ML20203H958
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TENNESSEE VALLEY AUTHORITY Division of Power Production SEMIANNUAL REPORT August 17, 1973 - February 17, 197h Decket Number 50-259 License Number DPR-33 i
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Submitted by I
Plant uperintendent Browns Ferry Nuclear Plant Decatur, Alabama 9604300061 860317 PDR FOIA MORROW 85-782 PDR
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TABLE OF CONTENTS Page Operations Summary Plant Operations & Performance Characteristica
.1 Change in Facility Design
.8 Changes in Flant Instructions 9
Surveillance Testing.
9 Containment Leak Rate Tests 9
Changes, Tests, and Experiments Requiring Authorization from AEC Pursuant to 10 CFR 50.59(a) 10 Changes in the Plant Operating Organization 10 Power Generation and Shutdowns.
10 Maintenance 11 Changes, Tests, and Experiments Not Requiring Authorization fran AEC Pursuant to 10 CFR 50.59(a) 12 Effluent Releases
. 12 Solid Radioactive Waste 12 Record of NSSS Components, Transient and Operational Cycles, and Calculation of Ustge Factor..
. 12 Non-radiological Environmental In-Plant Monitoring Program.
. 11 Environmental Monitoring Program.
( A r vi i ~ AT
Operations Summary Plant Operations and Performance Characteristics A summary of plant operations is described belov and a list of the significant events in chronological order begins on page
- Events related to plant operations such as startup testins md abnormal occur-rences are not discussed unless the events directly affected plant operation.
The abnormal occurrences are included in the list of significant events.
The operations summary does not repeat details of maintenance where the maintenance summary provides adequate information.
August Initial criticality occurred on August 17 at 9: 20 a.m., notch 20 of the 53rd rod. After open vessel testing was completed, the reactor was shutdown on August 18 to install the reactor vessel steam separator, i
dryer and head, and the dryvell head. On August 29, following modification and steam testing at Moss Landing in July and August to meet delay times of 0.4 second and a response time of 0.1 s taond, the eleven relief valves were returned to the plant (details are described in abnormal occurrence l
BFAO T31h).
Installation was completed on August 31.
During the outage, Bergen-Paterson shock arrestors and Grinnell shock absorbers were repaired. Refer to response to RO 73-3 dated August 8,1973, for events prior to August 17 On August 31 two tubes in RHR heat exchanger 1C vere plugged.
Septemb er On September h and again on September 13, recirculation pump A speed drifted up to about 35%. On both occasions, the reactor was shut down and the pump was tripped by the unit operator.
Investigation indicated that the first cause was a wroken connecting rod between the Bailey controller (slave unit) and scoop tube on the M-G set. The second cause was due to a faulty speed relay on the master Bailey controller. No major speed problems have occurred on the pump since these repairs were made. There have been minor oscillatory problems which are attributed to the slave controller.
Current tests at the end of the reporting period were being conducted to determine if the slave controller can be eliminated.
The reactor was made critical on September 5 in preparation for nuclear heatup. Also, on the same date, the installed drywell head gasket was determined to be of silicone material rather than a Nordel material.
A decision had been made previously to use drywell head gaskets of a Nordel material to accommodate the high radiation exposure that would accompany a hypothetical TID-lh8hh release of fission products. The silicone "O" rings were to be used whenever preoperational activities required the drywell head to be in place. Since the silicone "O" rings had been inadvertently installed, an evaluation of these "0" rings by the Division of Engineering Design indicated that low power testing could continue without adversely l
Plant Operations and Performance Characteristics (Continued)
October On October 1, rated pressure and temperature vere reached in preparation for startup testing at the 1000 psig plateau. Testing was terminated due to a scram on October 2.
After instrumentation work and replacement of reactor water cleanup valve FCV 69-12, the reactor was made critical again on October 3 and reactor pressure increased to 1000 psig for resumption of startup testing. After another scram on October 5, the reactor was made critical again and reactor pressure increased to 920 psig on October 6 for the first turbine-generator roll.
The reactor scrammed on October 6, then was made critical again the same day. After several balancing shots, the turbine-generator was rolled again, reaching 1800 rpm on October 8.
The turbine was tripped later on October 8 for maintenance on the generator hydrogen seal. On October 9 and 10, during a unit shutdown, all hydraulic shock arrestors were inspected.
After three scrams and two criticals, the reactor was made critical on October 13 and all tests required at 1000 psig were completed.
The turbine was tripped manually at 1800 rpm on October 13 due to high vibration and on October lh the reactor scrammed. The reactor was made critical again in preparation to roll the turbine and on October lh reactor pressure was 920 psig with the turbine rolling at 1800 rpm. On October 15 at 5: 10 a.m., the generator was initially synchronized with the system.
The unit was taken off the line on this date and the turbine was tripped due to leaking steam seal valve FCV 1-lk6. The Hot Functional Test Program was also completed on this date. On October 16, maintenance on the steam seal valve was completed and on October 17, the generator was synchronized with the system. On October 17, the dryvell was entered and the three Orinnell arrestors were reinspected. The oil irrels were satisfactory and no evidence of leakage was found. On October Ad, 2 actor power was at 15%
thermal and 100 MWe with one (1) bypass valve e+ uck open. The unit was shut down on October 18 to repair the stuck bypnas sclve (replaced servo valve) and to exercise control rods. On October 19, the reactor was made critical again. On October 20, the unit was taken off the line due to a recirculation breaker problem. After two scrams and two criticals, the reactor was made critical on October 26. On October 27 the reactor reached 30% thermal power at 250 MWe with all bypass valves closed. A slow rate of power increase (1/3% per hour) commenced on this date for fuel precondi-tioning and continued for the remainder of the month.
Maximum thermal limits occurring include MCHFR, L.21 and LHOR, 7 9 kv/ft.
Minor problems occurred with the nuclear instrumentation during the month; the most significant was the replacement of the failed IRM detector on October 10.
Several problems occurred with the TIP system during this period.
TIP channels C & D became very erratic; the detectors were replaced.
Channels A and E had erratic X-axis signals (detector position) which were corrected by repairing the channel selector (stepping) switches.
1 Minor problems occurred with the level control in the lov pressure heaters. Air leaks in the instrument piping and evaporation of the instrument ref erence line due to system vacuum were the major contri-butors. The leaks were repaired and a fill line installed to keep the reference line filled.
Operations Summary Plant Operations and Performance Characteristics A summary of plant operations is described below and a list of the significant events in chronological order begins on page 14 Events related to plant operations such as startup testing and abnormal occur-rences are not discussed unless the events directly affected plant operation.
The abnormal occurrences are included in the list of significant events.
The operations summary does not repeat details of maintenance where the maintenance summary provides adequate information.
August Initial criticality occurred on August 17 at 9:20 a.m., notch 20 of the 53rd rod. After open vessel testing was completed, the reactor was l
shutdown on August 18 to install the reactor vessel steam separator, dryer and head, and the dryvell head. On August 29, following modification and steam testing at Moss Landing in July and August to meet delay times of 0.k second and a response time of 0.1 second, the eleven relief valves were returned to the plant (details are described in abnormal occurrence BFAO 7314).
Installation was completed on August 31.
During the outage, Bergen-Paterson shock arrestors and Grinnell shock absorbers were repaired. Refer to response to RO 73-3 dated l
August 8, 1973, for events prior to August 17 On August 31 two tubes in RiiR heat exchanger 1C vere plugged.
Septemb er l
2 On September k and again on September 13, recirculation pump A speed drifted up to about 35%. On both occasions, the reactor was shut down and the pump was tripped by the unit operator. Investigation indicated that the first cause was a broken connecting rod between the Bailey controller (slave unit) and secop tube on the M-G set. The second cause was due to a faulty speed relay on the master Bailey controller.
No major speed problems have occurred on the pump since these repairs were made. There have been j
minor oscillatory problems which are attributed to the slave controller.
Current tests at the end of the reporting period were being conducted to determine if the slave controller can be eliminated.
l The reactor was made critical on September 5 in preparation for j
nuclear heatup. Also, on the same date, the installed drywell head gasket i
was determined to be of silicone material rather than a Nordel material.
1 A decision had been made previously to use dryvell head gaskets of a Nordel material to accommodate the high radiation exposure that would accompany a hypothetical TID-1484k release of fission products. The silicone "0" rings were to be used whenever preoperational activities required the drywell head to be in place. Since the silicone "O" rings had been inadvertently installed, an evaluation of these "O" rings by the Division of Engineering Design indicated that low power testing could continue without adversely
Plant Operations and Performance Characteristics (Continued)
September (Continued) affecting safety. Testing was limited to 10% themal power. On September 11, testing was termine.ted at reactor pressure of 150 psig because the temperature below the dryw/down to correct the proble-i.
ell bulkhead could not be maintained I
below 150 F. and the reactor was shut Additional ventilation ducts were installed to direct air below the bulk-head area.
Details of the modifications are 4.ncluded in a letter dated October 15, 1973, to F. E. Kruesi, Director DRO. The silicone "O" rings for the dryvell head were also replaced with the Nordel material "0" rings during the outage. An inspection of unit 1 shock arrestors and absorbers was performed after completing a five-day period of unit 1 nuclear heatup during the drywell ventilation modification outage.
After the rebuild' program, both Bergen-Paterson and Grinne11 shock arrestors and absorbers were inspected. All were found in goed condition, except two slightly leaking Grinnell absorbers. Details of the inspection and repair program are contained in response to RO 73-h dated October 2,1973.
On September 17 a leak was found in the tube side of the RHR heat exchanger lA.
The leak was attributed to a tube that had severed in the first tube plate from the bottom.
Since the severed tube was iden-tical to one of the two tubes that were leaking in the RHR heat exchanger IC, the decision was made to plug the identical tubes in the RHR heat exchanger lA.
This work was completed on September 19.
After completion of the dryvell ventilation modifications, the reactor was made critical on September 25 and pressure raised for startup testing. On September 28 the recirculation pump minimum speed was increased from 20% to 27-1/2% to provide better data for determinine jet pump operability.
Startup testing had continued to the 800 psig plateau by the etid of the month. The reactor pressure regulator was placed in service at 150 psig and reactor pressure was maintained from 150 poig to 800 psig by the pressure regulator and turbine bypass valves. At about 250 psig the steam jet air ejectors (SJAE) and the reactor feed pumps were placed in service using reactor steam.
Condenser vacuum was maintained by the SJAE.
There were minor problems with the startup nuclear instrumentation up to this phase of startup testing. The basic problem was noise which was minimized by such means as are suppressors on detector withdraw and insert controls, terminal cabinet grounding, increasing detector polarizing voltage, and prohibiting velding in the reactor building during the time the startup range iL trumentation was in use.
Several increases in the conductivity and the suspended solids concentration were observed in the reactor water. The conductivity exceeded 2.0 umho/cm # 25 C. for a total of 81 hours9.375e-4 days <br />0.0225 hours <br />1.339286e-4 weeks <br />3.08205e-5 months <br />. The probable causes for the conductivity excursions were the decomposition of residue Powdex resin in the vessel and the carryover of ammonia to the condensate system via auxiliary boiler "A" during suppression chamber level control. The increases in the suspended solids concentration resulted from corrosion products (primarily iron) being shaken and flushed from system piping.
Plant Operations and Performance Characteristics (Continued)
October l
l On October 1, rated pressure and temperature were reached in preparation for startup testing at the 1000 psig plateau. Testing was terminated due to a scram on October 2.
After instrumentation work and replacement of reactor water cleanup valve FCV 69-12, the reactor was made critical again on October 3 and reactor pressure increased to 1000 psig for resumption of startup testing. After another scram on October 5, the reactor was made critical again and reactor pressure increased to 920 psig on October 6 for the first turbine-generator roll.
The reactor scrammed on October 6, then was made critical again the same day. After several balancing shots, the turbine-generator was rolled again, reaching 1800 rpm on October 8.
The turbine was trippei later on October 8 for maintenance on the generator hydrogen seal. On October 9 and 10, during a unit shutdown, all hydraulic shock arrestors were inspected.
After three scrams and two criticals, the reactor vna made critical on October 13 and all tests required at 1000 psig were completed.
The turbine was tripped manually at 1800 rpm on October 13 due to high vibration and on October 14 the reactor scrammed. The reactor was made critical again in preparation to roll the turbine and on October lh reactor pressure was 920 psig with the turbine rolling at 1800 rpm. On October 15 at 5: 10 a.m., the generator was initially synchronized with the system.
The unit was taken off the line on this date and the turbine was tripped due to leaking steam seal valve FCV l-lk6. The Hot Functional Test Program was also completed on this date. On October 16, maintenance on the steam seal valve was completed and on October 17, the generator was synchronized with the system. On October 17, the dryvell was entered and the three Grinnell arrestors were reinspected. The oil levels were satisfactory and no evidence of leakage was found. On Cetober 18, reactor power was at 15%
i thermal and 100 MWe with one (1) bypass valve stuck open. The unit was shut down on October 18 to repair the stuck bypass valve (replaced servo valve) and to exercise control rods. On October 19, the reactor was made critical again. On October 20, the unit was taken off the line due to a recirculation breaker problem. After two scrams and two critier.ls, the reactor was nade critical on October 26. On October 27 the reactor reached 30% thermal povar at 250 MWe with all bypass valves closed. A slow rate of power increase (1/3% per hour) commenced on this date for fuel precondi-tioning and continued for the remainder of the month.
Maximum thermal limits occurring include MCHFR, k.21 and LHGR, 7 9 kv/ft.
Minor problems occurred with the nuclear instrumentation during the month; the most significant was the replacement of the failed IM4 detector on October 10.
Several problems occurred with the TIP system during tnis period.
TIP channels C & D became very erratic; the detectors were replaced.
Channels A and E had erratic X-axis signals (detector position) which vere corrected by repairing the channel selector (stepping) switches.
i Minor problems occurred with the level control in the low pressure heaters. Air leaks in the instrument piping and evaporation of the instrument reference line due to system vacuum were the major contri-butors. The leaks were repaired and a fill line installed to keep the reference lir.e filled.
h-Plant Operations and Performance Characteristics (Continued)
October (Continued)
Minor delays due to hot control rod drives and difficulty in moving the control rods from '00' position occurred during the month.
As a result of these problems, a control rod (5h-27) was valved out in the withdrawn position and another control rod (26-55) was determined to be stuck in the withdrawn position on October 4 This event was reported as an abnormal occurrence in BFAO-7320. The hot control rod drives were generally caused by leaking scram outlet valves which were corrected after replacement or adjustment of the valve seat.
In addition, che temperature alarm setpoint was specified lower than recommended by General Electric.
(Request for changing the elarm setpoint from 250* F. to 350 F.
was being processed in February. ) Difficulty in movina control rods from
'00' position was determined as not unusual during initial startup based en information from General Electric. The cause was generally air in the system or dirt lodged in the seals. On October 18 and October 19, during a reactor shutdown, the control rods not withdrawn (55) were exercised; only two required an increased drive pressure of approximately 30 psi.
After initial movement was obtained, these rods moved normally.
Later during the month, several control rods required an elevated drive pressure to move off '00' position but functioned normally after movement was attained. The quality of the water in the primary coolant system improved during the month, primarily due to plugging of two leaking condenser tubes on October 25 in lA condenser. The reactor water conductivity exceeded 2.0 umho/cm @ 25 C. for a total of 63 hours7.291667e-4 days <br />0.0175 hours <br />1.041667e-4 weeks <br />2.39715e-5 months <br /> and caused a minor delay in startup testing.
November At the beginning of the month and for the first seven days, reactor power ves approximately 35% thermal. Peactor power was decreased to 25% thermal November 8 for startup tests No. 24, Bypass Valves,and No. 27, Control Valve Fast Closure. The generator was tripped on November 8 as required by startup test No. 27, resulting in separating the unit from the system for three minutes. On November 9, the reactor scrammed during prepara-tions to conduct Startup Test No. 31, Loss of T-G and Off-Site Power. The unit was back on the line November 10. On November 10, after a scram, the reactor was placed in cold shutdown for inspection of relief valve tail pipes and thermocouples and replacement of recirculation pump A mechanical seal.
During the outage, an inspection of the drywell shock arrestors was made.
On November 12, maintenance and inspections were completed and l
the reactor waa made critical on November 13.
1B recirculation pump tripped, causing the reactor to go sub-critical. The reactor was made critical again and remained below rated pressure for maintenance on 1B recirculation pump. The unit was placed on the line on November 15 with power increasing to 25% for Startup Test 31, Loss of T-G and Off-Site Power, and later that day the turbine was tripped in accordance with startup test
- 31. The reactor was made critical again and the unit was placed on the line.
On November 18, after completion of startup testing for test condition no.1, permission was received to increase thermal power to 60%. On November 2h,
Plant Operations and Performance Characteristics (Continued)
November (Continued) feedvater heaters were placed in service. On November 27, power was decreased to three bypass valves during vibration tests on the suppression chamber. On November 29, after another screm, the unit was placed on line and limited in power to bypass valve capacity (25% thermal) for the remainder of the month.
The group "C" rods (32 peripheral high vorth control rods) were withdrawn for the first time during the month.
Each normal startup and shutdown requires an exchange of these control rods at 30% power such that the rods are always full-in whenever reactor power is 130%. The maximum total peaking factor (TPF) observed when these rods are full-in has ranged from k.5 to 6.5, depending on the Xenon inventory and amount of recirculation flow. This TPF will drop sharply to values of 2.5 to 3.0 after partial withdrawal of group "C" rods (i.e.,16 of 32 to full-out) at > 30% power.
A slow rate of power increase (1/3% per hour) occurred three times during the month for fuel preconditioning. Maximum themal limits occurring include MCHFR h.k8, and LHGR 9 7 kv/ft. Maximum power output was Sk.lf, occurring on November 27.
Condenser tube leaks were discovered on two occasions and plugged before water quality limits were exceeded.
There were minor problems with the control rod drives, primarily due to stuck and hot drives. Corrective action involved venting, exercising (raising drive pressure), and scramming the drives.
December At the beginning of the month and for the next ten days, reactor power was approximately 26.5% thermal. Thermal power was limited to bypass valve capacity because of the suppression chamber ring-header nozzle stress problem. On December 11 the generator was tripped for the scheduled pre-varranty run outage, then the reactor scrammed on low vacuum.
From December 11, 1973,at L:26 p.m., through December IL, 1973, at 12:20 a.m.,
the reactor was made critical several times during operators' examinations by AEC. The reactor was made unavailable on December lh at 6:35 a.m. and was placed in cold shutdown for the scheduled pre-varranty run outage. On December 23 maintenance work was completed and the reactor was made critical.
On December 2k the generator was placed on the line with power being increased to 50%. After two scrams and a critical, the reactor was made-critical again in hot standby to test relief valves. On December 20 the unit was placed on the line and thermal power was raised to 35%. Thermal power was limited to <35% for the remainder of the month because of suppression chamber ring-header nozzle stress problem.
The work plan for the pre-warranty run outage consisted of 16k items. Of these,133 items were completed, 23 items were deleted, and 8 items were cancelled for lack of materials. The ma.jor items of work performed were:
1.
Installed the pre-varranty run test equipment.
2.
Replaced three relief valves (PCV-1-18, -13, and -3h).
3.
Installed CRD pump suction strainer bypass and temperature control valve in cooling line on both pumps.
Plant Operations and Performance Characteristics (Continued)
December (Continued) k.
Repaired suppression chamber support feet.Il) 5 Installed plugs and rods in RHR heat exchangers B and D 6.
Modified three relief valve vent lines in torus.(1) 7 Replaced CRD 26-07 and 34-Ok.
8.
Bergen-Paterson and Grinnell shock arrestors and absorbers repair.
The reactor was operated at a nominal power level of 25% during the month. On December 24, the rod pattern was adjusted for operation along the 50% flow line. Maximum thermal limits occurring include MCHFR 3.69, and LHGR 10.4 kw/ft. Maximum power output was 53 7% occurring on December 26.
The quality of water in the primary coolant system remained below 1.0 umho/cm @ 25 C. for most of the month. The development of condenser tube leaks caused reactor water conductivity to exceed 2.0 unho/cm @ 25' C. for 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br /> and chloride concentration to exceed 0.I ppm for 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />. This raised the 1973 calendar year total for reactor water conductivity exceeding 2.0 umho/cm @ 25* C. to 157 hours0.00182 days <br />0.0436 hours <br />2.595899e-4 weeks <br />5.97385e-5 months <br /> and for the chloride concentration exceeding 0.2 ppa to 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />.
January At the beginning of the month, the unit was on the line with reactor power at 3k%. On January 2 the reactor scrammed. The turbine was made unavailable at 5:00 p.m. for balancing shots on numbera 5 and 6 bearings.
The reactor was made critical at 7:50 p.m. and held at hot standby until 11:00 p.m., at which time the turbine was made available for restart. On January 3 the unit was placed on the line with thermal power being increased to about 50%. After several power changes to accommodate startup testing, power was being increased to about 50% on January 18 and later reduced to about 25% during a two-recirculating-pump trip test. On January 18 a planned turbine trip caused a reactor scram. The reactor was brought to cold shutdown to dye-penetrant-check three relief valve tail pipes. At this time all the Bergen-Paterson and Grinnell shock arrestors were inspected. Most of the arrestors were found in good condition; a few were leaking and subsequently repaired. On January 22 reactor startup was begun. On January 23 the unit was on the line and increasing to 50% power.
After two scrams on January 25, the reactor was made critical and the unit was on the line with power being increased to 50%. On January 26 the reactor was brought to het standby to replace TIP indexer "C" in the dryvell.
At 5:35 a.m., maintenance was completed in the drywell and at 6:k5 a.m.
the i
(1) Refer to interim report from J. E. Gilleland to Voss A. Moore dated January 10, 1974 l
Plant Operations and Performance Characteristics (Continued)
January (Continued) unit was placed on the line with power being increased to about Sof,, where it remained for the balance of the month. On January 29 the rod pattern was adjusted for operation along the 75% flow line. Maximum thermal limits occurring include MCHFR 3.kT and LHGR 10.1 kv/ft. Maximum power output was 58.1%, occurring on January 31. Puel preconditioning with a slow rate of power increase (1/3% per hour) commenced on January 30 at 6:00 p.m. and continued through the end of the month. Approval to continue testing to 85% thermal power was received on January 31.
The quality of water in the primary system improved during the month. There was one unplanned conductivity and chloride excursion in the reactor coolant resulting from condenser tube leaks. The conductivity of the reactor coolant also exceeded 2.0 umho/cm @ 25 c. as a result of injecting sodium sulfate into the primary system during the performance of Startup Tests 1, Chemical and Radiochemical, and 92, Steam Separator and Dryer. The conductivity exceeded 2.0 unho/cm @ 25 c. for 13 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> and the chloride concentration exceeded 0.2 ppm for 3 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> during the month.
February Puel preconditioning to the 75% power level was begun with the month and continued until February 3, when "B" reactor recirculating pump tripped due to brush failure on the M-G set exciter. On February k repairs to the M-G sets were completed and fuel preconditioning to the 75%
thermal power level was resumed. On February 9 control rod exchange from "A" to "B" sequence was begun at 12:00 noon and completed at 7:0h p.m.
Flux shaping and Xenon equilibrium were established and fuel preconditioning to the 75% power level was resumed on February 10.
On February 12 the reactor scra=med on MSIV closure due to high steam line tunnel temperature.
Relief valve PCV-1 kl stuck open and the unit was placed in cold shutdown for repairs to the relief valves.
PCV-1-18, kl, and k2 were replaced.
On February 15 a hydrostatic leak test of 1000 psig was conducted on the reactor with no leakage detected. On February 16 the steam packing exhauster motors burned up due to vater in the fan housing and the 1.75-minute, off-gas holdup line was found full of water. While maintenance was being performed on steam packing exhausters, the reactor was made critical seven times for operators' training.
The reactor was operated at a nominal power level of 75% during the month along the 75% flov line.
Puel preconditioning, slow power increase at 1/3% per hour, was completed for 55-75% power in control rod sequence "A" on February 7 One control rod pattern exchange was conducted at approximately k0% power. This exchange occurred with a relatively high Xenon concentration and required 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. Maximum thermal limits occurring included MCHFR 2.8k, MAPLHGR 10.3 kv/ft., and LHOR 13.2 kv/ft. Maximum power output was 77.5%, occurring February 6.
The conductivity of the reactor coolant (for entire month) exceeded 2.0 umho/cm @ 25' C. for 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br /> as a result of a planned injection of sodium sulfate added during the performance of STI 92, Steam Separator and Dryer Test. The chloride ion concentration in the reactor coolant remained
Operations Summary (Continued)
Plant Operations and Performance Characteristics (Continued)
February (Continued) 1 within limits during the month. This year the conductivity limit of 2.0 unho/cm 9 25* C. has been exceeded for 26.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> and the chloride j
concentration limit of 0.2 ppa has been exceeded for 3 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />.
1 i
Change in Facility Design i
Reactor Water Level Instruments On December 21 the mercury-type switches in four reactor water level instruments (Yarway) were replaced with seismically qualified i
magnetic type. The switches have functioned properly since installation and plans are to modify four more instruments at the next opportunity.
I Core Spray Sparger to Reactor Pressure Vessel d/p i
I On January 18 the core spray sparger to reactor pressure vessel d/p instrumentation sensing lines were exchanged to permit an onseale indication (see page 10). The indicated differential pressure has i
been about 3.5 psi on one core spray loop and about 3 5 or about 5 5 psi on the other loop (only these two values have been observed on the instrument). These values have been, for the most part, concistent within 0 5 psi for reactor power up to 77%, maximum for reporting period, and core flow up to 100%. The 3.5 psi agrees very closely with the calculated l
value; the 5 5 pst value is attributed to the loss of the water in the i
vertical core spray pipe inside the reactor vessel. This additional 2-psi i
differential has not yet been associated with a particular reactor condition.
Occasionally, at certain power levels, with low core flow, both instruments experien:e random oscillations of about 1 psi. This is believed to be caused by turbulence in the reactor, since the oscillations occur only in the cour.on instrument line that senses the pressure above the lover core plate and not in the lines from the core spray piping. Evaluation of the change and testing continued at the end of the reporting period.
l
,i t
1 i
)
_9 Operations Summary (Continued) i Changes in Plant Instructions Revisions made to plant instructions during the reporting period are summarized in the tabulation below.
A brief description of each revision except those in the 'other' category is shown on pages 23 and 2k.
g(1) Sept Oct Nov Dee Jan Feb(2) Total Change in facility design 0 8
3 5
3 3
0 22 i
Change in performance 0
2 1
3 0
0 h
10 characteristics Change required to 0
55 15 0
2 1
0 73 improve the safety of operation Other (clarity, hl h9 73 h8 22 35 26 29h simplify,etc.)
Total kl lik 92 56 27 39 30 399 Surveillance Testing A summary of surveillance tests is shown on page 25 Containment Leak Rate Tests Primary containment penetration leak rate tests performed are listed on page 26.
A secondary containment leak rate test was conducted
]
on January 22. The results are as follows:
SGTS Train A - Flow:
8h00 cfm, oP Refueling Floor: -0.h5 inch of water
' P Reactor Zone
-0.h8 inch of water SGTS Train B - Flow: 8700 cfs, oP Refueling Floor -0.h1 inch of water j
aP Reactor Zone
-0.45 inch of water i
(1) Beginning August 17 (2) Ending February 17 l
\\
l l
l 1
..m.
Operations Summary (Continued)
Changes, Tests, and Experiments Requiring Authorization from AEC Pursuant to 10CFR 50 59(a)
The technical specifications were changed on November 14 to eliminate references to Reactor High Water Level Instrument Channels which did not exist in the Browns Ferry Nuclear Plant.
Analyses shewed that high reactor water level initiation of MSIV closure was neither necessar-/ nor desirable in BWR plants having less than 40-percent turbine bypass capacity. MSIV closure on high reactor water level, when not in the "RUN" mode, was originally specified to prevent an unacceptably rapid reactor depressurization caused by a hypothetical failure of the steam pressure regulator causing the t, pass valves to fail open.
A temporary change was made to the technical specification on January 18 concerning the core spray sparger to reactor pressure vessel d/p trip level setting. The installed instrumentation did not function as described in the BFNP F3AR, which was to monitor the integrity of the core spray piping between the shroud and reactor vessel. The differing temperatures and lengths of the two vertical instrument sensing lines (one inside the pressure vessel and one outside) created a differential static pressure which was higher than expected on the low pressure side of the switenes. The installed instruments did not indicate a positive pressure differential during normal operation. To correct this problem, the instrument sensing lines were exchanged to obtain a positive ~onseale differential pressure and the setpoint changed to be compatible with the onscale indication.
Changes in the Plant Operating Or2anization There were no changes in the plant operating organization which involve positions for whien minimum qualifications are specified in the techni-cal specifications.
Fower Generation and Shutdowns Power generation and shutdowns are summarized on pages 27 through 29
1 Maintenance 4
Maintenance and inspection a'ctivities concerning the Bergen-Pat erson and Grinnell shock arrestors and absorbers are described below.
October 9-10 4
One Bergen-Pat erson arrestor on the core spray system was founti l
to have a low oil level. Three Grinnell arrestors located on the recircu-lation system had no oil indicated in the accumulators. Two of these Grinnell arrestors had evidence of oil leakage from the arrestor. Oil was added to all arrestors to restore the accumulators to the proper level.
October 2h The Bergen-Paterson arrestor on the core spray system and the three Grinnell arrestors on the recirculation system were inspected. These arrestors had no evidence of leakage and the oil reservoirs were adequately l
filled. During this drywell entry, two other Grinnell arrestors were found with empty reservoirs. No leakage was found and the reservoirs were filled.
l The suspected cause of oil reservoir level variation is the escape of air
]
trapped during prior repair activities.
)
November 10-13 I
of the h5 Bergen-Paterson arrestors installed in the drywell, j
one was found to be leaking.
It was rebuilt at the December outage. Ten of the 20 Grinnell arrestors installed in the drywell were found to have a low-fluid level in the reservoir; three were empty or almost empty. Three others were approximately 2 inches low.
Fluid was added to bring them to the proper fluid level. All the Grinnell shock arrestors were replaced in December with rebuilt arrestors from unit 3.
December 11-21 During the pre-warranty run outage, all Bergen-Paterson shock arrestors were rebuilt using the permanent ethylene propylene software parts. The program included the ik shock arrestors on unit 2 RHR "A-C" loop that are required for unit 1 operation. All cylinders were polished; some were honed or replaced. GE SF 1154 oil was used in all rebuilt arres-tors. A total of 138 arrestors were rebuilt during this outage. There are 6 j
arrestors from unit 2 or unit 3 that are installed in unit 1 as replacement snubbers. All but two of the Grinnell arrestors were replaced with those from unit 3 that were returned to the factory for rebuilding.
1 Relief Valve Tail Pipe Weld Inspection - On January 19 and 20, paint i
was removed from the velds where the tail pipes from relief valves PCV-1-19,
-22, and -31 pass through the 8-foot diameter vent lines (which connect the dry-well to the suppression chamber) into the suppression chamber.
Both the inside l
and outside welds were dye-penetrant-checked in accordance with special test instruction
- o. 22.
The velds were found satisfactory. This inspection was i
i
l Maintenance (Continued) made to ensure that these velds were hot damaged as a result of the suppression chambe-vibration tests. The special test specified that qualified technicians perform the testing and that it be performed in accordance with Magnaflux Corporation Quality Control Manual, Section 12N, Penetrant Procedure /Huclear -
Amendment 1.
Maintenance activities on other safety-related equipment are shown in the maintenance summary, pages 30 through 38.
4 Changes, Tests, and Experiments Not Requiring Authorization from AEC Pursuant to 10 CFR 50.59(a)
Special vibration tests were conducted on the suppression chamner and suppression chamber ring header November 18, 28, and 30 to determine deflection and associated stresses on the ring header nozzles during relief valve operation. As a result of the tests, vertical restraints were installed on the ring header at the sixteen suppression chamber support saddles. Single valve testing was conducted on December 3, 7, 8, and 24 Test results on December 24 vere acceptable and multiple valve testing was conducted on December 28 and 29. The suppression chamber support saddles were reshimmed during the December 8 and 2k tests. Tests conducted on January 4 and 11 con-cluded the torus vibration testing.
Results indicated that the stresses in the suppression chamber and torus ring header nozzles were acceptable for the interim. The permanent fix for the suppression chamber and torus ring header nozzles and/or relief valve tail pipes was pending at the end of the reporting period. Refer to interim report to Voss A. Moore from J. E. Gilleland, dated January 10, 197h.
Changes to the facility design begins on page 4.
Effluent Feleases Liquid and gaseous effluent releases are tabulated on paces 39 Colid Hadioactive Waste Solid radioactive vaste shipped off site is snown on page bl.
1 Pecord of '!SSS Components, Transient and Operatienal Cycles, and Calculation of Usage Factor The usage factors are tabulated on page 29 On February 12, during a scram, a single relief valve stuck open, allowing the reactor vessel to depressurize. According to The Babcock & Wilcox Campany's stress calculations for the reactor vessel transient analysis, two
. Record of NSSS Components, Transient, and Operational Cycles, and Calculation of Usage Factor (Continued) single relief or safety valve blowdowns are assumed to occur during the life of plant. Also, in their stress analysis, the blowdowns are a less severe transient than others analyzed. Therefore, for a more conservative stress calculation, blowdowns were included with the more severe transients to determine ussge factor. Calculations indicate that the blowdown did not contribute significantly to the vessel usage factor. (Refer to abnormal occurrence BFAO-7h9. )
ion-Radiological Environmental In-Plant Monitoring r
Reservoir water temperature did not exceed thermal discharge limits specified in the technical specifications during the reporting period.
The sewage treatment plant operated satisfactorily during the reporting period, with the concentration of residual chlorine in the effluent not exceeding the specified ILuit, except as reported in response to RO:II:WSL 50-259/74-1, dated February 25, J. E. Gilleland to Norman C. Moseley.
Apprcximately 2.44 E6 gallons of water were released from the emergency field. pond to the river during the reporting period. The pH of the released water was maintained within the limits specified in the technical specifications.
The ra.w water chlorination system was operated briefly during November for testing. No technical specification limits were exceeded during this time.
There were many abnormal occurrences during the reporting period due to fish impingement on the intake screens.
In February, the technical specifications were changed to provide a quantitative assessment of fish losses from normal plant operation and to identify the need for possible corrective action.
i
-1h-SIGNIFICANT OPERATIONAL EVENTS - BROWNS FERRY NUCLEAR PLANT - UNIT 1 DATE TIME REMARKS i
I 8/17/73 9:20 a.m.
Enitial criticality notch 20 of 53rd rod 8/18/73 11:00 a.m.
Shutdown No. 1.
Installed dryer and separator, vessel head, and drywell head 8/20/73 3:15 a.m.
Open vessel testing completed.
started hydrostatic leak test on reactor vessel 8/28/73 12:35 p.m.
Ended hydrostatic leak test on reactor vessel 9/1/73 2:05 a.m.
Started hydrostatic leak test on reactor vessel l
t 9/1/73 12:00 noon Ended hydrostatic leak test on reactor vessel I
9/2/73 BFAO-737 - Core spray System Loop r failure to meet rated flow 9/4/73 BFAO-738 - HPCI steam valve FCV-73-16 inoperability 9/5/73 3:45 a.m.
Pulling rods to critical 9/6/73 10:20 a.m.
Critical No. 2.
Began nuclear heatup
- 9/8/73 BFAO-739 - HPCI inverter power supply fuse failure 9/6/73 BFAO-7310 - Recirculation pump d/P switches (3) malfunction 9/9/73 3:45 a.m.
RCIC and HPCI startup tests 9/10/73 BFAO-7311 - HPCI failure to reach rated flow during automatic f
quick start 9/10/73 5:20 p.m.
RCIC and HPCI startup tests 9/11/73 7:57 p.m.
Shutdown No. 2.
Drywell ventilating and cooling problems 9/12/73 BFAO-7312 - Reactor Bldg. to suppression chamber vacuum breakers inoperability 9/14/73 BFAO-7313 - RCIC high flow pressure switch. malfunction 9/19/73 BFAO-7314 - Target Rock:rel er valve se tings 9/20/73 BFAO-7315 - HPCI hir) fiov pressu:e switch malfunction 9/25/73 5:15 a.m.
Drywell ventilating end coeling work completed 9/26/73 BFAO-7316 - stack gas mcnitor, vacuum pump failure 9/25/73 8:27 a.m.
CriticalNotb.
'~
9/26/73 7:10 p.m.
Scram No.~1.
APRM high P
f e
~
l f
r
._,,e e
DATE TIME REMARTS
-9/27/73 BFAO-7317 - RCIC high flow instrument lines reversed 9/27/73 5:00 a.m.
Critical No. 4 i
9/27/73 11:40 a.m.
Scram No. 2.
Iow air pressure on scram valves 9/27/73 11:29 p.m.
Critical No. 5
-9/29/73 BFAo-7318 - HPCI inverter power supply fuse failure 9/30/73 3:30 p.m.
Scram No. 3 Reactor low water level 9/30/73 10:25 p.m.
Critical No. 6
-10/1/73 BFAo-7319 - Reactor water cleanup system valve (Pcy-69-12) failure 10/2/73 1:33 a.m.
Scram No. 4 APRM high 10/3/73 3:20 a.m.
critical No. 7 I
-10/3,4/73 BFAo-7320 - control rods (2) 10/5/73 1:30 p.m.
Scram No. 5 Reactor low water level
-10/5/73 BFAo-7325 - HPCI system inner rupture diaphragm failure 10/5/73 4:57 p.m.
Critical No. 8 10/6/73' 3:15 a.m.
Initial rolling of turbine with reactor steam 10/6/73 7:12 p.m.
Scram No. 6.
IRM high 10/6/73 9:20 p.m.
Critical No. 9 i
i
-10/7/73 BFAo-7321 - Drywell pressure switches (2) malfunction 10/7/73 7:53 p.m.
Rolled turbine to rated speed 10/8/73 11:00 p.m.
Scram No. 7.
Work began on generator hydrogen seal (low resistanc
-ld/9/73 BFAc-7322 - Reactor water level switches (2) malfunction i
-10/11/73 BFAo-7323 - Turbine condenser low vacuum switches (2) malfunction 10/11/73 6:00 p.m.
Generator hydrogen seal work completed 10/11/73 10:50 p.m.
critical No. 10 10/12/73 12:52 p.m.
Scram No. 8.
DATE_
TIME REMARKS 10/12/73 3:33 p.m.
Critical No. 11 10/13/73 4:45 a.m.
Scram No. 9 Reactor low water level 10/13/73 8:35 a.m.
Critical No. 12 10/14/73 1:51 a.m.
Scram No. 10.
Reactor nigh pressure 10/14/73 6:15 a.m.
Critical No. 13
-10/15/73 BFAO-7326 - LPCI logic system d/p switches (3) malfunction
-10/15/73 BFAO-732h - Stack gas monitoring system failure 10/15/73 5:10 a.m.
Initial synchronization of generator 10/15/73 5:55 a.m.
Tripped turbine due to high vibration. Reactor was at rated pressure and temperature, MSIV's open and C7's closed. Maintenance on steam seal valve Fcy-1-146 10/15/73 Hot functional test program completed
-10/16/73 BFAO-7327 - Recirculation pump riser d/P switch (l' malfunction
-10/17/73 BFAO-7328 - Condensate header low level switches (2) malfunction 10/17/73 4:20 a.m.
Synchronized generator
-10/18,19/73 BFAO-7329 - HPCI inverter power supply fuses failure 10/18/73 11:29 a.m.
Turbine trip. Off for turbine steam byn ss valve No. l repair 10/18/73 8:00 p.m.
Shutdown No. 3.
Replaced servo valve and CR exercise
-10/19/73 BFAc-7330 - Unanalyzed liquid radwaste release 10/19/73 4:12 a.m.
Critical No. 14 10/19/73 11:19 a.m.
Synchronized generator 10/20/73 5:53 a.m.
Turbine trip (Manuali i
10/20/73 1:06 p.m.
Shutdown No. 4.
lA and 1B recire, breaker problem.
Test position linkage was removed from the normal and alternate breaker cubicles.
Connections to control switch were tightened 10/20/73 9:15 p.m.
Critical No. 15 10/21/73 5:18 a.m.
Synchronized generator 10/23/73 2:53 p.m.
Scram No. 11.
Reactor low water level 10/23/72 11:22 p.m.
Critical No. 16
DATE TIME REMARKS 10/24/73 Reactor water chemistry above limits
-10/25/73 BFAo-7331 - Turbine condenser vacuum switches (2) malfunction 10/25/73 4:39 a.m.
Synchronized generator 10/26/73 7:38 a.m.
Scram No. 12.
Condenser low vacuun 10/26/73 n:48 a.m.
Critical No. 17 10/26/73 3:43 p.m.
Synchronized generator 10/27/73 7:00 a.m.
Began PCIOMR. A sequence, 25% (823 MWt)
-10/31/73 BFAo-7332 - HPCI condensate header low level switch malfunction 10/31/73 4:51 a.m.
lA recire, pump trip. Apparent ground on recire. board one control system 10/31/73 8:50 a.m.
la recire pump trip. Apparent ground on recire. board c7e control system 11/1/73 10 00 p.m.
End PCIoMR. A sequence, 35% (115P MWt)
- n/8/73 BFAo-7333 - Reactor water level switch malfunction 11/8/73 5:07 p.m.
Tripped turbine on STI 27 11/9/73 5:10 p.m.
Synchronized generator n/9/73 7:45 p.m.
Scram No. 13. Reactor low water level
-11/10/73 BFAo-7334 - RCIC and HPCI systems inoperability 11/10/73 2:05 a.m.
Critical No. 18 11/10/73 6:35 a.m.
Synchronized generator 11/10/73 7:19 a.m.
Scram No. 14. Reactor low water level.
Inspection began on relief valve tail pipes and thermocouples
- n/13/73 BFAO-746 - Release of radioactive material
-11/13/73 BFAO-7335 - Plant change contrary to technical specifications n/13/73 3:23 a.m.
Critical No. 19 11/13/73 8:35 a.m.
1B recire, pump trip. Instantaneous over-current on C phase. No apparent cause was found
-11/14/73 BFAo-7336 - HPCI inverter power supply fuse failure
-11/14/73 BFAO-7337 - ADS permissive core spray pump discharge pressure switch malfunction
DATE TIME REMARKS 11/15/73 BFAO-7338 - RCIC and HPCI systems inoperability 11/15/73 BFAC-7339 - Condenser low vacuum switch malfunction 11/15/73 BFAO-73h0 - HPCI high steam flow switch malfunction 11/15,16/73 BFAn-7342 - HPCI suction valve abnormal transfer 11/15/73 12:34 a.m.
Synchronized generator 11/15/73 2:56 a.m.
Turbine trip STI 31 11/15/73 2:56 a.m.
Scram No. 15.
STI 31 11/15/73 8:22 a.m.
Critical No. 20 11/15/73 12:59 a.m.
Synchronized generator 11/16/73 BFAO-7341 - Reactor water level switch malfunction 11/16/73 1:00 p.m.
Drop in load due to failure of fast closure trip on
'B' control valve which occurred during aurveillance te.:t 11/17/73 12:30 a.m.
Reduce load to get 3 bypass valves open for relier valve tests.
BFN'-7343 - Torus and torus ring header vibration 11/18/73
- 11/18/73 3:25 p.m.
Testing completed for test condition 1 i
11/20/73 4:00 a.m.
Began FCICMR. A sequence, 4T (1CIL ' Lit 11/21/73 10:00 a.m.
End PCICMR. A sequence, hM (1616
'P i 11/22/73 4:30 p.m.
A recire, pump off 11/22/73 A recire. pump off 11/22/73 11:00 p.m.
Began PCIOMR. A sequence, W (161h ?dt' n/23/73 9:20 a.m.
A recire. pump off n/27/73 10:00 a.m.
End PCICMR. A sequence, 59.T (1"5 'L*ti 11/27/73 12:3C. a.m.
Reduced load to test relief valves 11/28/73 1:40 p.m.
Scram No. 16. Reactor low water level 11/28/73 7:53 p.m.
Critical No. 21 n/29/73 12:53 a.m.
Synchronized generator n/30/73 BFAO-7344 - Main steam line high flow pressure switch failure 11/30/73 BFAO-7345 - Core spray sparger differential ' pressure switch malfunction t
DATE TIME REMARKS
- 12/6/73 BFAO-7346-Recirculationpumpd/Pswitchmalfunction 12/11/73 12:46 p.m.
Turbine trip (Manual). Started control shutdown for prewarranty run outage work 12/11/73 1:07 p.m.
Scram No. 17 Condenser low vacuum. End relief valve test
-12/19/73 BFAO-7347 "A" Diesel generator voltage regulator failure 12/20/73 AEC issued a 100% power licen::e for ~ nit 1 12/21/73 5:25 a.m.
Started hydrostatic leak test on reactor vessel 12/21/73 8:00 a.m.
Ended hydrostatic leak test on reactor vessel 12/23/73 9:25 p.m.
Critical No. 22 12/24/73 10:16 a.m.
Synchronized generator
-12/25/73 BFAO-7348 - HPCI system inoperability
-12/25/73 BFA0-7349 - Relief valve bellows seal leak alarm 12/26/73 9:15 a.m.
Scram No. 18. Reactor high water level 12/26/73 10:22 p.m.
critical No. 23 12/27/73 2:20 a.m.
Synchronized generator 12/27/73 3:58 a.m.
Turbine Trip. Moisture separator high level 12/27/73 4:12 a.m.
Synchronized generator 12/27/73 2:20 p.m.
Scram No. 19 Control valve closure. Moisture separator drain valve repair 12/27/73 10.00 P.m.
Critical No. 24
-12/28/73 BFAO-7350 "c" Diesel generator start circuit failure 12/28/73 10:24 p.m.
Synchronized generator 12/29/73 3:00 a.m.
Resumed relier valve testing
-12/30/73 BFAO-7351 - Drywell floor drain inboard isolation valve inoperability 1/2/74 2:20 p.m.
Scram No. 20.
Reactor high water level i
1/2/74 7:50 p.m.
critical No. 25 i
1/3/74 4:26 a.m.
Synchronized generator
DATE TIME REMARKS 1/4/74 1:44 p.m.
Relief valve testing
-1/4/74 BFAC-7352 - Recirculation pump "A" d/? indicating switch malfunction
-1/6/74 BFAO-741 - Reactor water level switch malfunction l
-1/8/74 BFAC-742 - Two MSIV's closure times slow 1/8/74 MSIV closure (surveillance instruction) 1/9/74 12:c; mn Reduced load to adjust MSIV closure time.
-1/9/74 BFAO-743 - LPCI break detection pressure switches not in i
service 1/11/74 11:30 p.m.
Relief valve testing completed
-1/16/74 BFN?-744 - Start system failure on standby diesel engine 1/16/74 9:00 p.m.
la recirc. pump trip test (STI 30 & *)
-1/17/74.
BFAG-745 - Standby liquid control pump failure 1/17/74 11:30 a.m.
1B recire, pump trip test (STI 30 & 00) h 1/17/74 8:30 p.m.
Recire equalizer valve open test (STI 36) 1/18/74 5:00 a.m.
lA and 1B recire pump trip test 'STI 30 & 90) 1/18/74 11:00 a.m.
STI 27
~ 1/18/74 11:00 a.m.
Scram No. 21.
STI 27. Torus and drywell work (Dye check RV tailpipes PCV-1-19,-22, &-31) 1/22/74 4:55 p.m.
Critical No. 26 1/23/74 3:04 a.m.
Synchronized generator 1/24/74 6:10 a.m.
Scram No. 22.
Loss RPS MG Set A (Manual scram) 1/24/74 6:15 a.m.
Critical No. 27 1/24/74 11:45 p.m.
Scram No. 23. Reactor low water level 1/25/74 2:40 a.m.
Sersm No. 24 Reactor mode switch placed to run when reactor suberitical 1/25/74 9:16 a.m.
Critical No. 28 1/25/74 1:27 p.m.
Synchronized generator
-1/26/74 BFAO-747 - HPCI governor instability 1/26/74 6:10 a.m.
Reduced load due to reactor recire. pump trip test (STI 30 & 9c
-1/28/74 BFAO-748 - Removal of reactor and turbine building radiation monitor from service 1/28/74 7:41 p.m.
Shutdown No. 5 began 1/29/74 12:53 a.m.
Turbine trip (manual). Remained on turning gear, reactor remainel critical. Drywell work (replaced TIP indexer C) 1/29/7h 6:45 a.m.
Synchronized generator 1/30/74 8:00 a.m.
Began FCIOMR. A sequence, h'$ (161h Wt)
Testing completed for test conditions 2, 2A,ud ?
1/31/74 9
1/31/74 5:00 p.m.
End PCIOMR. A sequence, 58% (1910 Wt) 2/1/74 12:00 a.m.
Began PCIOMR. A sequence, 564 (184h Mwt) 2/3/7h 7:25 p.m.
End PCIOMR. A sequence, 73% (240h Wt). B recire. pump trip caused by brush failure and out-of-round collector rings 2/4/74 4:30 p.m.
1B recire. pump off to repair brush problem and true collector rings on M-G set exciters (M-G set A exciter collector ring cleaned and brushes replaced) 2/4/74 9:30 p.m.
Began PCIOMR. A sequence, 67% (22C6 Wt) 2/6/74 10:00 p.m.
End PCICMR. A sequence, 77% (2536 Wt).
Condensate demineralizer 1-G bypassed during backvash: cause unknown 2/8/7h 12 00 noon Held load because of Icad dispatcher 2/9/74 12:00 noon Dispatcher release load requirement. Began control
-M exchange from A to B sequence 2/9/74 7:04 p.m.
End control rod exchange from A to B sequence 2/9/74 10:30 p.m.
Began flux shaping 2/9/74 11:20 p.m.
End flux shaping, holding reactor power at about 50% (1647 wt) for Xenon equilibrium 2/lo/7h 9:32 p.m.
Xenon equilibrium established 2/11/74 4:00 a.m.
Began PCIOMR. B sequence, 54'! (1778 Wt)
I
. DATE TIME REMARKS
-2/12 /74 BFAO-749 - Main steam pressure relief valve failed to reseat 2/12/74 4:01 p.m.
End PCInMR. B sequence 65%, (2140 MWt). Sersm No. 25 MSIV closure due to high steam line tunnel temperature 2/12/74 5:09 p.m.
Relief valve PCV-141 stuck open 2/12/74 8:15 a.m.
Began relief valve work. Replaced PCV-1-18,-1 41,-1 42 (FCV-1-18 had a leaking bellows, and "CV-141 &-42 had a slow delay time)
-2/13/74 BFAC-7410 - Main steam line high flow sritch malfunction 2/15/74 5:30 a.m.
End relier valve work 2/15/74 4:00 p.m.
Began increasing reactor pressure for hydroststic lesk test 2/15/74 7:15 p.m.
Reactor st IC00#, hydrostatic lesk test began 2/15/74 7:35 p.m.
End hydrostatic leak test on reactor 2/16/74 4:25 a.m.
Critical No. 29 2/16/74 4:55 p.m.
Steam packing exhauster motors A and E burned up due to water in fan housing 2/16/74 6:00 p.m.
Began steam packing exhauster work.
2/16/74 6:10 p.m.
Began operators' training criticals.
2/17/74 7:00 a.m.
Began draining off gas holdup line.
2/17/74 4:21 p.m.
End operators' training criticals (7 criticals).
2/17/74
$:00 p.m.
End draining off gas holdup line.
-2 3-Chasses la Flant Instructione a wust 17. DT3 - February 17. 1976 Cateaorr instruction Peeson for Chanse Change la Facility Design Operating - rectreulatiet Penove two valves that were act part of the fleal destga from the valve ebeck list.
0 erating - ventilation A temporarf addendum was removet after the installation 1
of a reset feature on the statie fressure controller.
Before the modification a tripped controller could not be reset.
Surveillance - reactor pressure Setpoint change required by Divistoa of Eeaineerlag Destga.
fio technical specification change was required.
Surveillance - turbine first stage Same as above.
pressure Surveillance - asseous effluent Moving particular filters chanse to stationary type, radiatioa moaltors Startup test - dryer and steam Reflected actual lastallettom of sample lines.
separator Surveillance - tursine firet stage Setpotat changed to represent a resetor power of 305.
pressure Surveillance - APIM
!aop bypass test switches were installed.
Surveillance - SC*S System Motor operated exhaust dampers and controls retlaced by====117 operated dampers.
Surveillance - diesel generator Test pushbutton added to fuel oil transfer pumpe Surveillance - SCTS Imste Motor operated enhanat dampers and controls replaced by======11y J
operated dampers.
Surveillance - Core thermal Technical specification enance on fuel densificatica (local and performance planar IJiGR)
Startup test - Core thermal Aape na above.
performance Surveillance - HPCI Lcaic Exhaust rupture dise breas detection logic changed.
Surveillance.RCIC logie Same as above.
Surveillance - SCTS Logic Test evitebes added to circuitry.
Change in Performance Operattag - EPCI Specified opening of hotwell pump bypass valve to provost-
' Characteristics recyclins of condensate through valve.
Operattar - radvaate A floor drain collector tank pump was required to establish re$ed i
flow through floor trate filter.
l Operating - reactor water Changed conductivity limit on the effluent of the dominere11sers
)
eleanup frta the deetga value to an operational value.
Also permitted removal of the desterralizers warea silica began to increase la the effluest.
Surve111amee - EECW A pumn vsa required for maintatatas header pressure to mialaine water hammer.
Surveillance - DCIC Offsete were put la the steem flow inetrumentattoa to compensete for pressure differeattal ta the lastrument 11oes.
Operating - radvaste The 4/p across the floor trata and waste filters were taeressed to provide lomaer run time.
Startup test - DCIC Removed the retest requiremen*. for flow controller changes in the final system verificatten if as evaluattoo of system characteristics laticate reteettag is unseesseary.
Startup teet - MFCI Same as above.
Startup teet - drywell Dulhased temperature limit changed from 10' F. to 25' F.
Operettag - etreulettaa ester Addittend operetten of the Amertop shutoff fitpe were required to eteen debris from the lower screes.
a e
.4
2k.
Chanses la Plant Instructions ( untinue4)
Auduet 17, 1973 = February 17. 197k Catesory Instruction Season for Charge Change required to improve Operatina - intearsted systems An McNyR cheet was required before increasing core flow, the safety of operation Operatina = circulation Prereoufsites adJed to ensure that the motor start breamer will act landvertently close vtien repiscing blown fuses la the central circuitry.
Operating - 37 systems Instrument valves were required in service prior to system operettoa.
Operating = CRD Required a reactor shutdown if a control rod cancot be fully taserted and a shutdown marata of 3.331 i K/E cannot te met.
Operatir.g - reactor less test Pequired a check-off list for each step to ensure that every step to followed.
Operating - RCIC Vacuum breaker valve in the turbine exaaust line to the torus was required open to minimite water hammer daring tuttine operation.
Operating - HPCI Same as above.
Surveillance - scram testing itequired.peelal control rst sequence for group C rod movement.
Also specified the aceunulator charging water header valve be closed to prevent possitie deanae to the control rod drive.
Surveillance HPOI Oondensate Part of the HTCI logic was enecked durinA the cha. net test of sn.
header level condensate header level.
Mechanical Maintene -* - CR2 Prerequisites added to minimite the possibility of as landvertest criticality during sne testina.
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Teste AmenstIII sestater October se m ber Desesber Jaynary Februarr( '
4 MIN
$8 169 179 219 266 300 34)
Gem 41stenal(2) 39 123 95 92 70 76 86
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III September cetcher november December January February Tyne Test Unite Aarust Type A (integrated containment)
WT IT NT NT Ff BT FF Type 3 (dryvell/torue batches)
Personnel Air Loch (I-2) seth(2) 5.72 11.hb 31.b0 6.25 25 06 17.54 6.27 so. tests 1
8 11 1
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1 I3I serb 5.72 4.96 9.62 6.28 7.oh 6.07 6.27 Other hatches Torus hatch (b2005) ecft NT 0.00712 Ff 0.06h 0.004 FF Ff Torus hatch (I-200A) se fb FF 0.01187 FF 0.003 0.003 BT Iquipment batch (I-13) seth Fr 0.253 sf 0.2Tb WT Ff WT CRD removal hatch (I-6) sefh IT 0.00042b WT 0.001 IT Ff Igalpaent batch (1-1A) sefb FF 0.012 ST Bf IT FF Drywell Esed Access Hatch Fr
.000 BT WT NT FF TIP drives (I-35A)
NT
.133 WT ET FF FF TIP drives (I-353)
FT
.0000137 IT NT FT Ff NT TIP drives (L35C) rf
.0000 NT ET NT Ff FT T:P drives (I-35D NT
.0000 ST NT ST FF Ff TIP drives (L 35E)
.000035 UT BT 57 FF ET T:P drivee (I-357)
.0000055 ET NT FF Ff NT T P artres (b350)
.000013 E
ET BT NT FF Fever Operstico Test (LkT)
.00058 FF ST FT NT NT Construction Drata (1-213A)
FF 0.49 Ff IT NT ST Ff Canatructico Drain (b 2133)
.00000 WT ET NT Ff NT Drywell Eeed NT
.190 ET NT FT ST ET Type C.(1 solation valves) ecfh FF 0.08 ff IT b.kO3 FF FF (PCV-73-609.
(FCT-73-3) 73-24)
ET. De Test (8) Entire Month (2) manism vales (3) Weishted Average J
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- e. Thutdowns Auaust 17,19(3 - February 17, 1974 Method of Duratten Date Cause Diut dovet (Vur-)
Plant *tatus Correettve Action Other Ntepe t went e 9-26-73 APRM MICH FINE SCRAM 9.8)
Hot Chutdows pone Scram recovery only (Adataistrative error)
)
9-27 73 WSs or Courp0L AIR SCRAM 11.81 Mot Shutdown Modification belag evaluat ed Seres recovery Orly (Isolation of control air during electrical evitching) 9-30-73 14W FEAC7JR WATER LEVEL SCRAM 6.91 Mot Shutdown Recorder repaired Scram recovery only (Imvel recorder malfumetion while on manual feedvater control) 10-2 73 AP'M MICH LEVEL SCRAM 25.78 Mot Shutdows None Scraa recovery only (Adataistrative error) 10-5-73 REAC"CR WW WATER 12 VEL SCRAM 3.k$
Bot Shutdown Revised instruction Scras recovery only (Procedural error) 10-6.-73 IRM IIOR SCRAM 2.13 Mot Shutdown Wome Seram recovery only (Administrative error) 10-8 73 I4SS CCNTROL AIR SCRAM 63.7 Cold Shutdows Modifiestion being evalhetet Cleaned generator hydroges seal (Isolation of control air da ir.g electrieri evitehtag) 1 %12-73 SRM ICICATING NIGN MANUAL 2.68 Not Shutdows Bone Seras recovery only (Due to welding ta SCRAM reactor building) 10-1)-73 REACTOR IEW WATER LEVIL SCRAM 3.83 Bot Shutdown Revised instructica Scres recovery only (Procedural error) 1 % 1k 73 RZa".TOA alGE PREsguRE SCRAM i.k1 hot Shutdove aeplaced blown fuse Scram recovery only
(*!!Y elosare) l b l5-73 EIGa 7'm!33 YIBRATICE MANUAL k6.k1 Eat Standby Balanced Turbine Maintamance on stema seal valve 1-1-166 1% 15-73 BTPASS VALVI STUG OPE 5 MANUAL 23.63 Bot Standby Peplaced servo valve Rome la bypass valve 10-20-73 REC;RTIATIOR FUMP REAED MANUAL 23.k1 Bot Shutdows Corrected wiring None PROB:2M 1 % 23-73 REA T R W W WATER LEVIL SCRAM 37.76 Bot Shutdown 011 system repaired Peacter water chemis'try problem (Teodwater pump trip) 10-26-73 CCEDSD LOW VACUtst SCRAM 8.06 Rot Shutdown Adatalstrative jumpers Screa recovery only (Lces of power to SJAE valve) lastalled 11-9-73 REACICR I4h WATER LEYEL SCRAM 10.58 not Shutdown Corrected wiring Screa recovery only (Lose feedwater during electrical switchiag) 11-1% 73 REACTCR WW WATER LITEL SCRAM 113 25 Cold Shutdova Rome Beller valve tail pipe med (Adataistrative error) thersecouple inspeetton 11-15-73 STI 31 SCRAM 10.03 Mot Shutdows Weae Seres recovery only 11-23-73 REACTCR I4W WATER SCRAM 11.21 bot 8hutdows Error is piectag jsaper Scraa recovery only (Feedvater rumback) 12-11-73 CCIOUSD ICW VACULBE SCRAM 309.5 Cold Shutdove same Pre-Warranty run outage (Condenser vacuu breaker opened to slow turbine) 12-26-73 REACTCR u!2 WATD 12 VEL SCRAM 17.08 Bot Shutdown cause under lavestiretion Screa recovery only (1mes of salt preferred power) 12-27-73 W RSINE TRIP 0.h Rua Repair moisture separator some (Moisture severator level high) drata valve 12 27-73 CONT 1cL VALTE CLocuss SCRAM 32.06 not shutdown Repaires moisture separator Bene orale valve Admialstrative errore are all errors other than procedural errors. equigurat aalfunction. ans incorrect design.
.L 29-h tdowns (Continued)
Awesst 17. 1973 - February 17.197b
. Method of Date Cause "hutdown Ibration Mant *tatum f'orreettve Action Mher Outwe Fvente M2.Vb BIGN REACTOR WATER 12 VEL SCRAM lb.1 Hot Shutdown Cause under investiaation feram recovery only
(!ase of unit preferred power) 1 18 74 STI 27 SCRAM 112.C6 Cold thutdove some Dye eneck (3) relief valve sati pipes 1 24 7b Idrf RPS MG SET A SCRAM 31.25 Hot Shutdows cause betrut investigated some 1 29 74 TIF SYSTIB1 MA.TJAL 5.86 Hot Shutdova Replaced *C" indeser Ione 2 12 74 M31V C14SURE SCRAM 137.k3 Cold Shutdown Revised eurve111 mace Peplaces 3 reiset valves (kish temperature in lastructica steen tummel)
Power Generation August 17. 1973 - February 17, 197b puelear Unite Auevst September Detober Novenster Decevber Jamsary Feb ruary Total BCUPS REACTOR CRITICAL Rours 19.75 236.6 590 589.2 h27 616.98 587.6 3.065.13 CROCS THE3 MAL CENERATIN CWD 0
.223 9.475 29.614 17.955 33.18 68.97 139.42 Electrieel III GROSS CDERATIM MWE (3)
(3) kb 870 195.760 96.900 239.680 319.550 1,h73.970 Err CDERATICE MWH (3)
(3) 40.331 187.338 89.879 227.115 307.763 852.k76 UsIT USE nours (3)
(3) 264.33 574.6 385 11 579.68 514.23 2.317.9 (1) For entire month (2) Beactor generation only (auxiliary diesel generatica exel'uded)
(3) Cenerator act eyachroatsed with system until October 15 Penetor Vessel Cuusalative Usease Feeter August 17, 1973 - February 17, 197b september _0etober novamer Deeenber January February ( }
III teention Aaaust M at water line 0.0000999 0.000283 0.000559 0.0005933 0.0007k9 0.00073 0.00007 Feedwater seasle 0.000610 0.0020hb 0.005192 0.005478 0.00591 0.00627 0.00674 Clemure studs 0.01100 0.0173h 0.02467 0.0253h 0.C2933 0.030c0 0.03368 9
(1) For entire amata ag.
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30-blectrical "sintenance Sussary Aaaust 17, 1973 - February 17, 1974 Iffect on Cafe creration of Cause of eenalts of Aetton Taken to Date System Component Maint enanc e t*e reactor Mal
- net ten
_ N1furetten Preelwie P eurrence Bad inverter FFC! renteret Pepisced inverter Q/27 MPCI
!averter Inverter Coolant mode fattare inoperable in:p but otner T. p. # 1h516 coolant eyetene 14475 wcraed 0.K.
14915 9/2G steen cas staet gas Motor Monitortag sospie pump failure None Loss of oiler on Teno, loss of steen ktor replaced and vacuum pump ens sonttor until oiler repaired, System teca2p pump T.R.10037 s t art ed 10/10 Mata steam Manual relier Correct
'.one t;nknown, tround disap-ene weemly cheen of valve 1-22 grounded rested daring circuit 250V DC pcwer ett.
check by segger.
power circuit 10/16 Stack Gas Sample pumps Peplace Cisatted stack Icw voltaae at pnl.
Parmed up motors tr.:reased power cable Padistico A and 3 motors and saa monitor 25-39 low temp. insula-size feed pal. 25-39 Monitor revise power system tion in motor w1odinas fres #8 to #1/0 con-dactors. Rewount feed actors with class "E"
insulation.
10/19 EPCI EPCI laverter Correct KPCI Made HPCI Wirirut enor as result PPCI incierabit as Corrected wiring eat 5
power supply loale circuit inoperable of 1R1-253 prios changes result of power print error.
wiring incorrect supply fuse blown 10/31 Dieesi Lube oil Deplace temp.
None Thermostat setpoint Cil testerature f eplaced thermostat Generator bester control eviten had changed too het (150* F. )
with one calibrated to correct setpoint.
"D" 11/19 Reactor 1A 94. room Peplaced coil Wone Coil bad on valve fur;1y fan centree-Peplaced coll.
Dutiaing supply fan PSV-31-773 ter maltaaetioned Vest 11/50 RPCI and Isolation Pevise portion Prevented water Both systems isolate on EPCI and PCIC Pertsed part of logie RCIC
!agle of logic treeetton while lose of AC power systems reactor was isolated press atsed 11/lb MPCI
!averter power Placed spike NPCI 31own fuse KPCI tooperable Placed spike surpreecer eupply suppressor inoperable across relay coil.
across relay coil and replace fuse 11/13 NCIC PCY 71-8 Pepaired RCIC Movable contact hung Stena supply valve Pepaired coetador contactor inoperable on arcing hors to POIC woule act crea 11/15 RPCI EPCI teola-pose EPCI reset
!avestigettom revealed MPCI isolated Thorgush loveetige41oa ties etreult and started no cause and tripped continutaa imediately 11/10 480T Bernal feeder Peplaced Some Contacts on 'I' relay Normal feeder ACP Peflaced 'I' relays Aus.
to b80V shut-FI' relay woa't close cleaned and checked entire tromaer Power deva 34. 23 m
9 a 4
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31 F.loctrie=1 Mainsnance."eary (Continued)
August 17. 1973 yebruary 17. 1976 Effect on tafe Nature of operation of Cause of Peculte of Action Taken to
- Det, freten Camronent Maintenance the reactor "elfunetton "alfunetton f reelvie pecurrence 11/11 Primary
- Valve limit Limit evitch None Limit eviten was stuck Creen 11aht does not None Containment
'evitch was freed and causing areen light to go out vnee valve sprayed with stay on.
opeos.
labe.
11/12 Peettual FCV Th 66 Aligned None Screw that holds the Control fuses peplaced screw Meat breaker brenaer in compartment blow 194 on breater.
Pomoval was broken.
11/lb Primary Isolation Replaced Nome Isolatica valve Lees of power Replaced solenoid Inertlag valve solenoid on solenoid burned up.
ead fuses.
valve and fuses 11/16 Reactor Supply and Adjust dampers Some Despere do not open Fressarediff[ren-Adjusted dampere.
Bui141ad exhaust fans as they should.
tial stope 1A and Yeat la from runnias.
11/19 2$0V Undervoltade Replaced aga-None Coil in relay 2TB Alars on panet Peplaced agastet timing Reactor pelay 273 etat timing was opea.
9 8 would not relay.
ICV 34 13 relay reset.
12/9 TPCI Condensate Chanse wire zone Limit switch 2 Lees not evap from Chansed wire fram limit Suetica from limit ev.
broke.a on PCT T3 26 open to closed on evttch 2 to limit evitet valve 2 to limit ev.
torus Ei-level 3
TR #10614 1
12/15 MS Safety Solenoid P.eplacei toil None Periodic ground ir anual operattom Peplaced coil and w
Relier valvw coil manual circuit not poselble meagered circuite.
12/'6 EECW PCY 67-1 Motor replaced Bone Motor bed Actuator would not Motor replaced.
fumetton.
12/17 FCIS PCIS Belay Onaging power None Unreliability of Loos of power to Changed power supply Belare eupply power supply relaye Power Supply 12/20 Diesel Voltage Replare pane Bad regulator tiesel was inope able Peplace voltade regulater comorater Be6ulater voltage res.
12/21 EPCI aish water Circuit some some some some BCIC level trip undifiestion 1/b EPCI FCY 7316 peplaced pia valve fully Gear pin sheared on Motor overloads and Replaced pia en targen la torque closed rendere torque evitch tripe on closure evites and reset targne evitch azd KPCI inoper.
evitca TR 12721 reset torque ente 4
evitch 1/9 M
IAsie Replaced Rose Peley 10AK813 bed Relay would est peplaced reler 10112 system relay
.tae out and 1011b 1/36 WCI Govereer Defective MFCI laoperable EtBI bas wee bed EPC: taoperehle Peplaced bed parte la 3Gd bao EN boa 12$01 8/h care ys T N I.69 correct varies sene virtas errer reces.
FCY 75-37 stalaum Drawinas have been etectes.
Drut errer la en tale done flew brymee vrive for me:urney vita tae teatrol wee inoperable systen eenfiguretten etteelt automattently for low fler m
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e 32 Instrument fdaintenance Ruusary Aurust it.1973 - February 17. !??b Effect on safe nature of Operation of Cause of peoults of Action Taken to Date system Camponent Maintenance the reactor Mal funet t on welfunetton Preclude Henrrence 9/1 Cfr Gas Flow Trans.
Peplace Frratic operatto,a Water la tranesitter Asplifier coc111stinA Sealed conduit sitter Fr 66-20 Amplifier 10/10 IRN Channel "M" Peplace Pequires for Detector shorted Noisy signal. false Radiation levels make detector detector neatron mealtor.
indleation failure analpets ing for RPS tapossible 10/16 TIP Prive motor Peplace Pequired for LPRM Clutch slippage False riot of Bone motor c alibration ne. tron flus 10/17 CAN RM.90-250 Peplace Pequiret for turbine Shorted diode Alare condition None prwer building vest supply opere* 1on 10/20 TIP Channel C Replace Pequired for LPRM Detector er cable Errarf e tiot of Radiation levele make detector detector calibratica shorted neutron flus failure analyste tapossible 10/2?2 CAN All 3 channel lodine Allows accurate None Some None CAW s efficiency determinatica of verification setpotat 1*/30 TIP Channel D Peplace pequired for Detector or cable trratte plot of heatation levela amas detector detector
. PPM calibration shorted neatron flux failure analpets impose 1ble 11/10 control Probee (2)
Replace Pequired for rod Paulty reed evitches 5e position indi.
None Rod 1h.51 probes secuence control cation in certata Drive b6-31 positions 11/lb Im Freemplifier Peplace noisy Pequired for Faulty transister Noter signal.
Some D
preamplifier neutron monitoring false indiention for RP5 11/23 pt5 APftt Peplace card, required for rua Paulty operational Unable to calibrate pone Channel A flow blae mode esplifier erratte operation 12/21 RFIS Probe 09-35 Peplaced Sese Shorted reed evitch so full la indication Rome probe 12/21 Rs. Water b Terwer Peplaced Bees None. Deplaced Rome Bene Level Transmitters transmittore morewy switches LITS-3-52 with eetente lib 3-56A qualifted LIS-3-58A switchee L15-3-18b 12/D APIO1 A Terelaal Lacee teral-pose imoee screes Cutput drift pone strip esl connec.
Channel bypassed tiene O
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4
. t s.
le9treert Maintennnee :Nnmary (Cor.tinued)
Aunost 17,1 #73. Febr amry 17. I'JTb Fffect on safe Nature oferettom of Cause of pecults of Action Takes to Date
- ystes Camronent Maintenance the reactor "alfunetten Mal fume t t on Preelade Petwrrence 1/20 TIP
!adeser 'C' herlaced None Ceneva row was Would not operate Adjusted to prevent ladener bladier la one bindina poettien I
2/1 TS Vest Continuous Failed Unable to asalter Failed treastster Monitor did not None Red.
air soaitor discristnetor 1 131 release respond to 1131 Manitor L
2-10 Lita14 mediation Install tea-Falso ladication Mlah area back.
Unable to adeonately lastalled temporary Freesse element parary ground moattor process lead shieldias-Bad.
shieldled liquid i
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-A-Mech-nical Maintenance Sumesry Auaust 17, 1973 - Debruary 17,17th Effect on Safe Nature of operation of Cause of Pesalte of Action Taten to Dat?
System Component Maintenance the reeter
_ Malfe ction Malfunc t ion Precide pecurrence 8/18 CRD Scram talet Adjusted ralve None Valve leaning through Drive driftina inward Adjusted valve staa valve 1 %h7 sten poettion G/18 CRD Scram inlet Replaced valve None Valve leaking through pod driftina toward Pepaired valve valve 26-23 8/18 CRD Scram tales Replaced valve Mone Valve leaking through Pod drifting inward Peptred va;ve valve h2-07 8/A8 CRD Screa inlet Peplaced valve Rose Valve letaing through 904 driftina lavard Pepaired valve valve 22-59 G/10 CRD Scram talet Peplaced valve None Valve leanina through Pod driftica inward Pepaired valve valve 5k-19 G/50 CRD Scraa talet Replaced valve some Valve leaking through Rod driftlag inward Pepaired valve valve 3%31 C/2A CRD CRD blocs New gasket None Casket leak None Bev spiral gasket vs.1ve 10-47 installed G/27 CRD CRD inlet Adjusted valve sone Velve 1-=eine throur'
- M 4rt*tt e lawstd Adjuot=f valve stem seren valve stem 22-55 8/31 CRD Acco ulator Laded seat None Valve leaking through keing accumulator Laded seat valve 1-85-580 charge 9/19 CRD Module valve Installed new some Valve leakina throuah Drtve drifting invars new valve installed inlet 26-03 valve 9/19 CRD Module outlet Replaced None Valve letains through Drive oprattaa Replaced valve solenoid solenoid hot valve CG 27 valve 9/28 Core 3/4 test Crack welded some Pipe treach line core spray pire Crack around out and Sprer line cracked vibratita leaking (esell) rewe16ed. Pipe support System installed.
9/t Rs. N 0 1-PCV-68-80 Adjusted Nome Power lead broke Valve inoperable Repaired power lead and g
Retire.
valve adjusted limit switch operater 9/2 CRD Seren talet Peplaced seat some valve leaking throuan Drive drifttaa Petru11% valve valve 22-55 and rebuilt inward valve 9/3 mm. a o Valve Adjusted some Sten out worked loose Valve inoperable peseeted stem aut and p
Reetre.
1-FCV-6b79 leeklag out 9/5 CBD Scram tales Peplaced talet Nemo Valve leekins throuah Drive drifting Perlaced eith mee valva 2 M 3 aolenoid unive toward solenoid valve 9/6 CRD Mnemie pepleeed name valve leektaa throuan Drive drifttaa Installed new solenoid seleesta talet soleme14 valve inward valve valve 22-55
ab-Meenanical raintenance Cunmary (Continued)
Aunet 17, 1973 - February 17,13fb Effect os Safe Nature of operation of Cause of pesults of Action Takes to Ete "vetem Couronent Walntenance the resetor _
Malfunetton
% 1runetten trecluJe Heeurrence 9/6 CRD Module Peplaced valve sue Valve leanina throuah N runnina het lasta11ed new valve solenoid outlet 26-03 9/7 CRD Drive module Chansed filter None Filters dirty Drive operated Peplaced filtere 5 27 alowly 9/8 CRD Accumulator Installed an some Leaking "0" rien Water brpassina new "0" ring 46-55 acceulater pistoa 9/10 CRD CRD pump Replaced valve sone Valve seat to stem Valve teamine tnrouan New ko0C# valve lastalled 0-0-85-1 A vent valve dise voa's seal 9/12 CRD CRD Modale Drive module Ecos tarty filtere and Drive wouldn't Changed filters, filter filthy solenoid valve oprate properly installed new solesete valve 9/13 CRD Modale leaning Installed new pone "0" ring 9/12 CRD Outlet Peplaced gone Valve leaatng through Drive oprating hot Deplaced valve solenoid solenoid valve valve 10-a7 9/13 CRD Module Peplaced valve some Valve teamist through pod runnina hot lastalled new valve solenoid out.
1st valve 26-35 9/13 CRD Scram talet Replaced talet Bone Valve leaking through Drtre drifting Replaced with asw valve 14-35 solenoid valve trward solene14 valve 9/2h 0-P-85-1A CRD pop New filter pone Disty filter Biah delta pressure New filter lastalled CRD suction filter lastalled across filter 9/lb CED CRD Module Replaced filter Nome Dirty filter Drive operated Peplaced filter sicuir 9/15 CRD CRD modale Peplaced filter Bone Dirty filter Drive o p rated Replaced filter c2-23 slowly 9/I6 CM CRD module Drive module pcme Dirty filter Drive operated Depinced filter 18-51 filter etcwly L
9/16 CED Outlet Peplaced None Valve leaking through Drive operating hot solenoid 10-51 solenoid valve 9/16 CRD Drin module Changed filter some Dirty filters Drive operated seplaced filtere 30-43 slamly 9/16 CM Module Isotalled new some Valve 1eeming through Drive dri n tag New valve testalled solomoid solenoid en1ve Lavard talet valve 34 43 9/16 MR RRR heat Pluaged tube Bone Puytared tube Lenitas from water Plugged two tebec 1 5-Th-1A enchanger A (from tube side se shall side) 9/19 CM Modele Rep 1 meed valve Bone Valvo leeklag threeph Red ruaalag het lastalled mov valve soleme14 uut.
valve 6 35 10/2 CIS 54-27 serem Peplaced Bene valve stem te sent Dr..e operattaa het installed ase outlet valve valve seat 1eenese valve samt k
e
i l
Meersnical raintenance Susunary (Contin %d)
Auauet 17,1973 - Febru.
17, 197b l
f.ffect on Safe Nature of eteration of Cause of Pe9ults of A tion Takes to Dat*
Cystee Comrenent vairt enanc e tne resetor _
Malfunetton wal tu net t on Praelui. Peearre.
10/2 Diesel C Diesel start. Peplaced head 9one Warped compressor head Blown cylinder head Trued up compressor head Asaket Generator ina air ecm-gasset Aus111ary pressor (DC)
Power 10/3 Diesel 3 diesel AC Perlaced head None Warped emsprestor head Elcwn cylinder head
- rue 2 up contreasor band Generator starting air g as k et
)
Aam111ary campres sor I
Power 10/h CRD CRD module Drive module pone Filters dirty Drive operatina aiew Perlaced module filter No. 26-55 filter replacement i
10/h CRD
%-27 seren Adjusted valve None Valve steen to oest Drive operatina hot Adjusted valve stem outlet valve stem leakage position 13/h LRD
%.27 seran Peplaced valve Mose Valve steen to seat Drive operattag het Penewed seat and inspected valve outlet '.sive seat leakage 10/b CRD 26-07 serem Adjasted valve Rose Valve stem to seat Drive operating het Adjusted valve eten outlet valve stem leakage positico 10/3 EPCI HPCI turbine A replacement Nc,ne Pupture diaghream MPCI system Destan lavestigation laner rupture rupture dia=
failed due to a inoperable to consider replacing vacuum inside the Trerent fisk with one diaphrass pnraps ta=
with a vacuum support
~
stalled turbine discharge String and castes 10/3 CRD 22-03 Peplaced modale None Dirty filters and Drive woulin't move Peplaced filters and filters and.
sluggish valves wits moraal drive scienoid valves directional water pressure valves 10/9 CRD
%-27 seren Peplaced seat None Valve stem to east Drive operettad hot Peplaced seat and outlet valve and gaskets leakage or geeket gas kets b7 Tees 10/9 Core spr y Test bypass Tatriented new None Valve stem keeper Valve stas rots.
Installed facticated Coe11rg valve stem guide key not lastalled tien and hacaing, stes guide and keeper causina operater Pysten esd seeper to limit out 10/10 CRD D-h3 module Replaced pis-None Leaking "0* ring Water typosina Beeeved *0" rings ace m alator ton *0" riage acessulator piston 10/10 CRD C2-31 seren Adjusted valve pose Valve stem to east Drive drifted la Adjusted talet valve inlet valve aten leakage poet CO position stem 10/17 CRD 26-07 module Drive modele Base Filtere dirty Drive voa's move Peplaced filtere filter replace-out of pesttion 00 mosule filtere mest 10/17 CRB 26-51 seren Adjusted valve sene Valve leaking through Drive driftlag Adjusted valve stem 1 sward posittee inlet valve eten 4
.e.
- sf-Mechantest maintsnance %smry (Coe.tinued)
A wust 17, 1973 - Februwy 17 D74 Fffect on :'afe Nature of creration of Casse of Repalts of Aetion Taken to
- Det, g tem omnent W intenance tt.e resetor
'dal funct ion
%1r a tten free 194e vecurrence 10/17 Diese!
A diesel sen-Mjusted pump tone Improperly set gsar Would net r$sp oil Pump adjusted for Generator erator fuel clearance clearance or wear to enaine day tana prorer clearance Aus111ary oil traaefer Power pump 10/26 Diesel J air start Peplaced one Bone Dirty startire motors Fnaine would not Cleanet and replaced Generator motor - left air motori internally come up to start motors; sleaned air Auxiliary bank cleaned and speed supply filtera ta Power 1.bricated motors or.e mater 10/26 NPCI Valve 1 73-3 eesurfaced Mone Blown seal ring Steam cut bonres Machined a new seeltag sealina sur-sealina sur face surf ace on same angle face to same as before malfunetton assle and installed new seal ring 10/28 CRD b6 51 seren Adjusted valve Bone Yalve leak thru Drive drifttaa la Adjustment of stem talet valve stem position 11/1.
EPCI Gland Installed new Bone Blown head gasket Leaking eseessively New gasket tantalled condenaar head gasket and raa a leak test 11/10 CRD 38-15 Instan ed new sone water leaking by High aceu missor penewed "0" ring accusalator "0" ring "0" ring water level 11/16 CRD 1 %11 seren Affus*ed valve "one Valve stem to seat Pod driftina past langthen steen 1/2 inlet valve stem lesange C0 position threads 12/b CRD Discharge Changed None Dirty filter Elan delta pressure Installed a previously Filter filters filter acrees filter cleaned filter 12/7
.!TWCU Vent valve Cract ground None Vitration of voet Weld cracked and Pevelded installed gue.
line out and line due to improper was blowing steen sets and adjusted beagere revelded gussets and hangere 12/12 RER ECV-Th 89 Made new stem some Handwheel cet Valve Laoperable Peplaced stem met out and engaging and key replaced key 12/13 MPCI Steen trap Cleaned trap pone Trash to trop Trap passina steen Cleased and lastalled.
new geomet 12/14 Reactor Dampere Pevorked damper Bone Desper 1setalled Introper operation Peworked damper and Building r3) G 7 backwards of damper retastalled Ventilation FC0 G (G) t 12/lb NPCI RPCI stadtfied oil Rose No malfunction.
No malfanettom governar sucoly Installed to improve lubricattaa E
12/13 nrCI steen supply fastalled new some Bennet o.a1 rima steen leantes at sew eesi rims and valve 73-3 seal ring booset pecklag TF16
'and padding
e
. go.
Mechswat Nir,te ru.s e :'memry (Continued)
Ae.t 17, l'eti. Fel, runty 17, 117L tffeat on Cafe
- atere of sterstion of Cause of Pes 41ts of Action Taken to iv.t e Pvstem ci,mor ent t% 1 r '. e nan aa _
t'a rasetor
% 2funetton
_ Malf.netton l'real d e Pecarrence 12/16 Reactor Lasters on AJjusted to set
'sene Dnepers had slipped Lane of ver.ttistion A4 hsted huiltina exhaust and trorer reactor on shaft Yentilatics sarr.1v fans scae pressare Cysten FCo G.2A G.23 G 11A G-124 12/17 HPCI Test line
'iew nipple
'8ece Nipple broken
!est.tr.e leanina New nipple la valve (alpple)
- eldea la reflated wit's SCN 80 airp14 tr. stead of standard alpple 12/17 CRD Content rod Peplaced Scae 26 07 had a suspected CFD's not operatica Replacea CPO's with new drives 26 07 control rod internal plugged properly spare. Cid CBD's to be and 34 04 drives orifice rebuilt later 3k.04 rod.cestion indleator act work.
inn properly 12/18 Main Eteam Pelief valve ir. stalled 3 ltene Impros,er relief Oldn't neet A:MZ Bow ones properly set (E3 57, 59, G) r.ev valves setpoint setpctst criteria 12/18 RCIC Vent valve on Installed None Seat we'rik out Val'vEleE.ng lastalled new valve it.struner.t r.es valve 11ae 12/19 CRD C1scharge Cleaned
- ane Strainer dirty Nia': ee'.ta pressare Peplaced with spare pre.
strainer (A1) v1ously cleemed strainer 12/19 CRD Scram talet A b sted stem None Scram talet valve leak.
Rod tr1**. rast Adjusted eten valve 18 35 L ; tura tre through between OC rosit.;r.
seat and sten 12/2)
RPR Drais valve Nipple welded None Nipple broken Leutna et treak Cut out and replaced nipple "D" la PJiR pump best te alpp.e nipple and revelded enchanger 12/14 CSSC Shock and Replaced 'O' heae Polvurethane not com.
Hydra 411: fluid leans New ethylene propylene thru sway rinas and seal patible with CE 115s oat of suners
'O' rinse testalled 12/20 arrestore silicone hydraulle sad seals tastalled la fluid all Bergen.Pattersee soubters 12/Ob Dryvell Airlock to perairei cable
'fone Brosen cable due to
!cor ecr.tr:1s had bepaired cable and eser.
drywell ca socr loca introrer use to *e mentrusted Cperattaa toetruettee to : yen Jace is posted om door 1/25 ETC1 Filter (011)
Char. sed filter None Foreien matter la oil Pit'a 2 elta rref oure Installed new filter across filter 2/12 Mata Felief votre Ferlaced with Mene ruotected small 'O' Mene Perlaced valve I
8 team NV.1 10 FY CN ;*7 rir.e (Inrt.*1) inside tiie lectlaws was 1ensine kellef valve HerleeeJ with I**
ree hFAO Tko Tee PTA0 Te.)
- ee 1140 744 IW.1 41 44,
41 1 "A '7 t a 1.eller vnite f.etinced with
'4ane l'hycert st.le delev Mene keplaced valve l i.1.k.
ti.*
reemt.r e l la.e
. y).
Padioactive Liquid Efflueets August 17. 1973 - february 17, 1974 III Units Auaust September
&teter
'lovent er
_ Decenter J anuary Februar/II 1.
Crose Radioactivity (a, y)
Total release (Curles)
. 8.1 E 6 e5.078 b 3 4.008 f03 *5.5h b3 83.350 E-3
'6.05 E-3
- 2.185 E-2 Average concentrattom released ("C1/al) 1,0 g-5
- 1.12 E-6
- T.875 E-7 *1.489 E-6
'7.93 E-7
- 1.385 E-6
- T.21h E-6 (s i/al) 1.0 E-5 5.00 E-6 2.71 E-5 1.78 E-5 8.99 E-6 1.21 E-5 9.k4 E-5 Mazis m concestration released c
3.
Tritium Total release (Curies) e6.0 E k 1.2 E-3 3.0 E-3 2.7 b) 3.4 E-1 3.7 E-1 2.57 E-1 Average ecocentration released (WC1/al) 1.0 E 5 2.55 E-7 7.4 b7 7.h E-T 8.0 E-5 8.kh b5 8.5 E-5 3.
Dissolved noble gases Total release (Curtes)
=6.0 E b 4 5 E-2
=5.1 E-2
<3.7 E-2 ak.22 E-2 ab.37 E-2
- 3.03 E-2 Average concentration released (WC1/al) 1,0 g-$
<1.0 b5 el.0 b5 4.0 E-5 4.0 E-5 4.0 E-5
- 1.0 E-5 6.
Cross Alpha Radioactivity Total release (Curies)
<6.0 E-5 sk.5 b3
<5.1 E-3
<3.7 E-3 4.94 E-T
<8.17 E-9
<h.7 E-5 Averese concentratica (41/al)
.41.0 g 6 4.0 E 6 d.0 E-6
<1.0 E-11 4.6 E-11 4.87 b12
<1.55 E-8 5.
Volume of liquid weete to (1.iters) 5.9 Eh b.531 E6 5.089 E6 3.722 E6 k.223 E6 b.369 E6 3.03 36 discharge canal 6.
Volume of dilution water (Liters) 8.3 F8 2.610 E10 2.739 E10 1.465 E10 1.696 210 2.318 E10 1.77 E10 I
7.
Isotopes released (Curtes)
Ba + la
- 1ho
<1.08 E 6
.337 E-3
<0.022b
<4.824 b3 e5.130 E-3
<5.369 E-3
<4.23 E-3 1
1 11
<3.03 E-5
.2.329 E-3
<0.0212
=0.734 E-3 4.317 E-3 4.937 E-3
.0.97 E-3 Co 58 85.03 E-5 83.869 E-3
<0.0216 4.121 E-3 4.179 E-3 4.359 E-3 d.56 s-3 60
<T.55 E-5
'5.800 E-3
- 0.0223
- 1.911 E-3
- 1.929 E-3
- 2.180 E-3
<2.0b s-3 Co Cr - 51
<2.16 sh 4.663 E-2
<0.0249 6.9k6 b3
<6.708 E-3
<8.251 b3 8.29 E-3 Ce 134
<3.88 E-5 e2.981 b3
<0.0213
<0.810 d-3
<0.837 E-3
<0.952 E-3
<0.89 b3 Cs 137 85.37 E-5
.k.128 b3
<0.0216 4.021 E03 4.065 b3
<1.258 L 3. d.1b 5-3 Sh
.k.k1 E-5
- 3.394 E-3
- 0.0216 d.141 E-3 d.178 E-3 d.359 E-3 d.55 E-3 len sr - 89
<3.72 E-6
<2.86 E-b e5 1 E b
<3.7 b6
<2.2 E b
- 2.32 E b
- 1.75 5-4 Er - 90
< 3.72 E-6
- 2.86 E-k
- 5.1 E b
'3.7 E b
- 2.2 E 4
- 2.32 b6
<1.75 E 4 Ze 133 4.23 E-5
<3.253 b 3
=0.0228
- 1.065 L3
- 1.090 E-3
- 1.313 s 3 1.27 s-3 Ze 135
<2.56 E-5 4.966 E-3
<0.0221
- 0.329 b 3
<0.331 E-3
<0.h85 E-3 0.66 3-3 65
<1.19 E k
- 9.198 E-3
=0.0228
<2.973 E-3 83.052 E-3
'3.517 b 3 e3.38 5-3 Za othere (specifr) yone Bone 18 F
=
- 0.0000h
- 0.061 E-3 0.047 E-3
<0.143 E-3
<0.32 3-3 24 54
<0.0005b
- 1.458 E-3
<0.848 E-3
- 1.565 E-3 e5533 Percent of techattal specificatten (5) 0.06 0.4 0.32 0.40 0.26
.b8 1.76 lists for total activity releneed emeluding tritium. (lased on first technical specification 11mittag value of 1.25 euries/euarter.)
(1) Phr entire anson Et Dyuhel e terresents throeheld limit of analytteal eensitivity.
Thus, reported values are eenservatively hisher them actual yelseeg valueg, i
.e
?-
s.
.ko.
s Padioactive Caseous Effluente Aurust 17. 1773 - February 17. 1974 III III n tobec goveaker D,eeeber January February Sert eet er gtL Aurast e
1.
Total Noble Cases C\\ ries
< 3.3 E*2
< 3.2 E+2
<1.7 E+2
< 5 5 D1
<5.6 E+1 1.4 p2 3.0 > 2 2.
Total Halogens
<2 5 E+3
< 2.h p3 e6.0 L 0
<5.2 E+2
<6.2 E o
<3.5 E O
<3.2 3 0 3.
Total Particulate
< 2.0 E-1
<7.5 E-2
<T.7 E-2
<1.b E-2
< 1.2 b3
<2 3 E-3 1.1 E-3 Cross Radioactivity (8. y) b.
Total Tritium 8.6 E-3 8.3 b3 2.2 E4 8.4 E-3 2.3 E k 8.5 E-3 1.7 3 0 5.
Total Farticulate Cross
< 3.0 E 4
< 2.9 Ed
< 3.0 E4
< 2.9 E4
< 3.1 34
< 2.8 bb
<2 5 E4 Alptia Radioactivity 6.
Maximus Ecble Cas pC1/see 3.9 p2 3.3 E+2 3.k E+2 9.0 1+1 5.5 E+1 7.0 E+2 2.8 p 2 Pelease Rate 7.
Percentage of applicable limit for:
a) Boble Casee
<2.5 E-1 2 5 E-1 1.3 E-1 6.2 E-2 b.2 b2 1.0 E-1 2.5 E-1 b) Ealogene
<3.8 E O 3.8 E G
- 19E0
<b.9 E-1
< 4.8 b2
<1.2 E-1
<2.5 5-2 e) Particulatee
<1.8 E+1
<T.2 E o
<T.2 E 0 el.h E O
<1.1 E-1
<2.2 E-1
<1.1 3-1 8.
lootopes released Particulates Be Ibo Curies 47.0 E-2
.6.8 E-2
<T.0 E-2
< 1.2 E-2
< b.0 34
<8.5 E b
<3.7 5.h Cs - 13b
<3 0 E-3 e 2.9 b3
<3.0 E-3
<1 5 E-3
< h.5 EA 44.5 E k
<5.6 5-4 Cs - 137
<h.3 E-3
<h.2 E-3 s k.3 E-3
<1.2 E-3
< 3 3 bh
<9.9 E4
<1.b 5 b Sr - 89 3.2 E-5 1.b b5 1.5 E-5 1.5 E-5 1.5 E-5 1.4 E-5 1.3 5-5 Sr - 90 h.b E-7 b.3 E-T b.h E-7 b.5 E-7 b.6 E-7 b.2 E-7 3.8 5-7 Balogene I - 131
<b.1 E-2
<h.0 E-2
<2.1 E-2
<$.2 E-3
< 5.1 EA
<1.2 E-3
<2.b 5 4 I - 133
< 2.8 b3
<2.7 E-3
<2.8 E-3
<3.8 E-3
<3.0 1,3
<1.1 E-3
<1.0 5-3 1 - 135
< 2.5 b3
< 2.b 93
<5.9 E o
- 5.2 p2
<6.2 E o
<3.5 E O
<3.2 3 0 cases Ar bl
<4.5 E O
<b.5 E O
<3.h E o
<8.2 E-1
<9.0 E-2
<t.D E 0
<1.7 p1 Er - 85
< 2.8 D2
< 2.8 E+2
<1.7 E+2
<5.1 E+1
<5.2 1+1
<9.2 pl
<1.1 h3 Er - 85m
<6.4 r 1
<6.h E-1 e6.0 E-2
<1.2 bl
<1.1 E-1
<5.0 E-1
<1.5 E O Er - 87
<2.2 E O
<2.2 E O
<3 1 E-1
<b.1 E-1
<b.0 E-1 47.9 E 0
<1.6 >1 Er - 88
.{.
<1.7 E O
<1.7 3 0
<1.7 E O
< 3.3 E-1
<3.b E-1
- 1.8 E 0 d.5 E-1 Ze - 133
<1.2 E o
< 1.2 3 0
<9.0 E-2
<1.5 E-1
<1.7 E-1 d.2 E-1
<1.2 3 0 Ie - 135
<8.7 8-1
<8.7 E-1
<9.0 E-2
- 2.2 E-1
<2.3 E-1
<5.6 E-1
<2.4 3 e i
Io - 135m
<5.8 E-1
< 5.8 bl
<1.7 E-1
<1.6 E-1
<1.T E-1
<2 5 E-1 d.5 5-1 j
.s Io - 134
<2 5 >1
<2.5 5+1
<1.7 bl
<1.6 E o
<2.5 E O
<2.9 p1
<4.8 >1 i
/
. g,.
n l 1.-
T U
3 j
4A a.
.n r
f
[h
.. e
~
J,.
g 1
(1) For entire aesth r~
M SyeM' - espresents threehalt limit of eaalysten1 censitivitF. 718'8 e 4 _,..,
ret a
,Aaaes are cosearvatively hister than actual release valune.
t.
t
-g.
4 s
.4,,>
.,,,p 3
1 y.-
I x
e kt-e Colic Nadioactive WesteIII August 17. 1974 - February 17, 197h Scent pesin - 1sw level t'n tt e Auruet N Dtember Ntober
__gwest er Decenter January Petruary Total volme shipped ca. ft.
0 0
625 1$15 306 1362 0
Cross activity curies 3
0 1.25 E-1 2.5 T.1 4.2 E-1 6.kS9 E.1 0
4 Dates shipped 10/10 11/1 12/11 1/4 10/23 11/3 12/1h 1/6 1
10/29 11/9 1/10 10/31 11/11 1/17 11/13 1/21 1
11/15 1/23 11/19 1/25 11/20 1/29 f
11/23 11/27 Scent poeta - tish tevel i
Total volue shipped cu. ft.
0 0
160 0
151 176 0
Cross activity curtee 0
0 8 E-1 0
6.7 1.5 0
Dates shipped 10/23 12/b 1/9 (2) g,,,gg,
~-
'hstal volse 55 sal. dr me 0
0 n
a 0
80 0
l Oroes activity curies 0
0 0
0 0
b.9 5-1 0
I Date shippet 1/lb l
I
)
?
h 1
i (1) All veste oblemed to geraye11. S. C.
j (2) Campested paper, rego, etc.
1 l
I s
i
=
i h
gn i
7 7
-,----nm
,-m-
-.,e
,,--,.,,e,--.q-,
p
-,y-,,e w -, -,.p,n-g y,
e r-_-.y y
s e
.42-i
/
4 z
-f
/ -
Plar.t %41f tentions A vust 17, 1973 - February 17, 1974 Modifiention Usfety Fvelvatton 11Tk - Setpoint chanses to the following:
he setpoint of these instrwsents was char:ael in tne safe direction to allow for PS-2-13% A-D TS-2-121 A-D instrument tolerance. The setpointo were etavel to assure snat t%e inaccuracies dP15-2-136A,B
-122 A-D of the instrament would no: emase a tr1F 1* vel settir.a to te euested.
-137 A, B 123 A-D 130 A B.
-124 A-D
-139 A, B TS-13-7 ) A-D
-P3 A-D PS-13 83, Sr. #1
-B1 h-D PS-13-83, Sw. 72
-32 A-D PS-13-84, Sr. El TS-23-101 A-D PS-13-86, So. #2
-102 A-D s
-103 A-D PS-2-3-102 A-D
-104 A-D
.r e
LS-2-3-72 A, B, Sv.1 & 2 M -bSTA 2_
he setpoint of these instru=ents was ensated ir. the sa*e direction for various
-% A, e reasons. In eact. of taese cases, tue o*entir.a rac.ee cf the Maat la LS-2-3-79 A, B, Sv.1 to 2 G 2-3-72 A, B, Sw. 3 & k 13-r-3-83 A. B -
reduced and tripe ow.r c'.eser to tse narre? operettaa point.
1S-2-3-79 A, B. Sw. 3 & b P5 '$1L A-D LS-2-3-101 A-D, Sw. 3 & b P! 4-17 A-U 13-23-90 A, B TS-11 kB ne setpointa of these instruments were chasses in t'.e OEK inta sheet to allow for
-91 A, B
'*S-12-11.*['
instrum:ent tolerancea Q. LS-23-90A, B, and T.
A. B. are se ety related1 the T5-12-89 A, B
.TS-12 61 A, 8 setpoints are within the teebsneal speelfsfit;-n limits after the additi a of the E2 a..B tolerances. TS-11 k8 controls the s*ande.' m e-trol s4ution and the change mesures that a stalmas temperature is so!atained. W e other instruments are est d rectly safety related.
/
i PS-2-116 A-D, -117 A-D, -115 A-D, l Calculation indleases that 106 pet correspor.is to 1601 rated steam ficar based to and -119 A-D - Main Steen Line Nigh Plow r.
Permutit Company calibration cerve. *41s enasse. mas to convert the setpoint from flow to preneure.
e oo l
-.o 6d.
,*f.
ti
..7.--.-
e e
h)-
Plant Modificatione (Continued)
August 17. 1773 - February 17. 197h Mod ifientica Safety haluation L100k - Continued PO-2-3-51 A-D - Beactor Pressure The setpoint was changed as a result of a technical specificattom revistos made prior to issuance of the operatina license.
PdIS-23-76 and EPCI Steen Line High Flow
%e setpoint was changed to correspon.1 to 2251 steam flow.
LS-2-3-101 A-D. Sw.1 Reactor Iov Water The setpoint was caansed to refleet tne correct instrument tolerance. It was
[
ehanged in an unsafe direction but still remained above the techateal spect-fication requirement.
L1062 - EECW System A enarging line from the raw coolina water (PCW) system and a vacuum priming line will be added to the EECW eystes to prevent air voids. vtich will alalaise water basener during startup of an EECW ruso. The charaina line has a chech valve to prevent EEC"d flow from going into the PCW eystes. The vacuum line has a vacuum ealee which allows only air to pas. Failure of the vaem:n plair.g systez
)
will be detected by LS-67-52; an EECW pump will be used to maintain a charged system i
until the vacuum prising systes is restored.
R. Added as altrasonic flow instrument and The new flow systens do not degrade the existina instrumentation or system.. It j
2b Wa in,eettoa system to the condensate to used to obtaia more accurate flow measuremente.
and feedveter systems.
I I
l L1119 - Separatin of hidh and low annuneistors The separation of the two alarus provides the operator with more information for in the eostrol room for the seren valve pilot
' prompt deeletos making. Safety of the plant was not reduced.
air header air p eesure.
L1120 - Provided a lower point for removing the he RSCS to enabled below 305 rewtor power. Prior to the modifiestion it was renseed RSC3 fras service.
from service at about 375, whlen caused operational problems. The endification removes the system at 325 and does not dearade the esteting irttrmtaties. The F
mov pressure evitehoe and associated etreuttry is compettble quality with the e;
esteting pressure evitehoe and circuitry.
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Plant Modificatione (Continuet)
A m at 17. 1773 = February 17. 197b Safety tvat us= len
$4041ftention L11V. Changed alarm of relief valve from 200' F.
Osta from startup teettna indleated that sne relief valve normal temperature was to 250' F.
higher than espected. ne increase in alsrs value aces not affect the esfety function of the valves or degrade ability to detect stema leanape.
he evitch disables the automatic bypass of the scram facticr.s. turbine stop and Iowered setpoint of turbine first-stade pressure evitch to correspond to 3c5 control valves closure above the setpoint. Tne turnice etcp ar.d control valves fumetion la the PPS le not required telw byrass ca;acity (255 thermal power)s reactor power.
therefore. Iowerir.a the setpoint would recove the tatocatie tyraes at a 1 carer reactor power and within the steam bypass car,acity. No degradattom of safety would result.
214/87000 Replacement of nuts on the head
- wenty.four outs on the head cooling spray acatle were replaced with nute that meet cooling spray nossle.
quality assurrance requirements.
21}/67000 Modified fuel support grapple to 3e fuel support grapple was reworked in accordance with General Electrie Didineering
_ remove the fuel supports that are in the Chanae Notices NE.376k0 and NE.376k2. Se acdification did sct affect the safe prosimity of the source holder.
serviceability of the grattle.
226/87000 Modified local area underwater local area undeWater lights were ebanAed te ensure that the lens would not come lights.
loose and fall into the reactor.
236/87000 - Changed calibratica of ne feedwater flow not:1e was modified to improve the accuracy of the flow measuremmets.
feedwater flow mosale.
No safety system er component degradation resulted.
2kT/BT000 - Replaced solenoide on MCIV The solenoids were replaced to be ecopatible with the plant DC voltage system. We manifolds with correct voltage rating degradation of a safety system or component resulted.
solenoide.
?$3/87000 = Special tastrumentation on the Accelerametere and LVIff'e were installed external to the valves for measuring opealag relief valves for startup teettas.
and eloeing times. De instrumentation does not interfer with the operetten of the relief valves.
g. Setente brealms the reacter level The breetag was added tethe eelume to prevent a poselble treach of the lastreest
,lastrummet reference solumn.
line during a setente disturtence.
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6 9
.bS-3 P1 ant Modifteations (Coatinued)
August 17. 1773 - February 17, 1974 Modifteetions fafety Fvaluation M - bdified the Ml!V logie The modification provided additional testability of tie loalc. whleh permits a more ecaplete fumetional test and does not interfer with tne oprattom of the existing logie.
M - The fuel pool cooling and cleanup system was The chanae trovides aJditional safety to plant cierstless ty enssing cooling of the revamped to isolate the fuel pool (skimains fuel pool should a line to the deafneraliser break.
surge tasas) and heat erthanger from the desteeraliser and provide close-eyele cooltag through the heat exchangers in the event of a line treak from the heat exchanger to the domineraliser.
E - Aided shielding heads to transistors la the The beads were added to existing translators to reduce noise in the system end neutros monitorias system laverters.
does no: interfor with the operstlos of the components.
g - Added 155 seres to APIN The IST scram was added to each APfW channel as a backup to the 1104 to ensure trip capability in the event that a refuetion in fewer occurs with the !???
detector fully withdrawn. The etreuitry consisted of quality componente F
compatible with the existing etreuitry.
E b 14odified containment ap er isolation valve limit switches were added to the contalement spray isolatica valve logie to en1ves avoid the possibility of manually bypassing the ecstainment epray laterlock vbes as automatie lattistica is not presost.
I g - level switch lastalled in the off.das A level evitch vae addet to provide a more reliable and independent operation of the goedensate collector pep la the radweste Previous design used contacts from another level evitek.
sump.
.reten.
at - set-it ww1.s testalles os pm.1 The nr in, ou added to the panel to preve.t the.alfmica of instr o.tesse.
p-1s tunted on the panel sa the eveet of a sete ie disturs ee.
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t 46 Plant Modifteatione (Continue 1)
Auruet 17, 1973 - February 17, 197h Modifteetion refety Fvaluation TPCU - Modified primary conta1 ament isolation Main steam isolation valve isolation signais were re eyed from the reactor water loste.
sample valves and reactor low water level and esta stens line hiah radiattom signals were chanted to teclate the santle valves directly. *his change was made to provide testadtlity of each sample teolattoa valve.
E - Added shielding beads to transistors The beads were added to existing transistors to reduce noise la the system in the amplifier and attenuator of the and does not interfer with the operation of the cosponente.
wide reage maaltor.
!!'-67' "he signal modiff er was replaced ne generator is used for contro11e4 openine of the governor valves te prevent witt a ramp senerator on the RPCI &
instantaneous opening of these valves and subsequently causing a turbine trip 30:0 systems.
dae to overspeed. P.10 modification will be checked during the startup test program to verify its desten funetton. The possibility of a spurious trip is reduced whien will provide a more reliable system.
IlM11 - Addition of pressure evitches to the An additional three pressure switches were added to monitor cressure between the inner RCIC and EPCI steam line rupture dise and outer rupture discs and connected in a 1-out-of 2-taken-twice logie. he original evitch vse used to monitor the rutture of the inner rupture dies. The modification will ensure that a st%rious signal does not trip the turbine and still retain personnel protection if a legittaate signal occurs. H e operetten of the eyeten te not affected by the modifiention.
I;t-905 - Battery board room, mechanical The air flow rates were chanmed on dravisse.
equipseat rome, and toiles rom eahaust th906 - Reactor building ama turblee building The despers do act have a safety fumetica.
ventilattoa systen discharge damper operators were thaaged from electrie to poematie.
!Js.909 - Reeval of a control damper 64-39 and h e despere do not have a safety fumettes.
damper eestrel loop from the reactor buildlag Teat 11 sties apeten.
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