ML20147A864

Proposed Tech Specs Re Exemption from 10CFR50,App J,Section III.A.3 to Allow Use of mass-plot Calculational Method in Lieu of point-to-point or Total Time Method

ML20147A864
Person / Time
Site:	Oyster Creek
Issue date:	02/19/1988
From:	GENERAL PUBLIC UTILITIES CORP.
To:
Shared Package
ML20147A845	List: ML20147A841 ML20147A848 ML20147A864
References
NUDOCS 8803010376
Download: ML20147A864 (15)

Text

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's (1) Maintain 'at least one isolation valve operable in each affected penetration that is open and within 4 hows (48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> for the traversing in-core probe system) either; (a) Restore the inoperable valve (s) to operable status or (b) Isolate each affected penetration by use of at least one deactivated automatic valve secured in the isolation position, or (c) Ir.olate each affected penetration by use of at least one closed manual valve or blind flange.

(2) An inoperable containment isolation valve of the shutdown cooling system may be opened with a reactor water temperature equal to or less than 350*F in order to place the reactor in the cold shutdown condition. The inoperable valve shall be returned to the operable status prior to placing the reactor in a condition where primary containment integrity is required.

b. If the primary containment air lock is inoperable, per specification 4.5.E.5, restore the inoperable air lock to operable status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or be in at least a shutdown condition within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in cold shutdown within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

4. Reactor Building to Suppression Chamber Vacuum Breaker System

a. Except as specified ir Specification 3.5. A.4.b below, two reactor building to suppression chamber vacuum breakers in each line shall be operable at all times when primary containment integrity is required. The set point of the differential pressure instrumentation which actuates the air-operated vacuum breakers shall not exceed 0.5 psid. The vacuum breakers shall move from closed to fully open when subjected to a force equivalent of not greater than 0.5 psid acting on the vacuum breaker disc.

b. From the time that one of the reactor building to suppression chamber vacuum breaker is made or found to be inoperable, the vacuum breaker shall be locked closed and reactor operation is permissible only during the succeeding seven days unless such vacuum breaker is made operable sooner, provided that the procedure does not violate primary containment integrity.

0YSTER CREEK 3.5-3 Amendment No: 21, 44, 45, 54, 87, 8803010376 880219 PDR ADOCK 05000219 p DCD

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.- exceeded, reactor shutdown shall .bs . initiated and - l the reactor shall be in a cold shutdown condition within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

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OYSTER CREEK 3.5-3a Amendment No.:

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~4.5 CONTAINMENT SYSTEM Applicability: Applies to containment system leakage rate, continuous leak rate monitor, functional testing of valves, standby gas treatment system operability, inerting surveillance, drywell coating surveillance, instrument line flow check valve surveillance, suppression chamber surveillance, and snubber surveillance.

Obj ectives: To verify operability of containment systems, and that leakage from the containment system is maintained within specified values, as outlined in Appendix J of 10 CFR 50. .

Specification: A. Type "A" Primary Containment Integrated Leak Rate Test (PCILRT).

1. PCILRT shall be performed at a pressure (Pt ) Of at least 20 psig,but not greater than 35.0 psig (Pa )-

2. Closure of the containment isolation valves shall be accomplished by their normal operation and without any adjustment, e.g. no preliminary exercising or tightening of the remote operated valves after closure.

3. The duration of the containment test '

stabilization period shall be at least four (4) hours prior to the start of the PCILRT.

4. The verification test shall superimpose a calibrated leakage between 75% and 125% of the allowable leakage rate (Lt ) for at least four (4) hours following the PCILRT.

5. The test duration shall not be less than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for integrated leak rate measurements.

6. A general inspection of the accessible interior and exterior surfaces of the containment structures and components will be performed prior to any PCILRT. Any significant structural deterioration that could effect leak tightness will be repaired prior to the test.

i OYSTER CREEK 4.5-1 Amendment No.:

I Change No.: 7

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B. Acceptance Criteria

1. The maximum allowable leakage rate (La) shall not exceed 1.0 weight percent of the contained air per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at a test pressure adjusted to 35 psig (Pa).

2. The allowable leakage rate (L t ), at the test pressure (Pt ) shall not exceed the following:

r N Lt = 1.0 wt.% Pt/Pa with Pt and Pa converted to absolute pressure for calculations.

3. The maximum allowable operational leakage rate (Ltm) Max., which shall be met prior to resumption of power operation following a PCILRT (either as measured or following repairs and retest), shall not exceed 0.75L *t i.e., (Ltm) Max, < .75 Lt

4. The difference between the verification test result and the Type "A" PCILRT test result (not including Type "B" and "C" test data) shall be within 0.25Lt-C. Corrective Action

1. If prior to or during the PCILRT Test, including the verification test, excessive leakage paths are identified which will interfere with meeting the allowable leakage rate Lt ; either:

a. The Type "A" PCILRT will be tenninated and the leakage through such paths shall be measured using Type "B" and "C" Local Leak Rate Test methods.

Repairs and/or adjustments to the equipment shall be made and a Type "A" PCILRT reperformed. If the containment was not depressurized below Pt , no additional stabilization period is required prior to reperforming the PCILRT; or

b. The leakage pachs will be isolated and the Type "A" test may proceed until completion. At that time, local leakage tests shall be performed at a pressure of at least P ,t before and after the repair of each isolated leakage path and the sum of the post repair local leakage rates will be added to the PCILRT result. This total shall be less than the allowable operational leakage rate (L tm) Max.

0YSTER CREEK 4.5-2 Amendment No.:

Change No.: 7

2. If repairs and/or adjustments are required in order to meet af ter the allowable having met theoperational (Lt m)(Max.,

leakage rate allowable leakage Lt)*

a. The integrated leakage rate test need not be repeated, however;

b. Local leak rate tests must be conducted at a pressure of Pt . The changes in local leak rates resulting from repairs or adjustments, when deducted from the PCILRT result, must yield a value not in excess of the allowable operational leakage rate (L m) t Max. This situation demonstrates sufficient containment integrity for startup, but the PCILRT is to be considered as not meeting acceptance criteria as referenced in section 4.5.0.2.

D. Frequency l 1. Three Type "A" overall Integrated Containment Leakage Rate Tests shall be conducted at approximately 40 month l intervals during scheduled shutdowns within each l 10-year service period. The third test of each set l shall be conducted during the shutdown for the 10-year plant inservice inspection.

l 2. If two consecutive periodic Type A tests fail to meet the acceptance criteria, the subsequent Type A test shall be performed at each shutdown for refueling or approximately every 18 months whichever occurs first.

This schedule will remain in effect until two t

consecutive Type A tests meet the acceptance criteria, at which time the frequency of testing noted in D.1 above may be resumed, i

E. Type "B ' and "C" Local Leak Rate Tests (LLRT)

1. Primary Containment testable penetrations (Type "B" Test) and isolation valves (Type "C" Test), except as l stated below, shall be tested at a pressure of at least 35 psig (Pa) each refueling outage.

2. The main steam line isolation valves shall be tested at a pressure of at least 20 psig during each refueling outage to determine if corrective action is required.

3. Isolation valve, Type "C", tests shall have each valve closed by normal operation. (e.g. no preliminary exercising or tightening of valve after closures by valve motor).

4. Bolted double gasketed seals shall be tested whenever the seal is closed after being opened, and at least at each refueling outage.

5. The drywell airlock shall be demonstrated operable by performing the following tests:

OYSTER CREEK 4.5-3 Amendment No.:

Change No. : 7

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, a.- The airlock must be tested at least once each 6 month interval at an internal pressure not less than Pa except:

(1) If there have been no airlock openings since the last successful test at Pa, the test pressure may be reduced to 10 psig and the full pressure test interval may be extended to the next refueling outage or airlock opening.

Opening of the airlock for the purpose of removing test equipment following any airlock test does not require further testing of the airlock.

(2) If the airlock is opened during a period when Containment Integrity is required, it must be tested within 3 days. If the airlock is opened more frequently than once every 3 days, the airlock must be tested at least once every 3 days during the period of frequent openings.

This intermediate testing may be accomplished at 10 psig. This reduced pressure testing may not be substituted for the full pressure testing requirement of the airlock in the previous paragraph.

(3) If the airlock is opened during a period when Containment Integrity is not required, it need not be tested while Containment Integrity is not required, but must be tested at P4 prior to returning the reactor to an operating mode requiring containment integrity.

F. Acceptance Criteria

1. The cuabined leakage rate of all potential leakage flow paths subject to type "B" tests (double-gasketed seals and drywell airlock doors) and type "C" tests (all penetrations and isolation valves)* shall be less than 0.60 of the maximum allowable limit (La) at 35 psig.

2. The leakage rate of an MSIV shall not exceed 5% of the allowable operational leakage rate (L tm) Max, as adjusted to or measured at 20 psig.

3. The drywell airlock 10 psig test shall be adjusted using the following:

LR(Pa) = (Pa + Pat)2 - (Pat)2

• LR (Pt) '

(Pt + Pat)4 - (Pat)4 L where: Pa = adjusted pressure Pat = atmospheric pressure (14.7 psig)

Pt = test pressure LR = leakage rate

• For valves in series the maximum leakage rate is used to calculate 60 La.

0YSTER CREEK 4.5-4 Amendment No.:

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G. Frequency Local Leak Rate Tests shall be performed as stated above but in no case may exceed 5ntervals of 24 months.

H. Continuous Leak Rate Monitor

1. When the primary containment is inerted the containment shall be continuously monitored for gross leakage by review of the inerting system makeup requirements.

2. This monitoring system may be taken out of service for the purpose of maintenance or testing but shall be returned to service as soon as practical.

I. Report of Test Results l Each integrated leakage rate test shall be the subject of a summary technical report, including results of the local leakage rate tests. The report shall include analysis and interpretation of the results which demonstrate compliance in meeting the specified leakage rate limits.

J. Functional Test of Valves l

1. All containment isolation valves specified in Table 3.5.2 shall be tested for automatic closure by an isolation signal during each refueling outage. The following valves are required to close in the time specified below:

Main steam line isolation valves > 3 sec. and < 10 sec.

Isolation condenser isolation valves < 60 sec.

Cleanup system isolation valves 7 60 sec.

Cleanup auxiliary pumps system isolation valves 7 60 sec.

Shutdown system isolation valves 160sec.

2. Each containment isolation valve shown in Table 3.5.2 shall be demonstrated operable prior to returning the valve to service after maintenance, repair or replacement work is performed on the valve or its associated actuator by cycling the valve through at least one complete cycle of full travel and verifying the specified isolating time. Following maintenance, repair or replacement work on the control or power circuit for the valves shown in Table 3.5.2, the affected component shall be tested to assure it will perform its intended function in the circuit.

3. During periods of sustained power operation each main steamline isolation valve shall be exercised in accordance with the following schedule.

a. Daily tests - Exercise valve (one at a time) to approximately 95%open position with reactor at operation power level,

b. Quarterly tests - Trip valve (one at a time) and check full closure time, with reactor power not greater than 50 % of rated power.

0YSTER CREEK 4.5-5 Amendment No.: 7, 14, 54,

j 4. Reactor Building to Suppression Chamber Vacuum Breakers

a. The reactor building to suppression chamber vacuum

, breakers and associated instrumentation, including set F

point, shall be checked for proper operation every three months,

b. During each refueling outage each vacuum breaker shall be tested to determine that the force required to open the vacuum breaker from closed to fully open does not exceed the force specified in Specification 3.5. A.4.a.

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air-operated vacuum breaker instrumentation shall be calibrated during each refueling outage.

5. Pressure Suppression Chamber - Drywell Vacuum Breakers

a. Periodic Operability Tests Once each month and following any release of energy which would tend to increase pressure to the suppression chamber, each operable suppression chamber - drywell vacuum breaker shall be exercised. Operation of position switches, indicators and alarms shall be verified monthly by operation of each operable vacuum breaker.

b. Refueling Outage Tests (1 ) All suppression chamber - drywell vacuum breakers shall be tested to determine the force required to open each valve from fully closed to fully open.

(2) The suppression chamber - drywell vacuum breaker position indication and alarms systems shall be calibrated and functionally tested.

(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 Specifications 3.5.A.5.a can be met.

(4) A drywell to suppression chamber leak rate test shall 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.

X. Reactor Building

1. Secondary containment capability tests shall be conducted after isolating tne 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 and shall demonstrate the capability to maintain 61/4 inch of l water vacuum under calm wind conditions with a Standby Gas Treatment System Filter train flow rate of not more than 4000 cfm.

0YSTER CREEK 4.5-6 Amendment No. 14, 52,

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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.

L. Standby Gas Treatment System

1. The capability of each Standby Gas Treatment System circuit i shall be demonstrated by:

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

(1) The charcoal absorbers remove >99% of a halogenated hydrocarbon refigerant test gas and the HEPA filters remove 799% of the D0P in a cold D0P test when tested Tn accordance with ANSI N510-1975.

(2) Results of laboratory carbor imple analysis shcw

>90% radioactive methyl iodine removal efficiency 21en tested in accordance with ASTM D 3803-79 (30*C, l 95% relative humidity). ,

b. At least once per 18 months by demonstrating:

(1) That the pressure drop across a HEPA filter is equal to or less than the maximum allowable pressure drop -

indicated in Figure 4.5.1.

(2) The inlet heater is capable of at least 10.9 KW input.

(~J Operation with a total flow within 10% of design flow,

c. At least once per 30 days on a STAGGERED TEST BASIS by

operating each circuit for a minimum of 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />.

d. Anytime the HEPA filter bank or the charcoal absorbers ,

i have been partially or completely replaced, the test per '

j 4.5.L.1.a (as applicable) will be performed prior to returning the system to OPERABLE STATUS. ,

e. Automatic initiation of each circuit every 18 months.

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Inerting Surveillance  !

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When an inert atmosphere is required in the primary containment the oxygen co,1 centration in the primary containment shall be checked at least weekly.  !

OYSTER CREEK 4.5-7 Amendment No.:

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N. Drywell Coating rurveillance b Carbon steel test panels coated with Firebar D shall be placed

<. inside the drywell near the reactor core midplane level. They i shall be removed for visual observation and weight loss measurements during the first, second, fourth and eighth refueling outages.

O. Instrumnt Line F,0w Check Valves Surveillance The capability of each instrument line flow check valve to isolate shall be tested at least once in every period between refueling outages. Each time an instrument line is returned to service after any condition which could have produced a pressure or flow disturbance in that line, the open position of the flow check valve in that line shall be verified. Such conditions include:

Leakage at instrument fittings and valves Venting an unisolated instrument or instrument line Flushing or draining an instrument Installation of a new instrument or instrument line P. Suppression Chamber Surveillance

1. At least once per day the suppression chamber water level and temperature and pressure suppression system pressure shall be checked.

2. A visual inspection of the suppression chamber interior, including water line regions, shall be made at each major refueling outage.

3. Whenever heat from relief valve operation is being added to ,

the suppression pool, the pool temperature shall be continually monitored and also observed until the heat addition is terminated.

4. Whenever operation of a relief valve is indicated and the

suppression pool temperature reaches 160*F or above while the re;ctor primary coolant system pressure is greater thar.180 psig, an external visual examination of the suppression chamber shall be made before resuming normal power operation, i

l 0YSTER CREEK 4.5-8 Amendme.it No.: 14, 18, 32, 87, 104, l

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Q. Shock Suppressors (Snubb:rsi

1. Each snubber shall be demonstrated operable by performance of the following inspection program:

a. Yitual Inspections All snubbers shall be visually inspected in accordance with the followino schedule:

No. Inoperable Snubbers Subsecuent Visual Per Inspection Period Inspection Period

• 0 18 months + 25%

1 12 months T 25%

2 6 months T 25%

3, 4 124 days T 25% l 5,6,7 62 days T 25%

8 or more 31 days 125%

• The provisions of Technical Specification 1.24 are not applicable.

The required inspection interval shall not be lengtnened more than one step at a time. The snubbers may be categorized into two groups: those accessible and those inaccessible during reactor operation. Each group may be inspected independently in accordance with the above schedule.

b. Visual Inspection Acceptance Criteria Visual inspections shall verify (1) that there are no visible indications of damage or impaired OPERABILITY, (2) attachments to the foundation or supporting structure are secure,and (3) in those locations where snubber movement can be manually induced without disconnecting the snubber, that the snubber has freedom of movement and is not seized. Snubbers which appear inoperable as a result of visual inspections may be detemined OPERABLE for the purpose of establishing the next visual inspection interval, providing that the affected snubber is functionally tested in the as found condition and determined operable per Snecification 4.5.Q d or 4.5.Q.e as applicable and that tha cause for the rejection has been clearly established and remedied for that particular snubber.

c. Functional Tests At least once each refueling cycle, a representative sample (10% of the total of each type of snubber in use in the plant) shall be functionally tested either in place or in a bench test. For each snubber that 0YSTER CREEK 4.5-9 Amendment No. : 18, 32, 87, 100

~ does not meet th? functional test acceptance criteria

, of Specification 4.5.Q.d or 4.5.Q.e, an additional 10%

of that type of snubber shall be functionally tested.

As used in this specification, type of snubber shall mean snubbers of the same design and manufacturer, mechanical or hydraulic.

The representative sample selected for functional testing shall include the various configurations, operating environments and the range of size and capacity of snubbers. At lest 25% of the snubbers in the representative sample shall include snubbers from the following three categories:

1. The first snubber away from each reactor vessel nozzle.

2. Snubbers within 5 feet of heavy equipment (valve, pump, motor, etc. ).

3. Snubbers within 10 feet of the discharge from a safety relief valve.

In addition to the regular sample, snubbers which failed a previous functional test shall be retested during the next test period. If a spare snubber has been installed in place of a failed snubber, then both the failed (if it is repaired and installed in another position) and the replacement snubber shall be retested. The, results from testing of these snubbers are not included for determining additional sampling requi rements.

For any snubber that fails to lockup or fails to move, i.e., frozen in place, the cause will be evaluated.

If caused by manufacturer or design deficiency, actions shall be taken to ensure that all snubbers of the same de';,ign are not subject to the same defect,

d. Hydraulic Snubbers Functional Test Acceptable Criteria The hydraulic snubber functional test shall verify that:

1. Activation (restraining action) is achieved within the specified range of velocity or acceleration in both tension and compression.

2. Snubber bleed, or release rate, where required, is within the specified range in compression or tension. For snubbers specifically required to not displace under continuous load, the ability of the snubbers to withstand load without displacement shall be verified.

0YSTER CREEK 4.5-10 Amendment No.: 100

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e. Mechanical Snubbers Functional Test Acceptance Criteria The mechanical snubber functional test shall verify that:

1. The force that initiated free movement of the snubber rod in either tension or compression is less than the specified maximum drag force.

2. Activation (restraining action) is achieved within the specified range of velocity or acceleration in both tension and compression.

3. Snubber release rate where required, is within the specified range in compression or tension. For snubbers specifically required not to displace under continuous load, the ability of the snubber to withstand load without displacement shall be verified,

f. Snubber Service Life Monitoring A record of the service life of each snubber, the date at which the designated service life commences and the installation and maintenance records on which the designated service life is based shall be maintained as required by Specification 6.10.2.1.

Concurrent with the first inservice visual inspection and at least once per 18 months thereafter, the installation and maintenance records for each snubber shall be reviewed to verify that the indicated service life has not been exceeded or will not be exceeded prior to the next scheduled snubber service life review. If the indicated service life will be exceeded prior to the next scheduled snubber service life review, the snubber service life shall be reevaluated or the snubber shall be replaced or reconditioned so as to extend its service life beyond the date of the next scheduled service life review.

This reevaluation, replacement or reconditioning shall be indicated in the records. Service life shall not [

U. any time affect reactor operations.

0YSTER CREEK 4.5-11 Amendment No.: 100

, , *- Basis: In the event of a loss-of-coolant accident, the peak drywsil

,, pressure would be 38 psig which would rapidly reduce to 20 psig within 100 seconds following the pipe break. The total time the drywell pressure would be above 35 psig is calculated to be about 7 seconds, following the pipe braak, absorption chamber pressure rises to 20 psig within 8 seconds, equalizes with drywell pressure at 25 psig within 60 seconds a thereafter rapidly decays with the drywell pressure decay.

The design pressures of the drywell gnd absorption chamber are 62 psig and 35 psig, respectively. W The' design leak rate of'0.5% / day at a pressure of 35 psig. As pointed out above, the pressure response of the drywell and absorption chamber following an accident would be the same af ter about 60 seconds.

Based on the calculated primary containment pressure response discussed above the absorption chamber design pressure, primary containment preoperational test pressures were chosen. Also, based on the primary containment pressure response and the fact that the drywell and absorption chamber function as a unit, the primary containment will be tested as a unit rather than testing the individual components separately.

The design basis loss-of-coolant accident was evaluated at the primary containment maximum allowable accident leak rate of.

1.0%/ day at 35 psig. The analysis showed that with this leak rate and a standby gas treatment system filter efficiency of 90 percent for halogens, 95% for particulates, and assuming the fission product release fractions stated in TID-14844, the maximum total whole body passing cloud dose is about 10 rem and the maximum total thyroid dose is about 139 rem at the site boundary considering fumigation conditions over an exposure duration of two hours. The resultant doses that would occur for

the duration of the accident at the low population distance of 2 miles are lower than those stated due to the variability of meteorological conditions that would be expected to occur over a 30-day period. 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 through the I filters and stack to the environs. Therefore, the specified primary containment leak rate and filter efficiency are conservative and provide margin between expected offsite doses and 10 CFR 100 guideline limits.

! Although the dose calculations suggest that the allowable test i leak rate could be allowed to increase to about 2.0%/ day before l the guideline thyroid dose limit given in 10CFR 100 would be exceeded, establishing the limit of 1.0%/ day provides an j adequate margin of safety to assure the health and safety of the i

general public. It is further considered that the allowable l 1eak rate should not deviate significantly from the containment design value to take advantage cf the design leak-tightness l capability of the structure over its service lifetime.

Additional margin to maintain the containment in the "as l

Change: 7, 27, 0YSTER CREEK 4.5-12 Amendment No.:

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. built" condition is achieved by establishing the allowabin operational leak rate. The operational limit is derived by multiplying the allowable test leak rate by 0.75 thereby providing a 25% margin to allow for leakage deterioration which may occur during the period between leak rate tests.

The primary containment leak rate test frequency is based on maintaining adequate assurance that the leak rate remains within the specification.

The leak rate test frequency is based on the 10CFR50 requirements for developing) vessel s. (

leak rate testing and surveillance of reactor containment The penetration and air purge piping leakage test frequency, along with the containment leak rate tests, is adequate to allow detection of leakage trends. Whenever a double gasketed penetration (primary t

containment head equipment hatches and the absorption chamber access hatch) is broken and remade, the space between the gaskets is pressurized to determine that the seals are performing properly. The test pressure of 35 psig is consistent with the accident analyses and the maximum preoperational leak rate test pressure.

l Monitoring the nitrogen makeup requirements of the inerting system provides i method of observing leak rate trends and would detect gross leaks in a very short time. This equipment must be periodically removed from service for test and maintenance, but this out-of-service time will be kept to a practical minimum.

The containment integrity isolation valves are provided to maintain containment integrity following the design basis loss-of-coolant accident. The closure times of the isolation valves on the containment are not critical because it is on the order of minutes before significant fission product release to the containment atmosphere for the design basis loss of coolant. These valves are highly reliable, see infrequent service and most of them are normally in the closed position. Therefore, a test during each refueling outage is sufficient. l Large lines connecting to the reactor coolant system, whose failure could result in uncovering the reactor core, are supplied with automatic isolation valves (except containment cooling). The specified closure times are adequate to restrict the coolant loss from the circumferential rupture of any of these lines outside the containment to less than that for a main steam line rupture. Therefore, this isolation valve closure is suf ficient to prevent uncovering the core. l 0YSTER CREEK 4.5-12a Amendment No.:

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