ML20129A573

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Proposed Tech Specs,Revising Addl Group of Surveillances Where Justification Completed Following Receipt of Amend 144
ML20129A573
Person / Time
Site: Oyster Creek
Issue date: 10/10/1996
From:
GENERAL PUBLIC UTILITIES CORP.
To:
Shared Package
ML20129A524 List:
References
NUDOCS 9610220184
Download: ML20129A573 (6)
v • d • e


Text

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TABLE 4.1.1 (Cont'd.)

MINIMUM CI1ECK. CAllBRATION AND TEST FREOUENCY FOR PROTECTIVE INSTRUMENTATION Check Calibrate Test Remarks (Apolies to Test and Instrument Channel Calibration)

13. DELLTED
14. liigh Radiation in Reactor Building Operating Floor 1/s 1/3 mo 1/3 mo Using gamma source for Ventilation Exhaust 1/s 1/3 mo 1/3 mo calibration
15. liigh Radiation on 1/3 mo 1/3 mo Using built-in calibration Air Ejector Off-Gas equipment 1/s Channel Check 1/mo Source check 1/24 mo Calibration according to established station calibration procedures 1/24 mo Note a
16. IRM Ixvel N/A Each N/A startup
  • *
  • Using built-in calibration IRM Scram equipment
17. IRM Blocks N/A Prior Prior Upscale and downscale to to startup stanup and and shutdown shutdown
18. Condenser Low N/A 1/24 mo 1/24 mo Vacuum
19. Manual Scram Buttons N/A N/A 1/3 mo 20.11igh Temperature Main N/A 1/24 mo Each Using heat source box Steamline Tunnel refueling outage OYSTER CREEK 4.1-4 Amendment No.: 71,108,141,169,171 Change. 7 9610220184 DR 961010 g ADOCK 05000219 PDR g

,6 .

. TABLE 4.1.1 (cont'd)

Check Calibrate -Teg Remarks (Apolies to Test and l Instrument Channel 2' Calibration) 4

  • ~*
  • Using built-in calibration i

) 21. SRM

' equipment

22. Isolation Condenser High Flow N/A 1/3 mo 1/3 mo ~By application of test pressure AP (Steam and Water)-

l

23. Turbine Trip Scram N/A N/A 1/3 mo
24. Generator Load Rejection N/A 1/3 mo 1/3 mo Scram
25. Recirculation Loop Flow .N/A 1/24 mo N/A By application of test pressure l
26. Low Reactor Pressure Core N/A 1/3 mo 1/3 mo By application of test Spray Valve Permissive pressure i
27. Scram Discharge Volume (Rod Block)

N/A Each re- 1/3 mo Calibrate by varying level a) Water level high fueling in sensor column outage b) Scram Trip N/A N/A Each re I

bypass fueling outage

28. Loss of Power a) 4.16 KV 1/d 1/24 mo 1/mo Emergency Bus  !

Undervoltage

'(Loss of voltage)  !

b) 4.16 KV 1/d 1/24 mo 1/mo ,

Emergency Bus Undervoltage (Degraded Voltage) .

OYSTER CREEK -4.1-5 Amendment No.: 144,171

~1 .

4 TABLE 4.1.2 MINIMUM TEST FREOUENCIES FOR TRIP SYSTEMS l Trio System Minimum Test Freauency l

Same as for respective l 1) Dual Channel (Scram) instrumentation in Table 4.1.1 Rod Block Same as for respective 2) instrumentation in Table 4.1.1 DELETED DELETED ,

! 3) 1 Automatic Depressurization Each refueling outage

4)
each trip system, one at a

} time '

MSIV Closure, each closure Each refueling outage 5) logic circuit independently (1 valve at a time) i

6) - Core Soray, each trip 1/3 mo and each refueling outage j system, one at a time i

Primary Containment Each refueling outage l 7)

Isolation, each closure circuit independently l

, (1 valve at a time) l Refuelinn Interlocks Prior to each refueling operation  !

8)

Isolation Condenser Actuation Each refueling outage

! 9) 4 and Isolation, each j

) trip circuit independently i

(1 valve at a time) l i

I 10) Reactor Building isolation Same as for respective and SGTS Initiation instrumentation in Table 4.1.1 I Prior to each startup

11) . Condenser Vacuum Pumo i isolation i Each refueling outage
12) Air Elector Offuas Line Isolation
13) Containment Vent and Purge 1/24 mo I

Isolation i

4.1-7 Amendment No. 108,116,144,160,171 OYSTER CREEK i

u_

  • G. Primary Coolant System Pressure Isolation Valves Specification:
1. Periodic leakage testing
  • on each valve listed in Table 4.3.1 shall l

be accomplished prior to exceeding 600 psig reactor pressure every time the plant is placed in the cold shutdown condition for )

refueling, each time the plant is placed in a cold shutdown condition for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> if testing has not been accomplished in the j l preceding 9 months, whenever the valve is moved whether by manual actuation or due to flow conditions, and after returning the -

valve to service after maintenance, repair or replacement work is i

4 performed. ,

i

! H. Rgactor Coolant System feakane l i

1. Unidentified leakage mte shall be calculated at least once every 4

' hours.

i l

2. Total leakage rate (identified and unidentified) shall be calculated at least once every 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. .

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3. A channel calibration of the primary containment sump flow l integrator and the primary containment equipment drain tank flow integrator shall be conducted at least once per 24 months.

An inservice inspection program for piping identified in NRC Generic Letter

[ 1.

88-01 shall be performed in accordance with the NRC staff positions on

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- schedule, methods, personnel, and sample expansion included in the generic letter or in accordance with alternate measures approved by the NRC staff.

! Bases:

Data is available relating neutron fluence (E>1.0MeV) and the change in the Reference Nil-Ductility Transition Temperature (RTNur). The pressure-temperature (P-T) operating curves (a),(b) and (c) in Figure 3.3.1 were developed based on the results of testing and evaluation of specimens removed from the vessel after 8.38 EFPY of operation. Similar testing and analysis will be performed throughout vessel life to monitor the effects of neutron irradiation on the reactor vessel shell materials.

The inspection program will reveal problem areas should they occur, before a leak develops. In addition, extensive visual inspection for leaks will be made on critical systems. Oyster Creek was designed and constructed prior to

( To satisfy ALARA requirements, leakage may be measured indirectly (as from the performance of pressure indicators) if accomplished in accordance with approved procedures and supported by computations showing that the method is capable of demonstrating valve compliance with the leakage criteria.

  • NRC Order dated April 20,1981.

OYSTER CREEK 4.3-2 Amendment No. 82, 90, 97, 118, 120, 151, 154

4.4 .EMER_GENCY COOLING l,

Apolicability: Applies to surveillance requirements for the emergency cooling systems.

Obiective: To verify the operability of the emergency cooling systems.

  • Specification: Surveillance of the emergency cooling systems shall be performed as follows:

Freouency Iten1 A. Core Sprav System a

1. Pump Operability Once/ month. Also after nqior maintenance and i

' prior to startup following a refueling outage.

2. Motor operated valve Once/ month l

i operability i

3. Automatic actuation test Every three months
4. Pump compartment water- Once/ week and after each entry tight doors closed i 5. Core spray header AP instrumentation check Once/ day calibrate Once/3 months Once/3 months ]

test 1

B. Automatic Deoressurization

l. Valve operability Once every 24 months
  • l
2. Automatic actuation test Every refueling outage C. Containment Cooling System
1. Pump Operability Once/ month. Also after major mainterance and prior to startup following a refueling outage.
  • Valve operability shall be demonstrated at system operating pressure prior to exceeding 5 percent power, following a refueling outage.

1 OYSTER CREEK 4.4-1 Amendment No. 109,144

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.. ,' (3) At least four of the suppression chamber - drywell vacuum breakers shall be inspected. If deficiencies are found, all vacuum breakers shall be inspected and deficiencies corrected such that Specification 3.5. A.5.a can be met. l l

l (4) A drywell to suppression chamber leak rate test shall be perfomied once every 24 months to demonstrate, that with an initial differential pressure of not less than 1.0 psi, the differential pressure decay rate shall not exceed the equivalent of air flow through a 2-inch orifice.

i' G. Reactor Building

l. Secondary containment capability tests shall be conducted after isolating the reactor building and placing either Standby Gas Treatment System filter train in operation.
2. The tests shall be performed at least once per operating cycle (interval not to exceed 20 months) and shall demonstrate the capability to maintain a % inch of water vacuum under calm wind conditions with a Standby Gas Tmatment System Filter train flow rate of not more than 4000 cfm.
3. A secondary containment capability test shall be conducted at each refueling outage prior to refueling.
4. The results of the secondary containment capability tests shall be in the subject of a summary technical report which can be included in the reports specified in Section 6.

II. Standby Gas Treatment System

1. The capability of each Standby Gas Treatment System circuit shall be demonst'ated

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i by:

1

a. At least once per 18 months, after every 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> of operation, and following significant painting, fire, or chemical release in the reactor i

building during operation of the Standby Gas Treatment System by verifying that:

)

(1) The charcoal absorbers remove 199% of a halogenated hydrocarbon l

refrigerant test gas and the HEPA filters remove 199% of the DOP in a cold DOP test when tested in accordance with ANSI N510-1975.

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l OYSTER CREEK 4.5-4 Amendment No.
144

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