report Numbers,' Components, Cause of Malfunctions, Results and Effects on Safe Operation, and Action Taken to Prevent Repetition.
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UNIT.1 MAINTENANCE
SUMMARY
, WORK REQUEST NO.: -Q53163
.LER NUMBER: N/A
~ COMPONENT:~.Sy' stem 8350 -- Repaired sections. of 250'VDC battery racks.
CAUSE OF MALFUNCTION: There was no malfunction..This was a planned occur-
_rence in which the 250 VDC battery was.taken out-of-service to be replaced
.per Modification'4-1-85-43.
-RESULTS'& EFFECTS ON SAFE OPERATION: At the time this work was'being done
-both units were in-the shutdown-mode.
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ACTION TAKEN TO-PREVENT REPETITION: No corrective action-is necessary as thisl Deviation Report was initiated only to document the Unit One1250 VDC
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battery being taken out-of-service.
WORK REQUEST NO.:.Q54059
.LER NUMBER: N/A COMPONENT:
System 300 - Installed mounting bolts on Hydraulic. Control Units.
1CAUSE OF MALFUNCTION: The cause of the two missing floor mounting bolts.on the Hydraulic Control Units was due to installation error.
RESULTS & EFFECTS ON SAFE OPERATION: According to a study conducted by Sargent & Lundy, the missing bolts do not impair the operability of the Hydraulic Control Units.
ACTION TAKEN TO PREVENT REPETITION: The corrective action taken was~to replace the missing bolts and torque them to 50 ft-lbs.
WORK REQUEST No.: Q54746 LER NUMBER: N/A
. COMPONENT: System 7500 - Replaced contacts on 1/2B SBGT Heater Breaker.
CAUSE OF MALFUNCTION: The root cause of the 1/2 B SBGT Heater Breaker failure was that the HFA relay contact was not making up adequately causing the' auxiliary contact to bind.
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s UNIT 1-MAINTENANCE
SUMMARY
WORK REQUEST NO.: Q54746 (cont.)
RESULTS & EFFECTS ON SAFE OPERATION: The-safety significance is considered minimal because the A SBGT was always available and proven operable as required
.by the Technical Specifications.
ACTION TAKEN TO PREVENT REPETITION: Action taken was to adjust the HFA relay, replace the auxiliary contact and the main contacts of the contactor. As this is an isolated incident no further action is necessary.
WORK REQUEST NO.: Q55342 LER-NUMBER: N/A COMPONENT:
System 1600 - Adjusted limit switch on Torus to Drywell Vacuum Breaker, 1-1601-32A.
CAUSE OF MALFUNCTION: The failure of the Drywell Vacuum Breaker, 1-1601-32A, was due to two pair of limit switches being out of adjustment.
RESULTS & EFFECTS ON SAFE OPERATION: The safety consequences of this event were minimal since the vacuum breaker was shown to be closed by the separation test.
ACTION TAKEN TO PREVENT REPETITION: The corrective action taken was to readjust the limit switches. No further action is deemed necessary at this time.
WORK REQUEST NO.:
Q55646 LER NUMBER:
87-004 COMPONENT:
System 2300 - Adjusted open limit on HPCI CCST Suction MCV.
(1-2301-6).
CAUSE OF MALFUNCTION: The cause of the HPCI CCST Suction Valve (MCV l-2301-6) to fail was due to normal wear.
RESULTS & EFFECTS ON SAFE OPERATION: The safety implications were minimal because it was subsequently demonstrated that all systems required to be operable were operable.
ACTION TAKEN TO PREVENT REPETITION: The action taken was to adjust the open limit switch. The valve was then cycled and timed three times success-fully. This is considered an isolated incident.
s UNIT 2 MAINTENANCE
SUMMARY
WORK REQUEST No.: Q51471 LER NUMBER: 87-002 COMPONENT:
System 1300 - Installed 1 " piping on RCIC Turbine.
CAUSE OF MALFUNCTION: The root cause for the oil flooding of the outboard bearing was a modification design deficiency.
RESULTS & EFFECTS ON SAFE OPERATION: As the RCIC system became operable within the required time limit and the HPCI system was proven operable during this time, safety consequences were minimal.
ACTION TAKEN TO PREVENT REPETITION: The action taken to prevent repetition of the oil flooding was the installation of 1/2" larger piping on the drain pipes from the outboard bearing casing.
WORK REQUEST No.: Q54741 LER NUMBER: N/A COMPONENT: System 6600 - Installed new motor and wiring to Unit 2 Diesel Generator Soak Back Pump (2-6601).
CAUSE OF MALFUNCTION: The root cause of the Diesel Generator Soak Back Pump Motor failure was due to normal wear of the motor's components.
RESULTS & EFFECTS ON SAFE OPERATION: Since Unit 2 was in the refuel mode at the time and the 1/2 Diesel Generator was already on, therefore operable, safety implications were minimal.
ACTION TAKEN TO PREVENT REPETITION: The motor was replaced and no further corrective action is considered necessary at this time.
WORK REQUEST No.: Q54963 LER NUMBER:
87-002 COMPONENT: System 1300 - Installed Ib" piping on RCIC Turbine.
CAUSE OF MALFUNCTION: The root cause for the oil flooding of the inboard bearing was a modification design deficiency.
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UNIT 2 MAINTENANCE
SUMMARY
WORK REQUEST NO.: Q54963 (cont.)
RESULTS & EFFECTS ON SAFE OPERATION: As the RCIC system became operable within the required time limit and the HPCI system was proven operable during this time, safety consequences were minimal.
ACTION TAKEN TO PREVENT REPETITION: The action taken to prevent repetition of the oil flooding was the installation of 1/2" larger piping on the drain pipes from the inboard bearing casing.
WORK REQUEST NO.: Q55379 LER NUMBER: N/A COMPONENT:
System 2300 - Cleaned the side of the open switch for MO 2-2301-35.
CAUSE OF MALFUNCTION: Valve 2-2301-35 would not close due to arcing at the open pushbutton switch contacts on the local control station. The arcing was caused by moisture and dirt on the switch contacts.
RESULTS & EFFECTS ON SAFE OPERATION: Valve 2-2301-36 is in service with 2-2301-35 and both are normally closed. Therefore, since 2-2301-36 was always shut the HPCI system maintained its normal pump suction path and would have been able to switch to its alternate source of water had it been required.
ACTION TAKEN TO PREVENT REPETITION:
Electrical Maintenance cleaned the open pushbutton switch contacts and returned the local control station to normal. The Unit Operator was then able to close the valve. As this is an isolated incident, no further correction action is necessary.
WORK REQUEST NO.:
Q55455 LER NUMBER: N/A COMPONENT:
System 200 - Cleaned connector and threshold on Acoustic Monitor for 2-203-3E.
CAUSE OF MALFUNCTION: The cause for the acoustic monitor problem on the 2-203-3E relief valve has been attributed to a dirty cable connector at the monitoring equipment on the 902-21 panel in the control room.
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I UNIT 2 MAINTENANCE
SUMMARY
I WORK REQUEST NO.: Q55455 (cont.)
RESULTS & EFFECTS ON SAFE OPERATION: As the thermocouple that provides a temperature measurement for this relief valve was still available, therefore continued operation was justified and safety implications were minimal.
ACTION TAKEN TO PREVENT REPETITION: The cable connection associated with the monitor was cleaned resulting in proper operation of the 3E relief valve. No further action is deemed necessary at this time.
WORK REQUEST NO.: Q55458 LER NUMBER:
87-004 COMPONENT: System 1600 - Reset the counter balance on the Drywell to Suppression Chamber Vacuum Breaker ( 2-1601-33A).
CAUSE OF MALFUNCTION: The cause for the 2-1601-33A vacuum breaker failure was determined to be to a dimpled valve bushing or a rusted and corroded solenoid associated with the air operated testing mechanism.
RESULTS & EFFECTS ON SAFE OPERATION: A GSEP Unusual Event was declared and appropriate notifications completed. The Unit was placed in cold shutdown and the GSEP Event terminated.
ACTION TAKEN TO PREVENT REPETITION: The vacuum breaker was disassembled, inspected, and reassembled. Various parts were replaced or adjusted, a dimpled bushing was filed smooth, and the solenoid replaced. This is considered an isolated incident and no further corrective action is necessary.
WORK REQUEST No.: Q55494 LER NUMBER:
87-004 COMPONENT: System 1600 - Replaced test cylinder and o-rings on the Drywell to Suppression Chamber Vacuum Breaker (2-1601-33A).
CAUSE OF MALFUNCTION: The cause for the 2-1601-33A vacuum breaker failure was determined to be to a dimpled valve bushing or a rusted and corroded solenoid associated with the air operated testing mechanism.
RESULTS & EFFECTS ON SAFE OPERATION: A GSEP Unusual Event was declared and appropriate notifications completed. The Unit was placed in cold shutdown and the GSEP Event terminated.
ACTION TAKEN TO PREVENT REPETITION: The vacuum breaker was disassembled, inspected, and reassembled.
Various parts were replaced or adjusted, a dimpled bushing was filed smooth, and the solenoid replaced. This is considered an isolated incident and no further corrective action is necessary.
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IV.
LICENSEE EVENT REPORTS l.
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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.B.2. of the Technical Specifications.
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UNIT I Licensee Event ~
Report' Number-Date Title of Occurrence 87-06 4-3-87 HPCI Inoperable --
Turbine Trip Would not Reset 87-07 4-14-87 Units 1/2 Diesel Fire Pump Inoperable UNIT 2' There were no-licensee event reports for the reporting period.
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V.
DATA TA8ULATIONS 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 0027H/0061Z L
OPERATING DATA REPORT DOCKET NO.
50-254 UNIT-ONE DATE6 MAY 1987 COMPLETED BYK.A. SCHMI_DT TELEPHONE 309-654-2241 OPERATING STATUS 0000 040187 1.
Reporting period 2400 043087 Gross hours in reporting period 719
-2.
Currently authorized power level (MWt): 2511 Max. Depend capacity
-(MW -Net): 769* Design electrital rating (MWe-Net): 789
- 3. Power: level to which restricted (if any)(MWe-Net): NA
- 4. Reasons for restriction (if any):
1 This Month Yr.to Date Cunulative 5.
Number of hours reactor was critical 719.0 2016.6
_ 105629.3 6.
Reactor reserve shutdown hours 0.0 0.0 3421.9 7.
Hours generator on line 7192 2000.6 10?2117.i 8.
Unit. reserve shutdown hours.
_0.0 0.0 909.2 9.
Gross thernal energy generated (MWH) 1714328 6687000 215744898 10._ Gross electrical energy generated (MWH) 565374 2214472 69967856 ii. Net electrical energy generated (MWH)
SR094 211.7997
_ 65565199 12.-Reactor service factor 100.0 97.8 80.5
- 13. Reactor avo11ob111ty factor 100.0 97.8 83.1
- 14. Unit service factor 1 0 0
__0 97._3 77.8
- 15.. Unit avo11obility factor 100.0 97.3 78.5 16.~ Unit copocity factor (Using MDC) 97.9 95.7.
65.0 17.-Unit capacity factor (Using Des.MWe)
_95.4_
9 3,._2 63.3
- 18. Unit forced outage rate O c0
.9 5.6
- 19. Shutdowns scheduled over next 6 nonths (Type, Dote,and Duration o f' each):
20.-If shutdown at end of report period,estinated date of startup l
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$UN0FFICIAL COMPMY NUMBERS ME USED IN THIS REPORT k
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- APPENDIX B f.
-AVERAGE' DAILY-UNIT. POWER LEVEL' d:
,b DOCKET NO..
50-25
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UNITi._.
ONE r
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DATE6'MAY 1987
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COMPLETED.BYK.A. SCHMIDT TELEPHONE 109-654-R241 MON'TH Ant 11'1987 DAY AVERAGE DAILY' POWER LEVEL DAY AVERAGE DAILY POWER LEVEL
(MWe-Net)
- (MWe-Net) 1.-
781.5 17, 701.7-
,2. s 784.5 18, 791.4
~3.s 772.8 19.
-753.5 4,
780.9 20.
786.8 5.-
686.8
'21, 769.4-l
.6.:
762.3 22..
789.8 r
7.
750.5 23.
741.0
'O.
772.3 24.
765.5 754.8 9.'
~727.0 25.
LO.
768.7 26, 747.6
'ii. -
750.O 27.
765 8 2
12.
750.6 28, 785.8 13.
772.7 29, 770.7 14.
774.3 30.
764.0
.15. --
660 7 2
.16.
468.3 INSTRUCTIONS e
On this forn
' neerest whole, list the evereqe dellt enit powr level in fik-kt for each day in the reporting nonth.Conpete to the negemett -
I These figeres will be esed to plot a graph for each reporting nenth. Nr.e that when notinen dependable capacity is sted for the net electrical rating of the snit,there not be ecceslens when the delly overage pour level exceeds the i-190I line (or the restricted powr level line).In soth cases,the overage dellt enit powr setpet sheet should be feetnoted to explain the apperent onenely 1
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OPERATING DATA REPORT DOCKET NO.
50-265
- UNIT, TWO DATE6_MAY 1987 COMPLETED BYK._&, SCHMIDT TELEPHONE 309-654-2241 OPERATING STATUS 0000 040187 i
Reporting period:2400 043037 Gross hours in reporting period 719
- 2. Currently authorized power level (MWt): 2511 Max. Depend copocity j
(MW2-Net): 769*' Design electrical rating (MWe-Net): 789
)
- 3. Power -level to which restricted (if any)(MWe-Net): NA L
- 4. Reasons for restriction (if any):
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This Month Yr.to Date CumulotIve
- 5. Number of hours reactor was critical 719.0 2251.7 99967.4 6.
Rect.t or reser ve shutdown hours
'01 0.0 2985.8 7.-Hours generator on line 719.0 2198.7 96897.0 8.
Unit reserve shutdown hours.
0.0 0.0 702.9
- 9. Gross thernal energy generated (HWH) 1701609 5101286 206440985
- 10. Gross electrical energy generated (MWH) 554264 1665084 66024376
- 11. Net electrical energy generated (MWH) 530906 1591596 62108633
- 12. Reactor service factor 100.0 78.2 76.7
- 13. Reactor avo11ob111ty factor 100.0
_70.2 79.0
[
- 14. Unit service factor 100.0 76.4 74.4
- 15. Unit a vo110tilli t y factor 100.0 76.4 74.9
- 16. Unit copucity factor (Using MDC) 96,0
_ 71.9 62.1 n
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- 17. Unit capacity factor (Using Des.MWe) 13.6 70.1 60.5
- 18. Unit forced outage rate 0.0 6,9 7.7
- 19. Shutdowns scheduled over next 6 nonths (Type,Date,and Duration of each):
- 20. If shutdown at end of report period,estinated date of stortup
$UN0FFICIAL COMPMY HUMERS ARE USED IN THIS REPORT
b APPENDIX B
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-AVERAGE DAILY UNIT' POWER LEVEL DOCKET NO.
50-265-UNIT,_
TWO I'
DATE6_MAY 1987 COMPLETED BYK.A. SCHMIDT TELEPHONE 309-654-2241 MONTH Aorl1 1987
,; DAY AVERAGE DAILY POWER LEVEL-DAY AVERAGE DAILY POWER LEVEL (MWe-Net).
(MWe-Net)
.i.
776.6 17.
742.1 2.
771.9 18.
743.4 3.
767.5 19.
752 5 4.
626,i 20.
703.8 5.
740.6 21, 775.9
~6.
743.2 22.
778_.0 7.
750 1 23.
73ZtB 0..
771.0 24.
770.1 9.
730.3 25.
753 B t
10.
767.2 26.
398.2
-ii.
752.2 27.
730.3 l
12. -
687.7 28.
777.1 13.
694.0 29.
768,0 14.
741.4 30.
751,0 15.
774.8
'16.
769.9
-INSTRUCTIONG
'On this fern list the overage dolly unit powr level in Me-Net for each day in the reporting nenth.Conpste to the
. nearest whole, negawatt.
These figures will be used to plot a graph for each reperting nenth. Note that when narinen dependable capacit is used for the net electrical roting of the snit,there may be occasions when the daily overage power level excee 5 the 100% line (or the restricted power level line).In sich cases,the overage dolly unit power entput sheet sheeld be festnoted to explain the apparent onenoly
-)
e ID/SA APPENDIX D QTP 300-S13 UNIT SHLTTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO.
050-254 August 1982 UNIT NAME Quad-Cities Unit 1 COMPLETED BY-K. Schmidt DATE May 6, 1987 REPORT MONTH APRIL 1987 TELEPHONE 309-654-2241 5
w e
5 g=@
$m w
@l@
$ gM g@
LICENSEE w
H w DURATION EVENT o"
NO.
DATE (HOURS)
REPORT NO.
u CORRECTIVE ACTIONS /COtt1ENTS o
87-10 870415 F
0 A
4 CH VALVEX Power reduction to repair'fe'edwater header drain valves.
I APPROVED AUG 161982 (final)
Q. C. U. S H
\\
l
e-
. ~..
ID/5A APPENDIX D QTP 300-S13 UNIT SHITTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO.
050-265 August 1982 UNIT NAME Quad-Cities Unit 2 COMPLETED BY K. Schmidt DATE May 6, 1987 REPORT MONTH APRIL 1987 TELEPHONE 309-654-2241 A
m
=
Et g
=
8 8~M MM 58 h"o x
LICENSEE g
mo go w
DURATION M
EVENT o"
g g
NO.
DATE (HOURS)
REPORT NO.
u g
CORRECTIVE ACTIONS /C0ftlENTS 87-15 870404 S
0 B
4 HC HTEXCH Power reduction for Helium Leak Testing of Main Condenser.
87-16 870426 F
0 B
4 CC VALV0P Power reduction for adjustment of MSIV operating time.
APPROVED' AUG161982 (final) y g,9 3 g
m-VI.lUNIQUEREPORTINGREQUIREMENTS-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.
0027H/0061Z L
c 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.
0027H/0061Z L
QTP 300-532 Revision 1 QUAD-CITIES REFUELING March 1978 INFORMATION REQUEST 1.
Unit:
01 Reload:
8 Cycle:
9 2.
Scheduled date for next refueling shutdown:
9-14-87 3.
Scheduled date for restart following refueling:
12-7-87 4.
Will refueling or resumption of operation thereafter require a technical specification change or other license amendment: YES. TECHNICAL SPECIFICATION CHANGES WILL BE REQUIRED FOR NEW FUEL TYPES (MAPHLGR CURVES) AND A LICENSE AMENDMENT TO MOVE SINGLE LOOP OPERATION INTO TECHNICAL SPECIFICATIONS.
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 supplier, unreviewed design or performance analysis, methods, significant changes in fuel design, new operating procedures:
FIRST RELOAD OF GEN.ERAL ELECTRIC, GE8E FUEL WITH 4 WATER-RODS AND LHGR LIMIT OF 14.4 KW/FT. FIRST CYCLE UTILIZING A DIFFUSION BASED CORE MONITORING CODE.
7.
The number of fuel assemblies.
a.
Number of assemblies In core:
724 b.
Number of assemblies in spent fuel pool:
1573 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 nur.ber 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: 2008
' C FD P Ft () \\/ EC E)
A 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:
8 Cycle:
9 2.
Scheduled date for next refueling shutdown:
3-14-88 3
scheduled date for restart following refueling:
5-22-88 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:
DECEMBER 14, 1987 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:
NONE AT PRESENT TIME.
7 The number of fuel assemblies.
I a.
Number of assemblies in core:
724 b.
Number of assemblies in spent fuel pool:
1308 8.
The present licensed spent fuel pool storage capacity and the size of any i
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 l
spent fuel pool assuming the present licensed capacity: 2008 WPPROVED APR 2 01978 Q.C.O.S.R.
____-_.m.
_ ~ _,
r"-~
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 Atmospherlc Monitoring ANSI American National Standards Institute Average Power Range Monitor APRM ATHS Anticipated Transient Without Scram Bolling Hater Reactor BHR CRD Control Rod Drive Electro-Hydraulic Control System EHC Emergency Operations Facility EOF Generating Stations Emergency Plan GSEP High-Efficiency Particulate Filter HEPA HPCI High Pressure Coolant Injection System HRSS High Radiation Sampling System Integrated Primary Containment Leak Rate Test IPCLRT Intermediate Range Monitor IRM ISI Inservice Inspection Licensee Event Report LER LLRT Local Leak Rate Test LPCI Low Pressure Coolant Injection Mode of RHRS Local Power Range Monttor LPRM Maximum Average Planar Linear Heat Generation Rate MAPLHGR 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 Primary Containment Isolation PCI PCIOMR Preconditioning Interim Operating Management Recommendations Reactor Building Closed Cooling Water System RBCCW RBH Rod Block Monitor Reactor Core Isolation Cooling System RCIC Residual Heat Removal System RHRS Reactor Protection System RPS RHH Rod Horth Minimizer Standby Gas Treatment System SBGTS Standby Liquid Control SBLC Shutdown Cooling Mode of RHRS SDC Scram Olscharge Volume SOV Source Range Monitor SRM Turbine Building Closed Cooling Hater System TBCCH TIP Traversing Incore Probe Technical Support Center TSC 0027H/0061Z b - - ----
O Commonwealth Edison ouad Cities Nuclear Power Station 22710 206 Avenue North Cordova. Illinois 61242 Telephone 309/654-2241 RAR-87-23 May 8, 1987 Director, Office of Inspection & Enforcement United States Nuclear Regulatory Commission 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, 1987.
Respectfully, COMMONHEALTH EDISON COMPANY QUAD-CITIES NUCLEAR POWER STATION
,S. 0 R. A. Robe Services Superintendent Ifd Enclosure 0027H/00612
'0