ML20116M179
| ML20116M179 | |
| Person / Time | |
|---|---|
| Site: | Peach Bottom  |
| Issue date: | 10/19/1992 |
| From: | PECO ENERGY CO., (FORMERLY PHILADELPHIA ELECTRIC |
| To: | |
| Shared Package | |
| ML20116M173 | List: |
| References | |
| NUDOCS 9211200099 | |
| Download: ML20116M179 (19) | |
Text
.
ATTACHMENT 2 PEACH BOTTOM ATOMIC POWER STATION UNITS 2 AND 3 Docket Nos. 50-277 50-278 License Nos. DPR-44 DPR-56 TECHNICAL SPECIFICATION CHANGES List of Attached Pages Unit 2 Unit 3 8
8 44 44 81a 81a-06a 86a-157 157 170 170 193 193 211 211 240v 240v 92112dOO99 921019 PDR ADOCK 05000277 P
Unit 2 PBAPS 1.0 DEFINITIONS (Cont'd)
Simulated Automatic Actuation - Simulated automatic actuation means applying a simulated signal to the sensor to actuate the circuit in question.
Site Boundary - That line beyond which the land is not owned, leased c.r otherwise controlled by licensee.
Source Check - A source check shall be the qualitative assessment of channel response when the channel sensor is exposed to a radioactive source.
Startup/ Hot Standby Mode - In this n. ode the reactor protection scram trips, initiated by condenser low vacuum and main steam line isolation valve closura are bypassed, the reactor protection system is energized with IRH neutron monitoring system trip, the APRM
.15% high flux trip, and control rod withdrawal interlocks in service. This is often referred to as just Startup Mode. This is intended to imply the Startup/ Hot Standby position of thc mode switch.
Surveillance Frequency - Periodic surveillance tests, checks, calibrations, and e
examinations shall be performed within the specified surveillance intervals. Specified periodic surveillance intervals are defined as:
(K) Hours Atleastonceper(N) hours
$niftly At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Daily At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> (H) Days Atleastonceper(H) days Twice Per Week At least once per 4 dcys Weekly At least once per 7 days (N) Weeks Atleastonceper(7xH) days Semi monthly At least once per 15 days Monthly At least once per.31 days 2 Honth At least once per 61 days Quarterly or 3 month At least once per 92 days Semi-annually or 6 month At least once per 184 days Annually or 12 month At least once per 366 days i
Once Per Cycle At least once per 732 days 18 month At least once per 550 days 1
Refuel At least once per 732 days (H) Years At least once per (366xN) days (H) Refuel Cycle At least once per (732xN) days 24 Honths At least once per 732 days These specified time intervals may be exceeded by 25%. Surveillance tests are not required on systems or parts cf the systems that are not required to be operable or are tripped.
If tests are missed on parts not required to be-operable or are tripped, then they shall be performed prior to returning the system to an operable status.
A surveillance test of the diesel generators, that requires a plant outage, may be deferred beyond the calculated due date until the next refueling outage, provided the equipment has been similarly tested and meets the surveillance requirement for the other unit.
Transition Boiling - Transition boiling means the boiling regime between nucleate and film boiling.
Transition boiling is the regime in which both nucleate and film boiling occur intermittently with neither type being completely stable.
Trip System - A trip system means an arrangement of instrument channel trip signals and auxiliary equipment required to initiate Unii2 TABLE 4.1.2 REACTOR PROTECTION SYSTEM (SCRAM) INSTRUMENT CALIBRATION MINIMUM CALIBRATION FREQUENCIES FOR REACTOR PROTECTION INSTRUMENT CHANNELS Instrument Channel Group (1)
Calibration (4)
Minimum Frequency (2)
IRM High Flux C
Comparison to APRM on Maximum frequency once Controlled Shutdown per week.
APRM High Flux Output Signal.
B1 Heat Balance Twice per week.
I Flow Bias Signal B1 With Standard Pressure Every eighteen months.
Source g
LPRM Signal B1 TIP System Traverse Every 6 weeks.
High Reactor Pressure 82 Standard Pressure Source Once ptc oper. ting cycle.
High Drywell Pressure B2 Standard Pressure Source Once per operatoing-cycle.
Reactor Low Water Level B2 Pressure Standard Once per operating cycle.
High Water Level in scram A
Water Column Every refueling outage.
Discharge Instrument Volume Turbine Condenser Low Vacuum B2 Standard Vacuum Source Once per operating cycle.
Main Steam Line Isolation-A Note (5)
Note (5)
Valve Closure Main Steam Line High Radiation Bl.
Standard Current Source (3)
Every 3 months.
Turbine-First' State Pressure A
Standard Pressure Source Every 6 months.
Permissive
Unit 2 TABLE 4.2.B (CONTINUED)
MINIMUM TEST AND CAllBRATION FREQUENCY FOR CSCS
' Instrument Channel Instrument Functional Test Calibration Frequency Instrument Check
Once/3 months None Steam Line Low Pressure
- 14) HPCI-Suction Source (1)
Once/3 months None Levels
$t 16). ADS Relief Valves Once/ operating cycle Once/ operating cycle None
?
Bellows Pressure Switches
- 17) LPCI/ Cross Connect
'Once/ refueling cycle N/A N/A Valve Position
- 18) Condensate Storage
'Once/3 months Once/ operating cycle Once/ day Tank Level (RCIC) (7) l 19)'4KV Emergency Power Once/ month.
Once/ eighteen months None Source Degraded.
Voltage Relays _
(IAV.CV-6,ITE)
o Unit 2 H
TABLE 4.2.F MINIMUM TEST AND CALIBRATION FREQUENCY FOR SURVEILLANCE INSTRUMENTATION Instrument Channel Calibration Frequency Instrument Check
- 18) Drywell High' Range Radiation Monitors Once/ operating cycle **
Once/ month l 19,. Main Stack High Range Once/ eighteen months Once/ month Radiation Monitor I 20) Reactor Bldg. Roof. Vent Once/ eighteen months Once/ month i
High Range Radiation Monitor 1
- 21) Drywell Hydrogen Concentration Quarterly ***
Once/ month.
Analyzer and Monitor k
7 Perform instrument functional check once per operating cycle.
Channel calibration.shall consist of an electronic calibration of the channel, not including the detector, for range decades above 10R/hr and a one point calibration check of the detector below 10R/hr with an installed or portable gamma source.
At least a two-point calibration using sample gas.
i n.
j
..i i
Unit 2 PBAPS 3.6.D & 4.6.D BASES Safety and Relief Valves The safety / relief and safety valves are required to be operable-above the pressure (122 psig) at which the core spray system is not designed to deliver full flow.
The pressure relief system for each unit at the Peach Bottom APS has been sized to meet two design bases.
First, the total capacity of the safety / relief and the safety valves has been established to meet the overpressure protection criteria of the ASME code.
Second, the distribution of this required capacity between safety / relief valves and safety valves has been set to meet design basis 4.4.4.1 of subsection 4.4 of the FSAR which states that the nuclear system safety / relief valves shall prevent opening of the safety valves during normal plant isolations and lead rejections.
The details of the analysis which show compliance with the ASME code requirements is presented in subsection 4.4 of the FSAR and the Reactor Vessel Overpressure Protection Summary Technical Report presented in Appendix K of the FSAR.
Eleven safety / relief valves and two cafety valves have been installed on Peach Bottom Unit 3 with a total capacity of 79.51% of rated steam flow. The analysis of the worst overpressure transient demonstrates margin to the code allowable overpressure limit'of 1375 psig.
To meet the power generation design basis, the total pressure rollef system capacity of 79.51% has been divided into 65.96%-
safety / relief (11 valves) and 13.55% safety (2 valves).
The analysis of the plant isolation transient shows that the 11 safety / relief valves limit pressure at the safety valves below the setting of the safety valves.
Therefore, the safety vajves will not open.
Experience in safety / relief and safety valve operation shows that l a testing of 50 per cent of the valves per cycle is adequate to detect failure or deteriorations.
The safety / relief and safety valves are benchtested every second.
- 157 -
, Unit 2 PBAPS LlHITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.7.APrimaryContainment(Cont'd.)
4.7.APrimaryContainment(Cont'd.)
3.
Pressure Suppression Chamber-
- h. Drywell Surfaces Reactor Building Vacuum Breakers
~
The interior surfaces of the drywell and torus shall be visually-a.
Except as specified in 3.7.A.3.b inspected each operating cycle below, two pressure suppression for evidence of deterioration.
In chamber-reactor building vacuum addition, the external surfaces of breakers shall be operable at the torus below the water level all times when primary contain-shall be inspected on a routine ment integrity is required, basis for evidence of torus The setpoint of the differential corrosion or-leakage, pressure instrumentation which actuates the pressure suppression
- 3. Pressure Suppression Chamber-chamber-resctor building vacuum Reactor Building Vacuum Breakers brcakers shall be 0.5 + 0.25 psid.
a.
The pressure suppression chamber-b.
From and after the date that one reactor building vacuum breakers of the pressure suppression chamber-shall be checked for proper operation-reactor building vacuum breakers every refueling outage. Associated is made or found to be inoperable instrumentation including setpoint for any reason, reactor operation shall be checked for proper is permissible only during the operation every eighteen months.
succeeding seven days unless such vacuum breaker is sooner made opera-
- 4. Drywell-Pressure Suppression ble provided that the repair proce-Chamber Vacuum Breakers dure does not violate primary
- 5. Each drywell-suppression chamber containment integrity, vaccuum breaker shall be exercised through an opening-4.
Drywell-Pressure Suupression closing cycle once a month.
Chamber Vacuum Breakers
- b. When it is determined that a.
When primary containment is a vacuum breaker is inoperable required, all drywell-suppression for opening at a time chamber vacuum breakers shall when operability-is required, be operable and positioned all other operable vacuum-breakers in the fully closed position shall be exercised immediately-(except during testing) except and every 15 days thereafter as specified in 3.7.A.4.b and until the inoperable c below.
vacuum breaker has been returned to normal service, b.
Drywell-suppression chamber vacuum breaker (s) may be
- c. Once per operating cycle "not fully seated" as each vacuum breaker shall shown by position indication be visually inspected if testing confirms that the bypass area is less than or equivalent to a one-inch diameter hole. Testing shall be initiated withing 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> of initial detection of a "not fully seated" position
-170-
=.
Unit 2 PBAPS 3.7.A & 4.7 A BASES (Cont'd.)
The design basis loss-of-coolant accident was evaluated at the primary containment maximum allowable accident leak rate of 0.St/ day at 56 psig.
Calculations made by the AEC staff with leak rate and a standby gas treatment system filter efficiency of 90%
for r:dogens and assuming the fisrlon product release fractions state ' an TID 14844, show that the maximum total whole body passing cloud dose is about 1.0 REM and the maximum total thyroid dose is about 14 REM at 4500 meters from the stack over an exposure duration of two hours.
The resultant doses that would occur for the duration of the accident at the low population zone distance of -
7300 meters are about 2.5 REM total whole body and 105 REM total thyroid.
Thus, the doses reported are the maximum that would be expected in the unlikely event of a design basis loss-of-coolant accident.
These doses are also based on the assumption of no holdup in the secondary containment resulting in a direct release of fission products from the primary containment through the filters and stack to the environs.
Therefore, the specified primary containment leak rate and filter efficiency are conservative and provide margin between expected of f-site doses and 10 CFR 100 guidelines.
The water in the suppression chamber is used only for cooling in the event of an accident; i.e.,
it is not used for normal operation; therefore, a daily check of the temperature and volume is adequate to assure that cdequate heat removal capability is present.
Drywell Interior The interiors of the drywell and suppression chamber are painted to prevent rusting.
The inspectica of the paint during each major refueling outage, assures the aint is intact.
Experience with r
this type of paint at fossil fueled generating stations indicates that the inspection interval is adequate.
Post LOCA Atmosphere Dilution In order to ensure that the containment atmosphere remains inerted, i.e.
the-oxygen-hydrogen mixture below the flammable limit, the capability to inject nitrogen into the containment af ter a LOCA is provided.
During the first year of c7: ration the normal inerting nitrogen makeup system will be available for this purpose.
After that time the specifically designed CAD system will serve as the post-LOCA Containment Atmosphere Dilution System.
By maintaining a minimum of 2000 gallons of 11guld N, in the storage tank it is assured that a seven-day supply of N tor post-LOCA containment 2
inerting is available.
Since the inerting makeup system is continually functioning, no
- 193 -
Unit 2 pggp3 LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS and one main staa shall also demonstrate that noble gas monitor control room alarm an-shall be operable and set nunciation occurs if any of to' alarm in accordance the following conditions exist:
with the methodology 1.
Instrument indicates and parameters in the measured levels ODCH From and after the above the alarm date that both reactor setpoint.
building exhaust vent 2.
Instrument indicates monitors or both main a downscale failure, stack noble gas monitors Additionally, an instrument are made or found to be check shall be performed inoperable for any reason, every day.
effluent releases via 4b.
The reactor building their respective pathway exhaust vent--and the-may continue provided at main stack-flow rate least two independent monitors shall be grab samples are taken calibrated every 12 at least once per 8 hrs, months. Additionally, an and these samples are instrument check shall analyzed for gross be performed every day, activity within 24 4c.
The reactor,kuilding hours, and at least two exhaust vent and the main-technically qualified stack iodine and particulate members of the facility sample flow rate monitors staff independently shall be calibrated every verify the release 12 months. Additionally, rate calculations, an instrument check shall c.
One reactor building be performed every day-exhaust vent iodine-for the reactor building filter and one main exhaust vent sample flow stack iodine filter rate monitors, and every and one reactor build-week for the main stack ing exhaust vent sample flow rate monitor.
particulate filter 4d.
The main stack sample and one main stack flow line Hi/Lo pressure particulate filter with switches shall be their respective flow functionally tested every rate monitors shall be 6 months and calibrated operable. From and after every 24 months.
the date that all lodine filters or all particulate filters for either the reactor building exhaust vent monitor or the main stack monitor are made or found to be inoperable for any reason, effluent releases via their respective pathway may l
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Ur.it 2 Table 4.15
SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REOUIREMENTS Instrument
- Instrument
- Functional Instrument check Test Callitrction Instruments and Sensor Locations 1 1.
Triaxal Time-History Accelercgraphs a.
Containment Foundation (torus compartment)
M SA R
b.
Refueling Floor M
SA R
c.
RCIC Pump (Rm #7)
M SA R
d.
"C" Diesel Generator M
SA R
2.
Triaxal Peak Accelerographs a.
Reactor Piping (Drywell)
NA NA R
b.
Refueling Floor NA
!!A R
c.
"C" Diesel Generator NA NA R
3.
Triaxal Response-Spectrum Recorders a.
Cable Spreading Rm M
SA R
Surveillance Frecuencies M:
every month SA:
every 6 months i
l R:
every 24 months Effective upon completion of installation.
Seismic instrumentation located in Unit 2.
-240v-S
1 Unit 3 PBAPS 1.0 DEFINITIONS (Cont'd)
Simulated Automatic Actuation - Simulated automatic actuation means applying a simulated signal to the sensor to actuate the circuit in question.
Site Boundary - That line beyond which the land is not owned, leased or otherwise controlled by licensee.
Source Check - A source check shall be the qualitative assessment of channel response when the channel sensor is exposed to a radioactive source.
Startup/Ilot Standby Mode - In this mode the reactor protection scram trips, initiated by condenser low vacuum and main steam line isolation valve closure are bypassed, the reactor protection system is energized with IRH neutron monitoring system trip, the APRM 15% high flux trip, and control rod withdrawal interlocks in service. This is often referred to as just Startup Mode. This is intended to imply the Startup/ Hot Standby position of the mode switch.
Surveillance frequency - Periodic surveillance tests, checks, calibrations, and examinations shall be performed within the specified surveillance intervals. Specified periodic surveillance intervals are defined as:
(H) Hours Atleastunchper(H) hours Shiftly At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Daily At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> (H) Days Atleastonceper(N) days Twice Per Week At least once per 4 days Weekly At least once per 7 days (H) Weeks Atleastonceper(7xN) days Semi monthly At least once per 15 days Honthly At least once per 3. days 2 Honth At least once per 61 days Quarterly or 3 month At leart once per 92 days Semi-annually or 6 month At least once per 184 days Annually or 12 month At least once per 366 days l
Once Per Cycle At least once per 732 days 18 month At least once per 550 days l
Refuel At least once per 732 days (H) Years Atleastonceper(366xH) days (H) Refuel Cycle Atleastonceper(732xH) days 24 Honths At least once per 732 days These specified time intervals may be exceeded by 25%. Surveillance tests are not required on systems or parts of the systems that are not required to be operable or are-tripped.
If tests are missed on parts not required to be operable or are tripped, then they shall be performed prior to returning the system to an operable status.
A surveillance test of the diesel generators, that requires a plant outage, may be deferred beyond the calculated due date until the next refueling outage, provided the equipment has been similarly tested and meets the surveillance requirement for the other unit.
Transition Boiling - Transition boiling means the boiling regime between nucleate and film boiling.
Transition boiling is the regime in which both nucleate and film boiling occur intermittently with neither type being completely stable.
Trip System - A trip system means an arrangement of instrument channel trip signals and auxiliary equfpment required to initiate Unit 3 TABLE 4.1.2 REACTOR PROTECTION SYSTEM (SCRAM) INSTRUMENT CALIBRATION MINIMUM CALIBRATION FREQUENCIES FOR REACTOR PROTECTION. INSTRUMENT CHANNELS Instrument Channel Group (1)
' libration (4)
Minimum Frequency (2)
'IRM High Flux C
Comparison to APRM on Maximum frequency once Controlled Shutdown per week.
APRM High Flux Dutput Signal 81 Heat Balance Twice per week.
l Flow: Bias Signal B1 With Standard Pressure Every eighteen months.
Source LPRM Signal BI TIP System Traverse Every 6 weeks.
- 1
?
High Reactor Pressure B2 Standard Pressure Source Once per operating cycle.
High Drywell Pressure B2 Standard Pressure Source.
Once per operatoing cycle.
Reactor Low Water Level 82 Pressure Standard Once per. operating cycle.
.o High Water Level.in Scram.
A Water Column-Every refueling outage.
Discharge Instrumei.. Volume-Turbine Condenser Low Vacuum B2 Standard Vacuum Source Once per operating cycle.
Main Steam Line Isolation A
Note (5)
Note (5)
Valve. Closure Main Steam Line High Radiation B1 Standard Curri7t SoJrce (3)
Every 3 months.
Turbine First State 1 Pressure.
A Standard Pressure Source Every 6 months.
Permissive
-6; i-
. Unit 3 TABLE 4.2.B (CONTINUED)
MINIMUM TEST AND CALIBRATION FREQUENCY FOR CSCS Instrument Channel Instrument Functional Test Calibration Frequency Instrument Check'
Once/3 months None Steam Line Low Pressure
- 14) HPCI Suction Source (1)
Once/3 months None Levels 15).4KV: Emergency Power Once/ operating cycle Once/5 years None System. Voltage Relays (HGA,SV)
- 16) ADS. Relief Valves Once/ operating cycle
'Once/ operating cycle None y
Bellows Pressure i
Switches
- 17) LPCI/ Cross Connect
.0nce/ refueling cycle N/A N/A Valve Position
- 18) Condensate Storage Once/3 months.
Once/ operating cycle Once/ day Tank Level (RCIC) (7) l
- 19) 4KV. Emergency Power Once/ month Once/ eighteen months
.None Source Degraded Voltage Relays (IAV CV-6,ITE)
'5
UnitL3 TABLE 4.2.F MINIMUM TEST AND CALIBRATION FREQUENCY FOR SURVEILLANCE INSTRUMENTATION Instrument Channel Calibration Frequency Instrument Check
- 18) Drywell High Range Radiation Monitors Once/ operating cycle **
Once/ month l 19) Main Stack High Range Once/ eighteen months Once/ month Radiation Monitor 1 20) Reactor Blcj. Roof Vent Once/ eighteen months Once/ month High Range Radiation Monitor
- 21) Drywell Hydrogen Concentration Quarterly ***
Once/ month Analyzer and Monitor Perform instrument functional check once per operating cycle.
Channel calibration shall consist of an electronic calibration of the channel, not including the detector, for range decades above 10R/hr and a one point calibration check of the detector below'10R/hr with an installed-or portable gamma source.
At least a two-point calibratica using sample gas.
I aS[ 2
Unit 3 PBAPS 3.6.D & 4.6.D BAS F.S Safety and Relief Valves The safety / relief and safety valves are required to be operable above the pressure (122 psig) at which the core spray 'Jystem is not designed to deliver full flow.
The pressure relief si stem for each unit at the Peach Bottom APS has been sized to me at two design bases.
First, the total capacity of the safety ;elief and the safety valves has been established to meet tne overpressure protection criteria of the ASME code.
Second,-the distribution of-this required capacity between cafety/ relief valves and - safety valves has been set to meet design basis 4.4.4.1 of. subsection 4.4 of the FSAR which states that the nuclear system safety / relief valves shall prevent opening of the safety valves during normal plant isolations and load rejections.
The details of the analysis which show compliance.with the ASME code requirements is presented in subsection 4.4 of the FSAR and the Reactor Vessel Overpressure Protection Summary Technical Report presented in Appendix K of the FSAR.
Eleven safety / relief valves and two safety -valves have been installed on Peach Bottom Unit 3 with a total capacity of 79.51% of rated steam flow. The analysis of the worst overpressure transient demonstrates margin to the code allowable overpressure-limit of 1375 psig.
To meet the power generation design basis, the total pressure relief. system capacity of 79.51% has been -divided into 65.96%
safety / relief (11 valves) and 13.55% safety (2 valves).
The analysis of the plant isolation transient shows that the 11 safety / relief valves limit pressure at-the safety valves below the setting of the safety valves.
Therefore, the safety valves will not open.
Experience in safety / relief and safety valve operation shows that la testing of 50 per cent of the valves per cycle is adequate to detect failure or deteriorations.
.The safety / relief and safety valves are benchtested every second.
- 157 -
4
Mit31 ? * " W-PE$
- s.;..
.m PBAP!
l e
-LIMITING CONDITIONS FOR'0PERATION SURVEILLANCE REQUIREMENTS-
[
t
. 3.7APrimaryConteinment(Cont'd.)-
-4.7.APrimaryContainment(Cont'd.):
~
3.
Pressure Suppression Chamber-
- h. Drywell Surfaces:
Reactor Building Vacuum Breakers
-The interior surfaces of the r
drywell and torus shall be visually a.
Except as specified in 3.7.A 3.b inspected.each operating cycle below, two pressure suppression for. evidence of deterioration.-- In-chamber-reactor building vacuum addition, the external surfaces of breakers shall be operable at the torus below the water level-all times when primary contain-shall.be inspected on a routine ment integrity is required.
basis for evidence of torus The setpoint of the differential corrosion or leakage.-
f pressure instrumentation which actuates the pressure suppression
- 3. Pressure-Suppression Chamber-f chamber-reactor building vacuum Reactor Building Vacuum Breakers breakers shall be 0.5 + 0.25 psid.
a.
The pressure suppression chamber-b.
From and after tne date that one reactor building vacuum breakers.
of the pressure suppression chamber-shall be checked for proper operation-reactor building vacuum breakers every refueling outage.:. Associated is made or found to be inoperable instrumentation including setpoint-for any reason, reactor operation shall be' checked for proper-is permissible only during the-operation every eighteen months.
1 succeeding seven days unless such vacuum breaker is sooner made opera-
- 4. Drywell-Pressure Suppression ble provided that the repair proce-Chamber Vacuum Breakers dure does not violate primary
- a. Each drywell-suppression chamber containment integrity, vaccuum breaker shall be-exercised through an opening-4.
Drywell-Pressure Suppression closing cycle once a month.
Chamber Vacuum Breakers
- b. When it is ~ determined 'that -
a.
Whan primary containment is-a vacuum breaker is inoperable required, all drywell-suppression for opening at a.t he chamber vacuum breakers shall when operability is required,z be operable and positioned all other operable' vacuum breeker:.
in the fully. closed position shall be exercised immediately (except during testing) except and every 15 days thereafter as specified in 3.7.A.4.b and until the inoperabic-c below.
vacuum breaker has been returned to normal service.
b.
Drywell-suppression chamber vacuum breaker (s) may be
- c. Once per operating cycle
~
"not fully seated" as each vacuum breaker shall shown by position indication be visually inspected if testing confirms that the bypass area is less than or equivalent to a one-inch diameter hole. Testing shall be initiated witting 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> of initial detection of a "not fully seated" position
-170-
Unit 3 4
PBAPS 3.7.A & 4.7.A BASES (Cont'd.)
The design basis loss-of-coolant accident was evaluated at the primary corit =11 nmen t maximum allowable accident leak rate of 0.5%/ day at 56 psig.
Calculations made by the AEC staff with leak rate and a standby gas treatment system filter efficiency of 90%
for halogens and assuming the fission product release fractions stated in TID 14844, show that the maximum total whole body passing cloud dose is about 1.0 REM and the maximum total thyroid dose is about 14 REM at 4500 meters from the stack over an exposure duration of two hours.
The resultant doses that would occur for the duration of the accid 7nt at the low population zone distance of 7300 meters are about 2.5 REM total '9010 body and 105 REM total thyroid.
Thus, the doses reported are the maximum that would be expected in the erilikely event of a design basis loss-of-coolant accident.
These doses are also based on the assumption of no holdup in the secondary containment resulting in a direct release of fission products from the primary containment through the filters and stack to the environs.
Therefore, the specified primary containment leak rate and filter efficiency are conservative and provide margin between expected of f-site doses and 10 CFR 100 guidelines.
The water in the suppression chamber is used only for cooling in the event of an accident; J.e.,
it is not used for normal operation; therefore, a daily check of the temperature and volume is adequate to assure that adequate heat removal capability is present.
Drywell Interior The interiors of the drywell and suppression chanber are peinte.1 to prevent rusting.
The inspection of the paint. during each major refueling outage, assures the paint is intact.
Experience with this type of paint at fossil fueled generating stations indicates that the inspection interval is adequate.
Post LOCA Atmosphere Dilution In order to ensure that the containment atmrohere remains inerted, j
1.e.
the oxygen-hydrogen mixture below the flammable limit, the capability to inject nitrogen into the containment after a LOCA is provided.
During the first year _.of operation the normal inerting nitrogen makeup system will be available for this purpose.
After that time the specifically designed CAD system will serve as the post-LOCA Containment Atmosphere Dilution System.
By maintaining a minimum of 2000 gallons of 11guld N in the storage tank it is 2
assured that a seven-day supply of N for post-LOCA containment a
I Inerting is available.
Since the inerting makeup system is I
continua 11y functioning, no
- 193 -
l l
l
Unit 3 PBAPS LIMITING CONDITIONS FOR OPEPXi10H SURVEILLANCF. REQdlREMENTS i
and one main stack shall also demonstrate that noble gas monitor control room alars an-shall be operable and set nunciation occurs if any of to alarm in accredance the following conditions exist, with the method. logy 1.
Instrument indicates and parameters in the measured levels ODCH. From and after the above the alam date that both reactor setpoint.
building exhaust vent 2.
Instrument indicates monitors or both main a downscale failure.
stack noble gas monitors Additionally, an instrument are made or found to be check shall be performed inoperable for any reason, every day, effluent releases via 4b.
The reactor building their respective pathway exhaust vent and the may continue provided at main stack flow rate least tw9 independent monitors shall be grab sac.p'.es are taken calibrated every 12 at least once per 8 hrs, months. Additionally, an and these samples are instrument check shall analyzt. jar gross be performed every day, activity within 24 4c.
The reactor building hours, and at least two exhaust vent and the main technically qualified stack iodine and particulate members of the facility sample flow rate monitors staff independently shall be calibrated every verify the release 12 mon ds. Additionally, rate calculations, an instrument check shall c.
One reactor building be performed every day exhaust vent iodine for the reactor building filter and one main exhaust vent sample flow stack iodine filter rate monitors, and every and one reactor build-week for the.nain stack ing exhaust vent sample flow rate monitor.
particulate filter 4d.
The main st=ck sample and one main stack flow line t /Lo pressure particulate filter with switches sh;'l be their respective flow functionally tested every rate monitors shall be 6 months and calibrated operable. From and after l
every 24 months.
the date that all iodine filters or all particulate filters for either the reactor building exhaust vent monitor or the main stack monitor are made or found to be inoperable for any reason, effluent releases via their respective pathway may
-211-
, -~ n, u...,,,3
~
Unit 3 Table 4.15_'l SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REOUIREMENTS Instrument
- Instrument
- Functional Instrument Check Test Calibration Inutruments and Sensor Locations #
1.
Triaxa.i Time-History Accelerographs a.
Containment Foundation (torus compartment)
M SA R
b.
Refueling Floor M
SA R
c.
RCIC Pump (Rm #7)
M SA R
d.
"C" Diesel Generator M
SA R
2.
Triaxal Peak Accelerographs a.
Reactor Piping (Drywell)
NA NA R
b.
Refueling Floor NA NA R
c.
"C" Diesel Generator NA NA R
3.
Triaxal Response-Spectrum Recorders a.
Cablo Spreading Rm M
SA R
Surveillance Frecuencies Mt every month SA:
overy 6 months l
Rt overy 24 months Effective upon completion of installation.
Seismic instrumentation located in Unit 2.
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