ML101100392
| ML101100392 | |
| Person / Time | |
|---|---|
| Site: | Susquehanna  |
| Issue date: | 04/06/2010 |
| From: | Susquehanna |
| To: | Gerlach R Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| Download: ML101100392 (42) | |
Text
Apr. 06, 2010 Page 1 of 2 MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2010-14896 USER INFORMATION:
GERLACH*ROSE M EMPL#:028401 CA#: 0363 Address: NUCSA2 Phone#: 254-3194 TRANSMITTAL INFORMATION:
TO: GERLACH*ROSE M 04/06/2010 LOCATION: USNRC 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.
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TSBI - TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 04/03/2010 ADD MANUAL TABLE OF CONTENTS DATE: 04/05/2010 CATEGORY: DOCUMENTS TYPE: TSBI 4oc(
Apr. 06, 2010 Page 2 of 2 ID: TEXT 3.3.2.2 REMOVE: REV:I ADD: REV: 2 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT 3.7.1 REMOVE: REV:3 ADD: REV: 4 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT LOES ADD: REV: 96 REMOVE: REV:95 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT TOC ADD: REV: 18 REMOVE: REV:17 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 i
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: TSB1 Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL Table Of Contents Issue Date: 04/05/2010 Procedure Name Rev Issue Date Change ID Change Number TEXT LOES 96 04/05/2010
Title:
LIST OF EFFECTIVE SECTIONS TEX:T TOC 18 04/05/2010//
Title:
TABLE OF CONTENTS TEXT 2.1.1 5 05/06/2009
Title:
SAFETY LIMITS (SLS) REACTOR CORE SLS 1\
TEX T 2.1.2 1 10/04-/2)007
Title:
SAFETY LIMITS (SLS) REACTOR COOLANT SYSTEM (RCS) PRESSURE S T 3.0 3 *0/20"/2009 TEX
Title:
LIMITING CONDITION FOR/OPERAT'ION (LCO) APPLICABILITY
/ \ "\\,
TEX*T 3.1.1 <' 1', 04/18/2006
Title:
/
REACTIVITY CONTROLSYST\ES N~* SHUTDOWN MARGINAGI SM (SDM)
N
_ _ ! \* \.... ....
TEXT 3.1.2 / U0 1II/15/UU2
Title:
REACTIVITY CONTROL SYSTEMS REACTIVITY ANOMALIES TEXT 3.1.3 N 2 01/19/2009
Title:
REACT IVITY,/ONTROL 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 04/18/2006
Title:
REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Report Date: 04/05/10 Pagel Page 1 of of 88 Report Date: 04/05/10
SSES MANIJAIL Manual Name: TSB1 4 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:POWER7RATIO (MCPR)
TEXT 3.2.3 2 ,04/23/2008
Title:
POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE (LHGR)
TEXT 3.3.1.1 4 04/23/2008
-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 3 04/23/2008
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 LDCN 4710 TEXT 3.3.3.1 8 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 04/23/2008
Title:
INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATION Page 2 of .8 Report Date: 04/05/10
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,(ECCSý) INSTRUMENTATION..
TEXT 3.3.5.2 0 11/15/2002
Title:
INSTRUMENTATION REACTOR CORE ISOLATION COOLING-'(RCIC) SYSTEM INSTRUMENTATION TEXT 3.3.6.1 4 - 04/23/2008
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 .(CREOASY SYSTEM INSTRUMENTATION TEXT 3.3.8.1 2 12/17/2007
Title:
INSTRUMENTATION LOSS OF POWER (LOP) INSTRUMENTATION TEXT 3.3.8.2 0 11/15/2002
Title:
INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER-MONITORING TEXT 3.4.1 3 ý 04/12/2006
Title:
REACTOR COOLANT SYSTEM (RCS) RECIRCULATION LOOPS OPERATING TEXT 3.4.2 1 04/23/2008
Title:
REACTOR COOLANT SYSTEM (RCS) JET PUMPS TEXT 3.4.3 2 04/23/2008
Title:
REACTOR COOLANT SYSTEM RCS SAFETY RELIEF VALVES S/RVS TEXT 3.4.4 0 11/15/2002
Title:
REACTOR*COOLANT SYSTEM (RCS) RCSOPERATIONAL LEAKAGE Report Date: 04/05/10 Page~
Page 3 of of 8
.8 Report Date: 04/05/10
SSES MANUA-AI Manual Name: TSB1 Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.4.5 1 01/16/2006
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 11/15/2002
Title:
REACTOR COOLANT SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM
- COLD SHUTDOWN TEXT 3.4.10 3 04./23/2008
Title:
REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE (P/T) LIMITS TEXT 3.4.11 0 11/15/2002
Title:
REACTOR COOLANT SYSTEM (RCS) REACTOR STEAM DOME PRESSURE TEXT 3. 5.1 2 01/16/2006
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATIONb COOLING (RCIC)
SYSTEM ECCS - OPERATING TEXT 3.5.2 0 11/15/2002
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM ECCS - SHUTDOWN TEXT 3.5.3 1 04/18/2005
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM RCIC SYSTEM TEXT 3.6.1.1 3 04/23/2008
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT TEXT 3.6.1.2 1 04/23/2008
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK 04/05/10 of ~8 Repor~t1ý Date:
Page4 Page 4 of Reporil Date: 04/05/10
SSES MANUAL Manual Name: TSB1 Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT I MANUAL TEXT 3.6.1.3 8 04/23/2008
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT ISOLATION-VALVES (PCIVS)
LDCN 3092 LDCN 4683 TEXT 3.6.1.4 1 04/23/2008
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 11/15/2002
Title:
. CONTAINMENT SYSTEMS SUPPRESSION CHAMBER-T0-DRYWELL VACUUM BREAKERS TEXT 3.6.2.1 2 04/23/2008
Title:
CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE TEXT 3.6.2.2 0 11/15/2002
Title:
CONTAINMENT SYSTEMS SUPPRESSION POOL WATER LEVEL TEXT 3.6.2.3 1 *01/16/2006
Title:
CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL COOLING
'TEXT 3.6.2.4 0 11/15/2002
Title:
CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL SPRAY TEXT 3.6.3.1 2 06/13/20'06
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 11/15/2002
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION Report Date: 04/05/10 Pages Page 5 of of 8
.8 Report Date: 04/05/10
SSES MANUAL Manual Name: TSB1 Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.6.4.1 7 10/04/2007
Title:
CONTAINMENT SYSTEMS SECONDARY CONTAINMENT 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 4 . 04/05/2010
Title:
PLANT SYSTEMS RESIDUAL HEAT REMOVAL SERVICE WATER (RHRSW) SYSTEM AND THE ULTIMA\TE HEAT SINK (UHS)
TEXT 3.7. 2 2 .02/11/2009
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 11/15/2002
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 04/23/2008
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 3.7. 8 0 04/23/2008
Title:
PLANT SYSTEMS
'? TEXT 3.8.1 6 05/06/2009
Title:
ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING Report Date; 04/05/10 Page~
Page 6 of of 8 8 Report Date: 04/05/10
SSES M1ANUAL Manual Name: TSBI Manual
Title:
TECHNICAL SPECIFICATION BASES'UNIT 1 MANUAL TEXT 3.8.2 0 11/15/2002
Title:
ELECTRICAL POWER SYSTEMS AC SOURCES - SHUTDOWN TEXT 3.8.3 1 04/23/2008
Title:
ELECTRICAL POWER SYSTEMS DIESEL FUEL OIL, LUBE OIL ' AND STARTING AIR LDCN 4755 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 DCISOURCES - SHUTDOWN' TEXT 3.8.6 1 12/14/:2006
Title:
ELECTRICAL POWER SYSTEMS BATTERY CELL PARAMETERS TEXT 3.8.7 1 10/05/2005
Title:
ELECTRICAL POWER SYSTEMS DISTRIBUTIONýSYSTEMS- OPERATING TEXT 3.8.8 0 11/15/2002
Title:
ELECTRICAL POWER SYSTEMS DISTRIBUTION SYSTEMS- SHUTDOWN TEXT 3.9.1 0 11/15/2002
Title:
REFUELING OPERATIONS REFUELING EQUIPMENT INTERLOCKS TEXT 3.9.2 0 11/15/2002
Title:
REFUELING OPERATIONS REFUEL POSITION ONE-ROD-OUT INTERLOCK TEXT 3.9.3 0 11/15/2002
Title:
REFUELING OPERATIONS CONTROL ROD POSITION TEXT 3.9.4 0 11/15/2002
Title:
REFUELING OPERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/15/2002
Title:
REFUELING OPERATIONS CONTROL ROD OPERABILITY - REFUELING Report Date: 04/05/10 Page Pagel7 of of ~8 Report Date: 04/05/10
SSES MANUAL Manual Name: TSBI Manual
Title:
TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.9.6 1 10/04/2007
Title:
REFUELING OPERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL TEXT 3.9.7 0 11/15/2002 Title': REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - HIGH WATER LEVEL TEXT 3:.9.8 0 '11/15/2002
Title:
REFUELING OPERATIONS RESIDUAL. HEAT REMOVAL (RHR .- LOW WATER LEVEL TEXT 3.10.1 1 01/23/2008
Title:
SPECIAL OPERATIONS INSERVICE LEAK AND HYDROSTATIC TESTING OPERAT,ION.*
TEXT 3.10.2 0. _ 11/15/2002;
Title:
SPECIAL OPERATIONS REACTOR MODE SWITCH INTERLOCK TESTING TEXT 3.10.3 0 11/15-:/2002
Title:
SPECIAL OPERATIONS SINGLE CONTROL- RODWITHDRAWAL - HOT SHUTDOWN ,
TEXT 3.10.4 0 11 /T15/,2002 Tit le: SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL -. COLD SHUTDOWN TEXT 3.10.5 0 11/15/2002
Title:
SPECIAL OPERATIONS SINGLE CONTROL ROD DRIVE (CRD) REMOVAL - REFUELING TEXT 3.10.6 0. 11/15/2002
Title:
SPECIAL OPERATIONS MULTIPLE CONTROL ROD WITHDRAWAL - REFUELING TEXT 3.10.7 1 04/18/2006
Title:
SPECIAL OPERATIONS CONTROL ROD TESTING - OPERATING TEXT 3.10.8 1 04/12/2006
Title:
SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING Repoit Date: 04/05/10 Page~
Page 8 of of 88 Repor"t Date: 04/05/10
TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)
B2.0 SA FETY LIM ITS (S Ls) .................................................................................. B2.0-1 B2 .1.1 R eactor C ore S Ls ........................................................................... B 2.0-1 B2.1.2 Reactor Coolant System (RCS) Pressure SL ........................... TS/B2.0-7 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 Shutdown Margin (SDM) .................................... B3.1-1 B3.1.2 R eactivity A nom alies .............. ...................................................... B3.1-8 B3.1.3 Control Rod O PERABILITY ............................................................ B 3.1-13 B3.1.4 Control Rod Scram Tim es ........................................................ 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 POW ER 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 Instrumentation ................................................... TS/B3.3-55 B3.3.3.1 Post Accident Monitoring (PAM) Instrumentation ..................... TS/B3.3-64 B3.3.3.2 Remote Shutdown System ........................... B3.3-76 B3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)
Instrum entation ......................................................................... B 3.3-81 B3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATVVS-RPT) Instrumentation ............. TS/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 Instrumentation ............................... . B3.3-1-35 B3.3.6.1 Primary Containment Isolation Instrumentation .............................. B3.3-147 B3.3.6.2 Secondary Containment Isolation Instrumentation ................... TS/B3.3-180 B3.3.7.1 Control Room Emergency Outside Air Supply (CREOAS)
System Instrum entation ...................................................... TS/B3.3-1,92 (continued)
SUSQUEHANNA - UNIT 1 TS / B TOC - 1 Revision 18
TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)
B3.3 INSTRUMENTATION (continued)
B3.3.8.1 Loss of Power (LOP) Instrumentation ....................................... TSIB3.3-205 B3.3.8.2 Reactor Protection System (RPS) Electric Power Mo n ito ring ................................................................................ B3 .3-2 13 B3.4 REACTOR COOLANT SYSTEM (RCS) ............................................... B3.4-1 B3.4.1 Recirculation Loops Operating ....................................................... B3.4-1 B3 .4.2 Jet P um ps ...................................................................................... B3.4-10 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 ................................. 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 B3.4.1 1 Reactor Steam Dome Pressure ................................................ TS/B3.4-58 B3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM .................................. B3.5-1 B3.5.1 EC CS - O perating ......................................................................... 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 .................................................................... B3.6-41 B3.6.1.5 Drywell Air Temperature ........................................................... TS/B3.6-44 B3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers ................ TS/B3.6-47 B3.6.2.1 Suppression Pool Average Temperature .................................. TS/B3.6-53 B3.6.2.2 Suppression Pool Water Level ....................................................... B3.6-59 B3.6.2.3 Residual Heat Removal (RHR) Suppression Pool C o o ling ..................................................................................... B 3 .6-62 B3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ................ B3.6-66 B3.6.3.1 Not Used .................................................................................. T S/B3.6-70 B3.6.3.2 Drywell Air Flow System ................................................................. B3.6-76 B3.6.3.3 Primary Containment Oxygen Concentration .................................. B3.6-81 B3.6.4.1 Secondary Containment ........................................................... TS/B3.6-84 B3.6.4.2 Secondary Containment Isolation Valves (SCIVs) .................... TS/B3.6-91 B3.6.4.3 Standby Gas Treatment (SGT) System ................................... TS/B3.6-101 (continued)
SUSQUEHANNA vvv*v-- ................
- UNIT 1 TS / B TOC - 2 Revision 18
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/13.7-1 B3.7.2 Emergency Service Water (ESW) System ................................ TS/B3.7-7 B3.7.3 Control Room Emergency Outside Air Supply (CREOAS) System ........................... TS/B3.7-12 13.7.4 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 - O perating .......................................................... TS/B3.8-1 13.8.2 AC Sources - Shutdown ................................................................ B3.8-38 B3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ................................ TS/B3.8-45 B3.8.4 DC Sources - Operating .......................................................... TS/B3.8-54 B3.8.5 DC Sources - Shutdown .......................................................... TS/B3.8-66 B3.8.6 Battery Cell Param eters ........................................................... TS/B3.8-71 B3.8.7 Distribution Systems - Operating ................................................... B3.8-78 B3.8.8 Distribution Systems - Shutdown ................................................... B3.8-86 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/3.10-1 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 .................................................... B3.10-29 B3.10.8 SHUTDOWN MARGIN (SDM) Test- Refueling ............................. B3.10-33 TSB1 Text TOC 3/26/2010 Revision 18 UNIT I1 TS / B TOO -3 SUSQUEHANNA - UNIT SUSQUEHANNA -
TS / B TOC - 3 Revision 18
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision TOC Table of Contents 18 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 3.0-1 Ia 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 I B 3.3-34 through TS / B 3.3-36 1 Pages TS / B 3.1-37 and TS / B 3.1-38 2 Page 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 TS/B LOES-1 Revision 96 SUSQUEHANNA - UNIT SUSQUEHANNA -
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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 4 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 Pages TS / B 3.3-28 through TS / B 3.3-30 3 Page TS / B 3.3-30a 0 UNIT 1 TS/BLOES-2 Revision 96 SUSQUEHANNA - UNIT SUSQUEHANNA -
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Section Title Revision Pages B 3.3-76 through 3.3-77 0 Page TS / B 3.3-78 1 Pages B 3.3-79 through B 3.3-81 0 Page B 3.3-82 1 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 Page B 3.3-88 0 Page B 3.3-89 1 Page TS / B 3.3-90 1 Page B 3.3-91 0 Pages TS / B 3.3-92 through TS B B 3.3-100 1 Pages TS / B 3.3-101 through TS / B 3.3-103 0 Page TS / B 3.3-104 2 Pages TS / B 3.3-105 and TS / B 3.3-106 0 Page TS / B 3.3-107 1 Page TS / B 3.3-108 0 Page TS / B 3.3-109 1 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 / 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 Page TS / B 3.3-124a 0 Page TS / B 3.3-125 0 Pages TS / B 3.3-126 and TS / B 3.3-127 1 Pages TS / B 3.3-128 through TS/ B 3.3-130 0 Page TS / B 3.3-131 1 Pages TS / B 3.3-132 through TS / B 3.3-134 0 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 3.3-162 1 Page TS / B 3.3-163 2 Pages TS / B 3.3-164 and TS / B 3.3-165 1 Pages TS / B 3.3-166 and TS / B 3.3-167 2 Revision 96 SUSQUEHANNA - UNIT SUSQUEHANNA -
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Section Title Revision 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 Page TS / B 3.4-50 1 Page TS / B 3.4-51 3 Page TS / B 3.4-52 2 Page TS / B 3.4-53 1.
Pages TS / B 3.4-54 through TS / B 3.4-56 2 Page TS / B 3.4-57 3 Pages TS / B 3.4-58 through TS / B 3.4-60 1 B 3.5 ECCS AND RCIC BASES Pages B 3.5-1 and B 3.5-2 0 Page TS / B 3.5-3 2 Page TS / B 3.5-4 1 Page TS / B 3.5-5 2 Page TS / B 3.5-6 1 Pages B 3.5-7 through B 3.5-10 0 Page TS / B 3.5-11 1 Page TS / B 3.5-12 0 Page TS / B 3.5-13 1 Pages TS / B 3.5-14 and TS / B 3.5-15 0 Pages TS / B 3.5-16 through TS / B 3.5-18 1 Pages B 3.5-19 through B 3.5-24 0 Page TS / B 3.5-25 1 Pages TS / B 3.5-26 and 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 Pages TS / B 3.6-5 and TS / B 3.6-6 3 Pages TS / B 3.6-6a and TS / B 3.6-6b 2 Page TS / B 3.6-6c 0 Pages B 3.6-7 0 Page B 3.6-8 1 Pages B 3.6-9 through B 3.6-14 0 Page TS / B 3.6-15 2 Page TS / B 3.6-15a 0 Page TS / B 3.6-15b 2 UNIT I1 TS/B LOES-6 Revision 96 SUSQUEHANNA SUSQUEHANNA - UNIT TS / B LOES-6 Revision 96
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Section Title Revision Pages TS / B 3.6-16 and TS / B 3.6-17 1 Page TS / B 3.6-17a 0 Pages TS / B 3.6-18 and TS / B 3.6-19 0 Page TS / B 3.6-20 1 Page TS / B 3.6-21 2 Page TS / B 3.6-22 1 Page TS / B 3.6-22a 0 Page TS / B 3.6-23 1 Pages TS / B 3.6-24 and TS / B 3.6-25 0 Pages TS / B 3.6-26 and TS / B 3.6-27 2 Page TS / B 3.6-28 7 Page TS / B 3.6-29 2 Page TS / B 3.6-30 1 Page TS / B 3.6-31 3 Page TS / B 3.6-32 0 Page TS / B 3.6-33 1 Pages TS / B 3.6-34 and TS / B 3.6-35 0 Page TS / B 3.6-36 1 Page TS / B 3.6-37 0 Page TS / B 3.6-38 3 Page TS / B 3.6-39 2 Page TS / B 3.6-40 6 Page B 3.6-41 1 Pages B 3.6-42 and B 3.6-43 3 Pages TS / B 3.6-44 and TS / B 3.6-45 1 Page TS / B 3.6-46 2 Pages TS / B 3.6-47 through TS / B 3.6-51 1 Page TS / B 3.6-52 2 Pages TS / B 3.6-53 through TS / B 3.6-56 0 Page TS / B 3.6-57 1 Page TS / 3.6-58 2 Pages B 3.6-59 through B 3.6-63 0 Pages TS / B 3.6-64 and TS / B 3.6-65 1 Pages B 3.6-66 through B 3.6-69 0 Pages TS / B 3.6-70 through TS / B 3.6-72 1 Page TS / B 3.6-73 2 Pages TS / B 3.6-74 and TS / B 3.6-75 1 Pages B 3.6-76 and B 3.6-77 0 Page TS / B 3.6-78 1 Pages B 3.6-79 through B 3.3.6-83 0 Page TS / B 3.6-84 3 Page TS / B 3.6-85 2 Page TS / B 3.6-86 4 LOES-7 Revision 96 SUSQUEHANNA - UNIT SUSQUEHANNA -
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Section Title Revision Pages TS / B 3.6-87 through TS / B 3.6-88a 2 Page TS / B 3.6-89 4 Page TS / B 3.6-90 2 Page TS / B 3.6-91 3 Pages TS / B 3.6-92 through TS / B 3.6-96 1 Page TS / B 3.6-97 2 Pages TS / B 3.6-98 and TS / B 3.6-99 1 Page TS / B 3.6-100 3 Page TS / B 3.6-100a 0 Pages TS / B 3.6-101 and TS / B 3.6-102 1 Pages TS / B 3.6-103 and TS / B 3.6-104 2 Page TS / B 3.6-105 3 Page TS / B 3.6-106 2 Page TS / B 3.6-107 3 B 3.7 PLANT SYSTEMS BASES Pages 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 1 Page TS / B 3.7-6 3 Page TS / B 3.7-6a 2 Page TS I B 3.7-6b 1 Page TS / B 3.7-6c 2 Page TS / B 3.7-7 3 Page TS / B 3.7-8 2 Pages TS / B 3.7-9 through TS / B 3.7-11 1 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 3.7-23 1 Page 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 5 Page TS / B 3.7-30 2 Page 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 Revision 96 SUSQUEHANNA SUSQUEHANNA - UNIT
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Section Title Revision B 3.8 ELECTRICAL POWER SYSTEMS BASES Page TS / B 3.8-1 3 Pages TS / B 3.8-2 and TS / B 3.8-3 2 Page TS / B 3.8-4 3 Pages TS / B 3.8-4a and TS / B 3.8-4b 0 Page TS / B 3.8-5 5 Page TS / B 3.8-6 3 Pages TS / B 3.8-7 through TS/B 3.8-8 2 Page TS / B 3.8-9 4 Page TS / B 3.8-10 3 Pages TS / B 3.8-11 and TS / B 3.8-17 2 Page TS / B 3.8-18 3 Pages TS / B 3.8-19 through TS / B 3.8-21 2 Pages TS / B 3.8-22 and TS / B 3.8-23 3 Pages TS / B 3.8-24 through TS / B 3.8-37 2 Pages B 3.8-38 through B 3.8-44 0 Page TS / B 3.8-45 1 Pages TS / B 3.8-46 through B 3.8-48 0 Page TS / B 3.8-49 1 Pages B 3.8-50 through B 3.8-53 0 Pages TS / B 3.8-54 through TS / B 3.8-57 2 Pages TS / B 3.8-58 through TS / B 3.8-61 3 Pages TS / B 3.8-62 and TS / B 3.8-63 5 Page TS / B 3.8-64 4 Page TS / B 3.8-65 5 Pages TS / B 3.8-66 through TS / B 3.8-77 1 Pages TS / B 3.8-77A through TS / B 3.8-77C 0 Pages B 3.8-78 through B 3.8-80 0 Page TS / B 3.8-81 1 Pages B 3.8-82 through B 3.8-90 0 B 3.9 REFUELING OPERATIONS BASES Pages TS / B 3.9-1 and TS / B 3.9-1a 1 Pages TS / B 3.9-2 through 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 Revision 96 SUSQUEHANNA SUSQUEHANNA - UNIT
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Section Title Revision 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 3.10-31 0 Page TS / B 3.10-32 2 Page B 3.10-33 0 Page TS / B 3.10-34 1 Pages B 3.10-35 and B 3.10-36 0 Page TS / B 3.10-37 1 Page TS / B 3.10-38 2 TSB1 Text LOES.doc 3/26/2010 Revision 96 SUSQUEHANNA - UNIT SUSQUEHANNA -
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PPL Rev. 2 Feedwater - Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 B 3.3 INSTRUMENTATION B 3.3.2.2 Feedwater- Main Turbine High Water Level Trip Instrumentation BASES BACKGROUND The feedwater - main turbine high water level trip instrumentation is designed to detect a potential failure of the Feedwater Level Control System that causes excessive feedwater flow.
With excessive feedwater flow, the water level in the reactor vessel rises toward the high water level, Level 8 reference point, causing the trip of the three feedwater pump turbines and the main turbine.
Reactor Vessel Water Level-High, Level 8 signals are provided by level sensors that sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level in the reactor vessel (variable leg). Three channels of Reactor Vessel Water Level instrumentation are input to the Integrated Control System (ICS) to provide the Reactor Vessel Water Level High, Level 8 trips of the Feedwater Pump Turbines and the Main Turbine. The channel trip signals are evaluated independently in each of the three ICS distributed control logic cabinets located in the Computer Room using a two-out-of three channel coincident trip logic configuration, to provide the Level 8 trips of the feedwater pump turbines. The feedwater pump turbine trip initiation signal is provided with redundant trip paths to the individual feedwater pump turbine ICS cabinets located in the turbine building. The Level 8 trip of the Main Turbine is provided directly by the ICS via a hardwired discrete contact two-out-three channel coincident trip logic inputting to the main turbine electro-hydraulic controls.
A trip of the feedwater pump turbines limits further increase in reactor vessel water level by limiting further addition of feedwater to the reactor vessel. A trip of the main turbine and closure of the stop valves protects the turbine from damage due to water entering the turbine.
APPLICABLE The feedwater - main turbine high water level trip instrumentation is SAFETY ANALYSES assumed to be capable of providing a turbine trip in the design basis transient analysis for a feedwater controller failure, maximum demand event (Ref. 1). The Level 8 trip indirectly initiates a reactor scram from (continued)
SUSQUEHANNA - UNIT 1 TS / B 3.3-55 Revision 2
PPL Rev. 2 Feedwater - Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES APPLICABLE the main turbine trip (above 26% RTP) and trips the feedwater pumps, SAFETY ANALYSES thereby terminating the event. The reactor scram mitigates the (continued) reduction in MCPR. Feedwater - main turbine high water level trip instrumentation satisfies Criterion 3 of the NRC Policy Statement. (Ref.
3)
LCO The LCO requires three channels of the Reactor Vessel Water Level-High, Level 8 trip instrumentation to be OPERABLE to ensure that no single instrument failure will prevent the feedwater pump turbines and main turbine trip on a valid Level 8 signal. Two of the three channels are needed to provide trip signals in order for the feedwater - main turbine trips to occur. Each channel must have its setpoint set within the specified Allowable Value of SR 3.3.2.2.3. The Allowable Value is set to ensure that the thermal limits are not exceeded during the event.
The actual setpoint is calibrated to be consistent with the applicable setpoint methodology assumptions. Nominal trip setpoints are specified in the setpoint calculations. The nominal setpoints are selected to ensure that the setpoints do not exceed the Allowable Value between successive CHANNEL CALIBRATIONS. Operation with a trip setpoint less conservative than the nominal trip setpoint, but within its Allowable Value, is acceptable.
Trip setpoints are those predetermined values of output at which an action should take place. The setpoints are compared to the actual process parameter (e.g., reactor vessel water level), and when the measured output value of the process parameter reaches the setpoint, the associated device changes state. The analytic limits are derived from the limiting values of the process parameters obtained from the safety analysis. The Allowable Values are derived from the analytic limits, corrected for calibration, process, and some of the instrument errors. A channel is inoperable if its actual trip setpoint is not within its required Allowable Value. The trip setpoints are then determined accounting for the remaining instrument errors (e.g., drift). The trip setpoints derived in this manner provide adequate protection because instrumentation uncertainties, process effects, calibration tolerances, instrument drift, and severe environment errors (for channels that must function in harsh environments as defined by 10 CFR 50.49) are accounted for.
(continued)
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PPL Rev. 2 Feedwater - Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES (continued)
APPLICABILITY The feedwater - main turbine high water level trip instrumentation is required to be OPERABLE at > 23% RTP to ensure that the fuel cladding integrity Safety Limit is not violated during the feedwater controller failure, maximum demand event. As discussed in the Bases of LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR),"
sufficient margin to these limits exists below 23% RTP; therefore, the requirements are only necessary when operating at or above this power level.
ACTIONS A Note has been provided to modify the ACTIONS related to feedwater - main turbine high water level trip instrumentation channels.
Section 1.3, Completion Times, specifies that 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 that 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 inoperable feedwater - main turbine high water level trip instrumentation channels provide appropriate compensatory measures for separate inoperable channels. As such, a Note has been provided that allows separate Condition entry for each inoperable feedwater -
main turbine high water level trip instrumentation channel.
A. 1 With one channel inoperable, the remaining two OPERABLE channels can provide the required trip signal. However, overall instrumentation reliability is reduced because a single failure in one of the remaining channels concurrent with feedwater controller failure, maximum demand event, may result in the instrumentation not being able to perform its intended function. Therefore, continued operation is only allowed for a limited time with one channel inoperable. If the inoperable channel cannot be restored to OPERABLE status within the Completion Time, the channel must be placed in the tripped condition per Required Action A.1. Placing the (continued)
SUSQUEHANNA - UNIT I TS / B 3.3-57 Revision 1
PPL Rev. 2 Feedwater - Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES ACTIONS A.1 (continued) inoperable channel in trip would conservatively compensate for the inoperability, restore capability to accommodate a single failure, and allow operation to continue with no further restrictions. Alternately, if it is not desired to place the channel in trip (e.g., as in the case where placing the inoperable channel in trip would result in a feedwater or main turbine trip), Condition C must be entered and its Required Action taken.
If the failure only effects the trip function of a single component, such as a main feed pump, an option is always available to remove the affected component from service and restore OPERABILITY. This is acceptable because removing the component from service performs the safety function.
The Completion Time of 7 days is based on the low probability of the event occurring coincident with a single failure in a remaining OPERABLE channel.
B. 1 With two or more channels inoperable, the feedwater - main turbine high water level trip instrumentation cannot perform its design function (feedwater - main turbine high water level trip capability is not maintained). Therefore, continued operation is only permitted for a 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> period, during which feedwater - main turbine high water level trip capability must be restored. The trip capability is considered maintained when sufficient channels are OPERABLE or in trip such that the feedwater - main turbine high water level trip logic will generate a trip signal on a valid signal. This requires two channels to each be OPERABLE or in trip. If the required channels cannot be restored to OPERABLE status or placed in trip, Condition C must be entered and its Required Action taken.
If the failure only affects the trip function of a single main feed pump, an option is always available to remove the affected component from service and restore OPERABILITY. This is acceptable because removing the component from service performs the safety function.
(continued)
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PPL Rev. 2 Feedwater - Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES ACTIONS B.1 (continued)
The 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Completion Time is sufficient for the operator to take corrective action, and takes into account the likelihood of an event requiring actuation of feedwater - main turbine high water level trip instrumentation occurring during this period. It is also consistent with the 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Completion Time provided in LCO 3.2.2 for Required Action A. 1, since this instrumentation's purpose is to preclude a MCPR violation.
C.1 With the required channels not restored to OPERABLE status or placed in trip, THERMAL POWER must be reduced to < 23% RTP within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. As discussed in the Applicability section of the Bases, operation below 23% RTP results in sufficient margin to the required limits, and the feedwater - main turbine high water level trip instrumentation is not required to protect fuel integrity during the feedwater controller failure, maximum demand event. The allowed Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is based on operating experience to reduce THERMAL POWER to < 23% RTP from full power conditions in an orderly manner and without challenging plant systems.
If the failure only affects the trip function of a single main feed pump, an option is always available to remove the affected component from service and restore OPERABILITY. This is acceptable because removing the component from service performs the safety function.
SURVEILLANCE The Surveillances are modified by a Note to indicate that when a REQUIREMENTS channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains feedwater - main turbine high water level trip capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> allowance, the channel must be returned to OPERABLE status (continued)
SUSQUEHANNA - UNIT 1 TS / B 3.3-59 Revision. 1
PPL Rev. 2 Feedwater - Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES SURVEILLANCE or the applicable Condition entered and Required Actions taken. This REQUIREMENTS Note is based on the reliability analysis (Ref. 2) assumption that (continued) 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is the average time required to perform channel Surveillance.
That analysis demonstrated that the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not significantly reduce the probability that the feedwater pump turbines and main turbine will trip when necessary.
SR 3.3.2.2.1 Performance of the CHANNEL CHECK once every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between instrument channels could be an indication of excessive instrument drift in one of the channels, or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria, which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is Inoperable.
The Frequency is based on operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal checks of channel status during normal operational use of the displays associated with the channels required by the LCO.
SR 3.3.2.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.3-60 Revision 0
PPL Rev. 2 Feedwater- Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES SURVEILLANCE SR 3.3.2.2.2 (continued)
REQUIREMENTS The Frequency of 92 days is based on reliability analysis (Ref. 2).
This SR is modified by two Notes. Note 1 provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design architecture of the ICS (e.g. digital control blocks and logic) does not facilitate complete functional testing of all required logic blocks, which input into the combinational logic. (Reference 4) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.
Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the change of state of the "logical blocks" which input into the combinational logic. The required "logical blocks" not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.2.2.4.
This is acceptable because operating experience shows that the "logical blocks" not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.
Note 2 provides a second specific exception to the definition of CHANNEL FUNCTIONAL TEST. For the Feedwater - Main Turbine High Water Level Trip Function, certain required channel "logical blocks" are not included in the performance of the CHANNEL FUNCTIONAL TEST. These exceptions are necessary because the circuit design does not facilitate functional testing of the entire channel through to the combinational logic. (Reference 4) Specifically, testing of all required "logical blocks" could lead to unplanned transients.
Therefore, for this circuit, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the actuation of circuit devices up to the point where further testing could result in an unplanned transient.
(References 5 and 6) The required "logical blocks" not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.2.2.4. This exception is acceptable because operating experience shows that the devices not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.3-61 Revision 1
PPL Rev. 2 Feedwater - Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES SURVEILLANCE SR 3.3.2.2.3 REQUIREMENTS (continued) CHANNEL CALIBRATION verifies that the channel responds to the measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
The Frequency is based upon the assumption of an 24 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.
SR 3.3.2.2.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific channel. The system functional test of the feedwater - main turbine valves is included as part of this Surveillance and overlaps the LOGIC SYSTEM FUNCTIONAL TEST to provide complete testing of the assumed safety function. Therefore, if a valve is incapable of operating, the associated instrumentation would also be inoperable. 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 that these components usually pass the Surveillance when performed at the 24 month Frequency.
REFERENCES 1. FSAR, Section 15.1.2.
- 2. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.
- 3. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.3-62 Revision 0
PPL Rev. 2 Feedwater- Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES REFERENCES 4. NRC Inspection and Enforcement Manual, Part 9900: Technical (continued) Guidance, Standard Technical Specification Section 1.0 Definitions, Issue date 12/08/86.
- 5. PLA-2618: NRC Inspection Reports 50-387/85-28 and 50-388/85-23.
- 6. NRC Region I Combined Inspection 50-387/90-20, 50-388/90-20.
SUSQUEHANNA - UNIT 1 TS / B 3.3-63 Revision 0
PPL Rev. 4 RHRSW System and UHS B 3.7.1 B 3.7 PLANT SYSTEMS B 3.7.1 Residual Heat Removal Service Water (RHRSW) System and the Ultimate Heat Sink (UHS)
BASES BACKGROUND The RHRSW System is designed to provide cooling water for the Residual Heat Removal (RHR) System heat exchangers, required for a safe reactor shutdown following a Design Basis Accident (DBA) or transient. The RHRSW System is operated whenever the RHR heat exchangers are required to operate in the shutdown cooling mode or in the suppression pool cooling or spray mode of the RHR System.
The RHRSW System consists of two independent and redundant subsystems. Each subsystem is made up of a header, one pump, a suction source, valves, piping, heat exchanger, and associated instrumentation. Either of the two subsystems is capable of providing the required cooling capacity to maintain safe shutdown conditions. The two subsystems are separated so that failure of one subsystem will not affect the OPERABILITY of the other subsystem. One Unit 1 RHRSW subsystem and the associated (same division) Unit 2 RHRSW subsystem constitute a single RHRSW loop. The two RHRSW pumps in a loop can each, independently, be aligned to either Unit's heat exchanger. The RHRSW System is designed with sufficient redundancy so that no single active component failure can prevent it from achieving its design function.
The RHRSW System is described in the FSAR, Section 9.2.6, Reference 1.
Cooling water is pumped by the RHRSW pumps from the UHS through the tube side of the RHR heat exchangers. After removing heat from the RHRSW heat exchanger, the water is discharged to the spray pond (UHS) by way of the UHS return loops. The UHS return loops direct the return flow to a network of sprays that dissipate the heat to the atmosphere or directly to the UHS via a bypass header.
The system is initiated manually from the control room except for the spray array bypass manual valves that are operated locally in the event of a failure of the spray array bypass valves. The system can be started any time the LOCA signal is manually overridden or clears.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.7-1 Revision 3
PPL Rev. 4 RHRSW System and UHS B 3.7.1 BASES BACKGROUND The ultimate heat sink (UHS) system is composed of approximately (continued) 3,300,000 cubic foot spray pond and associated piping and spray risers.
Each UHS return loop contains a bypass line, a large spray array and a small spray array. The purpose of the UHS is to provide both a suction source of water and a return path for the RHRSW and ESW systems.
The function of the UHS is to provide water to the RHRSW and ESW systems at a temperature less than the 97 0 F design temperature of the RHRSW and ESW systems. UHS temperature is maintained less than the design temperature by introducing the hot return fluid from the RHRSW and ESW systems into the spray loops and relying on spray cooling to maintain temperature. The UHS is designed to supply the RHRSW and ESW systems with all the cooling capacity required during a combination LOCA/LOOP for thirty days without fluid addition. The UHS is described in the FSAR, Section 9.2.7 (Reference 1).
APPLICABLE The RHRSW System removes heat from the suppression pool to limit the SAFETY suppression pool temperature and primary containment pressure following ANALYSES a LOCA. This ensures that the primary containment can perform its function of limiting the release of radioactive materials to the environment following a LOCA. The ability of the RHRSW System to support long term cooling of the reactor or primary containment is discussed in the FSAR, Chapters 6 and 15 (Refs. 2 and 3, respectively). These analyses explicitly assume that the RHRSW System will provide adequate cooling support to the equipment required for safe shutdown. These analyses include the evaluation of the long term primary containment response after a design basis LOCA.
The safety analyses for long term cooling were performed for various RHRSW and UHS configurations. As discussed in the FSAR, Section 6.2.2 (Ref. 2) for these analyses, manual initiation of the OPERABLE RHRSW subsystem and the associated RHR System is required. The maximum suppression chamber water temperature and pressure are analyzed to be below the design temperature of 220OF and maximum allowable pressure of 53 psig.
/-
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.7-2 Revision 4
PPL Rev. 4 RHRSW System and UHS B 3.7.1 BASES APPLICABLE The UHS design takes into account the cooling efficiency of the spray SAFETY arrays and the evaporation losses during design basis environmental ANALYSES conditions. The spray array bypass header provides the flow path for the (continued) ESW and RHRSW system to keep the spray array headers from freezing.
The small and/or large spray arrays are placed in service to dissipate heat returning from the plant. The UHS return header is comprised of the spray array bypass header, the large spray array, and the small spray array.
The spray array bypass header is capable of passing full flow from the RHRSW and ESW systems in each loop. The large spray array is capable of passing full flow from the RHRSW and ESW systems in each loop. The small spray array supports heat dissipation when low system flows are required.
The RHRSW System, together with the UHS, satisfy Criterion 3 of the NRC Policy Statement. (Ref. 4)
LCO Two RHRSW subsystems are required to be OPERABLE to provide the required redundancy to ensure that the system functions to remove post accident heat loads, assuming the worst case single active failure occurs coincident with the loss of offsite power.
An RHRSW subsystem is considered OPERABLE when:
- a. One pump is OPERABLE; and
- b. An OPERABLE flow path is capable of taking suction from the UHS and transferring the water to the RHR heat exchanger and returning it to the UHS at the assumed flow rate, and
The OPERABILITY of the UHS is based on having a minimum water level at the overflow weir of 678 feet 1 inch above mean sea level and a maximum water temperature of 85°F; unless either unit is in MODE 3. If a unit enters MODE 3, the time of entrance into this condition determines the appropriate maximum ultimate heat sink fluid temperature. If the earliest unit to enter MODE 3 has been in that condition for less than twelve (12) hours, the peak temperature to maintain OPERABILITY of the ultimate heat sink remains at 85 0 F. If either unit has been in MODE 3 for more than twelve (12) hours but less than twenty-four (24) hours, the OPERABILITY temperature of the ultimate heat sink becomes 87 0 F. If either unit has been in MODE 3 for twenty-four (24) hours or more, the OPERABILITY temperature of the ultimate heat sink becomes 88 0 F.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.7-3 Revision 3
PPL Rev. 4 RHRSW System and UHS B 3.7.1 BASES LCO In addition, the OPERABILITY of the UHS is based on having sufficient (continued) spray capacity in the UHS return loops. Sufficient spray capacity is defined as one large and one small spray array in one loop.
This OPERABILITY definition is supported by analysis and evaluations performed in accordance with the guidance given in Regulatory Guide 1.27.
APPLICABILITY In MODES 1, 2, and 3, the RHRSW System and the UHS are required to be OPERABLE to support the OPERABILITY of the RHR System for primary containment cooling (LCO 3.6.2.3, "Residual Heat Removal (RHR)
Suppression Pool Cooling," and LCO 3.6.2.4, "Residual Heat Removal (RHR) Suppression Pool Spray") and decay heat removal (LCO 3.4.8, "Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown"). The Applicability is therefore consistent with the requirements of these systems.
In MODES 4 and 5, the OPERABILITY requirements of the RHRSW System are determined by the RHR shutdown cooling subsystem(s) it supports (LCO 3.4.9, "Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown," LCO 3.9.7, "Residual Heat Removal (RHR) -
High Water Level," and LCO 3.9.8, "Residual Heat Removal (RHR) - Low Water Level").
In MODES 4 and 5, the OPERABILITY requirements of the UHS is determined by the systems it supports.
ACTIONS The ACTIONS are modified by a Note indicating that the applicable Conditions of LCO 3.4.8, be entered and Required Actions taken if the inoperable RHRSW subsystem results in inoperable RHR shutdown cooling (SDC) (i.e., both the Unit I and Unit 2 RHRSW pumps in a loop are inoperable resulting in the associated RHR SDC system being inoperable). This is an exception to LCO 3.0.6 because the Required Actions of LCO 3.7.1 do not adequately compensate for the loss of RHR SDC Function (LCO 3.4.8).
Condition A is modified by a separate note to allow separate Condition entry for each valve. This is acceptable since the Required Action for this Condition provides appropriate compensatory actions.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.7-4 Revision 3
PPL Rev. 4 RHRSW System and UHS B 3.7.1 BASES ACTIONS A.1, A.2, and A.3 (continued)
With one spray array bypass valve not capable of being closed on demand, the associated Unit 1 and Unit 2 RHRSW subsystems cannot use the spray cooling function of the affected UHS return loop. As a result, the associated RHRSW subsystem must be declared inoperable.
With one spray array loop bypass valve not capable of being opened on demand, a return flow path is not available. As a result, the associated RHRSW subsystems must be declared inoperable.
With one spray array bypass manual valve not capable of being closed, the associated Unit 1 and Unit 2 RHRSW subsystems cannot use the spray cooling function of the affected UHS return path if the spray array bypass valve fails to close. As a result, the associated RHRSW subsystems must be declared inoperable.
With one spray array bypass manual valve not open, a return flow path is not available. As a result, the associated RHRSW subsystems must be declared inoperable.
With one large spray array valve not capable of being opened on demand, the associated Unit 1 and Unit 2 RHRSW subsystems cannot use the full required spray cooling capability of the affected UHS return path. With one large spray array valve not capable of being closed on demand, the associated Unit 1 and Unit 2 RHRSW subsystems cannot use the small spray array when loop flows are low as the required spray nozzle pressure is not achievable for the small spray array. As a result, the associated RHRSW subsystems must be declared inoperable.
With one small spray array valve not capable of being opened on demand, the associated Unit 1 and Unit 2 RHRSW subsystems cannot use the spray cooling function of the affected UHS return path for low loop flow rates. For a single failure of the large spray array valve in the closed position, design bases LOCA/LOOP calculations assume that flow is reduced on the affected loop within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> after the event to allow use of the. small spray array. With one small spray array valve not capable of being closed on demand, the associated Unit 1 and Unit 2 RHRSW subsystems cannot use the large spray array for a flow path as the required nozzle pressure is not achievable for the large spray array. As a result, the associated RHRSW subsystems must be declared inoperable.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.7-5 Revision 3
PPL Rev. 4 RHRSW System and UHS B 3.7.1 BASES ACTIONS A.1, A.2, and A.3 (continued)
With any UHS return path valve listed in Tables 3.7.1-1, 3.7.1-2, or 3.7.1-3 inoperable, the UHS return path is no longer single failure proof.
For combinations of inoperable valves in the same loop, the UHS spray capacity needed to support the OPERABILITY of the associated Unit 1 and Unit 2 RHRSW subsystems is affected. As a result, the associated RHRSW subsystems must be declared inoperable.
The 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> completion time to establish the flow path provides sufficient time to open a path and de-energize the appropriate valve in the open position.
The 72-hour completion time is based on the fact that, although adequate UHS spray loop capability exists during this time period, both units are affected and an additional single failure results in a system configuration that will not meet design basis accident requirements.
If an additional RHRSW subsystem on either Unit is inoperable, cooling capacity less than the minimum required for response to a design basis event would exist. Therefore, an 8-hour Completion Time is appropriate.
The 8-hour Completion Time provides sufficient time to restore inoperable equipment and there is a low probability that a design basis event would occur during this period.
B.1 Required Action B.1 is intended to ensure that appropriate actions are taken if one Unit 1 RHRSW subsystem is inoperable. Although designated and operated as a unitized system, the associated Unit 2 subsystem is directly connected to a common header, which can supply the associated RHR heat exchanger in either unit. The associated Unit 2 subsystem is considered capable of supporting the associated Unit 1 RHRSW subsystem when the Unit 2 subsystem is OPERABLE and can provide the assumed flow to the Unit 1 heat exchanger. A Completion time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, when the associated Unit 2 RHRSW subsystem is not capable of supporting the associated Unit 1 RHRSW subsystem, is allowed to restore the Unit 1 RHRSW subsystem to OPERABLE status.
In this configuration, the remaining OPERABLE Unit 1 RHRSW subsystem is adequate to perform the RHRSW heat removal function.
However, the overall reliability is reduced because a single failure in the OPERABLE RHRSW subsystem (continued)
SUSQUEHANNA - UNIT 1 TS / B 3.7-5a Revision 1
PPL Rev. 4 RHRSW System and UHS B 3.7.1 BASES ACTIONS B.1 (continued) could result in loss of RHRSW function. The Completion Time is based on the redundant RHRSW capabilities afforded by the OPERABLE subsystem and the low probability of an event occurring requiring RHRSW during this period.
With one RHRSW subsystem inoperable, and the respective Unit 2 RHRSW subsystem capable of supporting the respective Unit 1 RHRSW subsystem, the design basis cooling capacity for both units can still be maintained even considering a single active failure. However, the configuration does reduce the overall reliability of the RHRSW System.
Therefore, provided the associated Unit 2 subsystem remains capable of supporting its respective Unit 1 RHRSW subsystem, the inoperable RHRSW subsystem must be restored to OPERABLE status within 7 days.
The 7-day Completion Time is based on the remaining RHRSW System heat removal capability.
C.1 Required Action C. 1 is intended to ensure that appropriate actions are taken if both Unit I RHRSW subsystems are inoperable. Although designated and operated as a unitized system, the associated Unit 2 subsystem is directly connected to a common header, which can supply the associated RHR heat exchanger in either unit. With both Unit 1 RHRSW subsystems inoperable, the RHRSW system is still capable of performing its intended design function. However, the loss of an additional RHRSW subsystem on Unit 2 results in the cooling capacity to be less than the minimum required for response to a design basis event.
Therefore, the 8-hour Completion Time is appropriate. The 8-hour Completion Time for restoring one RHRSW subsystem to OPERABLE status is based on the Completion Times provided for the RHR suppression pool spray function.
With both Unit 1 RHRSW subsystems inoperable, and both of the Unit 2 RHRSW subsystems capable of supporting their respective Unit 1 RHRSW subsystem, if no additional failures occur which impact the RHRSW System, the remaining OPERABLE Unit 2 subsystems and flow paths provide adequate heat removal capacity following a design basis LOCA. However, capability for this alignment is not assumed in long term containment response analysis and an additional single failure in the RHRSW System could reduce the system capacity below that assumed in the safety analysis.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.7-6 Revision 3
PPL Rev. 4 RHRSW System and UHS B 3.7.1 BASES ACTIONS 0.1 (continued)
Therefore, continued operation is permitted only for a limited time. One inoperable subsystem is required to 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 />. The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time for restoring one inoperable RHRSW subsystem to OPERABLE status is based on the fact that the alternate loop is capable of providing the required cooling capability during this time period.
D.1 and D.2 If the RHRSW subsystems cannot be restored to OPERABLE status within the associated Completion Times, or the UHS is determined to be inoperable, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in 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 in 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 unit conditions from full power conditions in an orderly manner and without challenging unit systems.
SURVEILLANCE SR 3.7.1.1 REQUIREMENTS This SR verifies the water level to be sufficient for the proper operation of the RHRSW pumps (net positive suction head and pump vortexing are considered in determining this limit). The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency is based on operating experience related to trending of the parameter variations during the applicable MODES.
SR 3.7.1.2 Verification of the UHS temperature, which is the arithmetical average of the UHS temperature near the surface, middle and bottom levels, ensures that the heat removal capability of the ESW and RHRSW Systems are within the assumptions of the DBA analysis. The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Frequency is based on operating experience related to trending of the parameter variations during the applicable MODES.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.7-6a Revision 2
PPL Rev. 4 RHRSW System and UHS B 3.7.1 BASES SURVEILLANCE SR 3.7.1.3 REQUIREMENTS (continued) Verifying the correct alignment for each manual, power operated, and automatic valve in each RHRSW subsystem flow path provides assurance that the proper flow paths will exist for RHRSW operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves are verified to be in the correct position prior to locking, sealing, or securing. A valve is also allowed to be in the nonaccident position, and yet considered in the correct position, provided it can be realigned to its accident position. This is acceptable because the RHRSW System is a manually initiated system.
This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.
The 31-day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.
SR 3.7.1.4 The UHS spray array bypass valves are required to actuate to the closed position for the UHS to perform its design function. These valves receive an automatic signal to open upon emergency service water (ESW) or residual heat removal service water (RHRSW) system pump start and are required to be operated from the control room or the remote shutdown panel. A spray bypass valve is considered to be inoperable when it cannot be closed on demand. Failure of the spray bypass valve to close on demand puts the UHS at risk to exceed its design temperature. The failure of the spray bypass valve to open on demand makes one return path unavailable, and therefore the associated RHRSW subsystems must be declared inoperable. This SR demonstrates that the valves will move to their required positions when required. The 92-day Test Frequency is based upon engineering judgment and operating/testing history that indicates this frequency gives adequate assurance that the valves will move to their required positions when required.
(continued)
SUSQUEHANNA - UNIT 1 TS / B 3.7-6b Revision I
PPL Rev. 4 RHRSW System and UHS B 3.7.1 BASES SURVEILLANCE SR 3.7.1.5 REQUIREMENTS (continued) The UHS return header large spray array valves are required to open in order for the UHS to perform its design function. These valves are manually actuated from either the control room or the remote shutdown panel, under station operating procedure, when the RHRSW system is required to remove energy from the reactor vessel or suppression pool.
This SR demonstrates that the valves will move to their required positions when required. The 92-day Test Frequency is based upon engineering judgment and operating/testing history that indicates this frequency gives adequate assurance that the valves will move to their required positions when required.
SR 3.7.1.6 The small spray array valves HV-01224A2 and B2 are required to operate in order for the UHS to perform its design function. These valves are manually actuated from the control room or the remote shutdown panel, under station operating procedure, when the RHRSW system is required to remove energy from the reactor vessel or suppression pool. This SR demonstrates that the valves will move to their required positions when required. The 92-day Test Frequency is based upon engineering judgment and operating/ testing history that indicates this frequency gives adequate assurance that the valves will move to their required positions when required.
SR 3.7.1.7 The spray array bypass manual valves 012287A and B are required to operate in the event of a failure of the spray array bypass valves to close in order for the UHS to perform its design function.
REFERENCES 1. FSAR, Section 9.2.
- 2. FSAR, Chapter 6.
- 3. FSAR, Chapter 15.
- 4. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).
SUSQUEHANNA - UNIT 1 TS / B 3.7-6c Revision 2