ML20247H599

Monthly Operating Repts for Aug 1989 for Quad-Cities Nuclear Power Station,Units 1 & 2

ML20247H599
Person / Time
Site:	Quad Cities
Issue date:	08/31/1989
From:	Deelsnyder L, Robey R COMMONWEALTH EDISON CO.
To:	NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
RAR-89-60, NUDOCS 8909200032
Download: ML20247H599 (25)

Text

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., O, 7-~~'N Commonwrith Edison 1 / --

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) ouad Cities Nuclear Power Station

- 22710 206 Avenue North

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Cordova, Illinois 61242 9740 s

Telephone 309/654 2241 RAR-89-60 September 1. 1989 Director of Nuclear Reactor Regulations U. S. Nuclear Regulatory Commission Mail Station Pl-137 Washington, D. C. 20555 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, 1989.

Respectfully, COMMONWEALTH EDISON COMPANY QUAD-CITIES NUCLEAR POWER STATION R. A. Robey Technical Superintendent RAR/LFD/djb Enclosure 8909200032 890831 PDR ADOCK 05000254 R ppc 0027H/0061Z l g

.. 'o QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT AUGUST, 1989 COMMONWEALTH EDISON COMPANY AND IOWA-ILLINOIS GAS & ELECTRIC COMPANY NRC DOCKET NOS. 50-254 AND 50-265 LICENSE NOS. DPR-29 AND DPR-30 l

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• 1 TABLE OF CONTENTS l

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 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 Saf2ty 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 I

VIII. Glossary 0027H/0061Z

r I. INTRODUCTION Quad-Cities Nuclear Power Station is composed of two Boiling Water Reactors, each with a Maximum Dependable Capacity of 769 MWe Net, located in Cordova, Illinois. The Station is jointly owned by Commonwealth Edison Company and Iowa-Illinois Gas & Electric Company. The Nuclear Steam Supply Systems are General Electric Company Boiling Water Reactors. The Architect / Engineer was Sargent & Lundy Incorporated, and the primary construction contractor was United Engineers & Constructors. The Mississippi River is the condenser cooling water source. The plant is subject to license numbers DPR-29 and DPR-30, issued October 1, 1971, and 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 Verna Koselka, telephone number 309-554-2241, extensions 2185 and 2240.

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II.

SUMMARY

OF OPERATING EXPERIENCE A. Unit One Unit One began the month of August operating at 726 MWe. At 0213 hours0.00247 days <br />0.0592 hours <br />3.521825e-4 weeks <br />8.10465e-5 months <br />, the unit was placed in Economic Generation Control (EGC). At 0327 hours0.00378 days <br />0.0908 hours <br />5.406746e-4 weeks <br />1.244235e-4 months <br />, EGC was tripped and a power reduction to 500 MWe was taken at the request of the Chicago Load Dispatcher. At 0723 hours0.00837 days <br />0.201 hours <br />0.0012 weeks <br />2.751015e-4 months <br />, power levels were increased to 677 MWe per the request of the Load Dispatcher. Power levels remained l constant while control rod maintenance and testing was performed. On 1

Augost 3, at 0140 hours0.00162 days <br />0.0389 hours <br />2.314815e-4 weeks <br />5.327e-5 months <br />, the unit was placed in EGC, At 0415 hours0.0048 days <br />0.115 hours <br />6.861772e-4 weeks <br />1.579075e-4 months <br />, EGG was tripped and the unit was taken to maximum attainable power while control rod maintenance continued.

On August 4, at 0320 hours0.0037 days <br />0.0889 hours <br />5.291005e-4 weeks <br />1.2176e-4 months <br />, power levels were adjusted in preparation for EGC operation. At 0345 hours0.00399 days <br />0.0958 hours <br />5.704365e-4 weeks <br />1.312725e-4 months <br />, the unit was placed in EGC. At 1040 hours0.012 days <br />0.289 hours <br />0.00172 weeks <br />3.9572e-4 months <br />, ECC.was tripped and a power increase was taken per the request of the Load Dispatcher. On August 3, at 0104 hours0.0012 days <br />0.0289 hours <br />1.719577e-4 weeks <br />3.9572e-5 months <br />, the unit was placed in EGC. At 2110 hours0.0244 days <br />0.586 hours <br />0.00349 weeks <br />8.02855e-4 months <br />, ECC was_ tripped-and a power reduction to 250 MWe was taken for the purpose of performing a hanger inspection per a Technical Staff modification. On August 6, at 0620 hours0.00718 days <br />0.172 hours <br />0.00103 weeks <br />2.3591e-4 months <br />, a load increase to 450 MWe was taken using recirculation pumps. At 0900 hours0.0104 days <br />0.25 hours <br />0.00149 weeks <br />3.4245e-4 months <br />, power levels were further increased to 750 MWe at the request of the Load Dispatcher.

From August 7 to August 9 power levels were adjusted according to the demands of the Chicago Load Dispatcher. On August 9, at 1845 hours0.0214 days <br />0.513 hours <br />0.00305 weeks <br />7.020225e-4 months <br />, the unit was placed in EGC. On August 10, at 1230 hours0.0142 days <br />0.342 hours <br />0.00203 weeks <br />4.68015e-4 months <br />, ECC was tripped and the unit was taken to maximum attainable power per the request of the Load Dispatcher.

At 1930 hours0.0223 days <br />0.536 hours <br />0.00319 weeks <br />7.34365e-4 months <br />, the unit was placed in EGC. On August 11, at 1000 hours0.0116 days <br />0.278 hours <br />0.00165 weeks <br />3.805e-4 months <br />, the unit was taken off of FGC and load was increased to 683 MWe. On August 12, at 0030 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />, power levels were adjusted, and the unit was placed in EGC.

At 0130 hours0.0015 days <br />0.0361 hours <br />2.149471e-4 weeks <br />4.9465e-5 months <br />, on August 13, EGC was tripped, and a power reduction to 250 MWe was taken.

From August 13 to August 15, power levels were adjusted according to the demands of the Chicago Load Dispatcher. On August 15, at 0227 hours0.00263 days <br />0.0631 hours <br />3.753307e-4 weeks <br />8.63735e-5 months <br />, the unit was placed in EGC. The unit remained in EGC until August 16. At 1643 hours0.019 days <br />0.456 hours <br />0.00272 weeks <br />6.251615e-4 months <br />, EGC was tripped and the unit was taken to maximum attainable power levels while routine surveillance and normal operational activities were performed. On August 17, at 1300 hours0.015 days <br />0.361 hours <br />0.00215 weeks <br />4.9465e-4 months <br />, power levels were adjusted and the unit was placed in EGC. The unit remained in EGC until August 18.

At 0115 hours0.00133 days <br />0.0319 hours <br />1.901455e-4 weeks <br />4.37575e-5 months <br />, the unit was taken out of EGC and a load reduction was taken to 450 MWe. At 0650 bours, load was increased to 658 MWe at the request of the Load Dispatcher.

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.. :1 From August 19 to August 22, normal operational activities occurred and power levels were adjusted according to the requests of the Chicago Load Dispatcher.' Power levels remained near maximum attainable power or the unit operated in EGC. Monthly surveillance were successfully performed and completed.

On August 23, the motor-generator set electrical stops were set for maximum core flow due to continuous recirculation flow spiking. The unit operated in EGC as requested by the Load Dispatcher, and power levels were adjusted accordingly.

On August 25, at.1045 hours0.0121 days <br />0.29 hours <br />0.00173 weeks <br />3.976225e-4 months <br />, the unit was taken out of EGC and the recircu-lation pumps were placed to MANUAL mode. A power reduction was taken due to control valve fast acting solenoids being inoperable. A Generating Station Emergency Plan unusual event was declared. At 1208 hours0.014 days <br />0.336 hours <br />0.002 weeks <br />4.59644e-4 months <br />, power levels were held constant at 315 MWe while the problem was resolved. On August 26, a load increase was begun using control rods and recirculation pumps. At 1544 hours0.0179 days <br />0.429 hours <br />0.00255 weeks <br />5.87492e-4 months <br />, the 1A recirculation pump seal outboard pressure was observed to be fluctuating from 450 PSI to 300 PSI. Shift engineer was notified, and the seal leakage was closely monitored.

On August 29, at 1025 hours0.0119 days <br />0.285 hours <br />0.00169 weeks <br />3.900125e-4 months <br />, a condenser low vacuum alarm was received in the control room. Load was quickly reduced using recirculation pumps and control rods. At 1040 hours0.012 days <br />0.289 hours <br />0.00172 weeks <br />3.9572e-4 months <br />, condenser vacuum was still decreasing.

At 1202 hours0.0139 days <br />0.334 hours <br />0.00199 weeks <br />4.57361e-4 months <br />, the mode switch was placed to Startup/ Hot Standby, and at 1206 hours0.014 days <br />0.335 hours <br />0.00199 weeks <br />4.58883e-4 months <br />, the generator was taken off line. Investigations were made into the cause of the condenser air inleakage. The cause of the excessive air inleakage,was determined to be a loosening of a temporary patch on the steam supply line between the A low pressure turbine and the #4 CIV. Repairs were made to the patch. The generator was synchronized at 2052 hours0.0238 days <br />0.57 hours <br />0.00339 weeks <br />7.80786e-4 months <br />. On August 30, at 0030 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />, power levels were increased to 200 MWe and investi-gations for other smaller sources of air inleakage continued. At 0815 hours0.00943 days <br />0.226 hours <br />0.00135 weeks <br />3.101075e-4 months <br />, load was increased towards the maximum attainable capacity. At 1740 hours0.0201 days <br />0.483 hours <br />0.00288 weeks <br />6.6207e-4 months <br />, 750 MWe was reached.

For the remainder of the month, maximum attainable power levels were held constant while normal operational activities occurred.

B. Unit Two i

Unit Two began the month of August operating at 807 MWe, Power levels were held constant while Traversing In-Core Probe Set testing was performed.

On August 2, at 1315 hours0.0152 days <br />0.365 hours <br />0.00217 weeks <br />5.003575e-4 months <br />, the unit was placed in Economic Generation Control (EGC). On August 3, at 1259 hours0.0146 days <br />0.35 hours <br />0.00208 weeks <br />4.790495e-4 months <br />, EGC was tripped at the request of'the Chicago Load Dispatcher, and the unit was taken to full power. On August 4, at 0315 hours0.00365 days <br />0.0875 hours <br />5.208333e-4 weeks <br />1.198575e-4 months <br />, a power reduction to 600 MWe was taken for condenser flow reversal. At 0618 hours0.00715 days <br />0.172 hours <br />0.00102 weeks <br />2.35149e-4 months <br />, the unit was taken back up to 784 MWe with control rod maneuvers. On August 5, routine surveillance were completed.

On August 6, at 0113 hours0.00131 days <br />0.0314 hours <br />1.868386e-4 weeks <br />4.29965e-5 months <br />, power levels were adjusted and the unit was placed in ECC. On August 6, at 2305 hours0.0267 days <br />0.64 hours <br />0.00381 weeks <br />8.770525e-4 months <br />, EGC was tripped at the request of the Load Dispatcher.

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,,_ e, From August 7 thru August 14, normal operational activities and routine surveillance were performed and successfully completed. Power levels

,ere adjusted accordingly and the demands of the Chicago Load Dispatcher were met.

From August 15 thru August 19, the unit operated in EGC or remained near full power levels. From August 20 thru August.24, normal plant activities were conducted, and power levels were adjusted according to the requests of the Load Dispatcher.

A scheduled maintenance outage was started on August 25 to replace 2A recirc pump seal. At 0032 hours3.703704e-4 days <br />0.00889 hours <br />5.291005e-5 weeks <br />1.2176e-5 months <br />, the main turbine was tripped and the generator was taken off-line. At 0125 hours0.00145 days <br />0.0347 hours <br />2.066799e-4 weeks <br />4.75625e-5 months <br />, the mode switch was placed to SHUTDOWN and the reactor was manually scrammed. This was to be a scheduled maintenance outage thru August 27. However, at 1000 hours0.0116 days <br />0.278 hours <br />0.00165 weeks <br />3.805e-4 months <br /> on August 27, a report was received that there was an excessive amount of water running in the Turbine Building elevator. Upon investigation, it was discovered that the "B" Residual Heat Removal Service Water Line, which had been ieaking, had increased its leakage rate. A pipe plate was installed to isolate the leak from the 2B RHR heat exchanger and the Unit One to Unit Two B loop RHRSW crosstie was opened. An emergency Tech Spec change was granted to allow continued operation.

On' August 31, at 1820 hours0.0211 days <br />0.506 hours <br />0.00301 weeks <br />6.9251e-4 months <br />, reactor startup commenced. At 2008 hours0.0232 days <br />0.558 hours <br />0.00332 weeks <br />7.64044e-4 months <br />, the reactor was made critical. The generator was synchronized to the grid on September.1._

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l III. PLANT OR PROCEDURE CHANGES, TESTS, EXPERIMENTS, AND SArETY RELATED MAINTENANCE A. Amendments to Facility License or Technical Specifications lhere 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 werc no Tests or Experiments requiring NRC approval for the reporting period.

l D. Corrective Maintenance of Safety Reinted Equipment  ;

The following represents a tabular summary of the major safety related maintenance performed on Units One and Two during the reporting period. This summary includes the following: Work Request Numbers, Licensee Event Report Numbers, Components.

Cause of Malfunctions, Results and Effects on Safe Operation, and Action Taken to Prevent Repetition.

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, g UNIT 1 MAINTENANCE

SUMMARY

WORK REQUEST NO.: Q76736 LER NUMBER: N/A

, COMPONENT: System 302 - A Channel "B" half scram was received due to erratic Scram Discharge Volume (SDV) Level Switch LS 1-302-82B.

CAUSE OF MALFUNCTION: The cause of the Channel "B" half scram is due to a defective circuit board in level switch LS 1-302-82B. When the circuit board failed, the 590-100B relay intermittently de-energized causing the spurious "B" channel half scram.

RESULTS & EFFECTS ON SAFE OPERATION: There are four switches for each SDV high high level scram. This is part of the Reactor Protection System (RPS) which utilizes a one-out-of-two taken twice logic to prevent a single compo-nent failure from actuating a full scram. The safety consequences for this event were minimal because had an actual high level occurred, the system would have functioned as designed and a reactor scram would have occurred.

ACTION,TAKEN TO PREVENT REPETITION: Work .90 guest Q76736 was written to. investigate the Chranel "B" half sc. ram. The circuit board for the level switch was replaced and the cause of the circuit board failure was investigated under Work Request Q76738. The results of the investigation were not available, however, at the time of this report.

Work Request No.: Q76990, Q76995 LER NUMBER: N/A COMPONENT: System 6600 - While performing QOS 6600-1, Diesel Generator Monthly Load Test, the control room received the DIESEL 1 TROUBLE alarm. The trouble was determined to be the " ENGINE TEMPERATURE HIGH" local clarm. The engine temperature was 193*F and increasing. The Diesel Generator was unloaded and an investigation began.

CAUSE OF MALFUNCTION: The causr.- of the engine high temperature was component failure of one or more thermostatic valves due to o-ring seal wear and hardening.

0-ring seal wear and hardening resulted in the failure of one or more of the valves to open at the set temperatures. This resulted in too much coolant flow being routed from the engine outlet directly back to the engine, with a resultant decrease in flow to the heat exchangers, which caused the elevated operating temperatures.

RESULTS & EFFECTS ON SAFE OPERATION: The safety implications of this event were minimal since the safety systems required by Technical Specifications were fully operable. Further, the Diesel Generator Engine High Temperature Trip is bypassed under emergency conditions and thus could continue its operation at elevated temperatures. The 1/2 Diesel Generator was available at all times during the event.

ACTION TAKEN TO PREVENT REPETITION: The immediate corrective action was to shutdown the Diesel Generator and to investigate the abnormal temperature conditions. This was done under work requests Q76990 and Q76995. Mechanical Maintenance removed the nine thermostatic valves. All showed signs of o-ring seal wear and hardening. As a precautionary measure, all nine valves were replaced with new valves.

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WORK REQUEST NO.: Q76999 LER NUMBER: 89-007 COMPONENT: System 1700 - The 1A Refuel Floor Radiation Monitor spiked high causing the reactor building vents and control room HVAC to isolate and 1/2A Standby Gas Treatment System (SBGTS) to auto-start.

CAUSE OF MALFUNCTION: The cause of the event was a faulty Geiger Mueller (GM) tube in the sensor converter assembly. When these GM tubes become defective, ,

I their response becomes erratic, producing spikes that may result in spurious signals.

RESULTS & EFFECTS ON SAFE OPERATION: The safety consequences of the event were minimal since the IB refuel floor radiation monitor was operable throughout the event. The 1A refuel floor radiation monitor was inoperable for only 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

Technical Specifications allow any one of the monitors to be inoperable for a 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> period. In addition, all protective trips and alarms occurred as designed.

ACTION TAKEN TO PREVENT REPETITION: Work Request Q76999 was written to trouble-shoot the monitor. The faulty GM tube was replaced.

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UNIT 2 MAINTENANCE

SUMMARY

WORK REQUEST NO.: Q76658 LER NUMBER: N/A COMPONENT: System 1700 - The 2B Main Steam Line (MSL) radiation monitor failed, causing a half scram and half isolations. Work Request Q76658 was written to repair the radiation monitor. The monitor was replaced with a calibrated and functionally tested spare.

CAUSE OF MALFUNCTION: The cause of the event was declared to be random equip-ment failure. The K3 relay of the input / output board fa11ed, causing the upscale contact to fail open. This resulted in a half Group I isolation and half scram.

RESULTS & EFFECTS ON SAFE OPERATION: The safety consequences were minimal since the Reactor Protection System and Primary Containment Isolation System were fully operable during the entire event.

ACTION TAKEN TO PREVENT REPETITION: Work Request Q76658 was written to repair the "B" MSL radiation monitor. The monitor was replaced with a tested spare.

The failure of the K3 relay was found to be an isolated incidence.

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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.B.2. of the Technical : specifications.

UNIT 1 Licensee Event Report Number Date Title of Occurrence 89-013 8-21-89 Missed Four Hour Tech Spec Surveillance on Main Chimney Sample Pp 89-012 8-25-89 GSEP Unusual Event Control Valve Fast Acting Solenoid Valves were Inoperable UNIT 2 There were no Licensee Event Reports for Unit 2 for this reporting period.

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

A. Operating Data Report B. Average Daily Unit Power Level C. Unit Shutdowns and Power Reductions 0027H/00612

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APPENOlX C OPERATING DATA REPORT DOCKET NO. 50-254 UNIT One ____

DATE September 7, 1989 COMPLETED BY Lynne Deelsnyder TELEPHONg 309-654-2241 l

OPERATING STATUS 0000 090189 083189 744

t. REPORTING PSR 00:. 2400 GROSE HOURS IN REPORTING PER100:

2511 Max. OEPENO. CAPACITY (BANo.atse. 769

2. 08580N CURRENTLY AUTMORIZED POWER LEVEL ELECTRICAL RATING (tRes.Ned:

/0 (Mul@9 N/A

3. POWER LEVEL TO WMICH RGETRICTED (17 ANYI (Ares. Net):

4. REAM 185 POR RESTRICTION (IP ANYl:

THIS MONTH YA TO DATE CUtfuLATIVE 5550.3 123092.5

5. NutfSSR OF MOURS REACTOR WAS CRITICAL . . . . . . . . . . . . . . 744. 0 0.0 0.0 3421.9_

s. REACTOR RESERVE SMUTOOW88 MOUng 5438.2 119097.4

7. MOUR$ GENERATOR 0N LINE . . . . . . . . . . . . . . . . . . . . .. . . . . 7 3 5. 2 0.0 0.0 909.2

8. UNIT RESSRVE SMUTOOWN HOURS . . . . . . . . . . . . . . . . . . . . . .

11883237 253573316

9. GROSS TMER44AL ENERGY GENERATED (MWM) . . . . . . . . . . . . . 14 515 9 2 434131 3818445 82176058

10. GROSS ELECTRICAL ENERGY GENER ATED (MWMi . . . . . . . . . . .

430917__ 3644578 77209852

11. NET ELECTRICAL ENERGY GENERATED (MWM) ............ .

100.0 95.2 R1.I

12. 'EACTOR SERVICE F ACTOR . . . . . . . . . . . . . . . . . .

100.0 95.2 83.4

13. REACTOR Av AILAtiLITY FACTOR . . . . . . . . . . . . . . . .

98.8 93.3 _ 78.5_

14. UNIT SERVICE F ACTOR . . . . . . . . . . . . . . . .

90*O ,

93.3 79.1

15. UNIT AVAILABILITY F ACTOR . . . . . . . . . . . . .

75.3 _

81.3 66.2

18. UNIT CAPACITY F ACTOR (usens MOCl . . . . . . . . . . . . . .

73.4 79.2 64.5

17. UNIT CAPACITY P ACTOR (Uune Osme MWel . . . . . . . . . . . . . . . .

1.2 6.7 5.4

18. UNIT PORCEO OUTAGE RATE . . . . . .

19. SMUTDOWNS SCMGOUL50 CVER NEXT 6 MONTHS (TYPE. DATE. ANO DURATION OF EACM):

20. IF SMUT DOWN AT END OF REPORT PERIOD. ESTIMATED DATE OF STARTUP.

FORECAST ACHIEVED

21. UNITS IN TEST STATUS (PRIOR TO COMMERCIAL OPERATION):

INITIAL CRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERA 78088 l 1.1M

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APPENOlX C OPERATING DATA AEPORT DOCKET NO. 50-265 UNIT Twn DATE September 7, 1989 COMPLETED 8Y Lynne Deelsnyder TELEPHONE 309-654-2241 , l OPERATING STATUS 0000 080189 2400 083189 744

1. ASPORTite0 PER800: GROSS HOURS IN REPORTINO PEntOO:

2511 max OEPENox,APAC Ty (Mio,Ned: 769

2. CURRENTLY AUTHORIZED POWER LEYEL ( 9 DESIGN ELECTRICAL RATING (hR4e.Ned:

N/A

3. POWER LEVEL TO WHICH REETRICTED (IP ANY1 (MWo.Ned:

4. REASONS POR ResTRICTIONllP ANYl:

THIS MONTH YM TO OATE CUMULATIVE 5551.9 116501.8_

5. NUMOSR OF HOURS REACTOR WAS CRITICAL . . . . . . . . . . . . . . 5 81. 3 0.0 0.0 2985.8_

S. REACTOR RESERVE SHUTOOWN HOURS . . . . . . . . . .

..... 576.5 5505.1 113236.8-

7. HOUR $ GENERATOR ON LINE . . . . . . . . . . . . . . . . . . .

. 0.0 702.9

8. UNIT RES$RVE SHUTOOWN HOURS . . . . . . . . . . . . . . . . . . . . .

12012221 242922494

9. GROSS THERMAL ENERGY GENERATED (MWHI ..............I278545 409332 3886287 77819758

10. GROSS ELECTRICAL ENERGY GENERATED (MWM) . . . . . . . . . . .

3713822 73450399

11. NET ELECTOd%L ENERGY GENERATED (MWHI ...........

. 388297 78 I 95 2 77 '

12. REACTOR SERViCa FACTOR . . . . . . .......... ..

78.1 95.2 79.2-

13. REACTOR AV AILA8iLITY F ACTOR . . . . . . . . . . . . . . . .

77.5 94.4 7s.1

14. UNIT SERYlCE F ACTOR . . . . . . . . . . . . . .

77.5 94.4 7 5 . ",

15. UNIT AV AILABILITY F ACTOR . . . . . . . . ...............

67.9 82.8 63.3

18. UNIT CAPACITY P ACTOR (Using MOCl . . .......... ..... .

80.7 61.7

17. UNIT CAPACITY F ACTOR tusme Desip MWel . . . . . . . . . . . . .. 66.1 15.4 4.6 8.3

18. UNIT FORCED OUTAGE RATE . . . . . . . . . . . .

19. SHUTOOWN5 SCHEDULAD OVER NEXT 4 MONTMS (TYPE. DATE. AND DURATION OF EACHl:

20. IF IMUT DOWN AT END OF REPORT PERIOD. ESTIMATED DATE OF STARTUP:

FORECAST ACHIEVED

21. UNITS IN TEST STATUS (PRIOR TO COMMERCt AL OPERATION):

INITIAL CRITICALITY IN:TIAL ELECTRICITY COMMERCIAL OPERATION 1.1 M

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APPENDIX B .

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. AVERAGE DAILY. UNIT POWER LEVEL ,

DOCKET NO. , 50-254 '

UNIT one DATE september 5,1989 '

COMPLETED BY tvnne Deel studer TELEPHONE 20,2.654-2741, l

MONTH August, 1989 t. -

'h DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe Net) 3 633 , 37 639 2 644 jg 586 3 '643 ig 573 1

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643 g 532 5 610 21 635 g 466 22 .

607 -

y 589 23 587 8 566 592 24 g 638 441 3

10- 631 g 501 ji 635 27 638 12 614 602 3

13 492 3 277 14 601 30 418 15 627 33 645 16 606 INSTRUCTIONS On this forn., list the ive..se daily unit power level in MWe-Net for each day in me reporting month. Compute to the neatest wi> ole megawat'..

These Ggures will be used to plot a graph for cach reporting month. Note that when maximum dependable capacityis used te,r the net electricel rating of the unit, there may be occasions when the caily average power level exceeds the 10&% line (or the restricted power level line). In such cases, the average daily unit power output sheet should be footnoted to explam the apparent anomaly.

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. ' APPENDIX B

.  ; , AVERAGE DAILY UNIT POWER LEVEL 3m  :

9 DOCKET NO. 50-265 _

P UNIT Two M

t :o' DATE September 5,1989

): o; ' COMPLETED BY Lynne Deelsnyder TELEPHONE- 309-654-2241 a, - . ,

MONTH Aunust, 1989 s

. DAY AVER AGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net)

-( p 754 37 725 2 749 3, 698 3-

755 g 497 4 ,,

724 3 595 i J

765 III g 2f t -

6' _

668 22 759 ,

[ c 7 614 749 s

23 8 j612 594 34

g. 733 5 -8 gg- . 697 y --8 11 695 27

-8 12 649 g -8 13 505 y -10 14 669 g -11 15 701- 33

-12 16 681 i

INSTRUCTIONS ,

I On this form, !!st the aversy daily unit power level in MWe-Net for each day in the reporting month. Compute to the neaisst whole megawatt. l These figures wdl be used to plot a graph for each reporting month. Note that when maximum dependable capacity is l used for the net electrical rating of the unit, there may be occasions when the daily averap power level exceeds the l 1001 line (or the restncted power level line). In such cases, the average daily urut power output sheet should be footnoted to explain the apparent anomaly.

1.16 8

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

A. MAIN STEAM RELIEF VALVE OPERATIONS

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

Unit: Two Date: August 25, 1989 Valves Actuated No. 6 Type of Actuation 2-203-3A 1 Manual 2-203-3B 1 Manual 2-203-3C 1 Manual 2-203-3D 1 Manual 2-203-3E 1 Manual Plant Conditions: Reactor Pressure - 935 Description of Events: Semi-Annual, Manual Operation of Electromatic Relief Valves (QOS 201-S1); Tech Spec: Ref. 4.5.D.1.a 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 Specifications 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.

0027H/0061Z

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

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

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Revision 1 QUAD-CITIES REFUELING March 1978 lNFORMATION REQUEST JE 1. Unit: 01 Reload: 9 Cycle: 10

2. Scheduled date for next refueling shutdown: 9-9-89 3 Scheduled date for restart following refueling: 11-18-89

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 information:

JUNE 10, 1989

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.

a. Number of assemblies in core: 724

b. Number of assemblies in spent fuel pool: 1405 8 The present licensed spent fuel pool storage capacity and the size of any increese 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: 2008

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

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

1. Unit: 02 Reload: 9 Cycle: 10

2. Scheduled date for next refueling shutdown: 2-3-90 3 Scheduled date for restart following refueling: 5-5-90

4. Will refueling of resumption of operation thereafter 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:

NOVEMBER 2, 1990

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,

a. Number of assemblies in core: 724

b. Number of assemblies in spent fuel pool: 1843

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 capactty 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 Itcensed capacity: 2008 4 P P R .O V E D APR 2 01978

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t 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 -

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 Injectior. 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 Operatin", Management Recommendations RBCCW - Reactor Building Closed Coolir.g Water System RBM -

Rod Block Monitor RCIC - Reactor Core Isolation Cooling System RHRS - Residual Heat Removal System

.RPS - Reactor Protection Systen.

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 TBCCH - Turbine Building Closed Cooling Water System TIP - Traversing Incore Probe TSC - Technical Support Center 0027H/0061Z

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