ML19344A439

Monthly Operating Repts for Jul 1980

ML19344A439
Person / Time
Site:	Quad Cities
Issue date:	08/01/1980
From:	Hafera T COMMONWEALTH EDISON CO.
To:
Shared Package
ML19344A435	List: ML19344A433 ML19344A439
References
NUDOCS 8008200288
Download: ML19344A439 (23)

Text

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i QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT JULY 1980 i

! COMMONWEA(.TH EDISON COMPANY 4

AND IOWA-ILLINOIS GAS & ELECTRIC COMPANY i

NRC DOCKET NOS. 50-254 and 50-265 l LICENSE NOS. DPR-29 and DPR-30 i

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( 8008200 M E r

TABLE OF CONTENTS

l. I n t roduc t ier.

II. Summary of Operating Experience A. Unit Oree

< B. Unit Two j lit. Plant or Procedure Changes, Tests, Experiments, and Safety Related Maintenance .

A. Amendments to Facility License or Technical Specifications B. Facility e r 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 VI. Unique Reporting Requirements A. Main Steam Relief Valve Operations B. Control Red Drive Scram Timing Data Vll. Refueling Info mation Vill. Glos sa ry I

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1. 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 lowa-lilinois Gas & Electric Company. The Nuclear Steam Supply Systems are General E.lectric Company Boiling Water Reactors. The Architect / Engineer j was Sargent & Lundy, Inc. and the primary construction contractor was l

United Engineers & Constructors. The condenser cooling method is a closed-cycle spray canal, and 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 1 and 2 respectively were October 18, 1971 and April 26, 1972.

Commercial generation of power began on February 18, 1973 for Unit I and March 10, 1973 for Unit 2.

This report was compiled by Becky Brown and Tom Hafera, telephone number l 654-2241, extensions 245 and 176 i

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II.

SUMMARY

OF OPERATING EXPERIENCE A. UNIT ONE July 1-2: Unit One began the reporting period holding a load of 564 MWe, and held an average load of 561 MWe, At 1100 on July 2 load was reduced at a rate of 50 MWe/ hour until a load of 410 MWe was achieved and held at 1400. At this time the drywell was entered to inspect a leak on a feed-water check valve. At 2010 the load was reduced at a rate of 100 MWe/

hour in order to shut down the reactor to repair the feedwater check

. valve.

July 3-4: At 2148 on July 3 the main generator was manually tripped off line. At 1401 on July 4, the reactor was scrammed twice on an NRC order to verify the closing time of the scram discharge volume drains. At 1418 the NRC scram test was repeated.

July 5-6: At 1630 on July 5 reactor criticality was achieved; at 2200 the reactor was scrammed manualli as required by NRC Bulletin 80-17. At 0126 on July 6 reactor criticality was achieved; at 0640 the reactor was scrammed by downscaling the intermediate range monitors as required by NRC Bulletin 80-17 At 0890 the reactor was scrammed as required by NRC Bulletin 80-17, in order to test the scram discharge volume.

July 7: At 1920 reactor criticality was achieved and held for pressure vessel warming.

July 8-9: The reactor remained in HOT STANDBY until 0435 on July 8 when the reactor mode switch was moved to the RUN position. At 0802 the generator was synchronized; load was increased until a load of 400 MWe was achieved at 1155 Load was held at 400 MWe for fuel preconditioning until 1600 then increased at a rate of 50 MWe/ hour. At 1800 the rate of load increase was changed to 8 MWe/ hour, until at 1500 on July 9 a full load of 595 MWe was achieved.

July 10: At 2110 the load was reduced 75 MWe in one hour on order of the Load Dispatcher.

July 11: At 0600 the load was increased at a rate of 50 MWe/ hour until a full load of 540 MWe was achieved at 0740. At 2245 the load was reduced 75 MWe in one hour due to high spray canal temperature.

July 12: At 0630 the load was increased at a rate of 50 MWe/ hour until a full load of 545 MWe was achieved at 0800.

July 13-15: Unit One held an average load of 541 MWe. At 1900 on July 15 the load was reduced at a rate of 100 MWe/ hour for two hours due to high condenser backpressure.

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. l July 16: At 0300 the load was increased at a rate cf 100 MWe/ hour; at 0400 the rate was changed to 50 MWe/ hour, and at 0500 the rate was changed to 10 MWe/ hour. At 0815 full load was achieved and held at 534 MWe.

July 17-31: Unit One held an average load of 516 MWe, and finished the reporting period holding a load of 495 MWe.

B. UNIT TWO July 1: Unit Two began the reporting period holding a load of 425 MWe for fuel preconditioning. At 0400 the load was increased at a rate of 50 MWe/ hour; at 0730 the rate was changed to 5 MWe/ hour.

July 2: At 0245 load was held at 724 MWe due to maximum recirculation flow. At 0810 the load was increased at a rate of 5 MWe/ hour until a full load of 775 MWe was achieved at 1930.

July 3-4: Unit Two held load until 0130 on July 4. The load was decreased at a rate of 100 MWe/ hour. At 0507 load was held at 450 MWe to reverse the main condenser flow and perform the weekly turbine test.

At 0630 the load was increased at a rate of 50 MWe/ hour. At 0805 the load was held at 530 MWe on order of the Load Dispatcher.

July 5-6: At 0830 on July 5 the load was increased at a rate of 50 Mhu/

hour; at 1045 the rate was changed to 25 MWe/ hour, and at 1230 the rate was changed to 5 MWe/ hour. At 0145 on July 6 full load was achieved and held at 791 MWe.

July 7: At 0015 load was reduced 50 MWe in order to change condensate pumps. At 0250 the load was increased at a rate of 12 MWe/ hour; at 0450 the rate was changed to 8 MWe/ hour. At 0730 full load was achieved and held at 784 MWe.

July 8: At 1000 the load was reduced 25 MWe due to high differential pressure acrossed the main condenser. At 1540 the load was reduced 50 MWr Jue to high differential pressure acrossed the main condenser.

July 9: At 0830 the load was reduced 25 MWe due to high differential pressure acrossed the main condenser. At 2115 the load was reduced 25 MWe due to high differential pressure acrossed the main condenser.

July 10: At 1250 the load was reduced 25 MWe due to high circulating water inlet temperature. At 2l05 the load was reduced 25 MWe in one hour to a load of 625 MWe by order of the Lead Dispatcher.

July 11: At 0600 the load was increased 25 MWe in one hour. At 1415 the load was reduced 20 MWe due to high differential pressure acrossed the main condenser. At 2245 the load was reduced 25 MWe in one hour to a load of 605 MWe due to high spray canal temperature.

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July 12: At 0630 the load was increased 25 MWe in one hour. At 1800 load was reduced 100 MWe/ hour to shutdown the unit to perform reactor scram tests as ordered by NRC Bulletin 80-17 At 2330 the turbine was i manually tripped off line. l July 13: At 0022 the reactor was manually scrammed as required by NRC Bulletin 80-17 At 0441 reactor criticality was achieved; at 0541 the reactor was scrammed by downscaling the intermediate range monitors as required by NRC Bulletin 80-17 At 1035 reactor criticality was achieved; at 1100 the reactor mode switch was placed in the HOT STANDBY position and held to perform repairs.

July 14: At 0354 the generator was synchronized. At 0530 the load was held at 0340 MWe in order to perform a transverse in-core probe test.

At 1343 the load was increased 100 MWe in one hour to a level of 450 MWe wherein was held for fuel preconditioning.

July 15: At 0130 the load was increased at a rate of 20 MWe/ hour; at 0200 the rate was changed to 5 MWe/ hour. At 2400 the load was held at 620 MWe.

July 16-17: Unit Two held an average load of 607 MWe until 1415 on July 17 when the load was increased at a rate of 5 MWe/ hour. At 1530 the load was held at 615 MWe.

July 18: At 1200 the load was increased at a rate of 5 MWe/ hour until a load of 650 MWe was achieved and held at 2000.

July 19-21: Unit Two held an average load of 646 MWe, At 0245 on July 20 load was reduced at a rate of 100 MWe/ hour to a level of 400 MWe at 0510. The load was reduced to reverse the main condenser flow, but due to low condenser vacuum the flow reversal could not be per-formed. At 0545 the load was increas>d at a rate of 50 MWe/ hour; at 0745 the rate was changed to 25 MWe/hos ; at 0945 the rate was changed to 8 MWe/ hour, and at 2215 the rate was changed to 5 MWe/ hour. At 0600 on July 21 the load was held at 700 MWe.

July 22-23: Unit Two held an average load of 673 MWe. At 0930 on July 23 the load was increased at a rate of 8 MWe/ hour. At 1300 the load was held at 705 MWe. At 2000 the load was reduced at a rate of 100 MWe/ hour to reverse the main condenser flow. At 2325 the load was held at 350 MWe and the condenser flow reversal was performed.

July 24-25: At 0505 on July 24 the load was increased at a rate of 50 MWe/ hour; at 1015 the rate was changed to 5 MWe/ hour. At 0615 on July 25 the load was held at 700 MWe. At 0815 the load was increased at a rate of 8 MWe/ hour. At 1115 the load was held at 715 MWe due to low main condenser vacuum.

July 26-31: Unit Two held an average load of 704 MWe, and finished the reporting period holding load at 708 MWe.

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Ill. PLANT OF PROCEDURE CHANGES, TESTS, EXPERIMENTS, AND SAFETY RELATED MAINTENANCE A. Amendments to Facility License or Techni~ cal Specifications There were no Amendments to Facility License or Technical Specifications duiing the reporting period.

B. Facility or Procedure Changes Recuiring NRC Acoroval There were no facility or procedure changes requiring NRC approval.

C. Tests and Exoeriments Requiring NRC Approval There were no tests or experiments performed during the reporting period.

D. Corrective Maintenance of Safety Related Equipment The following represents a tabular summary of the safety related maintenance performed on Unit One and Unit Two during the reporting period. The headings indicated in this summary include Work Request Numbers, LER Numbers, Components, Cause of Malfun'ctic7s, Results and Effects on Safe Operation, and Action Taken to Frevent Repetition.

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UMIT ONE MAINTrMANCL SUitttARY CAURE RESULTS S EFFLCT5 U.R. LER OF 0.1 ACT10tl TAtEN 10

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U;;BER  !!U;tBER CCt:PCf;DIT Y.L FUt:CT I G!1 SAFE CPERATICN PREVENT REPE_TITICi; Q06354 80-16/03L MSIV (1-203- The exhaust re- The valve failed to The exhaust restrictor 2C) strictor was too close with the switch was opened; the valve far closed. In the close position was storked three times but would close when and timed, the air supply was removed.

Q06361 CRD 34-39 The accumula'.or The accumulator was The accumulator was re-Accumulator was bad. giving high water placed and the replace-(1-0305-128) alarms. ment was tested.

Q06406 Cont. Spray The breaker was The breaker would The breaker was replaced Valve (1-1001- broken. not go to the ON and the valve was stroked 23A) position. three times.

Q06475 Reactor Water There was a loose The indicator failed The wire was reattached Level Inst. wire on the fuse downscale. and the fuse was replaced.

l (1-263-106A) holder and the fuse was blown.

Q06587 80-17/03L Torus to Reactor The soleno'id The Control Room The coil was replaced and Building Vacuum position indicator t,he valve was stroked '

4 valve coil was Breaker (1-1601- bad. was lost. three times.

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, Q06709 Torus Level The instrument Tiere was a dif ference The instrument was adjusted 1

Indicator was out of .n local and Control and the indications were '

(1-1626) adjustment. Room indications. verified to be the same.

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LAUSE RESULTS S EFFECTS

'.! . P. . LER OF ON ACTI0tt TAKEt! TO

• iU;'3ERe r.'L' tlc E R C0ftP0t!Ef T ltAL FUi;CT I ON SAFE OPERATIG:1 PREVEt4T REPETITI0tt QO3549 RBCCW Return The latch was The breaker would The switch was repaired Valve Breaker broken. not close. and the valve was stroked (M0-2-3706) three times.

Q06332 Refuel Bridge There was a The main hoist motor The loose wire was re-

! loose wire on the would not raise or attached; the blower brake coll. lower the main grapple. motor was replaced and the

, system was tested.

Q06739 80-17/03L Vacuum Breaker The switch was The switch would not .The switch was replaced Pressure Switch defective. adjust properly, and ST 48 was performed.

(PS-2-1622B) 4 4

IV. LICENSEE EVENT REPORTS The following is a tabular summary of all license event reports for Quad-Cities Units One and Two occurring during the reporting period, pursuant to the reportable occurrence reporting requirements as set forth in sections 6.6.B.1. and 6.6.B.2. of the Technical Specifications.

UNIT ONE Licensee Event Report Number Date Title of Occurrence 80-17/03L 7-16-80 Torus Vacuum Breaker 1-1601-20B failed to open UNIT TWO 80-16/03L 7-23-80 Main Steam Line Low Pressure Switch Drift 80-17/03L 7-24-80 Torus to Reactor Building Vacuum Breaker Switch -

failure

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

A. Operating Data Report B. Average Daily Unit Power Level C. Unit Shutdown and Power Reductions I

I OPERATING DATA REPORT DOCKET NO. 50-254 UNIT ONE DATE August 1, 1980 COMPLETED BY T. Hafera TELEPHONE 303-654-2241, ext. 176 OPERATING STATUS 0000 070100

1. Reporting period:2400 073180 Gross hours in reporting period: 744

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

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

4. Reasons for restriction (if any):

This Month Yr.to Date Cumulative

5. Number of hours reactor was critico1 642.3_ 4999.7 59713.0

6. Reactor reserve shutdown hours 0.0 0.0 3421.9

7. Hours generator on line 613.8 4903.0 56943.9

8. Unit reserve shutdown hours. 0.0 0.0 909.2

9. Gross thermal energy generated (MWH) 1025631 10317008 114860989

10. Gross electrical energy generated (MWH) 315687 3333012 36956066

11. Net electrical energy generated (MWH) 279211 3094500 34510036

12. Reactor service factor 86.3 97.8 82.8

13. Reactor avoilobility factor f>6.3 97.8 87.6

14. Unit service factor 92.5 95.9 79.0

15. Unit ovcilobility factor 12.5 05.9, 80.2

16. Unit copocity factor (Using Des.MWe) 43.8 78.7 62.2

17. Unit capacity factor (Using MDC) 47.6 76.7 60.7 l

18. Unit forced outage rote 9.4 2.8 7.7

19. Shutdowns scheduled over next 6 months ( T y s .e , Do t e , on d Duration 39 each):

20. If shutdown at end of report period, estimated dot 2 of startup ___f________

8The MDC not h leur then 769 mie dering periods of high entiant tencerstere m to the thernal perfernance of the spray canel.

OPER ATING DATA REPORT DOCKET NO. 50-265 UNIT TWO DATE August 1, 1980 COMPLETED BY T. Hafera TELEPHONE 309-654-2241, qt_176 OPERATING STATUS 0000 070180

1. Reporting period:2400 073180 Gross hours in reporting period: 744

2. Currently authorized power level (MWt): 2511 Max. Depend copocity (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 734,8 2317,5 55446,4

6. Reactor reserve shutdown hours 0.0 t.0 2985.8

7. Hours generator on line 715.6 2198.0 52989.8

8. Unit reserve shutdown hours. 0.0 0.0 702.9

9. Gross thermal energy generated (MWH) 1527335 4794790 107810899

10. Gross electrical energy generated'(MWH) 467385 1505603 34769653

11. Net electrical energy generated (MWH) 444767 1392588 32135113

12. Reactor service factor 98.8 45,3 77,9

13. Recctor ovallobility factor 98,8 45.3 82,i

14. Unit service factor 96.2 43.0 74.4

15. Unit ovallobility factor 96.2 43,0 75.4

16. Unit capacity factor (Using Des.MWe) 77,7 35.4 58.7

17. Unit copocity factor (Using MDC) 75,8 34.5 57.2

18. Unit forced outage rate 0,0 9.2 9.2

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

20. If shutdown at end of report period,estincted date o f s t ar t u p ____ N A_______

8The MDC Mt be lever then 769 mit dering periods of high ediant temperatore doe to the thermi perfernance of the spray canal.

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APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-254 UNIT ONE DATE August 1 1980 COMPLETED BY T. Hafera TELEPHONE 309-654-2241, ext. 176 MONTH Julv 1980 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net)

1. 487.4 17. 493.3 ,

2. 398.2 18. 464.2

3. -31.1 19, 474.4

4. -32.8 20. 462.1

5. -33.3 21. 459.2

6. -35,2 22, 462.8

7. -33.2 23, 461.9

8. 241.1 24, 459.7

7. 528.5 25, 452.4

10. 471.0 26. 461.6 ti. 463.3 27. 448.9

12. 469.3 28. 449.7

13. 480.7 29. 444.8 l

14, 492.3 30, 439.5

15. 430.9 31. 441.6 16, 460.7 INSTRUCTIONS On this forn, list the average dail; init power level in Mile-Met for each do; in the reporting nonth. Compete to the neartst whole negauett.

These flaires will be esed to plot a graph for each reporting month. Note that when no inen dependable capacitt is used for'the r.et electricsl rating of the enit there not be occasions when the daily overage asser level excetts the 188 line (or the restricted power level line).,In sech cases,the average daily enit power evtput sheet should be feetnoted to explain the apperent onently

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APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-265 UNIT TWO

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DATE August 1, 1980 COMPLETED BY T. Hafera TELEPHONE 309-654-2241, ext. 176 MONTH Julv 1980 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net)

i. 564.2 17, 577.4

2. 724.6 18. 587.6 3, 734.5 19. 607.0

4. 524.7 20, 545.2

5. 598.5 21. 643.8

6. 729.6 22. 637.1

7. 732.7 23, 623.4

8. 724.4 24, 505.2

9. 671.7 25. 667.6

10. 609.8 26. 683.4 11, 603.3 27. 650.4

12. 509.6 28. 668.9

13. -15.9 29. 667.8 14, 324.5 30. 669.4 15, 510.2 31. 674.6 16, 576.8 INSTRUCTIONS On this forn, list the average daily snit powr level in leit-Net for each dat in the reporting nonth.Coppste to the nearest uhelt negemtt.

These figeres will be esed to plot a graph for each 4perting nenth. Nett that when notinen dependable capacitt is osed for the net ele:trical reting of the snit ther: ney be occasions when the daily overage powr level exceeds the illI line (or the restricted powr level line).,In sech cases,the averegt 4o119 snit powr evtput sheet shoold be festnoted to erplain the opptrent an6as17 9

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I APPEllDIX D QTP 300-T.1)

Ul!IT SilUTD0\lNS ArtD PC'IER REDUCTIONS Revisic> 5 00CrET i;0. 50-254 March 197P, Util! IIAME Qu d-Cities Unit One COMPLETED BY T. Hafera DATE

^"U"S' I' REPORT MONTil TELEPHONE 309-654-2241, JULY 1980

'ex t . 176 bc y[ h fj ,h b LICENSEE f'5_W $g

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,_ DURATIO!! $ 3 EVEllT y> S pg S *

!!O . DATE "- c REPORT t:0. 3 CORRECTIVE ACTIONS /COMMEt;TS (110VRS) y 5 .]

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10 800703 F 130.2 A 1 NA NA NA 64 hours7.407407e-4 days <br />0.0178 hours <br />1.058201e-4 weeks <br />2.4352e-5 months <br /> of outage due to leak on feede:ater check valve, 66.2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> of outage used to perform NRC Scram Tests (IE Bulletin 80-17).

11 800715 F 0.0 F NA NA NA NA Load reduction due to high spray canal temperature 1

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APPE!1 DIX D QTP 300-013 Ut;IT SilVTDOU;;S NJD POUER REDUCTIO l4S Revision S 50-265 GCCKET i9. March 1$78 U:;i T t:N 4E . COMPLETED BY T. Hafera DA f E August 1, 1980 REPORT 110f1Til JULY 1980 TFl.EPHONE 309-654-2241, ext. 1/b e

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10 800704 S 0.0 B NA NA NA NA Load reduction to perform weekly turbine test and

. reverse main condenser flow.

i 11 800712 S 28.4 D 2 NA NA NA NRC Scram Testing (IE Bulletin 80-17) 12 800720 5 0.0 B NA NA NA NA Load reduction to reverse main condenser flow. -1 t

l 13 800723 S 0.0 B NA NA NA NA Load reduction to reverse main condenser flow.  !

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VI. UNIQUE REPORTING REQUIREMENTS t

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 during ths reporting period.

8. CONTROL ROD DRIVE SCRAM TIMING There were no control rod drive scram timing operations during the reporting period.

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4.

Vll. REFUELING INFORMATION The following'information about future reloads at quad-Cities Station was t

requested in a January 26, 1978, licensing memorandum (78-24) f rom D. E.

0'Brien to C. Reed, et. al., titled "Dresden, Quad-Cities, and Zion Station - NRC request for refueling information dated January 18, 1978.

4

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QTP 300-532 .

. F.cvi s i on 1 tiarch IT/3 i

QUAD-CITIES REFUELING i!!Fo?.!%T100 REQUEST -

! 1 Reload: 5 __ cycle: 6

1. Unic:

Scheduled date for next refueling shutdown: 8-3G /Shv4* :n (Eoc5) 2.

; 12-7-80(Startun EOC6)'

3 Scheduled date for restart follo.ving refuciing: . .

! thereaf ter require a technical -

4. Will refueling o'r resumption of operation No, Plan ~ 100FR50.59 ' reloads specification change or other license amendment:

for futuro cycles of Quad Citics Unit 1. The revicu uill be conducted l

in June, 1980. .

Scheduled date(s) for sub;nitting proposed . licensing action and sgporting 5 et 90 days.

. in forma tion: June, 1980 for 10CFR50.59 related changes prior to shutdown.

e.g., new or

6. Important licensing consideratic,s associated with refueling,

' dif ferent fuel desig'n or supplier, unreviewed design 'or performance baalysis -

ractbods, significant changes in fuel design, new operating procedercs:

Umt fuel desi';nc: Retrofit 8x8 fUc12.65- w/os r (^- 224) '

4 .

/. The number of fuel assemblics. , , , ,

72'?

a. Num'ser.of assemb!Ies in core: -

i Mumher of assemblics in spent fuel pool: 596 b.

E. . The present licens2d spent fuci pool storage capacity and the size of any increase in licensed storage capacity that has been requasted or is plann2d ,

.in number of fuel assemblies:

1 4

Licensed storage capacity for' spen't fuel: 1h60 .

a. - . s.

Nona -

b. Planned increase in licensed storage:

j 1.

9 The projected date of the last refueling licensed that can be dischargad capacity: _Septchter, to theic 3"q pent 'f uel pool assuming the prer.cnt ~

~

(en:1, of bacch discharge' capao111'cy) WPPROVED <

i A?R 2.01973 i- .* Q. C. O. S. R.

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1 QTP 300-532 .

I

• Revision 1 CUAD-CITIES REFUEL!:;G  !! arch 197,3 It!F0idAT l0f! REO.UEST t

1.

2 Reload: 4 Cycle: 5 -

1. Unit: _

Scheduled date for next refueling shutdown: 11 1.C-7_9_(Shutdoyn EOCT

2. .

Scheduled date for restart folicwing refueling: 1-17 80 (Starbup EOC5) 3 - .

l h. 1/ill refueling o'r resumption of operation thereafter require a technical speci fication change or other 1icense ~ amendment: No, Plan 10CFR50.59 Reloads l

for future cyclou of Quad Citica Unit 2. The revleu will be conducted-by early September, 1979 .

S.

scheduled date(s) for~ submitting proposed licensing action and supporting

,a information: Early August, 1979 for 10CFR50.59 related changes a 90 days prior to chutdown.

t.

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

}; 6.

' dif ferent fuel design or supplier, unreviewed design or performance 6nalysis l' raethods, significcnt changes in fuel design, new operating procedures:

,; Mau Fuel Design: Retrofit 8x8 fuel (180)_ _

a nat. U at bundle top and botto:n

^ b two larger water rods i c new enrichment distribution

, d preprecuurized s

- This fun 1 desiga was 'provioucly used for Quad Citica Unit 1 Cycle 5

'I and Dresden Unit 2 Cycle 7 l,

I 7 The number of fuel assemblies.

l

a.  !!uraber of assemb!ics in core: 724 j?

t i

b.  !! umber of assemblics in spent fuei poo!: 492

0. The present licensed spent fuel pool stora;;c capacity and the sir.e of any i

increase in licensed storage capacity that has been requested or is planned in number of fuct assemblies: .

a. Licensed storage capacity for ' spent fuel: _

11460 Planned increase in Iicensed storage: Npne I~ b.

l 9. The projected date of the last refueling that can be discharged to the spent 'f oci pool assuraing the presdnt licensed capacity: March, 198f i (En:1 or batch dischar;;e capability) .A.P P il O V.E. O .

.c APR 2 01973 Q. C. O. S. R.

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

CRD -

Control Rod Drive System SBLC -

Standby Liquid Control System MSIV -

Main Steam isolation Valve RHRS -

Residual Heat Removal System RCIC -

Reactor Core Isolation Cooling System HPCI -

High Pressure Coolant injection System SRM -

Source Range Monitor I RM -

Intermediate Range Monitor LPRM -

Local Power Power Range Monitor APRM -

Average Power Range Monitor TIP -

Traveling incore Probe RBCCW -

Reactor Building Closed Cocling Water System TBCCW -

Turbine Building Closed Cooling Water System RWM -

Rod Worth Minimizer SBGTS -

Standby Gas Treatment System HEPA -

High-Efficiency Particulate Filter RPS -

Reactor Protection System IPCLRT -

Integrated Primary Containment Leak Rate Test LPCI -

Low Pressure Coolant injection Mode of RHRS RBM -

Rod Block Monitor BWR -

Boiling Water Reactor ISI - In-Service inspection MPC -

Maximum Permissible Concentration PCI -

Primary Containment Isolation SDC -

Shutdown Cooling Mode of RHRS LLRT -

Local Leak Rate Testing MAPLHGR -

Maximum Average Planar Linear Heat Generation Rate RO -

Reportable Occurrence DW -

Drywell RX -

Reactor EHC -

Electro-Hydraulic Control System MCPR -

Minimum Critical Power Ratio PCIOMR -

Preconditioning Interim Operating Management Recommendations LER - Licensee Event Report ANSI -

American National Standards institute NIOSH - National Institute for Occupational Safety and Health ACAD/ CAM - Atmospheric Containment Atmospheric Dilution / Containment Atmospheric Monitoring s

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