ML14205A013
| ML14205A013 | |
| Person / Time | |
|---|---|
| Site: | Susquehanna  |
| Issue date: | 07/17/2014 |
| From: | Susquehanna |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| Download: ML14205A013 (38) | |
Text
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MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2014-35377 USER INFORMATION:
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DOCUMENTS TYPE: TSBI
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SSES MANUAL Manual Name:
TSBI Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL CON"TROLLED Table Of Contents Issue Date:
07/16/2014 Procedure Name Rev TEXT LOES 118
Title:
LIST OF EFFECTIVE SECTIONS Issue Date 07/16/2014 Change ID Change Number TEXT TOC
Title:
TABLE OF CONTENTS 23 07/02/2014 TEXT 2.1.1 5
Title:
SAFETY LIMITS (SLS)
REACTOR TEXT 2.1.2 1
Title:
SAFETY LIMITS (SLS)
REACTOR 05/06/2009 CORE SLS 10/04/2007 COOLANT SYSTEM (RCS)
PRESSURE S TEXT 3.0 3
08/20/2009
Title:
LIMITING CONDITION FOR OPERATION (LCO)
APPLICABILITY TEXT 3.1.1
Title:
REACTIVITY TEXT 3.1.2
Title:
REACTIVITY TEXT 3.1.3
Title:
REACTIVITY TEXT 3.1.4
Title:
REACTIVITY TEXT 3.1.5
Title:
REACTIVITY 1
CONTROL SYSTEMS 0
CONTROL SYSTEMS 2
CONTROL SYSTEMS 4
CONTROL SYSTEMS 1
CONTROL SYSTEMS 04/18/2006 SHUTDOWN MARGIN (SDM) 11/15/2002 REACTIVITY ANOMALIES 01/19/2009 CONTROL ROD OPERABILITY 01/30/2009 CONTROL ROD SCRAM TIMES 07/06/2005 CONTROL ROD SCRAM ACCUMULATORS TEXT 3.1.6 3
02/24/2014
Title:
REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Pagel of 8 Report Date: 07/17/14 Page I of
.8 Report Date: 07/17/14
SSES MANUAL Manual Name:
TSB1 Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.1.7 3
04/23/2008
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 2
04/23/2008
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
04/23/2008
Title:
POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE (LHGR)
TEXT 3.3.1.1 6
02/24/2014
Title:
INSTRUMENTATION 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 4
02/24/2014
Title:
INSTRUMENTATION CONTROL ROD BLOCK INSTRUMENTATION TEXT 3.3.2.2 2
04/05/2010
Title:
INSTRUMENTATION FEEDWATER MAIN TURBINE HIGH WATER LEVEL TRIP INSTRUMENTATION TEXT 3.3.3.1
Title:
INSTRUMENTATION 9
02/28/2013 POST ACCIDENT MONITORING (PAM)
INSTRUMENTATION TEXT 3.3.3.2 1
04/18/2005
Title:
INSTRUMENTATION REMOTE SHUTDOWN SYSTEM TEXT 3.3.4.1 2
02/24/2014
Title:
INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT)
INSTRUMENTATIO W
Page 2 of 8
Report Date: 07/17/14
SSES MANUAL Manual Name:
TSBI Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.3.4.2 0
11/15/2002
Title:
INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP (ATWS-RPT)
INSTRUMENTATION TEXT 3.3.5.1 3
08/20/2009
Title:
INSTRUMENTATION EMERGENCY CORE COOLING SYSTEM (ECCS)
INSTRUMENTATION TEXT 3.3.5.2 0
11/15/2002
Title:
INSTRUMENTATION REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM INSTRUMENTATION TEXT 3.3.6.1 7
03/31/2014
Title:
INSTRUMENTATION PRIMARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.6.2 4
09/01/2010
Title:
INSTRUMENTATION SECONDARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.7.1
Title:
INSTRUMENTATION INSTRUMENTATION 2
10/27/2008 CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS)
SYSTEM TEXT 3.3.8.1 2
12/17/2007
Title:
INSTRUMENTATION LOSS OF POWER (LOP)
INSTRUMENTATION TEXT 3.3.8.2
Title:
INSTRUMENTATION 0
11/15/2002 REACTOR PROTECTION SYSTEM (RPS)
ELECTRIC POWER MONITORING TEXT 3.4.1 4
04/27/2010
Title:
RECIRCULATION LOOPS OPERATING TEXT 3.4.2 3
10/23/2013
Title:
JET PUMPS TEXT 3.4.3 3
01/13/2012
Title:
REACTOR COOLANT SYSTEM RCS SAFETY RELIEF VALVES S/RVS TEXT 3.4.4
Title:
11/15/2002 SYSTEM (RCS)
RCS OPERATIONAL LEAKAGE Page3 of 8
Report Date: 07/17/14 Page 3 of
.8 Report Date: 07/17/14
SSES MANUAL Manual Name:
TSB1 Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.4.5 1
01/16/2006
Title:
RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE TEXT 3.4.6 4
02/19/2014
Title:
RCS LEAKAGE DETECTION INSTRUMENTATION TEXT 3.4.7 2
10/04/2007
Title:
RCS SPECIFIC ACTIVITY TEXT 3.4. 8
Title:
REACTOR COOLANT HOT SHUTDOWN TEXT 3.4.9
Title:
REACTOR COOLANT COLD SHUTDOWN 2
SYSTEM (RCS) 1 SYSTEM (RCS) 03/28/2013 RESIDUAL HEAT REMOVAL (RHR)
SHUTDOWN COOLING SYSTEM 03/28/2013 RESIDUAL HEAT REMOVAL (RHR)
SHUTDOWN COOLING SYSTEM0 TEXT 3.4.10 3
04/23/2008
Title:
RCS PRESSURE AND TEMPERATURE (P/T) LIMITS TEXT 3.4. 11
Title:
REACTOR COOLANT TEXT 3.5.1 0
11/15/2002 SYSTEM (RCS)
REACTOR STEAM DOME PRESSURE 4
07/16/2014
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS)
AND REACTOR SYSTEM ECCS -
OPERATING TEXT 3.5.2 0
11/15/2002
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS)
AND REACTOR SYSTEM ECCS -
SHUTDOWN TEXT 3.5.3 3
02/24/2014
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS)
AND REACTOR SYSTEM RCIC SYSTEM CORE ISOLATION COOLING (RCIC)
CORE ISOLATION COOLING (RCIC)
CORE ISOLATION COOLING (RCIC)
TEXT 3.6.1.1
Title:
02/24/2014 TEXT 3.6.1.2 1
04/23/2008
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK Page4 of 8 Report Date: 07/17/14 Page 4 of 3
Report Date: 07/17/14
SSES MANUAL Manual Name:
TSB1 Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.6.1.3
Title:
CONTAINMENT TEXT 3.6.1.4
Title:
CONTAINMENT TEXT 3.6.1.5
Title:
CONTAINMENT TEXT 3.6.1.6
Title:
CONTAINMENT TEXT 3.6.2.1
Title:
CONTAINMENT TEXT 3.6.2.2
Title:
CONTAINMENT TEXT 3.6.2.3
Title:
CONTAINMENT TEXT 3.6.2.4
Title:
CONTAINMENT TEXT 3.6.3.1
Title:
CONTAINMENT TEXT 3.6.3.2
Title:
CONTAINMENT TEXT 3.6.3.3
Title:
CONTAINMENT TEXT 3.6.4.1
Title:
CONTAINMENT 11 07/02/2014 SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS) 1 04/23/2008 SYSTEMS CONTAINMENT PRESSURE 1
10/05/2005 SYSTEMS DRYWELL AIR TEMPERATURE 0
11/15/2002 SYSTEMS SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKERS 2
04/23/2008 SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE 0
11/15/2002 SYSTEMS SUPPRESSION POOL WATER LEVEL 1
01/16/2006 SYSTEMS RESIDUAL HEAT REMOVAL (RHR)
SUPPRESSION POOL COOLING 0
11/15/2002 SYSTEMS RESIDUAL HEAT REMOVAL (RHR)
SUPPRESSION POOL SPRAY 2
06/13/2006 SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS 1
04/18/2005 SYSTEMS DRYWELL AIR FLOW SYSTEM 1
02/28/2013 SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION 10 04/25/2014 SYSTEMS SECONDARY CONTAINMENT Page5 of 8
Report Date: 07/17/14 Page 5 of
.8 Report Date: 07/17/14
SSES MANUAL Manual Name:
TSBl Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT I MANUAL TEXT 3.6.4.2 9
04/25/2014
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
Title:
PLANT SYSTEMS ULTIMATE HEAT 4
04/05/2010 RESIDUAL HEAT REMOVAL SERVICE WATER (RHRSW)
SYSTEM AND THE SINK (UHS)
TEXT 3.7.2
Title:
PLANT TEXT 3.7.3
Title:
PLANT TEXT 3.7.4
Title:
PLANT 2
02/11/2009 SYSTEMS EMERGENCY SERVICE WATER (ESW)
SYSTEM 1
01/08/2010 SYSTEMS CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS)
SYSTEM 0
11/15/2002 SYSTEMS CONTROL ROOM FLOOR COOLING SYSTEM TEXT 3.7.5
Title:
PLANT SYSTEMS 1
10/04/2007 MAIN CONDENSER OFFGAS TEXT 3.7.6
Title:
PLANT TEXT 3.7.7
Title:
PLANT 2
04/23/2008 SYSTEMS MAIN TURBINE BYPASS SYSTEM 1
10/04/2007 SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL TEXT 3.7.8
Title:
PLANT SYSTEMS 0
04/23/2008 TEXT 3.8.1 7
02/24/2014
Title:
ELECTRICAL POWER SYSTEMS AC SOURCES -
OPERATING TEXT 3.8.2 0
11/15/2002
Title:
ELECTRICAL POWER SYSTEMS AC SOURCES -
SHUTDOWN Pages of 8
Report Date: 07/17/14 Page 6 of a
Report Date: 07/17/14
SSES MANUAL Manual Name:
TSB1 Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3. 8.3
Title:
ELECTRICAL TEXT 3.8.4
Title:
ELECTRICAL TEXT 3.8.5
Title:
ELECTRICAL TEXT 3.8.6
Title:
ELECTRICAL TEXT 3.8.7
Title:
ELECTRICAL TEXT 3.8.8
Title:
ELECTRICAL TEXT 3.9.1
Title:
REFUELING C TEXT 3.9.2
Title:
REFUELING TEXT 3.9.3
Title:
REFUELING TEXT 3.9.4
Title:
REFUELING C TEXT 3.9.5
Title:
REFUELING TEXT 3.9.6
Title:
REFUELING (
POWER SYST POWER SYST POWER SYST POWER SYST POWER.SYST POWER SYST DPERATIONS
)PERATIONS
)PERATIONS OPERATIONS
)PERATIONS
)PERATIONS 4
10/23/2013
'EMS DIESEL FUEL OIL, LUBE OIL, AND STARTING AIR 3
01/19/2009
'EMS DC SOURCES -
OPERATING 1
12/14/2006
'EMS DC SOURCES -
SHUTDOWN 1
12/14/2006
'EMS BATTERY CELL PARAMETERS 1
10/05/2005
'EMS DISTRIBUTION SYSTEMS -
OPERATING 0
11/15/2002
'EMS DISTRIBUTION SYSTEMS -
SHUTDOWN 0
11/15/2002 REFUELING EQUIPMENT INTERLOCKS 1
09/01/2010 REFUEL POSITION ONE-ROD-OUT INTERLOCK 0
11/15/2002 CONTROL ROD POSITION 0
11/15/2002 CONTROL ROD POSITION INDICATION 0
11/15/2002 CONTROL ROD OPERABILITY -
REFUELING 1
10/04/2007 REACTOR PRESSURE VESSEL (RPV)
WATER LEVEL Page7 of ~
Report Date: 07/17/14 Page 7 of
-8 Report Date: 07/17/14
SSES MANUIAL Manual Name:
TSBI Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.9.7 0
11/15/2002
Title:
REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR)
HIGH WATER LEVEL TEXT 3.9.8 0
11/15/2002
Title:
REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR)
LOW WATER LEVEL TEXT 3.10.1
Title:
SPECIAL TEXT 3.10.2
Title:
SPECIAL TEXT 3.10.3
Title:
SPECIAL TEXT 3.10.4
Title:
SPECIAL TEXT 3.10.5
Title:
SPECIAL TEXT 3.10.6
Title:
SPECIAL TEXT 3.10.7
Title:
SPECIAL TEXT 3.10.8
Title:
SPECIAL OPERATIONS OPERATIONS OPERATIONS OPERATIONS OPERATIONS OPERATIONS OPERATIONS OPERATIONS 1
01/23/2008 INSERVICE LEAK AND HYDROSTATIC TESTING OPERATION 0
11/15/2002 REACTOR MODE SWITCH INTERLOCK TESTING 0
'11/15/2002 SINGLE CONTROL ROD WITHDRAWAL -
HOT SHUTDOWN 0
11/15/2002 SINGLE CONTROL ROD WITHDRAWAL -
COLD SHUTDOWN 0
11/15/2002 SINGLE CONTROL ROD DRIVE (CRD)
REMOVAL -
REFUELING 0
11/15/2002 MULTIPLE CONTROL ROD WITHDRAWAL REFUELING 1
04/18/2006 CONTROL ROD TESTING -
OPERATING 1
04/12/2006 SHUTDOWN MARGIN (SDM)
TEST -
REFUELING Pages of 8 Report Date: 07/17/14 Page 8 of
-8 Report Date: 07/17/14
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision TOC Table of Contents 23 B 2.0 SAFETY LIMITS BASES Page B 2.0-1 0
Page TS / B 2.0-2 3
Page TS / B 2.0-3 5
Page TS / B 2.0-4 3
Page TS / B 2.0-5 5
Page TS / B 2.0-6 1
Pages TS / B 2.0-7 through TS / B 2.0-9 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 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 B 3.1-15 0
Page TS / B 3.1-16 1
Pages B 3.1-17 through 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 / B 3.1-29 1
Pages B 3.1-30 through B 3.1-33 0
Pages TS / B 3.3-34 through TS / B 3.3-36 1
Page TS / B 3.1-37 2
Page TS / B 3.1-38 3
Pages TS / B 3.1-39 and TS / B 3.1-40 2
Page TS / B 3.1-40a 0
Pages TS / B 3.1-41 and TS / B 3.1-42 2
SUSQUEHANNA
- UNIT 1 TS/BLOES-1 Revision 118 SUSQUEHANNA - UNIT 1 TS / B LOES-1 Revision 118
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Page TS / B 3.1.43 1
Page TS / B 3.1-44 0
Page TS / B 3.1-45 3
Pages TS / B 3.1-46 through TS / B 3.1-49 1
Page TS/ B 3.1-50 0
Page TS / B 3.1-51 3
B 3.2 POWER DISTRIBUTION LIMITS BASES Page TS / B 3.2-1 2
Pages TS / B 3.2-2 and TS / B 3.2-3 3
Pages TS / B 3.2-4 and TS / B 3.2-5 2
Page TS / B 3.2-6 3
Page B 3.2-7 1
Pages TS / B 3.2-8 and TS / B 3.2-9 3
Page TS / B 3.2.10 2
Page TS / B 3.2-11 3
Page TS / B 3.2-12 1
Page TS / B 3.2-13 2
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 3.3-7a 1
Page TS / B 3.3-8 5
Pages TS / B 3.3-9 through TS / B 3.3-12 3
Pages TS / B 3.3-12a 1
Pages TS / B 3.3-12b and TS / B 3.3-12c 0
Page TS / B 3.3-13 1
Page TS / B 3.3-14 3
Pages TS / B 3.3-15 and TS / B 3.3-16 1
Pages TS / B 3.3-17 and TS / B 3.3-18 4
Page TS / B 3.3-19 1
Pages TS / B 3.3-20 through TS / B 3.3-22 2
Page TS / B 3.3-22a 0
Pages TS / B 3.3-23 and TS / B 3.3-24 2
Pages TS / B 3.3-24a and TS / B 3.3-24b 0
Page TS / B 3.3-25 3
Page TS / B 3.3-26 2
Page TS / B 3.3-27 1
Page TS / B 3.3-28 3
Page TS / B 3.3-29 4
Page TS / B 3.3-30 3
Page TS / B 3.3-30a 0
SUSQUEHANNA - UNIT 1SUSQUEHANNA-UNIT 1 TS / B LOES-2 Revision 118 TS / B LOES-2 Revision 118
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Page TS / B 3.3-31 4
Page TS / B 3.3-32 5
Pages TS / B 3.3-32a 0
Page TS / B 3.3-32b 1
Page TS / B 3.3-33 5
Page TS / B 3.3-33a 0
Page TS / B 3.3-34 1
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
Page TS / B 3.3-39 2
Pages TS / B 3.3-40 through TS / B 3.3-43 1
Page TS / B 3.3-44 4
Pages TS / B 3.3-44a and TS / B 3.3-44b 0
Page TS / B 3.3-45 3
Pages TS / B 3.3-45a and TS / B 3.3-45b 0
Page TS / B 3.3-46 3
Pages TS / B 3.3-47 2
Pages TS / B 3.3-48 through TS / B 3.3-51 3
Pages TS / B 3.3-52 and TS / B 3.3-53 2
Page TS / B 3-3-53a 0
Page TS / B 3.3-54 5
Page TS / B 3.3-55 2
Pages TS / B 3.3-56 and TS / B 3.3-57 1
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Pages TS / B 3.3-62 and TS / B 3.3-63 0
Pages TS / B 3.3-64 and TS / B 3.3-65 2
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Page TS / B 3.3-68 4
Page TS / B 3.3-69 5
Pages TS / B 3.3-70 4
Page TS / B 3.3-71 3
Pages TS / B 3.3-72 and TS I B 3.3-73 2
Page TS / B 3.3-74 3
Page TS / B 3.3-75 2
Page TS / B 3.3-75a 6
Page TS / B 3.3-75b 7
Page TS / B 3.3-75c 6
Pages B 3.3-76 through B 3.3-77 0
Page TS / B 3.3-78 1
SUSQUEHANNA-UNITi TS / B LOES-3 Revision 118 SUSQUEHANNA - UNIT 1 TS / B LOES-3 Revision 118
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Pages B 3.3-79 through B 3.3-81 0
Page TS / B 3.3-82 2
Page B 3.3-83 0
Pages B 3.3-84 and B 3.3-85 1
Page B 3.3-86 0
Page B 3.3-87 1
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Page B 3.3-89 1
Page TS / B 3.3-90 1
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Pages TS / B 3.3-110 and TS / B 3.3-111 0
Pages TS / B 3.3-112 and TS / B 3.3-112a 1
Pages TS / B 3.3-113 through TS / B 3.3-115 1
Page TS / B 3.3-116 3
Page TS I B 3.3-117 1
Pages TS / B 3.3-118 through TS / B 3.3-122 0
Pages TS / B 3.3-123 and TS / B 3.3-124 1
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Pages B 3.3-135 through B 3.3-137 0
Page TS / B 3.3-138 1
Pages 8 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 3.3-159and TS / B 3.3-160 1
Page TS / B 3.3-161 2
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 through TS / B 3.3-167 2
SUSQUEHANNA - UNIT 1 TS I B LOES-4 Revision 118 SUSQUEHANNA - UNIT 1 TS / B LOES-4 Revision 118
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Pages TS / B 3.3-168 and TS / B 3.3-169 1
Page TS / B 3.3-170 3
Page TS / B 3.3-171 2
Pages TS / B 3.3-172 through TS / B 3.3-177 1
Pages TS / B 3.3-178 and TS / B 3.3-179 2
Page TS / B 3.3-179a 2
Pages TS / B 3.3-179b and TS / B 3.3-179c 0
Page TS / B 3.3-180 1
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PPL Rev. 4 ECCS-Operating B 3.5.1 B 3.5 B 3.5.1 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ECCS-Operating BASES BACKGROUND The ECCS is designed, in conjunction with the primary and secondary containment, to limit the release of radioactive materials to the environment following a loss of coolant accident (LOCA). The ECCS uses two independent methods (flooding and spraying) to cool the core during a LOCA. The ECCS network consists of the High Pressure Coolant Injection (HPCI) System, the Core Spray (CS) System, the low pressure coolant injection (LPCI) mode of the Residual Heat Removal (RHR)
System, and the Automatic Depressurization System (ADS). The suppression pool provides the required source of water for the ECCS.
Although no credit is taken in the safety analyses for the condensate storage tank (CST), it is capable of providing a source of water for the HPCI and CS systems.
On receipt of an initiation signal, ECCS pumps automatically start; simultaneously, the system aligns and the pumps inject water, taken either from the CST or suppression pool, into the Reactor Coolant System (RCS) as RCS pressure is overcome by the discharge pressure of the ECCS pumps. Although the system is initiated, ADS action is delayed, allowing the operator to interrupt the timed sequence if the system is not needed.
The HPCI pump discharge pressure quickly exceeds that of the RCS, and the pump injects coolant into the vessel to cool the core. If the break is small, the HPCI System will maintain coolant inventory as well as vessel level while the RCS is still pressurized. If HPCI fails, it is backed up by ADS in combination with LPCI and CS. In this event absent operator action, the ADS timed sequence would time out and open the selected safety/relief valves (S/RVs) depressurizing the RCS, thus allowing the LPCI and CS to overcome RCS pressure and inject coolant into the vessel. If the break is large, RCS pressure initially drops rapidly and the LPCI and CS cool the core.
Water from the break returns to the suppression pool where it is used again and again. Water in the suppression pool is circulated through a heat exchanger cooled by the RHR Service Water System. Depending on the location and size of (continued)
SUSQUEHANNA - UNIT 1 B 3.5-1 Revision 0
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES BACKGROUND the break, portions of the ECCS may be ineffective; however the overall (continued) design is effective in cooling the core regardless of the size or location of the piping break. Although no credit is taken in the safety analysis for the RCIC System, it performs a similar function as HPCI, but has reduced makeup capability. Nevertheless, it will maintain inventory and cool the core while the RCS is still pressurized following a reactor pressure vessel (RPV) isolation.
All ECCS subsystems are designed to ensure that no single active component failure will prevent automatic initiation and successful operation of the minimum required ECCS equipment.
The CS System (Ref. 1) is composed of two independent subsystems.
Each subsystem consists of two motor driven pumps, a spray sparger above the core, and piping and valves to transfer water from the suppression pool to the sparger. The CS System is designed to provide cooling to the reactor core when reactor pressure is low. Upon receipt of an initiation signal, the CS pumps in both subsystems are automatically started when AC power is available. When the RPV pressure drops sufficiently, CS System flow to the RPV begins. A full flow test line is provided to route water from and to the suppression pool to allow testing of the CS System without spraying water in the RPV.
LPCI is an independent operating mode of the RHR System. There are two LPCI subsystems (Ref. 2), each consisting of two motor driven pumps and piping and valves to transfer water from the suppression pool to the RPV via the corresponding recirculation loop. The two LPCI subsystems can be interconnected via the RHR System cross tie valves; however, at least one of the two cross tie valves is maintained closed with its power removed to prevent loss of both LPCI subsystems during a LOCA. The LPCI subsystems are designed to provide core cooling at low RPV pressure. Upon receipt of an initiation signal, all four LPCI pumps are automatically started. RHR System valves in the LPCI flow path are automatically positioned to ensure the proper flow path for water from the suppression pool to inject into the recirculation loops. When the RPV pressure drops sufficiently, the LPCI flow to the RPV, via the corresponding recirculation loop, begins. The water then enters the reactor through the jet pumps.
(continued)
SUSQUEHANNA - UNIT 1 B 3.5-2 Revision 0
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES BACKGROUND Full flow test lines are provided for each LPCI subsystem to route water (continued) from the suppression pool, to allow testing of the LPCI pumps without injecting water into the RPV. These test lines also provide suppression pool cooling capability, as described in LCO 3.6.2.3, "RHR Suppression Pool Cooling."
The HPCI System (Ref. 3) consists of a steam driven turbine pump unit, piping, and valves to provide steam to the turbine, as well as piping and valves to transfer water from the suction source to the core via the feedwater system line, where the coolant is distributed within the RPV through the feedwater sparger. Suction piping for the system is provided from the CST and the suppression pool. Pump suction for HPCI is normally aligned to the CST source to minimize injection of suppression pool water into the RPV. Whenever the CST water supply is low, an automatic transfer to the suppression pool water source ensures an adequate suction head for the pump and an uninterrupted water supply for continuous operation of the HPCI System. The steam supply to the HPCI turbine is piped from a main steam line upstream of the associated inboard main steam isolation valve.
The HPCI System is designed to provide core cooling for a wide range of reactor pressures (165 psia to 1225 psia). Upon receipt of an initiation signal, the HPCI turbine stop valve and turbine control valve open and the turbine accelerates to a specified speed. As the HPCI flow increases, the turbine control valve is automatically adjusted to maintain design flow.
Exhaust steam from the HPCI turbine is discharged to the suppression pool. A full flow test line is provided to route water to the CST to allow testing of the HPCI System during normal operation without injecting water into the RPV.
The ECCS pumps are provided with minimum flow bypass lines, which discharge to the suppression pool. The valves in these lines automatically open to prevent pump damage due to overheating when other discharge line valves are closed. To ensure rapid delivery of water to the RPV and to minimize water hammer effects, all ECCS pump discharge lines are filled with water. The HPCI, LPCI and CS System discharge lines are kept full of water using a "keep fill" system that is supplied using the condensate transfer system.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-3 Revision 3
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES BACKGROUND (continued)
The ADS (Ref. 4) consists of 6 of the 16 S/RVs. It is designed to provide depressurization of. the RCS during a small break LOCA if HPCI fails or is unable to maintain required water level in the RPV. ADS operation reduces the RPV pressure to within the operating pressure range of the low pressure ECCS subsystems (CS and LPCI), so that these subsystems can provide coolant inventory makeup. Each of the S/RVs used for automatic depressurization is equipped with two gas accumulators and associated inlet check valves. The accumulators provide the pneumatic power to actuate the valves.
APPLICABLE SAFETY ANALYSES The ECCS performance is evaluated for the entire spectrum of break sizes for a postulated LOCA. The accidents for which ECCS operation is required are presented in References 5, 6, and 7. The required analyses and assumptions are defined in Reference 8. The results of these analyses are also described in Reference 9.
This LCO helps to ensure that the following acceptance criteria for the ECCS, established by 10 CFR 50.46 (Ref. 10), will be met following a LOCA, assuming the worst case single active component failure in the ECCS:
- a. Maximum fuel element cladding temperature is < 2200°F;
- b. Maximum cladding oxidation is < 0.17 times the total cladding thickness before oxidation;
< 0.01 times the hypothetical amount that would be generated if all of the metal in the cladding surrounding the fuel, excluding the cladding surrounding the plenum volume, were to react;
- d. The core is maintained in a coolable geometry; and
- e. Adequate long term cooling capability is maintained.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-4 Revision 1
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES APPLICABLE SPC performed LOCA calculations for the SPC ATRIUM'T-10 fuel design.
SAFETY The limiting single failures for the SPC analyses are discussed in ANALYSES Reference 11. For a large break LOCA, the SPC analyses identify the (continued) recirculation loop suction piping as the limiting break location. The SPC analysis identifies the failure of the LPCI injection valve into the intact recirculation loop as the most limiting single failure.
For a small break LOCA, the SPC analyses identify the recirculation loop discharge piping as the limiting break location, and a battery failure as the most severe single failure. One ADS valve failure is analyzed as a limiting single failure for events requiring ADS operation. The remaining OPERABLE ECCS subsystems provide the capability to adequately cool the core and prevent excessive fuel damage.
The ECCS satisfy Criterion 3 of the NRC Policy Statement (Ref. 15).
LCO Each ECCS injection/spray subsystem and six ADS valves are required to be OPERABLE. The ECCS injection/spray subsystems are defined as the two CS subsystems, the two LPCI subsystems, and one HPCI System.
The low pressure ECCS injection/spray subsystems are defined as the two CS subsystems and the two LPCI subsystems.
With less than the required number of ECCS subsystems OPERABLE, the potential exists that during a limiting design basis LOCA concurrent with the worst case single failure, the limits specified in Reference 10 could be exceeded. All ECCS subsystems must therefore be OPERABLE to satisfy the single failure criterion required by Reference 10.
LPCI subsystems may be considered OPERABLE during alignment and operation for decay heat removal when below the actual RHR cut in permissive pressure in MODE 3, if capable of being manually realigned (remote or local) to the LPCI mode and not otherwise inoperable. At these low pressures and decay heat levels, a reduced complement of ECCS subsystems should provide the required core cooling, thereby allowing operation of RHR shutdown cooling when necessary.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-5 Revision 2
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES (continued)
APPLICABILITY All ECCS subsystems are required to be OPERABLE during MODES 1, 2, and 3, when there is considerable energy in the reactor core and core cooling would be required to prevent fuel damage in the event of a break in the primary system piping. In MODES 2 and 3, when reactor steam dome pressure is < 150 psig, ADS and HPCI are not required to be OPERABLE because the low pressure ECCS subsystems can provide sufficient flow below this pressure. ECCS requirements for MODES 4 and 5 are specified in LCO 3.5.2, "ECCS-Shutdown."
ACTIONS A Note prohibits the application of LCO 3.0.4.b to an inoperable HPCI subsystem. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an inoperable HPCI subsystem and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance.
A. 1 If any one low pressure ECCS injection/spray subsystem is inoperable for reasons other than Condition B, the inoperable subsystem must be restored to OPERABLE status within 7 days. In this Condition, the remaining OPERABLE subsystems provide adequate core cooling during a LOCA. However, overall ECCS reliability is reduced, because a single failure in one of the remaining OPERABLE subsystems, concurrent with a LOCA, may result in the ECCS not being able to perform its intended safety function. The 7 day Completion Time is based on a reliability study (Ref. 12) that evaluated the impact on ECCS availability, assuming various components and subsystems were taken out of service. The results were used to calculate the average availability of ECCS equipment needed to mitigate the consequences of a LOCA as a function of allowed outage times (i.e., Completion Times).
B. 1 If one LPCI pump in one or both. LPCI subsystems is inoperable, the inoperable LPCI pumps must be restored to OPERABLE status within 7 days. In this Condition, the remaining OPERABLE LPCI pumps and at least one CS subsystem (continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-6 Revision 1
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES ACTIONS B.1 (continued) provide adequate core cooling during a LOCA. However, overall ECCS reliability is reduced, because a single failure in one of the remaining OPERABLE subsystems, concurrent with a LOCA, may result in the ECCS not being able to perform its intended safety function. A 7 day Completion Time is based on a reliability study cited in Reference 12 and has been found to be acceptable through operating experience.
C.1 and C.2 If the inoperable low pressure ECCS subsystem or LPCI pump(s) cannot be restored to OPERABLE status within the associated Completion Time, 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.
D.1 and D.2 If the HPCI System is inoperable and the RCIC System is verified to be OPERABLE, the HPCI System must be restored to OPERABLE status within 14 days. In this Condition, adequate core cooling is ensured by the OPERABILITY of the redundant and diverse low pressure ECCS injection/spray subsystems in conjunction with ADS. Also, the RCIC System will automatically provide makeup water at most reactor operating pressures. Verification of RCIC OPERABILITY is therefore required when HPCI is inoperable. This may be performed as an administrative check by examining logs or other information to determine if RCIC is out of service for maintenance or other reasons. It does not mean to perform the Surveillances needed to demonstrate the OPERABILITY of the RCIC System. If the OPERABILITY of the RCIC System cannot be verified, however, Condition H must be immediately entered. If a single active component fails concurrent with a design basis LOCA, there is a potential, depending on the specific failure, that the minimum required ECCS equipment (continued)
SUSQUEHANNA - UNIT 1 TS I B 3.5-7 Revision 0
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES ACTIONS D.1 and D.2 (continued) will not be available. A 14 day Completion Time is based on a reliability study cited in Reference 12 and has been found to be acceptable through operating experience.
E.1 and E.2 If Condition A or Condition B exists in addition to an inoperable HPCI System, the inoperable low pressure ECCS injection/spray subsystem or the LPCI pump(s) or the HPCI System must be restored to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. In this Condition, adequate core cooling is ensured by the OPERABILITY of the ADS and the remaining low pressure ECCS subsystems. However, the overall ECCS reliability is significantly reduced because a single failure in one of the remaining OPERABLE subsystems concurrent with a design basis LOCA may result in the ECCS not being able to perform its intended safety function. Since both a high pressure system (HPCI) and a low pressure subsystem are inoperable, a more restrictive Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is required to restore either the HPCI System or the low pressure ECCS injection/spray subsystem to OPERABLE status. This Completion Time is based on a reliability study cited in Reference 12 and has been found to be acceptable through operating experience.
F. I The LCO requires six ADS valves to be OPERABLE in order to provide the ADS function. Reference 11 contains the results of an analysis that evaluated the effect of one ADS valve being out of service. Per this analysis, operation of only five ADS valves will provide the required depressurization. However, overall reliability of the ADS is reduced, because a single failure in the OPERABLE ADS valves could result in a reduction in depressurization capability. Therefore, operation is only allowed for a limited time. The 14 day Completion Time is based on a reliability study cited in Reference 12 and has been found to be acceptable through operating experience.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-8 Revision 0
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES ACTIONS G.1 and G.2 (continued)
If Condition A or Condition B exists in addition to one inoperable ADS valve, adequate core cooling is ensured by the OPERABILITY of HPCI and the remaining low pressure ECCS injection/spray subsystem.
However, overall ECCS reliability is reduced because a single active component failure concurrent with a design basis LOCA could result in the minimum required ECCS equipment not being available. Since both a high pressure system (ADS) and a low pressure subsystem are inoperable, a more restrictive Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is required to restore either the low pressure ECCS subsystem or the ADS valve to OPERABLE status. This Completion Time is based on a reliability study cited in Reference 12 and has been found to be acceptable through operating experience.
H.1 and H.2 If any Required Action and associated Completion Time of Condition D, E, F, or G is not met, or if two or more ADS valves are inoperable, the plant must be brought to a condition 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 reactor steam dome pressure reduced to < 150 psig 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.
1.1 When multiple ECCS subsystems are inoperable, as stated in Condition I, LCO 3.0.3 must be entered immediately.
SURVEILLANCE SR 3.5.1.1 REQUIREMENTS The flow path piping has the potential to develop voids and pockets of entrained air. Maintaining the pump discharge lines of the HPCI System, CS System, and LPCI subsystems (continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-9 Revision 0
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.1 (continued)
REQUIREMENTS full of water ensures that the ECCS will perform properly, injecting its full capacity into the RCS upon demand. This will also prevent a water hammer following an ECCS initiation signal. One acceptable method of ensuring that the lines are full is to vent at the high points. The 31 day Frequency is based on the gradual nature of void buildup in the ECCS piping, the procedural controls governing system operation, and operating experience.
SR 3.5.1.2 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position since these were verified to be in the correct position prior to locking, sealing, or securing.
A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. For the HPCI System, this SR also includes the steam flow path for the turbine and the flow controller position.
The 31 day Frequency of this SR was derived from the Inservice Testing Program requirements for performing valve testing at least once every 92 days. The Frequency of 31 days is further.justified because the valves are operated under procedural control and because improper valve position would only affect a single subsystem. This Frequency has been shown to be acceptable through operating experience.
This SR is modified by a Note that allows LPCI subsystems to be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the RHR cut in permissive pressure in MODE 3, if capable of being manually realigned (remote or local) to the (continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-10 Revision 0
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.2 (continued)
REQUIREMENTS LPCI mode and not otherwise inoperable. This allows operation in the RHR shutdown cooling mode during MODE 3, if necessary.
SR 3.5.1.3 Verification every 31 days that ADS gas supply header pressure is
> 135 psig ensures adequate gas pressure for reliable ADS operation.
The accumulator on each ADS valve provides pneumatic pressure for valve actuation. The design pneumatic supply pressure requirements for the accumulator are such that, following a failure of the pneumatic supply to the accumulator, at least one valve actuations can occur with the drywell at 70% of design pressure.
The ECCS safety analysis assumes only one actuation to achieve the depressurization required for operation of the low pressure ECCS. This minimum required pressure of Ž> 135 psig is provided by the containment instrument gas system. The 31 day Frequency takes into consideration administrative controls over operation of the gas system and alarms associated with the containment instrument gas system.
SR 3.5.1.4 Verification every 31 days that at least one RHR System cross tie valve is closed and power to its operator is disconnected ensures that each LPCI subsystem remains independent and a failure of the flow path in one subsystem will not affect the flow path of the other LPCI subsystem.
Acceptable methods of removing power to the operator include opening the breaker, or racking out the breaker, or removing the breaker. If both RHR System cross tie valves are open or power has not been removed from at least one closed valve operator, both LPCI subsystems must be considered inoperable. The 31 day Frequency has been found acceptable, considering that these valves are under strict administrative controls that will ensure the valves continue to remain closed with motive power removed.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-11 Revision 1
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.1.5 Verification every 31 days that each 480 volt AC swing bus transfers automatically from the normal source to the alternate source on loss of power while supplying its respective bus demonstrates that electrical power is available to ensure proper operation of the associated LPCI inboard injection and minimum flow valves and the recirculation pump discharge and bypass valves. Therefore, each 480 volt AC swing bus must be OPERABLE for the associated LPCI subsystem to be OPERABLE. The test is performed by actuating the load test switch or by disconnecting the preferred power source to the transfer switch and verifying that swing bus automatic transfer is accomplished. The 31 day Frequency has been found to be acceptable through operating experience.
SR 3.5.1.6 Cycling the recirculation pump discharge and bypass valves through one complete cycle of full travel demonstrates that the valves are mechanically OPERABLE and provides assurance that the valves will close when required to ensure the proper LPCI flow path is'established. Upon initiation of an automatic LPCI subsystem injection signal, these valves are required to be closed to ensure full LPCI subsystem flow injection in the reactor via the recirculation jet pumps. De-energizing the valve in the closed position will also ensure the proper flow path for the LPCI subsystem. Acceptable methods of de-energizing the valve include opening the breaker, or racking out the breaker, or removing the breaker.
The specified Frequency is once during reactor startup before THERMAL POWER is > 25% RTP. However, this SR is modified by a Note that states the Surveillance is only required to be performed if the last performance was more than 31 days ago. Therefore, implementation of this Note requires this test to be performed during reactor startup before exceeding 25% RTP. Verification during reactor startup prior to reaching
> 25% RTP is an exception to the normal Inservice Testing Program generic valve cycling Frequency of 92 days, but is considered acceptable due to (continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-12 Revision 0
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.6 (continued)
REQUIREMENTS the demonstrated reliability of these valves. If the valve is inoperable and in the open position, the associated LPCI subsystem must be declared inoperable.
SR 3.5.1.7, SR 3.5.1.8, and SR 3.5.1.9 The performance requirements of the low pressure ECCS pumps are determined through application of the 10 CFR 50, Appendix K criteria (Ref. 8). This periodic Surveillance is performed (in accordance with the ASME OM Code requirements for the ECCS pumps) to verify that the ECCS pumps will develop the flow rates required by the respective analyses. The low pressure ECCS pump flow rates ensure that adequate core cooling is provided to satisfy the acceptance criteria of Reference 10.
The pump flow rates are verified against a system head equivalent to the RPV pressure expected during a LOCA. The total system pump outlet pressure is adequate to overcome the elevation head pressure between the pump suction and the vessel discharge, the piping friction losses, and RPV pressure present during a LOCA. These values may be established during preoperational testing.
The flow tests for the HPCI System are performed at two different pressure ranges such that system capability to provide rated flow is tested at both the higher and lower operating ranges of the system. Additionally, adequate steam flow must be passing through the main turbine or turbine bypass valves to continue to control reactor pressure when the HPCI System diverts steam flow. Reactor steam pressure is considered adequate when Ž_ 920 psig to perform SR 3.5.1.8 and >_ 150 psig to perform SR 3.5.1.9. However, the requirements of SR 3.5.1.9 are met by a successful performance at any pressure -< 165 psig. Adequate steam flow is represented by at least 1.25 turbine bypass valves open.
Therefore, sufficient time is allowed after adequate pressure and flow are achieved to perform these tests. Reactor startup is allowed prior to performing the low pressure Surveillance test because the reactor pressure is low and the time allowed to satisfactorily perform the Surveillance test is short. The reactor pressure is allowed to be increased to normal operating pressure since it is assumed that the low pressure test has been satisfactorily (continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-13 Revision 2
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.7, SR 3.5.1.8. and SR 3.5.1.9 (continued)
REQUIREMENTS completed and there is no indication or reason to believe that HPCI is inoperable.
Therefore, SR 3.5.1.8 and SR 3.5.1.9 are modified by Notes that state the Surveillances are not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after the reactor steam pressure and flow are adequate to perform the test.
The Frequency for SR 3.5.1.7 and SR 3.5.1.8 is in accordance with the Inservice Testing Program requirements. The 24 month Frequency for SR 3.5.1.9 is based on the need to perform the Surveillance under the conditions that apply just prior to or during a startup from a plant outage.
Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
SR 3.5.1.10 The ECCS subsystems are required to actuate automatically to perform their design functions. This Surveillance verifies that, with a required system initiation signal (actual or simulated), the automatic initiation logic of HPCI, CS, and LPCI will cause the systems or subsystems to operate as designed, including actuation of the system throughout its'emergency operating sequence, automatic pump startup and actuation of all automatic valves to their required positions. This functional test includes the LPCI and CS interlocks between Unit 1 and Unit 2 and specifically requires the following:
A functional test of the interlocks associated with the LPCI and CS pump starts in response to an automatic initiation signal in Unit 1 followed by a false automatic initiation signal in Unit 2; A functional test of the interlocks associated with the LPCI and CS pump starts in response to an automatic initiation signal in Unit 2 followed by a false automatic initiation signal in Unit 1; and (continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-14 Revision 0
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.10 (continued)
REQUIREMENTS A functional test of the interlocks associated with the LPCI and CS pump starts in response to simultaneous occurrences of an automatic initiation signal in both Unit 1 and Unit 2 and a loss of Offsite power condition affecting both Unit 1 and Unit 2.
The purpose of this functional test (preferred pump logic) is to assure that if a false LOCA signal were to be received on one Unit simultaneously with an actual LOCA signal on the second Unit, the preferred LPCI and CS pumps are started and the non-preferred LPCI and CS pumps are tripped for each Unit. This functional test is performed by verifying that the non-preferred LPCI and CS pumps are tripped. The verification that preferred LPCI and CS pumps start is performed under a separate surveillance test. Only one division of LPCI preferred pump logic is required to be OPERABLE for each Unit, because no additional failures needs to be postulated with a false LOCA signal. If the preferred or non-preferred pump logic for CS is inoperable, the associated CS pumps shall be declared inoperable and the pumps should not be operated to ensure that the opposite Unit's CS pumps or 4.16 kV ESS Buses are protected.
This SR also ensures that the HPCI System will automatically restart on an RPV low water level (Level 2) signal received subsequent to an RPV high water level (Level 8) tdp and that the suction is automatically transferred from the CST to the suppression pool. The LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1 overlaps this Surveillance.
This SR can be accomplished by any series of sequential overlapping or total steps such that the entire channel is tested.
The 24 month Frequency is acceptable because operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
This SR is modified by a Note that excludes vessel injection/spray during the Surveillance. Since all active components are testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-15 Revision 0
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.1.11 The ADS designated S/RVs are required to actuate automatically upon receipt of specific initiation signals. A system functional test is performed to demonstrate that the mechanical portions of the ADS function (i.e.,
solenoids) operate as designed when initiated either by an actual or simulated initiation signal, causing proper actuation of all the required components. SR 3.5.1.12 and the LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1 overlap this Surveillance to provide complete testing of the assumed safety function.
The 24 month Frequency is based on the need to perform portions of the 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 that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
This SR is modified by a Note that excludes valve actuation. This prevents an RPV pressure blowdown.
SR 3.5.1.12 A manual actuation of each ADS valve actuator is performed to verify that the valve and solenoid are functioning properly. This is demonstrated by the methods described below. Proper operation of the valve tailpipes is ensured through the use of foreign material exclusion during maintenance.
Valve OPERABILITY and the setpoints for overpressure protection are verified, per ASME requirements, prior to valve installation.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-16 Revision 3
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.12 (continued)
REQUIREMENTS Manual actuation of the actuator at atmospheric temperature and pressure during cold shutdown is performed. Proper functioning of the valve actuator and solenoid is demonstrated by visual observation of actuator movement. The ADS actuator will be disconnected from the valve to ensure no damage is done to the valve seat or to the valve internals.
Each valve shall be bench-tested prior to reinstallation. The bench-test along with the test on the ADS actuator establishes the OPERABILITY of the valves.
SR 3.5.1.11 and the LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1 overlap this Surveillance to provide complete testing of the assumed safety function. The Frequency of 24 months ensures that both solenoids for each ADS valve are alternately tested. The Frequency is based on the need to perform the Surveillance under the conditions that apply just prior to or during a startup from a plant outage. Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
SR 3.5.1.13 This SR ensures that the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is less than or equal to the maximum value assumed in the accident analysis. Response Time testing acceptance criteria are included in Reference 13. This SR is modified by a Note that allows the instrumentation portion of the response time to be assumed to be based on historical response time data and therefore, is excluded from the ECCS RESPONSE TIME testing. This is allowed sincethe instrumentation response time is a small part of the ECCS RESPONSE TIME (e.g., sufficient margin exists in the diesel generator start time when compared to the instrumentation response time) (Ref. 14).
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.5-17 Revision 3
PPL Rev. 4 ECCS-Operating B 3.5.1 BASES SURVEILLANCE REQUIREMENTS SR 3.5.1.13 (continued)
The 24-month Frequency is consistent with the typical industry refueling cycle and is acceptable based upon plant operating experience.
REFERENCES
- 1.
FSAR, Section 6.3.2.2.3.
- 2.
FSAR, Section 6.3.2.2.4.
- 3.
FSAR, Section 6.3.2.2.1.
- 4.
FSAR, Section 6.3.2.2.2.
- 5.
FSAR, Section 15.2.4.
- 6.
FSAR, Section 15.2.5.
- 7.
FSAR, Section 15.2.6.
- 8.
- 9.
FSAR, Section 6.3.3.
- 10. 10 CFR 50.46.
- 11.
FSAR, Section 6.3.3.
- 12.
Memorandum from R.L. Baer (NRC) to V. Stello, Jr. (NRC),
"Recommended Interim Revisions to LCOs for ECCS Components,"
December 1, 1975.
- 13.
FSAR, Section 6.3.3.3.
- 14.
NEDO 32291-A, "System Analysis for the Elimination of Selected Response Time Testing Requirements, October 1995.
- 15. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).
SUSQUEHANNA - UNIT 1 TS / B 3.5-18 Revision I