ML13072A619

Revision to Technical Specifications Bases, Manual

ML13072A619
Person / Time
Site:	Susquehanna
Issue date:	03/01/2013
From:	Susquehanna
To:	Gerlach R Document Control Desk, Office of Nuclear Reactor Regulation
References
028401, 2013-8107
Download: ML13072A619 (62)

Text

Mar. 01, 2013 Page 1 of 3 MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2013-8107 USER INFORMATION:

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

TO: GERLACH*ROSE M 03/01/2013 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.

ATTENTION: "REPLACE" directions do not affect the Table of Contents, Therefore no TOC will be issued with the updated material.

TSB2 - TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 02/08/2013 ADD MANUAL TABLE OF CONTENTS DATE: 02/28/2013 CATEGORY: DOCUMENTS TYPE: TSB2 AIýo I

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SSES MANTAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL Table Of Contents Issue Date: 02/28/2013 Procedure Name Rev Issue Date Change ID Change Number TEXT LOES i1i 02/28/2013

Title:

LIST OF EFFECTIVE SECTIONS TEXT TOC 19 02/28/2013

Title:

TABLE OF CONTENTS TEXT 2.1.1 4 05/06/2009

Title:

SAFETY LIMITS (SLS) REACTOR CORE SLS TEXT 2.1.2 1 10/04/2007

Title:

SAFETY LIMITS (SLS) REACTOR COOLANT SYSTEM (RCS) PRESSURE SL TEXT 3.0 3 08/20/2009

Title:

LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY TEXT 3.1.1 1 03/24/2005

Title:

REACTIVITY CONTROL SYSTEMS SHUTDOWN MARGIN (SDM)

TEXT 3.1.2 0 11/18/2002 Title; REACTIVITY CONTROL SYSTEMS REACTIVITY ANOMALIES TEXT 3.1.3 2 01/19/2009

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD OPERABILITY TEXT 3.1.4 4 01/30/2009

Title:

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

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS TEXT 3.1.6 2 03/24/2005

Title:

REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL 03/01/13 Pagel Page 1 of of .a8 Report Date:

Report Date: 03/01/13

SSES MANUAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.1.7 3 10/04/2007

Title:

REACTIVITY CONTROL SYSTEMS STANDBY LIQUID CONTROL (SLC) SYSTEM TEXT 3.1.8 3 05/06/2009

Title:

REACTIVITY CONTROL SYSTEMS SCRAM DISCHARGE VOLUME (SDV) VENT AND DRAIN VALVES TEXT 3.2.1 4 05/06/2009

Title:

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

TEXT 3.2.2 3 05/06/2009

Title:

POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)

TEXT 3.2.3 2 05/06/2009

Title:

POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE LHGR TEXT 3.3.1.1 4 05/06/2009

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 2 04/09/2007

Title:

INSTRUMENTATION CONTROL ROD BLOCK INSTRUMENTATION TEXT 3.3.2.2 2 02/22/2012

Title:

INSTRUMENTATION FEEDWATER - MAIN TURBINE HIGH WATER LEVEL TRIP INSTRUMENTATION TEXT 3.3.3.1 8 02/28/2013

Title:

INSTRUMENTATION POST ACCIDENT MONITORING (PAM) INSTRUMENTATION LDCN 4816 TEXT 3.3.3.2 1 04/18/2005

Title:

INSTRUMENTATION REMOTE SHUTDOWN SYSTEM TEXT 3.3.4.1 1 05/06/2009 0

Title:

INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATION Report Date: 03/01/13 Page22 Page of of 88 Report Date: 03/01/13

SSES MANUAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.3.4.2 0 11/18/2002

Title:

INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP (ATWS-RPT) INSTRUMENTATION TEXT 3.3.5.1 4 08/20/2009

Title:

INSTRUMENTATION EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION TEXT 3.3.5.2 0 11/18/2002

Title:

INSTRUMENTATION REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM INSTRUMENTATION TEXT 3.3.6.1 4 05/06/2009

Title:

INSTRUMENTATION PRIMARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.6.2 4 09/01/2010

Title:

INSTRUMENTATION SECONDARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.7.1 2 10/27/2008

Title:

INSTRUMENTATION CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM INSTRUMENTATION TEXT 3.3.8.1 3 12/17/2007

Title:

INSTRUMENTATION LOSS OF POWER (LOP) INSTRUMENTATION TEXT 3.3.8.2 0 11/18/2002

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORING TEXT 3.4.1 4 07/20/2010

Title:

REACTOR COOLANT SYSTEM (RCS) RECIRCULATION LOOPS OPERATING TEXT 3.4.2 2 07/20/2010

Title:

REACTOR COOLANT SYSTEM (RCS) JET PUMPS TEXT 3.4.3 3 01/13/2012

Title:

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

TEXT 3.4.4 0 11/18/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE 03/1/1 Page..o.8.ep.t.Dte:

Page3 of 8 Report Date: 03/01/13

SSES MANUAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3. 4.5 3 03/10/2010

Title:

REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE TEXT 3.4.6 3 01/25/2011

Title:

REACTOR COOLANT SYSTEM (RCS) RCS LEAKAGE DETECTION INSTRUMENTATION TEXT 3.4.7 2 10/04/2007

Title:

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

Title:

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

- HOT SHUTDOWN TEXT 3.4.9 0 11/18/2002

Title:

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

- COLD SHUTDOWN TEXT 3.4.10 3 05/06/2009

Title:

REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE (P/T) LIMITS TEXT 3.4.11 0 11/18/2002

Title:

REACTOR COOLANT SYSTEM (RCS) REACTOR STEAM DOME PRESSURE TEXT 3. 5.1 3 01/16/2006

Title:

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

SYSTEM ECCS - OPERATING TEXT 3.5.2 0 11/18/2002

Title:

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

SYSTEM ECCS - SHUTDOWN TEXT 3.5.3 2 07/09/2010

Title:

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

SYSTEM RCIC SYSTEM TEXT 3.6.1.1 4 11/09/2011

Title:

PRIMARY CONTAINMENT TEXT 3.6.1.2 1 05/06/2009

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK Report Date: 03/01/13 Page44 Page of of 8 8 Report Date: 03/01/13

SSES MANUAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.6.1.3 11 04/14/2010

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)

TEXT 3.6.1.4 1 05/06/2009

Title:

CONTAINMENT SYSTEMS CONTAINMENT PRESSURE TEXT 3.6.1.5 1 10/05/2005

Title:

CONTAINMENT SYSTEMS DRYWELL AIR TEMPERATURE TEXT 3.6.1.6 0 11/18/2002

Title:

CONTAINMENT SYSTEMS SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKERS TEXT 3.6.2.1 2 12/17/2007

Title:

CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE TEXT 3.6.2.2 0 11/18/2002

Title:

CONTAINMENT SYSTEMS SUPPRESSION POOL WATER LEVEL TEXT 3.6.2.3 1 01/16/2006

Title:

CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL COOLING TEXT 3.6.2.4 0 11/18/2002

Title:

CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL SPRAY TEXT 3.6.3.1 2 06/13/2006

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS

• LDCN 5018 TEXT 3.6.3.2 1 04/18/2005

Title:

CONTAINMENT SYSTEMS DRYWELL AIR FLOW SYSTEM TEXT 3.6.3.3 1 02/28/2013

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION LDCN 5017 TEXT 3.6.4.1 8 03/26/2012

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT Page o 8 Repor e 0 1I Page 5 of 8 Report Date: 03/01/13

SSES MANUAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL 0 TEXT 3.6.4.2 7 02/28/2013

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT ISOLATION VALVES (SCIVS)

LDCN 5011 LDCN 5012 LDCN 5015 TEXT 3.6.4.3 4 09/21/2006

Title:

CONTAINMENT SYSTEMS STANDBY GAS TREATMENT (SGT) SYSTEM TEXT 3.7.1 5 04/27/2012

Title:

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

TEXT 3.7.2 2 05/02/2008

Title:

PLANT SYSTEMS EMERGENCY SERVICE WATER (ESW) SYSTEM TEXT 3.7.3 1 01/08/2010

Title:

PLANT SYSTEMS CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM TEXT 3.7.4 0 11/18/2002

Title:

PLANT SYSTEMS CONTROL ROOM FLOOR COOLING SYSTEM TEXT 3.7.5 1 10/04/2007

Title:

PLANT SYSTEMS MAIN CONDENSER OFFGAS TEXT 3.7.6 3 01/25/2011

Title:

PLANT SYSTEMS MAIN TURBINE BYPASS SYSTEM TEXT 3.7.7 1 10/04/2007

Title:

PLANT SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL TEXT 3.8.1 8 05/06/2009

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING TEXT 3.7.8 0 05/06/2009

Title:

MAINE TURBINE PRESSURE REGULATION SYSTEM Report Date: 03/01/13 Page 66.

Page of.

of 88 Report Date: 03/01/13

SSES MANUAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.8.2 0 11/18/2002

Title:

ELECTRICAL POWER SYST'EMS AC SOURCES - SHUTDOWN TEXT 3.8.3 3 02/28/2013

Title:

ELECTRICAL POWER SYST?EMS DIESEL FUEL OIL LUBE OIL AND STARTING AIR LDCN 4998 TEXT 3.8.4 3 01/19/2009

Title:

ELECTRICAL POWER SYST*EMS DC SOURCES - OPERATING TEXT 3.8.5 1 12/14/2006

Title:

ELECTRICAL POWER SYST'EMS DC SOURCES - SHUTDOWN TEXT 3.8.6 1 12/14/2006

Title:

ELECTRICAL POWER SYST EMS BATTERY CELL PARAMETERS TEXT 3.8.7 4 04/27/2012

Title:

ELECTRICAL POWER SYST'EMS DISTRIBUTION SYSTEMS - OPERATING TEXT 3.8.8 0 11/18/2002

Title:

ELECTRICAL POWER SYST?EMS DISTRIBUTION SYSTEMS - SHUTDOWN TEXT 3.9.1 0 11/18/2002

Title:

REFUELING OPERATIONS REFUELING EQUIPMENT INTERLOCKS TEXT 3.9.2 i 09/01/2010

Title:

REFUELING )PERATIONS REFUEL POSITION ONE-ROD-OUT INTERLOCK TEXT 3.9.3 0 11/18/2002

Title:

REFUELING )PERATIONS CONTROL ROD POSITION TEXT 3.9.4 0 11/18/2002

Title:

REFUELING C)PERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/18/2002

Title:

REFUELING C)PERATIONS CONTROL ROD OPERABILITY - REFUELING Pae2 o"8Rpr Dae 03/01/13....

Page7 of 8 Report Date: 03/01/13

SSES MANUALJ Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.9.6 1 10/04/2007

Title:

REFUELING OPERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL TEXT 3.9.7 0 11/18/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - HIGH WATER LEVEL TEXT 3.9.8 0 11/18/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - LOW WATER LEVEL TEXT 3.10.1 1 01/23/2008

Title:

SPECIAL OPERATIONS INSERVICE LEAK AND HYDROSTATIC TESTING OPERATION TEXT 3.10.2 0 11/18/2002

Title:

SPECIAL OPERATIONS REACTOR MODE SWITCH INTERLOCK TESTING TEXT 3.10.3 0 11/18/2002

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL- HOT SHUTDOWN TEXT 3.10.4 0 11/18/2002

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - COLD SHUTDOWN TEXT 3.10.5 0 11/18/2002

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD DRIVE (CRD) REMOVAL - REFUELING TEXT 3.10.6 0 11/18/2002

Title:

SPECIAL OPERATIONS MULTIPLE CONTROL ROD WITHDRAWAL - REFUELING TEXT 3.10.7 1 03/24/2005

Title:

SPECIAL OPERATIONS CONTROL ROD TESTING - OPERATING TEXT 3.10.8 2 04/09/2007

Title:

SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING Report Date: 03/01/13 Page8 Page 8 of of 8 8 Report Date: 03/01/13

TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)

B2.0 SAFETY LIMITS (SLs) ............................................................................ TS/B2.0-1 B2.1.1 Reactor Core SLs ..................................................................... TS/B2.0-1 B2.1.2 Reactor,Coolant System (RCS) Pressure SL ....................... TS/B2.0-6 B3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ........ TS/B3.0-1 B3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ...................... TSIB3.0-10 B3.1 REACTIVITY CONTROL SYSTEMS .................................................... B3.1-1 B3.1.1 Shutdown Margin (SDM) ................................................................ B3.1-1 B3.1.2 Reactivity Anom alies ...................................................................... B3.1-8 B3.1.3 Control Rod OPERABILITY ............................................................ B3.1-13 B3.1.4 Control Rod Scram Times ........................................................ TS/B3.1-22 B3.1.5 Control Rod Scram Accumulators ............................ .... TS/B3.1-29 B3.1.6 Rod Pattern Control ................................................................. TS/B3.1-34 B3.1.7 Standby Liquid Control (SLC) System ...................................... TS/B3.1-39 B3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves .......... TS/B3.1-47 B3.2 POWER DISTRIBUTION LIMITS ................................................... TS/B3.2-1 B3.2.1 Average Planar Linear Heat Generation Rate (APLHGR) ........ TS/B3.2-1 B3.2.2 Minimum Critical Power Ratio (MCPR) ..................................... TS/B3.2-5 B3.2.3 Linear Heat Generation Rate (LHGR) ....................................... TS/B3.2-10 B3.3 INSTRUMENTATION ..................................................................... TS/B3.3-1 B3.3.1.1 Reactor Protection System (RPS) Instrumentation ................... TS/B3.3-1 B3.3.1.2 Source Range Monitor (SRM) Instrumentation ......................... TS/B3.3-35 B3.3.2.1 Control Rod Block Instrumentation ........................................... TS/B3.3-44 B3.3.2.2 Feedwater - Main Turbine High Water Level Trip Instrum entation ................................................................... TS/B 3.3-55 B3.3.3.1 Post Accident Monitoring (PAM) Instrumentation ..................... TS/B3.3-64 B3.3.3.2 Remote Shutdown System ........................... B3.3-76 B3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrum entation ......................................................................... B3.3-81 B3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation .................................. B3.3-92 B3.3.5.i Emergency Core Cooling System (ECCS)

Instrum entation .................................................................... TS/B3.3-1 01 B3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrum entation ......................................................................... B3.3-135 B3.3.6.1 Primary Containment Isolation Instrumentation .............................. B3.3-147 B3.3.6.2 Secondary Containment Isolation Instrumentation ................... TS/B3.3-180 B3.3.7.1 Control Room Emergency Outside Air Supply (CREOAS)

System Instrumentation ...................................................... TS/B3.3-192 (continued)

SUSQUEHANNA - UNIT 2 TS / B TOC - 1 Revision 19

TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)

B3.3 INSTRUMENTATION (continued)

B3.3.8.1 Loss of Power (LOP) Instrumentation ....................................... TS/B3.3-206 B3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ................................................................................ B3.3-2 14 B3.4 REACTOR COOLANT SYSTEM (RCS) ......................................... TS/B3.4-1 B3.4.1 Recirculation Loops Operating ................................................. TS/B3.4-1 B3.4.2 Jet Pum ps ................................................................................ T S/B 3.4-10 B3.4.3 Safety/Relief Valves (S/RVs) .................................................... TS/B3.4-15 B3.4.4 RCS Operational LEAKAGE ........................................................... B3.4-19 B3.4.5 RCS Pressure Isolation Valve (PIV) Leakage ........................... TS/B3.4-24 B3.4.6 RCS Leakage Detection Instrumentation .................................. TS/B3.4-30 B3.4.7 RCS Specific Activity ................................................................ TS/B3.4-35 B3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown ........................................................... B3.4-39 B3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown ......................................................... B3.4-44 B3.4.10 RCS Pressure and Temperature (P/T) Limits ........................... TS/B3.4-49 B3.4.11 Reactor Steam Dome Pressure TS/B3.4-58 B3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ............................ TS/B3.5-1 B3.5.1 ECCS - Operating ................................................................... TS/B3.5-1 B3.5.2 ECCS - Shutdown ......................................................................... B3.5-19 B3.5.3 RCIC System ........................................................................... TS/B3.5-25 B3.6 CONTAINMENT SYSTEMS ............................................................ TS/B3.6-1 B3.6.1.1 Primary Containment ................................................................ TS/B3.6-1 B3.6.1.2 Primary Containment Air Lock ........................................................ B3.6-7 B3.6.1.3 Primary Containment Isolation Valves (PCIVs) ......................... TS/B3.6-15 B3.6.1.4 Containment Pressure .............................................................. TS/B3.6-40 B3.6.1.5 Drywell Air Temperature ........................................................... TS/B3.6-43 B3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers ................ TS/B3.6-46 B3.6.2.1 Suppression Pool Average Temperature ........................................ B3.6-52 B3.6.2.2 Suppression Pool Water Level ....................................................... B3.6-58 B3.6.2.3 Residual Heat Removal (RHR) Suppression Pool C oo ling ..................................................................................... B3 .6-6 1 B3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ................ B3.6-65 B3.6.3.1 Not Used ................................................................................. TS/B3.6-69 B3.6.3.2 Drywell Air Flow System ................................................................. B3.6-75 B3.6.3.3 Primary Containment Oxygen Concentration ............................ TS/B3.6-80 B3.6.4.1 Secondary Containment ........................................................... TS/B3.6-83 B3.6.4.2 Secondary Containment Isolation Valves (SCIVs) .................... TS/B3.6-90 B3.6.4.3 Standby Gas Treatment (SGT) System .................................... TS/B3.6-1 00 (continued)

SUSQUEHANNA - UNIT 2 TS / B TOC - 2 Revision 19

TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS BASES)

B3.7 PLANT SYSTEMS ......................................................................... TS/B3.7-1 B3.7.1 Residual Heat Removal Service Water (RHRSW) System and the Ultimate Heat Sink (UHS) ...................................... TS/B3.7-1 B3.7.2 Emergency Service Water (ESW) System ................................ TS/B3.7-7 B3.7.3 Control Room Emergency Outside Air Supply (CREOAS) System ............................................................. TS/B3.7-12 B3.7.4 Control Room Floor Cooling System ........................................ TS/B3.7-19 B3.7.5 Main Condenser Offgas ........................................................... TS/B3.7-24 B3.7.6 Main Turbine Bypass System ................................................... TS/B3.7-27 B3.7.7 Spent Fuel Storage Pool Water Level ...................................... TS/B3.7-31 B3.7.8 Main Turbine Pressure Regulation System .............................. TS/B3.7-34 B3.8 ELECTRICAL POWER SYSTEM ................................................... TS/B3.8-1 B3.8.1 AC Sources - Operating .......................................................... TS/B3.8-1 B3.8.2 AC Sources - Shutdown ................................................................ B3.8-39 B3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ................................ TS/B3.8-47 B3.8.4 DC Sources - Operating .......................................................... TS/B3.8-56 B3.8.5 DC Sources - Shutdown .......................................................... TS/B3.8-70 B3.8.6 Battery Cell Parameters ........................................................... TS/B3.8-77 B3.8.7 Distribution Systems - Operating ................................................... B3.8-84 B3.8.8 Distribution Systems - Shutdown ................................................... B3.8-94 B3.9 REFUELING OPERATIONS .......................................................... TS/B3.9-1 B3.9.1 Refueling Equipment Interlocks ................................................ TS/B3.9-1 B3.9.2 Refuel Position One-Rod-Out Interlock ..................................... TS/B3.9-5 B3.9.3 Control Rod Position ...................................................................... B3.9-9 B3.9.4 Control Rod Position Indication ...................................................... B3.9-12 B3.9.5 Control Rod OPERABILITY- Refueling ......................................... B3.9-16 B3.9.6 Reactor Pressure Vessel (RPV) Water Level ........................... TS/B3.9-19 B3.9.7 Residual Heat Removal (RHR) - High Water Level ........................ B3.9-22 B3.9.8 Residual Heat Removal (RHR) - Low Water Level ......................... B3.9-26 B3.10 SPECIAL OPERATIONS ............................................................ TS/B3.10-1 B3.10.1 Inservice Leak and Hydrostatic Testing Operation ............... TS/B3.10-1 B3.10.2 Reactor Mode Switch Interlock Testing .......................................... B3.10-6 B3.10.3 Single Control Rod Withdrawal - Hot Shutdown ............................. B3.10-11 B3.10.4 Single Control Rod Withdrawal - Cold Shutdown ........................... B3.10-16 B3.10.5 Single Control Rod Drive (CRD) Removal - Refueling ................... B3.10-21 B3.10.6 Multiple Control Rod Withdrawal - Refueling .................................. B3.10-26 B3.10.7 Control Rod Testing - Operating .................................................... B3.10-30 B3.10.8 SHUTDOWN MARGIN (SDM) Test- Refueling ............................. B3.10-34 TSB2 TOC.doc 2/26/2013 Revision 19 UNIT 22 SUSQUEHANNA - UNIT SUSQUEHANNA - TS I/ B TS TOC -3 B TOC -3 Revision 19

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

Section Title Revision TOC Table of Contents 19 B 2.0 SAFETY LIMITS BASES Page TS / B 2.0-1 1 Pages TS / B 2.0-2 and TS / B 2.0-3 4 Page TS / B 2.0-4 6 Pages TS / B 2.0-5 through TS / B 2.0-8 1 B 3.0 LCO AND SR APPLICABILITY BASES Page TS / B 3.0-1 1 Pages TS / B 3.0-2 through TS / B 3.0-4 0 Pages TS / B 3.0-5 through TS / B 3.0-7 1 Page TS / B 3.0-8 3 Pages TS / B3.0-9 through Page TS / B 3.0-11 2 Page TS / B 3.0-1 la 0 Page TS / B 3.0-12 1 Pages TS / B 3.0-13 through TS / B 3.0-15 2 Pages TS / B 3.0-16 and TS / B 3.0-17 0 B 3.1 REACTIVITY CONTROL BASES Pages B 3.1-1 through B 3.1-4 0 Page TS / B 3.1-5 1 Pages TS / B 3.1-6 and TS / B 3.1-7 2 Pages B 3.1-8 through B 3.1-13 0 Page TS / B 3.1-14 1 Page TS / B 3.1-15 0 Page TS / B 3.1-16 1 Pages TS / B 3.1-17 through TS / B 3.1-19 0 Pages TS / B 3.1-20 and TS / B 3.1-21 1 Page TS / B 3.1-22 0 Page TS / B 3.1-23 1 Page TS / B 3.1-24 0 Pages TS / B 3.1-25 through TS / B 3.1-27 1 Page TS / B 3.1-28 2 Page TS / 3.1-29 1 Pages B 3.1-30 through B 3.1-33 0 Pages TS / B 3.1.34 through TS / B 3.1-36 1 Pages TS / B 3.1-37 and TS / B 3.1-38 2 Pages TS / B 3.1-39 and TS / B 3.1-40 2 Page TS / B 3.1-40a 0 Page TS / B 3.1-41 1 Page TS / B 3.1-42 2 Revision 111 TS/BLOES-1 UNIT 2 SUSQUEHANNA - UNIT SUSQUEHANNA 2 TS / B LOES-1 .Revision 111

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Section Title Revision Pages TS / B 3.1-43 1 Page TS / B 3.1-44 0 Page TS / B 3.1-45 3 Page TS / B 3.1-46 0 Page TS / B 3.1-47 1 Pages TS / B 3.1-48 and TS / B 3.1-49 1 Page B 3.1-50 0 Page TS / B 3.1-51 3 B 3.2 POWER DISTRIBUTION LIMITS BASES Pages TS / B 3.2-1 and TS / B 3.2-2 2 Page TS / B 3.2-3 4 Page TS / B 3.2-4 1 Page TS/ B 3.2-5 3 Page TS /B 3.2-6 4 Page TS /B 3.2-7 3 Pages TS / B 3.2-8 and TS / B 3.2-9 4 Pages TS / B 3.2-10 through TS / B 3.2-12 2 Page TS / B 3.2-13 1 B 3.3 INSTRUMENTATION Pages TS / B 3.3-1 through TS /B 3.3-4 1 Page TS / B 3.3-5 2 Page TS / B 3.3-6 1 Page TS / B 3.3-7 3 Page TS / B 3.3-8 4 Pages TS / B 3.3-9 through TS /B 3.3-13 3 Page TS / B 3.3-14 4 Pages TS / B 3.3-15 and TS / B 3.3-16 2 Pages TS / B 3.3-17 through TS / B 3.3-21 3 Pages TS / B 3.3-22 through TS / B 3.3-27 2 Page TS / B 3.3-28 3 Page TS / B 3.3-29 4 Pages TS / B 3.3-30 and TS / B 3.3-31 3 Pages TS / B 3.3-32 and TS / B 3.3-33 4 Page TS /B 3.3-34 2 Page TS / B 3.3-34a 1 Pages TS / B 3.3-34b through TS / B 3.3-34d 0 Page TS / B 3.3-34e 1 Pages TS / B 3.3-34f through TS / B 3.3-34i 0 Pages TS / B 3.3-35 and TS / B 3.3-36 2 Pages TS / B 3.3-37 and TS / B 3.3-38 1 Revision 111 TS/8 LOES-2 SUSQUEHANNA - UNIT SUSQUEHANNA -

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Section Title Revision Page TS / B 3.3-39 2 Pages TS / B 3.3-40 through TS / B 3.3-43 2 Pages TS / B 3.3-44 through TS / B 3.3-54 3 Pages TS / B 3.3-54a through TS / B 3.3-54e 0 Page TS / B 3.3-55 2 Page TS / B 3.3-56 0 Page TS / B 3.3-57 1 Page TS / B 3.3-58 0 Page TS / B 3.3-59 1 Page TS / B 3.3-60 0 Page TS / B 3.3-61 1 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 Page TS / B 3.3-66 4 Page TS / B 3.3-67 3 Page TS / B 3.3-68 4 Page TS / B 3.3.69 5 Page TS / B 3.3-70 4 Page TS / B 3.3-71 3 Pages TS / B 3.3-72 and TS / B 3.3-73 2 Page TS / B 3.3-74 3 Page TS / B 3.3-75 2 Pages TS / B 3.3-75a and TS / B 3.3-75 b 6 Page TS / B 3.3-75c 6 Pages B 3.3-76 and TS / B 3.3-77 0 Page TS / B 3.3-78 1 Pages B 3.3-79 through B 3.3-81 0 Page TS / B 3.3-82 1 Page B 3.3-83 0 Pages TS / B 3.3-84 and TS / B 3.3-85 1 Page 3.3-86 0 Page TS / B 3.3-87 1 Page B 3.3-88 0 Page TS / B 3.3-89 1 Pages B 3.3-90 and B 3.3-91 0 Pages TS / B 3.3-92 through TS / B 3.3-103 1 Page TS / B 3.3-104 3 Pages TS / B 3.3-105 and TS / B 3.3-106 1 Page TS / B 3.3-107 2 Page TS / B 3.3-108 1 Page TS / B 3.3-109 2 Pages TS / B 3.3-110 through TS/ B 3.3-112 1 Page TS / B 3.3-113 2 Revision 111 UNIT 2 TS/B LOES-3 SUSQUEHANNA SUSQUEHANNA - UNIT 2 TS / [] LOES-3 Revision 111

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Section Title Revision Page TS / B 3.3-114 1 Page TS / B 3.3-115 2 Page TS / B 3.3-116 3 Pages TS / B 3.3-117 and TS / B 3.3-118 2 Pages TS / B 3.3-119 through TS / B 3.3-120 1 Pages TS / B 3.3-121 and TS / B 3.3-122 2 Page TS / B 3.3-123 1 Page TS / B 3.3-124 2 Page TS / B 3.3-124a 0 Page TS / B 3.3-125 1 Page TS / B 3.3-126 2 Page TS / B 3.3-127 3 Page TS / B 3.3-128 2 Pages TS / B 3.3-129 through TS / B 3.3-131 1 Page TS / B 3.3-132 - 2 Pages TS / B 3.3-133 and TS / B 3.3-134 1 Pages B 3.3-135 through B 3.3-137 0 Page TS / B 3.3-138 1 Pages B 3.3-139 through B 3.3-149 0 Pages TS/ B 3.3-150 and TS / B 3.3-151 1 Pages TS / B 3.3-152 through TS / B 3.3-154 2 Page TS / B 3.3-155 1 Pages TS / B 3.3-156 through TS / B 3.3-158 2 Pages TS / B 3.3-159 through TS / B 3.3-161 1 Page TS / B 3.3-162 1 Page TS / B 3.3-163 2 Page TS / B 3.3-164 1 Pages TS / B 3.3-165 and TS / B 3.3-166 2 Pages TS / B 3.3-167 and TS / B 3.3-168 1 Pages TS / B 3.3-169 and TS / B 3.3-170 2 Pages TS / B 3.3-171 through TS / B 3.3-177 1 Page TS / B 3.3-178 2 Page TS / B 3.3-179 3 Page TS / B 3.3-179a 2 Page TS ! B 3.3-180 1 Page TS / B 3.3-181 3 Page TS / B 3.3-182 1 Page TS / B 3.3-183 2 Page TS / B 3.3-184 1 Page TS / B 3.3-185 4 Page TS / B 3.3-186 1 Pages TS / B 3.3-187 and TS / B 3.3-188 2 Pages TS / B 3.3-189 through TS / B 3.3-191 1 Revision 111 UNIT 2 TS/BLOES-4 SUSQUEHANNA - UNIT SUSQUEHANNA -

2 TS / B LOES-4 Revision 111

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Section Title Revision Page TS / B 3.3-192 0 Page TS / B 3.3-193 1 Pages TS/B 3.3-194 and TS / B 3.3-195 0 Page TS / B 3.3-196 2 Pages TS / B 3.3-197 through TS / B 3.3-205 0 Page TS / B 3.3-206 1 Pages B 3.3-207 through B 3.3-209 0 Page TS / B 3.3-210 1 Page TS / B 3.3-211 2 Pages TS / B 3.3-212 and TS / B 3.3-213 1 Pages B 3.3-214 through B 3.3-220 0 B 3.4 REACTOR COOLANT SYSTEM BASES Pages TS / B 3.4-1 and TS / B 3.4-2 2 Pages TS / B 3.4-3 through TS / B 3.4-5 4 Pages TS / B 3.4-6 through TS / B 3.4-9 3 Page TS / B 3.4-10 1 Pages TS / B 3.4-11 and TS / B 3.4-12 0 Page TS / B 3.4-13 1 Page TS / B 3.4-14 0 Page TS / B 3.4-15 2 Pages TS / B 3.4-16 and TS / B 3.4-17 4 Page TS / B 3.4-18 w 2 Pages B 3.4-19 through B 3.4-23 0 Pages TS / B 3.4-24 through TS / B 3.4-27 0 Page TS / B 3.4-28 1 Page TS / B 3.4-29 3 Page TS / B 3.4-30 1 Page TS / B 3.4-31 0 Pages TS / B 3.4-32 and TS / B 3.4-33 1 Page TS / B 3.4-34 0 Pages TS / B 3.4-35 and TS / B 3.4-36 1 Page TS / B 3.4-37 2 Page B 3.4-38 1 Pages B 3.4-39 and B 3.4-40 0 Page TS / B 3.4-41 1 Pages B 3.4-42 through B 3.4-48 0 Page TS / B 3.4-49 3 Pages TS / B 3.4-50 through TS / B 3.4-52 2 Page TS / B 3.4-53 1 Pages TS / B 3.4-54 through TS / B 3.4-57 2 Pages TS / B 3.4-58 through TS / B 3.4-60 1 Revision 111 TS/BLOES-5 SUSQUEHANNA -

UNIT 2 SUSQUEHANNA - UNIT 2 TS / B LOES-5 Revision 111

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Section Title Revision B 3.5 ECCS AND RCIC BASES Pages TS / B 3.5-1 and TS / B 3.5-2 1 Pages TS / B 3.5-3 through TS / B 3.5-6 2 Pages TS / B 3.5-7 through TS / B 3.5-10 1 Pages TS / B 3.5-11 and TS / B 3.5-12 2 Pages TS / B 3.6-13 and TS / B 3.5-14 1 Pages TS / B 3.5-15 and TS / B.3.5-16 2 Page TS / B 3.5-17 3 Page TS / B 3.5-18 1 Pages B 3.5-19 through B 3.5-24 0 Pages TS / B 3.5-25 through TS / B 3.5-27 1 Page TS / B 3.5-28 0 Page TS / B 3.5-29 1 Pages TS / B 3.5-30 and TS / B 3.5-31 0 B 3.6 CONTAINMENT SYSTEMS BASES Page TS / B 3.6-1 2 Page TS / B 3.6-1a 3 Page TS / B 3.6-2 4 Page TS / B 3.6-3 3 Page TS / B 3.6-4 4 Page TS / B 3.6-5 3 Page TS / B 3.6-6 4 Pages TS / B 3.6-6a and TS / B 3.6-6b 3 Page TS / B 3.6-6c 0 Page B 3.6-7 0 Page TS / 3.6-8 1 Pages B 3.6-9 through B 3.6-14 0 Page TS / B 3.6-15 3 Page TS / B 3.6-15a 0 Page TS / B 3.6-15b 3 Pages TS / B 3.6-16 and TS / B 3.6-17 2 Page TS / B 3.6-17a 0 Pages TS / B 3.6-18 and TS / B 3.6-19 1 Page TS / B 3.6-20 2 Page TS / B 3.6-21 3 Pages TS / B 3.6-21a and TS / B 3.6-21b 0 Pages TS / B 3.6-22 and TS / B 3.6-23 2 Pages TS / B 3.6-24 and TS / B 3.6-25 1 Pages TS / B 3.6-26 and TS / B 3.6-27 3 Page TS / B 3.6-28 7 Page TS / B 3.6-29 5 Page TS / B 3.6-29a 0 Page TS / B 3.6-30 2 Revision 111 TS / B LOES-6 SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-6 Revision 111

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

Section Title Revision Page TS / B 3.6-31 3 Pages TS / B 3.6-32 and TS / B 3.6-33 2 Page TS / B 3.6-34 1 Page TS / B 3.6-35 3 Pages TS / B 3.6-36 and TS / B 3.6-37 2 Page TS / B 3.6-38 3 Page TS / B 3.6-39 7 Page TS / B 3.6-40 1 Pages B 3.6-41 and B 3.6-42 0 Pages TS / B 3.6-43 and TS / B 3.6-44 1 Page TS / B 3.6-45 2 Pages TS / B 3.6-46 through TS / B 3.6-50 1 Page TS / B 3.6-51 2 Pages B 3.6-52 through B 3.6-55 0 Pages TS / B 3.6-56 and TS / B 3.6-57 2 Pages B 3.6-58 through B 3.6-62 0 Pages TS / B 3.6-63 and TS / B 3.6-64 1 Pages B 3.6-65 through B 3.6-68 0 Pages B 3.6-69 through B 3.6-71 1 Page TS / B 3.6-72 2 Pages TS / B 3.6-73 and TS / B 3.6-74 1 Pages B 3.6-75 and B 3.6-76 0 Page TS / B 3.6-77 1 Pages B 3.6-78 and B 3.6-79 0 Page TS / B 3.6-80 1 Pages TS / B 3.6-81 and TS / B 3.6-82 0 Page TS / B 3.6-83 4 Page TS / B 3.6-84 2 Page TS / B 3.6-85 4 Page TS / B 3.6-86 through TS / B 3.6-87a 2 Page TS / B 3.6-88 4 Page TS / B 3.6-89 2 Pages TS / B 3.6-90 and TS / B 3.6-91 3 Page TS / B 3.6-92 2 Pages TS / B 3.6-93 through TS / B 3.6-95 1 Page TS / B 3.6-96 2 Page TS / B 3.6-97 1 Page TS / B 3.6-98 2 Page TS / B 3.6-99 6 Page TS / B 3.6-99a 4 Page TS / B 3.6-99b 2 Pages TS / B 3.6-100 and TS / B 3.6-101 1 Pages TS / B 3.6-102 and TS / B 3.6-103 2 Page TS / B 3.6-104 3 Page TS / B 3.6-105 2 Page TS / B 3.6-106 3 SUSQUEHANNA - UNIT 2 TS / B LOES-7 Revision 111

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Section Title Revision B 3.7 PLANT SYSTEMS BASES Page TS / B 3.7-1 3 Page TS / B 3.7-2 4 Pages TS / B 3.7-3 through TS / B 3.7-5 3 Page TS / B 3.7-5a 2 Page TS / B 3.7-6 4 Page TS / B 3.7-6a 3 Page TS / B 3.7-6b 2 Page TS / B 3.7-6c 3 Page TS / B 3.7-7 3 Page TS / B 3.7-8 2 Pages B 3.7-9 through B 3.7-11 0 Pages TS / B 3.7-12 and TS / B 3.7-13 2 Pages TS / B 3.7-14 through TS / B 3.7-18 3 Page TS / B 3.7-18a 1 Pages TS / B 3.7-18b through TS / B 3.7-18e 0 Pages TS / B 3.7-19 through TS / B 3.7-24 1 Pages TS / B 3.7-25 and TS / B 3.7-26 0 Page TS / B 3.7-27 4 Pages TS / B 3.7-28 and TS / B 3.7-29 3 Pages TS / B 3.7-30 and TS / B 3.7-31 1 Page TS / B 3.7-32 0 Page TS / B 3.7-33 1 Pages TS / B 3.7-34 through TS / B 3.7-37 0 B 3.8 ELECTRICAL POWER SYSTEMS BASES Page TS / B 3.8-1 1 Pages B 3.8-2 and B 3.8-3 0 Page TS / B 3.8-4 1 Pages TS / B 3.8-4a and TS / B 3.8-4b 0 Pages TS / B 3.8-5 and TS / B 3.8-6 3 Page TS / B 3.8-6a 1 Pages B 3.8-7 and B 3.8-8 0 Page TS / B 3.8-9 2 Pages TS / B 3.8-10 and TS / B 3.8-11 1 Pages B 3.8-12 through B 3.8-18 0 Page TS / B 3.8-19 1 Pages B 3.8-20 through B 3.8-22 0 Page TS / B 3.8-23 1 Page B 3.8-24 0 Pages TS / B 3.8-25 and TS / B 3.8-26 1 Pages B 3.8-27 through B 3.8-35 0 Page TS / B 3.8-36 1 Revision 111 UNIT 2 TS/BLOES-8 SUSQUEHANNA - UNIT SUSQUEHANNA -

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Section Title Revision Page TS / B 3.8-37 0 Page TS / B 3.8-38 1 Pages TS / B 3.8-39 through TS / B 3.8-46 0 Page TS / B 3.8-47 2 Pages TS / B 3.8-48 through TS / B 3.8-50 0 Pages TS / B 3.8-51 and TS / B 3.8-52 2 Page TS / B 3.8-53 1 Page TS / B 3.8-54 0 Page TS / B 3.8-55 1 Pages TS / B 3.8-56 through TS / B 3.8-59 2 Pages TS / B 3.8-60 through TS / B 3.8-64 3 Page TS / B 3.8-65 4 Page TS / B 3.8-66 5 Pages TS / B 3.8-67 and TS / B 3.8-68 4 Page TS / B 3.8-69 5 Pages TS / B 3.8-70 through TS / B 3.8-83 1 Pages TS / B 3.8-83A through TS / B 3.8-83D 0 Pages B 3.8-84 through B 3.8-85 0 Page TS / B 3.8-86 1 Page TS / B 3.8-87 2 Pages TS / B 3.8-88 and TS / B 3.8-89 1 Page TS / B 3.8-90 2 Pages TS / B 3.8-91 through TS / B 3.8-93 1 Pages B 3.8-94 through B 3.8-99 0 B 3.9 REFUELING OPERATIONS BASES Pages TS / B 3.9-1 and TS / B 3.9-2 1 Pages TS / B 3.9-2a through TS / B 3.9-5 1 Pages TS / B 3.9-6 through TS / B 3.9-8 0 Pages B 3.9-9 through B 3.9-18 0 Pages TS / B 3.9-19 through TS / B 3.9-21 1 Pages B 3.9-22 through B 3.9-30 0 B 3.10 SPECIAL OPERATIONS BASES Page TS / B 3.10-1 2 Pages TS / B 3.10-2 through TS / B 3.10-5 1 Pages B 3.10-6 through B 3.10-32 0 Page TS / B 3.10-33 2 Page B 3.10-34 0 Page B 3.10-35 1 Pages B 3.10-36 and B 3.10-37 0 Page B 3.10-38 1 Page TS / B 3.10-39 2 TSB2 Text LOES.doc 02/26/2013 SUSQUEHANNA - UNIT 2 TS / B LOES-9 Revision 111

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 B 3.3 INSTRUMENTATION B 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation BASES BACKGROUND The primary purpose of the PAM instrumentation is to display plant variables that provide information required by the control room operators during accident situations. This information provides the necessary support for the operator to take the manual actions for which no automatic control is provided and that are required for safety systems to accomplish their safety functions for Design Basis Events.

The instruments that monitor these variables are designated as Type A, Category I, and non-Type A, Category I, in accordance with Regulatory Guide 1.97 (Ref. 1).

The OPERABILITY of the accident monitoring instrumentation ensures that there is sufficient information available on selected plant parameters to monitor and assess plant status and behavior following an accident. This capability is consistent with the recommendations of Reference 1.

APPLICABLE The PAM instrumentation LCO ensures the OPERABILITY of SAFETY ANALYSES Regulatory Guide 1.97, Type A variables so that the control room operating staff can:

• Perform the diagnosis specified in the Emergency Operating Procedures (EOPs). These variables are restricted to preplanned actions for the primary success path of Design Basis Accidents (DBAs), (e.g., loss of coolant accident (LOCA)), and

• Take the specified, preplanned, manually controlled actions for which no automatic control is provided, which are required for safety systems to accomplish their safety function.

The PAM instrumentation LCO also ensures OPERABILITY of Category I, non-Type A, variables so that the control room operating staff can:

Determine whether systems important to safety are performing their intended functions; (continued)

SUSQUEHANNA-UNIT2 TS / B 3.3-64 Revision 2

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES APPLICABLE 0 Determine the potential for causing a gross breach of the barriers SAFETY ANALYSES to radioactivity release; (continued)

" Determine whether a gross breach of a barrier has occurred; and

" Initiate action necessary to protect the public and for an estimate of the magnitude of any impending threat.

The plant specific Regulatory Guide 1.97 Analysis (Ref. 2 and 3) documents the process that identified Type A and Category I, non-Type A, variables.

Accident monitoring instrumentation that satisfies the definition of Type A in Regulatory Guide 1.97 meets Criterion 3 of the NRC Policy Statement. (Ref. 4) Category I, non-Type A, instrumentation is retained in Technical Specifications (TS) because they are intended to assist operators in minimizing the consequences of accidents. Therefore, these Category I variables are important for reducing public risk.

LCO LCO 3.3.3.1 requires two OPERABLE channels for all but one Function to ensure that no single failure prevents the operators from being presented with the information necessary to determine the status of the plant and to bring the plant to, and maintain it in, a safe condition following that accident.

Furthermore, provision of two channels allows a CHANNEL CHECK during the post accident phase to confirm the validity of displayed information.

The exception isolation valve to the two (PCIV) channelIn requirement position. this case, theis important primary containment information is the status of the primary containment penetrations. The LCO requires one position indicator for each active PCIV. This is sufficient to redundantly verify the isolation status of each isolable penetration either via indicated status of the active valve and prior knowledge of passive valve or via system boundary (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.3-65 Revision 2

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES LCO status. If a normally active PCIV is known to be closed and (continued) deactivated, position indication is not needed to determine status.

Therefore, the position indication for valves in this state is not required to be OPERABLE.

The following list is a discussion of the specified instrument Functions listed in Table 3.3.3.1-1 in the accompanying LCO. Table B3.3.3.1-1 provides a listing of the instruments that are used to meet the operability requirements for the specific functions.

1. Reactor Steam Dome Pressure Reactor steam dome pressure is a Type A, Category 1, variable provided to support monitoring of Reactor Coolant System (RCS) integrity and to verify operation of the Emergency Core Cooling Systems (ECCS). Two independent pressure channels, consisting of three wide range control room indicators and one wide range control room recorder per channel with a range of 0 psig to 1500 psig, monitor pressure. The wide range recorders are the primary method of indication available for use by the operators during an accident, therefore, the PAM Specification deals specifically with this portion of the instrument channel.

2. Reactor Vessel Water Level Reactor vessel water level is a Type A, Category 1, variable provided to support monitoring of core cooling and to verify operation of the ECCS. A combination of three different level instrument ranges, with two independent channels each, monitor Reactor Vessel Water Level.

The extended range instrumentation measures from -150 inches to 180 inches and outputs to three control room level indicators per channel. The wide range instrumentation measures from -150 inches to 60 inches and outputs to one control room recorder and three control room indicators per channel. The fuel zone range instrumentation measures from -310 inches to -110 inches and outputs to a control room recorder (one channel) and a control room indicator (one channel). These three ranges of instruments combine to provide level indication from the bottom of the Core to above the main steam line. The wide range level recorders, the fuel zone level indicator and level recorder, and one inner ring extended range level indicator per channel are the primary method of indication available for use by the operator during an accident, therefore the PAM (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.3-66 Revision 4

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES LCO 2. Reactor Vessel Water Level (continued)

Specification deals specifically with this portion of the instrument channel.

3. Suppression Chamber Water Level Suppression chamber water level is a Type A, Category 1, variable provided to detect a breach in the reactor coolant pressure boundary (RCPB). This variable is also used to verify and provide long term surveillance of ECCS function. A combination of two different level instrument ranges, with two independent channels each, monitor Suppression chamber water level. The wide range instrumentation measures from the ECCS suction lines to approximately the top of the chamber and outputs to one control room recorder per channel. The wide range recorders are the primary method of indication available for use by the operator during an accident, therefore the PAM Specification deals specifically with this portion of the instrument channel.

4. Primary Containment Pressure Primary Containment pressure is a Type A, Category 1, variable provided to detect a breach of the RCPB and to verify ECCS functions that operate to maintain RCS integrity. A combination of two different pressure instrument ranges, with two independent channels each, monitor primary containment pressure. The LOCA range measures from -15 psig to 65 psig and outputs to one control room recorder per channel. The accident range measures from 0 psig to 250 psig and outputs to one control room recorder per channel (same recorders as the LOCA range). The recorders (both ranges) are the primary method of indication available for use by the operator during an accident, therefore the PAM Specification deals specifically with this portion of the instrument channel.

5. Primary Containment High Radiation Primary containment area radiation (high range) is provided to monitor the potential of significant radiation releases (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.3-67 Revision 3

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES LCO 5. Primary Containment Hiqh Radiation (continued) and to provide release assessment for use by operators in determining the need to invoke site emergency plans. Two independent channels, which output to one control room recorder per channel with a range of 100 to 1X10 8 R/hr, monitor radiation. The PAM Specification deals specifically with this portion of the instrument channel.

6. Primary Containment Isolation Valve (PCIV) Position PCIV position is provided for verification of containment integrity. In the case of PCIV position, the important information is the isolation status of the containment penetration. The LCO requires a channel of valve position indication in the control room to be OPERABLE for an active PCIV in a containment penetration flow path, i.e., two total channels of PCIV position indication for a penetration flow path with two active valves. For containment penetrations with only one active PCIV having control room indication, Note (b) requires a single channel of valve position indication to be OPERABLE. This is sufficient to redundantly verify the isolation status of each isolable penetration via indicated status of the active valve, as applicable, and prior knowledge of passive valve or system boundary status. If a penetration flow path is isolated, position indication for the PCIV(s) in the associated penetration flow path is not needed to determine status. Therefore, the position indication for valves in an isolated penetration flow path is not required to be OPERABLE. Those valves which require position indication are specified in Table B 3.6.1.3-1. Furthermore, the loss of position indication does not necessarily result in the PCIV being inoperable.

The PCIV position PAM instrumentation consists of position switches unique to PCIVs, associated wiring and control room indicating lamps (not necessarily unique to a PCIV) for active PCIVs (check valves and manual valves are not required to have position indication). Therefore, the PAM Specification deals specifically with these instrument channels.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.3-68 Revision 4

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES LCO 7. Neutron Flux (continued)

Wide range neutron flux is a Category I variable provided to verify reactor shutdown. The Neutron Monitoring System Average Power Range Monitors (APRM) provides reliable neutron flux measurement from 0% to 125% of full power. The APRM consists of four channels each with their own chassis powered with redundant power supplies.

The APRM sends signals to the analog isolator module which in turn sends individual APRM signals to the recorders used for post accident monitoring. The PAM function for neutron flux is satisfied by having two channels of APRM provided for post accident monitoring. The PAM Specification deals specifically with this portion of the instrument channel.

The Neutron Monitoring System (NMS) was evaluated against the criteria established in General Electric NEDO-31558A to ensure its acceptability for post-accident monitoring. NEDO-31558A provides alternate criteria for the NMS to meet the post-accident monitoring guidance of Regulatory Guide 1.97. Based on the evaluation, the NMS was found to meet the criteria established in NEDO-31558A.

The APRM sub-function of the NMS is used to provide the Neutron Flux monitoring identified in TS 3.3.3.1 (Ref. 5 and 6).

8. Not Used.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.3-69 Revision 5

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES LCO 9. Drywell Atmosphere Temperature (continued)

Drywell atmosphere temperature is a Category I variable provided to verify RCS and containment integrity and to verify the effectiveness of ECCS actions taken to prevent containment breach. Two independent temperature channels, consisting of two control room recorders per channel with a range of 40 to 440 degrees F, monitor temperature.

The PAM Specification deals specifically with the inner ring temperature recorder portion of the instrument channel.

10. Suppression Chamber Water Temperature Suppression Chamber water temperature is a Type A, Category 1, variable provided to detect a condition that could potentially lead to containment breach and to verify the effectiveness of ECCS actions taken to prevent containment breach. The suppression chamber water temperature instrumentation allows operators to detect trends in suppression chamber water temperature in sufficient time to take action to prevent steam quenching vibrations in the suppression pool.

Two channels are required to be OPERABLE. Each channel consists of eight sensors of which a minimum of four sensors (one sensor in each quadrant) must be OPERABLE to consider a channel OPERABLE. The outputs for the temperature sensors are displayed on two independent indicators in the control room and recorded on the monitoring units located on control room panel 2C601. The temperature indicators are the primary method of indication available for use by the operator during an accident, therefore the PAM Specification deals specifically with this portion of the instrument channel.

APPLICABILITY The PAM instrumentation LCO is applicable in MODES 1 and 2.

These variables are related to the diagnosis and preplanned actions required to mitigate DBAs. The applicable DBAs are assumed to occur in MODES 1 and 2. In MODES 3, 4, and 5, plant conditions are such that the likelihood of an event that would require PAM instrumentation is extremely low; therefore, PAM instrumentation is not required to be OPERABLE in these MODES.

(continued)

SUSQUEHANNA-UNIT2 TS / B 3.3-70 Revision 4

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES (continued)

ACTIONS A Note has been provided to modify the ACTIONS related to PAM 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 PAM instrumentation channels provide appropriate compensatory measures for separate Functions. As such, a Note has been provided that allows separate Condition entry for each inoperable PAM Function.

A.1 When one or more Functions have one required channel that is inoperable, the required inoperable channel must be restored to OPERABLE status within 30 days. The 30 day Completion Time is based on operating experience and takes into account the remaining OPERABLE channels, the passive nature of the instrument (no critical automatic action is assumed to occur from these instruments), and the low probability of an event requiring PAM instrumentation during this interval.

B.1 If a channel has not been restored to OPERABLE status in 30 days, this Required Action specifies initiation of action in accordance with Specification 5.6.7, which requires a written report to be submitted to the NRC. This report discusses the results of the root cause evaluation of the inoperability and identifies proposed restorative actions.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.3-71 Revision 3

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES ACTIONS B.1 (continued)

This action is appropriate in lieu of a shutdown requirement because alternative actions are identified before the written report is submitted to the NRC, and given the likelihood of plant conditions that would require information provided by this instrumentation.

C.1 When one or more Functions have two required channels that are inoperable (i.e., two channels inoperable in the same Function), one channel in the Function should be restored to OPERABLE status within 7 days. The Completion Time of 7 days is based on the relatively low probability of an event requiring PAM instrument operation and the availability of alternate means to obtain the required information. Continuous operation with two required channels inoperable in a Function is not acceptable because the alternate indications may not fully meet all performance qualification requirements applied to the PAM instrumentation. Therefore, requiring restoration of one inoperable channel of the Function limits the risk that the PAM Function will be in a degraded condition should an accident occur.

D. 1 This Required Action directs entry into the appropriate Condition referenced in Table 3.3.3.1-1. The applicable Condition referenced in the Table is Function dependent. Each time an inoperable channel has not met any Required Action of Condition C, as applicable, and the associated Completion Time has expired, Condition D is entered for that channel and provides for transfer to the appropriate subsequent Condition.

E.1 For the majority of Functions in Table 3.3.3.1-1, if any Required Action and associated Completion Time of Condition C are not met, the plant must be brought to a MODE in which the LCO 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 />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.3-72 Revision 2

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES ACTIONS E.1 (continued) from full power conditions in an orderly manner and without challenging plant systems.

F. 1 Since alternate means of monitoring primary containment area radiation have been developed and tested, the Required Action is not to shut down the plant, but rather to follow the directions of Specification 5.6.7. These alternate means will be temporarily installed if the normal PAM channel cannot be restored to OPERABLE status within the allotted time. The report provided to the NRC should discuss the alternate means used, describe the degree to which the alternate means are equivalent to the installed PAM channels, justify the areas in which they are not equivalent, and provide a schedule for restoring the normal PAM channels.

SURVEILLANCE The following SRs apply to each PAM instrumentation Function in REQUIREMENTS Table 3.3.3.1-1.

SR 3.3.3.1.1 Performance of the CHANNEL CHECK once every 31 days ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel against 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 (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.3-73 Revision 2

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES SURVEILLANCE SR 3.3.3.1.1 (continued)

REQUIREMENTS 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 of 31 days is based upon plant operating experience, with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one channel of a given Function in any 31 day interval is rare. The CHANNEL CHECK supplements less formal checks of channels during normal operational use of those displays associated with the required channels of this LCO.

SR 3.3.3.1.2 and SR 3.3.3.1.3 A CHANNEL CALIBRATION is performed every 24 months except for the PCIV Position Function. The PCIV Position Function is adequately demonstrated by the Remote Position Indication performed in accordance with 5.5.6, "Inservice Testing Program." CHANNEL CALIBRATION verifies that the channel responds to measured parameter with the necessary range and accuracy, and does not include alarms.

The CHANNEL CALIBRATION for the Containment High Radiation instruments shall consist of an electronic calibration of the channel, not including the detector, for range decades above 10 R/hr and a one point calibration check of the detector below 10 R/hr with an installed or portable gamma source.

The Frequency is based on operating experience and for the 24 month Frequency consistency with the industry refueling cycles.

(continued)

SUSQUEHANNA - UNIT 2 TS I B 3.3-74 Revision 3

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 BASES (continued)

REFERENCES 1. Regulatory Guide 1.97 Rev. 2, "Instrumentation for Light Water Cooled Nuclear Power Plants to Assess Plant and Environs Conditions During and Following an Accident," February 6, 1985.

2. Nuclear Regulatory Commission Letter A. Schwencer to N. Curtis, Emergency Response Capability, Conformance to R.G. 1.97, Rev. 2, dated February 6, 1985.

3. PP&L Letter (PLA-2222), N. Curtis to A. Schwencer, dated May 31, 1984.

4. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 32193).

5. NEDO-31558A, BWROG Topical Report, Position on NRC Reg.

Guide 1.97, Revision 3 Requirements for Post Accident Neutron Monitoring System (NMS).

6. Nuclear Regulatory Commission Letter from C. Poslusny to R. G. Byram dated July 3, 1996.

SUSQUEHANNA-UNIT2 TS / B 3.3-75 Revision 2

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 TABLE B 3.3.3.1-1 Post Accident Instruments (Page 1 of 3)

Instrument/variable Element Transmitter Recorder Indicator

1. Reactor Steam N/A PT-24201A UR-24201A PI-24202A Dome Pressure (Red)' PI-24202A1 PI-24204A N/A PT-24201 B UR-24201 B PI-24202B (left side)

(Red)* PI-24202B 1 (left side)

PI-24204B (left side)

2. Reactor Vessel N/A LT-24201A UR-24201A LI-24201A (left side)

Water Level (Wide Range) (Blue)* LI-24201A1 (left side)

LI-24203A (left side)

N/A LT-24201 B UR-24201 B LI-24201 B (left side)

(Wide Range) (Blue)* LI-24201 B1 (left side)

LI-24203B (left side)

N/A LT-24203A N/A LI-24201 A (right side)*(')

(Extended Range) Ll-24201A1 (right side)

LI-24203A (right side)

N/A LT-242038 N/A Ll-24201B (right side)*(')

(Extended Range) LI-24201 B1 (right side)

LI-24203B (right side)

N/A LT-24202A UR-24201A N/A (Fuel Zone Range) (Brown)*

N/A LT-24202B UR-24201 B (Fuel Zone Range) (Brown)*

3. Suppression N/A LT-25776A UR-25776A N/A Chamber Water Level (Wide Range) (Red)'

N/A LT-25776B UR-25776B N/A (Wide Range) (Red)*

N/A LT-25775A UR-25776A LI-25775A (Narrow Range) (Blue)

N/A LT-25775B UR-25776B LI-25775B I (Narrow Range) (Blue)

SUSQUEHANNA-UNIT2 TS / B 3.3-75a Revision 6

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 TABLE B 3.3.3.1-1 Post Accident Instruments (Page 2 of 3)

Instrument/Variable Element Transmitter Recorder Indicator

4. Primary N/A PT-25709A UR-25701A (Dark Blue)* N/A Containment Pressure (0 to 250 psig)

N/A PT-25709B UR-25701 B (Dark Blue)* N/A (0 to 250 psig)

N/A PT-25710A UR-25701A (Red)* N/A

(-15 to 65 psig)

N/A PT-25710B UR-25701 B (Red)* N/A

(-15 to 65 psig)

5. Primary Containment RE-25720A RITS-25720A UR-25776A N/A High Radiation (Green)*

RE-25720B RITS-25720B UR-25776B N/A (Green)*

6. PCIV Position See Technical Specification Bases Table B 3.6.1.3-1 for PCIV that require position indication to be OPERABLE

7. Neutron Flux N/A APRM-1 NR-C51-2R603A N/A (red pen)*

N/A APRM-2 NR-C51-2R603B N/A (red pen)*

N/A APRM-3 NR-C51-2R603C N/A (red pen)*

N/A APRM-4 NR-C51-2R603D N/A (red pen)*

8. Not Used SUSQUEHANNA - UNIT 2 TS / B 3.3-75b Revision 6

PPL Rev. 8 PAM Instrumentation B 3.3.3.1 TABLE B 3.3.3.1-1 Post Accident Instruments (Page 3 of 3)

Instrument/Variable Element Transmitter Recorder Indicator

9. Drywell Atmosphere TE-25790A TT-25790A UR-25701A (Brown)* N/A Temperature TR-25790A (Red)

TE-257908 TT-25790B UR-25701B (Brown)* N/A TR-25790B (Red)

10. Suppression Chamber TE-25753 TX-25751 TIAH-25751 TI-25751 Water Temperature TE-25755 TE-25757 TE-25759 TE-25763 TE-25765 TE-25767 TE-25769 TE-25752 TX-25752 TIAH-25752* TI-25752 TE-25754 TE-25758 TE-25760 TE-25762 TE-25766 TE-25768 TE-25770 Indicates that the instrument (and associated components in the instrument channel) is considered as instrument channel surveillance acceptance criteria.

(1) In the case of the inner ring indicators for extended range level, it is recommended that LI-24201A and Li-24201B be used as acceptance criteria, however Li-24201A1, LI-24201B1, LI-24203A. or LI-24203B may be used in their place provided that surveillance requirements are satisfied. Only one set of these instruments needs to be OPERABLE.

SUSQUEHANNA - UNIT 2 TS / B 3.3-75c Revision 6

PPL Rev. 1 Primary Containment Oxygen Concentration B 3.6.3.3 B 3.6 CONTAINMENT SYSTEMS B 3.6.3.3 Primary Containment Oxygen Concentration BASES BACKGROUND All nuclear reactors must be designed to withstand events that generate hydrogen either due to the zirconium metal water reaction in the core or due to radiolysis. The primary method to control hydrogen is to inert the primary containment. With the primary containment inert, that is, oxygen concentration < 4.0 volume percent (v/o), a combustible mixture cannot be present in the primary containment for any hydrogen concentration. The capability to inert the primary containment and maintain oxygen < 4.0 v/o works together with the Hydrogen Recombiner System and the Drywell Air Flow System (LCO 3.6.3.2, "Drywell Air Flow System") to provide redundant and diverse methods to mitigate events that produce hydrogen.

For example, an event that rapidly generates hydrogen from zirconium metal water reaction will result in excessive hydrogen in primary containment, but oxygen concentration will remain < 4.0 v/o and no combustion can occur. Long term generation of both hydrogen and oxygen from radiolytic decomposition of water may eventually result in a combustible mixture in primary containment, except that the hydrogen recombiners remove hydrogen and oxygen gases faster than they can be produced from radiolysis and again no combustion can occur. This LCO ensures that oxygen concentration does not exceed 4.0 v/o during operation in the applicable conditions.

APPLICABLE The Reference 1 calculations assume that the primary containment is SAFETY inerted when a Design Basis Accident loss of coolant accident occurs.

ANALYSES Thus, the hydrogen assumed to be released to the primary containment as a result of metal water reaction in the reactor core will not produce combustible gas mixtures in the primary containment. Oxygen, which is subsequently. generated by radiolytic decomposition of water, is recombined by the hydrogen recombiners more rapidly than it is produced.

Primary containment oxygen concentration satisfies Criterion 2 of the NRC Policy Statement. (Ref. 2)

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.6-80 Revision 1

PPL Rev. I Primary Containment Oxygen Concentration B 3.6.3.3 BASES (continued)

LCO The primary containment oxygen concentration is maintained < 4.0 v/o to ensure that an event that produces any amount of hydrogen does not result in a combustible mixture inside primary containment.

APPLICABILITY The primary containment oxygen concentration must be within the specified limit when primary containment is inerted, except as allowed by the relaxations during startup and shutdown addressed below. The primary containment must be inert in MODE 1, since this is the condition with the highest probability of an event that could produce hydrogen.

Inerting the primary containment is an operational problem because it prevents containment access without an appropriate breathing apparatus.

Therefore, the primary containment is inerted as late as possible in the plant startup and de-inerted as soon as possible in the plant shutdown.

As long as reactor power is < 15% RTP, the potential for an event that generates significant hydrogen is low and the primary containment need not be inert. Furthermore, the probability of an event that generates hydrogen occurring within the first 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of a startup, or within the last 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> before a shutdown, is low enough that these "windows," when the primary containment is not inerted, are also justified. The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> time period is a reasonable amount of time to allow plant personnel to perform inerting or de-inerting.

ACTIONS A. 1 If oxygen concentration is > 4.0 v/o at any time while operating in MODE 1, with the exception of the relaxations allowed during startup and shutdown, oxygen concentration must be restored to < 4.0 v/o within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Completion Time is allowed when oxygen concentration is 2!4.0 v/o because of the availability of other hydrogen mitigating systems (e.g., hydrogen recombiners) and the low probability and long duration of an event that would generate significant amounts of hydrogen occurring during this period.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.6-81 Revision 0

9 PPL Rev. 1 Primary Containment Oxygen Concentration B 3.6.3.3 BASES ACTIONS B. 1 (continued)

If oxygen concentration cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, power must be reduced to < 15% RTP within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. The 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Completion Time is reasonable, based on operating experience, to reduce reactor power from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE REQUIREMENTS SR 3.6.3.3.1 The primary containment must be determined to be inert by verifying that oxygen concentration is < 4.0 v/o. The 7 day Frequency is based on the slow rate at which oxygen concentration can change and on other indications of abnormal conditions (which would lead to more frequent checking by operators in accordance with plant procedures). Also, this Frequency has been shown to be acceptable through operating experience.

REFERENCES 1. FSAR, Section 6.2.5.

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

SUSQUEHANNA - UNIT 2 TS / 3.6-82 Revision 0

PPL Rev. 7 SCIVs B 3.6.4.2 B 3.6 CONTAINMENT SYSTEMS B 3.6.4.2 Secondary Containment Isolation Valves (SCIVs)

BASES BACKGROUND The function of the SCIVs, in combination with other accident mitigation systems, is to limit fission product release during and following postulated Design Basis Accidents (DBAs) (Ref. 1). Secondary containment isolation within the time limits specified for those isolation valves designed to close automatically ensures that fission products that leak from primary containment into secondary containment following a DBA, or that are released during certain operations when primary containment is not required to be OPERABLE or take place outside primary containment, are maintained within the secondary containment boundary.

The OPERABILITY requirements for SCIVs help ensure that an adequate secondary containment boundary is maintained during and after an accident by minimizing potential paths to the environment. These isolation devices consist of either passive devices or active (automatic) devices. Manual valves or dampers, de-activated automatic valves or dampers secured in their closed position (including check valves with flow through the valve secured), and blind flanges are considered passive devices.

Automatic SCIVs close on a secondary containment isolation signal to establish a boundary for untreated radioactive material within secondary containment following a DBA or other accidents.

Other non-sealed penetrations which cross a secondary containment boundary are'isolated by the use of valves in the closed position or blind flanges.

APPLICABLE The SCIVs must be OPERABLE to ensure the secondary containment SAFETY barrier to fission product releases is established. The principal accidents for ANALYSES which the secondary containment boundary is required are a loss of coolant accident (Ref. 1) and a fuel handling accident inside secondary containment (Ref. 2). The secondary containment performs no active function in response to either of these limiting events, but the boundary (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.6-90 Revision 3

PPL Rev. 7 SCIVs B 3.6.4.2 BASES APPLICABLE established by SCIVs is required to ensure that leakage from the primary SAFETY containment is processed by the Standby Gas Treatment (SGT) System ANALYSES before being released to the environment.

(continued)

Maintaining SCIVs OPERABLE with isolation times within limits ensures that fission products will remain trapped inside secondary containment so that they can be treated bythe SGT System prior to discharge to the environment.

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

LCO SCIVs that form a part of the secondary containment boundary are required to be OPERABLE. Depending on the configuration of the secondary containment only specific SCIVs are required. The SCIV safety function is related to control of offsite radiation releases resulting from DBAs.

The automatic isolation valves are considered OPERABLE when their isolation times are within limits and the valves actuate on an automatic isolation signal. The valves covered by this LCO, along with their associated stroke times, are listed in Table B 3.6.4.2-1.

The normally closed isolation valves or blind flanges are considered OPERABLE when manual valves are closed or open in accordance with appropriate administrative controls, automatic SCIVs are deactivated and secured in their closed position, or blind flanges are in place. These passive isolation valves or devices are listed in Table B3.6.4.2-2. Penetrations closed with sealants are considered part of the secondary containment boundary and are not considered penetration flow paths.

Certain plant piping systems (e.g., Service Water, RHR Service Water, Emergency Service Water, Feedwater, etc.) penetrate the secondary containment boundary. The intact piping within secondary containment provides a passive barrier which maintains secondary containment requirements. When the SDHR and temporary chiller system piping is connected and full of water, the piping forms the secondary containment boundary and the passive devices in TS Bases Table B3.6.4.2-2 are no longer required for these systems since the piping forms the barrier. During certain plant evolutions, piping systems may be drained and breached within secondary containment. During the pipe breach, system isolation valves can be used to provide secondary containment isolation. The isolation valve alignment will be controlled when the piping system is breached.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.6-91 Revision 3

PPL Rev. 7 SCIVs B 3.6.4.2 BASES (continued)

APPLICABILITY In MODES 1, 2, and 3, a DBA could lead to a fission product release to the primary containment that leaks to the secondary containment. Therefore, the OPERABILITY of SCIVs is required.

In MODES 4 and 5, the probability and consequences of these events are reduced due to pressure and temperature limitations in these MODES.

Therefore, maintaining SCIVs OPERABLE is not required in MODE 4 or 5, except for other situations under which significant radioactive releases can be postulated, such as during operations with a potential for draining the reactor vessel (OPDRVs), during CORE ALTERATIONS, or during movement of irradiated fuel assemblies in the secondary containment.

Moving irradiated fuel assemblies in the secondary containment may also occur in MODES 1, 2, and 3.

ACTIONS The ACTIONS are modified by three Notes. The first Note allows penetration flow paths to be unisolated intermittently under administrative controls. These controls consist of stationing a dedicated operator, who is in continuous communication with the control room, at the controls of the isolation device. In this way, the penetration can be rapidly isolated when a need for secondary containment isolation is indicated.

The second Note provides clarification that for the purpose of this LCO separate Condition entry is allowed for each penetration flow path. This is acceptable, since the Required Actions for each Condition provide appropriate compensatory actions for each inoperable SCIV. Complying with the Required Actions may allow for continued operation, and subsequent inoperable SCIVs are governed by subsequent Condition entry and application of associated Required Actions.

The third Note ensures appropriate remedial actions are taken, if necessary, if the affected system(s) are rendered inoperable by an inoperable SCIV.

A.1 and A.2 In the event that there are one or more required penetration flow paths with one required SCIV inoperable, the affected penetration flow path(s) must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure.

Isolation barriers that meet this criterion are a closed and de-activated automatic SCIV, a closed manual valve, and a blind flange. For penetrations isolated in (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.6-92 Revision 2

PPL Rev. 7 SCIVs B 3.6.4.2 BASES ACTIONS A.1 and A.2 (continued) accordance with Required Action A. 1, the device used to isolate the penetration shobild be the closest available device to secondary containment. The Required Action must be completed within the 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Completion Time. The specified time period is reasonable considering the time required to isolate the penetration, and the probability of a DBA, which requires the SCIVs to close, occurring during this short time is very low.

I For affected penetrations that have been isolated in accordance with Required Action A.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that secondary containment penetrations required to be isolated following an accident, but no longer capable of being automatically isolated, will be in the isolation position should an event occur. The Completion Time of once per 31 days is appropriate because the valves are operated under administrative controls and the probability of their misalignment is low. This Required Action does not require any testing or device manipulation. Rather, it involves verification that the affected penetration remains isolated.

Condition A is modified by a Note indicating that this Condition is only applicable to those penetration flow paths with two SCIVs. For penetration flow paths with one SCIV, Condition C provides the appropriate Required Actions.

Required Action A.2 is modified by a Note that applies to devices located in high radiation areas and allows them to be verified closed by use of administrative controls. Allowing verification by administrative controls is considered acceptable, since access to these areas is typically restricted.

Therefore, the probability of misalignment, once they have been verified to be in the proper position, is low.

B.*I With two SCIVs in one or more penetration flow paths inoperable, the affected penetration flow path must be isolated within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. The method of isolation must (continued)

SUSQUEHANNA- UNIT 2 TS / B 3.6-93 Revision 1

PPL Rev. 7 SCIVs B 3.6.4.2 BASES ACTIONS B.1 (continued) include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time is reasonable considering the time required to isolate the penetration and the probability of a DBA, which requires the SCIVs to close, occurring during this short time, is very low.

The Condition has been modified by a Note stating that Condition B is only applicable to penetration flow paths with two isolation valves. For penetration flow paths with one SCIV, Condition C provides the appropriate Required Actions.

C.1 and C.2 With one or more required penetration flow paths with one required SCIV inoperable, the inoperable valve must be restored to OPERABLE status or the affected penetration flow path must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action C.1 must be completed within the 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time. The Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is reasonable considering the relative stability of the system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting secondary containment OPERABILITY during MODES 1, 2, and 3.

In the event the affected penetration flow path is isolated in accordance with Required Action C.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that secondary containment penetrations required to be isolated following an accident are isolated.

The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.6-94 Revision 1

PPL Rev. 7 SCIVs B 3.6.4.2 BASES ACTIONS C.1 and C.2 (continued) valves are operated under administrative controls and the probability of their misalignment is low.

Condition C is modified by a Note indicating that this Condition is only applicable to penetration flow paths with only one SCIV. For penetration flow paths with two SCIVs, Conditions A and B provide the appropriate Required Actions.

Required Action C.2 is modified by a Note that applies to valves and blind flanges located in high radiation areas and allows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted.

Therefore, the probability of misalignment of these valves, once they have been verified to be in the proper position, is low.

D.1 and D.2 If any Required Action and associated Completion Time cannot be met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and to MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

E.1, E.2, and E.3 If any Required Action and associated Completion Time are not met, the plant must be placed in a condition in which the LCO does not apply. If applicable, CORE ALTERATIONS and the movement of irradiated fuel assemblies in the secondary containment must be immediately suspended.

Suspension of these activities shall not preclude completion of movement of a component to a safe position. Also, if applicable, actions must be immediately initiated to suspend OPDRVs in order to minimize the probability of a vessel draindown and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.6-95 Revision 1

PPL Rev. 7 SCIVs B 3.6.4.2 BASES ACTIONS E.1, E.2, and E.3 (continued)

Required Action E.1 has been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODE 4 or 5, LCO 3.0.3 would not specify any action. If moving fuel while in MODE 1, 2, or 3, the fuel movement is independent of reactor operations.

Therefore, in either case, inability to suspend movement of irradiated fuel assemblies would not be a sufficient reason to require a reactor shutdown.

SURVEILLANCE SR 3.6.4.2.1 REQUIREMENTS This SR verifies that each secondary containment manual isolation valve and blind flange that is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside of the secondary containment boundary is within design limits. This SR does not require any testing or valve manipulation.

Rather, it involves verification (typically visual) that those required SCIVs in secondary containment that are capable of being mispositioned are in the correct position.

Since these SCIVs are readily accessible to personnel during normal operation and verification of their position is relatively easy, the 31 day Frequency was chosen to provide added assurance that the SCIVs are in the correct positions.

Two Notes have been added to this SR. The first Note applies to valves and blind flanges located in high radiation areas and allows them to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these SCIVs, once they have been verified to be in the proper position, is low.

A second Note has been included to clarify that SCIVs that are open under administrative controls are not required to meet the SR during the time the SCIVs are open.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.6-96 Revision 2

PPL Rev. 7 SCIVs B 3.6.4.2 BASES SURVEILLANCE SR 3.6.4.2.2 REQUIREMENTS (continued) SCIVs with maximum isolation times specified in Table B 3.6.2.4-1 are tested every 92 days to verify that the isolation time is within limits to demonstrate OPERABILITY. Automatic SCIVs without maximum isolation times specified in Table B 3.6.4.2-1 are tested under the requirements of SR 3.6.4.2.3. The isolation time test ensures that the SCIV will isolate in a time period less than or equal to that assumed in the safety analyses.

SR 3.6.4.2.3 Verifying that each automatic required SCIV closes on a secondary containment isolation signal is required to prevent leakage of radioactive material from secondary containment following a DBA or other accidents.

This SR ensures that each automatic SCIV will actuate to the isolation position on a secondary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.2.5 overlaps this SR to provide complete testing of the safety function. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.*

REFERENCES 1. FSAR, Section 6.2.

2. FSAR, Section 15.

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

SUSQUEHANNA - UNIT 2 TS / B 3.6-97 Revision 1

PPL Rev. 7 SCIVs B 3.6.4.2 Table B 3.6.4.2-1 Secondary Containment Ventilation System Automatic Isolation Dampers (Page 1 of 1)

Reactor Maximum Building Valve Number Valve Description Type of Valve Isolation Time Zone (Seconds)

I HD-1 7586 A&B Supply System Dampers Automatic Isolation Damper 10.0 I HD-1 7524 A&B Filtered Exhaust System Dampers Automatic Isolation Damper 10.0 I HD-17576A&B Unfiltered Exhaust System Automatic Isolation Damper 10.0 II HD-27586 A&B Supply System Dampers Automatic Isolation Damper 10.0 II HD-27524 A&B Filtered Exhaust System Dampers Automatic Isolation Damper 10.0 II HD-27576 A&B Unfiltered Exhaust System Automatic Isolation Damper 10.0 III HD-17564 A&B Supply System Dampers Automatic Isolation Damper 14.0 Ill HD-17514 A&B Filtered Exhaust System Dampers Automatic Isolation Damper 6.5 III HD-1 7502 A&B Unfiltered Exhaust System Automatic Isolation Damper 6.0 III HD-27564 A&B Supply System Dampers Automatic Isolation Damper 14.0 III HD-27514 A&B Filtered Exhaust System Dampers Automatic Isolation Damper 6.5 III HD-27502 A&B Unfiltered Exhaust System Automatic Isolation Damper 6.0 N/A HD-17534A Zone 3 Airlock 1-606 Automatic Isolation Damper N/A N/A HD-17534B Zone 3 Airlock 1-611 Automatic Isolation Damper N/A N/A HD-17534D Zone 3 Airlock 1-803 Automatic Isolation Damper N/A N/A HD-17534E Zone 3 Airlock 1-805 Automatic Isolation Damper N/A N/A HD-17534F Zone 3 Airlock 1-617 Automatic Isolation Damper N/A N/A HD-17534H Zone 3 Airlock 1-618 Automatic Isolation Damper N/A N/A HD-27534A Zone 3 Airlock 11-606 Automatic Isolation Damper N/A N/A HD-27534D Zone 3 Airlock'l1-803 Automatic Isolation Damper N/A N/A HD-27534E Zone 3 Airlock 11-805 Automatic Isolation Damper N/A N/A HD-27534G Zone 3 Airlock C-806 Automatic Isolation Damper N/A N/A HD-27534H Zone 3 Airlock 11-618 Automatic Isolation Damper N/A N/A HD-275341 Zone 3 Airlock 11-609 Automatic Isolation Damper NWA SUSQUEHANNA - UNIT 2 TS / B 3.6-98 Revision 2

PPL Rev. 7 SCIVs B 3.6.4.2 Table B 3.6.4.2-2 Secondary Containment Ventilation System Passive Isolation Valves or Devices (Page I of 3)

Device Number I Device Description Area/Elev. I Required Position / Notes X-29-2-44 SDHR System to Fuel Pool Cooling Yard/670 Blind Flanged / Note 1 X-29-2-45 SDHR System to Fuel Pool Cooling Yard/670 Blind Flanged / Note 1 110176 SDHR Supply Drain VIv 29/670 Closed Manual Iso Valve / Note 1 110186 SDHR Discharge Drain Vlv 29/670 Closed Manual Iso Valve / Note 1 110180 SDHR Supply Vent VIv 29/749 Closed Manual Iso Valve / Note 1 110181 SDHR Discharge Fill VIv 27/749 Closed Manual Iso Valve / Note 1 110182 SDHR Discharge Vent VIv 27/749 Closed Manual Iso Valve / Note 1 110187 SDHR Supply Fill Vlv 29/749 Closed Manual Iso Valve / Note 1 210186 SDHR Supply Drain Vlv 33/749 Closed Manual Iso Valve / Note 1 210187 SDHR Supply Vent Vlv 33/749 Closed Manual Iso Valve / Note 1 210191 SDHR Discharge Vent VMv 30/749. Closed Manual Iso Valve / Note 1 210192 SDHR Discharge Drain VIv 30/749 Closed Manual Iso Valve / Note 1 210193 SDHR Discharge Vent VMv 33/749 Closed Manual Iso Valve / Note 1 X-29-2-46 Temporary Chiller to RBCW Yard/670 Blind Flanged / Note 2 X-29-2-47 Temporary Chiller to RBCW Yard/670 Blind Flanged / Note 2 X-29-5-95 Temporary Chiller to Unit 1 RBCW 29/749 Blind Flanged / Note 2 X-29-5-96 Temporary Chiller to Unit 1 RBCW 29/749 Blind Flanged / Note 2 X-29-5-91 Temporary Chiller to Unit 2 RBCW 33/749 Blind Flanged / Note 2 X-29-5-92 Temporary Chiller to Unit 2 RBCW 33/749 Blind Flanged / Note 2 187388 RBCW Temp Chiller Discharge Iso VMv 29/670 Closed Manual Iso Valve / Note 2 187389 RBCW Temp Chiller Supply Iso VIv 29/670 Closed Manual Iso Valve / Note 2 187390 RBCW Temp Chiller Supply Drain VIv 29/670 Closed Manual Iso Valve / Note 2 187391 RBCW Temp Chiller Discharge Drain Vlv 29/670 Closed Manual Iso Valve / Note 2 X-28-2-3000 Utility Penetration to Unit 1 East Stairwell Yard/670 Blind Flanged / Note 3 X-29-2-48 Utility Penetration to Unit 1 RR Bay Yard/670 Capped / Note 5 X-33-2-3000 Utility Penetration to Unit 2 East Stairwell Yard/670 Blind Flanged / Note 4 X-28-2-3000 Utility Penetration to Unit 1 East Stairwell 28/670 Blind Flanged / Note 3 X-29-2-48 Utility Penetration to Unit 1 RR Bay 29/670 Capped / Note 5 X-33-2-3000 Utility Penetration to Unit 2 East Stairwell 33/670 Blind Flanged / Note 4 X-29-3-54 Utility Penetration to Unit 1 RBCCW Hx Area 27/683 Blind Flanged / Note 6 X-29-3-55 Utility Penetration to Unit 1 RBCCW Hx Area 27/683 Blind Flanged / Note 6 X-29-5-97 Utility Penetration from Unit 1 RR Bay to Unit 2 Elev. 33/749 Capped 749 X-27-6-42 Diamond Plate Cover over Floor Penetration 27/779' Installed X-27-6-92 Instrument Tubing Stubs 27/779' Capped X-29-7-4 1"Spare Conduit Threaded Plug 291818' Installed X-30-6-72 Instrument Tubing Stubs 30/779' Capped X-30-6-1002 Stairwell #214 Rupture Disc 30/779' Installed Intact X-30-6-1003 Airlock 11-609 Rupture Disc 30/779' Installed Intact X-25-6-1 008 Airlock 1-606 Rupture Disc 25/779' Installed Intact X-29-4-D1 -B Penetration at Door 4330 29/719' Blind Flange Installed X-29-4-D1-A Penetration at Door 4330 29/719' Blind Flange Installed X-29-4-D1-B Penetration at Door 404 33/719' Blind Flange Installed X-29-4-D1-A Penetration at Door 404 33/719' Blind Flange Installed SUSQUEHANNA - UNIT 2 TS / B 3.6-99 Revision 6

PPL Rev. 7 SCIVs B 3.6.4.2 Table B 3.6.4.2-2 Secondary Containment Ventilation System Passive Isolation Valves or Devices (Page 2 of 3)

Device Number Device Description Area/Elev. Required Position I Notes HD17534C Airlock 1-707 Blind Flange 28/799' Blind Flange Installed HD27534C Airlock 11-707 Blind Flange 33/799' Blind Flange Installed XD-17513 Isolation damper for Railroad Bay Zone IIIHVAC 29/799' Position is dependent on Railroad Supply Bay alignment XD-17514 Isolation damper for Railroad Bay Zone IIIHVAC 29/719' Position is dependent on Railroad Exhaust Bay alignment XD-12301 PASS Air Flow Damper 11/729' Closed Damper XD-22301 PASS Air Flow Damper 22/729' Closed Damper 161827 HPCI Blowout Steam Vent Drain Valve 25/645' Closed Manual Iso Valve / Note 3 161828 RCIC Blowout Steam Vent Drain Valve 28/645' Closed Manual Iso Valve / Note 3 161829 'A' RHR Blowout Steam Vent Drain Valve 29/645' Closed Manual Iso Valve / Note 3 161830 'B' RHR Blowout Steam Vent Drain Valve 28/645' Closed Manual Iso Valve / Note 3 261820 RCIC Blowout Steam Vent Drain Valve 33/645' Closed Manual Iso Valve / Note 4 261821 'A' RHR Blowout Steam Vent Drain Valve 34/645' Closed Manual Iso Valve / Note 4 261822 'B' RHR Blowout Steam Vent Drain Valve 33/645' Closed Manual Iso Valve / Note 4 SUSQUEHANNA- UNIT 2 TS / B 3.6-99a Revision 4

PPL Rev. 7 SCIVs B 3.6.4.2 Table B 3.6.4.2-2 Secondary Containment Ventilation System Passive Isolation Valves or Devices (Page 3 of 3)

Note 1: The two blind flanges on the SDHR penetrations (blind flanges for device number X-29-2-44 and X-29-2-45) and all the closed manual valves for the SDHR system (110176,110186,110180,110181,110182,110187, 210186, 210187, 210191,210192, 210193) can each be considered as a separate secondary containment isolation device for the SDHR penetrations. If one or both of the blind flanges is removed and all the above identified manual valves for the SDHR system are closed, the appropriate LCO should be entered for one inoperable SCIV in a penetration flow path with two SCIVs. With the blind flange removed, the manual valves could be opened intermittently under administrative controls per the Technical Specification Note. When both SDHR blind flanges are installed, opening of the manual valves for the SDHR system will be controlled to prevent cross connecting ventilation zones. When the manual valves for the SDHR system are open in this condition, the appropriate LCO should be entered for one inoperable SCIV in a penetration flow path with two SCIVs. When the SDHR system piping is connected and full of water, the piping forms the secondary containment boundary and the above listed SCIVs in Table B3.6.4.2-2 are no longer required for this system since the piping forms the barrier.

Note 2: Due to the multiple alignments of the RBCW temporary chiller, different devices will perform the SCIV function depending on the RBCW configuration. There are three devices/equipment that can perform the SCIV function for the RBCW temporary chiller supply penetration. The first SCIV for the RBCW temporary chiller supply penetration is the installed blind flange on penetration X-29-2-47. The second SCIV for the RBCW temporary chiller supply penetration is isolation valve 187389. The third SCIV for the temporary RBCW chiller supply penetration is closed drain valve 187390 and an installed blind flange on penetrations X-29-5-92 and/or X-29-5-96. Since there are effectively three SCIVs, any two can be used to define the SCIV for the penetration. Removal of one of the two required SCIVs requires entry into the appropriate LCO for one inoperable SCIV in a penetration flow path with two SCIVs. Opening of drain valve 187390 and operation of blank flanges X-29-5-96 and X-29-5-92 will be controlled to prevent cross connecting ventilation zones. These three SCIVs prevent air inleakage into secondary containment. The isolation of the penetration per the Technical Specification requirement is to assure that one of the above SCIVs is closed so that there is no air inleakage into secondary containment.

There are three devices/equipment that can perform the SCIV function for the RBCW temporary chiller return penetration. The first SCIV for the RBCW temporary chiller return penetration is the installed blind flange on penetration X-29-2-46. The second SCIV for the RBCW temporary chiller return penetration is isolation valve 187388. The third SCIV for the temporary RBCW chiller return penetration is closed drain valve 187391 and an installed blind flange on penetrations X-29-5-91 and/or X-29-5-95. Since there are effectively three SCIVs, any two can be used to define the SCIV for the penetration. Removal of one of the two required SCIVs requires entry into the appropriate LCO for one inoperable SCIV in a penetration flow path with two SCIVs. Opening of drain valve 187391 and operation of blank flanges X-29-5-91 and X-29-5-95 will be controlled to prevent cross connecting ventilation zones. These three SCIVs prevent air inleakage into secondary containment. The isolation of the penetration per the Technical Specification requirement is to assure that one of the above SCIVs is closed so that there is no air inleakage into secondary containment.

When the RBCW temporary chiller piping is connected and full of water, the piping inside secondary containment forms the secondary containment boundary and the above listed SCIVs in Table B3.6.4.2-2 are no longer required for this system.

Note 3: These penetrations connect Secondary Containment Zone I to a No-Zone. When Secondary Containment Zone I is isolated from the recirculation plenum, the above listed SCIVs in Table B3.6.4.2-2 are no longer required.

Note 4: These penetrations connect Secondary Containment Zone I to a No-Zone. When Secondary Containment Zone 11is isolated from the recirculation plenum, the above listed SCIVs in Table B3.6.4.2-2 are no longer required.

Note 5: These penetrations connect the Railroad Bay to a No-Zone. When the Railroad Bay is a No-Zone, the above listed SCIVs in Table B3.6.4.2-2 are no longer required.

Note 6: These penetrations connect Secondary Containment Zone I to the Railroad Bay. The above listed SCIVs in Table B3.6.4.2-2 are not required ifthe Railroad Bay is a No-Zone and Zone I is isolated from the recirculation plenum OR if the Railroad Bay is aligned to Zone I.

SUSQUEHANNA - UNIT 2 TS / B 3.6-99b Revision 2

PPL Rev. 3 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air BASES BACKGROUND Each diesel generator (DG) is provided with storage capacity sufficient to operate that DG for a period of 7 days while the DG is supplying its continuous rated load, as discussed in FSAR, Section 9.5.4 (Ref. 1).

The maximum load demand is calculated using the assumption that at least three DGs are available. This on-site fuel oil capacity, which, for the A-D DGs, includes the available volume in the diesel day tanks and storage tanks, is sufficient to operate the DGs for longer than the time to replenish the onsite supply from outside sources.

Fuel oil is transferred from storage tank to day tank by a transfer pump associated with each storage tank. Independent pumps and piping preclude the failure of one pump, or the rupture of any pipe, valve, or tank to result in the loss of more than one DG. All outside tanks, pumps, and piping are located underground.

For proper operation of the standby DGs, it is necessary to ensure the proper quality of the fuel oil. Regulatory Guide 1.137 (Ref. 2) addresses the recommended fuel oil practices as supplemented by ANSI N195 (Ref. 3). The fuel oil properties governed by these SRs are the water and sediment content, the kinematic viscosity, specific gravity (or API gravity) and impurity level.

The DG lubrication system is designed to provide sufficient lubrication to permit proper operation of its associated DG under all loading conditions. The system is required to circulate the lube oil to the diesel engine working surfaces and to remove excess heat generated by friction during operation. Each engine oil sump contains an inventory capable of supporting a minimum of 7 days of operation. This supply is sufficient to allow the operator to replenish lube oil from outside sources.

Each DG has an air start system with two air receivers (DG E has four air receivers) and each DG air start system provides adequate capacity for five successive start cycles on the DG without recharging the air start receivers. Each bank of two air receivers for DG E has adequate capacity for a minimum of five successive start cycles.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.8-47 Revision 2

PPL Rev. 3 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES (continued)

APPLICABLE The initial conditions of Design Basis Accident (DBA) and transient SAFETY ANALYSES analyses in FSAR, Chapter 6 (Ref. 4), and Chapter 15 (Ref. 5), assume Engineered Safety Feature (ESF) systems are OPERABLE. The DGs are designed to provide sufficient capacity, capability, redundancy, and reliability to ensure the availability of necessary power to ESF systems so that fuel, Reactor Coolant System, and containment design limits are not exceeded. These limits are discussed in more detail in the Bases for Section 3.2, Power Distribution Limits; Section 3.4, Reactor Coolant System (RCS); and Section 3.6, Containment Systems.

Since diesel fuel oil, lube oil, and starting air subsystem support the operation of the standby AC power sources, they satisfy Criterion 3 of the NRC Policy Statement (Ref. 6).

LCO Stored diesel fuel oil is required to have sufficient supply for 7 days of full load operation. Itis also required to meet specific standards for quality.

Additionally, sufficient lube oil supply must be available to ensure the capability to operate at full load for 7 days. This requirement, in conjunction with an ability to obtain replacement supplies within 7 days, supports the availability of DGs required to shut down the reactor and to maintain it in a safe condition for an anticipated operational occurrence (AOO) or a postulated DBA with loss of offsite power. DG day tank fuel oil requirements, as well as transfer capability from the storage tank to the day tank, are addressed in LCO 3.8.1, "AC Sources-Operating," and LCO 3.8.2, "AC Sources-Shutdown."

The starting air system is required to have a minimum capacity for five successive DG start attempts without recharging the air start receivers.

APPLICABILITY The AC sources (LCO 3.8.1 and LCO 3.8.2) are required to ensure the availability of the required power to shut down the reactor and maintain it in a safe shutdown condition after an AOO or a postulated DBA.

Because stored diesel fuel oil, lube oil, and starting air subsystem support LCO 3.8.1 and LCO 3.8.2, stored diesel fuel oil, lube oil, (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.8-48 Revision 0

PPL Rev. 3 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES APPLICABILITY and starting air are required to be within limits when the associated DG is (continued) required to be OPERABLE.

ACTIONS The ACTIONS Table is modified by a Note indicating that separate Condition entry is allowed for each DG. This is acceptable, since the Required Actions for each Condition provide appropriate compensatory actions for each inoperable DG subsystem. Complying with the Required Actions for one inoperable DG subsystem may allow for continued operation, and subsequent inoperable DG subsystem(s) governed by separate Condition entry and application of associated Required Actions.

A.1 Inthis Condition, the 7 day fuel oil supply for a DG is not available.

However, the Condition is restricted to fuel oil level reductions that maintain at least a 6 day supply. These circumstances may be caused by events such as:

a. Full load operation required for an inadvertent start while at minimum required level; or

b. Feed and bleed operations that may be necessitated by increasing particulate levels or any number of other oil quality degradations.

This restriction allows sufficient time for obtaining the requisite replacement volume and performing the analyses required prior to addition of the fuel oil to the tank. A period of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> is considered sufficient to complete restoration of the required level prior to declaring the DG inoperable. This period is acceptable based on the remaining capacity (> 6 days), the fact that action will be initiated to obtain replenishment, the availability of fuel oil in the storage tank of the fifth diesel generator that is not required to be OPERABLE, and the low probability of an event during this brief period.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.8-49 Revision 0

PPL Rev. 3 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES ACTIONS B.1 (continued)

With lube oil sump level not visible in the sight glass, sufficient lube oil to support 7 days of continuous DG operation at full load conditions may not be available. Therefore, the DG is declared inoperable immediately.

C.1 This Condition is entered as a result of a failure to meet the acceptance criterion for particulates. Normally, trending of particulate levels allows sufficient time to correct high particulate levels prior to reaching the limit of acceptability. Poor sample procedures (bottom sampling), contaminated sampling equipment, and errors in laboratory analysis can produce failures that do not follow a trend. Since the presence of particulates does not mean failure of the fuel oil to bum properly in the diesel engine, since particulate concentration is unlikely to change significantly between Surveillance Frequency intervals, and since proper engine performance has been recently demonstrated (within 31 days), it is prudent to allow a brief period prior to declaring the associated DG inoperable. The 7 day Completion Time allows for further evaluation, resampling, and re-analysis of the DG fuel oil.

D.1 With the new fuel oil properties, defined in the Bases for SR 3.8.3.3 not within the required limits, a period of 30 days is allowed for restoring the stored fuel oil properties. This period provides sufficient time to test the stored fuel oil to determine that the new fuel oil, when mixed with previously stored fuel oil, remains acceptable, or to restore the stored fuel oil properties. This restoration may involve feed and bleed procedures, filtering, or combination of these procedures. Even if a DG start and load was required during this time interval and the fuel oil properties were outside limits, there is high likelihood that the DG would still be capable of performing its intended function.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.8-50 Revision 0

PPL Rev. 3 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES ACTIONS E. 1 (continued)

With starting air receiver pressure < 240 psig in one or more air receivers, sufficient capacity for five successive DG start attempts can not be provided by the air start system. However, as long as all receiver pressures are > 180 psig, there is adequate capacity for at least one start attempt, and the DG can be considered OPERABLE while the air receiver pressure is restored to-the required limit. A period of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> is considered sufficient to complete restoration to the required pressure prior to declaring the DG inoperable. This period is acceptable based on the remaining air start capacity, the fact that most DG starts are accomplished on the first attempt, and the low probability of an event during this brief period. Entry into Condition E is not required when air receiver pressure is less than required limits following a successful start while the DG is operating.

F. 1 With a Required Action and associated Completion Time of A through E not met, or the stored diesel fuel oil, lube oil, or starting air not within SR limits for reasons other than addressed by Conditions A, B, C, D or E, the associated DG may be incapable of performing its intended function and must be immediately declared inoperable.

SURVEILLANCE SR 3.8.3.1 REQUIREMENTS For DG's A-D, this SR, in conjunction with SR 3.8.1.4, provides verification that there is adequate inventory of fuel oil available to support DG operation for 7 days at its continuous rated load, which is greater than the maximum post accident demand load. For DG-E, this SR provides verification that there is adequate inventory of fuel oil available to support DG operation for 7 days at its continuous rated load, which is also greater than the maximum post accident load demand. The 7 day period is sufficient time to place the unit in a safe shutdown condition and to bring in replenishment fuel from an offsite location.

The 31 day Frequency is adequate to ensure that a sufficient supply of fuel oil is available, since low level alarms are provided and unit operators would be aware of any large uses of fuel oil during this period.

(continued)

SUSQUEHANNA - UNIT 2 TS / B 3.8-51 Revision 2

PPL Rev. 3 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.2 REQUIREMENTS (continued) This Surveillance ensures that sufficient lubricating oil inventory is available to support at least 7 days of full load operation for each DG. The sump level requirement is based on the DG manufacturer's consumption values. The acceptance criteria of maintaining a visible level in the sight glass ensures adequate inventory for 7 days of full load operation without the level reaching the manufacturer's recommended minimum level.

A 31 day Frequency is adequate to ensure that a sufficient lube oil supply is onsite, since DG starts and run time are closely monitored by the plant staff.

SR 3.8.3.3 The tests listed below are a means of determining whether new fuel oil is of the appropriate grade and has not been contaminated with substances that would have an immediate detrimental impact on diesel engine combustion. If results from these tests are within acceptable limits, the fuel oil may be added to the storage tanks without concern for contaminating the entire volume of fuel oil in the storage tanks. These tests are to be conducted prior to adding the new fuel to the storage tank(s), but in no case is the time between receipt of new fuel and conducting the tests to exceed 31 days. The tests, limits, and applicable ASTM Standards are as follows:

a. Sample the new fuel oil following the guidelines of ASTM D4057 (Ref. 7);

b. Verify, following the guidelines of the tests specified in ASTM D975 (Ref. 7), that the sample has:

- a Density at 150C of Ž0.825 kg/L and

• 0.876 kg/L or an API Gravity of Ž_30 and *<40

- a Kinematic Viscosity at 400 C of _>1.9 centistokes and

• 4.1 centistokes

- A Flash Point of >_520C (continued)

SUSQUEHANNA - UNIT 2 TS / B 3.8-52 Revision 2

PPL Rev. 3 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.3 (continued)

REQUIREMENTS

c. Verify that the new fuel oil has a clear and bright appearance when tested following the guidelines of ASTM D4176 procedure (Ref. 7),

or has

• 0.05% (vol) water and sediment when tested following the guidelines of ASTM D1796 (Ref. 7). Note that if dye is used in the diesel fuel oil, the water and sediment test must be performed.

Failure to meet any of the limits for key properties of new fuel oil prior to addition to the storage tank is cause for rejecting the new fuel oil, but does not represent a failure to meet the LCO concern since the fuel oil is not added to the storage tanks.

Within 31 days following the initial new fuel oil sample, the fuel oil is analyzed to establish that the other properties specified in Specification 5.5.9 and Reference 7 are met for new fuel oil when tested following the guidelines of ASTM D975 (Ref. 7). The 31 day period is acceptable because the fuel oil properties of interest, even ifthey were not within stated limits, would not have an immediate effect on DG operation. This Surveillance ensures the availability of high quality fuel oil for the DGs.

Fuel oil degradation during long term storage shows up as an increase in particulate, mostly due to oxidation. The presence of particulate does not mean that the fuel oil will not bum properly in a diesel engine. The particulate can cause fouling of filters and fuel oil injection equipment, however, which can cause engine failure.

Particulate concentrations should be determined following the guidelines of ASTM D2276 (Ref. 7), appropriately modified to increase the range to

> 10 mg/I. This method involves a gravimetric determination of total particulate concentration in the fuel oil. This limit is 10 mg/I. It is acceptable to obtain a field sample for subsequent laboratory testing in lieu of field testing. The Frequency of this test takes into consideration fuel oil degradation trends that indicate that particulate concentration is unlikely to change significantly between Frequency intervals.

SR 3.8.3.4 This Surveillance ensures that, without the aid of the refill compressor, sufficient air start capacity for each DG is available. The system design requirements provide for a minimum of five engine start cycles without recharging.

(continued)

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PPL Rev. 3 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.4 (continued)

REQUIREMENTS The pressure specified in this SR is intended to reflect the lowest value at which the five starts can be accomplished. The air starting system capacity for each start cycle is calculated based on the following:

1. each cranking cycle duration should be approximately three seconds, or

2. consist of two to three engine revolutions, or

3. air start requirements per engine start provided by the engine manufacturer, whichever air start requirement is larger.

This Surveillance is modified by a Note, which does not require the SR to be met when the associated DG is running. This is acceptable because once the DG is started the safety function of the air start system is performed.

The 31 day Frequency takes into account the capacity, capability, redundancy, and diversity of the AC sources and other indications available in the control room, including alarms, to alert the operator to below normal air start pressure.

SR 3.8.3.5 Microbiological fouling is a major cause of fuel oil degradation. There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive. Removal of water from the fuel storage tanks once every 31 days eliminates the necessary environment for bacterial survival. This is the most effective means of controlling microbiological fouling. In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation.

Water may come from any of several sources, including condensation, ground water, rain water, contaminated fuel oil, and from breakdown of the fuel oil by bacteria. Frequent checking for and removal of accumulated water minimizes fouling and (continued)

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PPL Rev. 3 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.5 (continued)

REQUIREMENTS provides data regarding the watertight integrity of the fuel oil system. The Surveillance Frequencies are established by Regulatory Guide 1.137 (Ref. 2). This SR is for preventive maintenance. The presence of water does not necessarily represent failure of this SR, provided the accumulated water is removed during performance of the Surveillance.

REFERENCES 1. FSAR, Section 9.5.4.

2. Regulatory Guide 1.137.

3. ANSI N195, 1976.

4. FSAR, Chapter 6.

5. FSAR, Chapter 15.

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

7. ASTM Standard: D4057; D975; D4176; D1796; and D2276.

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