ML19350A900
| ML19350A900 | |
| Person / Time | |
|---|---|
| Site: | Quad Cities  |
| Issue date: | 03/02/1981 |
| From: | Tubbs R COMMONWEALTH EDISON CO. |
| To: | |
| Shared Package | |
| ML19350A892 | List: |
| References | |
| NUDOCS 8103170374 | |
| Download: ML19350A900 (21) | |
Text
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QUAD-CITIES NUCLEAR POWER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT FEBRUARY 1981
,. COMMONWEALTH EDISON COMPANY AND 10WA-lLLIN0ls GAS & ELECTRIC COMPANY NRC DOCKET NOS. 50-254 AND 50-265 LICENSE NOS. DPR-29 AND DPR-30 i
3103110 4 ;
TABLE OF CONTENTS 1.
Introduction 11.
Summary of Operating Experience A.
Unit One B.
Unit Two til.
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 Safety Related Equipment IV.
Licensee Event Reports V.
Data Tabulations A.
Operating Data Report B.
Average Daily Unit Power Level C.
Unit Shutdowns and Power Reductions VI.
Unique Reporting Requirements A.
Main Steam Relief Valve Operations B.
Control Rod Drive Scram Timing Data Vll.
Refueling Information Vill. Glossary i
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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 oy Commonwealth Edison Company and towa-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 con-denser cooling method is a closed-cycle spray canal, and the Mississippi River is the condenser cooling water source. The plant is subject to f
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 Robert Tubbs, telephone number 309-654-2241, extensions 245 and 174.
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SUMMARY
OF OPERATING EXPERIENCE A.
UNIT ONE February 1-5: The unit began the reporting period holding a load of 820 MWe. On February 1, load was dropped to perform the turbine weekly tests. On February 2 and 3 a load of 825 MWe was held. On February 3, at 2200, load was dropped to take a high pressure heater out of service.
During the next two days a load of 775 was held while leaks were repaired on the heater. After the heater was restored to service on February 5, load was increased back to 825 Mue.
February 6-26: Over this twenty-one day period, load was held at an average load of 822 MWe.
Load was dropped on February 8,14, and 22 On these to perform weekly turbine tests and reverse condenser flow.
three days there was an average load of 775 MWe.
February 27-28: Load was held at 820 MWe on February 27 until 2000, when load was dropped in preparation for scheduled maintenance outage.
The turbine was tripped off-line at 0120 on February 28. The unit remained shutdown for the remainder of the reporting period.
Major work to be performed includes:
locate and repair steam leaks in the Drywell, repairs to SJAE valves and other miscellaneous valves in various systems.
B.
UNIT TVO February 1-4: Unit Two began the reporting period in a continuation of a maintenance outage. Major items worked were RCIC manual isolation valve, repairs to 2B SJAE, added Furmanite to
'B' Recirc pump suction valve and repair' miscellaneous valves in various other The outage continued und February 2, when the reactor was systems.
brought critical at 0426, and the generator was put on line at 2015 Load was increased until 2225 when a shutdown wcs initiated due to the concurrent inoperability of both HPCI and RCIC.
At 2330, RCIC was restored; and at 0030 on February 3 all operability checks were completed and the load increase was resumed.
Load was increased at various rates until a load of 745 MWe was held cn February !. at 1001.
February 5-9: Load was held until 1900 when it was dropped to 450 MWe to perform a control rod pattern change.
Load was then increased at 5 MWe/ hour, until a load of 805 MWe was reached at 0200 on February 9 February 10-19: On February 10, load was dropped to 600 MWe due to Load remained at that level problems with condensate demineralizers.
for approximately nine hours, then was increased until a load of 800 MWe was reached at 2000 on February 11.
Due to lack of a spere condensate demineralizer on February 12, 16, 17, and 18, a*. approximately
..~. _ _. _ _ _. _
e 2400, load was reduced to 650 MWe to backwash and precoat a demi ne ra l i ze r.
Load was then increased back to 785 MWe at approximately 2000 the next day. On February 15 at 0030, load was dropped in ant!cipation of reversing condenser flow and performing turbine weekly j
tests.
However, load drop was halted by the Load Dispatcher for an hour, then allowed to proceed.
Load was held at 794 MWe, at 2230 that day.
February 20-27: During this eight day period, load was held at an average of 78,4 MWe. The only exception occurred on February 21, when load was dropped to 700 MWe, to perform weekly turbine tests, resulting in an average load of 763 MWe for that day.
February 28,: Load was held at 796 MWe until 2300 when load was dropped at 100 MWe/ hour in preparation to change the control rod pattern.
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Ill. PLANT OR PROCEDURE CHANGES, TESTS, EXPERIMENTS, AND SAFETY RELATED MAINTL 'NCE A.
Amendments to Facility License or Technical Specifications Amendments 62 and 56 to Licenses DPR-29 and DPR-30, respectively.
On February 6, 1981, the NRC issued Amendment 62 to License DPR-29 and Amendment 56 to License DPR-30.
These changes incorporate certain TMI-2 Lessons Learned Category "A" requirements.
These requirements concern:
(1) Valve position indication; (2)
In-tegrity of Systems Outside Containment, and; (3) lodine Monitoring.
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 nc Tests aid Experimer.ts requiring NRC approval for the repo ting period.
D.
Lot-a-t*ve Maintenance of Safety Related Eauipment 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 Mal-functions, Results and Effects on Safe Operation, and Action Taken to Prevent Repetition.
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1 U"!T ONF t'.AINTENANCE SUt'.."RRY
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LER OF 0:!
ACTfCN
~~'l TO nut:?.ER NU 42?R CO.'0C'! INT M/.L" ":CT ! ON SAFE CI: RAT 10N
. ir/E; 7.5 27:. ::"
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ql0399 Accumulator for CRD Accumulator 0-Kept getting high water Replaced accumulator.
CRD 26-19 rings were worn, level alarm.
Pressure g
was satisfactory. Scram function not affected.
l Q09914 50-1-305-120 Faulty valve.
Rod E-7 slow to with-Replaced valve and withdraw Valve draw.
Scram function timed withdraw and for CRD E-7 not a f fected.
Insertion.
i Q10309 81-2/03L Diesel Gen-Loose fuse holder Diesel Generator Tightened fuse holder.
crator in diesel control tripped and would not i
circuit.
re-start.
,f Q05960 IB RPS HG Faulty circuit Circuit breaker would Replaced breaker.
Set Output breaker.
not trip.
RPS bus was Circuit operative.
Breaker t
e t
S
U: lT iWO mal"TF. NANCE
SUMMARY
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LER OF Cr;
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Q10862 2-203-3C Electro-Discharge flange--
Steam leaking into Replaced gasket.
matic Relief defective gasket.
Drywell. Volve was Valve operable.
Q10896 2-1301-50 Seal ring leaking.
Minor water leakage Replaced seal ring.
RCIC Check Valve, was still operable.
Q10891 80-35/03L 2-2001-16 Valve packing was Valve closure t'me Re packed valve and too tight.
exceeded Tech 5pec tested sati.iactorily.
limit.
Inboard valve e
was closed.
Q10458 81-2/03L 2-203-38 Instrument set-Electromatic relief Replaced microswitch point drift.
setpoint was too assembly, recalibrateo, high. Other valve and tested.
s setpoints were with-in limits.
Q10670 2-1399-101 Valve needed seal Minor steam leakage Repacked and replaced RCIC Manual ring and packing.
in MSIV Room.
RCIC seal ring.
Isolation Valve was operable.
Q10868 2-1301-50 Seal ring leaking.
Minor water leakage in Re-tapered plag am.
RCIC was replaced seal ring.
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Q10981 80-35/03L 2-2001-16 Valve slow to Inboard valve in-line Cleaned valve internals close and in-closed.
and repacked. Testse operable.
satisfactorily.
. =.
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 reportli'g 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 License Event Report Number Date Title of Description 81-5/01T 2-20-81 Low Condenser Vacuum Pressure Switch Drift UNIT TWO 81-3/0lT 2-2-81 HPCI Inoperable (MO 2301-5) 81-4/01T 2-20-81 Low Condenser Vacuum Pressure Switch Orift 81-5/03L 2-24-81 RCIC Steam Line High Flow DPIS-2-1360-IB Switch Drift 4
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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
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P00R ORIGINAL OPERATING DATA REPORT DOCKET NO.
50-254 UNIT ONE D ATE March 2, 1981 COMPLETED BY R C Tubbs TELEPHONE 309-654-2241, ext. 17C OPE?ATING STATUS 0000 020181
- 1. Reporting period:2400 022881 Gross hours in reporting period:
672
- 2. Cterently 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.
Ni.inber of hours reactor was critical 649.9 1352.6 6'058.9 6.
Peactor reserve shutdown hourn 0.0 0.0 f.421.9 7.
Hours gencrut r on line 649.3 1339.6
'.223.4 8.
Unit reserve shutdown hours.
0. 0_
0. t:
_ 909.2 9.
Gross thernal energy generoted(MWH) 1579116 1082741
,1y '24029
- 13. Gross electrical energy generated (MWH) 525340 10179an 3f 96R47 1.1.
Net electrical energy generated (MWH) 489318 956185
- 13464 1.2. Peactor service factor 96.7 95.5 80.4
- 13. Reactor availubility factor 96.7 95.5 84.0 1.1.
Unit service factor 76.6_
94.6
___ 76.7 i'i. Un.it availability factor 96.6 94.6 77,9 Unit cepucity inctor (Ue.ing Dcs.MWe) 94.5, 07_.O.
, _, 60.3
- 17. L.a i
- e:gracit" /cctor (Using MDC) 92.1.
85.!
58.8 i:. dr..i t N r c :1 ot.tcyc rate 0.0 0.f 7.6
... n. :- t r b : <' u i.. o >o
. i c s.
6 m.nths ( T y pe,, Dn t e : nnd Durnt..
ch):
'y.
p o.r i od,e n inct ed d a t e o f s t or i t..'
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OPERATING DATA REPORT DOCl(ET NO.
50-265 UNIT TWO DATE March 2, 1981 COMPLETED BY R C Tubbs TELEPHONE 309-654-2241, ext. 174 CPERATINC STATUS 0000 020181
- 1. Reporting period:2400 022881 Gross hours in reporting period:
672
- 2. Currently authorized power level (MWt): 2511 Max. Depend capacity
'.MWe-Net):
76* Design electrical rating (MWe-Net): 789 3.
Power level to which restricted (if cry)(MWe-Net): NA 4.
Reasons for restriction (if cny):
This Month Yr.to Date Cuoulative
'. Number of hoces reactor.Jos criticci 643.6 1362.2 60195.0
- 6. Recctor reserve shutdown aours 0.0 0. 0.
2905.8 Hoers generator on line 627. B_
1346.1
%7527.3_
'?. Unit reserve shutdoun hours.
0.0 0. 0_
_ __,702.0 Gross therncl energy generated (MWH) 1461003 7119050 tiEft9458 J.
Gross electrical energy generated (MUH) 462648 990283 37711834 t_.
Net electrical energy generated (MWH) 441517 931443
_ L5?43395
~2.
Rccctor service factor 95.8 96.2 78.9
- 3. Reactor avnilobility factor 95.8 06.2
__ 82.8
- t.
Unit service factor 93.4 95.1 75.6
- 2. 3. Unit uvuilcb ili t y factor 9 3. 4_
95.1
,_ 76.5
- 1.. Unit copecity factor (Using Des.HWe) 85.4_
85.5.
_ _ _ 60.2 Unit capac i t y f ac t rir (Using MDC) 33.3 83.4
_ __.58.6
- .. Unit forced uutog-rate 0.0 0.0 9.0 a
- h ) :
Sriutdcuas 5 ch..I 91cd no r ntxt
(, non hi (Type,Dute,cnd Dtaation <
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9 c e.p o r t -per iod e s,t ina t ed ditte of u:uctor.
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APPENDIX D AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.
50-P54
'JNIT ONE DATE March 2. 1981 COMPLETED BY R C Tubtg TELEPHONE 109-6 44-22h.l.,
ext. 174 MONTli Febrimrv 1981 DAY AVERAGE DAILY POWER LEVEL DAY AVER AGE ~ $ILY POWE:1 LEVEL (Mue-Net)
-Net) 1.
758.5 17.
765.0 2.
771.5 18, 762.2 -
3.
762.1 19, 762.0._
1.
725.3 20.
757.9 5.
722.8 21.
7 AG. ':
f,.
~~767.B~
22.
70L.y 7.
768.0 23.
7 5 G.1,_ _
B.
731.2 24.
764. T.,
P.
764.2 25, 765.0 10.
772.8 26.
7GH.h ti.
768.6 27.
677..'
L2.
762.1 28.
-28 7 _
U.
776.3 i'.
731.9 t1.
772.7 757.3 i;!OT!UCTIUNG
- M s f r J.it: :h erop hily voit';me level it, dt-Net ice ecch def in the reprting conth.Co.=pte t: tr..
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i hper.P.tla cc c:9
~3 i.,:.
1.iu a nei 9 sht a e,t rS 4. e.ach reesttin auth thte tMt wr.ar, aci nui:C%is'.". @;D O! d!ily 0;fc0* puddr I! Vel ;
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P00R BRIGINM APPENDIX B AVERAGE DAILY UNIT POWER I.EVEL DOCKET NO.
50-265 i
UNIT TUO DATE March 2. 1981 COMPLETED BY R C Tubbs TELEP HONEl09-654-2241.
1 ext. 174
~_ NTH Fe b r im r u 1981
_Nr AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (HWe-Net)
(HWe-Net)
-7.6 17.
705.3 1.
c.
15.A 18, 697.i_ _
I.
460.8 19.
721.4 679.1 20.
741.0 665.5 21, 736.0 ___
' 646.7 22.
740 3_ _,
m 597.9 23.
752. ? _
707.0 24, 753.3 759.0 25.
75n.7 639.6 26, 747.3 7 ? *' 5 27.
745_i
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740.2 28, 752.5 755.7 738.9 694.8 732.3 INSTRUCTInN3 i n,h st the cie;r..t k i) enit ? m : level in.He. Mat ist er.h de-in the re; rti::g e. cath.Ces;ste *. 6.
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't; 2 ATE March 2,,1981 REPORT MONTil FEBRUARY 1981 TELEPP.Ci:E 309-654-2241, y'
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ZZ ZZZZZZ j Maintenance Outage to repair leaking valves
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- 4 in Drywell and miscellaneous valves in various L other systems l
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VI.
UNIQUE REPORTING REQUIREMENTS The following items are included in this report based on prior commitraents to the commission:
i A.
Main Steam Relief Valve Operations There were no Main Steam Relief Valve Operations during the reporting period.
B.
Control Rod Drive Scram Timing Data for Units One and Two There were no Control Rod Drive Scram Timings for the reporting period.
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5 Vll.
REFUELING INFORMATION The following information about future reloads at quad-Cities Station was requested in a January 26, 1978, licensing memorandum (78-24) f rom D. E.
4 0'Brien to C. Reed, et. al., titled "Dresden, quad-Cities, and Zion 4
Statica--NRC Request for Refueling Information", dated January 18, 1978.
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P00R ORIGINAL
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GTP 300-s32 Revisica 1 QUAD-C! TIES REFUEt.i%
tiarch 1973
(-
liiFORi% iC." REQUEST
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Unit:
1 Reload:
6
__ Cycle: _
2.
Scheduled date for next refuelin9 shutdown:
1 ?_ _02. ( Shu t_.o. a..E0 C
(
30C7) 12-5-82 (Star
- 3 Scheduled date for restart followin9 refualln=":
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4.
l!ill refcaling or resciaption of oparatica thereaf ter require t :.ha i cc i spacificatica changa or other license amar 72nt: i:c, Plan 10:FP.f'.59 reie ds i
for futurc cycles of Quad Citics Unit 1.
The review uill be conduct d i.-
August, 1982.
for sus.ii t ting proposad licensing actica and s";.'wc' 7 ---
5 Scb ehale pres-nt licensed spent feal pool r.torag capaci t'.' acd tha s i, c.'
' store.;c c::;;x i t'/ that h.m br::n re lucr;t ad et i..
- d i;:.,:aw i n li c<.
i n n u.:.,.ia r o f u a. 4.c a r::5...ica:
i a.
Li n.2.'
s t r.
.,e. cn,a ci te for spant fuel:
11:.'. :
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- i s : C i.
.~.J in I i :'.Ciisi:d b U. *.'00 ;
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p s.. p r,..,5 et de-of t l, la:
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P00R ORlGlNAL
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Re/ision 1 QUAD-CITIES REFU2ll;lG llarch 1970 il' FORMAT 10il REQUEST
.(
1.
Unit:
2 Reload:
5 Cycle:
6..__..
2.
Schedule.l date for next refueling shutdr.;n:
8-30 -01 h :w! wn EcC5) 12-20 : ( ~,,. tn :0C6) 3 Scheduled date for restart followin.; rcTueling:
- l..
Uill refueling or resemption of operatica thereaf t:r require: a teci:aical sp2cification change or other license er.1end.unt: ::o, Plen 10CFR5').59 R: loads for future cycles of quad Ci ties Uni t 2.
The review uill be cenducted Irf early August, 19G1.
5 Sch..dair.d date(s) for s.J.c.ti t tin; proposad licensing cctica cnd sn:cortint i
i a fori.u ti ca : Early August, 1901 for 10';?R50.59 related chan:; u ~')0 d :ys a
prior to shutdown.
1 e
Important l.icensing considerat. ions associatan, wit,a rerue,.ing, e.g.,
nru e,r a
v.
fuel design or su, plier, unreviu';rd design or perfor::crce en tif-is
- diffarent l
noth _ '. signi ficant chang:s in fuel desi
.1, new opara ting proce:h:res:
liew Fua! Dc:ign:
1.
Darrier Fuel 6
2.
Centrul Call Core 7
The numbar of fuel a.sse..:31ies.
a.
!!umb-r of asse=Slics in core:
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GLOSSARY The following abbreviations which may have been used in the Monthly Report, are defined below:
ACAD/ CAM Atmospheric Containment Atmospheric Dilution / Containment Atmospneric Monitoring ANSI
- American National Standards Institute APRM
- Average Power Range Monitor ATWS
- Anticipated Transient Without Scram BWR
- Boiling Water Reactor Control Rod Drive CRD Electro-Hydraulic Control System EHC EOF
- Emergency Operations Facility GSEP
- Generating Stations Emergency Plan High-Efficiency Particulate Filter HEPA HPCI
- High Pressure Coolant Injection System HRSS
- High Radiation Sampling System IPCLRT Integrated Pricary Containment Leak Rate Test I N4 Intermediate Range Monitor 151 In-Service 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 Minimum Critical Power Ratio MCPR MPC
- Maximum Permissible Concentration MSIV
- Main Steam isolation Valve National Institute for Occupational Safety and Health NIOSH PCI
- Primary Containment isolation PCIOMR
- P recondi tioning 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 Rod Worth Minimizer RWM SBGTS
- Standby Gas Treatment System Standby Liquid Control SBLC SDC
- Shutdown Cooling Mode of RHRS SDV
- Source Range Monitor TBCCW
- Turbine Building Closed Cooling Water System TIP
- : Traveling incore Probe TSC
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