ML14196A040

Susquehanna, Unit 1, Technical Specification Bases, Manual

ML14196A040
Person / Time
Site:	Susquehanna
Issue date:	07/03/2014
From:	Susquehanna
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
028401, 2014-33659
Download: ML14196A040 (54)

Text

Jul. 03, 2014Page1 of 2MANUAL HARD COPY DISTRIBUTIONDOCUMENT TRANSMITTAL 2014-33659USER INFORMATION:GERLACH*ROSEY MEMPL#:028401 CA#: 0363Address: NUCSA2Phone#: 254-3194TRANSMITTAL INFORMATION:TO: GERLACH*ROSEY M 07/03/2014LOCATION: USNRCFROM: NUCLEAR RECORDS DOCUMENT CONTROL CENTER (NUCSA-2)THE FOLLOWING CHANGES HAVE OCCURRED TO THE HARDCOPY OR ELECTRONIC MANUAL ASSIGNEDTO YOU. HARDCOPY USERS MUST ENSURE THE DOCUMENTS PROVIDED MATCH THE INFORMATION ONTHIS TRANSMITTAL. WHEN REPLACING THIS MATERIAL IN YOUR HARDCOPY MANUAL, ENSURE THEUPDATE DOCUMENT ID IS THE SAME DOCUMENT ID YOU'RE REMOVING FROM YOUR MANUAL. TOOLSFROM THE HUMAN PERFORMANCE TOOL BAG SHOULD BE UTILIZED TO ELIMINATE THE CHANCE OFERRORS.ATTENTION: "REPLACE" directions do not affect the Table of Contents, Therefore noTOC will be issued with the updated material.TSBI -TECHNICAL SPECIFICATION BASES UNIT 1 MANUALREMOVE MANUAL TABLE OF CONTENTS DATE: 04/25/2014ADD MANUAL TABLE OF CONTENTS DATE: 07/02/2014CATEGORY: DOCUMENTS TYPE: TSBI-ul Jul. 03, 2014Page 2 of 20ID: TEXT 3.6.1.3REMOVE: REV:10ADD: REV: 11CATEGORY: DOCUMENTS TYPE: TSB1ID: TEXT LOESADD: REV: 117REMOVE: REV:116CATEGORY: DOCUMENTS TYPE: TSB1ID: TEXT TOCREMOVE: REV:22ADD: REV: 23ANY DISCREPANCIES WITH THE MATERIAL PROVIDED, CONTACT DCS @ X3107 OR X3136 FORASSISTANCE. UPDATES FOR HARDCOPY MANUALS WILL BE DISTRIBUTED WITHIN 3 DAYS INACCORDANCE WITH DEPARTMENT PROCEDURES. PLEASE MAKE ALL CHANGES AND ACKNOWLEDGECOMPLETE IN YOUR NIMS INBOX UPON COMPLETION OF UPDATES. FOR ELECTRONIC MANUALUSERS, ELECTRONICALLY REVIEW THE APPROPRIATE DOCUMENTS AND ACKNOWLEDGE COMPLETE INYOUR NIMS INBOX.

SSES MANUALManual Name: TSBIManual Title: TECHNICAL SPECIFICATION BASES UNIT 1 MANUALTable Of ContentsIssue Date: 07/02/2014Procedure Name RevTEXT LOES 117Title: LIST OF EFFECTIVE SECTIONSIssue Date Change ID Change Number07/02/2014TEXT TOCTitle: TABLE OF CONTENTS23 07/02/2014TEXT 2.1.1 5 05/06/2009Title: SAFETY LIMITS (SLS) REACTOR CORE SLSTEXT 2.1.2 1Title: SAFETY LIMITS (SLS) REACTOR10/04/2007COOLANT SYSTEM (RCS) PRESSURE STEXT 3.0 3 08/20/2009Title: LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITYTEXT 3.1.1Title: REACTIVITYTEXT 3.1.2Title: REACTIVITYTEXT 3.1.3Title: REACTIVITYTEXT 3.1.4Title: REACTIVITYTEXT 3.1.5Title: REACTIVITYTEXT 3.1.6Title: REACTIVITY1 04/18/2006CONTROL SYSTEMS SHUTDOWN MARGIN (SDM)0 11/15/2002CONTROL SYSTEMS REACTIVITY ANOMALIES2 01/19/2009CONTROL SYSTEMS CONTROL ROD OPERABILITY4 01/30/2009CONTROL SYSTEMS CONTROL ROD SCRAM TIMES1 07/06/2005CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS3 02/24/2014CONTROL SYSTEMS ROD PATTERN CONTROLPagel of 8 Report Date: 07/03/14Page I of .8Report Date: 07/03/14 SSES MANUALManual Name: TSB1Manual Title: TECHNICAL SPECIFICATION BASES UNIT 1 MANUALTEXT 3.1.7 3 04/23/2008Title: REACTIVITY CONTROL SYSTEMS STANDBY LIQUID CONTROL (SLC) SYSTEMTEXT 3.1.8Title: REACTIVITY CONTROL3 05/06/2009SYSTEMS SCRAM DISCHARGE VOLUME (SDV) VENT AND DRAIN VALVESTEXT 3.2.1 2 04/23/2008Title: POWER DISTRIBUTION LIMITS AVERAGE PLANAR LINEAR HEAT GENERATIONTEXT 3.2.2 3 05/06/2009Title: POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)TEXT 3.2.3 2 04/23/2008Title: POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE (LHGR)TEXT 3.3.1.1 6 02/24/2014Title: INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATIONRATE (APLHGR)TEXT 3.3.1.2Title: INSTRUMENTATION2 01/19/2009SOURCE RANGE MONITOR (SRM) INSTRUMENTATIONTEXT 3.3.2.1 4 02/24/2014Title: INSTRUMENTATION CONTROL ROD BLOCK INSTRUMENTATIONTEXT 3.3.2.2 2 04/05/2010Title: INSTRUMENTATION FEEDWATER MAIN TURBINE HIGH WATER LEVEL TRIP INSTRUMENTATIONTEXT 3.3.3.1Title: INSTRUMENTATION9 02/28/2013POST ACCIDENT MONITORING (PAM) INSTRUMENTATIONTEXT 3.3.3.2 1 04/18/2005Title: INSTRUMENTATION REMOTE SHUTDOWN SYSTEMTEXT 3.3.4.1 2 02/24/2014Title: INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATIONPage 2 of .8Report Date: 07/03/14 SSES MANUiTAL.Manual Name: TSBIManual Title: TECHNICAL SPECIFICATION BASES UNIT 1 MANUALTEXT 3.3.4.2 0 11/15/2002Title: INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP(ATWS-RPT) INSTRUMENTATIONTEXT 3.3.5.1 3 08/20/2009Title: INSTRUMENTATION EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATIONTEXT 3.3.5.2 0 11/15/2002Title: INSTRUMENTATION REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM INSTRUMENTATIONTEXT 3.3.6.1Title: INSTRUMENTATION7 03/31/2014PRIMARY CONTAINMENT ISOLATION INSTRUMENTATIONTEXT 3.3.6.2 4 09/01/2010Title: INSTRUMENTATION SECONDARY CONTAINMENT ISOLATION INSTRUMENTATIONTEXT 3.3.7.1Title: INSTRUMENTATIONINSTRUMENTATION2 10/27/2008CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEMTEXT 3.3.8.1 2 12/17/2007Title: INSTRUMENTATION LOSS OF POWER (LOP) INSTRUMENTATIONTEXT 3.3.8.2 0 11/15/2002Title: INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORINGTEXT 3.4.1 4 04/27/2010Title: REACTOR COOLANT SYSTEM (RCS) RECIRCULATION LOOPS OPERATINGTEXT 3.4.2 3 10/23/2013Title: REACTOR COOLANT SYSTEM (RCS) JET PUMPSTEXT 3.4.3Title: REACTOR COOLANT3 01/13/2012SYSTEM RCS SAFETY RELIEF VALVES S/RVSTEXT 3.4.4 0 11/15/2002Title: REACTOR COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGEPage 3 of 8 Report Date: 07/03/14Page3of _8Report Date: 07/03/14 SSES MANUALManual Name: TSBlManual Title: TECHNICAL SPECIFICATION BASES UNIT 1 MANUALTEXT 3.4.5 1 01/16/2006Title: REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGETEXT 3.4.6 4 02/19/2014Title: REACTOR COOLANT SYSTEM (RCS) RCS LEAKAGE DETECTION INSTRUMENTATIONTEXT 3.4.7 2 10/04/2007Title: REACTOR COOLANT SYSTEM (RCS) RCS SPECIFIC ACTIVITYTEXT 3.4.8Title: REACTOR COOLANT-HOT SHUTDOWNTEXT 3.4.9Title: REACTOR COOLANT-COLD SHUTDOWN2 03/28/2013SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM1 03/28/2013SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLINGSYST6TEXT 3.4.10 3 04/23/2008Title: REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE (P/T) LIMITSTEXT 3.4.11 0 11/15/2002Title: REACTOR COOLANT SYSTEM (RCS) REACTOR STEAM DOME PRESSURETEXT 3.5.13 02/24/2014Title: EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATIONSYSTEM ECCS -OPERATINGTEXT 3.5.2 0 11/15/2002Title: EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATIONSYSTEM ECCS -SHUTDOWNTEXT 3.5.3 3 02/24/2014Title: EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATIONSYSTEM RCIC SYSTEMCOOLING (RCIC)COOLING (RCIC)COOLING (RCIC)TEXT 3.6.1.1Title: PRIMARY CONTAINMENT5 02/24/2014TEXT 3.6.1.2 1 04/23/2008Title: CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCKPage4 of 8 Report Date: 07/03/14Page 4 of .8Report Date: 07/03/14 SSES MANUYAL., Manual Name: TSBIManual Title: TECHNICAL SPECIFICATION BASES UNIT 1 MANUALTEXT 3.6.1.3Title: CONTAINMENTTEXT 3.6.1.4Title: CONTAINMENTTEXT 3.6.1.5Title: CONTAINMENTTEXT 3.6.1.6Title: CONTAINMENTTEXT 3.6.2.1Title: CONTAINMENTTEXT 3.6.2.2Title: CONTAINMENTTEXT 3.6.2.3Title: CONTAINMENTTEXT 3.6.2.4Title: CONTAINMENTTEXT 3.6.3.1Title: CONTAINMENTTEXT 3.6.3.2Title: CONTAINMENTTEXT 3.6.3.3Title: CONTAINMENTTEXT 3.6.4.1Title: CONTAINMENT11 07/02/2014SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)1 04/23/2008SYSTEMS CONTAINMENT PRESSURE1 10/05/2005SYSTEMS DRYWELL AIR TEMPERATURE0 11/15/2002SYSTEMS SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKERS2 04/23/2008SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE0 11/15/2002SYSTEMS SUPPRESSION POOL WATER LEVEL1 01/16/2006SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL C(0 11/15/2002SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL S]2 06/13/2006SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS1 04/18/2005SYSTEMS DRYWELL AIR FLOW SYSTEM1 02/28/2013SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION10 04/25/2014SYSTEMS SECONDARY CONTAINMENTOOLINGPRAYPae f8RprtDt:0/31Page 5 of 8Report Date: 07/03/14 SSES MANUJALManual Name: TSBlManual Title: TECHNICAL SPECIFICATION BASES UNIT 1 MANUALTEXT 3.6.4.2 9 04/25/2014Title: CONTAINMENT SYSTEMS SECONDARY CONTAINMENT ISOLATION VALVES (SCIVS)TEXT 3.6.4.3 4 09/21/2006Title: CONTAINMENT SYSTEMS STANDBY GAS TREATMENT (SGT) SYSTEMTEXT 3.7.1Title: PLANT SYSTEMSULTIMATE HEAT4 04/05/2010RESIDUAL HEAT REMOVAL SERVICE WATER (RHRSW) SYSTEM AND THESINK (UHS)TEXT 3.7.2Title: PLANTTEXT 3.7.3Title: PLANTTEXT 3. 7.4Title: PLANTTEXT 3 .7.5Title: PLANTTEXT 3.7.6Title: PLANTTEXT 3. 7.7Title: PLANT2 02/11/2009SYSTEMS EMERGENCY SERVICE WATER (ESW) SYSTEM1 01/08/2010SYSTEMS CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM0 11/15/2002SYSTEMS CONTROL ROOM FLOOR COOLING SYSTEM1 10/04/2007SYSTEMS MAIN CONDENSER OFFGAS2 04/23/2008SYSTEMS MAIN TURBINE BYPASS SYSTEM1 10/04/2007SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL0TEXT 3.7.8Title: PLANT SYSTEMS0 04/23/2008TEXT 3. 8.17 02/24/2014Title: ELECTRICAL POWER SYSTEMS AC SOURCES -OPERATINGTEXT 3,8.2 0 11/15/2002Title: ELECTRICAL POWER SYSTEMS AC SOURCES -SHUTDOWNPages of 8 Report Date: 07/03/14Page 6 of 8Report Date: 07/03/14 SSES MANUALManual Name: TSBIManual Title: TECHNICAL SPECIFICATION BASES UNIT 1 MANUALTEXT 3. 8.3Title: ELECTRICALTEXT 3.8.4Title: ELECTRICALTEXT 3.8.5Title: ELECTRICALTEXT 3.8.6Title: ELECTRICALTEXT 3.8.7Title: ELECTRICALTEXT 3.8.8Title: ELECTRICALTEXT 3.9.1Title: REFUELING (TEXT 3.9.2Title: REFUELING CTEXT 3.9.3Title: REFUELING CTEXT 3.9.4Title: REFUELING CTEXT 3.9.5Title: REFUELING CTEXT 3.9.6Title: REFUELING C4 10/23/2013POWER SYSTEMS DIESEL FUEL OIL, LUBE OIL, AND STARTING AIR3 01/19/2009POWER SYSTEMS DC SOURCES -OPERATING1 12/14/2006POWER SYSTEMS DC SOURCES -SHUTDOWN1 12/14/2006POWER SYSTEMS BATTERY CELL PARAMETERS1 10/05/2005POWER SYSTEMS DISTRIBUTION SYSTEMS -OPERATING0 11/15/2002POWER SYSTEMS DISTRIBUTION SYSTEMS -SHUTDOWN0 11/15/2002PERATIONS REFUELING EQUIPMENT INTERLOCKS1 09/01/2010PERATIONS REFUEL POSITION ONE-ROD-OUT INTERLOCK0 11/15/2002PERATIONS CONTROL ROD POSITION0 11/15/2002PERATIONS CONTROL ROD POSITION INDICATION0 11/15/2002PERATIONS CONTROL ROD OPERABILITY -REFUELING1 10/04/2007PERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL9933mPage7 of .~ Report Date: 07/03/14Page 7 of 8Report Date: 07/03/14 SSES MANUALManual Name: TSB1Manual Title: TECHNICAL SPECIFICATION BASES UNIT 1 MANUALTEXT 3.9.7 0 11/15/2002Title: REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) -HIGH WATER LEVELTEXT 3.9.8 0 11/15/2002Title: REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) -LOW WATER LEVELTEXT 3.10.1Title: SPECIALTEXT 3.10.2Title: SPECIALTEXT 3.10.3Title: SPECIALTEXT 3.10.4Title: SPECIALTEXT 3.10.5Title: SPECIALTEXT 3.10.6Title: SPECIALTEXT 3.10.7Title: SPECIALTEXT 3.10.8Title: SPECIAL1 01/23/2008INSERVICE LEAK AND HYDROSTATIC TESTING OPERATIONOPERATIONS0 11/15/2002OPERATIONS REACTOR MODE SWITCH INTERLOCK TESTINGOPERATIONSOPERATIONSOPERATIONSOPERATIONSOPERATIONSOPERATIONS0 11/15/2002SINGLE CONTROL ROD WITHDRAWAL -HOT SHUTDOWN0 11/15/2002SINGLE CONTROL ROD WITHDRAWAL -COLD SHUTDOWN0 11/15/2002SINGLE CONTROL ROD DRIVE (CRD) REMOVAL -REFUELING0 11/15/2002MULTIPLE CONTROL ROD WITHDRAWAL -REFUELING1 04/18/2006CONTROL ROD TESTING -OPERATING1 04/12/2006SHUTDOWN MARGIN (SDM) TEST -REFUELINGPage8 of 8 Report Date: 07/03/14Page 8 of 8Report Date: 07/03/14 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionTOC Table of Contents 23B 2.0 SAFETY LIMITS BASESPage B 2.0-1 0Page TS / B 2.0-2 3Page TS / B 2.0-3 5Page TS / B 2.0-4 3Page TS / B 2.0-5 5Page TS / B 2.0-6 1Pages TS / B 2.0-7 through TS / B 2.0-9 1B 3.0 LCO AND SR APPLICABILITY BASESPage TS / B 3.0-1 1Pages TS / B 3.0-2 through TS / B 3.0-4 0Pages TS / B 3.0-5 through TS / B 3.0-7 1Page TS / B 3.0-8 3Pages TS / B 3.0-9 through TS / B 3.0-11 2Page TS / B 3.0-1 la 0Page TS / B 3.0-12 1Pages TS / B 3.0-13 through TS / B 3.0-15 2Pages TS / B 3.0-16 and TS / B 3.0-17 0B 3.1 REACTIVITY CONTROL BASESPages B 3.1-1 through B 3.1-4 0Page TS / B 3.1-5 1Pages TS / B 3.1-6 and TS / B 3.1-7 2Pages B 3.1-8 through B 3.1-13 0Page TS / B 3.1-14 1Page B 3.1-15 0Page TS / B 3.1-16 1Pages B 3.1-17 through B 3.1-19 0Pages TS / B 3.1-20 and TS / B 3.1-21 1Page TS / B 3.1-22 0Page TS / B 3.1-23 1Page TS / B 3.1-24 0Pages TS / B 3.1-25 through TS / B 3.1-27 1Page TS / B 3.1-28 2Page TS / B 3.1-29 1Pages B 3.1-30 through B 3.1-33 0Pages TS / B 3.3-34 through TS / B 3.3-36 1Page TS / B 3.1-37 2Page TS / B 3.1-38 3Pages TS / B 3.1-39 and TS / B 3.1-40 2Page TS / B 3.1-40a 0Pages TS / B 3.1-41 and TS / B 3.1-42 2SUSQUEHANNA -UNIT 1 TS/B LOES-1 Revision 117SUSQUEHANNA -UNIT 1TS / B LOES-1Revision 117 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionPage TS / B 3.1.43 1Page TS / B 3.1-44 0Page TS / B 3.1-45 3Pages TS / B 3.1-46 through TS / B 3.1-49 1Page TS / B 3.1-50 0Page TS / B 3.1-51 3B 3.2 POWER DISTRIBUTION LIMITS BASESPage TS / B 3.2-1 2Pages TS / B 3.2-2 and TS / B 3.2-3 3Pages TS / B 3.2-4 and TS / B 3.2-5 2Page TS / B 3.2-6 3Page B 3.2-7 1Pages TS / B 3.2-8 and TS / B 3.2-9 3Page TS / B 3.2.10 2Page TS / B 3.2-11 3Page TS / B 3.2-12 1Page TS / B 3.2-13 2B 3.3 INSTRUMENTATIONPages TS / B 3.3-1 through TS / B 3.3-4 1Page TS / B 3.3-5 2Page TS / B 3.3-6 1Page TS / B 3.3-7 3Page TS / B 3.3-7a 1Page TS / B 3.3-8 5Pages TS / B 3.3-9 through TS / B 3.3-12 3Pages TS / B 3.3-12a 1Pages TS / B 3.3-12b and TS / B 3.3-12c 0Page TS / B 3.3-13 1Page TS / B 3.3-14 3Pages TS / B 3.3-15 and TS / B 3.3-16 1Pages TS / B 3.3-17 and TS / B 3.3-18 4Page TS / B 3.3-19 1Pages TS / B 3.3-20 through TS / B 3.3-22 2Page TS / B 3.3-22a 0Pages TS / B 3.3-23 and TS / B 3.3-24 2Pages TS / B 3.3-24a and TS / B 3.3-24b 0Page TS / B 3.3-25 3Page TS / B 3.3-26 2Page TS / B 3.3-27 1Page TS / B 3.3-28 3Page TS / B 3.3-29 4Page TS / B 3.3-30 3Page TS / B 3.3-30a 0SUSQUEHANNA -UNIT 1TS / B LOES-2Revision 117 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionPage TS / B 3.3-31 4Page TS / B 3.3-32 5Pages TS / B 3.3-32a 0Page TS / B 3.3-32b 1Page TS / B 3.3-33 5Page TS / B 3.3-33a 0Page TS / B 3.3-34 1Pages TS / B 3.3-35 and TS / B 3.3-36 2.Pages TS / B 3.3-37 and TS / B 3.3-38 1Page TS / B 3.3-39 2Pages TS / B 3.3-40 through TS / B 3.3-43 1Page TS / B 3.3-44 4Pages TS / B 3.3-44a and TS / B 3.3-44b 0Page TS / B 3.3-45 3Pages TS / B 3.3-45a and TS / B 3.3-45b 0Page TS / B 3.3-46 3Pages TS / B 3.3-47 2Pages TS / B 3.3-48 through TS / B 3.3-51 3Pages TS / B 3.3-52 and TS / B 3.3-53 2Page TS / B 3-3-53a 0Page TS / B 3.3-54 5Page TS / B 3.3-55 2Pages TS / B 3.3-56 and TS / B 3.3-57 1Page TS / B 3.3-58 0Page TS / B 3.3-59 1Page TS / B 3.3-60 0Page TS / B 3.3-61 1Pages TS / B 3.3-62 and TS / B 3.3-63 0Pages TS / B 3.3-64 and TS / B 3.3-65 2Page TS / B 3.3-66 4Page TS / B 3.3-67 3Page TS / B 3.3-68 4Page TS / B 3.3-69 5Pages TS / B 3.3-70 4Page TS / B 3.3-71 3Pages TS / B 3.3-72 and TS / B 3.3-73 2Page TS / B 3.3-74 3Page TS / B 3.3-75 2Page TS / B 3.3-75a 6Page TS / B 3.3-75b 7Page TS / B 3.3-75c 6Pages B 3.3-76 through B 3.3-77 0.Page TS / B 3.3-78 1SUSQUEHANNA -UNIT 1 TS I B LOES-3 Revision 117SUSQUEHANNA -UNIT 1TS / B LOES-3Revision 117 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionPages B 3.3-79 through B 3.3-81 0Page TS / B 3.3-82 2Page B 3.3-83 0Pages B 3.3-84 and B 3.3-85 1Page B 3.3-86 0Page B 3.3-87 1Page B 3.3-88 0Page B 3.3-89 1Page TS / B 3.3-90 1Page B 3.3-91 0Pages TS / B 3.3-92 through TS / B 3.3-100 1Pages TS / B 3.3-101 through TS / B 3.3-103 0Page TS / B 3.3-104 2Pages TS / B 3.3-105 arid TS / B 3.3-106 0Page TS / B 3.3-107 1Page TS / B 3.3-108 0Page TS / B 3.3-109 1Pages TS/B 3.3-110 arid TS/B 3.3-111 0Pages TS / B 3.3-112 and TS / B 3.3-112a 1Pages TS / B 3.3-113 through TS / B 3.3-115 1Page TS / B 3.3-116 3Page TS / B 3.3-117 1Pages TS / B 3.3-118 through TS / B 3.3-122 0Pages TS / B 3.3-123 arid TS / B 3.3-124 1Page TS / B 3.3-124a 0Page TS / B 3.3-125 0Pages TS / B 3.3-126 and TS / B 3.3-127 1Pages TS / B 3.3-128 through TS/ B 3.3-130 0Page TS / B 3.3-131 1Pages TS / B 3.3-132 through TS / B 3.3-134 0Pages B 3.3-135 through B 3.3-137 0Page TS / B 3.3-138 1Pages B 3.3-139 through B 3.3-149 0Pages TS / B 3.3-150 and TS / B 3.3-151 1Pages TS / B 3.3-152 through TS / B 3.3-154 2Page TS / B 3.3-155 1Pages TS /.B 3.3-156 through TS / B 3.3-158 2Pages TS / B 3.3-159 and TS / B 3.3-160 1Page TS / B 3.3-161 2Page TS / B 3.3-162 1Page TS / B 3.3-163 2Page TS / B 3.3-164 1Pages TS / B 3.3-165 through TS / B 3.3-167 2SUSQUEHANNA -UNIT 1TS / B LOES-4Revision 117 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionPages TS / B 3.3-168 and TS / B 3.3-169 1Page TS / B 3.3-170 3Page TS / B 3.3-171 2Pages TS / B 3.3-172 through TS / B 3.3-177 1Pages TS / B 3.3-178 and TS / B 3.3-179 2Page TS / B 3.3-179a 2Pages TS / B 3.3-179b and TS / B 3.3-179c 0Page TS / B 3.3-180 1Page TS / B 3.3-181 3Page TS / B 3.3-182 1Page TS / B 3.3-183 2Page TS / B 3.3-184 1Page TS / B 3.3-185 4Page TS / B 3.3-186 1Pages TS / B 3.3-187 and TS / B 3.3-188 2Pages TS / B 3.3-189 through TS / B 3.3-191 1Page TS / B 3.3-192 0Page TS / B 3.3-193 1Pages TS / B 3.3-194 and TS / B 3.3-195 0Page TS I B 3.3-196 2Pages TS / B 3.3-197 through TS / B 3.3-204 0Page TS / B 3.3-205 1Pages B 3.3-206 through B 3.3-209 0Page TS / B 3.3-210 1Pages B 3.3-211 through B 3.3-219 0B 3.4 REACTOR COOLANT SYSTEM BASESPages B 3.4-1 and B 3.4-2 0Pages TS / B 3.4-3 and Page TS / B 3.4-4 4Page TS / B 3.4-5 3Pages TS / B 3.4-6 through TS / B 3.4-9 2Page TS / B 3.4-10 1Pages TS / 3.4-11 and TS / B 3.4-12 0Page TS / B 3.4-13 2Page TS / B 3.4-14 1Page TS / B 3.4-15 2Pages TS / B 3.4-16 and TS / B 3.4-17 4Page TS / B 3.4-18 2Pages B 3.4-19 through B 3.4-27 0Pages TS / B 3.4-28 and TS / B 3.4-29 1Page TS / B 3.4-30 2Page TS / B 3.4-31 1Pages TS / B 3.4-32 and TS / B 3.4-33 2Page TS / B 3.4-34 1Page TS / B 3.4-34a 0SUSQUEHANNA -UNIT I TSIBLOES-5 Revision 117SUSQUEHANNA -UNIT 1TS / B LOES-5Revision 117 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionPages TS / B 3.4-35 and TS / B 3.4-36 1Page TS / B 3.4-37 2Page TS / B 3.4-38 1Pages B 3.4-39 and B 3.4-40 0Page TS / B 3.4-41 2Pages TS / B 3.4-42 through TS / B 3.4-45 0Page TS / B 3.4-46 1Pages TS B 3.4-47 and TS / B 3.4-48 0Page TS / B 3.4-49 3Page TS / B 3.4-50 1Page TS / B 3.4-51 3Page TS / B 3.4-52 2Page TS / B 3.4-53 1Pages TS / B 3.4-54 through TS / B 3.4-56 .2Page TS / B 3.4-57 3Pages TS / B 3.4-58 through TS / B 3.4-60 1B 3.5 ECCS AND RCIC BASESPages B 3.5-1 and B 3.5-2 0Page TS / B 3.5-3 3Page TS / B 3.5-4 1Page TS / B 3.5-5 2Page TS / B 3.5-6 1Pages B 3.5-7 through B 3.5-10 0Page TS / B 3.5-11 1Page TS / B 3.5-12 0Page TS / B 3.5-13 2Pages TS / B 3.5-14 and TS / B 3.5-15 0Page TS / B 3.5-16 1Page TS / B 3.5-17 2Page TS / B 3.5-18 1Pages B 3.5-19 through B 3.5-24 0Page TS / B 3.5-25 1Page TS / B 3.5-26 and TS / B 3.5-27 2Page TS / B 3.5-28 0Page TS / B 3.5-29 1Pages TS / B 3.5-30 and TS / B 3.5-31 0B 3.6 CONTAINMENT SYSTEMS BASESPage TS / B 3.6-1 2Page TS / B 3.6-1a 3Page TS / B 3.6-2 4Page TS / B 3.6-3 3Page TS / B 3.6-4 4Pages TS / B 3.6-5 and TS / B 3.6-6 3SUSQUEHANNA -UNIT I TS I B LOES-6 Revision 117SUSQUEHANNA -UNIT 1TS / B LOES-6Revision 117 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionPage TS / B 3.6-6a 2Page TS / B 3.6-6b 4Page TS / B 3.6-6c 0Page B 3.6-7 0Page B 3.6-8 1Pages B 3.6-9 through B 3.6-14 0Page TS / B 3.6-15 3Page TS / B 3.6-15a 0Page TS / B 3.6-15b 2Pages TS / B 3.6-16 and TS / B 3.6-17 2Page TS / B 3.6-17a 1Pages TS / B 3.6-18 and TS / B 3.6-19 0Page TS / B 3.6-20 1Page TS / B 3.6-21 2Page TS / B 3.6-22 1Page TS / B 3.6-22a 0Page TS / B 3.6-23 1Pages TS / B 3.6-24 and TS / B 3.6-25 0Pages TS / B 3.6-26 and TS / B 3.6-27 2Page TS / B 3.6-28 7Page TS / B 3.6-29 2Page TS / B 3.6-30 1Page TS / B 3.6-31 3Pages TS / B 3.6-32 and TS / B 3.6-33 1Pages TS / B 3.6-34 and TS / B 3.6-35 0Page TS / B 3.6-36 1Page TS / B 3.6-37 0Page TS / B 3.6-38 3Page TS / B 3.6-39 2Page TS / B 3.6-40 6Page TS / B 3.6-40a 1Page B 3.6-41 1Pages B 3.6-42 and B 3.6-43 0Pages TS / B 3.6-44 and TS / B 3.6-45 1Page TS / B 3.6-46 2Pages TS / B 3.6-47 through TS / B 3.6-51 1Page TS / B 3.6-52 2Pages TS / B 3.6-53 through TS / B 3.6-56 0Page TS / B 3.6-57 1Page TS / 3.6-58 2Pages B 3.6-59 through B 3.6-63 0Pages TS / B 3.6-64 and TS / B 3.6-65 1Pages B 3.6-66 through B 3.6-69 0SUSQUEHANNA -UNIT 1 TS I B LOES-7 Revision 117SUSQUEHANNA -UNIT 1TS / B LOES-7Revision 117 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionPages TS / B 3.6-70 through TS / B 3.6-75 1Pages B 3.6-76 and B 3.6-77 0Page TS / B 3.6-78 1Pages B 3.6-79 and B 3.3.6-80 0Page TS / B 3.6-81 1Pages TS / B 3.6-82 and TS / B 3.6-83 0Page TS / B 3.6-84 4Page TS / B 3.6-85 2Page TS / B 3.6-86 4Pages TS / B 3.6-87 through TS / B 3.6-88a 2Page TS / B 3.6-89 6Page TS / B 3.6-90 3Page TS / B 3.6-90a 0Pages TS / B 3.6-91 and TS / B 3.6-92 3Page TS / B 3.6-93 2Pages TS / B 3.6-94 through TS / B 3.6-96 1Page TS / B 3.6-97 2Page TS / B 3.6-98 1Page TS / B 3.6-99 2Pages TS / B 3.6-100 and TS / B 3.6-100a 6Page TS / B 3.6-100b 4Page TS / B 3.6-100c 0Pages TS / B 3.6-101 and TS / B 3.6-102 1Pages TS / B 3.6-103 and TS / B 3.6-104 2Page TS / B 3.6-105 3Page TS / B 3.6-106 2Page TS / B 3.6-107 3B 3.7 PLANT SYSTEMS BASESPages TS / B 3.7-1 3Page TS / B 3.7-2 4Pages TS / B 3.7-3 through TS / B 3.7-5 3Page TS / B 3.7-5a 1Page TS / B 3.7-6 3Page TS / B 3.7-6a 2Page TS / B 3.7-6b 1Page TS / B 3.7-6c 2Page TS / B 3.7-7 3Page TS / B 3.7-8 2Pages TS / B 3.7-9 through TS / B 3.7-11 1Pages TS / B 3.7-12 and TS / B 3.7-13 2Pages TS / B 3.7-14 through TS / B 3.7-18 3Page TS / B 3.7-18a 1Pages TS / B 3.7-18b through TS I B 3.7-18e 0SUSQUEHANNA -UNIT 1SUSQUEHANNA -UNIT I TS I B LOES-8 Revision 117TS / B LOES-8Revision 117 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionPages TS / B 3.7-19 through TS I B 3.7-23 1Page TS / B 3.7-24 1Pages TS / B 3.7-25 and TS / B 3.7-26 0Pages TS / B 3.7-27 through TS / B 3.7-29 5Page TS / B 3.7-30 2Page TS / B 3.7-31 1Page TS / B 3.7-32 0Page TS / B 3.7-33 1Pages TS / B 3.7-34 through TS / B 3.7-37 0B 3.8 ELECTRICAL POWER SYSTEMS BASESPage TS / B 3.8-1 3Pages TS / B 3.8-2 and TS / B 3.8-3 2Page TS / B 3.8-4 3Pages TS / B 3.8-4a and TS / B 3.8-4b 0Page TS / B 3.8-5 5Page TS I B 3.8-6 3Pages TS / B 3.8-7 through TS/B 3.8-8 2Page TS / B 3.8-9 4Page TS / B 3.8-10 3Pages TS/B 3.8-11 and TS/B 3.8-17 2Page TS / B 3.8-18 3Pages TS / B 3.8-19 through TS / B 3.8-21 2Pages TS / B 3.8-22 and TS / B 3.8-23 3Pages TS / B 3.8-24 through TS / B 3.8-30 2Pages TS / B 3.8-31 and TS / B 3.8-32 3Pages TS / B 3.8-33 through TS / B 3.8-37 2Pages B 3.8-38 through B 3.8-44 0Page TS / B 3.8-45 3Pages TS / B 3.8-46 through TS / B 3.8-48 0Pages TS / B 3.8-49 and TS / B 3.8-50 3Page TS / B 3.8-51 1Page TS / B 3.8-52 0Page TS / B 3.8-53 1Pages TS / B 3.8-54 through TS / B 3.8-57 2Pages TS / B 3.8-58 through TS / B 3.8-61 3Pages TS / B 3.8-62 and TS / B 3.8-63 5Page TS / B 3.8-64 4Page TS / B 3.8-65 5Pages TS / B 3.8-66 through TS / B 3.8-77 1Pages TS / B 3.8-77A through TS / B 3.8-77C 0Pages B 3.8-78 through B 3.8-80 0Page TS / B 3.8-81 1Pages B 3.8-82 through B 3.8-90 0SUSQUEHANNA-UNITi TSIBLOES-9 Revision 117SUSQUEHANNA -UNIT 1TS / B LOES-9Revision 117 SUSQUEHANNA STEAM ELECTRIC STATIONLIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)Section Title RevisionB 3.9 REFUELING OPERATIONS BASESPages TS / B 3.9-1 and TS-/ B 3.9-1a 1Pages TS / B 3.9-2 through TS / B 3.9-5 1Pages TS / B 3.9-6 through TS / B 3.9-8 0Pages B 3.9-9 through B 3.9-18 0Pages TS / B 3.9-19 through TS / B 3.9-21 1Pages B 3.9-22 through B 3.9-30 0B 3.10 SPECIAL OPERATIONS BASESPage TS / B 3.10-1 2Pages TS / B 3.10-2 through TS / B 3.10-5 1Pages B 3.10-6 through B 3.10-31 0Page TS / B 3.10-32 2Page B 3.10-33 0Page TS / B 3.10-34 1Pages B 3.10-35 and B 3.10-36 0Page TS / B 3.10-37 1Page TS / B 3.10-38 2SUSQUEHANNA -UNIT 1SUSQUEHANNA -UNIT 1 TS / B LOES-lO Revision 117TS / B LOES-10Revision 117 TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)132.0 SA FETY LIM ITS (SLs) ............................................................................ TS/B 2.0-1E2.1.1 Reactor Core SLs ................................................................ TS/B2.0-1B2.1.2 Reactor Coolant System (RCS) Pressure SL ........................... TS/B2.0-7E3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ........ TS/B3.0-1B3.1 REACTIVITY CONTROL SYSTEMS .................................................... B3.1-133.1.1 Shutdown Margin (SDM) ............................ B3.1-133.1.2 R eactivity A nom alies ...................................................................... B3.1-8B3.1.3 Control Rod OPERABILITY ............................................................ B3.1-1313.1.4 Control Rod Scram Times ........................................................ TS/B3.1-22B3.1.5 Control Rod Scram Accumulators ............................................ TS/B3.1-29B3.1.6 Rod Pattern Control .................................................................. TS/B3.1-34B3.1.7 Standby Liquid Control (SLC) System ...................................... TS/B3.1-39B3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves .......... TS/B3.1-47B3.2 POWER DISTRIBUTION LIMITS ................................................... TS/B3.2-1133.2.1 Average Planar Linear Heat Generation Rate (APLHGR) ........ TS/B3.2-183.2.2 Minimum Critical Power Ratio (MCPR) ..................................... TS/B3.2-583.2.3 Linear Heat Generation Rate (LHGR) ....................................... TS/B3.2-10B3.3 INSTRUMENTATION ..................................................................... TS/B3.3-1B3.3.1.1 Reactor Protection System (RPS) Instrumentation ................... TS/13.3-1B3.3.1.2 Source Range Monitor (SRM) Instrumentation ......................... TS/B3.3-35B3.3.2.1 Control Rod Block Instrumentation ........................................... TS/B3.3-44133.3.2.2 Feedwater -Main Turbine High Water Level TripInstrum entation ................................................................... TS/1B 3.3-55B3.3.3.1 Post Accident Monitoring (PAM) Instrumentation .................... TS/B3.3-6483.3.3.2 Remote Shutdown System ............................................................. B3.3-76B3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)Instru m entation ......................................................................... B 3.3-81133.3.4.2 Anticipated Transient Without Scram Re.circulationPump Trip (ATWS-RPT) Instrumentation .............................. TS/B133-9213.3.5.1 Emergency Core Cooling System (ECCS)Instrum entation ................................................................... TS/B 3.3-1 0183.3.5.2 Reactor Core Isolation Cooling (RCIC) SystemInstrum entation ......................................................................... B 3.3-13583.3.6.1 Primary Containment Isolation Instrumentation ........................ TS/B3.3-147B3.3.6.2 Secondary Containment Isolation Instrumentation ................... TS/B3.3-180B3.3.7.1 Control Room Emergency Outside Air Supply (CREOAS)System Instrumentation ...................................................... TS/B3.3-192(continued)SUSQUEHANNA -UNIT 1TS / B TOC -1Revision 23 TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)B3.3 INSTRUMENTATION (continued)B3.3.8.1 Loss of Power (LOP) Instrumentation ....................................... TS/B3.3-205B3.3.8.2 Reactor Protection System (RPS) Electric PowerMonitoring ................................... B3.3-213B3.4 REACTOR COOLANT SYSTEM (RCS) ........................................... TS/B3.4-1B3.4.1 Recirculation Loops Operating ................................................... TS/B3.4-1B3.4.2 Jet P um ps ................................................................................ TS/B3.4-10B3.4.3 Safety/Relief Valves (S/RVs) .................................................... TS/B3.4-15B3.4.4 RCS Operational LEAKAGE .......................................................... B3.4-19B3.4.5 RCS Pressure Isolation Valve (PIV) Leakage ................................. B3.4-24B3.4.6 RCS Leakage Detection Instrumentation .................................. TS/B3.4-30B3.4.7 RCS Specific Activity ............................................................... TS/B3.4-35B3.4.8 Residual Heat Removal (RHR) Shutdown CoolingSystem -Hot Shutdown ........................................................... B3.4-39B3.4.9 Residual Heat Removal (RHR) Shutdown CoolingSystem -Cold Shutdown ................................................... TS/B3.4-44B3.4.10 RCS Pressure and Temperature (P/T) Limits ........................... TS/B3.4-49B3.4.1 1 Reactor Steam Dome Pressure ................................................ TS/B3.4-58B3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTORCORE ISOLATION COOLING (RCIC) SYSTEM .................................. B3.5-1B3.5.1 ECCS -Operating ......................................................................... B3.5-1B3.5.2 ECCS -Shutdown ......................................................................... B3.5-19B3.5.3 RCIC System ........................................................................... TS/B3.5-25B3.6 CONTAINMENT SYSTEMS ........................................................... TS/B3.6-1B3.6.1.1 Primary Containment ................................................................. TS/B3.6-1B3.6.1.2 Primary Containment Air Lock ........................................................ B3.6-7B3.6.1.3 Primary Containment Isolation Valves (PCIVs) ......................... TS/B3.6-15B3.6.1.4 Containment Pressure .................................................................... B3.6-41B3.6.1.5 Drywell Air Temperature ........................................................... TS/B3.6-44B3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers ................ TS/B3.6-47B3.6.2.1 Suppression Pool Average Temperature .................................. TS/B3.6-53B3.6.2.2 Suppression Pool Water Level ....................................................... B3.6-59B3.6.2.3 Residual Heat Removal (RHR) Suppression PoolC o o ling ..................................................................................... B 3 .6 -6 2B3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ................ B3.6-66B3.6.3.1 Not Used ................................................................................. TS/B3.6-70B3.6.3.2 Drywell Air Flow System ................................................................. B3.6-76B3.6.3.3 Primary Containment Oxygen Concentration ............................ TS/B3.6-81B3.6.4.1 Secondary Containment ........................................................... TS/B3.6-84B3.6.4.2 Secondary Containment Isolation Valves (SCIVs) .................... TS/B3.6-91B3.6.4.3 Standby Gas Treatment (SGT) System ................................... TS/B3.6-101(continued)SUSQUEHANNA -UNIT 1TS / B TOC -2Revision 23 TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)B3.7 PLANT SYSTEMS ......................................................................... TS/B3.7-1B3.7.1 Residual Heat Removal Service Water (RHRSW) Systemand the Ultimate Heat Sink (UHS) ...................................... TS/B3.7-1B3.7.2 Emergency Service Water (ESW) System ................................ TS/B3.7-7B3.7.3 Control Room Emergency Outside Air Supply(CREOAS) System............................................................. TS/B3.7-12B3.7.4 Control Room Floor Cooling System ........................................ TS/B3.7-19B3.7.5 Main Condenser Offgas ........................................................... TS/B3.7-24B3.7.6 Main Turbine Bypass System ................................................... TS/B3.7-27B3.7.7 Spent Fuel Storage Pool Water Level ................... TS/B3.7-31B3.7.8 Main Turbine Pressure Regulation System .............................. TS/B3.7-34B3.8 ELECTRICAL POWER SYSTEM ...................... TS/B3.8-1B3.8.1 AC Sources -Operating .......................................................... TS/B3.8-1B3.8.2 AC Sources -Shutdown ................................................................ B3.8-38B3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ................................ TS/B3.8-45B3.8.4 DC Sources -Operating .......................................................... TS/B3.8-54B3.8.5 DC Sources -Shutdown .......................................................... TS/B3.8-66B3.8.6 Battery Parameters .................................................................. TS/B3.8-71B3.8.7 Distribution Systems -Operating ................................................... B3.8-78B3.8.8 Distribution Systems -Shutdown ................................................... B3.8-86B3.9 REFUELING OPERATIONS .......................................................... TS/B3.9-1B3.9.1 Refueling Equipment Interlocks ................................................ TS/B3.9-1B3.9.2 Refuel Position One-Rod-Out Interlock ..................................... TS/B3.9-5B3.9.3 C ontrol Rod Position ...................................................................... B3.9-9B3.9.4 Control Rod Position Indication ...................................................... B3.9-12B3.9.5 Control Rod OPERABILITY- Refueling ......................................... B3.9-16B3.9.6 Reactor Pressure Vessel (RPV) Water Level ........................... TS/B3.9-19B3.9.7 Residual Heat Removal (RHR) -High Water Level ........................ B3.9-22B3.9.8 Residual Heat Removal (RHR) -Low Water Level ......................... B3.9-26B3.10 SPECIAL OPERATIONS ............................................................... TS/B3.10-1B3.10.1 Inservice Leak and Hydrostatic Testing Operation ............... TS/B3.10-1B3.10.2 Reactor Mode Switch Interlock Testing ........................................... B3.10-6B3.10.3 Single Control Rod Withdrawal -Hot Shutdown ............................. B3.10-11B3.10.4 Single Control Rod Withdrawal -Cold Shutdown ........................... B3.10-16B3.10.5 Single Control Rod Drive (CRD) Removal -Refueling ................... B3.10-21B3.10.6 Multiple Control Rod Withdrawal -Refueling .................................. B3.10-26B3.10.7 Control Rod Testing -Operating .................................................... B3.10-29B3.10.8 SHUTDOWN MARGIN (SDM) Test- Refueling ............................. B3.10-33TSBI Text TOC6/12/14SUSQUEHANNA -UNIT I TS / B TOO -3 Revision 23SUSQUEHANNA -UNIT 1TS / B TOC -3Revision 23 PPL Rev. 11PCIVsB 3.6.1.3B 3.6 CONTAINMENT SYSTEMSB 3.6.1.3 Primary Containment Isolation Valves (PCIVs)BASESBACKGROUND The function of the PCIVs, in combination with other accidentmitigation systems, including secondary containment bypassvalves that are not PCIVs, is to limit fission product release duringand following postulated Design Basis Accidents (DBAs) to withinlimits. Primary containment isolation within the time limitsspecified for those isolation valves designed to close automaticallyensures that the release of radioactive material to the environmentwill be, consistent with the assumptions used in the analyses for aDBA.The OPERABILITY requirements for PCIVs help ensure that anadequate primary containment boundary is maintained, during andafter an accident by minimizing potential paths to the environment.Therefore, the OPERABILITY requirements provide assurancethat primary containment function assumed in the safety analyseswill be maintained. For PCIVs, the primary containment isolationfunction is that the valve must be able to close (automatically ormanually) and/or remain closed, and maintain leakage within thatassumed in the DBA LOCA Dose Analysis. These isolationdevices 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), blindflanges, and closed systems are considered passive devices. TheOPERABILITY requirements for closed systems are discussed inTechnical Requirements Manual (TRM) Bases 3.6.4. Checkvalves, or other automatic valves designed to close withoutoperator action following an accident, are considered activedevices. Two barriers in series are provided for each penetrationso that no single credible failure or malfunction of an activecomponent can result in a loss of isolation or leakage thatexceeds limits assumed in the safety analyses. One of thesebarriers may be a closed system.For each division of H202 Analyzers, the lines, up to and includingthe first normally closed valves within the H202 Analyzer panels,are extensions of primary containment (i.e., closed system), andare required to be leak rate tested in(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-15Revision 3 PPL Rev. 11PCIVsB 3.6.1.3BASESBACKGROUND(continued)accordance with the Leakage Rate Test Program. The H202Analyzer closed system boundary is identified in the LeakageRate Test Program. The closed system boundary consists ofthose components, piping, tubing, fittings, and valves, which meetthe guidance of Reference 6. The closed system provides asecondary barrier in the event of a single failure of the PCIVs, asdescribed below. The closed system boundary between PASSand the H202 Analyzer system ends at the process samplingsolenoid operated isolation valves between the systems (SV-12361, SV-12365, SV-12366, SV-12368, and SV-12369). Thesesolenoid operated isolation valves do not fully meet the guidanceof Reference 6 for closed system boundary valves in that they arenot powered from a Class 1 E power source. However, basedupon a risk determination, operating these valves as closedsystem boundary valves is not risk significant. These valves alsoform the end of the Seismic Category I boundary between thesystems. These process sampling solenoid operated isolationvalves; are normally closed and are required to be leak rate testedin accordance with the Leakage Rate Test Program as part of theclosed system for the H202 Analyzer system. These valves are"closed system boundary valves" and may be opened underadministrative control, as delineated in Technical RequirementsManual (TRM) Bases 3.6.4. Opening of these valves to permittesting of PASS in Modes 1, 2, and 3 is permitted in accordancewith TRO 3.6.4.Each H202 Analyzer Sampling line penetrating primarycontainment has two PCIVs, located just outside primarycontainment. While two PCIVs are provided on each line, a singleactive failure of a relay in the control circuitry for these valves,could result in both valves failing to close or failing to remainclosed. Furthermore, a single failure (a hot short in the commonraceway to all the valves) could simultaneously affect all of thePCIVs within a H202 Analyzer division. Therefore, thecontainment isolation barriers for these penetrations consist of twoPCIVs and a closed system. For situations where one or bothPCIVs. are inoperable, the ACTIONS to be taken are similar to theACTIONS for a single PCIV backed by a closed system.(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-15aRevision 0 PPL Rev. 11PCIVsB 3.6.1.3BASESBACKGROUND The drywell vent and purge lines are 24 inches in diameter;(continued) the suppression chamber vent and purge lines are 18 inches indiameter. The containment purge valves are normally maintainedclosed in MODES 1, 2, and 3 to ensure the primary containmentboundary is maintained. The outboard isolation valves have2 inch bypass lines around them for use during normal reactoroperation.The RHR Shutdown Cooling return line containment penetrations{X-13A(B)}are provided with a normally closed gate valve{HV-151F015A(B)} and a normally open globe valve{HV-151F017A(B)} outside containment and a testable checkvalve {HV-151F050A(B)} with a normally closed parallel airoperated globe valve {HV-151F122A(B)} inside containment. Thegate valve is manually opened and automatically isolates upon acontainment isolation signal from the Nuclear Steam SupplyShutoff System or RPV low level 3 when the RHR System isoperated in the Shutdown Cooling Mode only. The LPCIsubsystem is an operational mode of the RHR System and usesthe same injection lines to the RPV as the Shutdown CoolingMode.The design of these containment penetrations is unique in thatsome valves are containment isolation valves while others performthe function of pressure isolation valves. In order to meet the10 CFR 50 Appendix J leakage testing requirements, theHV-1 51 F01 5A(B) and the closed system outside containment arethe only barriers tested in accordance with the Leakage Rate TestProgram. Since these containment penetrations {X-13A andX-13B} include a containment isolation valve outside containmentthat is tested in accordance with 10 CFR 50 Appendix Jrequirements and a closed system outside containment that meetsthe requirements of USNRC Standard Review Plan 6.2.4(September 1975), paragraph 11.3.e, the containment isolationprovisions for these penetrations provide an acceptable alternativeto the explicit requirements of 10 CFR 50, Appendix A, GDC 55.Containment penetrations X-13A(B) are also high/low pressuresystem interfaces. In order to meet the requirements to have two(2) isolation valves between the high pressure and low pressuresystems, the HV-151F050A(B), HV-151F122A(B), andHV-1 51 F01 5A(B) valves are used to meet this requirement andare tested in accordance with the pressure test program.(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-15bRevision 2 PPL Rev. 11PCIVsB 3.6.1.3BASESAPPLICABLE The PCIVs LCO was derived from the assumptions relatedSAFETY ANALYSES to minimizing the loss of reactor coolant inventory, and establishingthe primary containment boundary during major accidents. As partof the primary containment boundary, PCIV OPERABILITYsupports leak tightness of primary containment. Therefore, thesafety analysis of any event requiring isolation of primarycontainment is applicable to this LCO.The DBAs that result in a release of radioactive material within primarycontainment are a LOCA and a main steam line break (MSLB). In theanalysis for each of these accidents, it is assumed that PCIVs areeither closed or close within the required isolation times following eventinitiation. This ensures that potential paths to the environment throughPCIVs (including primary containment purge valves) and secondarycontainment bypass valves that are not PCIVs are minimized. Theclosure time of the main steam isolation valves (MSIVs) for a MSLBoutside primary containment is a significant variable from a radiologicalstandpoint. The MSIVs are required to close within 3 to 5 secondssince the 5 second closure time is assumed in the analysis. The safetyanalyses assume that the purge valves were closed at event initiation.Likewise, it is assumed that the primary containment is isolated suchthat release of fission products to the environment is controlled.The DE3A analysis assumes that within the required isolation timeleakage is terminated, except for the maximum allowable leakagerate, LK.The single failure criterion required to be imposed in the conduct ofunit safety analyses was considered in the original design of theprimary containment purge valves. Two valves in series on eachpurge line provide assurance that both the supply and exhaust linescould be isolated even if a single failure occurred.The primary containment purge valves may be unable to close inthe environment following a LOCA. Therefore, each of the purgevalves is required to remain closed during MODES 1, 2, and 3except as permitted under Note 2 of SR 3.6.1.3.1. In this case, thesingle failure criterion remains applicable to the primarycontainment purge valve(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-16Revision 2 PPL Rev. 11PCIVsB 3.6.1.3BASESAPPLICABLE due to failure in the control circuit associated with eachSAFETYANALYSES valve. The primary containment purge valve design(continued) precludes a single failure from compromising the primarycontainment boundary as long as the system is operated inaccordance with this LCO.Both H202 Analyzer PCIVs may not be able to close given a singlefailure in the control circuitry of the valves. The single failure* iscaused by a "hot short' in the cables/raceway to the PCIVs thatcauses both PCIVs for a given penetration to remain open or toopen when required to be closed. This failure is required to beconsidered in accordance with IEEE-279 as discussed in FSARSection 7.3.2a. However, the single failure criterion forcontainment isolation of the H202 Analyzer penetrations issatisfied by virtue of the combination of the associated PCIVs andthe closed system formed by the H202 Analyzer piping system asdiscussed in the BACKGROUND section above.The closed system boundary between PASS and the H202Analyzer system ends at the process sampling solenoid operatedisolation valves between the systems (SV-12361, SV-12365,SV-12366, SV-12368, and SV-12369). The closed system is notfully qualified to the guidance of Reference 6 in that the closedsystem boundary valves between the H202 system and PASS arenot powered from a Class I E power source. However, basedupon a risk determination, the use of these valves is considered tohave no risk significance. This exemption to the requirement ofReference 6 for the closed system boundary is documented inLicense Amendment No. 195.PCIVs satisfy Criterion 3 of the NRC Policy Statement. (Ref. 2)LCO PCIVs form a part of the primary containment boundary, or in thecase of SCBL valves limit leakage from the primary containment.The PCIV safety function is related to minimizing the loss ofreactor coolant inventory and establishing the primarycontainment boundary during a DBA.The power operated, automatic isolation valves are required tohave isolation times within limits and actuate on an automaticisolation signal. The valves covered by this LCO are listed inTable B 3.6.1.3-1 and Table B 3.6.1.3-2.(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-17Revision 2 PPL Rev. 11PCIVsB 3.6.1.3BASESLCO(continued)The normally closed PCIVs, including secondary containment bypassvalves listed in Table B 3.6.1.3-2 that are not PCIVs, are consideredOPERABLE Wien manual valves are closed or open in accordance withappropriate administrative controls, automatic valves are in their closedposition, blind flanges are in place, and closed systems are intact. Thesepassive isolation valves and devices are those listed in Table B 3.6.1.3-1.Leak rate testing of the secondary containment bypass valves listed in Table3.6.1.3-2 is permitted in Modes 1, 2 & 3 as described in the PrimaryContainment Leakage Rate Testing Program.Purge valves with resilient seals, secondary containment bypass valves,including secondary containment bypass valves listed in Table B 3.6.1.3-2that are not PCIVs, MSIVs, and hydrostatically tested valves must meetadditional leakage rate requirements. Other PCIV leakage rates areaddressed by LCO 3.6.1.1, "Primary Containment," as Type B or C testing.This LCO provides assurance that the PCIVs will perform their designedsafety functions to minimize the loss of reactor coolant inventory andestablish the primary containment boundary during accidentsAPPLICABILITYIn MODES 1, 2, and 3, a DBA could cause a release of radioactive materialto primary containment. In MODES 4 and 5, the probability andconsequences of these events are reduced due to the pressure andtemperature limitations of these MODES. Therefore, most PCIVs are notrequired to be(continued)UNIT 1 TS / B 3.6-17a Revision 1SUSQUEHANNA-[

PPL Rev. 11PCIVsB 3.6.1.3BASESAPPLICABILITY 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 inadvertentreactor vessel draindown. These valves are those whoseassociated instrumentation is required to be OPERABLE perLCO 3.3.6.1, "Primary Containment Isolation Instrumentation."(This does not include the valves that isolate the associatedinstrumentation.)ACTIONS The ACTIONS are modified by a Note allowing penetration flowpath(s) to be unisolated intermittently under administrativecontrols. These controls consist of stationing a dedicated operatorat the controls of the valve, who is in continuous communicationwith the control room. In this way, the penetration can be rapidlyisolated when a need for primary containment isolation isindicated.A second Note has been added to provide clarification that, for thepurpose of this LCO, separate Condition entry is allowed for eachpenetration flow path. This is acceptable, since the RequiredActions for each Condition provide appropriate compensatoryactions for each inoperable PCIV. Complying with the RequiredActions may allow for continued operation, and subsequentinoperable PCIVs are governed by subsequent Condition entryand application of associated Required Actions.The ACTIONS are modified by Notes 3 and 4. Note 3 ensuresthat appropriate remedial actions are taken, if necessary, if theaffected system(s) are rendered inoperable by an inoperable PCIV(e.g., an Emergency Core Cooling System subsystem isinoperable due to a failed open test return valve). Note 4 ensuresappropriate remedial actions are taken when the primarycontainment leakage limits are exceeded. Pursuant to LCO 3.0.6,these actions are not required even when the associated LCO isnot met. Therefore, Notes 3 and 4 are added to require the properactions be taken.A.1 and A.2With one or more penetration flow paths with one PCIV inoperableexcept for purge valve leakage not within limit,(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-18Revision 0 PPL Rev. 11PCIVsB 3.6.1.3BASESACTIONS A.1 and A.2 (continued)the affected penetration flow paths must be isolated. The method ofisolation must include the use of at least one isolation barrier that cannotbe adversely affected by a single active failure. Isolation barriers thatmeet this criterion are a closed and de-activated automatic valve, aclosed manual valve, a blind flange, and a check valve with flow throughthe valve secured. For a penetration isolated in accordance withRequired Action A.1, the device used to isolate the penetration should bethe closest available valve to the primary containment. The RequiredAction 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 /> formain 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 reasonableconsidering the time required to isolate the penetration and the relativeimportance of supporting primary containment OPERABILITY duringMODES 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 isallowed. 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 allowsa period of time to restore the MSIVs to OPERABLE status given the factthat MSIV closure will result in isolation of the main steam line(s) and apotential for plant shutdown.For affected penetrations that have been isolated in accordance withRequired Action A.1, the affected penetration flow path(s) must beverified to be isolated on a periodic basis. This is necessary to ensurethat primary containment penetrations required to be isolated following anaccident, and no longer capable of being automatically isolated, will be inthe isolation position should an event occur. This Required Action doesnot require any testing or device manipulation. Rather, it involvesverification that those devices outside containment and capable ofpotentially being mispositioned are in the correct position. TheCompletion Time of "once per 31 days for isolation devices outsideprimary containment" is appropriate because the devices are operatedunder administrative controls and the probability of their misalignment islow. For the devices inside primary containment, the time periodspecified "prior to entering MODE 2 or 3 from MODE 4, if primarycontainment was de-inerted while in MODE 4, if not performed within theprevious 92 days" is based on engineering judgment and is consideredreasonable in view of the inaccessibility of the devices and otheradministrative controls ensuring that device misalignment is an unlikelypossibility.(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-19Revision 0 PPL Rev. 11PCIVsB 3.6.1.3BASESACTIONS A. 1 and A.2 (continued)Condition A is modified by a Note indicating that this Condition isonly applicable to those penetration flow paths with two PCIVsexcept for the H202 Analyzer penetrations. For penetration flowpaths with one PCIV, Condition C provides the appropriateRequired Actions. For the H202 Analyzer Penetrations,Condition D provides the appropriate Required Actions.Required Action A.2 is modified by a Note that applies to isolationdevices located in high radiation areas, and allows them to beverified by use of administrative means. Allowing verification byadministrative means is considered acceptable, since access tothese areas is typically restricted. Therefore, the probability ofmisalignment of these devices, once they have been verified to bein the proper position, is low.B._1With one or more penetration flow paths with two PCIVsinoperable except for purge valve leakage not within limit, eitherthe inoperable PCIVs must be restored to OPERABLE status orthe 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 oneisolation barrier that cannot be adversely affected by a singleactive failure. Isolation barriers that meet this criterion are aclosed 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 withthe ACTIONS of LCO 3.6.1.1.Condition B is modified by a Note-indicating this Condition is onlyapplicable to penetration flow paths with two PCIVs except for theH202 Analyzer penetrations. For penetration flow paths with onePCIV, Condition C provides the appropriate Required Actions. Forthe H1-202 Analyzer Penetrations, Condition D provides theappropriate Required Actions.C.1 and C.2With one or more penetration flow paths with one PCIVinoperable, the inoperable valve must be restored to OPERABLEstatus or the affected penetration flow path(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-20Revision 1 PPL Rev. 11PCIVsB 3.6.1.3BASESACTIONS C.1 and C.2 (continued)must be isolated. The method of isolation must include the use ofat least one isolation barrier that cannot be adversely affected bya single active failure. Isolation barriers that meet this criterion area closed and de-activated automatic valve, a closed manual valve,and a blind flange. A check valve may not be used to isolate theaffected penetration. Required Action C.1 must be completedwithin 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 of72 hours is reasonable considering the relative stability of theclosed system (hence, reliability) to act as a penetration isolationboundary and the relative importance of supporting primarycontainment OPERABILITY during MODES 1, 2, and 3. Theclosed system must meet the requirements of Reference 6. Forconditions where the PCIV and the closed system are inoperable,the Required Actions of TRO 3.6.4, Condition B apply. For theExcess Flow Check Valves (EFCV), the Completion Time of12 hours is reasonable considering the instrument and the smallpipe diameter of penetration (hence, reliability) to act as apenetration isolation boundary and the small pipe diameter of theaffected penetrations. In the event the affected penetration flowpath is isolated in accordance with Required Action C. 1, theaffected penetration must be verified to be isolated on a periodicbasis. This is necessary to ensure that primary containmentpenetrations required to be isolated following an accident areisolated. The Completion Time of once per 31 days for verifyingeach affected penetration is isolated is appropriate because thevalves are operated under administrative controls and theprobability of their misalignment is low.Condition C is modified by a Note indicating that this Condition isonly applicable to penetration flow paths with only one PCIV. Forpenetration flow paths with two PCIVs and the H202 AnalyzerPenetration. Conditions A, B and D provide the appropriateRequired Actions.Required Action C.2 is modified by a Note that applies to valvesand blind flanges located in high radiation areas and allows themto be verified by use of administrative means. Allowing verificationby administrative means is considered acceptable, since accessto these areas is typically restricted. Therefore, the probability ofmisalignment of these valves, once they have been verified to bein the proper position, is low.(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-21Revision 2 PPL Rev. 11PCIVsB 3.6.1.3BASESACTIONS D.1 and D.2(continued)With one or more H202 Analyzer penetrations with one or bothPCIVs inoperable, the inoperable valve(s) must be restored toOPERABLE status or the affected penetration flow path must beisolated. The method of isolation must include the use of at leastone isolation barrier that cannot be adversely affected. by a singleactive failure. Isolation barriers that meet this criterion are aclosed and de-activated automatic valve, a closed manual valve,and a blind flange. A check valve may not be used to isolate theaffected penetration. Required Action D.1 must be completedwithin 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 of72 hours is reasonable considering the unique design of the H202Analyzer penetrations. The containment isolation barriers forthese penetrations consist of two PCIVs and a closed system. Inaddition, 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 reasonableconsidering the relative stability of the closed system (hence,reliability) to act as a penetration isolation boundary and therelative importance of supporting primary containmentOPERABILITY during MODES 1, 2, and 3. In the event theaffected penetration flow path is isolated in accordance withRequired Action D.1, the affected penetration must be verified tobe isolated on a periodic basis. This is necessary to ensure thatprimary containment penetrations required to be isolated followingan accident are isolated. The Completion Time of once per31 days for verifying each affected penetration is isolated isappropriate because the valves are operated under administrativecontrols and the probability of their misalignment is low.When an H202 Analyzer penetration PCIV is to be closed anddeactivated in accordance with Condition D, this must beaccomplished by pulling the fuse for the power supply, and eitherdeterrninating the power cables at the solenoid valve, or jumperingof the power side of the solenoid to ground.The OPERABILITY requirements for the closed system arediscussed in.Technical Requirements Manual (TRM) Bases 3.6.4.In the event that either one or both of the PCIVs and the closedsystem are inoperable, the Required Actions of TRO 3.6.4,Condition B apply.(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-22Revision 1 PPL Rev. 11PCIVsB 3.6.1.3BASESACTIONS D.1 and D.2 (continued)Condition D is modified by a Note indicating that this Condition isonly applicable to the H2Q2 Analyzer penetrations.E. 1With the secondary containment bypass leakage rate not withinlimit, the assumptions of the safety analysis may not be met.Therefore, the leakage must be restored to within limit within4 hours. Restoration can be accomplished by isolating thepenetration that caused the limit to be exceeded by use of oneclosed and de-activated automatic valve, closed manual valve, orblind flange. When a penetration is isolated, the leakage rate forthe isolated penetration is assumed to be the actual pathwayleakage through the isolation device. If two isolation devices areused to isolate the penetration, the leakage rate is assumed to bethe lesser actual pathway leakage of the two devices. The 4 hourCompletion Time is reasonable considering the time required torestore the leakage by isolating the penetration and the relativeimportance of secondary containment bypass leakage to theoverall containment function.F. 1In the event one or more containment purge valves are not withinthe purge valve leakage limits, purge valve leakage must berestored 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 isreasonable, considering that one containment purge valveremains closed, except as controlled by SR 3.6.1.3.1 so that agross breach of containment does not exist.G.1 and G.2If any Required Action and associated Completion Time cannot bemet in MODE 1, 2, or 3, the plant must be brought to a MODE inwhich the LCO does not apply. To achieve this status, the plantmust 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 toMODE 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 arereasonable, based on operating experience, to reach'the requiredplant conditions from full power conditions in an orderly mannerand without challenging plant systems.(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-22aRevision 0 PPL Rev. 11PCIVsB 3.6.1.3BASESACTIONS H.1 and H.2(continued)If any Required Action and associated Completion Time cannot bemet, the unit must be placed in a condition in which the LCO doesnot apply. If applicable, action must be immediately initiated tosuspend operations with a potential for draining the reactor vessel(OPDRVs) to minimize the probability of a vessel draindown andsubsequent potential for fission product release. Actions mustcontinue until OPDRVs are suspended or valve(s) are restored toOPERABLE status. If suspending an OPDRV would result inclosing the residual heat removal (RHR) shutdown coolingisolation valves, an alternative Required Action is provided toimmediately initiate action to restore the valve(s) to OPERABLEstatus. This allows RHR to remain in service while actions arebeing taken to restore the valve.SURVEILLANCE SR 3.6.1.3.1REQUIREMENTSThis SR ensures that the primary containment purge valves areclosed as required or, if open, open for an allowable reason. If apurge! valve is open in violation of this SR, the valve is consideredinoperable. If the inoperable valve is not otherwise known to haveexcessive leakage when closed, it is not considered to haveleakage outside of limits. The SR is also modified by Note 1,stating that primary containment purge valves are only required tobe closed in MODES 1, 2, and 3. If a LOCA inside primarycontainment occurs in these MODES, the purge valves may notbe capable of closing before the pressure pulse affects systemsdownstream of the purge valves, or the release of radioactivematerial will exceed limits prior to the purge valves closing. Atother times when the purge valves are required to be capable ofclosing (e.g., during handling of irradiated fuel), pressurizationconcerns are not present and the purge valves are allowed to beopen. The SR is modified by Note 2 stating that the SR is notrequired to be met when the purge valves are open for the statedreasons. The Note states that these valves may be opened forinerting, de-inerting, pressure control, ALARA or air qualityconsiderations for personnel entry, or Surveillances that requirethe valves to be open. The vent and purge valves.are capable ofclosing in the environment following a LOCA. Therefore, thesevalves are allowed to be open for(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-23Revision 1 PPL Rev. 11PCIVsB 3.6.1.3BASESSURVEILLANCE SR 3.6.1.3.1 (continued)REQUIREMENTSlimited periods of time. The 31 day Frequency is consistent withother PCIV requirements discussed in SR 3.6.1.3.2.SR 3.6.1.3.2This SR verifies that each primary containment isolation manualvalve and blind.flange that is located outside pnmary containmentand not locked, sealed, or otherwise secured and is required to beclosed during accident conditions is closed. The SR helps toensure that post accident leakage of radioactive fluids or gasesoutside 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 primarycontainment, and capable of being mispositioned, are in thecorrect position. Since verification of valve position for PCIVsoutside primary containment is relatively easy, the 31 dayFrequency was chosen to provide added assurance that thePCIVs are in the correct positions.Two Notes have been added to this SR. The first Note allowsvalves and blind flanges located in high radiation areas to beverified by use of administrative controls. Allowing verification byadministrative controls is considered acceptable since access tothese areas is typically restricted during MODES 1, 2, and 3 forALARA reasons. Therefore, the probability of misalignment ofthese PCIVs, once they have been verified to be in the properposition, is low. A second Note has been included to clarify thatPCIVs that are open under administrative controls are not requiredto meet the SR during the time that the PCIVs are open. This SRdoes not apply to valves that are locked, sealed, or otherwisesecured in the closed position, since these were verified to be inthe correct position upon locking, sealing, or securing.SR 3.6.1.3.3This SR verifies that each primary containment manual isolationvalve and blind flange that is located inside primary containmentand not locked, sealed, or otherwise(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-24Revision 0 PPL Rev. 11PCIVsB 3.6.1.3BASESSURVEILLANCE SR 3.6.1.3.3 (continued)REQUIREMENTSsecured and is required to be closed during accident conditions isclosed. The SR helps to ensure that post accident leakage ofradioactive fluids or gases outside the primary containmentboundary is within design limits. For PCIVs inside primarycontainment, the Frequency defined as "prior to entering MODE 2or 3 from MODE 4 if primary containment was de-inerted while inMODE 4, if not performed within the previous 92 days" isappropriate since these PCIVs are operated under administrativecontrols and the probability of their misalignment is low. This SRdoes not apply to valves that are locked, sealed, or otherwisesecured in the closed position, since these were verified to be inthe correct position upon locking, sealing, or securing. Two Noteshave been added to this SR. The first Note allows valves andblind flanges located in high radiation areas to be verified by useof administrative controls. Allowing verification by administrativecontrols is considered acceptable since the primary containment isinerted and access to these areas is typically restricted duringMODES 1, 2, and 3 for ALARA reasons. Therefore, theprobability of misalignment of these PCIVs, once they have beenverified to be in their proper position, is low. A second Note hasbeen included to clarify that PCIVs that are open underadministrative controls are not required to meet the SR during thetime that the PCIVs are open.SR 3.6.1.3.4The traversing incore probe (TIP) shear isolation valves areactuated by explosive charges. Surveillance of explosive chargecontinuity provides assurance that TIP valves will actuate whenrequired. Other administrative controls, such as those that limitthe shelf life of the explosive charges, must be followed. The31 day Frequency is based on operating experience that hasdemonstrated the reliability of the explosive charge continuity.SR 3.6.1.3.5Verifying the isolation time of each power operated and eachautomatic PCIV is within limits is required to demonstrateOPERABILITY. MSIVs may be excluded from this SR sinceMSIV(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-25Revision 0 PPL Rev. 11PCIVsB 3.6.1.3BASESSURVEILLANCE SR 3.6.1.3.5 (continued),REQUIREMENTSfull closure isolation time is demonstrated by SR 3.6.1.3.7. Theisolation time test ensures that the valve will isolate in a time periodless than or equal to that assumed in the Final Safety AnalysesReport. The isolation time and Frequency of this SR are inaccordance with the requirements of the Inservice TestingProgram.SR 3.6.1.3.6For primary containment purge valves with resilient seals, theAppendix J Leakage Rate Test Interval of 24 months is sufficient.The acceptance criteria for these valves is defined in the PrimaryContainment Leakage Rate Testing Program, 5.5.12.The SR is modified by a Note stating that the primary containmentpurge! valves are only required to meet leakage rate testingrequirements in MODES 1, 2, and 3. If a LOCA inside primarycontainment occurs in these MODES, purge valve leakage mustbe minimized to ensure offsite radiological release is within limits.At other times when the purge valves are required to be capableof closing (e.g., during handling of irradiated fuel), pressurizationconcerns are not present and the purge valves are not required tomeet any specific leakage criteria.SR 3.6.1.3.7Verifying that the isolation time of each MSIV is within the specifiedlimits is required to demonstrate OPERABILITY. The isolation timetest ensures that the MSIV will isolate in a time period that does notexceed the times assumed in the DBA analyses. This ensures thatthe calculated radiological consequences of these events remainwithin regulatory limits. The Frequency of this SR is in accordancewith the requirements of the Inservice Testing Program.(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-26Revision 2 PPL Rev. 11PCIVsB 3.6.1.3BASESSURVEILLANCEREQUIREMENTS(continued)SR 3.6.1.3.8Automatic PCIVs close on a primary containment isolation signalto prevent leakage of radioactive material from primarycontainment following a DBA. This SR ensures that eachautomatic PCIV will actuate to its isolation position on a primarycontainment isolation signal. The LOGIC SYSTEM FUNCTIONALTEST in SR 3.3.6.1.5 overlaps this SR to provide complete testingof the safety function. The 24 month Frequency was developedconsidering it is prudent that some of these Surveillances beperformed only during a unit outage since isolation of penetrationscould eliminate cooling water flow and disrupt the normaloperation of some critical components. Operating experience hasshown that these components usually pass this Surveillance whenperformed at the 24 month Frequency. Therefore, the Frequencywas concluded to be acceptable from a reliability standpoint.SR 3.6.1.3.9This SR requires a demonstration that a representative sample ofreactor instrumentation line excess flow check valves (EFCV) areOPERABLE by verifying that the valve actuates to check flow on asimulated instrument line break. As defined in FSAR Section6.2.4.3.5 (Reference 4), the conditions under which an EFCV willisolate, simulated instrument line break, are at flow rates, whichdevelop a differential pressure of between 3 psid and 10 psid.This SR provides assurance that the instrumentation line EFCVswill perform its design function to check flow. No specific valveleakage limits are specified because no specific leakage limits aredefined in the FSAR. The 24 month Frequency is based on theneed to perform some of these Surveillances under the conditionsthat apply during a plant outage and the potential for anunplanned transient if the Surveillance were performed with thereactor at power. The representative sample consists of anapproximate equal number of EFCVs such that each EFCV istested at least once every 10 years (nominal). The nominal10 year interval is based on other performance-based testingprograms, such as Inservice Testing (snubbers) and Option B to10 CFR 50, Appendix J. In addition, the EFCVs in the sample arerepresentative of the various plant configurations, models, sizesand operating environments. This ensures that any potentialcommon problems with a specific type or application of EFCV isdetected at the earliest possible time. EFCV failures will beevaluated to determine if additional testing in that test interval iswarranted to ensure overall reliability and that failures to isolateare very infrequent. Therefore, testing of a representative samplewas concluded to be acceptable from a reliability standpoint(Reference 7).(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-27Revision 2 PPL Rev. 11PCIVsB 3.6.1.3BASESSURVEILLANCEREQUIREMENTS(continued)SR 3.6.1.3.10The TIP shear isolation valves are actuated by explosive charges. An inplace functional test is not possible with this design. The explosive squibis removed and tested to provide assurance that the valves will actuatewhen required. The replacement charge for the explosive squib shall befrom the same manufactured batch as the one fired or from another batchthat has been certified by having one of the batch successfully fired. TheFrequency of 24 months on a STAGGERED TEST BASIS is consideredadequate given the administrative controls on replacement charges andthe frequent checks of circuit continuity (SR 3.6.1.3.4).SR 3.6.1.3.11This SR ensures that the leakage rate of secondary containment bypassleakage paths is less than the specified leakage rate. This providesassurance that the assumptions in the radiological evaluations ofReference 4 are met. The secondary containment leakage pathways andFrequency are defined by the Primary Containment Leakage RateTesting Program. This SR simply imposes additional acceptance criteria.A note is added to this SR, which states that these valves are onlyrequired to meet this leakage limit in MODES 1, 2, and 3. In the otherMODES, the Reactor Coolant System is not pressurized and specificprimary containment leakage limits are not required.SR 3.6.1.3.12The analyses in References 1 and 4 are based on the specified leakagerate. Leakage through each MSIV must be < 100 scfh for any one MSIVand < 300 scfh for total leakage through the MSIVs combined With theMain Steam Line Drain Isolation Valve, HPCI Steam Supply IsolationValve and the RCIC Steam Supply Isolation Valve. The MSIVs can betested at either > Pt (24.3 psig) or P, (48.6 psig). Main Steam Line DrainIsolation, HPCI and RCIC Steam Supply Line Isolation Valves, are testedat P, (48.6 psig). A note is added to this SR, which states that thesevalves are only required to meet this leakage limit in MODES 1, 2, and 3.In the other conditions, the Reactor Coolant System is not pressurizedand specific primary containment leakage limits are not required. TheFrequency is required by the Primary Containment Leakage Rate TestingProgram.(continued)SUSQUEHANNA -UNIT 1TS / B 3.6-28Revision 7 PPL Rev. 11PCIVsB 3.6.1.3BASESSURVEILLANCEREQUIREMENTS(continued)SR 3.6.1.3.13Surveillance of hydrostatically tested lines provides assurance thatthe calculation assumptions of Reference 2 are met. Theacceptance criteria for the combined leakage of all hydrostaticallytested lines is 3.3 gpm when tested at 1.1 Pa, (53.46 psig). Thecombined leakage rates must be demonstrated in accordance withthe leakage rate test Frequency required by the PrimaryContainment Leakage Testing Program.As noted in Table B 3.6.1.3-1, PCIVs associated with this SR arenot Type C tested. Containment bypass leakage is preventedsince the line terminates below the minimum water level in theSuppression Chamber. These valves are tested in accordancewith the IST Program. Therefore, these valves leakage is notincluded as containment leakage.This SR has been modified by a Note that states that these valvesare only required to meet the combined leakage rate in MODES 1,2, and 3, since this is when the Reactor Coolant System ispressurized and primary containment is required. In someinstances, the valves are required to be capable of automaticallyclosing during MODES other than MODES 1, 2, and 3. However,specific leakage limits are not applicable in these other MODES orconditions.REFERENCES1. FSAR, Chapter 15.2. Final Policy Statement on Technical SpecificationsImprovements, 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 ImprovementAnalyses for BWR Reactor Protection System,"March 1988.6. Standard Review Plan 6.2.4, Rev. 1, September 19757. NEDO-32977-A, "Excess Flow Check Valve TestingRelaxation," June 2000.SUSQUEHANNA -UNIT 1TS / B 3.6-29Revision 2 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1Primary Containment Isolation Valve(Page 1 of 11)Isolation SignalPlant System Valve Number Valve Description Type of Valve LC MaximUm Isolation(M3.im.6 FsuctiondNo._______________________________________________________ ______________ Time_(Seconds))ContainmentktmosphericControl1-57-193 (d)ILRTManualN/A1-57-194 (d) ILRT Manual N/AHV-15703 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15704 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15705 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15711 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15713 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15714 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15721 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15722 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15723 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15724 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15725 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)HV-15766 (a) Suppression Pool Cleanup Automatic Valve 2.b, 2.d (30)HV-15768 (a) Suppression Pool Cleanup Automatic Valve 2.b, 2.d (30)SV-157100 A Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157100 B Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-1 57101 A Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157101 B Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157102 A Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157102 B Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-1 57103 A Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157103 B Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157104 Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157105 Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157106 Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157107 Containment Radiation Detection Automatic Valve 2.b, 2.dSystSV-157,34 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15734 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15736 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15736 B (e)Containment Atmosphere SampleAutomatic Valve2.b, 2.dISV-15737 Nitrogen Makeup I Automatic Valve I 2.b, 2.d, 2.eSUSQUEHANNA -UNIT 1TS / B 3.6-30Revision 1 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1Primary Containment Isolation Valve(Page 2 of 11)Isolation SignalLCO 3.3.6.1 Function No.Plant System Valve Number Valve Description Type of Valve (Maximum IsolationTime (Seconds))Containment SV-1 5738 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.eAtmospheric SV-1 5740 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dControl SV-15740 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d(continued) SV-15742 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-1 5742 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15750 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15750 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15752 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15752 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-1 5767 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.eSV-1 5774 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15774 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15776 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-1 5776 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15780 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-15780 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-1 5782 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-1 5782 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.dSV-1 5789 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.eContainment 1-26-072 (d) Containment Instrument Gas Manual Check N/AInstrument Gas 1-26-074 (d) Containment Instrument Gas Manual Check N/A1-26-152 (d) Containment Instrument Gas Manual Check N/A1-26-154 (d) Containment Instrument Gas Manual Check N/A1-26-164 (d) Containment Instrument Gas Manual Check N/AHV-12603 Containment Instrument Gas Automatic Valve 2.c, 2.d (20)SV-1 2605 Containment Instrument Gas Automatic Valve 2.c, 2.dSV-12651 Containment Instrument Gas Automatic Valve 2.c, 2.dSV-1 2654 A Containment Instrument Gas Power Operated N/ASV-1 2654 B Containment Instrument Gas Power Operated N/ASV-12661 Containment Instrument Gas Automatic Valve 2.b, 2.dSV-1 2671 Containment Instrument Gas Automatic Valve 2.b, 2.dCore Spray HV-1 52F001 A (b)(c) CS Suction Valve Power Operated N/AHV-152F001 B (b)(c) CS Suction Valve Power Operated N/AHV-152F005 A CS Injection Power Operated N/AHV-152F005 B CS Injection Valve Power Operated N/AHV-152F006 A CS Injection Valve Air Operated Check N/AValveHV-152F006 B CS Injection Valve Air Operated Check N/AValveHV-152F01 5 A (b)(c) CS Test Valve Automatic Valve 2.c, 2.d (80)HV-1 52F01 5 B (b)(c) CS Test Valve Automatic Valve 2.c, 2.d (80)SUSQUEHANNA -UNIT 1TS / B 3.6-31Revision 3 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1 (continued)Primary Containment Isolation Valve(Page 3 of 11)Isolation SignalPlant System Valve Number Valve Description Type of Valve LCO 3.3.6.1 Function No.(Maximum IsolationTime (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/AHV-152F037 A CS Injection Power Operated N/A(Air)HV-152F037 B CS Injection Power Operated N/A(Air)XV-152F01 BA Core Spray Excess Flow Check N/AValveXV-152F018 B Core Spray Excess Flow Check N/AValveHPCI 1-55-038 (d) HPCI Injection Valve Manual N/A155F046 (b)(c)(d) HPCI Minimum Flow Check Valve Manual Check N/A155F049 (a)(d) HPCI Turbine Exhaust Valve Manual Check N/AHV-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 N/AHV-155F012 (b)(c) HPCI Minimum Flow Valve Power Operated N/AHV-155F042 (b)(c) HPCI Suction Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f,3.g (115)HV-155F066 (a) HPCI Turbine Exhaust Valve Power Operated N/AHV-155F075 HPCI Vacuum Breaker Isolation Automatic Valve 3.b, 3.d (15)ValveHV-155F079 HPCI Vacuum Breaker Isolation Automatic Valve 3.b, 3.d (15)ValveHV-155F100 HPCI Steam Supply Valve Automatic Valve 3.a, 3.b, 3.c,. 3.e, 3.f,3.g (6)XV-155F024 A HPCI Valve Excess Flow Check N/AValveXV-155F024 B HPCI Valve Excess Flow Check N/AValveXV-155F024 C HPCI Valve Excess Flow Check N/AValveXV-155F024 D HPCI Valve Excess Flow Check N/AValveLiquid Radwaste HV-16108 Al Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)Collection HV-16108 A2 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)HV-16116 Al Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)HV-16116 A2 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)Demin Water 1-41-017 (d) Dernineralized Water Manual N/A1-41-018 (d) Dernineralized Water Manual N/ANuclear Boiler 141 F010 A (d) Feedwater Isolation Valve Manual Check N/A141 F010 B (d) Feedwater Isolation Valve Manual Check N/ASUSQUEHANNA -UNIT 1TS / B 3.6-32Revision 1 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1 (continued)Primary Containment Isolation Valve(Page 4 of 11)Isolation SignalLCO 3.3.6.1 Function No.Plant System Valve Number Valve Description Type of Valve (Maximum IsolationTime (Seconds))Nuclear Boiler 141 F039 A (d) Feedwater Isolation Valve Manual Check N/A(continued) 141 F039 B (d) Feedwater Isolation Valve Manual Check N/A141818 A (d) Feedwater Isolation Valve Manual Check N/A141818 B (d) Feedwater Isolation Valve Manual Check N/AHV-141 F016 MSL Drain Isolation Valve Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e(10)HV-141 FO19MSL Drain Isolation ValveAutomatic Valve1.a, 1ib, 1.c, 1.d, i.e(15)HV-141F022 A MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, i.e(5)HV-141F022 B MSIV Automatic Valve l.a, 1b, 1.c, i.d, i.e(5)HV-141 F022 C MSIV Automatic Valve 1.a, 1.b, 1.c, i.d, 1.e.(5)HV-141 F022 D MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, i.e(5)HV-141F028 A MSIV Automatic Valve l.a, 1.b, 1.c, 1.d, i.e(5)HV-141 F028 B MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e(5)HV-141 F028 C MSIV Automatic Valve 1.a, 1.b, i.c, 1.d, i.e(5)HV-141 F028 D MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e(5)HV-141 F032 A Feedwater Isolation Valve Power Operated N/ACheckHV-141 F032 B Feedwater Isolation Valve Power Operated N/ACheckKV-141F009 Nuclear Boiler EFCV Excess Flow Check N/AValveKV-141F070 A Nuclear Boiler EFCV Excess Flow Check N/AValveKV-141 F070 B Nuclear Boiler EFCV Excess Flow Check N/AValve)'V-141 F070 C Nuclear Boiler EFCV Excess Flow Check N/AValveKV-141 F070 D Nuclear Boiler EFCV Excess Flow Check N/AValveX'V-141 F071 A Nuclear Boiler EFCV Excess Flow Check N/AValveKV-141 F071 B Nuclear Boiler EFCV Excess Flow Check N/AValveK'V-141 F071 C Nuclear Boiler EFCV Excess Flow Check N/AValveKV-141 F071 DNuclear Boiler EFCVExcess Flow CheckValveN/ASUSQUEHANNA -UNIT 1TS / B 3.6-33Revision 1 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1 (continued)Primary Containment Isolation Valve(Page 5 of 11)Isolation SignalLCO 3.3.6.1 Function No.Plant System Valve Number Valve Description Type of Valve (Maximum IsolationTime (Seconds))Nuclear Boiler XV-1 41 F072 A Nuclear Boiler EFCV Excess Flow Check N/A(continued) ValveXV-1 41 F072 B Nuclear Boiler EFCV Excess Flow Check N/AValveXV-141 F072 C Nuclear Boiler EFCV Excess Flow Check N/AValveXV-141 F072 D Nuclear Boiler EFCV Excess Flow Check N/AValveXV-1 41 F073 A Nuclear Boiler EFCV Excess Flow Check N/AValveXV-141 F073 B Nuclear Boiler EFCV Excess Flow Check N/AValveXV-141 F073 C Nuclear Boiler EFCV Excess Flow Check N/AValveXV-141 F073 D Nuclear Boiler EFCV Excess Flow Check N/AValveNuclear Boiler XV-14201 Nuclear Boiler Vessel Instrument Excess Flow Check N/AVessel ValveInstrumentation XV-1 4202 Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F041 Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F043 A Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-1 42F043 B Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F045 A Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F045 B Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-1 42F047 A Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F047 B Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F051 A Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F051 B Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F051 C Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142FO51 D Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F053 A Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F053 B Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveSUSQUEHANNA -UNIT 1TS / B 3.6-34Revision 0 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1 (continued)Primary Containment Isolation Valve(Page 6 of 11)Isolation SignalPlant System Valve Number Valve Description Type of Valve LCO 3.3.6.1 Function No.(Maximum IsolationTime (Seconds))Nuclear BoilerVesselInstrumentation(continued)XV-142F053 CNuclear Boiler Vessel InstrumentExcess Flow CheckValveN/AXV-142F053 D Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F055 Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F057 Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 A Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 B Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 C Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-1 42F059 D Nuclear Boiler Vessel Instrument Eicess Flow Check N/A.ValveXV-142F059 E Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 F Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 G Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 H Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 L Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 M Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 N Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 P Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 R Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 S Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 T Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveXV-142F059 U Nuclear Boiler Vessel Instrument Excess Flow Check N/AValveK(V-1 42F061Nuclear Boiler Vessel InstrumentExcess Flow CheckValveN/ARBCCW HV-11313 RBCCW Automatic Valve 2.c, 2.d (30)HV-11314 RBCCW Automatic Valve 2.c, 2.d (30)HV-1 1345 RBCCW Automatic Valve 2.c, 2.d (30)HV-1 1346 RBCCW J Automatic Valve 2.c, 2.d (30)SUSQUEHANNA -UNIT 1TS / B 3.6-35Revision 0 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1 (continued)Primary Containment Isolation Valve(Page 7 of 11)Isolation SignalLCO 3.3.6.1 Function No.Plant System Valve Number Valve Description Type of Valve (Maximum IsolationTime (Seconds))RCIC 1-49-020 (d) RCIC INJECTION Manual N/A149F021 (b)(c)(d) RCIC Minimum Recirculation Flow Manual Check N/A149F028 (a)(d) RCIC Vacuum Pump Discharge Manual Check N/A149F040 (a)(d) RCIC Turbine Exhaust Manual Check N/AFV-149F019 (b)(c) RCIC Minimum Recirculation Flow Power Operated N/AHV-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 RC:IC Injection Power Operated N/AHV-149F031 .(b)(c) RCIC Suction Power Operated N/AHV-149FO59 (a) RCIC Turbine Exhaust Power Operated N/AHV-149F060 (a) RCIC Vacuum Pump Discharge Power Operated NIAHV-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/AValveXV-149F044 B RCIC Excess Flow Check N/AValveXV-149F044 C RCIC Excess Flow Check N/AValveXV-149FO44 D RCIC Excess Flow Check NIAValveRB Chilled HV-18781 Al RB Chilled Water Automatic Valve 2.c, 2.d (40)Water System HV-18781 A2 RB Chilled Water Automatic Valve 2.c, 2.d (40)HV-18781 B1 RB Chilled Water Automatic Valve 2.c, 2.d (40)HV-18781 82 RB Chilled Water Automatic Valve 2.c, 2.d (40)HV-18782 Al RB Chilled Water Automatic Valve 2.c, 2.d (12)HV-18782 A2 RB Chilled Water Automatic Valve 2.c, 2.d (12)HV-18782 B1 RB Chilled Water Automatic Valve 2.c, 2.d (12)HV-18782 B2 RB Chilled Water Automatic Valve 2.c, 2.d (12)HV-18791 Al RB Chilled Water Automatic Valve 2.b, 2.d (15)HV-18791 A2 RB Chilled Water Automatic Valve 2.b, 2.d (15)HV-18791 B1 RB Chilled Water Automatic Valve 2.b, 2.d (15)HV-18791 B2 RB Chilled Water Automatic Valve 2.b, 2.d (15)HV-18792 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-18792 B1 RB Chilled Water Automatic Valve 2.b, 2.d (8)HV-18792 B2 RB Chilled Water Automatic Valve 2.b, 2.d (8)Reactor 143F013 A (d) Recirculation Pump Seal Water Manual Check N/ARecirculation 143F013 B (d) Recirculation Pump Seal Water Manual Check N/ASUSQUEHANNA -UNIT 1TS / B 3.6-36Revision 1 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1 (continued)Primary Containment Isolation Valve(Page 8 of 11)Isolation SignalLCO 3.3.6.1 Function No.Plant System Valve NValve Description Type of Valve (Maximum IsolationTime (Seconds))ReactorRecirculation(continued)IXV-143F003 AReactor RecirculationExcess Flow CheckValveN/AKV-143FOO3 B Reactor Recirculation Excess Flow Check N/AValveKV-143FOO4 A Reactor Recirculation Excess Flow Check N/AValveKV-143FOO4 B Reactor Recirculation Excess Flow Check N/AValveX'V-143FOO9 A Reactor Recirculation Excess Flow Check N/AValveXV-143F009 B Reactor Recirculation Excess Flow Check N/AValveKV-143FOO9 C Reactor Recirculation Excess Flow Check N/AValve'V-143FO09 D Reactor Recirculation Excess Flow Check N/AValveXV-143F010 A Reactor Recirculation Excess Flow Check N/AValveXV-143F010 B Reactor Recirculation Excess Flow Check N/AValveXV-143F010 C Reactor Recirculation Excess Flow Check N/AValveXV-143F010 D Reactor Recirculation Excess Flow Check N/AValveXV-1 43F01 1 A Reactor Recirculation Excess Flow Check N/AValveXV-143F01 1 B Reactor Recirculation Excess Flow Check N/AValveXV-143F01 1 C Reactor Recirculation Excess Flow Check N/AValveXV-143F011 D Reactor Recirculation Excess Flow Check N/AValveXV-1 43F01 2 A Reactor Recirculation Excess Flow Check N/AValveXV-143F012 B Reactor Recirculation Excess Flow Check N/A_ValveXV-143F012 C Reactor Recirculation Excess Flow Check N/AValveXV-143F012 D Reactor Recirculation Excess Flow Check N/AValveKV-143F017 A Recirculation Pump Seal Water Excess Flow Check N/AValveXV-143F017 B Recirculation Pump Seal Water Excess Flow Check N/AI ValveKV-143F040 AReactor RecirculationExcess Flow CheckValve.N/ASUSQUEHANNA -UNIT 1TS / B 3.6-37Revision 0 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1 (continued)Primary Containment Isolation Valve(Page 9 of 11)Isolation SignalLCO.3.3.6.1 Function No.Plant System Valve Number Valve Description Type of Valve (Ma3imum stion(Maximum IsolationTime (Seconds))Reactor XV-143F040 B Reactor Recirculation Excess Flow Check N/ARecirculation Valve(continued) XV-143F040 C Reactor Recirculation Excess Flow Check N/AValveXV-143F040 D Reactor Recirculation Excess Flow Check N/AValveXV-143F057 A Reactor Recirculation Excess Flow Check N/AValveXV-143F057 B Reactor Recirculation Excess Flow Check N/AValveHV-143F019 Reactor Coolant Sample Automatic Valve 2.b (9)HV-143F020 Reactor Coolant Sample Automatic Valve 2.b (2)Residual Heat HV-151 F004 A (b)(c) RHR -Suppression Pool Suction Power Operated N/ARemovalHV-151 F004 B (b)(c) RHR -Suppression Pool Suction Power Operated N/AHV-151 F004 C (b)(c) RHR -Suppression Pool Suction Power Operated N/AHV-1 51 F004 D (b)(c) RH R -Suppression Pool Suction Power Operated N/AHV-151 F007 A (b)(c) RHR-Minimum Recirculation Flow Power Operated N/AHV-151 F007 B (b)(c) RHR-Minimum Recirculation Flow Power Operated N/AHV-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/ACooling/SprayHV-151 F01I B (b)(d) RHR-Suppression Pool Manual N/ACooling/SprayHV-151 F015 A (f) RHR -Shutdown Cooling Power Operated N/AReturn/LPCI InjectionHV-151 F015 B (f) RHR -Shutdown Cooling Power Operated N/AReturn/LPCI InjectionHV-151F016 A (b) RHR -Drywell Spray Automatic Valve 2.c, 2.d (90)HV-151 F016 B (b) RHR -Drywell Spray Automatic Valve 2.c, 2.d (90)HV-151 F022 RHR -Reactor Vessel Head Spray Automatic Valve 2.d, 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/SprayHV-151 F028 B (b) RHR -Suppression Pool Automatic Valve 2.c, 2.d (90)Cooling/SprayHV-151 F050 A (g) RHR -Shutdown Cooling Air Operated Check N/ARetum/LPCI Injection Valve ValveHV-151 F050 B (g) RHR -Shutdown Cooling Air Operated Check N/ARetum/LPCI Injection Valve ValveHV-151 F103 A (b) RHR Heat Exchanger Vent Power Operated N/AHV-1 51 F1 03 B (b) RH R Heat Exchanger Vent Power Operated N/ASUSQUEHANNA -UNIT 1TS / B 3.6-38Revision 3 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1 (continued)Primary Containment Isolation Valve(Page 10 of 11)Isolation SignalLCO 3.3.6.1 Function No.Plant System Valve Number Valve Description Type of Valve (Maximum IsolationTime (Seconds))Residual Heat HV-151 F122 A (g) RHR -Shutdown Cooling Power Operated N/ARemoval Return/LPCI Injection Valve (Air)(continued) HV-151 F122 B (g) RHR -Shutdown Cooling Power Operated N/AReturn/LPCI Injection Valve (Air)PSV-1 5106 A (b)(d) RH R -Relief Valve Discharge Relief Valve N/APSV-1 5106 B (b)(d) RHR -Relief Valve Discharge Relief Valve N/APSV-151F126 (d) RHR -Shutdown Cooling Suction Relief Valve N/AXV-15109 A RHR Excess Flow Check N/AValveXV-15109 B RHR Excess Flow Check N/AValveXV-1 5109 C RHIR Excess Flow Check N/AValveXV-1 5109 D RI-R Excess Flow Check N/AValveRWCU HV-144FO01 (a) RVWCU Suction Automatic Valve 5.a, 5.b, 5.c, 5.d, 5.f,5.g (30)HV-144FO04 (a) RWCU Suction Automatic Valve 5.a, 5.b, 5.c, 5.d, 5. e,5.f, 5.g (30)XV-14411 A RWCU Excess Flow Check N/AValveXV-14411 B RVVCU Excess Flow Check N/AValveXV-14411 C RWCU Excess Flow Check N/AValveXV-14411 D RWCU Excess Flow Check N/AValveXV-144F046 RWCU Excess Flow Check N/AValveHV-14182 A RWCU Return Isolation Valve Power Operated N/AHV-14182 B RWCU Return Isolation Valve Power Operated N/ASLCS 148F007 (a)(d) SLCS Manual Check N/AHV-148F006 (a) SLCS Power Operated N/ACheck ValveTIP System C51-J004 A (Shear TIP Shear Valves Squib Valves N/AValve)C51-J004 B (Shear TIP Shear Valves Squib Valves N/AValve)C51-J004 C (Shear TIP Shear Valves Squib Valves N/AValve)C51-J004 D (Shear TIP Shear Valves Squib Valves N/AValve)C51-J004 E (Shear TIP Shear Valves Squib Valves N/AValve)SUSQUEHANNA -UNIT 1TS / B 3.6-39Revision 2 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-1Primary Containment Isolation Valve(Page 11 of 11)Isolation SignalPlant System Valve Number Valve Description Type of Valve LCO 3.3.6.1 Function No.(Maximum IsolationTime (Seconds))TIP System C51-J004 A (Ball TIP 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)C51-JO04 D (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)Valve)C51-J004 E (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)Valve)(a) Isolation barrier remains water filled or a water seal remains in the line post-LOCA, isolation valve is tested withwater. Isolation valve leakage is not included in 0.60 La total Type B and C tests.(b) Redundant isolation boundary for this valve is provided by the closed system whose integrity is verified by theLeakage Rate Test Program. This footnote does not apply to valve 155F046 (HPCI) when the associated PCIV,HV155F012 is closed and deactivated. Similarly, this footnote does not apply to valve 149F021 (RCIC) when it'sassociated PCIV, FV149F019 is closed and deactivated.(c) Containment Isolation Valves are not Type C tested. Containment bypass leakage is prevented since the lineterminates below the minimum water level in the 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 aclosed system. The closed system provides a redundant isolation boundary for both PCIVs, and its integrity isrequired to be verified by the Leakage Rate Test Program.(f) Redundant isolation boundary for this valve is provided by the closed system whose integrity is verified by theLeakage Rate Test Program.(g) These valves are not required to be 10 CFR 50, Appendix J tested since the HV-151 F015A(B) valves and a closedsystem form the 10 CFR 50, Appendix J boundary. These valves form a high/low pressure interface and arepressure tested in accordance with the pressure test program.SUSQUEHANNA -UNIT 1TS / B 3.6-40Revision 6 PPL Rev. 11PCIVsB 3.6.1.3Table B 3.6.1.3-2Secondary Containment Bypass Leakage Isolation Valves(Not PCIVs)(Page 1 of 1)Isolation SignalLCO 3.3.6.1 Function No.Plant System Valve Number Valve Description Type of Valve (Maximum IsolationTime (Seconds))Residual Heat HV-151F040 RHR -RADWASTE LINE lB ISO Automatic Valve 2.a, 2.d (45)Removal VLVHV-151 F049 RHR -RADWASTE LINE OB ISO Automatic Valve 2.a, 2.d (20)VLV1-51-136 RHR -COND TRANSFER OB SCBL Check Valve N/ACHECK VALVE1-51-137 RHR -COND TRANSFER lB SCBL Check Valve N/ACHECK VALVESUSQUEHANNA -UNIT 1TS / B 3.6-40aRevision 1