ML20238A549
| ML20238A549 | |
| Person / Time | |
|---|---|
| Site: | Peach Bottom  |
| Issue date: | 12/31/1974 |
| From: | Ullrich W PECO ENERGY CO., (FORMERLY PHILADELPHIA ELECTRIC |
| To: | |
| References | |
| EFF-74B, NUDOCS 8708310122 | |
| Download: ML20238A549 (64) | |
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d SEM!vANNUAL OPERATIONS REPORT NO. 3 July 1, 1974 through December 31, 1974 3
Submitted To The United States Nuclear Regulatory Commission Pursuant To Facility Operating License No. DPR-44 & 56 w
Preparation Directed by:
W. T. Ullrich, Superintendent Peach Bottom Atomic Power St a tion w
TABLE OF CONTENTS Page No.
I.
OPERATIONS I
A.
Summary 1
B.
Unit 2 Operations 1
C.
Unit 3 operations 4
D.
Reactor Shutdowns 7
E.
Power Generation 7
II.
EQUIPMENT 12 A.
Equipmen t Performance 12 B.
Changes to the Facility 13 C.
Design Fatigue Usage Evaluation Report 15 III.
MAINTENANCE
SUMMARY
15 A.
Equipment Maintenance 15 B.
Instrumentation and Controls 15 IV.
RADI0 ACTIVE WASTE 50 A.
Liquid Radioactive Release Data 50 B.
Isotopic Analysis of Liquid Radioactive Releases 50 C.
Gascous Radioactive Release Data 50 D.
Solid Radioactive Waste Shipments 50
.i.
TABLE OF CONTENTS Page No.
V.
, PERSONNEL E XPOSURE 55 VI.
ADMINISTRATIVE 55 A.
Technical Specification Compliance 55 B.
Organi zation Changes 55 C.
Training 56 L
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u TABLE S Page No.
I-0-1 UNIT 2 REACTOR SHUTDOWNS 8-9 I-0-2 UNIT 3 REACTOR SHUTDOWNS 10 - 11 III-A-1 UNIT 2 EQUIPMENT MAINTENANCE 16 - 23 (a) thru (h)
III-A-2 UNIT 3 EQUIPMENT MAINTENANCE 24 - 36 (c) thru (m)
III-B-1 UNIT 2 INSTRUM' NTS AND CONTROLS 38 - 42 t
(a) thru (e)
III-B-2 UNIT 3 INSTRUMENTS AND CONTROLS 43 - 49 (a) thru (g)
IV-A LIQUID RADI0 ACTIVE RELEASE DATA 51 IV-B ISOTOPIC ANALYSIS OF LIQUID RADIO-52 ACTIVE RELEASES IV-C GASEOUS RA910 ACTIVE RELEASE DATA 53 IV-D SOLID RADI0 ACTIVE WASTE SHIPMENTS 54 FJGURE S 1
UNIT 2 REACTOR POWER LEVEL 57 2
UNIT 3 REACTOR POWER LEVEL 58
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I.
OPERATIONS I
A.
j ummar y Tne first week in July marked the commercial operation of Unit 2 and the receipt of the fuel loading license for Unit 3 July li was the end of the warranty run on Unit 2.
Throughout July, Unit 2 basically operated at full power wSi te Unit 3 loaded fuel.
Dur ing August, Unit 2 operated near full power most of the time, while Unit 3 progressed from the end of fuel loading to the initial generator energization.
On September 1, Unit 3 generator was initially synchronized to the system and by month's end had completed the major 25 percent power dynamic tests.
Unit 2 operated at full power until September 16, when load became limited to 900 MWe due to the loss of a condensate pump.
All Unit 2 condensate pumps were operational by October 7, and load was no longer limited.
October saw several outages on both Units 2 and 3 By month's end, Unit 3 had reached 850 MWe.
Unit 2 condenser tube leaks caused power reductions in the months of July, August, October, November and December.
Modifications to the steam side of the condenser to reduce vibration of tubes in the ef fected zone corrected this generic problem.
Both units experienced shutdowns in November and by month's end, Unit 3 had achieved nominal full power.
Unit 3 was de-clared commercial on December 23 and all major transient testing had been completed.
On the last day of the year, station output was in excess of 2050 MWe.
B.
Unit 2 Operations July 1-2 The unit operated at full power since June 2c.
3-18 A low condenser vacuum scram occurred late on 7/2 from 750 MWe while attempting to repair a condenser tube leak. The Icaking tube was plugged and the uni t res ynchron i zed ear ly on 7/3 Early on 7/5 the unit was declared commercial and was near full load. The warranty run started on 7/8 and terminated on 7/12. The unit operated at full power until 7/19 19-21 A load drop to 375 MWe was taken on 7/19 so that additional bracing could be installed on the turbine EHC oil piping.
B y 7/20, the unit was returned to full load...
22-31 The plant was shutdown on 7/22 due to a Icaking bolted manway on a main turbine moisture separator drain tank. The bolted manway was re-gasketed and the unit synchronized on 7/23 During the rise to power, work on the feedwater control system caused a fuse to blow, initiating an increase in speed on a reactor feedpump. The resulting reactor high water level tripped the main turbine which caused the reactor to scram.
The unit was resynchronized later on 7/23 Control rod sequences were changed on this startup with the unit achieving near full load on 7/28.
August 2-24 Full load operation continued from 7/28 to 8/2.
On 8/2 a load drop to 700 MWe was taken to plug a leaking condenser tube.
Unusual vibration was noticed in a condensate pump and was traced to a small crack in the pump discharge head assembly.
The pump was removed from service to weld the crack. The return to service on 8/3 indicated that welding the crack had eliminated the vibra-tion. This phenomenon occurred again during the next two days and caused plant load to remain near 850 MWe.
By late on 8/5, all cracks on the conden-sate pump discharge head were repaired, with the
__J unit achieving full load on 8/6 and continuing to 8/ 25 25-31 Reactor power was reduced to 98 percent to allow Unit 3 to reach 2 percent, since the state restric-tion remained at 100 percent power of a single unit until circulating water environmental effects could be fully assessed. On 8/26, the "A" reactor recircu-lation pump M-G set tripped due to execssive wear on the exciter brushes.
Load was dropped to about 850 MWe and remained there until late on 8/27, when brushes had been replaced on both M-G sets.
On 8/28, the unit was at 950 MWe with fuel preconditioning toward full load in progress.
September 1-15 The unit operated at full load from 8/29 to 9/14, when a normal shutdown was initiated for a planned maintenance outage.
16-22 During the startup on 9/16, the mechanical failure of a shaft and impeller housing on a condensate pump caused a large condenser vacuum leak and sub-sequent scr am.
The plant was re-started after the pump was blocked fran service. The unit reached 600 MWe on 9/17 and maximum load of 900 MWe with..
two condensate pumps on 9/20. Load remained at 900 MWe until 9/23
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23-31 An MSIV c!osure and associated seram occurred when the instrument nitorgen supply to the inboard MSIV's was lost.
The pneumatic supply to the MSIV pistons was restored and the plant restarted, reaching 600 MWe early on 9/24. For the next several days, the unit load remained between 800 and 900 MWe, as con-trol rods were being moved to achieve an opt imum power shape. By 8/29, the failed condensate pump had been replaced by a spare and was placed in service.
Subsequently, another condensate pump was removed from service for inspection.
October.
1-31 On 10/1, load was dropped from 900 to 700 MWe to repair leaking condenser tubes and then was returned to 900 MWe, On 10/4, load was dropped to 350 MWe to rebrush M-G sets and plug. leaking condenser tubes.
Load was restored to 900 MWe on 10/5 On 10/7, the condensate pump was returned to service.
The unit operated at full load from 10/9 to 10/12, when load was dropped to 700 MWe to plug leaking condenser tubes. The unit was at full load on 10/15 when a f alse scram occurred, due to work ad-i jacent to an instrument panel. The unit was re-turned to service as soon as possible and was near 800 MWe on 10/16 when a main steam line relief valve stuck open. A manual scram was initiated and the relief valve was repaired. The unit was returned to service on 10/19, and was at full power on 10/23 when a false reactor low water 1cvel scram occurred during instrument testing.
During the ensuing plant stortup, there was another low level scram due to loss of a reactor feedpump.
nchro-ni zed on 10/24 and was held at 850 MWe onThe unit was sy/28 to 10 accommodate the State of Pennsylvania imposed limit of 125 percent of one unit total plant power output until circulating water environmental considerations were re solved.
November 1.
1 30 The unit operated at full power from 11/1 until 11/4, when a main steam line relief valve stuck open, ne-cessitating a manual scram. The "B" cooling tower lift pump also tripped on 10/4 rendering it inoper-able. The generator was back in service on 11/9 and was running at full power when it became neces-sary to reduce load to allow plugging of condenser tube leaks on 11/16. A manual scram was initiated as vacuum was dc casing during the tube plugging
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process. The unit was returned to service later the same day. By 11/19 the unit was near full power
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and operated there until a normal shutdown was initiated on 11/29 because of indications of a steam leak inside the drywell. The leak was repaired and the unit was returned to service on 12/2.
December 2-31 The week of 12/2 was spent manipulating control rods to optimize reactor power shapes.
The unit operated at full load from 12/12 through the end of the month with short load drops to 750 MWe on 12/16,12/18 and 12/21 to repair condenser tube Icaks.
C.
Unit 3 Operations July 5-31 The license to load fuel was received at the site i
on 7/5 and fuel loading commenced immediately.
Loading of the last fuel bundle occurred late on 7/31.
August hh) 1-31 The first week of August was spent in preparation for initial criticality which occurred early on 8/7 The next week was spent in installation of reactor vessel internals and installation of the reactor ve s se l head.
On 8/16 the reactor vessel operational hydro was completed, and the next several days were spent in preparing the unit for initial operation.
On 8/23, the unit was in operational readiness awaiting AEC authorization to heatup and exceed 0
212 F. Authorization was received and late on 8/23,
.he reactor was t aken cri tical. After several intermediate stopping points, the reactor reached full pressure at low power on 8/26. The last several days of the month were spent in initial rolling of the main turbine and initial energization of the main generator field.
September 1-30 The generator was synchronized to the system for the first time at 58 MWe on 9/l. The next several days were spent with the main turbine on and of f many times for those minor items which are normally associated with any power plant during the start-up phase.
The unit was loaded to 180 MWe o, 9/7 and the next several days were spent in pe r f ormi ng c om-puter-oriented startup tests at the nominal 25 percent
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I power plateau. The unit was at 180 MWe when a scram signal was generated due to resetting
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circulation pump M-G set scoop tube lock-up early a re-on 9/13 The unit was back on the bus the same i,
i day. Dynamic testing was performed at the nominal 25 percent power plateau culminating in " Turbine Tr ip", "Los s of Outside Power", and " Shutdown from Outside the Control Room" tests on 9/17 and 9/18.
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The ensuing outage would have been of short duration except that the HPCI turbine shaft was found to be scored in the shaf t seal area. A turbine shaft replacement was required. This prolonged the outage to the end of,the month.
October 1-31 By 10/1, the new HPCI shaft had been installed and the turbine operated uncoupled satisfactorily.
On 10/2, the HPCI turbine operated satisfactorily coupled to the pump.
On 10/3, the reactor was started and the unit was at 130 MWe by 10/5 with some turbine bypass valves open for testing.
Instrument work on the turbine control system spiked the bypass valves closed, initiating a reactor high pressure The reactor was immediately restarted and scram.
the next day was spent in main turbine testing.
l The overspeed trip testing was performed on 10/7 and the unit was ready for 50 percent power plateau testing. After a "C" rod swap and fuel precondition-ing the unit reached 603 MWe on 10/12. Dynamic testing was in progress when a water leak developed in the HPCI system on 10/15 A normal shutdown was initiated, the leak repaired, and the reactor restarted on the same day.
The unit was synchronized on 10/16.
On 10/18, a turbine trip was initiated as the last major dynamic test of the 50 percent power plateau. A short minor maintenance outage followed, with the reactor being restarted on 10/21.
Start-up problems were experienced with the air ejectors, but the unit was in a "C" rod swap by late on 10/ 22.
After the rod swap into the "B" sequence, fuel preconditioning commenced, with the unit reaching 850 MWe, nominal 75 percent power on 10/28. The last days of the month were spent in dynamic testing et 75 percent power.
November 1-30 On 11/1, a turbine trip from 75 percent power was initiated as the last major dynamic test at this 9
power le ve l. AEC licensing examinations on the reactor were performed on 11/2.
On 11/3, the unit v.;>
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was synchronized, and af ter optimi zing power shapes and fuel preconditioning, 882 MWe was reached late
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on 11/13 Load was gradually increased, reaching 7
981 MWe on 11/19, when instrumentation indicated a small leak inside the drywell. The required shutdown was accomplished with an MSIV closure as part of the startup test program.
f The small leak inside the drywell was repaired and i
the reactor was started on 11/20. The reactor was in the midst of a "C" rod exchange on 11/21, when a condenser tube leak forced the plant to shutdown because of water chemistry problems. The defective tube was plugged and the unit returned to service on 11/22. Dynamic testing at nominal 650 MWe con-tinued for the next several days. A reactor low level scram occurred on 11/27 as a result of leak-ing packing on a level control instrument valve creating a false control signal. The leak was corrected and the plant immediately restarted.
f Operational difficulties were experienced with the l
air ejector and recombiner system which were not l
entirely resolved until 11/30. The month ended with the unit at 500 MWe and increasing power.
December l
1-31 Power escalation continued up to near 900 MWe on s
12/6, when instrumentation indicated a leak inside the drywell. The reactor was shutdown.
Investi-gation revealed a valvo packing Icak-off line problem which was quickly resolved.
This opportunity was taken to finish many small
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work items prior to commercial operation. The reactor was restarted on 12/11 and the unit was at 155 MWe when a shutdown was necessitated on 12/12 due to a leaking condenser tube.
The defective tube was plugged and the unit was put on the bus on 12/13 Power was continuously increased for the next several j
days reaching 1035 MWe on 12/20, i
The last major dynamic test on 100 percent power, the turbine trip, was per formed late on 12/20. The unit was restarted and near 500 MWe on 12/22, when work adjacent to. an instrument panel causcd a reactor scram on false reactor high pressure. The reactor immediately restarted and was declared conmercial was on 12/23 The remainder of the year was spent in conp le t in g the less significant portions of the i
100 percent testing program.
V _
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A D.
Reactor Shutdowns 1.
Reactor shutdowns for Unit 2 are listed in Table I-D-1 2.
Reactor shutdowns for Unit 3 are listed in Tabic I-D-2.
E.
Power Gener ation July 1, 1974 to December 31, 1974 Unit 2
_ Unit 3 Gross Thermal Power, MWD 488,571 153,190 Gross E lec tr ical Power, MWD 3,851,396 1,133,400 Net Electrical Power, MWH 3,659,396 1,095,310 Reactor Critical, Hrs.
4,0 97 2,418 Generator Synchroni zed, Hr s.
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II.
EQUIPMENT A.
Equipment Performance 1.
Fuci Core fuel performance for both uni ts has been exceptional during the report period.
S tart-up operations ha ve been conducted in accordance wi th the General Electric Pre-condi tioning Interim Operating Management Recommendations (PCIOMR).
Precondi tioning power increases wi th flow were used to provide uniform pellet expansion changes in an assembly before sharp increases of power in the pellets were experienced with rod wi thdrawals.
Sequence changes of the control rods have been initiated at 1000 to 1500 MWD /T core burn-up interva ls.
These sequence changes q
have assisted in the maintenance of equitable fucI burn-up throughout the core.
The total control rod inventories at full power have followed the predicted reactivity trends of increasing core reactivity with increasing fuel burnup during the initial part of the cycle.
Units 2 and 3 average core burnups were approximately 4245 MWD /T and 985 mwd /T respectively at the end of the report period.
2.
Main Condensers The condenser reliability on both No. 2 and 3 units was seriously impaired by design deficiencies.
Inspection of the steam space around the tube bundles indicated that severe vibration of the upper tubes in the high steam velocity area had caused random failure of twenty tubes on No. 2 unit and six on No. 3 uni t.
Carbon steel stakes were installed at the center line of each support plate span, from the second to eleventh bays, completely around the tube bundic.
Also, several impingement plates on back-up heater and moisture separator dump lines were blown off or deformed and a new stiffened design considering impact loading was installed.
Tube plugging of the upper two rows of stainicss steel tubes on No. 2 uni t and one row on No. 3 unit was per-formed as a preventative measure against further leakage from vibration cracking, and for short term impingement p ro tecti on.
Inspection also revealed steam and water headers wi thout proper drain hoics and some improper support designs which could contribute to water hammer and associated cracking probicms. These condi tions were corrected. - - - _ _ _ - - _ _ _ _
.ks 3.
Hydraulic Snubbers 7
The inspections of hydraulic snubbers installed on safety related systems were completed as required by Section 4.11.D.1 of the Technical Specifications.
Each unit was out of service for greater than 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> twice during the reporting period and the inspections were performed during tha t time.
There was one inoperable snubber on Unit 2 and seven inoperabic snubbers on Unit 3, six of which were on a main steam relief valve discharge line. These defective snubbers were reported as abnornal occurrences pursuant to Section 6.7.2.A of the Technical Specifications.
The safety implications due to their inoperabili ty was mi ni ma l.
~
Minor deficiencies, such as fitting leaks and adjustment of hydraulic fluid reservoir Icvc1, were corrected during the inspections.
4.
Condensate Pumps During the report period, repairs and modifications were made to the main condensate pumps.
The work consisted primarily of adding sti ffening members to the pump dis-
)
charge head and improving the attachment of the suction head bushing to climinate vibration induced cracking of the discharge head assembly.
5.
Main Steam Relief Valves Leakage of the pilot valve seats resulted in spontaneous valve openings during the report period. As a result, all Target Rock Relief Valves on both uni ts were Icak tested and several small pilot leaks were identi fied.
All leaking valves were repaired, successfully leak tes ted and returned to service.
B.
Chanqcs to the Facili ty July 1, 1974 through December 31, 1974 1
Reactor Protection System Terminal biccks in junction boxes were installed in certain Reactor Protection System instrument circuits to facilitate the surveillance testing required by Techni cal Speci fi ca tions, Because there was no change of ci rcui t function, and because the modification pre-cludes the necessity to remove wires from terminals or fes open instruments, this change has no adverse effect
,./
cn plant safety.
13 -
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2.
Fuel' fland1ing Equi pmant h
Strengthening of the fucl handling bridge gropp!c section e
was accomplished by ti.e addition of crossbracing and re-placement of stop pins.
Because this change increases the reliabili ty of the equipment there it'no adverse cficct on plant safety.
3.
fuel Handling Equipment
'iodi fications were made to the fuel Support Piece Grapplc abs trengthen the posi tioning guards, prevent loss of parts, and improve operation.
Because this change en-hances the reliabi fi ty of the equipment there is no adverse ef fect on plarit safety.
l l
4.
Ra c'wa s te E. qui pmen t The Laundr'y Drain Tank Filter was replaced wi th one of a forger capacity to permi t the proper operation of 'the i
f system.
Becace l thin change improves the operation of i
the equipment there is no adverse effect on plat.s safety.
5.
service water system 1
I The service wdter standpipo spillover vents in the reactor i
building at cicvation 234' anch in t.he turbine building at l
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clevation 135' were piped outside to assure that there is no leekag J path from secondary containment.
Because this improves cbc irtagrity of the secondary containment there is no adveice Ji.'cet on plant safety, i
l 6.
RC,It. g em i
The.RCIC turbine trip logic was modified to trip the turbine at 35 psig exhaust pressure for the first 15 seconds following starWp and 20 psig thercaf ter rather j
than 2T p.ig at all tin s.
Because this change enhances the relieility of Rc1C and was reconrnended by the vendor i t 'does not adversely affect plant safety.
~
7.
Reci rcuia tion System "
A minor wi ring change was made: 1o the ci rcuitry which operates the reci rcula pion system valves.
This change removes the stop pushbutton f rom the automatic closure ci r kri t and thus preicnts opera tor intervention wi th the dronatic valve closure initiated by LPCI actuation logie.
Because this change enhances the intent of the design therc< i s no adverse % pact on plant. safety.
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8.
HPCI and RCIC In ver t er s An automatic reset circuit was installed in the inverters, o
a filter network was added to the DC so,' ply to the in-verters, and the high input voltage trip was raised to 150 volts DC.
Because these changes increase the
=
re-liability of HPCI and RCIC by eliminating inverter trippings there is no adverse impact on plant safety.
9 D r >we l l and Tor u s Ven t i l a t i on Va l ve s A minor change was made to reverse the inlet and outlet connections to a two way air valve in the pneumatic con-trols in several ventilation valves. This change stop-ped the valvo cycling which had been caused by air leakage internal to the two-way valve. Because the change enhances the reliability of the valves it has no adverse impact on plant safety.
P C.
Design Fatigue Usage Evaluation Report __
There were no operational transients on either unit during the reporting period which were comparable to or more severe than the transients evaluated in the stress report code fatigue usage calculations.
i III.
MAINTENANCE
SUMMARY
l A.
Equipment Maintenance 1.
Equipment maintenance for Unit 2 i s shown in Table III-A-1 (a) through Table III-A-1 (h).
2.
E quipmen t ma in tenance for Unit 3 is shown in Table III-A-2 (a) through Table III-A-2 (m).
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B.
Instrument s and Controls 1.
Instruments and controls for. Uni t 2 are shown in Table 111-0-1 (a)~ through Table III-B-1 (c).
2.
Instruments and controls for Un t 2 are 'hown in s
Table III-D-2 (a) through Table III-B-2 (g).
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RADIOACTIVE WAS_TE IV A.
_ Liquid Radioact ive Release Dat a See Tab le IV-A.
B.
I_sotopic Anal yni s of L. iquid Radioac t i ve Re leases See Table IV-B.
C.
Gascous Radioac t ive Release Data l
l See Table IV-C.
D.
Solid Radioactive Waste Shipments 5
See Table IV-D.
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V.
PERSONNEL EXPOSURE i
The data t abulated below summar izes the recorded whole-body ex-a posures for the site (Unit 1 ilTGR, DPR-12; Uni t 2 BWR, DPR-44 and Uni t 3 UWR, DPR-56) dur ing the report period.
j Annual Dose Ranges Number of Indi viduals I
(rem) in Each Range No Measurabic Exposurc 2132 Measurable Exposure Less Than 0.10 294 0.10 -- 0.25 58 1
0.25 -- 0.50 17 0 50 -- 0 75 2
Total Number of Individuals Reported 2503 There were no actual personnel exposures in any dose range beyond those reported. The above data are furnished for the total number of individuals for whom personnel monitoring was provided during the report period, t
VI.
ADMIN:STRATIVE A.
Technical Speci fication Compliance Plant operations and surveillance testing were carried out during the reporting period in accordance with applicable Technical Speci ficat ion requirements.
System deficiencies noted during the surveillance testing were corrected as soon as practicable. Deviat ions f rom the required limiting con-ditions for operation and criteria established by the sur-veillance requirements were reported to the AEC as Abnormal Occurrences in accordance with the Technical Specifications.
B.
Orgeni 7at ion Changes Previous Pre sent Name A s si gnmen t A s s i gnmen t l1. Metz Shift Superintendent Shift Superintendent (Training)
(S. L. O. )
Mr. Met z passed the S.L.O. examination during the repor ting period and assumed the full dutics of a Senior Licensed Shift Superintendent. _ _ _ _ _ _ _ _ _ _ -
m ;
C.
Training o
One of the Shift Superintendents received the AEC Senior Operator License in November 1974. There are presently 6 candidates in training for the Senior Operator AEC license.
. An Operator Requalification Program was implemented at 'the.
. site in December 1973 The first annual written and oral examinations were initiated in November 1974.
On shift training is in progress and. includes the review of emergency and no/ mal operating procedures, plant transients, technical specifications, and the use of respiratory equipment. Addi-tional training is scheduled to include requalification, and the arcos of personnel. safety, fire'. fighting, and electrical
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