ML20236W379

Monthly Operating Repts for Sept 1987

ML20236W379
Person / Time
Site:	Quad Cities
Issue date:	09/30/1987
From:	Robey R, Schmidt K COMMONWEALTH EDISON CO.
To:	Lieberman J NRC
References
RAR-87-44, NUDOCS 8712070428
Download: ML20236W379 (27)

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

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o' SEPTEMBER, 1987 COMMONWEALTH EDISON COMPANY

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IONA-ILLINOIS GAS & ELECTRIC COMPANY t

NRC DOCKET NOS. 50-254 AND 50-265 LICENSE N05. DPR-29 AND DPR-30

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i 6g i TABLE OF CONTENTS g

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I.

Introduction g

f II.

Summary /afOperating,berience g

f A.

div.t One

,l' B.

Unit Two kil,7orProce@r,',s,1hanges, Tests,Eneriments,andSafety III.

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4, A

AmendmStut to Facility License or Technical Specifications E, Facill1) or Procedure Changes Requiring NRC Approval C. 'iest; and Experiments Requiring NRC Approval D.

Corrective Maintenance of S Vety Related Equipment IV.

Licensee Event Reports

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V.

Data Tabulations

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A.

Operating Data Report i

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B.

A,'erage Daily Unit Power Level

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C. kJhit Shutdowns and Power Reductions

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VI. 1 Jq}queIhporting Requirements y

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MairI Steam Relief Vaiva Operations A.

i Control Rod Drive Stjja Tiraing Data B.

VII.

Refueling 11formatto VIII.

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INTRODUCTION

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Quad-Cities Nuclear _ Power. Station is composed of two Bolling Water l

Reactors, eachtwith.a.Miximum Dependable Capacity'of 769 MWe Net,. located in

+1 Cordova,-Illinois. The Station is jointly owned by Commonwealth Edison Company andilowa-Illinois Gas & Electht Company.

The Nuclear Steam Supply Systems are General Electric Ccmpany Bolling Water Reactors.

The Architect /Engiceer was Sargent. &;.txndy, Incorp ted, and.the primary.

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construction contractor was United Jngineers i Cd.nstructors.

The Mississippi }

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k River is the condenser cooling water source.

The plant is subject to licens'e s

b numbers OPR-29 and DPR-30, issued Octobdr 1,41971,and March 21, 1972, t

respectively; pursuant.to Docket Numbers 50-254 and 50-265.

Thedaieof initial: Reactor criticalities for Units OneJand 1wo, respectively were October 18, 1971, and April-26,:1972.; s Commercla sgeneration of power. began on February 18,' 1973 for. Unit One and. March 10, 1973 for Unit Two)

This report was complied by barna Kosel y and Kurt Schmidt, telephone number 309-654-2241, extensions 2240 ar.d 2147.

0027H/00612 1

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F Q-II.

SUMMARY

OF OPERATING EXPERIENCE n

A.

Unit One September 1-15 Unit One began September holding reduced load. At 0445 on September 1, a

' ' power ascent var begun and full load reached by 0715.

Full load was held until'1535 when power was reduced and the unit placed in EGC at 1545. The unit was operated in EGC until 0715 on September 2 when EGC was tripped due to a reserve' emergency. The unit was slowly increased to full power which it achieved at 1520 and held until 1325 on September 3.

At that time, power-was reduced and at 1340 the unit was placed in EGC. The' unit operated in EGC with only minor interruptions until September 10.

At 0920 EGC was tripped and the unit raised to full load in order to take turbine vibration readings as part.of the turbine rotor replacement project. Upon completion j([

of the vibration readings at 1830, the unit was placed back in EGC at 1852 and operated until 2315.

At that time, a downramping of power was begun ni in preparation for the unit refueling shutdown. At 0200 on September 11

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power reached;500 MWe and was held until-1230 when the power reduction was

~h resumed.

200 Mfe was reached at.1635. At 1950 torus and drywell deinerting began.

Power reduction continued, reaching 115 MWe at 2200,'and 61 MWe at

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2358. At 00053on September 12, the generator was tripped. At 0058 a manual

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reactor scram was performed. At 0807 the reactor head vents were opened.

On September 13 at'0228 the "B" Recirc M.G. set field breaker was found to

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be malfunctioning (See LER C7-018). At 1615, pressurization of the drywell commenced as part of the Integrated Primary Containment Leak Rate Test (IPCLRT). The pressurization was completed at 2127 at a pressure of 51.5 psig. The IPCLRT was performed and at 1300 on September 14, depressurization was commenced and was completed at 1600. The IPCLRT results were not-acceptable (See LER'87-019).

Septe'mber 16-30 At 1750 on September 16 the reactor vessel head was removed. At 1042 on September 19 defueling of the reactor commenced. Defueling was completed on September 23 at 0047.

The refueling shutdown is progressing normally, i

l 0027H/00612 l

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.B.

Unit Two' Septembe r' l-l_5,5 Unit Two began the month still in a shutdown to repair the transformer which failed on August 1.

The reactor startup was commenced on September 5 at 1020..The reactor achieved critica111ty at 1233 on September 5 with a 141 second period and at a temperature of 172*F.

The reactor head vents were closed at 1315. At 2153 the reactor mode switch was placed in RUN. Drywell inerting began at 0125 on September 6.

The turbine was rolled at 0216 and the generator went on line at 0304. At 0340 a power ascent using control rods' vas' begun from 60 We.

At 0500,-the power ascent was held at 168 We.

Scram timing of control rods was begun at 0725 and completed at 1125. The power ascent was resumed at September 7 at 0930. At 1330, power was held at 400 We for half power testing of the new transformer. The power ascent continued at 2125 and reached 700 We at 0237 on September 8.

From 1408 to 1440, power was increased with control rods to 740 We.

At 1523 the main transformer fire suppression system was actuated. There was no actual fire present.

The fire suppression system had to be isolated and a continuous fire watch stationed while the suppression system was isolated. This happened y

several more times in the succeeding days. The system malfunction was corrected on September 17 and no subsequent spurious actuations were experience, y*,

On September 9 at 0539 power was increased, full load reached at 0630 and

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held until 2150. Power was reduced and the unit placed in EGC at 2200.

EGC

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operation continued until September 10 at 0035. Power was reduced.at the request of the Load Dispatcher (LD) to a minimum of 620 We at 0150 and then retunred to full power by 0745. At 1600 the unit was returned to EGC. This pattern of EGC operations and/or minor load reductions to meet the dispatcher's needs continued-until September 14 at 0937. The unit was then raised to full load which it held until 2020 on September 16.

September 16-30 On September 16 full load was held until 2020, the unit was placed in EGC at 2052 and operated until 0310 on September 17 when load was reduced at LD request. The load reduction was halted at 0510 and an ascent begun. At 0547 a reactor scram occurred. During a surveillance of reactor water level instrumentation, the instrument technician failed to pre-pressurize a level cell sensing line prior to unisolating it.

This caused a low reactor water level signal which caused the scram.

(see LER 87-011)

Following deter-f mination of the cause of the scram, a reactor startup was commenced at 1130.

Critica111ty was achieved at 1531 with a 94 second period and at 399'F.

The f

turbine was rolled at 2206 and the generator went on line at 2232. The power ascent continued until 0740 on Sepcember 18.

At that' time, a high Local Power Range (Neutron] Monitor (LPRM) reading was observed, and power was reduced from 800 to 760 We.

From 1520 to 1547, a control rod pattern i

f adjustment was performed with an attendant power increase. On September 19 f

Power was at 0130 a load reduction was performed at the request of the LD.

held at 700 We f rom 0210 until 0525. A power ascent was begun but then stopped at 0730 because of a high LPRM reading. Load was held at 775 We j

until 1310 when the power ascent was resumed. At 1315, turbine control valve oscillations forced a temporary halt to the increase which was resumed at 1430 and reached full power at 2055. On September 20, a load reduction This was initiated at LD request and reached a minimum of 700 We at 0541.

was held until 0610 when a power ascent was begun and continued until 1325.

Power was reduced and the unit placed in EGC at 1340. At 2315 EGC was tripped due to erratic load changes and load held until 0505 on September A power ascent was begun but then stopped at 0555 because of erratic 21.

turbine control valve operation. Load was held at 770 We until 2112 when erratic operation of the control valve reoccurred. Load was reduced to 700 We and held until the unit was placed in EGC at 2338. The unit was operated in EGC until 0815 on September 22.

Full load was reached at 0825 and held until 1610. The unit was returned to ECC at 1632 and operated until 0935 i

on September 23.

Full load was reached and held until 1335. The unit was placed in EGC which operated with only minor interruptions until 0025 on Septembar 25. Load was reduced at LD request to a minimum of 525 We at 0150. This was held until 0515. A power ascent increased load to 800 We at 0837. Power was held at this level until September 26 at 0950 when it was reduced and the unit placed in EGC at 0955. The unit operated in EGC

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until 2330 on September 27 when a load reduction was initiated at LD request.

l A minimum of 610 We was held from 0035 uniel 0250 on September 28.

A power

c ascent was begun and the unit reached full load at 0740. At 1500 the B recire f

MG set malfunctioned, the field breaker tripped and the machine went to 100%

l speed. The unit operator stabilized reactor water level and then tripped the B recire MG set.

Following this, power level was 521 We.

At 1610, the speed of the A recire MG set was reduced and plant power reached 460 We, At 2150 the plant was stabilized for single recire pump operation with appropriate thermal and safety limits in force. On September 29, from 0930 to 0952, power was reduced with control rods in preparation for restoring the B recire pump. The pump was restarted at 1001 and at 1023 specia) control rod maneuvers restored normal control rod patterns. A power aas initiated subsequently and continued until 1930, when a load ascent reduction was performed at LD request.

Power reached a minimum of 500 We at 0200 on September 30 and was held until 0610.

A power ascent raised the unit to full load by 1005 and this was held until 2200.

Power was reduced to 720 We by 2300 and held at this level until 0115 on October 1st.

1

d III.

PLANT CR PROCEDURE CHANGES, TESTS, EXPERIMENTS, AND SAFETY RELATED MAINTENANCE A.

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

B.

Facility or Procedure Changes Requiring NRC Approval There were no Facility or Procedure changes requiring NRC approval for the reporting period.

C.

Tests and Experiments Requiring NRC Approval There were no Tests or Experiments requiring NRC approval for the reporting period.

D.

Corrective Maintenance of Safety Related Equipment

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Vi 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, j

and Action Taken to Prevent Repetition.

0027H/0061Z i

' UNIT 1 MAINTENANCE

SUMMARY

WORK REQUEST No.: Q56603 LER NUMBER:

87-006 COMPONENT:

System 2300 - Replaced coil on SV8 for HPCI Turbine Reset.

CAUSE OF MALFUNCTION: The cause of the High Pressure Coolant Injection (HPCI) turbine reset problem was revealed to be a loose soldered connection on the coil of the SV-8 solenoid valve. This is believed to have been a result of the normal vibrations created during HPCI operation.

RESULTS & EFFECTS ON SAFE OPERATION: When the HPCI System was declared inoperable the required Technical Specification surveillance were begun. Although, the HPCI system could always have'been reset locally at'the turbine front standard and then operated normally if a. turbine trip would have occurred following an initiation.

ACTION TAKEN TO PREVENT REPETITION: The immediate corrective action was to replace the SV-8 solenoid coil by one recommended by General Electric. Also, the solenoids

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for the Unit 1 SV-12 valve and Unit 2's SV-8 and SV-12 valves.will be replaced.

f In addition, a restraint will be placed on the solenoid wiring to reduce the h

1 strain on connections.

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WORK REQUEST NO.: Q57461 LER NUMBER: N/A COMPONENT:

System 300 - Installed new thyristors for 1-305-117 & 118 valves for CRD 26-27.

CAUSE OF MALFUNCTION: The cause of the single control rod scram of Control Rod Drive.26-27 was the result of thyristor 590-742B shorting out when water leaked into the junction box. The water came from a packing leak on valve 1-301-117.

RESULTS & EFFECTS ON SAFE OPERATION: As the control rod scrammed it failed in the. conservative direction.

Therefore safety implications were minimal.

ACTION TAKEN TO PREVENT REPETITION: The immediate corrective action was to reduce reactor power and return the control rod to its original position. Later, the thyristors (590-742A and 590-742B) were replaced like-for-like and proper operation verified. No water had penetrated surrounding junction boxes and the packing leak that had caused the problem will be repaired under Nuclear Work Request Q51001.

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WORK REQUEST NO.: Q57987

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LER NUMBER:- N/A

' COMPONENT:. Syst'em 7500 -. Inspected and replaced demister on 1/2B SBGT,'1/2B-7501.

CAUSE'0F MALFUNCTION: The cause of the fire in the 1/2B Standby Gas Treatment System (SBGTS) demister was attributed to a faulty flow transmitter 1/2-7541-6B which controlled the heater which started the fire.

RESULTS & EFFECTS ON~ SAFE OPERATION: 'The redundant "A" train was demonstrated to be operable as required by Technical Specifications. Therefore, safety implications were minimal.

ACTION TAKEN TO PREVENT REPETITION: Immediate corrective action was to replace damaged parts and recalibrates the flow transmitter. Operability tests were performed satisfactorily.' Also, the SBGTS shutdown procedure will be changed to verify that the heater turns off when the train is shutdown.

WORK REQUEST NO.: Q57989

'li 40 LER NUMBER: N/A B

COMPONENT: System 7500 - Calibrated flow switch and temperature switch on 1/2B SBGT, 1/2-7541-11B.

CAUSE OF MALFUNCTION: The cause of the fire in the 1/2B Standby Gas Treatment System (SBGTS) demister was attributed to a faulty flow transmitter 1/2-7541-6B which' controlled the heater which started the fire.

RESULTS & EFFECTS ON SAFE OPERATION: The redundant "A" train was demonstrated to be operable as. required by Technical Specifications. Therefore, safety implications were minimal.

ACTION TAKEN TO PREVENT REPETITION:

Immediate corrective action was to replace damaged parts and recalibrates the flow transmitter. Operability tests were performed satisfactorily. Also, the SBCTS shutdown procedure will be changed to verify that the heater turns off when the train is shutdown.

t4.

WORK REQUEST NO.:

Q58027 LER NUMBER: N/A COMPONENT:

System 7500 - Investigated and recalibrates flow transmitter for 1/2B (FT-1/2-7541-6B) SBGT.

.CAUSE OF MALFUNCTION:.The cause of the fire in the 1/2B Standby Gas Treatment

' System (SBGTS) demister was-attributed to'a faulty flow transmitter 1/2-7541-6B.

which controlled the heater which started the fire.

RESULTS & EFFECTS ON SAFE OPERATION:.The. redundant "A" train'was demonstrated to be operable as required by Technical Specifications. Therefore, safety implications were minimal.-

. ACTION TAKEN TO PREVENT REPETITION:. Immediate corrective action was.to replace damaged parts and recalibrates the flow transmitter. Operability tests were performed satisfactorily. Also, the SBGTS shutdown procedure will be changed to verify that the heater turns off when the train-is shutdown.

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-UNIT 2 MAINTENANCE

SUMMARY

WORK REQUEST NO.: Q56255

.87-006' LER NUMBER:

. COMPONENT: System 2300 - Fuses found blown for HPCI Controllers and replaced.

CAUSE OF MALFUNCTION: The cause of the Motor Speed Changer and the Motor Gear Unit failure to reduce the High Pressure Coolant Injection (HPCI) turbine speed was due to dirty switch contacts on switch 2330-340.

RESULTS & EFFECTS ON SAFE OPERATION: This event occurred at the conclusion of Therefore, the ability of the system to start and operate the operability test.

had been demonstrated when the. system malfunction was observed the required surveillance were begun. The HPCI system was repaired and tested satisfactorily within eight hours.

ACTION TAKEN TO PREVENT REPETITION: The corrective action was to clean the contacts Following and replace the blown fuses that had occurred due to.the dirty contacts.

this work the.HPCI system operability test, QOS 2300-S2, was completed and the m

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system determined to be operable.

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IV.

LICENSEE EVENT REPORTS

.The following is a tabular' summary of all licensee event reports for

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-Quad-Cities Units.One and Two occurring during the reporting period.' pursuant to the reportable occurrence reporting requirements as set forth in sections 6.6.8.1. and 6.6.8.2. of the Technical Specifications.

UNIT 1 Licensee. Event.

Report Number Date Title of Occurrence 016 9-12-87 Leak Rate from all valves &

s penetrations? T.S. limit

. ( -,87-018.

9-13-87 1B Recirc MG Set Field Breaker failed to trip

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87-01'9 9-14-87 Unit One Integrated Leak Rate Test Failure i

UNIT 2 87-011 9-17-87 Rx Scram - low; level 87-012 9-18-87 Loss of Dw/SC DP - 33E V.B.

I, 0027H/00612

C e

I V.

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

A.

Operating Data Report 8.

Average Daily Unit Power Level C.

Unit Shutdowns and Power Reductions i

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0027H/0061Z

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'4 i OPERATING STAfUS 0000 090187

1. Repor1inq per iod :2400 09.301)7 Gross hours in reportina perlod:

7.'.; U.

2.

Currently authortzed power level (MWt): 2511 Max. Depend capacity (MWe-Net): 769* Design electrical ratiny (MWe-Net): 789 i

3, Power level to which re<i.tr.icted(if any)(MWe-Net): NA 4.

Reasons for restriction ( i. f any);

lhis Month Yr,to Date C u a u.l a t i '>

S, Number o f h o o r n r e ta e t o r was critica1

.. _._. 2f.> 5,.,JL 6 0,ii;7,. p, lt,. 9]Ji) 4.t.

k m.

i 6.

Reactor re erve chutdown hourn 0.0 0.0 34;.1t i

7.

Hours generator on line 264.1 6016.7 1 0'. 3 0 '...

O.

Unit re",erve nhutdown hours.

0.0 0.0 909..

j 9

t';r n o s t h e r m a.I cnergy oenerated(MWil) 603109 1417233g.

'2,;!;.5 015 (

10. 'ir o s s e l e c t r.i c a.1 enerhy g e n e r <:it e d ( MWil) i; 914j.ii3

..16.59651

"'? W;M/'-

.1 S.T t l.. - e t e t '.: n l i:n "g y g e n.a r a t e d ( Mt.Jil)

..d2640 s4 41'@t r.'"'7 7 U 12.. Reuctor serv.ce foctor

.36 S 92.1 J.

13. Neuctor avullnb311ty fortor

. 6. a 7".1 s'

i4 l.in i t rvime i'n c t o r 36.7

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1S. Unit a o q 11 t h t 1.1 t y fuctor

.3 6.,

l. J 16.

U n i. t copnc. ty foctor (ik.inu MDC) 13. O J '/. V 7.

. :n i t cn..i ty. o t. t or

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.i' f6I (I u 11 P i ( t e fl1 -

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shurdowns scheduled over next 6 months ( 1 v p e, b a t e., n n ri Dueation oi di h.

f:n IF uhitdown

r. t

.nl s, f pi r i p a r i a I. e-. t.i rsa t e d date o f'

.tur on UN0FFICDL COMPANY NUMBERS ME V3ED 14 THIS FEPORT

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OP ER.'i T I NG D A T A R E P f.iR T l

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DOLKET NO. -.

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DATE6 0C.TQqEff 198'l C O M P L E T E D 0 Y li. fi., jlCl I.M.10 f _..

I EL.EP HONE 10 9-ft i:2,.2 41 S

ophRarING SfAfUS 40t10 0 'P 018'7 1.

K n a o r t i n a p e r A o d : ? 1.Q,0 093 0 f.37 Gr e s e h o u r s in repor tino p o i. o d :

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Currently authori ed power level (MWt): 2511 Max. Depend tepurity z

i. riWe Ne t ). 769* Desiqn electrical ratiny (r1We Ne t ) - 78Y 3.

I owte level to which certrtctedi.if ony)(t1We-Net)

NA 4.

Reusont for restriction (if any).

'this donth (r.to Dute t : 9 ti u. u t.:

5.

Number of hours reactor un u c r.t t i c a]

...._ _ 6. 0 ). '?

c.: 0. 7 5._D.

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R,.g O

6.

Reactor reserve shutdown hourn

,0.

0 0,0 290';.

'tf v.

i 7.

Hours gen'erator on line

_ lst 0 di

_,, ji.0101,_ ji WZOO.

B.

Unit reserve,hutdown hours.

0.0 0.0 NJ.'

9.

Gross thermal ?nergy generated (MWH) 1U..1255

.11763861 41/.10 M o t

10. Crosc electracol energy aenerated(MWH)

__ 410412

. 3802069 n q161 5 /.

't i, Net ? ). e c t r i c a l energy ge nur u t ed ( hWil)

.,.? V 0 2 RO.,

f629863 c Q .70, ld. Reactor nervace factor 33.6

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13. Reactor availability factor R3.6 77.5

14. Unit m : r v.t c e factor 00.6 76.3 I"

15. Ui: 2t o v a.t.l ob a l i t y factor 30.6

'76.3 16.

Unit cupacity foctor ( U n.t n q MDC)

-O 9

72.0 I?, tinit

.pocity lactor (linino Des.MWo)

_ 6 0. '?

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4 to, lintt forced outuqe rate li?.4 W.1 1Y. Shutdowns scheduled over ne<t 6 months (lype,0 ate,and Duratton on

+h 20.

l' f shutdown at end of.cport p e r i od,i.si a ma t e d date o >f

,tortop IUN0FFICIAL COMPANY NUMBERS ARE V3ED IN THIS REPORT

(d'P E t1D I A P AVERACE DA[LY UNIf POWE.P 1 E'M L DOCKET NO..

. 5. 0 - 2 '.A. _ _

UNII UNE D Ai E6 OG I OlltlfL if ff? _

COMPLETED BYK.A. SCHV'D1 T EL.E P HONE 3J19--654 - 22 4 i h0 NTH September 1'787 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DA.ILY PUWER LC. VEL (MWe Ne.t)

(hWe-Net.)

1.

752.5 17.

--9.8

.2.

756.2 10.

10.'

3.

~/ 6 2. 4 i '/.

-9.9 4,

735.1 20.

-H.B 5.

727.0 21.

-9.3

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749.3 22.

-9. 2 o.

4 7.

726.2 23.

24.

0-

. _ _........ E 'tL_0__._

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691.)

.7. 5.

-9, a,

t0.

735.0 26.

-1 it it.

130.5 2'/

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12.

-12.8 20.

13.

-9. 5 2'7.

-G H 14, 9.8 30.

1 15.

-10.3 l

16.

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INS FRtlCTIDMS On this forn, list the overcge daily unit power level in MWe-Net for each joy in the reporting month. Compete to the nearest whole necowett.

These figures will be used to plot a graph for toch reporting month. Note that when marinen dependeble capacity is used for the net electrical rating of the unit,there noy be accostons when the daily overagt power level exceeds tr.e 100% line (or the restricted power level line).In such cases,the overage cally unit power output sheet should be footnoted to explain the apparent inomaly

i AP E N D I X B 1

otK P r iUE DALLi U r41 r 1 0 U d P.

IEVEL 3

4 l-DOCKET i40.

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DATC6 O C..f,0 B F;I{ _ t 'H :7 COMPIETED BYK.A, SClifil.D i I F L EP HO NE 7e 0 9; 65:1.-22 ':

1 i

rtON T H jepj.cnte.Lr. 1707....,,

DA: AVLHiiGE DAILY I'Ol4ER LEVEL DAY AVERAGL DA:ILY P OWI. R LE'El.

(MWe-Net /

( tiWie -tk t )

1.

- 6.

9,,,_

17.

_,, j $ d, '/

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7.3 13, 701,t 3,

.. - 9. 3..._,,,....,

19, 719,2 4.

10,1 20, 732.0 S.

-31 3 21, 720,7

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t O.

....$.132..tI5 22=

793*U _

k Y<

$ ?.5 ?.....

23'

. 'bY A

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8.

t'04,0 24, Yi:N a

' ?-

I21..t.5.

25.

. _..... _.. Z 0 ;. ?

10,

/32.5 26, 762,b 11, 719.0 27, 722,0 13.

27.6 28.

60t.8 13, f* 3 3, 5 29, 960 U d8 h.

u e

. 723. i.

15,

1. 6.

770.4 INSTRUCT [ONS On -his form, list the enrage daily unit power level in MWe-Net for enth day in the reporting month Compute to the 94arest wrole secewett, frest figures will be used to plat a graph for each reporting month. Note that when notinen dependable c'1pocity is used for the net electrical roting of the unit.thert may be occostons when the cally overogt power level etteeds the 100% line (or the restricted power level line),In such cases,the overage daily unit power output sheet should te footnoted to explain ',he opperent onomaly

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I

J VI. UNIQUE REPORTING REQUIREMENTS The fol. lowing 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 The basis for reporting this data to the Nuclear Regulatory Commission are specified in the surveillance requirements of' Technical Specifica-tions 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.

4

(

.0027H/0061Z

e

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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.

7e

~

i 0027H/00612 I

.4 QTP 300-S32 Revision 1

.a

' March 1978

. QUAD-CITIES REFUELING INFORMATION REQUEST 1

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 reautre a technical specification change or other license amendment: YES. TECHNICAL SPECIFICATION CRANGES WILL' BE REQUIRED FOR NEW FUEL TYPES (MAPHLGR CURVE 1) AND A LICENSE '

' AMENDMENT TO MOVE SINGLE LOOP.0PERATION INTO TECHNICAL SPECIFICATIONS.

CHANGE-TO MCPR LIMIT AND OPERATION AT INCREASED CORE FLOW / FINAL'FELDWATER TEMP. REDUCTION.

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

SUBMITTED TO NUCLEAR LICENSING l

AUGUST 31, 1987 FOR TRANSMITTAL TO NRC 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 GENERAL ELECTRIC, GE8E FUEL WITH 4 WATER-RODS AND LHGR' LIMIT OF.14.4 KW/FT.

-4

\\

7 The number of fuel assemblies.

L) a.

Number of assemblies in core:

0 i

l b.

Number of assemblies in spent fuel pool:

2297

- i'l 8.

The present Ilcensed spent fuel pool storage capacity and the size of any increase in licensed storage capacity that has been requested or is planned in number of fuel assemblies:

a.

Licensed storage capacity for spent fuel:

3657 b.

Planned increase in licensed storage:

0 9.

The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity:

2008 WPPROVED i APR 2 01978 Q.C.O.S.R.

i

4 QTP 300-S32 Revision I l

2 QUAD-CITIES REFUELING March 1978

)

INFORMATION REQUEST l

1.

Unit:

02 Reload:

8 Cycle:

9 I

l 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 Ilcense 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 L.

methods, significant changes in fuel design, new operating procedures:

7!

1-li 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:

1311 s

8.

The present licensed spent fuel pool storage capacity and the size of any increase in licensed storage capacity that has been requested or is planned in number of fuel assemblies:

a.

Licensed storage capacity for spent fuel:

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 licensed capacity:

2008 APPROVED APR 2 01978 Q.C.O.S.R.

_ _ _ - - _ - - - - - ~ -. _ _ _. - - - _. - - - - - - - - - - - -

4L 1

VIII.

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

-ACAD/ CAM Atmospheric Containment Atmospheric Ollution/ Containment

. Atmospheric Monitoring ANSI-American National Standards Institute APRM.

Average Power Range Monitor

'ATHS Anticipated Transient Without Scram BNR' Boiling Water Reactor

- CRD Control Rod Drive Electro-Hydraulic Control System EHC o

Emergency Operations facility EOF Generating Stations Emergency Plan

.GSEP High-Efficiency Particulate Filter HEPA 1

HPCI High Pressure Coolant Injection System HRSS High Radiation Sampling System-IPCLRT Integrated Primary Containment Leak Rate Test IRM Intermediate Range Monitor ISI.

Inservice Inspection Licensee. Event Report LERL LLRT Local Leak Rate Test V

LPCI Low Pressure Coolant In'jection Mode of RHRS Local Power Range Monitor 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 NIOSH National Institute for Occupational Safety and Health Primary Containment Isolation PCI.

PCIOMR

. Preconditioning Interim Operating Management Recommendations RBCCW Reactor Building Closed Cooling Water' System RBM-Rod Block Monitor RCIC Reactor Core Isolation Cooling System RHRS Residual Heat Removal System Reactor Protection System RPS.

RWM Rod Worth Minimizer Standby Gas Treatment System

- SBGTS SBLC Standby Liquid Control Shutdown Cooling Mode of RHRS SDC SDV Scram Discharge Volume SRM Source Range Monitor TBCCW Turbine Building Closed Cooling Water System TIP Traversing Incore Probe TSC Technical Support Center 0027H/0061Z

4 Y L

. Commonwealth Edison ouad Cities Nuclear Power Station 22710 206 Avenue North Corcova, tilinois 61242 Telephone 309/654 2241 RAR-87-41

{f., $N October 2, 1987 f

U.S. Nuclear Regulatory Commission Washington, D. C.

20555 Attn:

J. Lieberman M/S MNBB-4100

\\

Enclosed for your information is the Monthly Performance Report covering the operation of Quad-Cities Nuclear Power Station, Units 1

One and Two, during the month of September, 1987.

Respectfully, COMMONWEALTH EDISON COMPANY QUAD-CITIES NUCLEAR POWER STATION R.h D

A. Robey Services Superintendent vk

.i Enclosure i

i l

)

0027H/0061Z s