ML20151N797

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Proposed Tech Specs Pages 165a,173,174,175,180 & 184 Re Containment Vent & Purge Valves
ML20151N797
Person / Time
Site: Cooper Entergy icon.png
Issue date: 04/19/1988
From:
NEBRASKA PUBLIC POWER DISTRICT
To:
Shared Package
ML20151N784 List:
References
NUDOCS 8804260017
Download: ML20151N797 (6)
v • d • e


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LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.7.B (cont'd) 4.7.B (cont'd)

4. If these conditions cannot be met, 4.a. At least once per operating cycle procedures shall be initiated automatic initiation of each branch of i immediately to establish reactor conditions for which the standby the standby gas treatment system shall gas treatment system is not be demonstrated.

required.

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5. Use of the Standby Gas Treatment for purging / venting the primary b. At least once per operating cycle i containment with both the inboard manual operability of the bypass and outboard exhaust isolation valve for filter cooling shall valves open in series from either the drywell (231MV and 246AV) and/or be demonstraced.

the Suppression Chamber (230MV

c. When one standby gas treatment system and 2i5AV) is limited to 90 hours0.00104 days <br />0.025 hours <br />1.488095e-4 weeks <br />3.4245e-5 months <br /> becomes inoperable the other standby per calendar year when coolant tempersture is greater than 212.F.

Eas treatment system shall be demon-During such time bsth Standby Gas atrated to be operable immediately and daily thereafter. A demonstra-Treatment Systems shall be operable cion of diesel generator operability and only one Standby Gas Treatment is not requ' red by this specification.

l System is to be used for the j ,

purge / vent operation.

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C. Secondary Containment C. Secondary Containment

1. Secondary containment integrity shall 1. Sec ndary containment surveillance be maintained during all modes of shall be performed as indicated plant operation except when all of the following conditions are met. ,

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8804260017 880419 -165a-PDR ADOCK 05000298 P DCD

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i TABLE 3.7.4 PRIMARY CONTAINMENT TESTABLE ISOLATION VALVES TEST PEN. NO. VALVE NUMBERS MEDIA X-7A MS-AO-80A and MS-AO-86A, Main Steam Isolation Valves Air X-7B MS-A0-80B and MS-AO-86B, Main Steam Isolation Valves Air X-70 MS-AO-80C and MS-AO-860, Main Steam Isolation Valves Air i'

X-7D MS-A0-80D and MS-AO-86D, Main Steam Isolation valves Air X-8 MS-MO-74 and MS-M0-77, Main Steam Line Drain Air X-9A RF-15CV and RF-16CV, Feedwater Check Valves Air A

X-9A RCIC-AO-22, RCIC-MO-17, and RVCU-15CV, RCIC/RWCU Connection to Feedwater Air X-9B RF-13CV and RF-14CV, Feedwater Check Valves Air l

X-9B HPCI-AO-18 and HPCI-MO-57, HPCI Connection to Feedwater Air j X-10 RCIC-MO-15 and RCIC-MO-16, RCIC Steam Line Air 1

l X-11 HPCI-MO-15 and HPCI-MO-16 HPCI Steam Line Air l

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I X-12 RHR-MO-17 and RHR-MO-18 RHR Suction Cooling Air j 2

X-13A RHR-M0-25A and RHR-M0-27A, RHR Supply to RPV Air -

X-13B RHR-MO-23B and RHR-MO-27B, RHR Supply to RPV Air  ;

j X-14 RWCU-M0-15 and RWCU-MO-18, Inlet to RWCU System Air )

X-16A CS-MO-11A and CS-MO-12A, Core Spray to RPV Air j X-16B CS-MO-11B and CS-MO-12B, Core Spray to RPV Air

, X-18 RW-732AV and RW-733AV, Drywell Equipment Sump Discharge Air

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X-19 RW-765AV and RW-766AV, Drywell Floor Drain Sump Discharge Air X-25 (Note 1) PC-232MV and PC-238AV, Purge and Vent Supply to Drywell Air l

X-25 ACAD-1305MV and ACAD-1306MV, Supply to Drywell Air 4

X-26 (Note 1) PC-231MV, PC-246AV, and PC-306 MV Purge and Vent l i Exhaust from Drywell l Air 4

X-26 ACAD-1310MV, Bleed from Drywell Air 4

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l TABLE 3.7.4 (page 2)

PRIMARY CONTAINMENT TESTABLE ISOLATION VALVES l

. TEST l PEN. NO.*' VALVE NUMBERS MEDIA

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i X-39A RHR-MO-26A and RHR-M0-31A, Drywell Spray Header Supply Air

X-39B RHR-MO-26B and RHR-MO-31B, Drywell Spray Header Supply Air X-39B ACAD-1311MV and ACAD-1312MV, Supply to Drywell Air X-41 RRV-740AV and RRV-741AV, Reactor Water Sample Line Air X-42 SLC-12CV and SLC-13CV, Standby Liquid Control Air X-205 (Note 1) PC-233MV and PC-237AV, Purge and Vent Supply to Torus Air X-205 PC-13CV and PC-243AV, Torus Vacuum Relief Air X-205 PC-14CV and PC-244AV, Torus Vacuum Relief Air j X-205. ACAD-1303MV and ACAD-1304MV, Supply to Torus Air X-210A RCIC-MO-27 and RCIC-13CV, RCIC Minimum Flow Line Air X-210A RHR-MO-21A, RHR to Torus Air.

X-210A RHR-MO-16A, RHR-10CV, and RHR-12CV, RHR Minimum Flow Line Air 4

X-210B RHR-MO-21B, RHR to Torus Air X-210B HPCI-17CV and HPCI-M0-25. HPCI Minimum Flow Line Air X-210B RHR-MO-168, RHR-11CV, and RHR-13CV, RHR Minimum Flow Line Air X-210A and 211A RHR-MO-34A, RHR-MO-38A, and RHR-MO-39A, RHR to Torus Air X-210B and 211B RHR-MO-34B, RHR-M0-38B, and RHR-MO-39B, RHR to Torus Air i

X-211B ACAD-130lMV and ACAD-1302MV, Supply to' Torus Air X-212 RCIC-15CV and RCIC-37, RCIC Turbine Exhaust Air X-214 HPCI-15CV and HPCI-44, HPCI Turbine Exhaust Air X-214 HPCI-AO-70 and HPCI-AO-71, HPCI Turbine Exhaust Drain Air X-214 RHR-MO-166A and RHR-MO-167A RER Heat Exch. Vent Air l X-214 RHR-M0-166B and RHR-MO-167B RHR Heat Exch. Vent Air J

l l X-220 (Note 1) PC-230MV, PC-245AV, and PC-305MV Purge end Vent Exhaust from Torus Air X-220 ACAD-1308MV, Bleed from Torus Air j X-221 RCIC-12CV and RCIC-42, RCIC Vacuum Line Air 3

X-222 HPCI-50 and HPCI-16CV, HPCI Turbine Drain Air 1

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,l TABLE 3.7.4 (page 3)

PRIMARY CONTAINMENT TESTABLE ISOLATION VALVES

. TEST g N. NO. VALVE NUMBERS- MEDIA i X-223A CS-M0-26A and CS-MO-5A, Core Spray Test and Minimum Flow Air i X-223B CS-MO-26B and CS-MO-5B, Core Spray Test and Minimum Flow Air  ;

X-225A-D RHR-MO-13A, RUR-MO-13C, RHR-MO-13B, RHR-MO-13D, RHR Suction From Torus Air X-224 RCIC-MO-41, RCIC Suction From Torus Air X-226 HPCI-M0-58, HPCI Suction From Torus Air X-227A, B' CS-MO-7A and CS-MO-7B, Core Spray Suction From Torus Air

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Notes to Table 3.7.4

l. Once per operating c.ycle, while shutdown, the devices which limit the maximum i opening angle shall be verified functional for the following valves-i PC-230MV '

a PC-231MV PC-232MV PC-233MV l

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3.7.A & 4.7.A BASES (cont'd)

The primary containment is normaJ1y slightly pressurized during periods of reactor operation. Nitrogen used for inerting could leak out of the containment but air could not leak in to increase oxygen concentration. Once the containment is filled with nitrogen to the required concentration, no monitoring of oxygen concentration is necessary. However, at least twice a week the oxygen concentration will be determined as added assurance.

The 500 gallon conservative limit on the nitrogen storege tank assures that adequate time is available to get the tank refilled assuming normal plant operation. The estimated maximum makeup race is 1500 SCFD which would require 1 bout 160 gallons for a 10 day makeup requirement. The normal leak rate should be about 200 SCFD.

3.7.B & 3.7.C STANDBY GAS TREATMENT SYSTEM AND SECONDARY CONTAINMENT The secondary containment is designed to minimize any ground level release of radio-active materials which might result f rom a serious accident. The reactor building provides secondary containment during reactor operation when the drywelF is sealed and in service. The reactor building provides primary containment when the reactor is shut down and the drywell is open, as during refueling. Because the secondary containment is an integral part of the complete containment system, secondary con-tainment is required at all times that primary containment is required as well as during refueling. Secondary containment may be broken for short periods of time to allow access to the reactor building roof to perform necessary inspections and maintenance. .

The standby gas treatment system is designed to filter and exhaust the reactor building atmosphere to the stack during secondary containment isolation conditions.

Both standby gas treatment system fans are designed to automatically-start upon-containment isolation and to maintain the reactor building pressure to the design negative pressure so that all leakage should be in-leakage. Should one system fail to start, the redundant system is designed to start automatically. Each of the two fans has 100 percent capacity.

The intent of Specification 3.7.B.S is to minimize the amount of time a' SBGT system l 1s on line while coolant temperature is greater than 212*F and both inboard and '

outboard exhaust isolation valves from the drywell and/or torus are open in series.

The concern is to decrease the probability of damage to the SBGT filters that would  !

occur from excessive differential pressure caused by a LOCA with the main isolation '

exhaust valves open in series. Even it this should occur, the other SBGT system will be operable and available for use. This specification does allow purge / venting with the inboard exhaust bypass valve and the outboard exhaust valve both open in series and the time does not count against the yearly limit. The NRC has accepted the determination that due to the small size of the bypass v.alve, 1 there is no chance of damage to the filters if a LOCA occurs while purging / venting j the containment through the bypass with a SBGT system on line. For the purpose of  !

Specification 3.7.B.S. the term "calendar year" is a period of time beginning on l January 1 and ending on December 31 for each numbered year. l 1

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3.7.D & 4.7.D BASES (cont'd) results in a failure probability of 1.1 x 10~7 that a line will not isolate.

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, More frequent testing for valve operability results in a greater assurance that the valve will be operable when needed.

4 In order to assure that the doses that may result from a steam line break do not exceed the ICCFR100 guidelines, it is necessary that no fuel rod perforation resulting from the accident occur prior to closure of the main steam line isolation valves. Analyses indicate that fuel rod cladding perforations would be avoided for main steam valve closure times, including instrument delay, as long as 10.5 seconds. r The primary containment is penetrated by several small diameter instrument lines connected to the reactor coolant system. Each instrument line contains a 0.25 inch restricting orifice inside the primary contain=ent and an excess flow check valve outside the primary containment. A program for periodic testing and examination of the excess flow check valves is performed as follows:

1. Vessel at pressure sufficient to actuate valves. This could be at time .

of vesse'l hydro following a refueling outage.

2. Isolate sensing line from its instrbment at the instrument manifold.
3. Provide means for observing and collecting the instrument drain or vent valve flow.  !
4. Open vent or drain valve. * - =
a. Observe flow cessation and any leakage rate.  !
b. Reset valve after test completion.
5. The head seal leak detection line cannot be teseed in this manner. This  ;

j valve will not be exposed to primary system pressure except under unlikely conditions of seal failure where it could be partially pressurized to ,

reactor pressure. Any leakage path is restricted at the source and there-

. fore this valve need not be tested. This valve is in a sensing line that is not safety related.

6. Valves will be accepted if a marked decrease in flow rate is observed and I the leakage rate is acceptable. ,

The operators t'or containaent vent / purge valves PC-230MV, PC-231MV, PC-232MV, and .

PC-233MV have devices in place to limit the maximum opening angle to 60 degrees. '

This has been done to ensure these valves are able to close against the maximum differential pressure expected to occur during a design basis LOCA. .

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