ML101040728
| ML101040728 | |
| Person / Time | |
|---|---|
| Site: | Susquehanna  |
| Issue date: | 04/01/2010 |
| From: | Susquehanna |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| Download: ML101040728 (70) | |
Text
IC Apr. 01, 2010 HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2010-9923 USER INFORMATION?
Name :-GERLACHROSE M EMPL#:028401 CA#:0363 Address: NUGSA2 Phone#: 254-3194 TRANSMITTAL INFORMATION:
TO: 9E-R-LAGCH*-RQSEýMn =03-/ -11/2 0i 0-10 LOCATION: UNR-C FROM: NUCLEAR RECORDS DOCUMENT CONTROL CENTER (NUCSA-2)
THE FOLLOWING CHANGES HAVE OCCURRED TO THE HARDCOPY OR ELECTRONIC MANUAL ASSIGNED TO YOU.
HARDCOPY USERS MUST ENSURE THE DOCUMENTS PROVIDED MATCH THE INFORMATION ON THIS TRANSMITTAL. WHEN REPLACING THIS MATERIAL IN YOUR HARDCOPY MANUAL, ENSURE THE UPDATE DOCUMENT ID IS THE SAME DOCUMENT ID YOU'RE REMOVING FROM YOUR MANUAL. TOOLS FROM THE HUMAN PERFORMANCE TOOL BAG SHOULD BE UTILIZED TO ELIMINATE THE CHANCE OF ERRORS.
ATTENTION: "REPLACE" directions do not affect the Table of Contents, Therefore no TOC will be issued with the updated material.
TSB2 - TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL REMOVE. MANUAL TABLE OF CONTENTS DATE: 03/09/2010 ADD MANUAL TABLE OF CONTENTS DATE:
CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.4.5 ADD: REV: 3 REMOVE: REV:2 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.6.1.3 ADD: REV: 10 REMOVE: REV:9 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.6.4.2 ADD: REV: 3 REMOVE: REV:2 Ac-,D I W4Aý-
a CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT LOES ADD: REV: 97 REMOVE: REV:96 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT TOC REMOVE: REV:15 ADD: REV: 16 ANY DISCREPANCIES WITH THE MATERIAL PROVIDED, CONTACT DCS @ X3107 OR X3136 FOR ASSISTANCE. UPDATES FOR HARDCOPY MANUALS WILL BE DISTRIBUTED WITHIN 3 DAYS IN ACCORDANCE WITH DEPARTMENT PROCEDURES. PLEASE MAKE ALL CHANGES AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX UPON COMPLETION OF UPDATES. FOR ELECTRONIC MANUAL USERS, ELECTRONICALLY REVIEW THE APPROPRIATE DOCUMENTS AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX.
SSES MANUAL Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL Table Of Contents Issue Date: 03/21/2010 Procedure Name Rev Issue Date Change ID Change Number TEXT LOES 97 03/10/2010
Title:
LIST OF EFFECTIVE SECTIONS TEXT TOC 16 03/10/2010
Title:
TABLE OF CONTENTS TEXT 2.1.1 4 05/06/2009
Title:
SAFETY LIMITS (SLS) REACTOR CORE SLS TEXT 2.1.2 1 10/04/2007
Title:
SAFETY LIMITS (SLS) REACTOR COOLANT SYSTEM (RCS) PRESSURE SL TEXT 3.0 3 08/20/2009
Title:
LIMITING CO NDITION FOR OPERATION (LCO) APPLICABILITY TEXT 3.1.1 1 03/24/2005
Title:
REACTIVITY CONTROL SYSTEMS SHUTDOWN MARGIN (SDM)
TEXT 3.1.2 0 11/18/2002
Title:
REACTIVITY CONTROL SYSTEMS REACTIVITY ANOMALIES TEXT 3.1.3 2 01/19/2009
Title:
REACTIVITY CONTROL SYSTEMS CONTROL ROD OPERABILITY TEXT 3.1.4 4 01/30/2009
Title:
REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM TIMES TEXT 3.1.5 1 07/06/2005
Title:
REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS TEXT 3.1.6 2 03/24/2005
Title:
REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Report Date: 04/01/10 Pagel Page 1 of
. of 8
.8 Report Date: 04/01/10
SSES MANUAL
. Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.1.7 3 10/04/2007
Title:
REACTIVITY CONTROL SYSTEMS STANDBY LIQUID CONTROL (SLC) SYSTEM TEXT 3.1.8 3 05/06/2009 Title. REACTIVITY CONTROL SYSTEMS SCRAM DISCHARGE VOLUME (SDV) VENT AND DRAIN VALVES TEXT 3.2.1 4 05/06/2009
Title:
POWER DISTRIBUTION LIMITS AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)
TEXT 3.2.2 3 05/06/2009
Title:
POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)
TEXT 3.2.3 2 05/06/2009
Title:
POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE LHGR
. TEXT 3.3.1.1
Title:
INSTRUMENTATION 4 05/06/2009 REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATION TEXT 3.3.1.2 2 01/19/2009
Title:
INSTRUMENTATION SOURCE RANGE MONITOR (SRM) INSTRUMENTATION TEXT 3.3.2.1 2 04/09/2007
Title:
INSTRUMENTATION CONTROL ROD BLOCK INSTRUMENTATION TEXT 3.3.2.2 1 05/06/2009
Title:
INSTRUMENTATION FEEDWATER - MAIN TURBINE HIGH WATER LEVEL TRIP INSTRUMENTATION TEXT 3.3.3.1 7 10/27/2008
Title:
INSTRUMENTATION POST ACCIDENT MONITORING (PAM) INSTRUMENTATION TEXT 3.3.3.2 1 04/18/2005
Title:
INSTRUMENTATION REMOTE SHUTDOWN SYSTEM TEXT 3.3.4.1 1 05/06/2009
Title:
INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATION Page 2 of .8 Report Date: 04/01/10
SSES MANUAL Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.3.4.2 0 11/18/2002
Title:
INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP (ATWS-RPT) INSTRUMENTATION TEXT 3.3.5.1 4 08/20/2009
Title:
INSTRUMENTATION EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION TEXT 3.3.5.2 0 11/18/2002
Title:
INSTRUMENTATION REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM INSTRUMENTATION TEXT 3.3.6.1 4 05/06/2009
Title:
INSTRUMENTATION PRIMARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.6.2 3 10/27/2008
Title:
INSTRUMENTATION SECONDARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.7.1 2 10/27/2008
Title:
INSTRUMENTATION CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM INSTRUMENTATION TEXT 3.3.8.1 3 12/17/2007
Title:
INSTRUMENTATION LOSS OF POWER (LOP) INSTRUMENTATION TEXT 3.3.8.2 0 11/18/2002
Title:
INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORING TEXT 3.4.1 3 04/09/2007
Title:
REACTOR COOLANT SYSTEM (RCS) RECIRCULATION LOOPS OPERATING TEXT 3.4.2 1 05/06/2009
Title:
REACTOR COOLANT SYSTEM (RCS) JET PUMPS TEXT 3.4.3 2 05/06/2009
Title:
REACTOR COOLANT SYSTEM (RCS) SAFETY/RELIEF VALVES (S/RVS)
TEXT 3.4.4 0 11/18/2002
Title:
REACTOR COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE Report Date: 04/01/10 Page 3 Page3 of of 8
-8 Report Date: 04/01/10
SSES MANUAL Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.4.5 3 03/10/2010
Title:
REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE TEXT 3.4.6 2 08/20/2009
Title:
REACTOR COOLANT SYSTEM (RCS), RCS LEAKAGE DETECTION INSTRUMENTATION TEXT 3.4.7 2 10/04/2007
Title:
REACTOR COOLANT SYSTEM (RCS) RCS SPECIFIC ACTIVITY TEXT 3.4.8 1 04/18/2005
Title:
REACTOR COOLANT SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM
- HOT SHUTDOWN TEXT 3.4.9 0 11/18/2002
Title:
REACTOR COOLANT SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM
- COLD SHUTDOWN TEXT 3.4.10 3 05/06/2009
Title:
REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE (P/T) LIMITS TEXT 3.4.11 0 11/18/2002
Title:
REACTOR COOLANT SYSTEM (RCS) REACTOR STEAM DOME PRESSURE TEXT 3.5.1 3 01/16/2006
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM ECCS - OPERATING TEXT 3.5.2 0 11/18/2002
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM ECCS - SHUTDOWN TEXT 3.5.3 1 04/18/2005
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM RCIC SYSTEM TEXT 3.6.1.1 3 05/06/2009
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT TEXT 3.6.1.2 1 05/06/2009
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK Report Date: 04/01/10 Page4 Page 4 of of 8
.8 Report Date: 04/01/10
SSES MANTJAI Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.6.1.3 10 03/10/2010
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)
LDCN 4684 TEXT 3.6.1.4 1 05/06/2009
Title:
CONTAINMENT SYSTEMS CONTAINMENT PRESSURE TEXT 3.6.1.5 1 10/05/2005
Title:
CONTAINMENT SYSTEMS DRYWELL AIR TEMPERATURE TEXT 3.6.1.6 0 11/18/2002
Title:
CONTAINMENT SYSTEMS SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKERS TEXT 3.6.2.1 2 12/17/2007
Title:
CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE TEXT 3.6.2.2 0 11/18/2002
Title:
CONTAINMENT SYSTEMS SUPPRESSION POOL WATER LEVEL TEXT 3.6.2.3 1 01/16/2006
Title:
CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL COOLING TEXT 3.6.2.4 0 11/18/2002
Title:
CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR} SUPPRESSION POOL SPRAY TEXT 3.6.3.1 2 06/13/2006
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS TEXT 3.6.3.2 1 04/18/2005
Title:
CONTAINMENT SYSTEMS DRYWELL AIR FLOW SYSTEM TEXT 3.6.3.3 0 11/18/2002
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION TEXT 3.6.4.1 7 10/04/2007
Title:
CONTAINMENT SYSTEMS SECONDARY CONTAINMENT Page 5 of -8 Report Date: 04/01/10
SSES MANUAL Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.6.4.2 3 03/10/2010
Title:
CONTAINMENT SYSTEMS SECONDARY CONTAINMENT ISOLATION VALVES (SCIVS)
TEXT 3.6.4.3 4 09/21/2006
Title:
CONTAINMENT SYSTEMS STANDBY GAS TREATMENT (SGT) SYSTEM TEXT 3.7.1 3 05/06/2009
Title:
PLANT SYSTEMS RESIDUAL HEAT REMOVAL SERVICE WATER (RHRSW) SYSTEM AND THE ULTIMATE HEAT SINK (UHS)
TEXT 3.7.2 2 05/02/2008
Title:
PLANT SYSTEMS EMERGENCY SERVICE WATER (ESW) SYSTEM TEXT 3.7.3 1 01/08/2010
Title:
PLANT SYSTEMS CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM TEXT 3. 7.4 0 11/18/2002
Title:
PLANT SYSTEMS CONTROL ROOM FLOOR COOLING SYSTEM TEXT 3. 7.5 1 10/04/2007
Title:
PLANT SYSTEMS MAIN CONDENSER OFFGAS TEXT 3. 7.6 2 05/06/2009
Title:
PLANT SYSTEMS MAIN TURBINE BYPASS SYSTEM TEXT 3. 7.7 1 10/04/2007
Title:
PLANT SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL TEXT 3. 8.1 8 05/06/2009
Title:
ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING TEXT 3.7.8 0 05/06/2009
Title:
MAINE TURBINE PRESSURE REGULATION SYSTEM TEXT 3.8.2 0 11/18/2002
Title:
ELECTRICAL POWER SYSTEMS AC SOURCES - SHUTDOWN Report Date: 04/01/10 Page~
Page 6 of of 8
.8 Report Date: 04/01/10
SSES MANJA-L Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.8.3 1 04/23/2008
Title:
ELECTRICAL POWER SYSTEMS DIESEL FUEL OIL LUBE OIL AND STARTING AIR LDCN 4756 TEXT 3.8.4 3 01/19/2009
Title:
ELECTRICAL POWER SYSTEMS DC SOURCES - OPERATING TEXT 3.8.5 1 12/14/2006
Title:
ELECTRICAL POWER SYSTEMS DC SOURCES - SHUTDOWN TEXT 3.8.6 1 12/14/2006
Title:
ELECTRICAL POWER SYSTEMS BATTERY CELL PARAMETERS TEXT 3.8.7 3 03/31/2006
Title:
ELECTRICAL POWER SYSTEMS DISTRIBUTION SYSTEMS OPERATING TEXT 3.8.8 0 11/18/2002
Title:
ELECTRICAL POWER SYSTEMS DISTRIBUTION SYSTEMS - SHUTDOWN TEXT 3.9.1 0 11/18/2002
Title:
REFUELING OPERATIONS REFUELING EQUIPMENT INTERLOCKS TEXT 3.9.2 0 11/18/2002
Title:
REFUELING OPERATIONS REFUEL POSITION ONE-ROD-OUT INTERLOCK TEXT 3.9.3 0 11/18/2002
Title:
REFUELING OPERATIONS CONTROL ROD POSITION TEXT 3.9.4 0 11/18/2002
Title:
REFUELING OPERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/18/2002
Title:
REFUELING OPERATIONS CONTROL ROD OPERABILITY REFUELING TEXT 3.9.6 1 10/04/2007
Title:
REFUELING OPERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL Report Date: 04/01/10 Pagel Page 7 of of 8
.8 Report Date: 04/01/10
SSES MANUIAL Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.9.7 0 11/18/2002
Title:
REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - HIGH WATER LEVEL TEXT 3.9.8 0 11/18/2002
Title:
REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - LOW WATER LEVEL TEXT 3.10.1 1 01/23/2008
Title:
SPECIAL OPERATIONS INSERVICE LEAK AND HYDROSTATIC TESTING OPERATION TEXT 3.10.2 0 11/18/2002
Title:
SPECIAL OPERATIONS REACTOR MODE SWITCH INTERLOCK TESTING TEXT 3.10.3 0 11/18/2002
Title:
SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - HOT SHUTDOWN TEXT 3.10.4 0 11/18/2002
Title:
SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - COLD SHUTDOWN TEXT 3.10.5 0 11/18/2002
Title:
SPECIAL OPERATIONS SINGLE CONTROL ROD DRIVE (CRD) REMOVAL - REFUELING TEXT 3.10.6 0 11/18/2002
Title:
SPECIAL OPERATIONS MULTIPLE CONTROL ROD WITHDRAWAL - REFUELING TEXT 3.10.7 1 03/24/2005
Title:
SPECIAL OPERATIONS CONTROL ROD TESTING - OPERATING TEXT 3.10.8 2 04/09/2007
Title:
SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING Report Date: 04/01/10 Page~
Page 8 of of 8
.8 Report Date: 04/01/10
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision TOC Table of Contents 16 B 2.0 SAFETY LIMITS BASES Page TS / B 2.0-1 1 Pages TS / B 2.0-2 and TS / B 2.0-3 4 Page TS / B 2.0-4 6 Pages TS / B 2.0-5 through TS / B 2.0-8 1 B 3.0 LCO AND SR APPLICABILITY BASES Page TS / B 3.0-1 1 Pages TS / B 3.0-2 through TS / B 3.0-4 0 Pages TS / B 3.0-5 through TS / B 3.0-7 1 Page TS / B 3.0-8 3 Pages TS / B 3.0-9 through Page TS / B 3.0-11 2 Page TS / B 3.0-11a 0 Page TS / B 3.0-12 1 Pages TS / B 3.0-13 through TS / B 3.0-15 2 Pages TS / B 3.0-16 and TS / B 3.0-17 * ) 0 B 3.1 REACTIVITY CONTROL BASES Pages B 3.1-1.through B 3.1-4 0 Page TS / B 3.1-5 1 Pages TS / B 3.1-6 and TS / B 3.1-7\ 2 Pages B 3.1-8 through B 3.1-13 0 Page TS / B 3.1-14 1 Page TS / B 3.1-15 0 Page TS / B 3.1-16 1 Pages TS / B 3.1-17 through TS / B 3.1-19 0 Pages TS / B 3.1-20 and TS / B 3.1-21 1 Page TS / B 3.1-22 0 Page TS / B 3.1-23 1 Page TS / B 3.1-24 0 Pages TS / B 3.1-25 through TS / B 3.1-27 1 Page TS / B 3.1-28 2 Page TS / 3.1-29 1 Pages B 3.1-30 through B 3.1-33 0 Pages TS / B 3.1.34 through TS / B 3.1-36 1 Pages TS / B 3.1-37 and TS /B 3.1-38 2 Pages TS / B 3.1-39 and TS / B 3.1-40 2 Page TS / B 3.1-40a 0 Page TS / B 3.1-41 1 Page TS / B 3.1-42 2 Revision 97 TS / B LOES-1 SUSQUEHANNA - UNIT SUSQUEHANNA -
UNIT 22 TS / B LOES-1 Revision 97
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Pages TS / B 3.1-43 1 Page TS / B 3.1-44 0 Page TS / B 3.1-45 3 Page TS / B 3.1-46 0 Page TS / B 3.1-47 1 Pages TS / B 3.1-48 and TS / B 3.1-49 1 Page B 3.1-50 0 Page TS / B 3.1-51 3 B 3.2 POWER DISTRIBUTION LIMITS BASES Pages TS / B 3.2-1 and TS / B 3.2-2 2 Page TS / B 3.2-3 4 Page TS / B 3.2-4 1 Page TS / B 3.2-5 3 Page TS / B 3.2-6 4 Page TS / B 3.2-7 3 Pages TS / B 3.2-8 and TS / B 3.2-9 4 Pages TS / B 3.2-10 through TS / B 3.2-12 2 Page TS / B 3.2-13 1 B 3.3 INSTRUMENTATION Pages TS / B 3.3-1 through TS / B 3.3-4 1 Page TS / B 3.3-5 2 Page TS / B 3.3-6 1 Page TS / B 3.3-7 3 Page TS / B 3.3-8 4 Pages TS / B 3.3-9 through TS / B 3.3-13 3 Page TS / B 3.3-14 4 Pages TS / B 3.3-15 and TS / B 3.3-16 2 Pages TS / B 3.3-17 through TS / B 3.3-21 3 Pages TS / B 3.3-22 through TS / B 3.3-27 2 Page TS / B 3.3-28 3 Page TS / B 3.3-29 4 Pages TS / B 3.3-30 and TS / B 3.3-31 3 Pages TS / B 3.3-32 and TS / B 3.3-33 4 Page TS / B 3.3-34 2 Page TS / B 3.3-34a 1 Pages TS / B 3.3-34b through TS / B 3.3-34d 0 Page TS / B 3.3-34e 1 Pages TS / B 3.3-34f through TS / B 3.3-34i 0 Pages TS / B 3.3-35 and TS / B 3.3-36 2 Pages TS / B 3.3-37 and TS / B 3.3-38 1 Revision 97 TS I B LOES-2 SUSQUEHANNA - UNIT SUSQUEHANNA -
UNIT 22 TS / B LOES-2 Revision 97
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Page TS / B 3.3-39 2 Pages TS / B 3.3-40 through TS / B 3.3-43 2 Pages TS / B 3.3-44 through TS / B 3.3-54 3 Pages TS / B 3.3-54a through TS-/ B 3.3-54e 0 Page TS / B 3.3-55 1 Page B 3.3-56 0 Page TS / B 3.3-57 1 Page B 3.3-58 0 Page TS / B 3.3-59 1 Pages B 3.3-60 through B 3.3-63 0 Pages TS / B 3.3-64 and TS / B 3.3-65 2 Page TS / B 3.3-66 4 Page TS / B 3.3-67 3 Page TS / B 3.3-68 4 Page TS / B 3.3.69 5 Page TS / B 3.3-70 4 Page TS / B 3.3-71 3 Pages TS / B 3.3-72 and TS / B 3.3-73 2 Page TS / B 3.3-74 3 Page TS / B 3.3-75 2 Pages TS / B 3.3-75a and TS / B 3.3-75 b 6 Page TS / B 3.3-75c 5 Pages B 3.3-76 and TS / B 3.3-77 0 Page TS / B 3.3-78 1 Pages B 3.3-79 through B 3.3-81 0 Page TS / B 3.3-82 1 Page B 3.3-83 0 Pages TS / B 3.3-84 and TS / B 3.3-85 1 Page 3.3-86 0 Page TS / B 3.3-87 1 Page B 3.3-88 0 Page TS / B 3.3-89 1 Pages B 3.3-90 and B 3.3-91 0 Pages TS / B 3.3-92 through TS / B 3.3-103 1 Page TS / B 3.3-104 3 Pages TS / B 3.3-105 and TS / B 3.3-106 1 Page TS / B 3.3-107 2 Page TS / B 3.3-108 1 Page TS / B 3.3-109 2 Pages TS / B 3.3-110 through TS/B 3.3-112 1 Page TS / B 3.3-113 2 Page TS / B 3.3-114 1 Page TS / B 3.3-115 2 Page TS / B 3.3-116 3 Pages TS / B 3.3-117 and TS/B 3.3-118 2 SUSQUEHANNA - UNIT 2 TS / B LOES-3 Revision 97
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVESECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Pages TS / B 3.3-119 through TS / B 3.3-120 1 Pages TS / B 3.3-121 and TS / B 3.3-122 2 Page TS / B 3.3-123 1 Page TS / B 3.3-124 2 Page TS / B 3.3-124a 0 Page TS / B 3.3-125 1 Page TS / B 3.3-126 2 Page TS / B 3.3-127 3 Page TS / B 3.3-128 2 Pages TS / B 3.3-129 through TS / B 3.3-131 1 Page TS / B 3.3-132 2 Pages TS / B 3.3-133 and TS / B 3.3-134 1 Pages B 3.3-135 through B 3.3-137 0 Page TS / B 3.3-138 1 Pages B 3.3-139 through B 3.3-149 0 Pages TS/ B 3.3-150 and TS / B 3.3-151 1 Pages TS / B 3.3-152 through TS / B 3.3-154 2 Page TS / B 3.3-155 1 Pages TS / B 3.3-156 through TS / B 3.3-158 2 Pages TS / B 3.3-159 through TS / B 3.3-161 1 Page TS / B 3.3-162 1 Page TS / B 3.3-163 2 Page TS / B 3.3-164 1 Pages TS / B 3.3-165 and TS / B 3.3-166 2 Pages TS / B 3.3-167 and TS / B 3.3-168 1 Pages TS / B 3.3-169 and TS / B 3.3-170 2 Pages TS / B 3.3-171 through TS I B 3.3-177 1 Page TS / B 3.3-178 2 Page TS / B 3.3-179 3 Page TS / B 3.3-179a .2 Page TS / B 3.3-180 1 Page TS / B 3.3-181 3 Page TS / B 3.3-182 1 Page TS / B 3.3-183 2 Page TS / B 3.3-184 1 Page TS / B 3.3-185 3 Page TS / B 3.3-186 1 Pages TS / B 3.3-187 and TS / B 3.3-188 2 Pages TS / B 3.3-189 through TS / B 3.3-191 1 Page TS / B 3.3-192 0 Page TS / B 3.3-193 1 Pages TS / B 3.3-194 and TS / B 3.3-195 0 Page TS / B 3.3-196 2 Revision 97 TS/BLOES-4 SUSQUEHANNA - UNIT SUSQUEHANNA -
UNIT 22 TS / B LOES-4 Revision 97
SUSQUEHANNA STEAM ELECTRIC STATION LIST OFEFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Pages TS / B 3.3-197 through TS / B 3.3-205 0 Page TS / B 3.3-206 1 Pages B 3.3-207 through B 3.3-209 0 Page TS / B 3.3-210 1 Page TS / B 3.3-211 2 Pages TS / B 3.3-212 and TS / B 3.3-213 1 Pages B 3.3-214 through B 3.3-220 0 B 3.4 REACTOR COOLANT SYSTEM BASES Pages TS / B 3.4-1 and TS / B 3.4-2 1 Pages TS / B 3.4-3 and TS / B 3.4-4 4 Pages TS / B 3.4-5 and TS / B 3.4-9 3 Pages B 3.4-10 through B 3.4-12 0 Page TS / B 3.4-13 1 Page B 3.4-14 0 Page TS / B 3.4-15 2 Pages TS / B 3.4-16 and TS / B 3.4-17 3 Page TS / B 3.4-18 2 Pages B 3.4-19 through B 3.4-23 0 Pages TS / B 3.4-24 through TS / B 3.4-27 0 Page TS / B 3.4-28 1 Page TS / B 3.4-29 3 Pages TS / B 3.4-30 and TS / B 3.3-31 0 Pages TS / B 3.4-32 and TS / B 3.4-33 1 Page TS / B 3.4-34 0 Pages TS / B 3.4-35 and TS / B 3.4-36 1 Page TS / B 3.4-37 2 Page B 3.4-38 1 Pages B 3.4-39 and B 3.4-40 0 Page TS / B 3.4-41 1 Pages B 3.4-42 through B 3.4-48 0 Page TS / B 3.4-49 3 Pages TS / B 3.4-50 through TS / B 3.4-52 2 Page TS / B 3.4-53 1 Pages TS / B 3.4-54 through TS / B 3.4-57 2 Pages TS / B 3.4-58 through TS / B 3.4-60 1 B 3.5 ECCS AND RCIC BASES Pages TS / B 3.5-1 and TS / B 3.5-2 1 Pages TS / B 3.5-3 through TS / B 3.5-6 2 Pages TS / B 3.5-7 through TS / B 3.5-10 1 Pages TS / B 3.5-11 and TS / B 3.5-12 2 Pages TS / B 3.6-13 and TS / B 3.5-14 1 Revision 97 TS/BLOES-5 SUSQUEHANNA-UNIT2 SUSQUEHANNA - UNIT 2 TS / B LOES-5 Revision 97
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTfONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Pages TS / B 3.5-15 and TS / B.3.5-16 2 Page TS / B 3.5-17 3 Page TS / B 3.5-18 1 Pages B 3.5-19 through B 3.5-24 0 Pages TS / B 3.5-25 through TS / B 3.5-27 1 Pages B 3.5-28 through B 3.5-31 0 B 3.6 CONTAINMENT SYSTEMS BASES Page TS / B 3.6-1 2 Page TS / B 3.6-1a 3 Page TS / B 3.6-2 4 Page TS / B 3.6-3 3 Page TS / B 3.6-4 4 Page TS / B 3.6-5 3 Page TS / B 3.6-6 4 Pages TS / B 3.6-6a and TS / B 3.6-6b 2 Page TS / B 3.6-6c 0 Page B 3.6-7 0 Page TS / 3.6-8 1 Pages 3.6-9 through B 3.6-14 0 Page TS / B 3.6-15 3 Page TS / B 3.6-15a 0 Page TS / B 3.6-15b 3 Pages TS / B 3.6-16 and TS / B 3.6-17 2 Page TS / B 3.6-17a 0 Pages TS / B 3.6-18 and TS / B 3.6-19 1 Page TS/ B 3.6-20 2 Page TS /B 3.6-21 3 Pages TS / B 3.6-21a and TS / B 3.6-21b 0 Pages TS / B 3.6-22 and TS / B 3.6-23 2 Pages TS / B 3.6-24 and TS / B 3.6-25 1 Pages TS / B 3.6-26 and TS / B 3.6-27 3 Page TS / B 3.6-28 7 Page TS / B 3.6-29 5 Page TS / B 3.6-29a 0 Page TS / B 3.6-30 2 Page TS / B 3.6-31 3 Page TS / B 3.6-32 1 Page TS / B 3.6-33 2 Page TS / B 3.6-34 1 Page TS / B 3.6-35 3 Pages TS / B 3.6-36 and TS / B 3.6-37 2 Page TS / B 3.6-38 3 Page TS / B 3.6-39 7 Revision 97 TS/BLOES-6 SUSQUEHANNA - UNIT SUSQUEHANNA -
UNIT 22 TS / B LOES-6 Revision 97
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision PageTS/B 3.6 1 Pages B 3.6-41 and B 3.6-42 0 Pages TS / B 3.6-43 and TS / B 3.6-44 1 Page TS / B 3.6-45 2 Pages TS / B 3.6-46 through TS / B 3.6-50 1 Page IS / B 3.6-51 2 Pages B 3.6-52 through B 3.6-55 0 Pages TS / B 3.6-56 and TS / B 3.6-57 2 Pages B 3.6-58 through B 3.6-62 0 Pages TS / B 3.6-63 and TS / B 3.6-64 1 Pages B 3.6-65 through B 3.6-68 0 Pages B 3.6-69 through B 3.6-71 1 Page TS / B 3.6-72 2 Pages TS / B 3.6-73 and TS / B 3.6-74 1 Pages B 3.6-75 and B 3.6-76 0 Page TS / B 3.6-77 1 Pages B 3.6-78 through B 3.6-82 0 Page TS / B 3.6-83 3 Page TS / B 3.6-84 2 Page TS / B 3.6-85 4 Page TS / B 3.6-86 through TS / B 3.6-87a 2 Page TS / B 3.6-88 4 Page TS / B 3.6-89 2 Page TS / B 3.6-90 3 Pages TS / B 3.6-91 through TS / B 3.6-95 1 Page TS / B 3.6-96 2 Pages TS / B 3.6-97 and TS / B 3.6-98 1 Page TS / B 3.6-99 3 Page TS / B 3.6-99a 0 Pages TS / B 3.6-100 and TS / B 3.6-101 1 Pages TS / B 3.6-102 and TS / B 3.6-103 2 Page TS / B 3.6-104 3 Page TS / B 3.6-105 2 Page TS / B 3.6-106 3 B 3.7 PLANT SYSTEMS BASES Page TS / B 3.7-1 3 Page TS / B 3.7-2 4 Pages TS / B 3.7-3 through TS /B 3.7-5 3 Page TS / B 3.7-5a 0 Page TS / B 3.7-6 and TS / B 3.7-6a 2 Page TS / B 3.7-6b 1 SUSQUEHANNA - UNIT 2 TS / B LOES-7 Revision 97
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Page TS / B 3.7-6c 2 Page TS / B 3.7-7 3 Page TS / B 3.7-8 2 Pages B 3.7-9 through B 3.7-11 0 Pages TS / B 3.7-12 and TS / B 3.7-13 2 Pages TS / B 3.7-14 through TS / B 3.7-18 3 Page TS / B 3.7-18a 1 Pages TS / B 3.7-18b through TS / B 3.7-18e 0 Pages TS / B 3.7-19 through TS / B 3.7-24 1 Pages TS / B 3.7-25 and TS / B 3.7-26 0 Pages TS / B 3.7-27 through TS / B 3.7-29 3 Pages TS / B 3.7-30 and TS / B 3.7-31 1 Page TS / B 3.7-32 0 Page TS / B 3.7-33 1 Pages TS / B 3.7-34 through TS / B 3.7-37 0 B 3.8 ELECTRICAL POWER SYSTEMS BASES Page TS / B 3.8-1 1 Pages B 3.8-2 and B 3.8-3 0 Page TS / B 3.8-4 1 Pages TS / B 3.8-4a and TS / B 3.8-4b 0 Pages TS / B 3.8-5 and TS / B 3.8-6 3 Page TS / B 3.8-6a 1 Pages B 3.8-7 and B 3.8-8 0 Page TS / B 3.8-9 2 Pages TS / B 3.8-10 and TS / B 3.8-11 1 Pages B 3.8-12 through B 3.8-18 0 Page TS / B 3.8-19 1 Pages B 3.8-20 through B 3.8-22 0 Page TS / B 3.8-23 1 Page B 3.8-24 0 Pages TS / B 3.8-25 and TS / B 3.8-26 1 Pages B 3.8-27 through B 3.8-35 0 Page TS / B 3.8-36 1 Page TS / B 3.8-37 0 Page TS / B 3.8-38 1 Pages TS / B 3.8-39 through TS / B 3.8-46 0 Page TS / B 3.8-47 1 Pages TS / B 3.8-48 through TS / B 3.8-50 0 Page TS / B 3.8-51 1 Pages TS / B 3.8-52 through TS / B 3.8-55 0 Pages TS / B 3.8-56 through TS / B 3.8-59 2 Pages TS / B 3.8-60 through TS / B 3.8-64 3 Revision 97 TS I B LOES-8 SUSQUEHANNA - UNIT SUSQUEHANNA -
UNIT 22 TS / B LOES-8 Revision 97
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Page TS / B 3.8-65 4 Page TS / B 3.8-66 5 Pages TS / B 3.8-67 and TS / B 3.8-68 4 Page TS / B 3.8-69 5 Pages TS / B 3.8-70 through TS / B 3.8-83 1 Pages rS / B 3.8-83A through TS / B 3.8-83D 0 Pages B 3.8-84 through B 3.8-85 0 Page TS / B 3.8-86 1 Page TS / B 3.8-87 2 Pages TS / B 3.8-88 through TS / E 3.8-93 1 Pages B 3.8-94 through B 3.8-99 0 B 3.9 REFUELING OPERATIONS BASES Pages TS / B 3.9-1 and TS / B 3.9-2 1 Page TS / B 3.9-2a 1 Pages TS / B 3.9-3 and TS / B 3.9-4 1 Pages B 3.9-5 through B 3.9-18 0 Pages TS / B 3.9-19 through TS / B 3.9-21 1 Pages B 3.9-22 through B 3.9-30 0 B 3.10 SPECIAL OPERATIONS BASES Page TS / B 3.10-1 2 Pages TS / B.3.10-2 through TS / B 3.10-5 1 Pages B 3.10-6 through B 3.10-32 0 Page TS / B 3.10-33 2 Page B 3.10-34 0 Page B 3.10-35 1 Pages B 3.10-36 and B 3.10-37 0 Page B 3.10-38 1 Page TS / B 3.10-39 2 TSB2 Text LOES.doc 2/25/2010 Revision 97 TS / B LOES-9 SUSQUEHANNA - UNIT SUSQUEHANNA -
UNIT 22 TS / B LOES-9 Revision 97
TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)
B2.0 SA FETY LIM ITS (S Ls) ............................................................................ TS/B2.0-1 B2.1.1 Reactor C ore S Ls ..................................................................... TS/B2.0-1 B2.1.2 Reactor Coolant System (RCS) Pressure SL ........................... TS/B2.0-6 B3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ........ TS/B3.0-1 B3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ...................... TS/B3.0-10 B3.1 REACTIVITY CONTROL SYSTEMS .................................................... B3.1-1 B3.1.1 Shutdow n Margin (SDM ) ................................................................ B3.1-1 B3.1.2 Reactivity Anom alies ..................................................................... B3.1-8 B3.1.3 Control Rod OPERABILITY ............................................................ B3.1-13 B3.1.4 Control Rod Scram Times ........................................................ TS/B3.1-22 B3.1.5 Control Rod Scram Accumulators ............................................ TS/B3.1-29 B3.1.6 Rod Pattern Control ............. ;.................................................... TS/B3.1-34 B3.1.7 Standby Liquid Control (SLC) System ...................................... TS/B3.1-39 B3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves .......... TS/B3.1-47 B3.2 POWER DISTRIBUTION LIMITS ................................................... TS/B3.2-1 B3.2.1 Average Planar Linear Heat Generation Rate (APLHGR) ........ TS/B3.2-1 B3.2.2 Minimum Critical Power Ratio (MCPR) ..................................... TS/B3.2-5 B3.2.3 Linear Heat Generation Rate (LHGR) ....................................... TS/B3.2-10 B3.3 INSTRUM ENTATIO N..................................................................... TS/B3.3-1 B3.3.1.1 Reactor Protection System (RPS) Instrumentation ................... TS/B3.3-1 B3.3.1.2 Source Range Monitor (SRM) Instrumentation ......................... TS/B3.3-35 B3.3.2.1 Control Rod Block Instrumentation ........................................... TS/B3.3-44 B3.3.2.2 Feedwater - Main Turbine High Water Level Trip Instrum entation ................................................................... TS/B 3.3-55 B3.3.3.1 Post Accident Monitoring (PAM) Instrumentation ..................... TS/B3.3-64 B3.3.3.2 Remote Shutdown System ........................................................... I.B3.3-76 B3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)
Instrumentation ................... ................................... ...... B3.3-81 B3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation .................................. B3.3-92 B3.3.5.1 Emergency Core Cooling System (ECCS)
Instrum entation ................................................................... TS/B3.3-1 01 B3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrum entation ......................................................................... B3.3-135 B3.3.6.1 Primary Containment Isolation Instrumentation .............................. B3.3-147 B3.3.6.2 Secondary Containment Isolation Instrumentation ................... TS/B3.3-180 83.3.7.1 Control Room Emergency Outside Air Supply (CREOAS)
System Instrumentation ...................................................... TS/B3.3-192 (continued)
SUSQUEHANNA-UNIT2 TS / B TOC - I Revision 16
TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)
B3.3 INSTRUMENTATION (continued)
B3.3.8.1 Loss of Power (LOP) Instrumentation ...................................... TS/B3.3-206 B3.3.8.2 Reactor Protection System (RPS) Electric Power Mo nitoring ................................................................................ B3 .3-2 14 B3.4 REACTOR COOLANT SYSTEM (RCS) .......................................... TS/B3.4-1 B3.4.1 Recirculation Loops Operating .............. I.................................. TS/B3.4-1 B3.4.2 Jet P um ps ...................................................................................... B 3.4-10 B3.4.3 Safety/Relief Valves (S/RVs) .................................................... TS/B3.4-15 B3.4.4 RCS Operational LEAKAGE ........................................................... B3.4-19 B3.4.5 RCS Pressure Isolation Valve (PIV) Leakage ........................... TS/B3.4-24 B3.4.6 RCS Leakage Detection Instrumentation .................................. TS/B3.4-30 B3.4.7 RCS Specific Activity ................................................................ TS/B3.4-35 B3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown ........................................................... B3.4-39 B3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown ......................................................... B3.4-44 B3.4.10 RCS Pressure and Temperature (P/T) Limits ........................... TS/B3.4-49 B3.4.11 Reactor Steam Dome Pressure TS/B3.4-58 B3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ............................ TS/B3.5-1 B3.5.1 ECCS - Operating ................................................................... TS/B3.5-1 B3.5.2 ECCS - Shutdown ......................................................................... B3.5-19 B3.5.3 RCIC System ........................................................................... TS/B3.5-25 B3.6 CONTAINMENT SYSTEMS ........................................................... TS/B3.6-1 B3.6.1.1 Primary Containment ................................................................ TS/B3.6-1 B3.6.1.2 Primary Containment Air Lock ........................................................ B3.6-7 B3.6.1.3 Primary Containment Isolation Valves (PCIVs) ......................... TS/B3.6-15 B3.6.1.4 Containment Pressure .............................................................. TS/B3.6-40 B3.6.1.5 Drywell Air Temperature ........................................................... TS/B3.6-43 B3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers ............... TS/B3.6-46 B3.6.2.1 Suppression Pool Average Temperature ........................................ B3.6-52 B3.6.2.2 Suppression Pool Water Level ....................................................... B3.6-58 B3.6.2.3 Residual Heat Removal (RHR) Suppression Pool C oo ling ..................................................................................... B3 .6-6 1 B3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ................ B3.6-65 B3.6.3.1 Not Used ................................................................................. T S/B3.6-69 B3.6.3.2 Drywell Air Flow System ................................................................. B3.6-75 B3.6.3.3 Primary Containment Oxygen Concentration .................................. B3.6-80 B3.6.4.1 Secondary Containment ........................................................... TS/B3.6-83 B3.6.4.2 Secondary Containment Isolation Valves (SCIVs) .................... TS/B3.6-90 B3.6.4.3 Standby Gas Treatment (SGT) System .................................... TS/B3.6-1 00 (continued)
SUSQUEHANNA - UNIT 2 TS / B TOC - 2 Revision 16
TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)
B3.7 PLA NT SYSTEM S ......................................................................... TS/B3.7-1 B3.7.1 Residual Heat Removal Service Water (RHRSW) System and the Ultimate Heat Sink (UHS) ...................................... TS/B3.7-1 B3.7.2 Emergency Service Water (ESW) System ................................ TS/B3.7-7 B3.7.3 Control Room Emergency Outside Air Supply (C REOAS) System ............................................................. TS/B3.7-12 B3.7.4 Control Room Floor Cooling System ........................................ TS/B3.7-19 B3.7.5 Main Condenser Offgas ........................................................... TS/B3.7-24 B3.7.6 Main Turbine Bypass System ................................................... TS/B3.7-27 B3.7.7 Spent Fuel Storage Pool Water Level ..................................... TS/B3.7-31 B3.7.8 Main Turbine Pressure Regulation System .............................. TS/B3.7-34 B3.8 ELECTRICAL POWER SYSTEM ................................................... TS/B3.8-1 B3.8.1 AC Sources - Operating .......................................................... TS/B3.8-1 B3.8.2 AC Sources - Shutdown ................................................................ B3.8-39 B3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ................................ TS/B3.8-47 B3.8.4 DC Sources - Operating .......................................................... TS/B3.8-56 B3.8.5 DC Sources - Shutdown ..................... . ....... TS/B3.8-70 B3.8.6 Battery Cell Param eters ........................................................... TS/B3.8-77 B3.8.7 Distribution Systems - Operating ................................................... B3.8-84 B3.8.8 Distribution Systems - Shutdown ................................................... B3.8-94 B3.9 REFUELING OPERATIONS .......................................................... TS/B3.9-1 B3.9.1 Refueling Equipment Interlocks ................................................ TS/B3.9-1 B3.9.2 Refuel Position One-Rod-Out Interlock ........................................... B3.9-5 B3.9.3 Control Rod Position ...................................................................... B3.9-9 B3.9.4 Control Rod Position Indication ...................................................... B3.9-12 B3.9.5 Control Rod OPERABILITY - Refueling ......................................... B3.9-16 B3.9.6 Reactor Pressure Vessel (RPV) Water Level ........................... TS/B3.9-19 B3.9.7 Residual Heat Removal (RHR) - High Water Level ........................ B3.9-22 B3.9.8 Residual Heat Removal (RHR) - Low Water Level ........... B3.9-26 B3.10 SPECIAL OPERATIONS ............................ TS/B3.10-1 B3.10.1 Inservice Leak and Hydrostatic Testing Operation ................... TS/B3.10-1 B3.10.2 Reactor Mode Switch Interlock Testing .......................................... B3.10-6 B3.10.3 Single Control Rod Withdrawal - Hot Shutdown ............................. B3.10-11 B3.10.4 Single Control Rod Withdrawal - Cold Shutdown.: ......................... B3.10-16 B3.10.5 Single Control Rod Drive (CRD) Removal - Refueling ................... B3.10-21 B3.10.6 Multiple Control Rod Withdrawal - Refueling .................................. B3.10-26 B3.10.7 Control Rod Testing - Operating .................................................... B3.10-30 B3.10.8 SHUTDOWN MARGIN (SDM) Test - Refueling ............................. B3.10-34 TSB2 TOC.doc 2/25/2010 Revision 16 UNIT 22 SUSQUEHANNA - UNIT SUSQUEHANNA -
TS // B TS TOC -3 B TOC -3 Revision 16
PPL Rev. 3 RCS PIV Leakage B 3.4.5 B 3.4 REACTOR COOLANT SYSTEM (RCS)
B 3.4.5 RCS Pressure Isolation Valve (PIV) Leakage BASES BACKGROUND The function of RCS PIVs is to separate the high pressure RCS from an attached low pressure system. This protects the RCS pressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), and GDC 55 of 10 CFR 50, Appendix A (Refs. 1, 2, and 3). RCS PIVs are defined as any two normally closed valves in series within the reactor coolant pressure boundary (RCPB). PIVs are designed to meet the requirements of Reference 4. During their lives, these valves can produce varying amounts of reactor coolant leakage through either normal operational wear or mechanical deterioration.
The RCS PIV LCO allows RCS high pressure operation when leakage through these valves exists in amounts that do not compromise safety.
The PIV leakage limit applies to each individual valve. Leakage through these valves is not included in any allowable LEAKAGE specified in LCO 3.4.4, "RCS Operational LEAKAGE."
Although this specification provides a limit on allowable PIV leakage rate, its main purpose is to prevent overpressure failure of the low pressure portions of connecting systems. The leakage limit is an indication that the PIVs between the RCS and the connecting systems are degraded or degrading. PIV leakage could lead to overpressure of the low pressure piping or components. Failure consequences could be a loss of coolant accident (LOCA) outside of containment, an unanalyzed event that could degrade the ability for low pressure injection.
A study (Ref. 5) evaluated various PIV configurations to determine the probability of intersystem LOCAs. This study concluded that periodic leakage testing of the PIVs can substantially reduce intersystem LOCA probability.
(continued)
SUSQUEHANNA - UNIT 2 TS /B 3.4-24 Revision 0
PPL Rev. 3 RCS PIV Leakage B 3.4.5 BASES BACKGROUND PIVs are provided to isolate the RCS from the following typically (continued) connected systems:
- a. Residual Heat Removal (RHR) System; and
- b. Core Spray System.
The PIVs are listed in Table B 3.4.5-1 "Pressure Isolation Valve."
APPLICABLE Reference 5 evaluated various PIV configurations, leakage testing of the SAFETY valves, and operational changes to determine the effect on the probability ANALYSES of intersystem LOCAs. This study concluded that periodic leakage testing of the PIVs can substantially reduce the probability of an intersysiem LOCA.
PIV leakage is not considered in any Design Basis Accident analyses.
This Specification provides for monitoring the condition of the RCPB to detect PIV degradation that has the potential to cause a LOCA outside of containment. RCS PIV leakage satisfies Criterion 2 of the NRC Policy Statement (Ref. 6).
LCO RCS PIV leakage is leakage into closed systems connected to the RCS.
Isolation valve leakage is usually on the order of drops per minute.
Leakage that increases significantly suggests that something is operationally wrong and corrective action must be taken. Violation of this LCO could result in continued degradation of a PIV, which could lead to overpressurization of a low pressure system and the loss of the integrity of a fission product barrier.
The LCO PIV leakage limit is 0.5 gpm per nominal inch of valve size with a maximum limit of 5 gpm (Ref. 4).
APPLICABILITY In MODES 1, 2, and 3, this LCO applies because the PIV leakage potential is greatest when the RCS is pressurized. In MODE 3, valves in the RHR shutdown cooling flow path are not required to meet the requirements of this LCO when in, (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.4-25 Revision 0
PPL Rev. 3 RCS PIV Leakage B 3.4.5 BASES APPLICABILITY or during transition to or from, the RHR shutdown cooling mode of (continued) operation. This is because RHR shutdown cooling will be placed in operation only below the current pressure permissive setpoint when the high to low pressure interface does not exist.
In MODES 4 and 5, leakage limits are not provided because the lower reactor coolant pressure results in a reduced potential for leakage and for a LOCA outside the containment. Accordingly, the potential for the consequences of reactor coolant leakage is far lower during these MODES.
ACTIONS The ACTIONS are modified by two Notes. Note 1 has been provided to modify the ACTIONS related to RCS PIV flow paths. Section 1.3, Completion Times, specifies once a Condition has been entered, subsequent divisions, subsystems, components, or variables expressed in the Condition discovered to be inoperable or not within limits will not result in separate entry into the Condition. Section 1.3 also specifies Required Actions of the Condition continue to apply for each additional failure, with Completion Times based on initial entry into the Condition. However, the Required Actions for the Condition of RCS PIV leakage limits exceeded provide appropriate compensatory measures for separate affected RCS PIV flow paths. As such, a Note has been provided that allows separate Condition entry for each affected RCS PIN/ flow path. Note 2 requires an evaluation of affected systems if a PIV is inoperable. The leakage may have affected system OPERABILITY, or isolation of a leaking flow path with an alternate valve may have degraded the ability of the interconnected system to perform its safety function. As a result, the applicable Conditions and Required Actions for systems made inoperable by PIVs must be entered. This ensures appropriate remedial actions are taken, if necessary, for the affected systems.
A.1 If leakage from one or more RCS PIVs is not within limit, the flow path must be isolated by at least one closed manual, deactivated automatic, or check valve within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.4-26 Revision 0
PPL Rev. 3 RCS PIV Leakage B 3.4.5 BASES ACTIONS A. (continued)
Required Action A.! is modified by a Note stating that the valves used for isolation must meet the same leakage requirements as the PIVs and must be on the RCPB or the high pressure portion of the system.
Four hours provides time to reduce leakage in excess of the allowable limit and to isolate the flow path if leakage cannot be reduced while corrective actions to reseat the leaking PIVs are taken. The 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> allows time for these actions and restricts the time of operation with leaking valves.
B.1 and B.2 If leakage cannot be reduced or the system isolated, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. This action may.reduce the leakage and also reduces the potential for a LOCA outside the containment. The Completion Times are reasonable, based on operating experience, to achieve the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.4.5.1 REQUIREMENTS Performance of leakage testing on each RCS PIV is required to verify that leakage is below the specified limit and to identify each leaking valve.
The leakage limit of 0.5 gpm per inch of nominal valve diameter up to 5 gpm maximum applies to each valve. Leakage testing requires a stable pressure condition. For the two PIVs in series, the leakage requirement applies to each valve individually and not to the combined leakage across both valves. If the PIVs are not individually leakage tested, one valve may have failed completely and not be detected if the other valve in series meets the leakage requirement. In this situation, the protection provided by redundant valves would be lost.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.4-27' Revision 0'
PPL Rev. 3 RCS PIV Leakage B 3.4.5 BASES SURVEILLANCE SR 3.4.5.1 (continued)
REQUIREMENTS The 24 month Frequency required by the Inservice Testing Program is within the ASME OM Code Frequency requirement and is based on the need to perform this Surveillance during an outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.
This SR is modified by a Note that states the leakage Surveillance is not required to be performed in MODE 3. Entry into MODE 3 is permitted for leakage testing at high differential pressures with stable conditions not possible in the lower MODES.
REFERENCES 1. 10 CFR 50.2.
- 2. 10 CFR 50.55a(c).
- 4. ASME Operation and Maintenance Code.
- 5. NUREG-0677, May 1980.
- 6. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).
SUSQUEHANNA - UNiT 2 TS / B 3.4-28 Revision 1
PPL Rev. 3 RCS PIV Leakage B 3.4.5 BASES (continued)
TABLE B 3.4.5-1 REACTOR COOLANT SYSTEM PRESSURE ISOLATION VALVES 1st Isolation 2nd Isolation Valve(s) Number(s) Valve(s) Number(s) Service HV-252F006A HV-252F005A Core Spray Injection HV-252F037A HV-252F006B HV-252F005B Core Spray Injection HV-252F037B HV-251F050A HV-251F015A LPCI Injection HV-251 F122A 251130 HV-251 F050B HV-251F122B HV-251F050B HV-251F015B LPCI Injection HV-251F122B 251130 HV-251 F050A HV-251F122A HV-251 F022 HV-251 F023 Head Spray HV-251 F009 HV-251 F008 Shutdown Cooling SUSQUEHANNA - UNIT 2 TS / B 3.4-29 Revision 3
PPL Rev. 10 PCIVs B 3.6.1.3 B 3.6 CONTAINMENT SYSTEMS B 3.6.1.3 Primary Containment Isolation Valves (PCIVs)
BASES BACKGROUND The function of the PCIVs, in combination with other accident mitigation systems, is to limit fission product release during and following postulated Design Basis Accidents (DBAs) to within limits. Primary containment isolation within the time limits specified for those isolation valves designed to close automatically ensures that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a DBA.
The OPERABILITY requirements for PCIVs help ensure that an adequate primary containment boundary is maintained during and after an accident by minimizing potential paths to the environment. Therefore, the OPERABILITY requirements provide assurance that primary containment function assumed in the safety analyses will be maintained. For PCIVs, the primary containment isolation function is that the valve must be able to close (automatically or manually) and/or remain closed, and maintain leakage within that assumed in the DBA LOCA Dose Analysis. These isolation devices are either passive or active (automatic). Manual valves, de-activated automatic valves secured in their closed position (including check valves with flow through the valve secured), blind flanges, and closed systems are considered passive devices. The OPERABILITY requirements for closed systems are discussed in Technical Requirements Manual (TRM) Bases 3.6.4. Check valves, or other automatic valves designed to close without operator action following an accident, are considered active devices. Two barriers in series are provided for each penetration so that no single credible failure or malfunction of an active component can result in a loss of isolation or leakage that exceeds limits assumed in the safety analyses. One of these barriers may be a closed system.
For each division of H20 2 Analyzers, the lines, up to and including the first normally closed valves within the H2 0 2 (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-15 Revision 3
PPL Rev. 10 PCIVs B 3.6.1.3 BASES BACKGROUND Analyzer panels, are exten~sions of primary containment (continued) (i.e., closed system), and are required to be leak rate tested in accordance with the Leakage Rate Test Program. The H202 Analyzer closed system boundary is identified in the Leakage Rate Test Program. The closed system boundary consists of those components, piping, tubing, fittings, and valves, which meet the guidance of Reference 6. The closed system provides a secondary barrier in the event of a single failure of the PCIVs, as described below. The closed system boundary between PASS and the H20 2 Analyzer system ends at the process sampling solenoid operated isolation valves between the systems (SV-22361, SV-22365, SV-22366, SV-22368, and SV-22369). These solenoid operated isolation valves do not fully meet the guidance of Reference 6 for closed system boundary valves in that they are not powered from a Class 1E power source. However, based upon a risk determination, operating these valves as closed system boundary valves is not risk significant. These valves also form the end of the Seismic Category I boundary between the systems. These process sampling solenoid operated isolation valves are normally closed and are required to be leak rate tested in accordance with the Leakage Rate Test Program as part of the closed system for the H2 0 2 Analyzer system. These valves are "closed system boundary valves" and may be opened under administrative control, as delineated in Technical Requirements Manual (TRM)
Bases 3.6.4. Opening of these valves to permit testing of PASS in Modes 1, 2, and 3 is permitted in accordance with TRO 3.6.4.
Each H 2 0 2 Analyzer Sampling line penetrating primary containment has two PCIVs, located just outside primary containment. While two PCIVs are provided on each line, a single active failure of a relay in the control circuitryfor these valves, could result in both valves failing to close or failing to remain closed. Furthermore, a single failure (a hot short in the common raceway to all the valves) could simultaneously affect all of the PCIVs within a H20 2 Analyzer division. Therefore, the containment isolation barriers for these penetrations consist of two PCIVs and a closed system. For situations where one or both PCIVs are inoperable, the ACTIONS to be taken are similar to the ACTIONS for a single PCIV backed by a closed system.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-15a Revision 0
,* PPL Rev. 10 PCIVs B 3.6.1.3 BASES BACKGROUND The drywell vent and purge lines are 24 inches in diameter; the (continued) suppression chamber vent and purge lines are 18 inches in diameter. The containment purge valves are normally maintained closed in MODES 1, 2, and 3 to ensure the primary containment boundary is maintained. The outboard isolation valves have 2 inch bypass lines around them for use during normal reactor operation.
The RHR Shutdown Cooling return line containment penetrations
{X-13A(B)}are provided with a normally closed gate valve
{HV-251F015A(B)} and a normally open globe valve
{HV-251 F017A(B)} outside containment and a testable check valve {HV-251 F050A(B)} with a normally closed parallel air operated globe valve {HV-251 F122A(B)} inside containment.
The gate valve is manually opened and automatically isolates upon a containment isolation signal from the Nuclear Steam Supply Shutoff System or RPV low level 3 when the RHR System is operated in the Shutdown Cooling Mode only. The LPCI subsystem is an operational mode of the RHR System and uses the same injection lines to the RPV as the Shutdown Cooling Mode.
The design of these containment penetrations is unique in that some valves are containment isolation valves while others perform the function of pressure isolation valves. In order to meet the 10 CFR 50 Appendix J leakage testing requirements, the HV-251F015A(B) and the closed system outside containment are the only barriers tested in accordance with the Leakage Rate Test Program. Since these containment penetrations {X-13A and X-13B} include a containment isolation valve outside containment that is tested in accordance with 10 CFR 50 Appendix J requirements and a closed system outside containment that meets the requirements of USNRC Standard Review Plan 6.2.4 (September 1975), paragraph 11.3.e, the containment isolation provisions for these penetrations provide an acceptable alternative to the explicit requirements of 10 CFR 50, Appendix A, GDC 55.
Containment penetrations X-13A(B) are also high/low pressure system interfaces. In order to meet the requirements to have two (2) isolation valves between the high pressure and low pressure systems, the HV-251FO50A(B), HV-251F122A(B), 251130, and HV-251 F01 5A(B) valves are used to meet this requirement and are tested in accordance with the pressure test program.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-15b Revision 3
PPL Rev. 10 PCIVs B 3.6.1.3 BASES APPLICABLE The PCIVs LCO was derived from the assumptions related to SAFETY ANALYSES minimizing the loss of reactor coolant inventory, and establishing the primary containment boundary during major accidents. As part of the primary containment boundary, PCIV OPERABILITY supports leak tightness of primary containment.
Therefore, the safety analysis of any event requiring isolation of primary containment is applicable to this LCO.
The DBAs that result in a release of radioactive material within primary containment are a LOCA and a main steam line break (MSLB). In the analysis for each of these accidents, it is assumed that PCIVs are either closed or close within the required isolation times following event initiation. This ensures that potential paths to the environment through PCIVs (including primary containment purge valves) are minimized. The closure time of the main steam isolation valves (MSIVs) for a MSLB outside primary containment is a significant variable from a radiological standpoint. The MSIVs are required to close within 3 to 5 seconds since the 5 second closure time is assumed in the analysis. The safety analyses assume that the purge valves were closed at event initiation. Likewise, it is assumed that the primary containment is isolated such that release of fission products to the environment is controlled.
The DBA analysis assumes that within the required isolation time leakage is terminated, except for the maximum allowable leakage rate, L,.
The single failure criterion required to be imposed in the conduct of unit safety analyses was considered in the original design of the primary containment purge valves. Two valves in series on each purge line provide assurance that both the supply and exhaust lines could be isolated even if a single failure occurred.
The primary containment purge valves may be unable to close in the environment following a LOCA. Therefore, each of the purge valves is required to remain closed during MODES 1, 2, and 3 except as permitted under Note 2 of SR 3.6.1.3.1. In this case, the single failure criterion remains applicable to the primary containment purge valve (continued)
SUSQUEHANNA - UNIT 2 TS I B 3.6-16 Revision 2
PPL Rev. 10 PCIVs B 3.6.1.3 BASES APPLICABLE due to failure in the control circuit associated with each valve.
SAFETY ANALYSIS The primary containment purge valve design precludes a single (continued) failure from compromising the primary containment boundary as long as the system is operated in accordance with this LCO.
Both H20 2 Analyzer PCIVs may not be able to close given a single failure in the control circuitry of the valves. The single failure is caused by a "hot short" in the cables/raceway to the PCIVs that causes both PCIVs for a given penetration to remain open or to open when required to be closed. This failure is required to be considered in accordance with IEEE-279 as discussed in FSAR Section 7.3.2a. However, the single failure criterion for containment isolation of the H20 2 Analyzer penetrations is satisfied by virtue of the combination of the associated PCIVs and the closed system formed by the H20 2 Analyzer piping system as discussed in the BACKGROUND section above.
The closed system boundary between PASS and the H20 2 Analyzer system ends at the process sampling solenoid operated isolation valves between the systems (SV-22361, SV-22365, SV-22366, SV-22368, and SV-22369). The closed system is not fully qualified to the guidance of Reference 6 in that the closed system boundary valves between the H20 2 system and PASS are not powered from a Class 1E power source. However, based upon a risk determination, the use of these valves is considered to have no risk significance. This exemption to the requirement of Reference 6 for the closed system boundary is documented in License Amendment No. 170.
PCIVs satisfy Criterion 3 of the NRC Policy Statement. (Ref. 2)
LCO PCIVs form a part of the primary containment boundary. The PCIV safety function is related to minimizing the loss of reactor coolant inventory and establishing the primary containment boundary during a DBA.
The power operated, automatic isolation valves are required to have isolation times within limits and actuate on an (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-17 Revision 2
PPL Rev. 10 PCIVs B 3.6.1.3 BASES LCO automatic isolation signal.' The valves covered by this LCO are (continued) listed in Table B 3.6.1.3-1.
The normally closed PCIVs are considered OPERABLE when manual valves are closed or open in accordance with appropriate administrative controls, automatic valves are in their closed position, blind flanges are in place, and closed systems are intact. These passive isolation valves and devices are those listed in Table B 3.6.1.3-1.
Purge valves with resilient seals, secondary containment bypass valves, MSIVs, and hydrostatically tested valves must meet additional leakage rate requirements. Other PCIV leakage rates are addressed by LCO 3.6.1.1, "Primary Containment," as Type B or C testing.
This LCO provides assurance that the PCIVs will perform their designed safety functions to minimize the loss of reactor coolant inventory and establish the primary containment boundary during accidents.
APPLICABILITY In MODES 1, 2, and 3, a DBA could cause a release of radioactive material to primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, most PCIVs are not required to be (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-17a Revision 01
PPL Rev. 10 PCIVs B 3.6.1.3 BASES APPLICABILITY OPERABLE and the primary containment purge valves are (continued) not required to be closed in MODES 4 and 5. Certain valves, however, are required to be OPERABLE to prevent inadvertent reactor vessel draindown. These valves are those whose associated instrumentation is required to be OPERABLE per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation."
(This does not include the valves that isolate the associated instrumentation.)
ACTIONS The ACTIONS are modified by a Note allowing penetration flow path(s) to be unisolated intermittently under administrative controls. These controls consist of stationing a dedicated operator at the controls of the valve, who is in continuous communication with the control room. In this way, the penetration can be rapidly isolated when a need for primary containment isolation is indicated.
A second Note has been added to provide clarification that, for the purpose of this LCO, separate Condition entry is allowed for each penetration flow path. This is acceptable, since the Required Actions for each Condition provide appropriate compensatory actions for each inoperable PCIV. Complying with the Required Actions may allow for continued operation, and subsequent inoperable PCIVs are governed by subsequent Condition entry and application of associated Required Actions.
The ACTIONS are modified by Notes 3 and 4. Note 3 ensures that appropriate remedial actions are taken, if necessary, if the affected system(s) are rendered inoperable by an inoperable PCIV (e.g., an Emergency Core Cooling System subsystem is inoperable due to a failed open test return valve). Note 4 ensures appropriate remedial actions are taken when the primary containment leakage limits are exceeded. Pursuant to LCO 3.0.6, these actions are not required even when the associated LCO is not met. Therefore, Notes 3 and 4 are added to require the proper actions be taken.
A.1 and A.2 With one or more penetration flow paths with one PCIV inoperable except for purge valve leakage not within limit, (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-18 Revision 1
PPL Rev. 10 PCIVs B 3.6.1.3 BASES ACTIONS A.1 and A.2 (continued) the affected penetration flow paths must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, a blind flange, and a check valve with flow through the valve secured.
For a penetration isolated in accordance with Required Action A. 1, the device used to isolate the penetration should be the closest available valve to the primary containment. The Required Action must be completed within the 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time (8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for main steam lines). The Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is reasonable considering the time required to isolate the penetration and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. For main steam lines, an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Completion Time is allowed. The Completion Time of 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for the main steam lines allows a period of time to restore the MSIVs to OPERABLE status given the fact that MSIV closure will result in isolation of the main steam line(s) and a potential for plant shutdown.
For affected penetrations that have been isolated in accordance with Required Action A. 1, the affected penetration flow path(s) must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident, and no longer capable of being automatically isolated, will be in the isolation position should an event occur. This Required Action does not require any testing or device manipulation. Rather, it involves verification that those devices outside containment and capable of potentially being mispositioned are in the correct position. The Completion Time of "once per 31 days for isolation devices outside primary containment" is appropriate because the devices are operated under administrative controls and the probability of their misalignment is low. For the devices inside primary containment, the time period specified "prior to entering MODE 2 or 3 from MODE 4, ifprimary containment was de-inerted while in MODE 4, if not performed within the previous 92 days" is based on engineering judgment and is considered reasonable in view of the inaccessibility of the devices and other administrative controls ensuring that device misalignment is an unlikely possibility.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-19 Revision 1
PPL Rev. 10 PCIVs B 3.6.1.3 BASES ACTIONS A.1 and A.2 (continued)
Condition A is modified by a Note indicating that this Condition is only applicable to those penetration flow paths with two PCIVs except for the H20 2 Analyzer penetrations. For penetration flow paths with one PCIV, Condition C provides the appropriate Required Actions. For the H20 2 Analyzer penetrations, Condition D provides the appropriate Required Actions.
Required Action A.2 is modified by a Note that applies to isolation devices located in high radiation areas, and allows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted. Therefore, the probability of misalignment of these devices, once they have been verified to be in the proper position, is low.
B. 1 With one or more penetration flow paths with two PCIVs inoperable except for purge valve leakage not within limit, either the inoperable PCIVs must be restored to OPERABLE status or the affected penetration flow path must be isolated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time is consistent with the ACTIONS of LCO 3.6.1.1.
Condition B is modified by a Note indicating this Condition is only applicable to penetration flow paths with two PCIVs except for the H20 2 Analyzer penetrations. For penetration flow paths with one PCIV, Condition C provides the appropriate Required Actions. For the H20 2 Analyzer penetrations, Condition D provides the appropriate Required Actions.
C.1 and C.2 With one or more penetration flow paths with one PCIV inoperable, the inoperable valve must be restored to (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-20 Revision 2
PPL Rev. 10 PCIVs B 3.6.1.3 BASES ACTIONS C.1 and C.2 (continued)
OPERABLE status or the affected penetration flow path must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action C.1 must be completed within the 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the relative stability of the closed system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. The closed system must meet the requirements of Reference 6. For conditions where the PCIV and the closed system are inoperable, the Required Actions of TRO 3.6.4, Condition B apply. For the Excess Flow Check Valves (EFCV), the Completion Time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is reasonable considering the instrument and the small pipe diameter of penetration (hence, reliability) to act as a penetration isolation boundary and the small pipe diameter of the affected penetrations. In the event the affected penetration flow path is isolated in accordance with Required Action C. 1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident are isolated. The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the valves are operated under administrative controls and the probability of their misalignment is low.
Condition C is modified by a Note indicating that this Condition is only applicable to penetration flow paths with only one PCIV. For penetration flow paths with two PCIVs and the H 2 0 2 Analyzer penetration, Conditions A, B, and D provide the appropriate Required Actions.
Required Action C.2 is modified by a Note that applies to valves and blind flanges located in high radiation areas and allows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-21 Revision 3
PPL Rev. 10 PCIVs B 3.6.1.3 BASES ACTIONS C.1 and C.2 (continued) restricted. Therefore, the probability of misalignment of these valves, once they have been verified to be in the proper position, is low.
D.1 and D.2 With one or more H20 2 Analyzer penetrations with one or both PCIVs inoperable, the inoperable valve(s) must be restored to OPERABLE status or the affected penetration flow path must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action D.1 must be completed within the 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the unique design of the H 20 2 Analyzer penetrations. The containment isolation barriers for these penetrations consist of two PCIVs and a closed system. In addition, the Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the relative stability of the closed system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. In the event the affected penetration flow path is isolated in accordance with Required Action D.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident are isolated. The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the valves are operated under administrative controls and the probability of their misalignment is low.
When an H20 2 Analyzer penetration PCIV is to be closed and deactivated in accordance with Condition D, this must be accomplished by pulling the fuse for the power supply, and either determinating the power cables at the solenoid valve, or jumpering of the power side of the solenoid to ground.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-21 a Revision 0
PPL Rev. 10 PCIVs B 3.6.1.3 BASES ACTIONS D.1 and D.2 (continued)
The OPERABILITY requirements for the closed system are discussed in Technical Requirements Manual (TRM)
Bases 3.6.4. In the event that either one or both of the PCIVs and the closed system are inoperable, the Required Actions of TRO 3.6.4, Condition B apply.
Condition D is modified by a Note indicating that this Condition is only applicable to the H20 2 Analyzer penetrations.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-21 b Revision 0
PPL Rev. 10 PCIVs B 3.6.1.3 BASES ACTIONS (continued) E.1 With the secondary containment bypass leakage rate not within limit, the assumptions of the safety analysis may not be met.
Therefore, the leakage must be restored to within limit within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. Restoration can be accomplished by isolating the penetration that caused the limit to be exceeded by use of one closed and de-activated automatic valve, closed manual valve, or blind flange. When a penetration is isolated, the leakage rate for the isolated penetration is assumed to be the actual pathway leakage through the isolation device. If two isolation devices are used to isolate the penetration, the leakage rate is assumed to be the lesser actual pathway leakage of the two devices. The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time is reasonable considering the time required to restore the leakage by isolating the penetration and the relative importance of secondary containment bypass leakage to the overall containment function.
F. 1 In the event one or more containment purge valves are not within the purge valve leakage limits, purge valve leakage must be restored to within limits. The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Completion Time is reasonable, considering that one containment purge valve remains closed, except as controlled by SR 3.6.1.3.1 so that a gross breach of containment does not exist.
G.1 and G.2 If any Required Action and associated Completion Time cannot be met in MODE 1, 2, or 3, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and to MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-22 Revision 2
PPL Rev. 10 PCIVs B 3.6.1.3 BASES ACTIONS (continued) H.1 and H.2 If any Required Action and associated Completion Time cannot be met, the unit must be placed in a condition in which the LCO does not apply. If applicable, action must be immediately initiated to suspend operations with a potential for draining the reactor vessel (OPDRVs) to minimize the probability of a vessel draindown and subsequent potential for-fission product release.
Actions must continue until OPDRVs are suspended or valve(s) are restored to OPERABLE status. If suspending an OPDRV would result in closing the residual heat removal (RHR) shutdown cooling isolation valves, an alternative Required Action is provided to immediately initiate action to restore the valve(s) to OPERABLE status. This allows RHR to remain in service while actions are being taken to restore the valve.
SURVEILLANCE REQUIREMENTS SR 3.6.1.3.1 This SR ensures that the primary containment purge valves are closed as required or, ifopen, open for an allowable reason. If a purge valve is open in violation of this SR, the valve is considered inoperable. If the inoperable valve is not otherwise known to have excessive leakage when closed, it is not considered to have leakage outside of limits. The SR is also modified by Note 1, stating that primary containment purge valves are only required to be closed in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, the purge valves may not be capable of closing before the pressure pulse affects systems downstream of the purge valves, or the release of radioactive material will exceed limits prior to the purge valves closing. At other times when the purge valves are required to be capable of closing (e.g., during handling of irradiated fuel), pressurization concerns are not present and the purge valves are allowed to be open. The SR is modified by Note 2 stating that the SR is not required to be met when the purge valves are open for the stated reasons. The Note states that these valves may be opened for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open. The vent and purge valves are capable of closing in the environment following (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-23 Revision 2
PPL Rev. 10 PCIVs B 3.6.1.3 BASES SURVEILLANCE REQUIREMENTS SR 3.6.1.3.1 (continued) a LOCA. Therefore, these valves are allowed to be open for limited periods of time. The 31 day Frequency is consistent with other PCIV requirements discussed in SR 3.6.1.3.2.
SR 3.6.1.3.2 This SR verifies that each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits.
This SR does not require any testing or valve manipulation.
Rather, it involves verification that those PCIVs outside primary containment, and capable of being mispositioned, are in the correct position. Since verification of valve position for PCIVs outside primary containment is relatively easy, the 31 day Frequency was chosen to provide added assurance that the PCIVs are in the correct positions.
Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable since access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in the proper position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PCIVs are open.
This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.
SR 3.6.1.3.3 This SR verifies that each primary containment manual isolation valve and blind flange that is located inside (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-24 Revision 1
PPL Rev. 10 PCIVs B 3.6.1.3 BASES SURVEILLANCE REQUIREMENTS SR 3.6.1.3.3 (continued) primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits. For PCIVs inside primary containment, the Frequency defined as "prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days" is appropriate since these PCIVs are operated under administrative controls and the probability of their misalignment is low. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing. Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable since the primary containment is inerted and access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in their proper position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time thAt the PCIVs are open.
SR 3.6.1.3.4 The traversing incore probe (TIP) shear isolation valves are actuated by explosive charges. Surveillance of explosive charge continuity provides assurance that TIP valves will actuate when required. Other administrative controls, such as those that limit the shelf life of the explosive charges, must be followed. The 31 day Frequency is based on operating experience that has demonstrated the reliability of the explosive charge continuity.
SR 3.6.1.3.5 Verifying the isolation time of each power operated and each automatic PCIV is within limits is required to demonstrate (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-25 Revision 1
PPL Rev. 10 PCIVs B 3.6.1.3 BASES SURVEILLANCE REQUIREMENTS SR 3.6.1.3.5 (continued)
OPERABILITY. MSIVs may be excluded from this SR since MSIV full closure isolation time is demonstrated by SR 3.6.1.3.7.
The isolation time test ensures that the valve will isolate in a time period less than or equal to that assumed in the Final Safety Analyses Report. The isolation time and Frequency of this SR are in accordance with the requirements of the Inservice Testing Program.
SR 3.6.1.3.6 For primary containment purge valves with resilient seals, the Appendix J Leakage Rate Test Interva! of 24 months is sufficient.
The acceptance criteria for these valves is defined in the Primary Containment Leakage Rate Testing Program, 5.5.12.
The SR is modified by a Note stating that the primary containment purge valves are only required to meet leakage rate testing requirements in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, purge valve leakage must be minimized to ensure offsite radiological release is within limits. At other times when the purge valves are required to be capable of closing (e.g., during handling of irradiated fuel), pressurization concerns are not present and the purge valves are not required to meet any specific leakage criteria.
SR 3.6.1.3.7 Verifying that the isolation time of each MSIV is within the specified limits is required to demonstrate OPERABILITY. The isolation time test ensures that the MSIV will isolate in a time period that does not exceed the times assumed in the DBA analyses. This ensures that the calculated radiological consequences of these events remain within regulatory limits.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-26 Revision 3
PPL Rev. 10 PCIVs B 3.6.1.3 BASES SURVEILLANCE REQUIREMENTS SR 3.6.1.3.7 (continued)
The Frequency of this SR is in accordance with the requirements of the Inservice Testing Program.
SR 3.6.1.3.8 Automatic PCIVs close on a primary containment isolation signal to prevent leakage of radioactive material from primary containment following a DBA. This SR ensures that each automatic PCIV will actuate to its isolation position on a primary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.1.5 overlaps this SR to provide complete testing of the safety function.
The 24 month Frequency was developed considering it is prudent that some of these Surveillances be performed only during a unit outage since isolation of penetrations could eliminate cooling water flow and disrupt the normal operation of some critical components.
Operating experience has shown that these components usually pass this Surveillance when performed at the 24 month Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
SR 3.6.1.3.9 This SR requires a demonstration that a representative sample of reactor instrumentation line excess flow check valves (EFCV) are OPERABLE by verifying that the valve actuates to check flow on a simulated instrument line break. As defined in FSAR Section 6.2.4.3.5 (Reference 4), the conditions under which an EFCV will isolate, simulated instrument line breaks are at flow rates which develop a differential pressure of between 3 psid and 10 psid. This SR provides assurance that the instrumentation line EFCVs will perform its design function to check flow. No specific valve leakage limits are specified because no specific leakage limits are defined in the FSAR. The 24 month Frequency is based on the need to perform some of these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. The representative sample consists of an approximate equal number of EFCVs such that each EFCV is tested at least once every 10 years (nominal). The nominal 10 year interval is based on other performance-based testing programs, such as Inservice Testing (snubbers) and Option B to 10 CFR 50, Appendix J. In addition, the EFCVs in the sample are representative of the various plant configurations, models, sizes and operating environments. This ensures that any potential common problem with a specific type or application of EFCV is (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-27 Revision 3
PPL Rev. 10 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.9 (continued)
REQUIREMENTS detected at the earliest possible time. EFCV failures will be evaluated to determine ifadditional testing in that test interval is warranted to ensure overall reliability and that failures to isolate are very infrequent.
Therefore, testing of a representative sample was concluded to be acceptable from a reliability standpoint (Reference 7).
SR 3.6.1.3.10 The TIP shear isolation valves are actuated by explosive charges. An in place functional test is not possible with this design. The explosive squib is removed and tested to provide assurance that the valves will actuate when required. The replacement charge for the explosive squib shall be from the same manufactured batch as the one fired or from another batch that has been certified by having one of the batch successfully fired. The Frequency of 24 months on a STAGGERED TEST BASIS is considered adequate given the administrative controls on replacement charges and the frequent checks of circuit continuity (SR 3.6.1.3.4).
SR 3.6.1.3.11 This SR ensures that the leakage rate of secondary containment bypass leakage paths is less than the specified leakage rate. This provides assurance that the assumptions in the radiological evaluations of Reference 4 are met. The secondary containment leakage pathways and Frequency are defined by the Primary Containment Leakage Rate Testing Program. This SR simply imposes additional acceptance criteria. A note is added to this SR which states that these valves are only required to meet this leakage limit in MODES 1, 2, and 3. In the other MODES, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required.
SR 3.6.1.3.12 The analyses in References 1 and 4 are based on the specified leakage rate. Leakage through each MSIV must be < 100 scfh for anyone MSIV and < 300 scfh for total leakage through the MSIVs combined with the Main Steam Line Drain Isolation Valve, HPCI Steam Supply Isolation Valve and the RCIC Steam Supply Isolation Valve. The MSIVs can be tested at either > Pt (24.3 psig) or Pa (48.6 psig). Main Steam Line Drain Isolation, HPCI and RCIC Steam Supply Line Isolation Valves, are tested at Pa (48.6 psig). A note is added to this SR which states that these valves are only required to meet this leakage limit in MODES 1, 2, and 3. In the other (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-28 Revision 7
PPL Rev. 10 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.12 (continued)
REQUIREMENTS conditions, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required. The Frequency is required by the Primary Containment Leakage Rate Testing Program.
SR 3.6.1.3.13 Surveillance of hydrostatically tested lines provides assurance that the calculation assumptions of Reference 2 are met. The acceptance criteria for the combined leakage of all hydrostatically tested lines is 3.3 gpm when tested at 1.1 Pa, (53.46 psig). The combined leakage rates must be demonstrated in accordance with the leakage rate test Frequency required by the Primary Containment Leakage Testing Program.
As noted in Table B 3.6.1.3-1, PCIVs associated with this SR are not Type C tested. Containment bypass leakage is prevented since the line terminates below the minimum water level in the suppression chamber. These valves are tested in accordance with the IST Program. Therefore, these valves leakage is not included as containment leakage.
This SR has been modified by a Note that states that these valves are only required to meet the combined leakage rate in MODES 1, 2, and 3, since this is when the Reactor Coolant System is pressurized and primary containment is required. In some instances, the valves are required to be capable of automatically closing during MODES other than MODES 1, 2, and 3. However, specific leakage limits are not applicable in these other MODES or conditions.
REFERENCES 1. FSAR, Chapter 15.
- 2. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).
- 3. 10 CFR 50, Appendix J, Option B.
- 4. FSAR, Section 6.2.
- 5. NEDO-30851-P-A, "Technical Specification Improvement Analyses for BWR Reactor Protection System," March 1988.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-29 Revision 5
PPL Rev. 10 PCIVs B 3.6.1.3 BASES REFERENCES (continued) 6. Standard Review Plan 6.2.4, Rev. 1, September 1975.
- 7. NEDO-32977-A, "Excess Flow Check Valve Testing Relaxation," June 2000.
SUSQUEHANNA - UNIT 2 TS / B 3.6-29a Revision 0
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 1 of 10)
Isolation Signal LCO Plant System Valve Number Valve Description Type of Valve 3.3.6.1 Function No.
(Maximum Isolation
__________ __________________ _________ Time_(Seconds))
Containment 2-57-199 (d) ILRT Manual N/A Atmospheric 2-57-200 (d) ILRT Manual N/A Control HV-25703 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25704 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25705 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25711 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25713 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25714 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25721 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25722 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25723 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25724 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25725 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)
HV-25766'(a) Suppression Pool Cleanup Automatic Valve 2.b, 2.d (35)
HV-25768 (a) Suppression Pool Cleanup Automatic Valve 2.b, 2.d (30)
SV-2571 00 A Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-2571 00 B Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-257101 A Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-2571 01 B Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-257102 A Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-257102 B Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-257103 A Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-257103 B Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-257104 Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-257105 Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-257106 Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-257107 Containment Radiation Detection Automatic Valve 2.b, 2.d, 2.f Syst SV-25734 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25734 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25736 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25736 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25737 Nitroaen Makeup Automatic Valve 2.b. 2.d. 2.e SUSQUEHANNA - UNIT 2 TS / B 3.6-30 Revision 2
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Paae 2 of 10)
Isolation Signal LCO Plant System Valve Number Valve Description Type of Valve 3.3.6.1 Function NO.
(Maximum Isolation Time (Seconds))
Containment SV-25738 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e Atmospheric SV-25740 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d Control SV-25740 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d (continued) SV-25742 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25742 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25750 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25750 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25752 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25752 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25767 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e SV-25774 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25774 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25776 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25776 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25780 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25780 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25782 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25782 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-25789 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e Containment 2-26-072 (d) Containment Instrument Gas Manual Check N/A Instrument Gas 2-26-074 (d) Containment Instrument Gas Manual Check N/A 2-26-152 (d) Containment Instrument Gas Manual Check N/A 2-26-154 (d) Containment Instrument Gas Manual Check N/A 2-26-164 (d) Containment Instrument Gas Manual Check N/A HV-22603 Containment Instrument Gas Automatic Valve 2.c, 2.d (20)
SV-22605 Containment Instrument Gas Automatic Valve 2.c, 2.d SV-22651 Containment Instrument Gas Automatic Valve 2.c, 2.d SV-22654 A Containment Instrument Gas Power Operated N/A SV-22654 B Containment Instrument Gas Power Operated N/A SV-22661 Containment Instrument Gas Automatic Valve 2.b, 2.d SV-22671 Containment Instrument Gas Automatic Valve 2.b, 2.d Core Spray HV-252F001 A (b)(c) CS Suction Power Operated N/A HV-252F001 B (b)(c) CS Suction Power Operated N/A HV-252F005 A CS Injection Power Operated N/A HV-252F005 B CS Injection Power Operated N/A HV-252F006 A CS Injection Air Operated N/A" Check Valve HV-252F006 B CS Injection Air Operated N/A Check Valve HV-252F01 5 A (b)(c) CS Test Automatic Valve 2.c, 2.d (80)
HV-252F015 B (b)(c) CS Test Automatic Valve 2.c, 2.d (80)
HV-252F031 A (b)(c) CS Minimum Recirculation Flow Power Operated N/A HV-252F031 B (b)(c) CS Minimum Recirculation Flow Power Operated N/A SUSQUEHANNA - UNIT 2 TS / B 3.6-31 Revision 3
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 3 of 10)
Isolation Signal LCO Plant System Valve Number Valve Description Type of Valve 3.3.6.1 Function No.
(Maximum Isolation Time (Seconds))
Core Spray HV-252F037 A CS Injection Power Operated N/A (continued) (Air)
HV-252F037 B CS Injection Power Operated N/A (Air)
XV-252F018 A Core Spray Excess Flow N/A Check Valve XV-252F01 8 B Core Spray Excess Flow N/A Check Valve Demin Water 2-41-017 (d) Demineralized Water Manual N/A 2-41-018 (d) Demineralized Water Manual N/A HPCI 2-55-038 (d) HPCI Injection Manual N/A 255F046 (b) (c) (d) HPCI Minimum Recirculation Flow Manual Check N/A 255F049 (a) (d) HPCI Manual Check N/A HV-255F002 HPCI Steam Supply Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g, (50)
HV-255F003 HPCI Steam Supply Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g, (50)
HV-255F006 HPCI Injection Power Operated N/A HV-255F012 (b) (c) HPCI Minimum Recirculation Flow Power Operated N/A HV-255F042 (b) (c) HPCI Suction Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g, (90)
HV-255F066 (a) HPCI Turbine Exhaust Power Operated N/A HV-255F075 HPCI Vacuum Breaker Automatic Valve 3.b, 3.d, (15)
HV-255F079 HPCI Vacuum Breaker Automatic Valve 3.b, 3.d, (15)
HV-255F100 HPCI Steam Supply Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g, (6)
XV-255F024 A HPCI Excess Flow N/A Check Valve XV-255F024 B HPCI Excess Flow N/A Check Valve XV-255F024 C HPCI Excess Flow N/A Check Valve XV-255F024 D HPCI Excess Flow N/A Check Valve Liquid Radwaste HV-26108 Al Liquid Radwaste Automatic Valve 2.b, 2.d (15)
Collection HV-26108 A2 Liquid Radwaste Automatic Valve 2.b, 2.d (15)
HV-26116 Al Liquid Radwaste Automatic Valve 2.b, 2.d (15)
HV-26116 A2 Liquid Radwaste Automatic Valve 2.b, 2.d (15)
Nuclear Boiler 241FO10 A (d) Feedwater Manual Check N/A 241FOl0 B (d) Feedwater Manual Check N/A 241 F039 A (d) Feedwater Isolation Valve Manual Check N!A 241 F039 B (d) Feedwater Isolation Valve Manual Check N/A 241818 A (d) Feedwater Isolation Valve Manual Check N/A 241818 B (d) Feedwater Isolation Valve Manual Check N/A SUSQUEHANNA - UNIT 2 TS / B 3.6-32 Revision 1
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 4 of 10)
Isolation Signal LCO Valve Number Valve Description Type of Valve aximum Isolation Plant System Time (Seconds))
Nuclear Boiler HV-241 F01 6 MSL Drain Automatic Valve 1.a, 1b, 1.c, 1d, 1.e (continued) (10)
HV-241F019 MSL Drain Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (15)
HV-241 F022 A MSIV Automatic Valve 1.a, lb, 1.c, 1.d, 1.e (5)
HV-241 F022 B MSIV Automatic Valve 1 a, 1.b, 1.c, 1.d, 1.e (5)
HV-241 F022 C MSIV Automatic Valve 1.a, 1.b, 1.c, 1d, 1.e (5)
HV-241 F022 D MSiV Automatic Valve i a, 1.b, 1.c, i.d, i.e (5)
HV-241 F028 A MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)
HV-241 F028 B MSIV Automatic Valve 1.a, lb, 1.c, 1.d, i.e (5)
HV-241 F028 C MSIV Automatic Valve l.a, 1.b, 1.c, i.d, i.e (5)
HV-241 F028 D MSIV Automatic Valve 1 .a, 1.b, 1.c, 1 .d, 1.e (5)
HV-241 F032 A Feedwater Isolation Valve Power Operated N/A Check Valves HV-241 F032 B Feedwater Isolation Valve Power Operated N/A Check Valves XV-241 F009 Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F070 A Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F070 B Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F070 C Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F070 D Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F071 A Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F071 B Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F071 C Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F071 D Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F072 A Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F072 B Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F072 C Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F072 D Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F073 A Nuclear Boiler EFCV Excess Flow N/A Check Valve SUSQUEHANNA - UNIT 2 TS / B 3.6-33 Revision 2
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 5 of 10)
Isolation Signal LCO Plant System Valve Number Valve Description Type of Valve 3,a3,.1 Function No.
(Maximum Isolation Timen (Seconds))
Nuclear Boiler XV-241 F073 B Nuclear Boiler EFCV Excess Flow N/A (continued) Check Valve XV-241 F073 C Nuclear Boiler EFCV Excess Flow N/A Check Valve XV-241 F073 D Nuclear Boiler EFCV Excess Flow N/A Check Valve Nuclear Boiler XV-24201 Nuclear Boiler Vessel Instrument Excess Flow N/A Vessel Check Valve Instrumentation XV-24202 Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F041 Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F043 A Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F043 B Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F045 A Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F045 B Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F047 A Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F047B Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F051 A Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F051 B Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F051 C Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F051 D Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F053 A Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F053 B Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve
'XV-242F053 C Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F053 D Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242FO55 Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F057 Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 A Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 B Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve SUSQUEHANNA- UNIT 2 TS / B 3.6-34 Revision 1
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 6 of 10)
Isolation Signal LCO Plant System Valve Number Valve Description Type of Valve 3.3.6.1 Function No.
(Maximum Isolation Time (Seconds))
Nuclear Boiler XV-242F059 C Nuclear Boiler Vessel Instrument Excess Flow N/A Vessel Check Valve Instrumentation XV-242F059 D Nuclear Boiler Vessel Instrument Excess Flow N/A (continued) Check Valve XV-242F059 E Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 F Nuclear Boiler Vessel Instrument Excess Flow N/A
.Check Valve XV-242F059 G Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 H Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 L Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 M Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 N Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 P Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 R Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 S Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 T Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F059 U Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve XV-242F061 Nuclear Boiler Vessel Instrument Excess Flow N/A Check Valve RB Chilled Water HV-28781 Al RB Chilled Water Automatic Valve 2.c, 2.d (40)
System HV-28781 A2 RB Chilled Water Automatic Valve 2.c, 2.d (40)
HV-28781 B1 RB Chilled Water Automatic Valve 2.c, 2.d (40)
HV-28781 B2 RB Chilled Water Automatic Valve 2.c, 2.d (40)
HV-28782 Al RB Chilled Water Automatic Valve 2.c, 2.d (12)
HV-28782 A2 RB Chilled Water Automatic Valve 2.c, 2.d (12)
HV-28782 B1 RB Chilled Water Automatic Valve 2.c, 2.d (12)
HV-28782 B2 RB Chilled Water Automatic Valve 2.c, 2.d (12)
HV-28791 Al RB Chilled Water Automatic Valve 2.b, 2.d (15)
HV-28791 A2 RB Chilled Water Automatic Valve 2.b, 2.d (15)
HV-28791 B1 RB Chilled Water Automatic Valve 2.b, 2.d (15)
HV-28791 B2 RB Chilled Water Automatic Valve 2.b, 2.d (15)
HV-28792 Al RB Chilled Water Automatic Valve 2.b, 2.d (8)
HV-28792 A2 RB Chilled Water Automatic Valve 2.b, 2.d (8)
HV-28792 B1 RB Chilled Water Automatic Valve 2.b, 2.d(8)
SUSQUEHANNA - UNIT 2 TS / B 3.6-35 Revision 3
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 7 of 10)
Isolation Signal LCO Plant System Valve Number Valve Description Type of Valve 3.3.6.1 Function No.
(Maximum Isolation Time (Seconds))
RB Chilled Water HV-28792 62 RB Chilled Water Automatic Valve 2.b, 2.d (8)
System (continued)
RBCCW HV-21313 RBCCW Automatic Valve 2.c, 2.d (30)
HV-21314 RBCCW Automatic Valve 2.c, 2.d (30)
HV-21345 RBCCW Automatic Valve 2.c, 2.d (30)
HV-21346 RBCCW Automatic Valve 2.c, 2.d (30)
RCIC 2-49-020 (d) RCIC Injection Manual N/A 249F021 (b) (c) (d) RCIC Minimum Recirculation Flow Manual Check N/A 249F028 (a) (d) RCIC Vacuum Pump Discharge Manual N/A 249F040 (a) (d) RCIC Turbine Exhaust Manual N/A FV-249F019 (b) (c) RCIC Minimum Recirculation Flow Power Operated N/A HV-249F007 RCIC Steam Supply Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f, 4.g (20)
HV-249F008 RCIC Steam Supply Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f, 4.g (20)
HV-249F013 RCIC Injection Power Operated N/A HV-249F031 (b) (c) RCIC Suction Power Operated N/A HV-249F059 (a) RCIC Turbine Exhaust Power Operated N/A HV-249F060 (a) RCIC Vacuum Pump Discharge Power Operated N/A HV-249F062 RCIC Vacuum Breaker Automatic Valve 4.b, 4.d (10)
HV-249F084 RCIC Vacuum Breaker Automatic Valve 4.b, 4.d (10)
HV-249F088 RCIC Steam Supply Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f, 4.g (12)
XV-249F044 A RCIC Excess Flow N/A Check Valve XV-249F044 B RCIC Excess Flow N/A Check Valve XV-249F044 C RCIC Excess Flow N/A Check Valve XV-249F044 D RCIC Excess Flow N/A Check Valve Reactor 243F01 3 A (d) Recirculation Pump Seal Water Manual Check N/A Recirculation 243F013 B (d) Recirculation Pump Seal Water Manual Check N/A HV-243F019 Reactor Coolant Sample Automatic Valve 2.b (9)
HV-243F020 Reactor Coolant Sample Automatic Valve 2.b (2)
XV-243F003 A Reactor Recirculation Excess Flow N/A Check Valve XV-243F003 B Reactor Recirculation Excess Flow N/A Check Valve XV-243FO04 A Reactor Recirculation Excess Flow N/A Check Valve XV-243F004 B Reactor Recirculation Excess Flow N/A Check Valve SUSQUEHANNA - UNIT 2 TS / B 3.6-36 Revision 2
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 8 of 10)
Isolation Signal LCO Pant System Valv Number Valve Description Type oValve 3.3.6.1 Function No.
(Maximum Isolation Time (Seconds))
Reactor XV-243F009 A Reactor Recirculation Excess Flow N/A Recirculation Check Valve (continued) XV-243F009 B Reactor Recirculation ExcessFlow N/A Check Valve XV-243F009 C Reactor Recirculation Excess Flow N/A Check Valve XV-243F009 D Reactor Recirculation Excess Flow N/A Check Valve XV-243F010 A Reactor Recirculation Excess Flow N/A Check Valve XV-243F010 B Reactor Recirculation Excess Flow N/A Check Valve XV-243F01 0 C Reactor Recirculation Excess Flow N/A Check Valve XV-243F010 D Reactor Recirculation - Excess Flow N/A Check Valve XV-243F011 A Reactor Recirculation Excess Flow N/A Check Valve XV-243F01 1 B Reactor Recirculation Excess Flow N/A Check Valve XV-243F01 1 C Reactor Recirculation Excess Flow N/A Check Valve XV-243F01 1 D Reactor Recirculation Excess Flow N/A Check Valve XV-243F012 A Reactor Recirculation Excess Flow N/A Check Valve XV-243F012 B Reactor Recirculation Excess Flow N/A Check Valve XV-243F012 C Reactor Recirculation Excess Flow N/A Check Valve XV-243F01 2 D Reactor Recirculation Excess Flow N/A Check Valve XV-243F017 A Recirculation Pump Seal Water Excess Flow N/A Check Valve XV-243F017 B Recirculation Pump Seal Water Excess Flow N/A Check Valve XV-243F040 A Reactor Recirculation Excess Flow N/A Check Valve XV-243F040 B Reactor Recirculation Excess Flow N/A Check Valve XV-243F040 C Reactor Recirculation Excess Flow N/A Check Valve XV-243F040 D Reactor Recirculation Excess Flow N/A Check Valve XV-243F057 A Reactor Recirculation Excess Flow N/A
__ Check Valve XV-243F057 B Reactor Recirculation Excess Flow N/A Check Valve Residual Heat HV-251 F004 A (b) (c) RHR - Suppression Pool Suction Power Operated N/A Removal HV-251 F004 B (b) (c) RHR - Suppression Pool Suction Power Operated N/A HV-251 F004 C (b) (c) RHR - Suppression Pool Suction Power Operated N/A SUSQUEHANNA,- UNIT 2 TS / B 3.6-37 Revision 2'
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 9 of 10)
Isolation Signal LCO Plant System Valve Number Valve Description Type of Valve 3.3.6.1 Function No.
(Maximum Isolation Time (Seconds))
Residual Heat HV-251 F004 D(b) (c) RHR - Suppression Pool Suction Power Operated N/A Removal HV-251 F007 A (b) (c) RHR - Minimum Recirculation Power Operated N/A (continued) HV-251 F007 B (b) (c) RHR - Minimum Recirculation Power Operated N/A HV-251 F008 RHR - Shutdown Cooling Suction Automatic Valve 6.a, 6.b, 6.c (52)
HV-251 F009 RHR - Shutdown Cooling Suction Automatic Valve 6.a, 6.b, 6.c (52)
HV-251 F01 I A (b) (d) RHR - Suppression Pool Cooling Manual N/A HV-251 F01 1 B (b) (d) RHR - Suppression Pool Cooling Manual N/A HV-251 F01 5 A (f) RHR - Shutdown Cooling Power Operated N/A Return/LPCI Injection HV-251 F015 B (f) RHR - Shutdown Cooling Power Operated N/A Return/LPCI Injection HV-251 F016 A (b) RHR - Drywell Spray Automatic Valve 2.c, 2.d (90)
HV-251 F01 6 B (b) RHR - Drywell Spray Automatic Valve 2.c, 2.d (90)
HV-251F022 RHR - Reactor Vessel Head Spray Automatic Valve 2.d, 6.a, 6.b, 6.c (30)
HV-251 F023 RHR - Reactor Vessel Head Spray Automatic Valve 2.d, 6.a, 6.b, 6.c (20)
HV-251 F028 A (b) RHR - Suppression Pool Automatic Valve 2.c, 2.d (90)
Cooling/Spray HV-251 F028 B (b) RHR - Suppression Pool Automatic Valve 2.c, 2.d (90)
Cooling/Spray HV-251 F050 A (g) RHR - Shutdown Cooling Air Operated N/A Return/LPCI Injection Check Valve HV-251 F050 B (g) RHR - Shutdown Cooling Air Operated N/A Return/LPCI Injection Check Valve HV-251 F103 A (b) RHR Heat Exchanger Vent Power Operated N/A HV-251 F103 B (b) RHR Heat Exchanger Vent Power Operated N/A HV-251 F122 A (g) RHR - Shutdown Cooling Power Operated N/A Return/LPCI Injection (Air)
HV-251 F122 B (g) RHR - Shutdown Cooling Power Operated N/A Retum/LPCI Injection (Air)
PSV-25106 A (b) (d) RHR- Relief Valve Discharge Relief Valve N/A PSV-25106 B (b) (d) RHR- Relief Valve Discharge Relief Valve N/A PSV-251 F126 (d) RHR- Shutdown Cooling Suction Relief Valve N/A XV-25109 A RHR Excess Flow N/A Check Valve XV-25109 B RHR Excess Flow N/A Check Valve XV-25109 C RHR Excess Flow N/A Check Valve XV-25109 D RHR Excess Flow N/A Check Valve RWCU HV-244F001 (a) RWCU Suction Automatic Valve 5.a, 5.b, 5.c, 5d, 5.f, 5.g (30)
HV-244F004 (a) RWCU Suction Automatic Valve 5.a, 5.b, 5.c, 5.d, 5.e, 5f, 5.g (30)
XV-24411 A RWCU Excess Flow N/A Check Valve I XV-24411 B RWCU Excess Flow N/A Check Valve I SUSQUEHANNA - UNIT 2 TS / B 3.6-38 Revision 3
PPL Rev. 10 PCIVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Paae 10 of 10)
Isolation Signal LCO Plant System Valve Number Valve Description Type of Valve 3.3.6.1 Function (Maximum No.
Isolation Time (Seconds))
RWCU XV-24411 C RWCU Excess Flow N/A (continued) Check Valve XV-24411 D RWCU Excess Flow N/A Check Valve XV-244F046 RWCU Excess Flow N/A Check Valve HV-24182 A RWCU Return Power Operated N/A HV-24182 B RWCU Return Power Operated N/A SLCS 248F007 (a) (d) SLCS Manual Check N/A HV-248F006 (a) SLCS Power Operated N/A Check Valve TIP System C51-J004 A (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)
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-J004 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) '
TIP System C51-J004 A (Shear TIP Shear Valves Squib Valve N/A (continued) Valve)
C51-J004 B (Shear TIP Shear Valves Squib Valve N/A Valve)
C51-J004 C (Shear TIP Shear Valves Squib Valve N/A Valve)
C51-J004 D (Shear TIP Shear Valves Squib Valve N/A Valve)
C51-J004 E (Shear TIP Shear Valves Squib Valve N/A Valve)
(a) Isolation barrier remains filled or a water seal remains in the line post-LOCA, isolation valve is tested with water.
Isolation valve leakage is not included in 0.60 L. total Type B and C tests.
(b) Redundant isolation boundary for this valve is provided by the closed system whose integrity is verified by the Leakage Rate Test Program. This footnote does not apply to valve 255F046 (HPCI) when the associated PCIV, HV255F012 is closed and deactivated. Similarly, this footnote does not apply to valve 249F021 (RC IC) when its associated PC IV, FV249F019 is closed and deactivated.
(c) Containment Isolation Valves are not Type C tested. Containment bypass leakage is prevented since the line terminates 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, (PCIV Position) does riot apply since these are relief valves, check valves, manual valves or deactivated and closed.
(e) The containment isolation barriers for the penetration associated with this valve consists of two PCIVs and a closed system. The closed system provides a redundant isolation boundary for both PCIVs, and its integrity is required 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 the Leakage Rate Test Program.
(g) These valves are not required to be 10 CFR 50, Appendix J tested since the HV-251 F015A(B) valves and a closed system form the 10 CFR 50, Appendix J boundary. These valves form a high/low pressure interface and are pressure tested in accordance with the pressure test program.
SUSQUEHANNA - UNIT 2 TS / B 3.6-39 Revision 7
PPL Rev. 3 SCIVs B 3.6.4.2 B 3.6 CONTAINMENT SYSTEMS B 3.6.4.2 Secondary Containment Isolation Valves (SCIVs)
BASES BACKGROUND The function of the SCIVs, in combination with other accident mitigation systems, is to limit fission product release during and following postulated Design Basis Accidents (DBAs) (Ref. 1). Secondary containment isolation within the time limits specified for those isolation valves designed to close automatically ensures that fission products that leak from primary containment into secondary containment following a DBA, or that are released during certain operations when primary containment is not required to be OPERABLE or take place outside primary containment, are maintained within the secondary containment boundary.
The OPERABILITY requirements for SCIVs help ensure that an adequate secondary containment boundary is maintained during and after an accident by minimizing potential paths to the environment. These isolation devices consist of either passive devices or active (automatic) devices. Manual valves or dampers, de-activated automatic valves or dampers secured in their closed position (including check valves with flow through the valve secured), and blind flanges are considered passive devices.
Automatic SCIVs close on a secondary containment isolation signal to establish a boundary for untreated radioactive material within secondary containment following a DBA or other accidents.
Other non-sealed penetrations which cross a secondary containment boundary are isolated by the use of valves in the closed position or blind flanges.
APPLICABLE The SCIVs must be OPERABLE to ensure the secondary containment SAFETY barrier to fission product releases is established. The principal accidents for ANALYSES which the secondary containment boundary is required are a loss of coolant accident (Ref. 1) and a fuel handling accident inside secondary containment (Ref. 2). The secondary containment performs no active function in response to either of these limiting events, but the boundary (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-90 Revision 3
PPL Rev. 3 SCIVs B 3.6.4.2 BASES APPLICABLE established by SCIVs is required to ensure that leakage from the primary SAFETY containment is processed by the Standby Gas Treatment (SGT) System ANALYSES before being released to the environment.
(continued)
Maintaining SCIVs OPERABLE with isolation times within limits ensures that fission products will remain trapped inside secondary containment so that they can be treated by the SGT System prior to discharge to the environment.
SCIVs satisfy Criterion 3 of the NRC Policy Statement (Ref. 3).
LCO SCIVs that form a part of the secondary containment boundary are required to be OPERABLE. Depending on the configuration of the secondary containment only specific SCIVs are required. The SCIV safety function is related to control of offsite radiation releases resulting from DBAs.
The automatic isolation valves are considered OPERABLE when their isolation times are within limits and the valves actuate on an automatic isolation signal. The valves covered by this LCO, along with their associated stroke times, are listed in Table B 3.6.4.2-1.
The normally closed isolation valves or blind flanges are considered OPERABLE when manual valves are closed or open in accordance with appropriate administrative controls, automatic SCIVs are deactivated and
-secured in their closed position, or blind flanges are in place. These passive isolation valves or devices are listed in Table B3.6.4.2-2. Penetrations closed with sealants are considered part of the secondary containment boundary and are not considered penetration flow paths.
In MODES 4 and 5, the probability and consequences of these events are APPLICABILITY In MODES 1, 2, and 3, a DBA could lead to a fission product release to the primary containment that leaks to the secondary containment. Therefore, the OPERABILITY of SCIVs is required.
In MODES 4 and 5, the probability and consequences of these events are reduced due to pressure and temperature (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-91 Revision 1
PPL Rev. 3 SCIVs B 3.6.4.2 BASES APPLICABILITY limitations in these MODES. Therefore, maintaining SCIVs OPERABLE is (continued) not required in MODE 4 or 5, except for other situations under which significant radioactive releases can be postulated, such as during operations with a potential for draining the reactor vessel (OPDRVs), during CORE ALTERATIONS, or during movement of irradiated fuel assemblies in the secondary containment. Moving irradiated fuel assemblies in the secondary containment may also occur in MODES 1, 2, and 3.
ACTIONS The ACTIONS are modified by three Notes. The first Note allows penetration flow paths to be unisolated intermittently under administrative controls. These controls consist of stationing a dedicated operator, who is in continuous communication with the control room, at the controls of the isolation device. In this way, the penetration can be rapidly isolated when a need for secondary containment isolation is indicated.
The second Note provides clarification that for the purpose of this LCO separate Condition entry is allowed for each penetration flow path. This is acceptable, since the Required Actions for each Condition provide appropriate compensatory actions for each inoperable SCIV. Complying with the Required Actions may allow for continued operation, and subsequent inoperable SCIVs are governed by subsequent Condition entry and application of associated Required Actions.
The third Note ensures appropriate remedial actions are taken, if necessary, if the affected system(s) are rendered inoperable by an inoperable SCIV.
A.1 and A.2 In the event that there are one or more required penetration flow paths with one required SCIV inoperable, the affected penetration flow path(s) must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure.
Isolation barriers that meet this criterion are a closed and de-activated automatic SCIV, a closed manual valve, and a blind flange. For penetrations isolated in (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-92 Revision .1
PPL Rev. 3 SCIVs B 3.6.4.2 BASES ACTIONS A.1 and A.2 (continued) accordance with Required Action A. 1, the device used to isolate the penetration should be the closest available device to secondary containment. The Required Action must be completed within the 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Completion Time. The specified time period is reasonable considering the time required to isolate the penetration, and the probability of a DBA, which requires the SCIVs to close, occurring during this short time is very low.
For affected penetrations that have been isolated in accordance with Required Action A.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that secondary containment penetrations required to be isolated following an accident, but no longer capable of being automatically isolated, will be in the isolation position should an event occur. The Completion Time of once per 31 days is appropriate because the valves are operated under administrative controls and the probability of their misalignment is low. This Required Action does not require any testing or device manipulation. Rather, it involves verification that the affected penetration remains isolated.
Condition A is modified by a Note indicating that this Condition is only applicable to those penetration flow paths with two SCIVs. For penetration flow paths with one SCIV, Condition C provides the appropriate Required Actions.
Required Action A.2 is modified by a Note that applies to devices located in high radiation areas and allows them to be verified closed by use of administrative controls. Allowing verification by administrative controls is considered acceptable, since access to these areas is typically restricted.
Therefore, the probability of misalignment, once they have been verified to be in the proper position, is low.
B.1 With two SCIVs in one or more penetration flow paths inoperable, the affected penetration flow path must be isolated within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. The method of isolation must (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-93 Revision 1
PPL Rev. 3 SCIVs B 3.6.4.2 BASES ACTIONS B.1 (continued) include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time is reasonable considering the time required to isolate the penetration and the probability of a DBA, which requires the SCIVs to close, occurring during this short time, is very low.
The Condition has been modified by a Note stating that Condition B is only applicable to penetration flow paths with two isolation valves. For penetration flow paths with one SCIV, Condition C provides the appropriate Required Actions.
C.1 and C.2 With one or more required penetration flow paths with one required SCIV inoperable, the inoperable valve must be restored to OPERABLE status or the affected penetration flow path must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action C.1 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. The Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is reasonable considering the relative stability of the system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting secondary containment OPERABILITY during MODES 1, 2, and 3.
In the event the affected penetration flow path is isolated in accordance with Required Action C. 1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that secondary containment penetrations required to be isolated following an accident are isolated.
The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the (continued).
SUSQUEHANNA - UNIT 2 TS / B 3.6-94 Revision 1
PPL Rev. 3 SCIVs B 3.6.4.2 BASES ACTIONS C.1 and C.2 (continued) valves are operated under administrative controls and the probability of their misalignment is low.
Condition C is modified by a Note indicating that this Condition is only applicable to penetration flow paths with only one SCIV. For penetration flow paths with two SCIVs, Conditions A and B provide the appropriate Required Actions.
Required Action C.2 is modified by a Note that applies to valves and blind flanges located in high radiation areas and allows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted.
Therefore, the probability of misalignment of these valves, once they have been verified to be in the proper position, is low.
D.1 and D.2 If any Required Action and associated Completion Time cannot be met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and to MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
E.1, E.2, and E.3 If any Required Action and associated Completion Time are not met, the plant must be placed in a condition in which the LCO does not apply. If applicable, CORE ALTERATIONS and the movement of irradiated fuel assemblies in the secondary containment must be immediately suspended.
Suspension of these activities shall not preclude completion of movement of a component to a safe position. Also, if applicable, actions must be immediately initiated to suspend OPDRVs in order to minimize the probability of a vessel draindown and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-95 Revision 1
'1~SK PPL Rev. 3 SCIVs B 3.6.4.2 BASES ACTIONS E.1, E.2, and E.3 (continued)
Required Action E.1 has been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODE 4 or 5, LCO 3.0.3 would not specify any action. If moving fuel while in MODE 1, 2, or 3, the fuel movement is independent of reactor operations.
Therefore, in either case, inability to suspend movement of irradiated fuel assemblies would not be a sufficient reason to require a reactor shutdown.
SURVEILLANCE SR 3.6.4.2.1 REQUIREMENTS This SR verifies that each secondary containment manual isolation valve and blind flange that is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside of the secondary containment boundary is within design limits. This SR does not require any testing or valve manipulation.
Rather, it involves verification (typically visual) that those required SCIVs in secondary containment that are capable of being mispositioned are in the correct position.
Since these SCIVs are readily accessible to personnel during normal operation and verification of their position is relatively easy, the 31 day Frequency was chosen to provide added assurance that the SCIVs are in the correct positions.
Two Notes have been added to this SR. The first Note applies to valves and blind flanges located in high radiation areas and allows them to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these SCIVs, once they have been verified to be in the proper position, is low.
A second Note has been included to clarify that SCIVs that are open under administrative controls are not required to meet the SR during the time the SCIVs are open.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-96 Revision 2
PPL Rev. 3 SCIVs B 3.6.4.2 BASES SURVEILLANCE SR 3.6.4.2.2 REQUIREMENTS (continued) SCIVs with maximum isolation times specified in Table B 3.6.2.4-1 are tested every 92 days to verify that the isolation time is within limits to demonstrate OPERABILITY. Automatic SCIVs without maximum isolation times specified in Table B 3.6.4.2-1 are tested under the requirements of SR 3.6.4.2.3. The isolation time test ensures that the SCIV will isolate in a time period less than or equal to that assumed in the safety analyses.
SR 3.6.4.2.3 Verifying that each automatic required SCIV closes on a secondary containment isolation signal is required to prevent leakage of radioactive material from secondary containment following a DBA or other accidents.
This SR ensures that each automatic SCIV will actuate to the isolation position on a secondary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.2.5 overlaps this SR to provide complete testing of the safety function. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
REFERENCES 1. FSAR, Section 6.2.
- 2. FSAR, Section 15.
- 3. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).
SUSQUEHANNA - UNIT 2 TS / B 3.6-97 Revision 1
PPL Rev. 3 SCIVs B 3.6.4.2 Table B 3.6.4.2-1 Secondary Containment Ventilation System Automatic Isolation Dampers (Page 1 of 1)
Reactor Maximum Building Valve Number Valve Description Type of Valve Isolation Blng ITime Zone* (Seconds)
I HD-1 7586 A&B Supply System Dampers Automatic Isolation Damper 10.0 I HD-1 7524 A&B Filtered Exhaust System Dampers Automatic Isolation Damper 10.0 I HD-17576A&B Unfiltered Exhaust System Automatic Isolation Damper 10.0 II HD-27586 A&B Supply System Dampers Automatic Isolation Damper 10.0 II HD-27524 A&B Filtered Exhaust System Dampers Automatic Isolation Damper 10.0 II HD-27576 A&B Unfiltered Exhaust System Automatic Isolation Damper 10.0 III . HD-1 7564 A&B Supply System Dampers Automatic Isolation Damper 14.0 III HD-17514 A&B Filtered Exhaust System Dampers Automatic Isolation Damper 6.5 III HD-17502 A&B Unfiltered Exhaust System Automatic Isolation Damper 6.0 III HD-27564 A&B Supply System Dampers Automatic Isolation Damper 14.0 III HD-27514 A&B Filtered Exhaust System Dampers Automatic Isolation Damper 6.5 III HD-27502 A&B Unfiltered Exhaust System Automatic Isolation Damper 6.0 N/A HD-17534A Zone 3 Airlock 1-606 Automatic Isolation Damper N/A N/A HD-17534B Zone 3 Airlock 1-611 Automatic Isolation Damper N/A N/A HD-17534C Zone 3 Airlock 1-707 Automatic Isolation Damper N/A N/A HD-17534D Zone 3 Airlock 1-803 Automatic Isolation Damper N/A N/A HD-17534E Zone 3 Airlock 1-805 Automatic Isolation Damper N/A N/A HD-17534F Zone 3 Airlock 1-617 Automatic Isolation Damper N/A N/A HD-17534H Zone 3 Airlock 1-618 Automatic Isolation Damper N/A N/A HD-27534A Zone 3 Airlock 11-606 Automatic Isolation Damper N/A N/A HD-27534C Zone 3 Airlock 11-707 Automatic Isolation Damper N/A N/A HD-27534D Zone 3 Airlock 11-803 Automatic Isolation Damper N/A N/A HD-27534E Zone 3 Airlock 11-805 Automatic Isolation Damper N/A N/A HD-27534G Zone 3 Airlock C-806 Automatic Isolation Damper N/A N/A HD-27534H Zone 3 Airlock 11-618 Automatic Isolation Damper N/A N/A HD-275341 Zone 3 Airlock 11-609 Automatic Isolation Damper N/A SUSQUEHANNA - UNIT 2 TS / B 3.6-98 Revision 1
B 3.6.4.2 Table B 3.6.4.2-2 , , ,ý,;
Secondary Containment Ventilation System Passive Isolation Valves or Devices (Page 1 of 2)
Device Number Device Description Area/Elev. Required Position X-28-2-3000 Utility Penetration to Unit 1 East Stairwell Yard/670 Blind Flanged X-29-2-44 SDHR System to Fuel Pool Cooling Yard/670 Blind Flanged X-29-2-45 SDHR System to Fuel Pool Cooling Yard/670 Blind Flanged X-29-2-46 Temporary Chiller to RBCW Yard/670 Blind Flanged X-29-2-47 Temporary Chiller to R BCW Yard/670 Blind Flanged X-29-2-48 Utility Penetration to Unit 1 RR Bay Yard/670 Capped X-33-2-3000 Utility Penetration to Unit 2 East Stairwell Yard/670 Blind Flanged X-28-2-3000 Utility Penetration to Unit 1 East Stairwell 28/670 Blind Flanged X-29-2-48 Utility Penetration to Unit 1 RR Bay 29/670 Capped X-33-2-3000 Utility Penetration to Unit 2 East Stairwell 33/670 Blind Flanged X-29-3-54 Utility Penetration to Unit 1 RBCCW Hx Area 27/683 Blind Flanged X-29-3-55 Utility Penetration to Unit 1 RBCCW Hx Area 27/683 Blind Flanged X-29-5-95 Temporary Chiller to Unit 1 RBCW 29/749 Blind Flanged X-29-5-96 Temporary Chiller to Unit 1 RBCW 29/749 Blind Flanged X-29-5-91 Temporary Chiller to Unit 2 RBCW 33/749 Blind Flanged X-29-5-92 Temporary Chiller to Unit 2 RBCW 33/749 Blind Flanged X295-97 Utility Penetration from Unit 1 RR Bay to Unit 2 Elev. 331749 Capped 749 X-27-6-42 Diamond Plate Cover over Floor Penetration 27/779' Installed X-27-6-92 Instrument Tubing Stubs 27/779' Capped X-29-7-4 1" Spare Conduit Threaded Plug 29/818' Installed X-30-6-72 Instrument Tubing Stubs 30/779' Capped X-30-6-1002 Stairwell #214 Rupture Disc 30/779' Installed Intact X-30-6-1003 Airlock 11-609 Rupture Disc 30/779' Installed Intact X-25-6-1008 Airlock 1-606 Rupture Disc 25/779' Installed Intact X-29-4-102 Penetration at Door 433 29/719' Blind Flange Installed X-29-4-103 Penetration at Door 433 29/719' Blind Flange Installed X-29-4-102 Penetration at Door 433 33/719' Blind Flange Installed X-29-4-103 Penetration at Door 433 33/719' Blind Flange Installed 1S2104 N2 Purge Line to Ul Containment Spectacle Flange 29/683' Blind Side Installed 2S2104 N2 Purge Line to U2 Containment Spectacle Flange 34/672' Blind Side Installed XD-17513 Isolation damper for Railroad Bay Zone Ill HVAC 29/799' Position is dependent on Railroad Supply Bay alignment XD-17514 Isolation damper for Railroad Bay Zone IIIHVAC 29/719' Position is dependent on Railroad Exhaust Bay alignment XD-1 2301 PASS Air Flow Damper 11/729' Closed Damper XD-22301 PASS Air Flow Damper 22/729' Closed Damper 161827 HPCI Blowout Steam Vent Drain Valve 25/645' Closed Manual Isolation Valve 161828 RCIC Blowout Steam Vent Drain Valve 28/645' Closed Manual Isolation Valve 161829 'A' RHR Blowout Steam Vent Drain Valve 29/645' Closed Manual Isolation Valve 161830 'B' RHR Blowout Steam Vent Drain Valve 28/645' Closed Manual Isolation Valve 261820 RCIC Blowout Steam Vent Drain Valve 33/645' Closed Manual Isolation Valve 261821 'A' RHR Blowout Steam Vent Drain Valve 34/645' Closed Manual Isolation Valve 261822 'B' RHR Blowout Steam Vent Drain Valve 33/645' Closed Manual Isolation Valve SUSQUEHANNA - UNIT 2 TS / B 3.6-99 Revision 3
PPL Rev. 3 SCIVs B 3.6.4.2 Table B 3.6.4.2-2 /
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Secondary Containment Ventilation System Passive Isolation Valves or Deices (Page 2 of 2)
Device Number Device Description Area/Elev. Required Position 187388 RBCW Temp Chiller Discharge Iso Vlv 29/670 Closed Manual Isolation Valve 187389 RBCW Ternp Chiller Supply Iso Vlv 29/670 Closed Manual Isolation Valve 187390 RBCW Temp Chiller Supply Drain VIv 29/670 Closed Manual Isolation Valve 187391 RBCW Temp Chiller Discharge Drain Vlv 29/670 Closed Manual Isolation Valve 110176 SDHR Supply Drain Vlv 29/670 Closed Manual Isolation Valve 110186 SDHR Discharge Drain VIv 29/670 Closed Manual Isolation Valve 110180 SDHR Supply Vent VIv 29/749 Closed Manual Isolation Valve 110181 SDHR Discharge Fill Vlv 27/749 Closed Manual Isolation Valve 110182 SDHR Discharge Vent Vlv 27/749 Closed Manual Isolation Valve 110187 SDHR Supply Fill VIv 29/749 Closed Manual Isolation Valve 210186 SDHR Supply Drain Vlv 33/749 Closed Manual Isolation Valve 210187 SDHR Supply Vent VIv 33/749 Closed Manual Isolation Valve 210191 SDHR Discharge Vent VIv 30/749 Closed Manual Isolation Valve 210192 SDHR Discharge Drain VIv 30/749 Closed Manual Isolation Valve 210193 SDHR Discharge Vent Vlv 33/749 Closed Manual Isolation Valve SUSQUEHANNA - UNIT 2 TS / B 3.6-99a Revision 0