ML20069L137

Proposed Changes to Tech Specs 3.2-22,3.2-48,3.7-10,3.7-10a, 3.7-33a & 3.7-34,deleting Drywell to Torus Differential Pressure Sys

ML20069L137
Person / Time
Site:	Hatch
Issue date:	04/22/1983
From:	GEORGIA POWER CO.
To:
Shared Package
ML20069L109	List: ML20069L105 ML20069L137
References
TAC-51998, NUDOCS 8304280050
Download: ML20069L137 (6)

Text

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Table'3.2-11~ ~+

.IllSTRUt1EllTATION WillCil PROVIDES SURVEILLAtlCE If1FORf1ATION -

Required Ref. Operable Ilo. Instrument Instrument , Type and (a) (b): Channels J Rang t Action Remarks 1 Reactor Water Level (GE/IlAC) 1 Recorder .

(c) (d) 2 Indicator 0 to 60" (c) (d)

2. Shroud Water Level 1 Recorder .(c) (d) 1 Indicator. -317" to -17" (c) (d) 3 Reactor Pressure 1 Recorder (c) (d) 2 Indicator 0 to 1200 psig (c) (d) 4 Drywell Pressure 2 Recorder -5 to +80 psig (c) (d) 5 Drywell Temperature 2 Recorder 0 to 500 F (c) (d)

{

j 6 Suppression Chamber Air Temperature 2 Recorder 0 to 500 F (c) (d) 7 Suppression Chamber Water Temperature 2 Recorder 0 to 250 F (c) (d)

. 8 Suppression Chamber Water Level 2 Indicator 0 to 300" (c) (d) 2 Recorder 0 to 30" (c)(e) (d) 9 Suppression Chamber Pressure 2 Recorder -5 to +80 psig (c) (d) 10 Rod Position Information System (RPIS) 1 28 Volt Indicating Lights (c) (d) 11 Ilydrogen and Oxygen Analyzer 1 Recorder 0 to 52 (c) '(d) 12 Post LOCA Radiation 11onitoring System 1 Recorder (c) (d)

Indicator 1 to 106 R/hr (c) (d) 13 a) Safety / Relief Valve Position Primary 1 Pressure Switch 4-100 psig (f)

Indicator b) Safety / Relief Valve Position Secondary 1 Temperature element 0-600 F (f)

Indicator 8304280050 830422 PDR ADOCK 05000321 P PDR -

Table 4.2-11 Check and Calibration itinimum Frequency for Instrumentation Ubich Provides Surveillance Information Ref. Instrument Instrument Check Instrtment Calibration flo. Ilinimum Frequency flinimtri Frequency (a) (b) 1 (c) 1 Reactor Water Level Each shift Every 6 months (GE/flAC) 2 Shroud Water Level Each shift Every 6 months 3 Reactor Pressure Each shift Every 6 months 4 Drywell Pressure Each shift Every 6 months 5 Drywell Temperature Each shift Every 6 renths P' 6 Suppression Chamber Air Each shift Every 6 months

][ Tempera ture 03 7 Suppression Chamber Uater Each shift Every 6 months Temperature 8 Suppression Chamber Water Each shift Every 6 months Level 9 Suppression Chamber Each shift Every 6 months Pressure .

10 Rod Position Information Each shift fl/A System (RPIS) 11 Hydrogen and Oxygen Each shift Every 6 months Analyzer 12 Post LOCA Radiation Each shift Every 6' months 13 a) Safety / Relief Valve Position Pri- tionthly Every 18 months mary Indicator b) Safety / Relief Valve Position f1onthly ,

Every 18 months c.-,.,a,- r.u-,.--

LJhlTING CONDITIONS FOR OPERATIO:1 SURVEILLANCE REQUIREMENTS 3.7.A.G.c. H and 0 Analyzer 2 2 4.7.A.6.c. H and 0 Analyzer 2 2 Whenever the reactor is in power Instrumentation surveillance is operation, there shall be at least listed in Table 4.2-11.

one CAD System H2 and 02 analyzer serving the primary containnent.

If one H2 and 02 analyzer is in-operable, the reactor may remain in operation for a period not to exceed seven days.

d. Post-LOCA Reoressurization Limit The maximum post-LOCA primary con-tainment repressurization limit allouable using the CAD System shall be 30 psig. Venting via the SGTS to the main stack nust be initiated at 30 psig following the initial post-LOCA pressure peak.

3.7-10

LIMITil!G CONDITIONS FOR OPERATION SURVEILLAilCE REQUIREMENTS

7. Shutdown Requirements, If Specification 3.7. A cannot be met, an orcerly shutdown shall be initiated and the reactor shall be brought to Hot Shutdown within 12 '

hours and shall be in the Cold Shut-down condition within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. ,

B. Standby Gas Treatment System B. Standby Gas Treatment System

1. Operability Reauirements 1. Surveillance 'elben System Operable A ainimum of three (2 of 2 in Unit 1 and 1 of 2 in Unit 2) of the four in- At least once per operating dependent standby gas treatment system cycle, not to exceed 18 months, trains shall be operable at all times the following conditions shall when Unit 1 secondary containment be demonstrated:

integrity is required.

a. Pressure drop across the With one of the Unit 1 standby gas combined HEPA filters and treatment systems inoperable, for charcoal absorber banks is any reason, Unit I reactor operation less than 6 inches of water and fuel handling and/or handling of at the system design flow casks in the vicinity of the spent rate (+10%, -03).

fuel pools is permissible for a period of seven (7) days provided b. Operability of inlet heater that all active components in the at rated power when. tested remaining standby gas treatment in accordance with ANSI systems in each unit shall be N510-1975.

demonstrated to be operable within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, and daily thereafter. c. Air distribution is uniform within 20% across the filter train when tested in accordance with ANSI N510-1975.

3.7-10a

BASES FOR LI:11Tli!G C0:lDIT10flS FOR OPERATIO:1 This page is left intentionally blank 3.7-33a

~

BASES FOR LlillTIr1G C0i!DITIO!!S F0R OPERATIO:1 3.7.A.7. Shutdown Requirements Bases for shutdown requirements are discussed above in conjunction with the in-dividual requirements for primary containment integrity.

B. Standby Gas Treatment System The standby gas treatment systems are designed to filter and exhaust the Unit 1 secondary containment atmosphere to the off-gas stack during secondary contain-ment isolation conditions, with a mininum release of radioactive materials from these areas, to the environs. The Unit 1 standby gas treatment system fans are designed to automatically start upon receipt of a high radiation signal from either the Unit 1 or Unit 2 refueling floor ventilation exhaust duct nonitors or the Unit 1 reactor building ventilation exhaust duct nonitors, or upon receipt of a signal from the Unit 1 prinary containment isolation system. The Unit 2 standby gas treatment system fans are designed to automatically start, '

to assist the Unit 1 fans to exhaust the Unit 1 secondary containment atmosphere upon receipt of a high radiation signal from either the. Unit 1 or Unit 2 re-fueling ficor ventilation exhaust duct monitors or the Unit i reactor buildina ventilation exhaust duct nonitors, or upon receipt of a signal from the Unit 1 primary containment isolation system. In addition, the systems may also be started manually, from the flain Control Room.

In the._ case of the Unit 1 standby gas treatment system, upon receipt of any of the isolation signals, both fans start, isolation danpers open and each fan draws air from the isolated Unit 1 secondary containment.

In the case of the Unit 2 standby gas treatment system, upon receipt of an isolation signal from the Unit 1 prinary containnent isolation system, reactor building ventilation exhaust duct monitors, or the Unit 1 or Unit 2 refueling floor ventilation exhaust duct nonitors, both fans start, fan supply and discharge dampers open, and the fans draw air from the isolated Unit 1 secondary containment.

Once the SGTS systems have been initiated autonatically, the operator may place any one of the Unit 1 and Unit 2 trains in the standby mode provided the re-maining train in each unit is operable. Should a failure occur in the remain-ing operating trains, resulting in air flow reduction below a preset value, the standby systems will restart automatically.

As a minimum for operation, one of the tuo Unit 1 standby gas treatment trains and one of the two Unit 2 standby gas treatment trains is required to achieve the design differential pressure, given the design building infiltration rate.

Once this design differential pressure is achieved, any leakage past the secondary containment boundary shall be inleakage.

A detailed discussion of the standby gas treatment systems may be found in Section 5.3.3.3 of the Unit 1 FSAR, and in Section 6.2.3 of the Unit 2 FSAR.

Any one of the four filter trains has sufficient absorption capacity to pro..

vide for cleanup of the Unit 1 secondary containment atmosphere following containment isolation. Any one of the four available standby gas treatment trains may be considered an installed spare. Therefore, with one of the standby gas treatment trains in each unit inoperable, there is no innediate threat to the Unit 1 containment system performance, and reactor operation or fuel handling operations nay continue wnile repairs are being made. Should either or both of the remaining standby gas treatment trains be found to be inoperable, the Unit 1 plant should be placed in a condition that does not require a standby gas treatment system.

3.7-32