ML052450157

Rev. 2 to Technical Specification Bases Unit 1 Manual

ML052450157
Person / Time
Site:	Susquehanna
Issue date:	08/25/2005
From:	Susquehanna
To:	Gerlach R Office of Nuclear Reactor Regulation
References
Download: ML052450157 (46)

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Aug. 25, 2005 Page 1 of 2 MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2005-35786 USER INFORMATION:

GERLACH*ROSE M EMPL#:028401 CA#: 0363 Address: NUCSA2 Phone#: 254-3194 TRANSMITTAL INFORMATION:

TO: GERLACH*ROSE M 08/25/2005 LOCATION: USNRC FROM: NUCLEAR RECORDS DOCUMENT CONTROL CENTER (NUCSA-2)

THE FOLLOWING CHANGES HAVE OCCURRED TO THE HARDCOPY OR ELECTRONIC MANUAL ASSIGNED TO YOU:

TSB1 - TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 08/23/2005 ADD MANUAL TABLE OF CONTENTS DATE: 08/24/2005 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT 3.6.1.3 REMOVE: REV:1 ADD: REV: 2 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT LOES REMOVE: REV:61

Aug. 25, 2005 Page 2 of 2 ADD: REV: 62 UPDATES FOR HARD COPY MANUALS WILL BE DISTRIBUTED WITHIN 5 DAYS IN ACCORDANCE WITH DEPARTMENT PROCEDURES. PLEASE MAKE ALL CHANGES AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX UPON RECEIPT OF HARD COPY. FOR ELECTRONIC MANUAL USERS, ELECTRONICALLY REVIEW THE APPROPRIATE DOCUMENTS AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX.

N SSES MANUAL r Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL Table Of Contents Issue Date: 08/23/2005 Procedure Name Rev Issue Date Change ID change Number TEXT LOES 61 07/06/2005

Title:

LIST OF EFFECTIVE SECTIONS mTF.X fCFA 7 04/1812005

Title:

TABLE OF CONTENTS TEXT 2.1.1 1 04/27/2004

Title:

SAFETY LIMITS (SLS) REACTOR CORE SLS TEXT 2.1.2 0 '11/15/2002

Title:

SAFETY LIMITS (SLS) REACTOR COOLANT SYSTEM (RCS) 'PRESSURE SL TEXT 3.0 1 04/18/2005 g

Title:

LIMITING CONDITION FOR OPERATION- (LCO) APPLICABILITY TEXT 3.1.1 0 i" f11/15/2002

Title:

REACTIVITY CONTROL SYSTEMS.SHUTDOWN MARGIN (SDM)

TEXT 3.1.2 a 0 11/15/2002

Title:

REACTIVITY CONTROL-SYSTEMS REACTIVITY ANOMALIES TEXT 3.1.3 - 1 07/06/2005

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD OPERABILITY TEXT 3.1.4 I U I/Ub/'UUD

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM TIMES TEXT 3.1.5 1 07/06/2005

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS TEXT 3.1.6 1 02/17/2005

Title:

REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Report Date: 08/24/05 Page 11 of of 88 Report Date: 08/24/05

SSES MANUAL

• Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.1.7 0 11/15/2002

Title:

REACTIVITY CONTROL SYSTEMS STANDBY LIQUID CONTROL (SLC) SYSTEM TEXT 3.1.8 0 11/15/2002

Title:

REACTIVITY CONTROL SYSTEMS SCRAM DISCHARGE VOLUME (SDV) VENT AND DRAIN VALVES TEXT 3.2.1 0 11/15/2002

Title:

POWER DISTRIBUTION LIMITS AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)

TEXT 3.2.2 0 11/15/2002

Title:

POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)

TEXT 3.2.3 0 11/15/2002

Title:

POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE (LHGR)

TEXT 3.2.4 1 07/06/2005

Title:

POWER DISTRIBUTION LIMITS AVERAGE POWER RANGE MONITOR (APRM). GAIN AND SETPOINTS _,f TEXT 3.3.1.1 2 07/06/2005

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATION TEXT 3.3.1.2 0 11/15/2002

Title:

INSTRUMENTATION SOURCE RANGE MONITOR (SRM) INSTRUMENTATION TEXT 3.3.1.3 0 11/22/2004

Title:

OPRM INSTRUMENTATION TEXT 3.3.2.1 1 02/17/2005

Title:

INSTRUMENTATION CONTROL ROD BLOCK INSTRUMENTATION TEXT 3.3.2.2 0 11/15/2002

Title:

INSTRUMENTATION FEEDWATER - MAIN TURBINE HIGH WATER LEVEL TRIP INSTRUMENTATION TEXT 3.3.3.1 2 07/06/2005

Title:

INSTRUMENTATION POST ACCIDENT MONITORING (PAM) INSTRUMENTATION Report Date: 08/24/05 Page22 Page of of 8 a Report Date: 08/24/05

SSES MANUAL

. Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.3.3.2 1 04/18/2005

Title:

INSTRUMENTATION REMOTE SHUTDOWN SYSTEM TEXT 3.3.4.1 0 11/15/2002

Title:

INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATION TEXT 3.3.4.2 0 11/15/2002

Title:

INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP (ATWS-RPT) INSTRUMENTATION TEXT 3.3.5.1 2 07/06/2005

Title:

INSTRUMENTATION EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION TEXT 3.3.5.2 0 11/15/2002

Title:

INSTRUMENTATION REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM INSTRUMENTATION TEXT 3.3.6.1 1 11/09/2004

Title:

INSTRUMENTATION PRIMARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.6.2 11/09/2004

Title:

INSTRUMENTATION SECONDARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.7.1 0 11/15/2002

Title:

INSTRUMENTATION CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM INSTRUMENTATION TEXT 3.3.8.1 1 09/02/2004

Title:

INSTRUMENTATION LOSS OF POWER (LOP) INSTRUMENTATION TEXT 3.3.8.2 0 11/15/2002

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORING TEXT 3.4.1 2 11/22/2004

Title:

REACTOR COOLANT SYSTEM (RCS) RECIRCULATION LOOPS OPERATING TEXT 3.4.2 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) JET PUMPS Report Date: 08/24/05 Page33 Page of 8 8 Report Date: 08/24/05

SSES MANUAL Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL

'JI TEXT 3.4.3 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) SAFETY/RELIEF VALVES (S/RVS)

TEXT 3.4.4 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE TEXT 3.4.5 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE TEXT 3.4.6 1 04/18/2005

Title:

REACTOR COOLANT SYSTEM (RCS) RCS LEAKAGE DETECTION INSTRUMENTATION TEXT 3.4.7 1 04/18/2005

Title:

REACTOR COOLANT SYSTEM (RCS) RCS SPECIFIC ACTIVITY TEXT 3.4.8 1 04/18/2005 S

Title:

REACTOR COOLANT SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM

- HOT SHUTDOWN TEXT 3.4.9 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM

- COLD SHUTDOWN TEXT 3.4.10 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE (P/T) LIMITS TEXT 3.4.11 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) REACTOR STEAM DOME PRESSURE TEXT 3.5.1 1 04/18/2005

Title:

EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM ECCS - OPERATING TEXT 3.5.2 0 11/15/2002

Title:

EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM ECCS - SHUTDOWN TEXT 3.5.3 1 04/18/2005

Title:

EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM RCIC SYSTEM .. I Report Date: 08/24/05 Page44 Page of of 88 Report Date: 08/24/05

SSES MANUAL Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.6.1.1 0 11/15/2002

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT TEXT 3.6.1.2 0 11/15/2002

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK TEXT 3.6.1.3 1 05/20/2005

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)

TEXT 3.6.1.4 0 11/15/2002

Title:

CONTAINMENT SYSTEMS CONTAINMENT PRESSURE TEXT 3.6.1.5 0 11/15/2002

Title:

CONTAINMENT SYSTEMS DRYWELL AIR TEMPERATURE TEXT 3.6.1.6 0 11/15/2002

__/

Title:

CONTAINMENT SYSTEMS SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKERS TEXT 3.6.2.1 0 11/15/2002

Title:

CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE TEXT 3.6.2.2 0 11/15/2002

Title:

CONTAINMENT SYSTEMS SUPPRESSION POOL WATER LEVEL TEXT 3.6.2.3 0 11/15/2002

Title:

CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL COOLING TEXT 3.6.2.4 0 11/15/2002

Title:

CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL SPRAY TEXT 3.6.3.1 1 04/18/2005

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS TEXT 3.6.3.2 1 04/18/2005

Title:

CONTAINMENT SYSTEMS DRYWELL AIR FLOW SYSTEM Report Date: 08/24/05 PageS Page 5 of of 8 8 Report Date: 08/24/05

SSES MANUAL

-Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.6.3.3 0 11/15/2002

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION TEXT 3.6.4.1 2 03/01/2005

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT TEXT 3.6.4.2 2 01/03/2005

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT ISOLATION VALVES (SCIVS)

TEXT 3.6.4.3 2 11/09/2004

Title:

CONTAINMENT SYSTEMS STANDBY GAS TREATMENT (SGT) SYSTEM TEXT 3.7.1 0 11/15/2002

Title:

PLANT SYSTEMS RESIDUAL HEAT REMOVAL SERVICE WATER (RHRSW) SYSTEM AND THE ULTIMATE HEAT SINK (UHS)

TEXT 3.7.2 1 11/09/2004

Title:

PLANT SYSTEMS EMERGENCY SERVICE WATER (ESW) SYSTEM TEXT 3.7.3 0 11/15/2002

Title:

PLANT SYSTEMS CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM TEXT 3.7.4 0 11/15/2002

Title:

PLANT SYSTEMS CONTROL ROOM FLOOR COOLING SYSTEM TEXT 3.7.5 0 11/15/2002

Title:

PLANT SYSTEMS MAIN CONDENSER OFFGAS TEXT 3.7.6 1 01/17/2005

Title:

PLANT SYSTEMS MAIN TURBINE BYPASS SYSTEM TEXT 3.7.7 0 11/15/2002

Title:

PLANT SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL TEXT 3.8.1 2 04/18/2005

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING Report Date: 08/24/05 Page66 Page of of 8 8 Report Date: 08/24/05

SSES MANUAL

Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.8.2 0 11/15/2002

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - SHUTDOWN TEXT 3.8.3 0 11/15/2002

Title:

ELECTRICAL POWER SYSTEMS DIESEL FUEL OIL, LUBE OIL, AND STARTING AIR TEXT 3.8.4 0 11/15/2002

Title:

ELECTRICAL POWER SYSTEMS DC SOURCES - OPERATING TEXT 3.8.5 0 11/15/2002

Title:

ELECTRICAL POWER SYSTEMS DC SOURCES - SHUTDOWN TEXT 3.8.6 0 11/15/2002

Title:

ELECTRICAL POWER SYSTEMS BATTERY CELL PARAMETERS TEXT 3.8.7 0 11/15/2002 i

Title:

ELECTRICAL POWER SYSTEMS DISTRIBUTION SYSTEMS - OPERATING TEXT 3.8.8 0 11/15/2002

Title:

ELECTRICAL POWER SYSTEMS DISTRIBUTION SYSTEMS - SHUTDOWN TEXT 3.9.1 0 11/15/2002

Title:

REFUELING OPERATIONS REFUELING EQUIPMENT INTERLOCKS TEXT 3.9.2 0 11/15/2002

Title:

REFUELING OPERATIONS REFUEL POSITION ONE-ROD-OUT INTERLOCK TEXT 3.9.3 0 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION TEXT 3.9.4 0 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD OPERABILITY - REFUELING Report Date: 08/24/05 Page77 Page of of 88 Report Date: 08/24/05

SSES MANUAL r

Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL 4

TEXT 3.9.6 0 11115/2002

Title:

REFUELING OPERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL TEXT 3.9.7 0 11/15/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - HIGH WATER LEVEL TEXT 3.9.8 0 11/15/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - LOW WATER LEVEL TEXT 3.10.1 0 11/15/2002

Title:

SPECIAL OPERATIONS INSERVICE LEAK AND HYDROSTATIC TESTING OPERATION TEXT 3.10.2 0 11/15/2002

Title:

SPECIAL OPERATIONS REACTOR MODE SWITCH INTERLOCK TESTING TEXT 3.10.3 0 11/15/2002

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - HOT SHUTDOWN J TEXT 3.10.4 0 11/15/2002 -

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - COLD SHUTDOWN TEXT 3.10.5 0 11/15/2002

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD DRIVE (CRD) REMOVAL - REFUELING TEXT 3.10.6 0 11/15/2002

Title:

SPECIAL OPERATIONS MULTIPLE CONTROL ROD WITHDRAWAL - REFUELING TEXT 3.10.7 0 11/15/2002

Title:

SPECIAL OPERATIONS CONTROL ROD TESTING - OPERATING TEXT 3.10.8 0 11/15/2002

Title:

SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING Report Date: 08/24/05 Page88 Page of of 8B Report Date: 08/24/05

SUSQUEHANNA STEAM ELECTRIC STATION UST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

Section Title -I Revision TOC Table of Contents 7.

B2.0 SAFETY LIMITS BASES Page B 2.0-1 0 PageTS/B2.0-2 2 Page TS/B2.0-3 3.

Pages TS/ B 2.0-4 and TS / B2.0-5 .2 PageTS/B2.0-6 I Pages B 2.0-7 through B2.0-9 0.

It B 3.0 LCO AND SR APPLICABILITY BASES Pages B 3.0-1 through B3.0-4 0 Pages TS / B 3.0-5 through TS / B 3.0-7 I Pages TS / B3.0-8 through TS / B 3.0-9 / 2 Pages TS / B 3.0-10 through TS / B 3.0-12\,,' I Pages TS / B 3.0-13 through TS / B 3:.0-15 1 2 Pages TS / B 3.0-16 and TS/ B3.07.i7 ,7 0

' B3.1 REACTIVITY CONTROL BASES N ,1'4

• 0 Pages B 3.1-1 through B 3:1;5, Pages TS / B 3.1- andTS,/ B 3.--' I Pages B 3.1-8 through B 3.1-13>, 0 PageTS/B3.1-14,' " \ ; I Pages B 3.1-15,tliroughB 31-22 - 0 Page TS/B31-23 \ I Pages B 3.1-24through B 3.1-27 0 Page TS /1B,3.1-28':, ' I Page 1TS i B 3.1-29 I Pages B 3.1-30'through B 3.1-33 0 Pages TS /8 3.3-34 through TS / B 3.3-36 1.

fPageTS /B 3.1-37 2

('PageTS / B 3.1-38 I

\ XPages B 3.1-39 through B 3.1-51 I B3.2 POWER DISTRIBUTION LIMITS BASES Page TS / B 3.2-1 1 Page TS / B 3.2-2 2 Page TS / B 3.2-3 1 Page TS / B 3.2-4 2 Pages TS / B 3.2-5 and TS/B 3.2-6 1I Page B 3.2-7 0 Pages TS I B 3.2-8 through TS I B 3.2-10 I Page TS / B 3.2-11 .2 Page B 3.2-12 1.0 Page TS / B 3.2-13 2 Pages B 3.2-14 and B3.2-15 0 Page TS / B 3.2-16 2 TSIBLOES-1 Revision 62 SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT I1 TS I B LOES-1 IRevision 62

SUSQUEHANNA STEAM ELECTRIC STATION LIST OFEFFECTIVESECTIONS (TECHNICAL SPECIFICATIONS BASES)

ISection Title Revision Pages B 3.2-17 and B 3.2-18 0 Page TS / B 3.2-19 3 B 3.3 INSTRUMENTATION Pages TS / B 3.3-1 through TS / B 3.3-4 .1 Page TS / B 3.3-5 2 PageTS/B3.3-6 I Pages TS / B 3.3-7 through TS / B 3.3-11 2 Page TS / B 3.3-12 PageTS/B3.3-13 I Page TS / B 3.3-14 2 Pages TS / B 3.3-15 and TS / B 3.3-16 I Pages TS / B 3.3-17 and TS / B 3.3-18 2 Pages TS / B 3.3-19 through TS / B 3.3-27 .1 Pages TS / B 3.3-28 through TS / B 3.3-31 Pages TS / B 3.3-32 and TS / B 3.3-33 4 Pages TS / B 3.3-34 through TS / B 3.3-43 I Pages TS / B 3.3-43a through TS I B 3.3-43i 0 Pages TS I B 3.3-44 through TS / B 3.3-50 2 Pages TS I B 3.3-51 through TS / B 3.3-53 I Page TS / B 3.3-54 2 Pages B 3.3-55 through .B 3.3-63

• 0 Pages TS / B 3.3-64 and TS B 3.3-65 2 Page'TS / B 3.3-66

• 4.

Page TS/B3.3-67 - . . .3 Page TS / B 3.3-68 4 Pages TS / B 3.3-69 and TS I B 3.3-70 .3 Page TS / B 3.3-71 3 Pages TS / 3.3-72 through TS 3.3-75 2'

'Page TS / B 3.3-75a 4 Pages TS / B 3.3-75b and TS / B 3.3-75c 4 Pages B 3.3-76 through 3.3-77 0 Page TS / B 3.3-78 Pages B 3.3-79 through B 3.3-89 0 Page TS / B 3.3-90 1*

Page B 3.3-91 0 Page TS / B 3.3-92 through TS / B 3.3-1 00, I Pages B 3.3-1 01 through B 3.3-103 0 Page TS / B 3.3-104 I Pages B 3.3-105 and B 3.3-106 0 PageTSI/B3.3-107 I Page B 3.3-108 0 Page TS / B 3.3-109

• I Pages B 3.3-110 and B 3.3-111 0 Pages TS / B 3.3-112 and TS / B 3.3-112a I Pages TS / B 3.3-113 and TS / B 3.3-114 *1 Page TS / B 3.3-115 I Revision 62 SUSQUEHANNA -UNIT

- SUSQUEHANNA - UNIT I1 TS / B LOES-2 IS/B LOES-2 Revision 62-

SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

Section Title - . Revision Page TS / B 3.3-116 . .0 Page TS / B 3.3-117 Pages B 3.3-118 through B 3.3-122 Pages TS / B 3.3-123 and TS / B 3.3-124 - .1

- 2 Page TS / B 3.3-124a Page B 3.3-125 Page TS I B 3.3-126 Page TS / B 3.3-127 Pages B 3.3-128 through B 3.3-130 - '.1 Page TS / B 3.3-131 Pages B 3.3-132 through B 3.3-137 Page TS / B 3.3-138 Pages B 3.3-139 through B 3.3-149 .,2 Page TS / B 3.3-150 through TS / B 3.3-162 Page TS / B 3.3-163 Pages TS / B 3.3-164 through TS / B 3.3-177 Pages TS / B 3.3-178 and TS / B 3.3-179 Page TS / B 3.3-179a Page TS / B 3.3-179b 1*

Page TS / B 3.3-179c Page TS / B 3.3-180 2 Page TS / B 3.3-181 * ~ O Pages TS I B 3.3-182 through TS I B 3.3-186 *0 Pages TS / B 3.3-187 and TS / B 3.3-188 .' 1 Pages TS / B 3.3-189 through TS / B 3.3-191 0 Pages B 3.3-192:through B 3.3-204 Page TS / B 3.3-205 Pages B 3.3-206 through B 3.3-219 B 3.4 REACTOR COOLANT SYSTEM BASES Pages B 3.4-1 and B 3.4-2 O0 Page TS / B 3.4-3 and Page TS I B 3.4-4 3 Pages TS / B 3.4-5 through TS / B 3.4-9 2 Pages B 3.4-10 through B 3.4-14 Page TS / B 3.4-15 1 '.'

Pages TS / B 3.4-16 and TS / B 3.4-17 2 Page TS / B 3.4-18 1 Pages B 3.4-19 through B 3.4-28 0 Page TS / B 3.4-29 1 Pages B 3.4-30 and B 3.4-31 0 Page TS /B 3.4-32 I 1 Pages B 3.4-33 through B 3.4-36

• 0~

Page TS / B 3.4-37 I Pages B 3.4-38 through B 3.4-40 0 Page TS / B 3.4-41 1 Pages B 3.4-42 through B 3.4-48 0' Page TS / B 3.4-49 2 TS/BLOES-3 Revision 62

- SUSQUEHANNA-UNITi SUSQUEHANNA -UNIT 1- TS /B LOES-3 Revision 62

SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

.. Section Title Revision Page TS / B 3.4-50 Page TS / B 3.4-51 2 Pages TS / B 3.4-52 and TS I B 3.4-53 I1 Page TS / B 3.4-54 2 Page TS / B 3.4-55 2 Page TS / B 3.4-56 1 Page TS/B3.4-57 2 Pages TS / B 3.4-58 through TS / B 3.4-60 1.

B 3.5 ECCS AND RCIC BASES Pages B 3.5-1 and B 3.5-2 0 Page TS /B 3.5-3 2 PageTS/B3.5-4 1 PageTS/B3.5-5 2 PageTSIB3.5-6 1 Pages B 3.5-7 through B 3.5-10 0.

Page TS / B 3.5-11 I Pages B 3.5-12 through B 3.5-15 01 Pages TS / B 3.5-16 through TS / B 3.5-18 Pages B 3.5-19 through B 3.5-24 01 Page TS / B 3.5-25 1 Pages TS / B 3.5-26 andTSI B 3.5-27 Pages B 3.5-28 through B 3.5-31 0 B 3.6 CONTAINMENT SYSTEMS BASES Page TS / B 3.6-1 2 Page TS / B 3.6-1a 3 Pages TS / B 3.6-2 through TS I B 3.6-5 2 Page TS I B 3.6-6 3.

Pages TS / B 3.6-6a and TS I B 3.6-6b 2 Page TS / B 3.6-6c 0 Pages B 3.6-7 through B 3.6-14 .0 Page TS / B 3.6-15 2 Pages TS / B 3.6-15a and TS I B 3.6-15b 0 Page B 3.6-16 0 Page TS B 3.6-17 1 Page TS B 3.6-17a 0 PagesTS/B3.6-18andTS/B3.6-19 0 Page TS / B 3.6-20 *1 Page TS / B 3.6-21 2 Page TS I B 3.6-22 1 Page TS / B 3.6-22a r0 Page TS /B 3.6-23 Pages TS / B 3.6-24 through TS I B 3.6-25 0 Page TS / B 3.6-26 1 .1 Page TS / B 3.6-27 2 Page TS / B 3.6-28 5 TSIBLOES-4 Revision 62 SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT I1 ITS I B LOES-4 Revision 62

SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVESECTIONS (TECHNICAL SPECIFICATIONS BASES)

Section Title Revision Page TSIB3.6-29 Page TS I B 3.6-30 Page TS / B 3.6-31 3 Page B 3.6-32 0 Page TS/B3.6-33 Pages B 3.6-34 and B 3.6-35 I0 Page TS / B 3.6-36 Page B 3.6-37 0.

Page TS/B3.6-38 1I Page B 3.6-39 0.

Page TS / B 3.6-40 Pages B 3.6-41 through B 3.6-43 Pages TS / B 3.6-44 through TS / B3.6-51 3 Page TS / B 3.6-52 20 Pages B 3.6-53 through B 3.6-63 0O PageTS/B3.6-64 1 Pages B 3.6-65 through B 3.6-72 Page TS / B 3.6-73 Pages B 3.6-74 through B 3.6-77 Page TS/B3.6-78 Pages B 3.6-79 through B 3.3.6-83 Page TS / B 3.6-84 3 Pages TS J B 3.6-85 and TS I B3.6-86 2 Pages TS / B3.6-87 through TS / B3.6-88a 1.

Page TS /B 3.6-89 3 Page TS / B 3.6-90 .1 Page TS / B 3.6-91 .. 3.

Pages TS / B 3.6-92 through TS /B 3.6-96 3 Page TS / B 3.6-97 -2 Pages TS / B 3.6-98 and TS /B 3.6-99 Page TS / B 3.6-100 - 2 Pages TS / B 3.6-101 and TS / B 3.6-102 Pages TS / B 3.6-103 through TS / B 3.6-105 2 Pages TS / B 3.6-106 and TS / B 3.6-107 - *1 B3.7 PLANT SYSTEMS BASES Pages TS / B 3.7-1 through TS / B 3.7-6 2 Page TS / B 3.7-6a 2 PagesTS / B 3 3.7-6b and TS / B 3.7-6c O Page TS / B 3.7-7 I 2 Pages TS / B 3.7-8 through TS / B 3.7-11 I.

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• s SUSQUEHANNA - UNIT 1 TS /B LOES-5 Re-vision 62

SUSQUEHANNA STEAM ELECTRIC STATION UST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

Section Title Revision Page TS / B 3.7-30 2 Pages B 3.7-31 through B 3.7-33 - 0 B 3.8 ELECTRICAL POWER SYSTEMS BASES Pages TS J B 3.8-1 through TS / B 3.8-4 - 2 Page TS / B 3.8-5 4 Page TS I B 3.8-6 3 Pages TS / B 3.8-7 through TS/B 3.8-8 *2 Pages TS / B 3.8-9 and TS / B 3.8-10 3 Pages TS / B 3.8-11 and TS/ B 3.8-17 2 Page TS / B 3.8-18 3 Pages TS / B 3.8-19 through TS I B 3.8-21 2 Pages TS I B 3.8-22 and TS / B 3.8-23 3 Pages TS / B 3.8-24 through TS / B3.8-37 2 Pages B 3.8-38 through B 3.8-53 0 Pages TS / B 3.8-54 through TS I B 3.8-61 1

.PageTS / B 3.8-62 - 2 PageTS/B 3.8-63 -2 Page TS / B 3.8-64 1 Page TS / B 3.8-65 2 Pages B 3.8-66 through B 3.8-90 0 B 3.9 REFUELING OPERATIONS BASES Pages TS/ B 3.9-1 and TS B 3.9-1aa 1 Pages TS / B 3.9-2 through TS / B 3.9-4 - 1

- Pages B 3.9-5 through B 3.9-30 . 0 B 3.10 SPECIAL OPERATIONS BASES PageTS/B3.10-1 -

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TSB1 texd LOES 8/12/05 SUJSQUEHANNA - UNIT I TS/I B LOES-6 Revision 62

PPL Rev. 2 PCIVs B 3.6.1.3 B 3.6 CONTAINMENT SYSTEMS B 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

BASES BACKGROUND The function of the PCIVs, in combination with other accident mitigation systems, is to limit fission product release during and following postulated Design Basis Accidents (DBAs) to within limits. Primary containment isolation within the time limits specified for those isolation valves designed to close automatically ensures that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a DBA.

The OPERABILITY requirements for PCIVs help ensure that an adequate primary containment boundary is maintained during and after an accident by minimizing potential paths to the environment.

Therefore, the OPERABILITY requirements provide assurance that primary containment function assumed in the safety analyses will be maintained. For PCIVs, the primary containment isolation function is that the valve must be able to close (automatically or manually) and/or remain closed, and maintain leakage within that assumed in the DBA LOCA Dose Analysis. These isolation devices are either passive or active (automatic); Manual valves, de-activated automatic valves secured in their closed position (including check valves with flow through the valve secured), blind flanges, and closed systems are considered passive devices. The' OPERABILITY requirements for closed systems are discussed in Technical Requirements Manual (TRM) Bases 3.6.4. Check valves, or other automatic valves designed to close without operator action following an accident, are considered active devices. Two barriers in series are provided for each penetration so that no single credible failure or malfunction of an active component can result in a loss of isolation or leakage that exceeds limits assumed in the safety analyses. One of these barriers may be a closed system.

For each division of H202 Analyzers, the lines, up to and including the first normally closed valves within the H202 Analyzer panels, are extensions of primary containment (i.e.,

closed system), and are required to be leak rate tested in (continued)

SUSQUEHANNA - UNIT I .. .

TS / B 3.6-15 Revision 2

PPL Rev. 2 PCIVs

-'B 3.6.1.3 BASES I

'.X, BACKGROUND accordance with the Leakage Rate Test Program. The H202 (continued) Analyzer closed system boundary is identified in the Leakage Rate Test Program. The closed system boundary consists of those components, piping, tubing, fittings, and valves, which meet the guidance of Reference 6. The closed system provides a secondary barrier in the event of a single failure of the PCIVs, as described below. The closed system boundary between PASS and the H202 Analyzer system ends at the process sampling solenoid operated isolation valves between the systems (SV-12361, SV-12365, SV-12366, SV-12368, and SV-12369). These solenoid operated isolation valves do not fully meet the guidance of Reference 6 for closed system boundary valves in that they are not powered from a Class 1E power source. However, based upon a risk determination, operating these valves as closed system boundary valves is not risk significant. These valves also form the end of the Seismic Category I boundary between the.

systems. These process sampling solenoid operated isolation valves are normally closed and are required to be leak rate tested in accordance with the Leakage Rate Test Program as part of the closed system for the H202 Analyzer system. These valves are Mclosed system boundary valves" and may be opened under administrative control, as delineated in Technical Requirements Manual (TRM) Bases 3.6.4. Opening of these valves to permit testing of PASS in Modes 1, 2, and 3 is permitted in accordance with TRO 3.6.4.

Each H202 Analyzer Sampling line penetrating primary containment has two PCIVs, located just outside primary.

containment While two PCIVs are provided on each line, a single active failure of a relay in the control circuitry for these valves, could result in both valves failing to close or failing to remain closed. Furthermore, a single failure (a hot short in the common raceway to all the valves) could simultaneously affect all of the PCIVs within a H202 Analyzer division. Therefore, the containment isolation barriers for these penetrations consist of two

'PCIVs and a closed system. For situations where one or both PCIVs are inoperable, the ACTIONS to be taken are similar to the ACTIONS for a single PCIV backed by a closed system.

(continued)

SUSQUEHANNA- UNIT 1 TS / B 3.6-15a Revision 0

PPL Rev. 2 PCIVs B 3.6.1.3 BASES - --

BACKGROUND The drywell vent and purge lines are 24 inches in diameter; (continued) the suppression chamber vent and purge lines are 18 inches in diameter. The containment purge valves are normally maintained closed in MODES 1, 2, and 3 to ensure the primary containment boundary is maintained. The outboard isolation valves have 2 inch bypass lines around them for use during normal reactor operation.

j

-I (continued) -

SUSQUEHANNA- UNIT 1 TS / B 3.6-15b Revision 0

- I

PPL Rev. 2 PCIVs B 3.6.1.3 BASES (continued)

APPLICABLE The PCIVs LCO was derived from the assumptions related SAFETY ANALYSES to minimizing the loss of reactor coolant inventory, and establishing the primary containment boundary during major accidents. As part of the primary containment boundary, PCIV OPERABILITY supports leak tightness of primary containment.

Therefore, the safety analysis of any event requiring isolation of primary containment is applicable to this LCO.

The DBAs that result in a release of radioactive material within primary containment are a LOCA and a main steam line break (MSLB). Inthe analysis for each of these accidents, it is assumed that PCIVs are either closed or close within the required isolation times following event initiation. This ensures that potential paths to, the environment through PCIVs (including primary containment purge valves) are minimized. Of the events analyzed in Reference 1,the.

MSLB is the most limiting event due to radiological consequences.

The closure time of the main steam isolation valves (MSIVs) is a significant variable from a radiological standpoint. The MSIVs are required to close within 3 to 5 seconds since the 5 second closure time is assumed in the analysis. The safety analyses assume that the purge valves were closed at event initiation. Likewise, it is assumed.

that the primary containment is isolated such that release of fission products to the environment is controlled.

The DBA analysis assumes that within the required isolation time leakage is terminated, except for the-maximum allowable leakage rate, L-.

The single failure criterion required to be imposed in the conduct of unit safety analyses was considered in the original design of the primary containment purge valves. Two valves in series on each purge line provide assurance that both the supply and exhaust lines could be isolated even if a single failure occurred.

The primary containment purge valves may be unable to close in the environment following a LOCA. Therefore, each of the purge valves is required to remain closed during MODES 1,2, and 3 except as permitted under Note 2 of SR 3.6.1.3.1. In this case, the single failure criterion remains applicable to the primary containment purge valve (continued)

SUSQUEHANNA -UNITI1 B 3.6-1 Revision 0,

PPL Rev. 2 PCI Vs B 3.6.1.3 BASES APPLICABLE due to failure in the control circuit associated with each SAFETY ANALYSES valve. The primary containment purge valve design (continued) precludes a single failure from compromising the primary containment boundary as long as the system is operated in accordance with this LCO.

Both H202 Analyzer PCIVs may not be able to close given a single failure in the control circuitry of the valves. The single failure is caused by a "hot short" in the cables/raceway to the.PCIVs that causes both PCIVs for a given penetration to remain open or to open when required to be closed. This failure is required to be considered in accordance with IEEE-279 as discussed in FSAR Section 7.3.2a. However, the single failure criterion for containment isolation of the H202 Analyzer penetrations is satisfied by virtue of the combination of the associated PCIVs and the closed system formed by the H202 Analyzer.piping system as discussed in the BACKGROUND section above.

The closed system boundary between PASS and the H202 Analyzer system ends at the process sampling solenoid operated isolation valves between the systems (SV-12361, SV-12365, SV-12366, SV-12368, and SV-12369). The closed system is not fully qualified to the guidance of Reference 6 in that the closed system boundary valves between the H202 system and PASS are not powered from a Class 1E power source. However, based upon a risk determination, the use of these valves is considered to have no risk significance. This exemption to the requirement of Reference 6 for the closed system boundary is documented in License Amendment No. 195.

PCIVs satisfy Criterion 3 of the NRC Policy Statement. (Ref. 2)

LCO PCIVs form a part of the primary containment boundary. The PCIV safety function is related to minimizing the loss of reactor coolant inventory and establishing the primary containment

- boundary during a DBA.

The power operated, automatic isolation valves are required to have isolation times within limits and actuate on an automatic isolation signal. The valves covered by this LCO are listed in Table B 3.6.1.3-1. .

(continued)

SUSQUEHANNA - UNIT I TS IB 3.6-17 Revision I

PPL Rev. 2 PCIVs

- B 3.6.1.3 BASES LCO The normally closed PCIVs are considered OPERABLE (continued) when manual valves are closed or open in accordance with appropriate administrative controls, automatic valves are in their closed position, blind flanges are in place, and closed systems are intact These passive isolation valves and devices are those listed in Table B 3.6.1.3-1.

-Purge valves with resilient seals, secondary containment bypass valves, MSIVs, and hydrostatically tested valves must meet additional leakage rate requirements. Other PCIV leakage rates are addressed by LCO 3.6.1.1, "Primary Containment," as Type B or C testing.

This LCO provides assurance that the PCIVs will pefom their designed safety functions to minimize the loss of reactor coolant inventory and establish the primary containment boundary during accidents.

APPLICABILITY In MODES 1, 2, and 3, a DBA could cause a release of radioactive material to primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES.

Therefore, most PCIVs are not required to be (continued)

SUSQUEHANNA -UNIT 1I - TS/B3.6-17a Revision 0

PPL Rev. 2 PCIVs BASESB 3.6.1.3

~BASES APPLICABILITY OPERABLE and the primary containment purge valves are (continued) not required to be closed in MODES 4 and 5. Certain valves, however, are required to be OPERABLE to prevent inadvertent reactor vessel draindown. These valves are those whose associated instrumentation is required to be OPERABLE per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation."

(This does not include the valves that isolate the associated instrumentation.)

ACTIONS The ACTIONS are modified by a Note allowing penetration flow path(s) to be unisolated intermittently under administrative controls. These controls consist of stationing a dedicated operator at the controls of the valve, who is in continuous communication with the control room. In this way, the penetration can be rapidly isolated when a need for primary containment isolation is indicated.

A second Note has been added to provide clarification that, for the purpose of this LCO, separate Condition entry is allowed for each penetration flow path. This is acceptable, since the Required Actions for each Condition provide appropriate compensatory

actions-for each inoperable PCIV. Complying with the Required Actions may allow for continued operation, and subsequent inoperable PCIVs are governed by subsequent Condition entry and application of associated Required Actions.

The ACTIONS are modified by Notes 3 and 4. Note 3 ensures that appropriate remedial actions are taken, if necessary, if the affected system(s) are rendered inoperable by an inoperable PCIV' (e.g., an Emergency Core Cooling System subsystem is inoperable due to a failed open test return valve). Note 4 ensures appropriate remedial actions are taken when the primary containment leakage limits are exceeded. Pursuant to LCO 3.0.6, these actions are not required even when the associated LCO is not met. Therefore, Notes 3 and 4 are added to require the proper actions be taken.

A.1 and A.2 With one or more penetration flow paths with one PCIV inoperable except for purge valve leakage not within limit,

) ' (continued)

SUSQUEHANNA -UNIT 1 B 3.6-18 Revision 0

PPL Rev. 2 PCIVs B 3.6.1.3 BASES ACTIONS A.1 and A.2 (continued) the affected penetration flow paths must be isolated. The method of isolation must include the use of at least onelisolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, a blind flange, and a check valve with flow through the valve secured. For a penetration isolated in accordance with Required Action A.1, the device used to isolate the penetration should be the closest available valve to the primary containment. The' Required Action must be completed within the 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time (8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for main steam lines). The Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is reasonable considering the time required to isolate the penetration and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. For main steam lines, an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Completion Time is allowed. The Completion Time of 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for the main steam lines allows a period of time to restore the MSIVs to OPERABLE status given the fact that MSIV closure will result in isolation of the main steam line(s) and a potential for plant shutdown.

For affected penetrations that have been isolated in accordance with Required Action A.1, the affected penetration flow path(s) must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident, and no longer capable of being automatically isolated, will be in the isolation position should an event occur: This Required Action does not require any testing or device manipulation. Rather, it involves verification that those devices outside containment and capable of potentially being mispositioned are in the.correct position. The Completion Time of "once per 31 days for isolation devices outside primary containment" is appropriate because the devices are operated under administrative controls and the probability of their misalignment is low. For the devices inside primary containment, the time period specified "prior to entering MODE 2 or 3 from MODE 4, if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days" is based on engineering judgment and is considered reasonable in view of the inaccessibility of the devices and other administrative controls ensuring that device misalignment is an unlikely possibility.

(continued)

SUSQUEHANNA - UNIT I B 3.6-19 Revision 0

PPL Rev. 2 PCIVs B 3.6.1.3 BASES ACTIONS A.1 and A.2 (continued)

Condition A is modified by a Note indicating that this Condition is only applicable to those penetration flow paths with two PCIVs except for the H202 Analyzer penetrations.

For penetration flow paths with one PCIV, Condition C provides the appropriate Required Actions. Forthe H202 Analyzer Penetrations, Condition D provides the appropriate Required Actions.

Required Action A.2 is modified by a Note that applies to isolation devices located in high radiation areas, and allows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted. Therefore, the probability of misalignment of these devices, once they have been verified to be in the proper position, is low.

BA1 With one or more penetration flow paths with two PCIVs inoperable except for purge valve leakage not within limit, either the inoperable PCIVs must be restored to OPERABLE status or the affected penetration flow path must be isolated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this'criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time is consistent with the ACTIONS of LCO 3.6.1.1.

Condition B is modified by a Note indicating this Condition is only applicable to penetration flow paths with two PCIVs except for the H202 Analyzer penetrations. For penetration flow paths with one PCIV, Condition C provides the appropriate Required Actions. For the H202 Analyzer Penetrations, Condition D provides the appropriate Required Actions.

C.1 and C.2 With one or more penetration flow paths with one PCIV inoperable, the inoperable valve must be restored to OPERABLE status or the affected penetration flow path (continued)

SUSQUEHANNA - UNIT 1 TS IB 3.6-20 Revision I

PPL Rev. 2 PCIVs B 3.6.1.3 BASES ACTIONS C.1 and C.2 (continued) must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action C.1 must be completed within the 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the relative stability of the closed system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. The closed system must meet the requirements of Reference 6. For conditions where the PCIV and the closed system are inoperable, the Required Actions of TRO 3.6.4, Condition B apply. For the Excess Flow Check Valves (EFCV), the Completion Time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is reasonable considering the instrument and the small pipe diameter of penetration (hence, reliability) to act as a penetration isolation boundary and the small pipe diameter of the affected penetrations. In the event the affected penetration flow path is isolated in accordance with Required Action C.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment-penetrations required to be isolated following an accident are isolated. The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the valves are operated under administrative controls and the probability of their misalignment is. low.

Condition C is modified by a Note indicating that this Condition is only applicable to penetration flow paths with only one PCIV. For penetration flow paths with two PCIVs and the H202 Analyzer Penetration. Conditions A, B and D provide the appropriate Required Actions.

Required Action C.2 is modified by a Note that applies to valves and blind flanges located in high radiation areas and allows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted. Therefore, the probability of misalignment of these valves, once they have been verified to be in the proper position, is low.

(continued)

SUSQUEHANNA - UNIT I TS / B 3.6-21 Revision 2

PPL Rev. 2:

PCIVs B 3.6.1.3 BASES ACTIONS D.l and D.2 (continued)

With one or more H202 Analyzer penetrations with one or both PCIVs inoperable, the inoperable valve(s) must be restored to OPERABLE status or the affected penetration flow path must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action D.1 must be completed.

within the 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the unique design of the H2 02 Analyzer penetrations. The containment isolation barriers for these penetrations consist of two PCIVs and a closed system. In addition, the Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the relative stability of the closed system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. In the event the affected penetration flow path is isolated in accordance with Required Action D.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident are isolated. The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the valves are operated under administrative controls and the probability of their misalignment is low.

When an H202 Analyzer penetration PCIV is to be closed and deactivated in accordance with Condition D, this must be accomplished by pulling the fuse for the power supply, and either determinating the power cables at the solenoid valve, or jumpering of the power side of the solenoid to ground.

The OPERABILITY requirements for the closed system are discussed in Technical Requirements Manual (TRM) Bases 3.6.4.

In the event that either one or both of the PCIVs and the closed system are inoperable, the Required Actions of TRO 3.6.4, Condition B apply.

(continued)'

SUSQUEHANNA - UNIT I TS IB 3.6-22 Revision I

PPL Rev. 2 PCI Vs B 3.6.1.3 BASES ACTIONS D.1 and D.2 (continued)

Condition D is modified by a Note indicating that this Condition is only applicable to the H2 0 2 Analyzer penetrations.

E.1 With the secondary containment bypass leakage rate not within limit, the assumptions of the safety analysis may not be met.

Therefore, the leakage must be restored to within limit within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. Restoration can be accomplished by isolating the penetration that caused the limit to be exceeded by use of one closed and de-activated automatic valve, closed manual valve, or blind flange. When a penetration is isolated, the leakage rate for the isolated penetration is assumed to be the actual pathway leakage through the isolation device. If two isolation devices are used to isolate the penetration, the leakage rate is assumed to be the lesser actual pathway leakage of the two devices. The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time is reasonable considering the time required to restore the leakage by isolating the penetration and the relative importance of secondary containment bypass leakage to the overall containment function.

F.1*

In the event one or more containment purge -valves are not within the purge valve leakage limits, purge valve 16tikage must be restored to within limits. The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Completion Time is reasonable, considering that one containment purge valve remains closed, except as controlled by SR 3.6.1.3.1 so that a gross breach of containment does not exist G.1 and G.2 If any Required Action and associated Completion Time cannot be met in MODE 1, 2, or 3, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and to MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

(continued)

SUSQUEHANNA'- UNIT I TS IB 3.6-22a Revision 0

PPL Rev. 2

-PCIVs B 3.6.1.3 IBASES ACTIONS H.1 and H.2 (continued)

If any Required Action and associated Completion Time cannot be met, the unit must be placed in a condition in which the LCO does not apply. If applicable, action must be immediately initiated to suspend operations with a potential for draining the reactor vessel (OPDRVs) to minimize the probability of a vessel draindown and subsequent potential for fission product release. Actions must continue until OPDRVs are suspended or valve(s) are restored to OPERABLE status. If suspending an OPDRV would result in closing the residual heat removal (RHR) shutdown cooling isolation valves, an alternative Required Action is provided to immediately initiate action to restore the valve(s) to OPERABLE status. This allows RHR to remain in service while actions are being taken to restore the valve.

SURVEILLANCE SR 3.6.1.3.1 REQUIREMENTS This SR ensures that the primary containment purge valves are closed as required or, if open, open for an allowable reason. If a purge valve is open in violation of this SR, the valve is considered inoperable. Ifthe inoperable valve is not otherwise known to have excessive leakage when closed, it is not considered to have leakage outside of limits. The SR is also modified by Note 1, stating that primary containment purge valves are only required to be closed in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, the purge valves may not be capable of closing before the pressure pulse affects systems downstream of the purge valves, or the release of radioactive material will exceed limits prior to the purge valves closing. At other times when the purge valves are required to be capable of closing (e.g., during handling of irradiated fuel), pressurization concerns are not present and the purge valves are allowed to be open. The SR is modified by Note 2 stating that the SR is not required to be met when the purge valves are open for the stated reasons. The Note states that these valves may be opened for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open. The vent and purge valves are capable of Closing in the environment following a LOCA. Therefore, these valves are allowed to be open for (continued)

SUSQUEHANNA- UNIT I -TS / B3.6-23 Revision 1

PPL Rev. 2 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.1 (continued)

REQUIREMENTS limited periods of time. The 31 day Frequency is consistent with other PCIV requirements discussed in SR 3.6.1.3.2.

SR 3.6.1.3.2 This SR verifies that each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits.

This SR does not require any testing or valve manipulation.

Rather, it involves verification that those PCIVs outside primary containment, and capable of being mispositioned, are in the correct position. Since verification of valve position for PCIVs outside primary containment is relatively easy, the 31 day Frequency was chosen to provide added assurance that the PCIVs are in the correct positions.

Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be

-I , - verified by use of administrative controls. Allowing verification by administrative controls is considered-acceptable since access to these areas is typically restricted during MODES 1,2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in the proper

- position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PCIVs are open. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.

SR 3.6.1.3.3 This SR verifies that each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise (continued)

SUSQUEHANNA

. - UNIT B 3.6-24 Revision 0

PPL Rev. 2 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.3 (continued)

REQUIREMENTS secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits. For PCIVs inside primary containment, the Frequency defined as "prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days" is appropriate since these PCIVs are operated under administrative controls and the probability of their misalignment is low. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing. Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable since the primary containment is inerted and access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in their proper position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PCIVs are open.

SR 3.6.1.3.4 The traversing incore probe (TIP) shear isolation valves are actuated by explosive charges. Surveillance of explosive charge continuity provides assurance that TIP valves will actuate when required. Other administrative controls, such as those that limit the shelf life of the explosive charges, must be followed. The 31 day Frequency is based on operating experience that has demonstrated the reliability of the explosive charge continuity.

SR 3.6.1.3.5 Verifying the isolation time of each power operated and each automatic PCIV is within limits is required to demonstrate OPERABILITY. MSIVs may be excluded from this SR since MSIV 0D (continued)

SUSQUEHANNA - UNIT I IBB3.6-25 Revisio~n 0

PPL Rev. 2 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.5 (continued) '

REQUIREMENTS full closure isolation time is demonstrated by SR 3.6.1.3.7. The isolation time test ensures that the valve will isolate in a time period less than or equal to that assumed in the Final Safety Analyses Report. The isolation time and Frequency of this SR are in accordance with the requirements of the Inservice Testing Program.

SR 3.6.1.3.6 For primary containment purge valves with resilient seals, the Appendix J Leakage Rate Test Interval of 24 months is sufficient.

The acceptance criteria for these valves is defined in the Primary Containment Leakage Rate Testing Program, 5.5.12.

The SR is modified by a Note stating that the primary'containment purge valves are only required to meet leakage rate testing requirements in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, purge valve leakage must be minimized to ensure offsite radiological release is within limits.

At other times when the purge valves are required to be capable of closing (e.g., during handling of irradiated fuel); pressurization concerns are not present and the purge valves are not required to meet any specific leakage criteria.

SR 3.6.1.3.7 Verifying that the isolation time of each MSIV is within the specified limits is required to demonstrate OPERABILITY. The isolation time

-test ensures that the MSIV will isolate in a time period that does not exceed the times assumed in the DBA analyses. This ensures that the calculated radiological consequences of these events remain within 10 CFR 100 limits. The Frequency of this SR is in accordance with the requirements of the Inservice Testing Program.

(continued)

SUSQUEHANNA - UNIT I TS B 3.6-26 Revision I

PPL Rev. 2 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.8 REQUIREMENTS (continued) Automatic PCIVs close on a primary containment isolation signal to prevent leakage of radioactive material from primary containment following a DBA. This SR ensures that each automatic PCIV will actuate to its isolation position on a primary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.1.5 overlaps this SR to provide complete testing of the safety function. The 24 month Frequency was developed considering it is prudent that some of these Surveillances be performed only during a unit outage since isolation of penetrations could eliminate cooling water flow and disrupt the normal operation of some critical components. Operating experience has shown that these components usually pass this Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint SR 3.6.1.3.9 This SR requires a demonstration that a representative sample of reactor instrumentation line excess flow check valves (EFCV) are OPERABLE by verifying that the valve actuates to check flow on a simulated instrument line break. As defined in FSAR Section 6.2.4.3.5 (Reference 4), the conditions under which an EFCV will isolate, simulated instrument line break, are at flow rates which develop a differential pressure of between 3 psld and 10 psid.

This SR provides assurance that the instrumentation line EFCVs will perform its design function to check flow. No specific valve leakage limits are specified because no specific leakage limits are defined in the FSAR. The 24 month Frequency is based on the need to perform some of these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. The representative sample consists of an approximate equal number of EFCVs such that each EFCV is tested at least once every 10 years (nominal). The nominal 10 year interval is based on other performance-based testing programs, such as Inservice Testing (snubbers) and Option B to 10 CFR 50, Appendix J. In addition, the EFCVs in the sample are representative of the various plant configurations, models, sizes and operating environments. This ensures that any potential common problems with a specific type or application of EFCV is detected at the earliest possible time. EFCV failures will be evaluated to determine if additional testing in that test interval is warranted to ensure overall reliability and that failures to isolate are very infrequent. Therefore, testing of a representative sample was concluded to be acceptable from a reliability standpoint (Reference 7).

(continued)

SUSQUEHANNA - UNIT 1 TS T / B 3.6-27 Revision 2

PPL Rev. 2 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.10 REQUIREMENTS (continued) The TIP shear isolation valves are actuated by explosive charges. An in place functional test is not possible with this design. The explosive squib is removed and tested to provide assurance that the valves will actuate when required. The replacement charge for the explosive squib shall be from the same manufactured batch as the onefired or from another batch that has been certified by having one of the batch successfully fired. The Frequency of 24 months on a STAGGERED TEST BASIS is considered adequate given'the administrative controls on replacement charges and the frequent checks of circuit continuity (SR 3.6.1.3.4).

SR 3.6.1.3.11 This'SR ensures that the leakage rate of secondary containment bypass leakage paths is less than the specified leakage rate. This provides assurance that the assumptions in the radiological evaluations of Reference 4 are met. The secondary containment leakage pathways and Frequency are defined by the Primary Containment Leakage Rate Testing Program. This SR simply imposes additional acceptance criteria.

A note is added to this SR which states that these valves are only required to meet this leakage limit in MODES 1, 2, and 3. In the other MODES, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required.

SR 3.6.1.3.12 The analyses in References 1 and 4 are based on the specified leakage I.

rate. Leakage through each MSIV must be < 100 scfh for any one MSIV or < 300 scfh for total leakage through the MSIVs combined with the Main Steam Line Drain Isolation Valve, HPCI Steam Supply Isolation Valve and the RCIC Steam Supply Isolation Valve. The MSIVs can be tested at either > Pt (22.5 psig) or Pa (45 psig). Main Steam Line Drain Isolation, HPCI and RCIC Steam Supply Line Isolation Valves, are' tested at Pa (45 psig). A note is added to this SR which states that these valves are only required to meet this leakage limit in MODES 1, 2, and 3. In the other conditions, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required. The Frequency is required by the Primary Containment Leakage Rate Testing Program. If leakage from the MSIVs requires internal work on any MSIV, the leakage will be reduced for the affected MSIV to < 11.5 scfh.

(continued)

SUSQUEHANNA - UNIT 1 TS / B 3.6-28 Revision 5

PPL Rev. 2 PCIVs

- -B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.13 REQUIREMENTS (continued) Surveillance of hydrostatically tested lines provides assurance that the calculation assumptions of Reference 2 are met. The acceptance criteria for the combined leakage of all hydrostatically tested lines is 3.3 gpm when tested ati1.1 P., (49.5 psig). The combined leakage rates must be demonstrated in accordance with the leakage rate test Frequency required by the Primary Containment Leakage Testing Program.

As noted in Table B 3.6.1.3-1, PCIVs associated with this SR are not Type C tested. Containment bypass leakage is prevented since the line terminates below the minimum water level in the Suppression Chamber. These valves are tested in accordance with the IST Program. Therefore, these valves leakage is not included as containment leakage.

This SR has been modified by a Note that states that these valves are only required to meet the combined leakage rate in MODES 1, 2, and 3, since this is when the Reactor Coolant System is pressurized and primary containment is required. In some instances, the valves are required to be capable of automatically I--,'4 closing during MODES other than MODES 1, 2, and 3. However, specific leakage limits are not applicable in .these other MODES or

\Ij conditions.

. REFERENCES 1. 'FSAR, Chapter 15.

2. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).

3. 10 CFR 50, Appendix J, Option B.

4. FSAR, Section 6.2.

5. NEDO-30851-P-A, "Technical Specification Improvement Analyses for BWR Reactor Protection System,"

March 1988.

6. Standard Review Plan 6:2.4, Rev. 1, September 1975

7. NEDO-32977-A, uExcess Flow Check Valve Testing Relaxation," June 2000.

SUSQUEHANNA - UNIT 1 TS /B 3.6-29 Revision I1

PPL Rev. 2 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve'

'(Page 1 of 11)

Isolation Signal Plant System Valve Number Valve Description Type of Valve LC0 3.36.1 Function No.

-__ - . Time (Seconds))

(Iaiu .slto Containment 1-57-193 (d) ILRT Manual N/A Atmospheric 1-57-194(d) ILRT Manual N/A Control HV-15703 Containment Purge Automatic Valve 2 b, 2.d, 2.e (15)

HV-15704 Containment Purge Automatic Valve; 2b. 2d, 2.e (15)

HV-15705 Containment Purge Automatic Valve 2-b, 2.d. 2.e (15)

HV-15711 Containment Purge Automatic Valve 2b, 2d, 2.e (15)

HV-15713 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15714 Containment Purge Automatic Valve 2b. 2.d, 2.e (15)

HV-15721 Containment Purge Automatic Valve 2b, 2.d, 2.e (15)

HV-15722 Containment Purge Automatic Valve 2.b. 2d, 2.e (15)

HV-15723 Containment Purge Automatic Valve 2.b. 2.d, 2.e (15)

HV-15724 Containment Purge Automatic Valve 2b, 2.d, 2.e (15)

HV-15725 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-1 5766 (a) Suppression Pool Cleanup AutomaticValve 2b, 2.d (30)

HV-1 5768 (a) Suppression Pool Cleanup Automatic Valve - b, 2.d (30)

SV-1 57100 A Containment Radiation Detection Automatic Valve 2.b. 2.d Syst -

SV-1 57100 B Containment Radiation Detection Automatic Valve 2.b, 2.d

.__ _ _ _ _ _ S yst '_._.

SV-157101 A Containment Radiation Detection - Automatic Valve 2.b, 2.d SV-1571 SB:

oamt Radati .V SV-1571 01 B Containment Radiation Detection Automatic Valve 2.b, 2.d Syst ' - ' .  :

SV-157102 A Containment Radiation Detection Automatic Valve 2.b, Zd Syst_ _ _ _ _ _ _ _

SV-157102 B Containment Radiation Detection Automatic Valve 2.b, Zd Syst '_-_'_.

SV-1 57103 A Containment Radiation Detection Automatic Valve -2b, Zd Syst SV-157103 B Containment Radiation Detection Automatic Valve 2b, ad Syst '-

SV-157104 Containment Radiation Detection Automatic Valve Zb, 2d Syst SV-157105 Containment Radiation Detection Automatic Valve 2b, 2.d Syst -_-_-

SV-157106 Containment Radiation Detection Automatic Valve 2.b, 2.d Syst '_'_-

SV-157107 Containment Radiation Detection Automatic Valve 'b, 2.d

_ _ __ __ __ _ _ _ _ _ _ yst _ _ _ _ _ _ _ _

SV-15734 A (e) Containment Atmosphere Sample Automatic Valve 2.b. 2.d SV-15734 B (e) Containment Atmosphere Sample Automatic Valve 2.b. 2.d SV-15736 A (e) ContainmentAtmosphere Sample Automatic Valve 2b. 2.d SV-15736 B (e) Containment Atmosphere Sample Automatic Valve 2.b. 2.d

_SV-15737 jNitrogen Makeup Automac Valve 2.b, 2d, 2.e SUSQUEHANNA- UNIT T / B 3.6-30 TS Revision 1

PPL Rev. 2 PCIVs B 3.6.1.3 Table B-3.6.1.3-1 Primary Containment Isolation Valve (Page2of`11)

Isolation Signal Plant System Valve Number Valve Description Type of Valve LO3.61unction (Maximum Isolation

. Time (Seconds))

Containmerit SV-15738 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e Atmospheric SV-15740 A (e) Containment Atmosphere Sample Automatic Valve 2.b. 2d Control . SV-15740 B (e) Containment Atmosphere Sample Automatic Valve 2b. 2.d (continued) SV-15742 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15742 B (e) Containment Atmosphere Sample Automatic Valve 2b. 2.d SV-15750 A (e) Containment Atmosphere Sample Automatic Valve 2b, 2.d SV-15750 B (e) Containment Atmosphere Sample Automatic Valve 2b. 2.d SV-15752 A (e) Containment Atmosphere Sample Automatic Valve 2b, 2-d SV-1 5752 B (e) Containment Atmosphere Sample Automatic Valve 2.b. 2.d SV-15767 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e SV-15774 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2d SV-15774 B (e) Containment Atmosphere Sample Automatic Valve 2b, 2.d SV-15776 A (e) Containment Atmosphere Sample Automatic Valve 2b, 2.d SV-1 5776 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15780 A (e) Containment Atmosphere Sample -Automatic Valve 2b, 2.d SV-15780 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15782 A (e) Containment Atmosphere Sample Automatic Valve 2.bb 2d SV-1 5782 B (e) Containment Atmosphere Sample Automatic Valve Zb. 2d SV-1 5789 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e Containment 1-26-072 (d) Containment Instrument Gas Manual Check N/A Instrument Gas 1-26-074 (d) Containment Instrument Gas Manual Check N/A 1-26-152 (d) Containment Instrument Gas Manuil Check: N/A 1-26-154 (d). Containment Instrument Gas Manual Check N/A

. 1-26-164 (d) Containment Instrument Gas Manual Check N/A' HV-12603 Containment Instrument Gas .Automatic Valve 2.c, 2.d (20)

SV-12605 Containment Instrument Gas Automatic Valve 2.c, 2d SV-12651 Containment Instrument Gas Automatic Valve 2.c, 2.d SV-12654 A Containment Instrument Gas Power Operated N/A SV-12654 B Containment Instrument Gas Power Operated N/A SV-12661 Containment Instrument Gas Automatic Valve 2.b. 2.d SV-12671. Containment Instrument Gas Automatic Valve 2.b. 2.d Core Spray HV-152F001 A (b)(c) CS Suction Valve Power Operated N/A HV-152F001 B (b)(c) CS Suction Valve Power Operated N/A HV-1 52F005 A CS Injection Power Operated N/A HV-152F005 B CS Injection Valve Power Operated N/A HV-152F006 A CS Injection Valve Air Operated Check N/A Valve HV-152F006 B CS Injection Valve Air Operated Check N/A

._ Valve HV-152F015 A (b)(c) CS Test Valve Automatic Valve 2.c, 2.d (80)

. -HV-152F015 B (b)(c) CS Test Valve Automatic Valve 2.c, 2d (80)

SUSQUEHANNA - UNIT 1 . TS / B 3.6-31 Revision 3

PPL Rev. 2 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 3 of 11)

Isolation Signal

• Plant System Valve Number Valve Description Type of Valve LCO 3.3.6.1 Function No.

(Maximum solaton

.__ ._ _.. Time (Seconds))

Core Spray HV-152F031 A (b)(c) CS Minimum Recirculation Flow Power Operated N/A (continued) HV-152F031 B (b)(c) CS Minimum Recirculation Flow Power Operated N/A HV-1 52F037 A CS Injection Power Operated N/A

._ (Air)

HV-152F037 B CS Injection Power Operated N/A XV-152F018A CoreSpray _' Valve' NI(Air)

XV-152F018A Core Spray Excess Flow Check N/A alve X-1 52F01 8 B Core Spray Excess Flow Check NWA Valve HPCI 1-55-038 (d) HPCI Injection Valve Manual N/A 155F046 (b)(c)(d) HPCI Minimum Fiow CheckValve 'Manual Check WA 155F049 (a)(d) HPCI Turbine Exhaust Valve Manual Check N/A HV-155F002 HPCI Steam Supply Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f,

_ _ _ __ __ _ __ _ _ _ __ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _3 .g (50 )

HV-155F003 HPCI Steam Supply Valve Automatic Valve 3.a, 3.b, 3.c, 3.e( 3.f,

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _3.g (50)

HV-155F006 HPCI Injection Valve Power Operated . NIA HV-155F012 (b)(c) HPCI Minimum Flow Valve Power Operated NIA HV-155F042 (b)(c) HPCI Suction Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f,

_ __ _ _ __ _ _ _ __ _ _ __ __ __ _ _ _ _ _ _ _ _3 .g (90)

HV-155F066 (a) HPCI Turbine Exhaust Valve Powier Operated N/A HV-155F075 HPCI Vacuum Breaker Isolation Automatic Valve - 3.b, 3.d (15)

Valve HV-155F079 HPCI Vacuum Breaker Isolation Automatic Valve 3.b, 3.d (15)

Valve HV-155F100 HPCI Steam Supply Valve Automatic Valve 3.a,3.b, 3.c, 3.e, 3.f,

_ __ _ __ _ __ _ __ _ _ __ _ _ _ __ __ __ _ _ _ _ _ _ _ _3 wg (6 ) '

XV-155F024 A HPCI Valve Excess Flow Check ' NA

-_ __ Valve XV-155F024 B HPCI Valve Excess Flow Check N/A Valve XV-155F024 C HPCI Valve Excess Flow Check NIA Valve X-155F024 D HPCI Valve Excess Flow Check NIA Valve Liquid Radwaste HV-161 08 Al Liquid Radwaste Isolation Valve Automatic Valve 2.b, Zd (15)

Collection HV-1 6108 A2 Liquid Radwaste Isolation Valve Automatic Valve 2b, 2.d (15)

HV-161 16 Al Liquid Radwaste Isolation Valve Automatic Valve - 2b, 2.d (15)

HV-16116 A2 Liquid Radwaste Isolation Valve Automatic Valve 2.b. 2.d (15)

Demin Water 1-41-017 (d) Demineralized Water Manual N/A 1-41-018 (d) Demineralized Water Manual N/A Nuclear Boiler 141 F01 0 A (d) Feedwater Isolation Valve Manual Check N/A 141 F01 0 B (d) Feedwater Isolation Valve Manual Check N/A J i

SUSQUEHANNA - UNIT 1 B 3.6-32 .. Revision 0.

PPL Rev. 2 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 4 of 11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve Uaxlmum Isolton

-_ Time (Seconds))

Nuclear Boiler 141 F039 A (d) Feedwater Isolation Valve Manuat Check N/A (continued) 141 F039 B (d) Feedwater Isolation Valve Manual Check N/A 141818 A (d) Feedwater Isolation Valve Manual Check N/A 141818 B (d) Feedwater Isolation Valve Manual Check N/A HV-141F016 MSL Drain Isolation Valve omatic Valve 1.b. (.a, 0 1.d, .e 1.c,

_ _ _ _ _ _ ___ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _(1 0)

HV-141F019 MSL Drain Isolation Valve Automatic Valve l.a. 1.b, 1.c, 1.d, 1.e

._ (15) I HV-141F022A MSIV Automatic Valve : .a,1.b. 1.c, 1.d, I.e

. (5)

HV-141 F022 B MSIV Automatic Valve 1.a. 1.b, 1.c,.d,1 I.e

.__ -(5)

HV-141 F022 C MSIV Automatic Valve 1.a, 1.b. .c, 1.d, I.e

• (5)

HV-141 F022 D MSIV Automatic Valve l.a. 1.b, 1.c, 1.d, I.e

._ . (5)

HV-141F028A MSIV Automatic Valve 1.a, 1.b. .c1.d,1 I.e HV-141 F028 B MSIV. AutomatieValve 1.a,1.b,1e,1.d(5)

HV-141 F028 B MSIV Automatic Valve l.a, 1.b, 1.c, 1.d, I.e

. .(5)

HV-141 F028 D MSIV Automatic Valve- .a,1.b. 1.c, 1.d,1.e

_ __ _ __ _ _ _ __ __ _ _ _ __ _(5

_ _ _ )

HV-141 F032 A Feedwater Isolabon Valve Power Operated N/A Check

• HV-141 F032 B Feedwater Isolation Valve Power Operated N/A

__ _ _ _ _ __ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ h eck _ _ _ _ _ _ _

XV-141 F009 Nuclear Boiler EFCV, Excess Flow Check N/A Valve XV-141 F070 A Nuclear Boiler EFCV Excess Flow Check N/A Valve XV-141 F070 B Nuclear Boiler EFCV Excess Flow Check N/A

-__ ._ - Valve XV-141 F070 C Nuclear Boiler EFCV Excess Flow Check N/A Valve XV-141 F070 D Nuclear Boiler EFCV Excess Flow Check N/A

- _Valve XV-141 F071 A Nuclear Boiler EFCV Excess Flow Check N/A Xalve XV-141 F071 B Nuclear Boiler EFCV Excess Flow Check N/A

_ __ __ __ __ __ _ _ _ _ _ _ _ _ _ _ alve _ _ _ _ _ _ _

XV-141 F071 C Nuclear Boiler EFCV Excess Flow Check N/A Valve X-1 41 F071 D Nuclear Boiler EFCV Excess Flow Check .N/A Valve SUSQUEHANNA - UNIT 1 TS /.B 3.6-33 Revision I

PPL Rev. 2 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 5 of I1)

Isolation Signal Plant System Valve Number Valve Description Type of Valve LCO(Maximum 3.3.6.1 Function IsolationNo.

- Time (Seconds))

Nuclear Boiler XV-141 F072 A Nuclear Boiler EFCV ExcessFlow Check N/A (continued) alve XV-141 F072 B Nuclear Boiler EFCV Excess Flow Check N/A XV-141 F072 C Nuclear Boiler EFCV Excess Flow Check N/A XV-141____________ ___DNuclear__Boiler_ _ Valve XV-141 F072 D Nuclear Boiler EFCV Excess Flow Check N/A Valve XV-141 F073 A Nuclear Boiler EFCV Excess Flow Check N/A

_ __ _ __ _ __ __ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ a lv e_ _ _ _ _ _ _

XV-141 F073 B Nuclear Boiler EFCV Excess Flow Check N/A Vessel_ Valve XV-141 F073 C Nuclear Boiler EFCV Excess Flow Check N/A

_ _ _ _ __ _ _ _ _ _ __ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ alv e _ _ _ _ _ _ _

XV-141 F073 D Nuclear Boiler EFCV Excess Flow Check N/A

_ __ _ __ __ __ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ alv e _ _ _ _ _ _ _

Nuclear Boiler XV-14201 Nuclear Boiler Vessel Instrument Excess Flow Check N/A Vessel Valve Instrumentation XV-14202 Nuclear Boiler Vessel Instrument Excess Flow Check N/A

_ _ _ _ _ _ _A_ _ _ _ N __B _ _ _ r_ _ _ _ _l _ _ _ uValve _ _ __ _

XV-142F041 Nuclear Boiler Vessel Instrument Excess Flow Check N/A Valve XV-142F043 A Nuclear Boiler Vessel Instrument Excess Flow Check N/A

___ C Nuclear BoilerVsselInstrument Valve XV-142F043 B Nuclear Boiler Vessel Instrument Excess Flow Check N/A

_ __ _ __ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ alv e XV-1 42F045 A Nuclear Boiler Vessel Instrument Excess Flow Check N/A

___ _ __ _ _ __ NB

_ _ _ _ _ _ _ _ _ _en _ _ _ _ _ _ _ _ _ _ _ Valve X-1 42F045 B Nuclear Boiler Vessel Instrument Excess Flow Check N/A

_ __ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ alv e X-142F047 A Nuclear Boiler Vessel Instrument Excess Flow Check 'N/A

_ __ __ __ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ alv e X-142 P047 B Nuclear Boiler Vessel Instrument EcsFlwCekN/A X-142F051 A Nuclear Boiler Vessel Instrument Excess Flow Check W/A

_ _ __ __ __ __ _ _ __ _ _ _ _ _ _ _ __ __ __ _ __ __ __ _ _ V alv e X-142F051 B Nuclear Boiler Vessel Instrument -Excess Flow Check N/A

_ _ _ __ __ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Valve X-142F051 C Nuclear Boiler Vessel Instrument Excess Flow Check N/A

__ __ __ __ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Valve X-142F051 D Nuclear Boiler Vessel Instrument Excess Flow Check N/A

____ ___ ___ ____ ___ ___ Valve X-1 42F053 A Nuclear Boiler Vessel Instrument Excess Flow Check N/A Valve X-142F053 B Nuclear Boiler Vessel Instrument Excess Flow Check N/A

_ _ _ __ __ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ alv e

.0 SUSQUEHANNA - UNIT 1 *- - B 3.6-34 Revision 0

PPL Rev. 2 PCI Vs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 6 of 11)

Isolation Signal Plant System Valve Number Valve Description - Type of Valve .ax1mum Isoltion

__- . Time (Seconds))

Nuclear Boiler XV-142F053 C Nuclear Boiler Vessel Instrument Excess Flow Check N/A Vessel Valve '

Instrumentation XV-142F053 D Nuclear Boiler Vessel Instrument Excess Flow Check NIA (continued) - - Valve XV-142F055 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve '

-142F057 Nuclear Boiler Vessel Instrument Excess Flow Check N/A Valve '

XV-142F059 A Nuclear Boiler Vessel Instrument Excess Flow Check N/A

_________________ __-_Nucear _Bol er _Vesel ________V alve XV-142F059 B Nuclear Boiler Vessel Instrument Excess Flow Check N/A

__________ E_ - Nuclear Boiler Vessel InstrumentValve -_ __ _

XV-142F059 C Nuclear Boiler Vessel Instrument Excess Flow Check N/A

_ __ _ _ __ __ _ _ _ _ _ _ _V alve XV-142F059 D Nuclear Boiler Vessel Instrument Excess Flow Check N/A

._ _-_ _'_ _' _ __ _Valve  :

XV-142F059 E Nuclear Boiler Vessel Instrument Excess Flow Check N/A

-_ _ _ _ _ X V12 rBie Vse ntuValve XV-142F059 F Nuclear Boiler Vessel Instrument Excess Flow Check N/A

'_ Valve XV-142F059 G Nuclear Boiler Vessel Instrument Excess Flow Check N/A N oIValve.

XV-142F059 H Nuclear Boiler Vessel Instrument Excess Flow Check N/A 7 Valve XV-142F059 L Nuclear Boiler Vessel Instrument Excess Flow Check N/A Valve _ _ _ _ _ _ _

XV-142F059 M Nuclear Boiler Vessel Instrument Excess Flow Check N/A Valve XV-142F059 N Nuclear Boiler Vessel Instrument Excess Flow Check N/A Valve __ __ __ _ _(30)

X-142F059 P Nuclear Boiler Vessel Instrument Excess Flow Check N/A

• ValveValve _______d_(30)

V-142F059 R Nuclear Boiler Vessel Instrument Excess Flow Check N/A

_________ _'_A tomValve ti XV-1 42F059 S Nuclear Boiler Vessel Instrument Excess Flow Check N/A Valve _ _ _ _ _ _ _ _ _ _

X-1 42F059 T Nuclear Boiler Vessel Instrument ExesFowCekNA

____ ____ ____ ____ ____V alve X-1 42F059 U Nuclear Boiler Vessel Instrument Excess Flow Check N/A Valve _ _ _ _ _ _ _ _ _

X-142F061 Nuclear Boiler Vessel Instrument Excess Flow Check N/A Valve__ _ _ _ _ _ _ _

RBCCW HV-1 1313 BCWAutomatic Valve 2.c. Zd (30)

HV-1 1314 RBCCW Automatic Valve 2.c, 2-d (30)

IHV-1 1345 RBCCW Automatic Valve 2.c, 2.d (30)

_______HV-1 1346 RBCCW Automatic Valve

• 2.c. Zd (30)

SUSQUEHANNA - UNIT 1 B 3.6-35 ..- - Revision 0

PPL Rev. 2 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 7 of 11)

Isolaton Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve LCaximum Isnltion

___ ___ ___ __ ___ ___ ___ __ ___ ___ __ Tim e (S c nds)

RCIC - 1-49-020 (d) RCIC INJECTION Manuat NIA 149F021 (b)(c)(d) RCIC Minimum Recirculation Flow Manual Check N/A 149F028 (a)(d) RCIC Vacuum Pump Discharge Manual Check N/A 149F040 (a)(d) RCIC Turbine Exhaust Manual Check N/A FV-149F019 (b)(c) RCIC Minimum Recirculation Flow Power Operated NIA HV-149F007 RCIC Steam Supply Automatic Valve 4.a, 4.b. 4.c, 4.e, 4.f

-_ 4.g (20)

HV-149F008 RCIC Steam Supply Automatic Valve 4.a. 4.b. 4.c, 4.e, 4.f,

._ - 4.g (20)

HV-149F013 RCIC Injection Power Operated N/A HV-149F031 (b)(c) RCIC Suction Power Operated N/A HV-149F059 (a) RCIC Turbine Exhaust Power Operated NJA HV-149F060 (a) RCIC Vacuum Pump Discharge Power Operated N/A HV-149F062 RCIC Vacuum Breaker Automatic Valve 4.b, 4.d (10)

HV-149F084 RCIC Vacuum Breaker Automatic Valve 4.b, 4.d (10)

HV-149F088 RCIC Steam Supply Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f,

.__ '4.g (12)

XV-149F044 A RCIC Excess Flow Check N/A

._ __ Valve XV-149F044 B RCIC Excess Flow Check N/A

._ . Valve XV-149F044 C RCIC Excess Flow Check N/A Valve

• XV-149FO44 D RCIC Excess Flow Check N/A

. -_ Valve RB Chilled HV-18781 Al RB Chilled Water Automatic Valve 2.c, Zd (40)

Water System HV-18781 A2 RB Chilled Water Automatic Valve 2.c, 2.d (40)

HV-18781 Bi RB Chilled Water Automatic Valve 2.c, 2.d (40)

HV-18781 B2 RB Chilled Water Automatic Valve 2.c,Zd (40)

HV-18782 Al RB Chilled Water omatic Valve 2.c. Zd (12)

HV-18782 A2 RB Chilled Water Automatic Valve 2.c. 2d (12)

HV-18782 81 RB Chilled Water Atomatic Valve 2.c. d (12)

HV-18782 B2 RB Chilled Water Automatic Valve 2.c.Zd (12)

HV-18791 Al RB Chilled Water Automatic Valve 2b. 2.d (15)

HV-18791 A2 RB Chilled Water Automatic Valve 2b. 2.d (15)

HV-18791 81 RB Chilled Water Automatic Valve ' 2b. Zd (15)

HV-18791 B2 RB Chilled Water Automatic Valve 2b, 2Zd (15)

HV-1 8792 Al RB Chilled Water Automatic Valve 2.b. 2.d (8)

HV-1 8792 A2 RB Chilled Water Automatic Valve 2.b, 2.d (8)

HV-1 8792 81 RB Chilled Water Automatic Valve 2.b, 2.d (8)

' HV-18792 B2 RB Chilled Water Automatc Valve 2.b, 2.d (8)

Reactor 143F7l 3 A (d) Recirculation Pump Seal Water Manual Check W2A Recirculation 143F0l3 B (d) Recirculation Pump Seal Water Manual Check N/A SUSQUEHANNA- UNIT . . TS / B 3.6-36 Revision R 1

PPL Rev. 2 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 (continued) -

Primary Containment Isolation Valve (Page 8 of 11)

- Isolation Signal I LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve {aimum Isolaton

._ Time (Seconds))

Reactor XV-143F003 A Reactor Recirculation Excess Flow Check N/A Recirculation Valve (continued) XV-143F003 B Reactor Recirculation Excess Flow Check NWA Valve V-1 43F004 A Reactor Recirculation Excess Flow Check N/A Valve XV-143F004 B Reactor Recirculation Excess Flow Check N/A Valve XV-143F009 A Reactor Recirculation Excess Flow Check . N/A

. _Valve XV-143F009 B Reactor Recirculation Excess Flow Check N/A Valve XV-143F009 C Reactor Recirculation Excess Flow Check NWA alve XV-143F009 D Reactor Recirculation Excess Flow Check N/A Valve XV-143F010 A Reactor Recirculation Excess Flow Check NA-Valve XV-143F010 B Reactor Recirculation Excess Flow Check N/A

. _Valve I-- .

XV-143F010 C Reactor Recirculation Excess Flow Check NWA Valve XV-143F010 D Reactor Recirculation Excess Flow Check NWA Valve XV-143F011 A Reactor Recirculation Excess Flow Check N/A Valve XV-1 43F01 I B Reactor Recirculation Excess Flow Check N/A

._ Valve XV-143F01 I C Reactor Recirculation Excess Flow Check N/A Valve XV-143F011 D Reactor Recirculation Excess Flow Check N/A Valve XV-143F012A Reactor Recirculation Excess Flow Check N/A Valve XV-1 43F01 2 B Reactor Recirculation Excess Flow Check N/A Valve

-143F012 C Reactor Recirculation Excess Flow Check N/A Valve XV-143F012 D Reactor Recirculation Excess Flow Check N/A Valve XV-143F017 A Recirculation Pump Seal Water Excess Flow Check N/AI

. _Valve

-143F017 B Recirculation Pump Seal Water Excess Flow Check N/A Valve KV-143F040 A - Reactor Recirculation kExcess Valve Flow Check N/A C)

SUSQUEHANNA - UNIT 1 B 3.6-37 Revision O

PPL Rev. 2 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 (continued) '

Primary Containment Isolation Valve (Page 9 ofl1)  :

Isolation Signal Plant System Valve Number Valve Description Type of Valve LCO 3.3.6.1 Function (Maximum IsolationNo.

. Time (Secondsl)'

Reactor - - -143F040 B Reactor Recirculation Excess-Flow Check NIA Recirculation Valve (continued) XV-143F040 C Reactor Recirculation Excess Flow Check NWA Valve XV-143F040 D Reactor Recirculation Excess Flow Check N/A

-_ __V alve XV-143F057 A . Reactor Recirculation Excess Flow Check N/A Valve XV-143F057 B Reactor Recirculation Excess Flow Check NWA Valve HV-143F019 Reactor Coolant Sample Automatic Valve 2.b (9)

HV-143F020 Reactor Coolant Sample Automatic Valve' 2.b (2)

Residual Heat HV-1 51 F004 A (b)(c) RHR - Suppression Pool Suction Power Operated N/A Removal HV-151 F004 B (b)(c) RHR - Suppression Pool Suction Power Operated N/A HV-1 51 F004 C (b)(c) RHR - Suppression Pool Suction Power Operated N/A HV-151 F004 D (b)(c) RHR - Suppression Pool Suction Power Operated N/A HV-151 F007 A (b)(c) RHR-Minimum Recirculation Flow Power Operated N/A HV-151 F007 B (b)(c) RHR-Minimum Recirculation Flow Power Operated N/A HV-151 F008 RHR - Shutdown Cooling Suction Automatic Valve 6.a. 6.b, 6.c (52)

HV-151 F009 RHR - Shutdown Cooling Suction Automatic Valve 6.a, 6.b. 6.c (52)

HV-151 F01I A (b)(d) RHR-Suppression Pool Manual N/A Cooling/Spray  :

HV-151 F01I B (b)(d) RHR-Suppression Pool Manual . N/A Cooling/Spray HV-151 F015 A RHR - Shutdown Cooling Power Operated NWA

' __ _ Return/LPCI Injection .

HV-151 F015 B RHR - Shutdown Cooling Power Operated WA RetumrLPCI Injection '

HV-151F016A (b) RHR - Drywell Spray Automatic Valve 2.c, 2.d (90)

HV-151F016 B (b) RHR - Drywell Spray Automatic Valve 2.c, 2.d (90)

HV-151F022 RHR - Reactor Vessel Head Spray Automatic Valve 2d, 6.a, 6.b, 6.c (30)

HV-151 F023 RHR - Reactor Vessel Head Spray Automatic Valve 2.d, 6.a, 6.b, 6.c (20)

HV-151 F028 A (b) RHR - Suppression Pool Automatic Valve 2.c, 2.d (90)

Cooling/Spray  :

HV-151 F028 B (b) RHR - Suppression Pool Automatic Valve - 2.c, 2.d (90)

Cooling/Spray HV-151 F050 A RHR - Shutdown Cooling Air Operated Check N/A

- Return/LPCI Injection Valve Valve HV-151 F050 B RHR - Shutdown Cooling Air Operated Check N/A

. ReturnILPCI Injection Valve Valve '_'

HV-151 F103 A (b) RHR Heat Exchanger Vent Power Operated N/A

. HV-151F103 B (b) RHR Heat Exchanger Vent Power Operated N/A

&J SUSQUEHANNA- UNIT I TS / B 3.&38 Revision I -

PPL Rev. 2 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 10 of 11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve a Isolation

._ . . .. Time (Seconds))

Residual Heat HV-151 F122 A RHR - Shutdown Cooling Power Operated N/A Removal Return/LPCI Injection Valve (Air)

(continued) HV-151 F122 B RHR - Shutdown Cooling Power Operated N/A Retum/LPCI Injection Valve (Air)

PSV-15106 A (b)(d) RHR - Relief Valve Discharge Relief Valve N/A PSV-15106 B (b)(d) RHR - Relief Valve Discharge Relief Valve N/A PSV-1 51 F1 26(d) RHR - Shutdown Cooling Suction Relief Valve N/A XV-15109A RHR Excess FlowCheck N/A

. _Valve XV-15109 B RHR Excess Flow Check N/A

._ __ Valve XV-15109 C RHR Excess Flow Check N/A Valve .

XV-15109 D RHR Excess Flow Check N/A Valve RWCU HV-144F001 (a) RWCU Suction Automatic Valve 5.a, 5.b. 5.c, 5.d, 5.f,

._ . . 5.g (30)

HV-144F004 (a) RWCU Suction Automatic Valve 5.a, 5., 5.c, 5.d, 5.e, 5.f, 5.g (30)

XV-14411 A RWCU ExcessFlow Check

• N/A Valve XV-14411 B RWCU - Excess Flow Check N/A Valve .

XV-14411 C RWCU Excess Flow Check N/A Valve XV-14411 D RWCU Excess Flow Check N/A Valve XV-144F046 RWCU Excess Flow Check N/A Valve HV-14182 A RWCU Return Isolation Valve Power Operated N/A

, HV-14182 B RWCU Return Isolation Valve Power Operated N/A SLCS 148F007 (a)(d) SLCS Manual Check N/A HV-148F006 (a) SLCS Power Operated N/A

._ _Check ._ Valve P System C51-J004 A (Shear TIP Shear Valves Squib Valves N/A Valve)

C51-J004 B (Shear TIP Shear Valves . Squib Valves N/A Valve) . -_-;

C51-J004 C (Shear TIP Shear Valves Squib Valves N/A

.alve) (Shear TIPShearValves -_SquibVahesN/A C51-J004 D (Shear IP Shear Valves quib Valves N/A Valv e)__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _

C51-J004 E (Shear, P Shear Valves Suib Valves N/A

_ _ ___ __ _ _ _ _ V a lve) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _

SUSQUEHANNA- UNIT 1 B 3.6-39 . Revision 0.

- PPL Rev. 2 PCIVs B 3.6.1.3 Table R3.6.1.3-1 Primary Containment Isolation Valve (Page 11 of 11)

Isolation Signal Plant System Valve Number Valve Description Type of Valve LD 33.6.1 Funtion No.

- _ Time (Seconds))

TIP System - C51-J004 A (Ball IP Ball Valves Automatic Valve 7.a, 7.b (5)

(continued) Valve) .

C51-J004 B (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

C51-J004 C (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

C1-J04 D (Ball IP Ball Valves Automatic Valve 7.a, 7.b (5) alve ) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _

C51-J004 E(Ball IP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

(a) Isolation barrier remains water filled or a water seal remains inthe line post-LOCA, isolation valve is tested with water. Isolation valve leakage is not included in 0.60 L. total Type B and C tests.

(b) Redundant isolation boundary for this valve is provided by the closed system whose integrity is verified by the Leakage Rate Test Program.

(c) Containment Isolation Valves are not Type C tested. Containment bypass leakage is prevented since the line terminates below the minimum water level inthe Suppression Chamber. Refer to the IST Program.

(d) LCO 3.3.3.1, "PAM Instrumentation", Table 3.3.3.1-1, Function 6, does not apply since these are relief valves, check valves, manual valves or deactivated and closed.

(e) The containment isolation barriers for the penetration associated with this valve consists of two PCIVs and a dosed system. The closed system provides a redundant isolation boundary for both PFCIVs, and its integrity is required to be verified by the Leakage Rate Test Program.

SUSQUEHANNA - UNIT 1 TS / B 3.640 Revision 3