ML061720115
| ML061720115 | |
| Person / Time | |
|---|---|
| Site: | Susquehanna  |
| Issue date: | 06/14/2006 |
| From: | Susquehanna |
| To: | Gerlach R Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 028401 | |
| Download: ML061720115 (55) | |
Text
Jun. 14, 2006 Page I of 1 MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2006-27546 USER INFORMATION:
Name:GERLACH*ROSE M EMPL#:028401 CA#:0363 Address: NUCSA2 Phone#: 254-3194 TRANSMITTAL INFORMATION:
TO: GERLACH*ROSE M 06/14/2006 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 IC will be issued with the updated material.
TSB2 - TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 05/18/2006 ADD MANUAL TABLE OF CONTENTS DATE: 06/13/2006 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.3.3.1 REMOVE: REV:2 ADD: REV: 3 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.6.3.1 REMOVE: REV:1 ADD: REV: 2 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.8.4 REMOVE: REV:0 ADD: REV: 1 CATEGORY: DOCUMENTS TYPE: TSB2
\4MOVE:
TEXT LOES REV:72 A001 ADD: REV: 73 CATEGORY: DOCUMENTS TYPE: TSB2
Jun. 14, 2006 Page 2 of 2 ID: TEXT TOC REMOVE: REV:7 ADD: REV: 8 ANY DISCREPANCIES WITH THE MATERIAL PROVIDED, CONTACT DCS @ X3107 OR X3136 FOR ASSISTANCE. UPDATES FOR HARDCOPY MANUALS WILL BE DISTRIBUTED WITHIN 5 DAYS IN ACCORDANCE WITH DEPARTMENT PROCEDURES. PLEASE MAKE ALL CHANGES AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX UPON COMPLETION OF UPDATES. FOR ELECTRONIC MANUAL USERS, ELECTRONICALLY REVIEW THE APPROPRIATE DOCUMENTS AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX.
SSES MANUAL Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL Table Of Contents Issue Date: 06/13/2006 Procedure Name Rev Issue Date Change ID Change Number TEXT LOES 73 06/13/2006
Title:
LIST OF EFFECTIVE SECTIONS TEXT TOC 8 06/13/2006
Title:
TABLE OF CONTENTS TEXT 2.1.1 1 10/27/2004
Title:
SAFETY LIMITS (SLS) REACTOR CORE SLS TEXT 2.1.2 0 11/18/2002N SYT.. R . "
COOLANT "*SYSTEM',.,( RCS ) PRESSURE SL
Title:
SAFETY LIMITS (SLS) REACTOR TEXT 3.0 1 ./ 04/08/2005
Title:
LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY K. TEXT3.11 .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 . 1 07/06/2005
Title:
REACTIVITY CONTROL SYSTEMS CONTROL ROD OPERABILITY TEXT 3.1.4 2 07/06/2005
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 Page I of 8 Report Date: 06/13/06
SSES MANUAL Manual Name: TSB£-
Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL K>
TEXT 3.1.7 1 08/30/2005
Title:
REACTIVITY CONTROL SYSTEMS STANDBY LIQUID CONTROL (SLC) SYSTEM TEXT 3.1.8 1 10/19/2005
Title:
REACTIVITY CONTROL SYSTEMS SCRAM DISCHARGE VOLUME (SDV) VENT AND DRAIN VALVES TEXT 3.2.1 2 10/05/2005
Title:
POWER DISTRIBUTION LIMITS AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)
TEXT 3.2.2 -1 03/24/2005
Title:
POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)
TEXT 3.2.3 0 11/18/2002
Title:
POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE LHGR TEXT 3.2.4 1 07/06/2005
Title:
POWER DISTRIBUTION LIMITS AVERAGE POWER RANGE MONITOR (APRM) GAIN AND SETPOINTS TEXT 3.3.1.1 2 07/06/2005
Title:
INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATION TEXT 3.3.1.2 0 11/18/2002
Title:
INSTRUMENTATION SOURCE RANGE MONITOR (SRM) INSTRUMENTATION TEXT 3.3.1.3 0 11/22/2004
Title:
OPRM INSTRUMENTATION TEXT 3.3.2.*1 1 02/17/2005
Title:
INSTRUMENTATION CONTROL ROD BLOCK INSTRUMENTATION TEXT 3.3.2.2 0 11/18/2002
Title:
INSTRUMENTATION FEEDWATER - MAIN TURBINE HIGH WATER LEVEL TRIP INSTRUMENTATION TEXT 3.3.3.1 3 06/13/2006
Title:
INSTRUMENTATION POST ACCIDENT MONITORING (PAM) INSTRUMENTATION Report Date: 06/13/06 Page22 Page of 88 Report Date: 06/13/06
SSES MANUAL
\Manual Name: TSB2--
manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.3.3.2 1 04/18/2005
Title:
INSTRUMENTATION REMOTE SHUTDOWN SYSTEM TEXT 3.3.4.1 0 11/18/2002
Title:
INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATION 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 -3 07/06/2005
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 1 11/09/2004
Title:
INSTRUMENTATION PRIMARY CONTAINMENT ISOLATION INSTRUMENTATION -
TEXT 3.3.6.2 1 11/09/2004
Title:
INSTRUMENTATION SECONDARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.7.1 0 11/18/2002
Title:
INSTRUMENTATION CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM INSTRUMENTATION TEXT 3.3.8.1 2 03/31/2006
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 2 11/22/2004
Title:
REACTOR COOLANT SYSTEM (RCS) RECIRCULATION LOOPS OPERATING TEXT 3.4.2 0 11/18/2002
Title:
REACTOR COOLANT SYSTEM (RCS) JET PUMPS Page 3 of 8 Report Date: 06/13/06
SSES MANUAL Manual Name: TSB2-Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.4.3 1 01/16/2006
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 TEXT 3.4.5 C1 01/16/2006
Title:
REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE TEXT 3.4.6 04/18/2005
Title:
REACTOR COOLANT SYSTEM (RCS) RCS LEAKAGE DETECTION INSTRUMENTATION TEXT 3.4.7 1 04/18/2005
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 SYSTEMý.
- HOT SE[UTDOWN TEXT 3.4.9 0 11/18/2002
Title:
REACTOR COOLANT SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM
- COLD S HUTDOWN TEXT 3.4.10 2 05/10/2006
Title:
REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE (P/T) LIMITS TEXT 3.4.11 0 11/18/2002
Title:
REACTOR COOLANT SYSTEM (RCS) REACTOR STEAM DOME PRESSURE TEXT 3.5.1 3 01/16/2006
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM ECCS - OPERATING TEXT 3.5.2 0 11/18/2002
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM ECCS - SHUTDOWN TEXT 3.5.3 1 04/18/2005
Title:
EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM RCIC SYSTEM Page4 of 8Repot Dat: 0613/0 Page 4 of 8 Report Date: 06/13/06
SSES MANUAL Manual Name: TSBý--
Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.6.1.1 0 11/18/2002
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT TEXT 3.6.1.2 0 11/18/2002
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK TEXT 3.6.1.3 3 12/08/2005
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)
TEXT 3.6.1.4 *0 11/18/2002
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 0 11/18/2002
Title:
CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE TEXT 3.6.2.2 0 11/18/2002
Title:
CONTAINMENT SYSTEMS SUPPRESSION POOL WATER LEVEL TEXT 3.6.2.3 1 01/16/2006
Title:
CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL COOLING TEXT 3.6.2.4 0 11/18/2002
Title:
CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL SPRAY TEXT 3.6.3.1 2 06/13/2006
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS TEXT 3.6.3.2 1 04/18/2005
Title:
CONTAINMENT SYSTEMS DRYWELL AIR FLOW SYSTEM Report Date: 06/13/06 PageS5 Page of of 88 Report Date: 06/13/06
SSES MANUAL Manual Name: TSB&
Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL
\%-~ I TEXT 3.6.3.3 0 11/18/2002
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION TEXT 3.6.4.1 5 03/16/2006
Title:
CONTAINMENT SYSTEMS SECONDARY CONTAINMENT TEXT 3.6.4.2 2 01/03/2005
Title:
CONTAINMENT SYSTEMS SECONDARY CONTAINMENT ISOLATION VALVES (SCIVS)
TEXT 3.6.4.3 -3 10/24/2005
Title:
CONTAINMENT SYSTEMS STANDBY GAS TREATMENT (SGT) SYSTEM TEXT 3.7.1 0 11/18/2002
Title:
PLANT SYSTEMS RESIDUAL HEAT REMOVAL SERVICE WATER (RHRSW) SYSTEM AND THE ULTIMATE HEAT SINK (UHS)
TEXT 3.7.2 1 11/09/2004
Title:
PLANT SYSTEMS EMERGENCY SERVICE WATER (ESW) SYSTEM TEXT 3.7.3 0 11/18/2002
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 0 11/18/2002
Title:
PLANT SYSTEMS MAIN CONDENSER OFFGAS TEXT 3.7.6 1 01/17/2005
Title:
PLANT SYSTEMS MAIN TURBINE BYPASS SYSTEM TEXT 3.7.7 0 11/18/2002
Title:
PLANT SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL TEXT 3.8.1 4 04/18/2006
Title:
ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING Report Date: 06/13/06 Page66 Page of of 88 Report Date: 06/13/06
SSES MANUAL Manual Name: TS-B2--
Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.8.2 0 11/18/2002
Title:
ELECTRICAL POWER SYSTEMS AC SOURCES - SHUTDOWN TEXT 3.8.3 0 11/18/2002
Title:
ELECTRICAL POWER SYSTEMS DIESEL FUEL OIL, LUBE OIL, AND STARTING AIR TEXT 3.8.4 1 06/13/2006
Title:
ELECTRICAL POWER SYSTEMS DC SOURCES - OPERATING TEXT 3.8.5 .0 11/18/2002
Title:
ELECTRICAL POWER SYSTEMS DC SOURCES - SHUTDOWN TEXT 3.8.6 0 11/18/2002
Title:
ELECTRICAL POWER SYST'EMS BATTERY CELL PARAMETERS TEXT 3.8.7 3 03/31/2006 y*/
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 )PERATIONS REFUELING EQUIPMENT INTERLOCKS TEXT 3.9.2 0 11/18/2002
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 )PERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/18/2002
Title:
REFUELING )PERATIONS CONTROL ROD OPERABILITY - REFUELING Report Date: 06/13/06 Page77 Page of of 88 Report Date: 06/13/06
SSES MANUAL Manual Name: TSB2-Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.9.7 0 11/18/2002
Title:
REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - HIGH WATER LEVEL TEXT 3.9.8 0 11/18/2002
Title:
REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - LOW WATER LEVEL TEXT 3.10.1 0 11/18/2002
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 K-
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 1 03/24/2005
Title:
SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING
\%-
Report Date: 06/13/06 Page88
. Page of of 88 Report Date: 06/13/06
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 .............. B2.0-6 B3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY .............. B3.0-1 B3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ................. TS/B3.0-10 B3.1 REACTIVITY CONTROL SYSTEMS .................................................... B3.1-1 B3.1.1 Shutdown Margin (SDM) ................................................................ B3.1-1 B3.1.2 Reactivity Anomalies ...................................................................... B3.1-8 B3.1.3 Control Rod OPERABILITY ............................................................ B3.1-13 B3.1.4 Control Rod Scram Times ........................... B3.1-22 B3.1.5 Control Rod Scram Accumulators ...................... .B3.1-29 B3.1.6 Rod Pattern Control ........................................... ..... TS/lB3.1-34 B3.1.7 Standby Liquid Control (SLC) System ..................... .... ............. B3.1-39 B3.1.8 Scram Discharge Volume (SDV) Vent and Drain'Valves ................ B3.1-47 B3.2 POWER DISTRIBUTION LIMITS ............ K"^ ..................... TS/B3.2-1.
B3.2.1 Average Planar Linear Heat Generationhate'(APLHGR) ........ TS/B3.2-1 B3.2.2 Minimum Critical Power Ratio (MOPR)...\ ......................... TS/B3.2-5 B3.2.3 Linear Heat Generation Rate,(LHG . ................... TS/B3.2-10 B3.2.4 Average Power Range Moni~tor,.(APRM) Gain
- and Setpoints ................... ....... TS/B3.2-14 B3.3 INSTRUMENTATO 1 N ........................ TS/B3.3-1 B3.3.1.1 Reactor Protecti'0 demn,(kPS) Instrumentation ........ TS/B3.3-1 B3.3.1.2 Source Range1jMrnit6r4(SRM) Instrumentation ........................ TS/B3.3-35 B3.3.1.3 Oscillation ;0. a-ng6 Mo Monitor io .............. ........TS/B3.343a 343 B3.3.2.1 Control Rddt jock4,is-trumentation ........................................... TS/B3.3-44 B3.3.2.2 Feedwate ýWain turbine High Water Level Trip In_ MSie-ntaibn ......... ...................... B3.3-55 B3.3.3.1 P. T t Monitoring (PAM) Instrumentation ..................... TS/B3.3-64 B3.3.3.2 bm6t utdown System............................ .. B3.3-76 B3.3.4.1 ~ ~ycle Recirculation Pump Trip (EOC-RPT) n'1*tumentation ............................... B3.3-81 B3.3.4.2 tici*pated Transient Without Scram Recirculation
-7. Pump Trip (ATWS-RPT) Instrumentation .................................. B3.3-92 B3.3.5.1 Emergency Core Cooling System (ECCS)
Instrumentation ................................. ............................. TS/B3.3-101 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 ............................................. B3.3-192 (continued)
SUSQUEHANNA - UNIT 2 TS / B TOC - 1 Revision 8
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 ................................................ I............................... B3.3-214 B3.4 REACTOR COOLANT SYSTEM (RCS) ......................................... TS/B3.4-1 B3.4.1 Recirculation Loops Operating ................................................. TS/B3.4-1 B3.4.2 Jet Pumps ...................................................................................... B3.4-10 B3.4.3 Safety/Relief Valves (S/RVs) .................................................... TS/83.4-15 B3.4.4 RCS Operational LEAKAGE .......... B3.4-19 B3.4.5 RCS Pressure Isolation Valve (PIV) Leakage ................................. B3.4-24 B3.4.6 RCS Leakage Detection Instrumentation ........................................ B3.4-30 B3.4.7 RCS Specific Activity ..................................................................... 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 83.4.10 RCS Pressure and Temperature (PIT) 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 .................................................................... 83.6-40 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 ooling ..................................................................................... B3.6-61 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 .................................. 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/B3.6-100 (continued)
SUSQUEHANNA - UNIT 2 TS / B TOC - 2 Revision 8
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 ................................................................. B3.7-24 B3.7.6 Main Turbine Bypass System ................................................... TS/B3.7-27 B3.7.7 Spent Fuel Storage Pool Water Level ............................................ B3.7-31 B3.8 ELECTRICAL POWER SYSTEM ........................................................ B3.8-1 B3.8.1 AC Sources - Operating ................................................................ B3.8-1 B3.8.2 AC Sources - Shutdown ................................................................ B3.8-39 B3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ...................................... B3.8-47 B3.8.4 DC Sources - Operating .......................................................... TS/B3.8-56 B3.8.5 DC Sources - Shutdown ................................................................ B3.8-70 B3.8.6 Battery Cell Parameters ................................................................. B3.8-77 B3.8.7 Distribution Systems - Operating ................................................... B3.8-84 B3.8.8 Distribution Systems - Shutdown ................................................... B3.8-94 B3.9 REFUELING OPERATIONS ......................... TS/B3.9-1 B3.9.1 Refueling Equipment Interlocks ................................................ TS/B3.9-1 B3.9.2 Refuel Position One-Rod-Out Interlock ........................................... B3.9-5 B3.9.3 Control Rod Position ...................................................................... B3.9-9 B3.9.4 Control Rod Position Indication ...................................................... B3.9-12 B3.9.5 Control Rod OPERABILITY - Refueling .................. B3.9-16 B3.9.6 Reactor Pressure Vessel (RPV) Water Level ................................. 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 5/23/2006 SUSQUEHANNA- UNIT 2 TS / B TOC - 3 Revision 8
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision TOC Table of Contents 8 B 2.0 SAFETY LIMITS BASES Page TS / B2.0-1 1 Page TS / B2.0-2 2 Page TS / B2.0-3 3 Page TS / B2.0-4 4 Page TS / B2.0-5 1 Pages B2.0-6 through B 2.0-8 0 B 3.0 LCO AND SR APPLICABILITY BASES Pages B 3.0-1 through B 3.0-4 0 Pages TS / B 3.0-5 through TS / B 3.0-7 1 Pages TS / B 3.0-8 through TS / B 3.0-9 2 Pages TS / B 3.0-10 through 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 Pages B 3.1-15 through B 3.1-22 0 Page TS / B 3.1-23 1 Pages B 3.1-24 through B 3.1-27 0 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 / B3.1.34 through TS / B 3.1-36 1 Pages TS / B 3.1-37 and TS / B 3.1-38 2 Pages B 3.1-39 through B 3.1-44 0 Page TS / B 3.1-45 1 Pages B 3.1-46 and B 3.1-47 0 Pages TS / B3.1-48 and TS / B 3.1-49 1 Page B 3.1-50 0 Page TS / B 3.1-51 1 B 3.2 POWER DISTRIBUTION LIMITS BASES Pages TS / B 3.2-1 and TS / B 3.2-2 1 Page TS / B 3.2-3 3 Page TS / B 3.2-4 1 Pages TS / B 3.2-5 and TS / B 3.2-6 3 Page TS / B 3.2-7 2 Pages TS / B3.2-8 and TS / B 3.2-9 3 SUSQUEHANNA - UNIT 2 TS / B LOES-1 Revision 73
SUSQUEHANNA STEAM ELECTRIC STATION LIST OFEFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Pages TS / B 3.2-10 through TS / B 3.2-17 1 Page TS / 3.2-18 2 Page TS / 3.2-19 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 Pages TS / B 3.3-7 through TS / B 3.3-12 2 Page TS / B 3.3-13 1 Page TS / B 3.3-14 2 Pages TS / B 3.3-15 and TS / B 3.3-16 1 Pages TS / B 3.3-17 and TS / B 3.3-18 2 Pages TS / B 3.3-19 through TS / B 3.3-27 1 Pages TS / B 3.3-28 through TS / B 3.3-30 2 Page TS / B 3.3-31 1 Page TS / B 3.3-32 3 Page TS / B 3.3-33 2 Pages TS / B 3.3-34 through TS / B 3.3-43 1 Pages TS / B 3.3-43a though TS / B 3.3-43i 0 Pages TS / B 3.3-44 through TS / B 3.3-54 2 Pages B 3.3-55 through B 3.3-63 0 Pages TS / B 3.3-64 and TS / B 3.3-65 2 Page TS / B 3.3-66 4 Page TS / B 3.3-67 3 Pages TS / B 3.3-68 and TS / B 3.3.69 4 Pages TS / B 3.3-70 and TS / B 3.3-71 3 Pages TS / B 3.3-72 and TS / B 3.3-73 2 Pages TS / B 3.3-74 3 Pages TS / B 3.3-75 2 Pages B 3.3-75a through TS / B 3.3-75c 4 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 3.3-91 0 Pages TS / B 3.3-92 through TS / B 3.3-103 1 Page TS / B 3.3-104 2 Pages TS / B 3.3-105 and TS / B 3.3-106 1 Page TS / B 3.3-107 2 Page TS / B 3.3-108 1 Page TS / B 3.3-109 2 Pages TS / B 3.3-110 through TS / B 3.3-112 1 Page TS / B 3.3-113 2 Page TS / B 3.3-114 1 Page TSi/B 3.3-115 2 Pages TS / B 3.3-116 through TS / B 3.3-118 2 Pages TS / B 3.3-119 through TS / B 3.3-120 1 SUSQUEHANNA -UNIT 2 TS / B LOES-2 Revision 73
SUSQUEIHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision 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 / B3.3-128 2 Pages TS / B3.3-129 through TS / B 3.3-131 1 Page TS / B 3.3-132 2 Pages TS / B3.3-133 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 through TS / B 3.3-162 1 Page TS / B3.3-163 2 Pages TS / B 3.3-164 through TS I B 3.3-177 1 Page TS / B 3.3-178 2 Page TS / B 3.3-179 3 Page TS / B 3.3-179a 2 Page TS / B3.3-180 1 Page TS / B3.3-181 2 Pages TS / B 3.3-182 through 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 /lB3.3-191 1 Pages B 3.3-192 through B 3.3-205 0 Page TS / B 3.3-206 1 Pages B 3.3-207 through B 3.3-209 0 Pages TS / B 3.3-210 through TS / B 3.3-213 1 Pages B 3.3-214 through B 3.3-220 0 B 3.4 REACTOR COOLANT SYSTEM BASES Pages TS / B 3.4-1 and TS / B 3.4-2 1 Pages TS / B 3.4-3 through TS / B 3.4-9 3 Pages B 3.4-10 through B 3.4-14 0 Page TS / B3.4-15 1 Pages TS / B 3.4-16 through TS / B 3.4-18 2 Pages B 3.4-19 through B 3.4-27 0.
Pages TS / B 3.4-28 and TS / B 3.4-29 1 Pages B 3.4-30 through B 3.3-31 0 Page TS / B3.4-32 1 Pages B 3.4-33 through B 3.4-36 0 Page TS / B3.4-37 1 Pages B.3.4-38 through B 3.4-40 0 Revision 73 UNIT 2 TSIBLOES-3 SUSQUEHANNA - UNIT SUSQUEHANNA -
2 TS / B LOES-3 Revision 73
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Page TS / B 3.4-41 1 Pages B 3.4-42 through B 3.4-48 0 Page TS / B 3.4-49 3 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 and TS / B 3.4-55 2 Page TS / B 3.4-56 1 Page TS / B 3.4-57 2 Pages TS / B 3.4-58 through TS / B 3.4-60 1 B 3.5 ECCS AND RCIC BASES Pages TS / B 3.5-1 and TS / B 3.5-2 1 Pages TS / B 3.5-3 through TS / B 3.5-6 2 Pages TS / B 3.5-7 through TS / B 3.5-10 1 Pages TS / B 3.5-11 and TS / B 3.5-12 2 Pages TS / B 3.6-13 and TS / B 3.5-14 1 Pages TS / B 3.5-15 and TS / B.3.5-16 2 Page TS / B 3.5-17 3 Page TS / B 3.5-18 1 Pages B 3.5-19 through B 3.5-24 0 Pages TS / B 3.5-25 through TS / B 3.5-27 1 Pages B3.5-28 through B 3.5-31 0 B 3.6 CONTAINMENT SYSTEMS BASES Page TS / B 3.6-1 2 Page TS / B 3.6-1a 3 Pages TS / B 3.6-2 through TS / B 3.6-5 2 Page TS / B 3.6-6 3 Pages TS / B 3.6-6a and TS / B 3.6-6b 2 Page TS / B3.6-6c 0 Pages B 3.6-7 through B 3.6-14 0 Page TS / B 3.6-15 3 Pages TS / B 3.6-15a and TS / B 3.6-15b 0 Page TS / B3.6-16 1 Page TS / B3.6-17 2 Page TS / B3.6-17a 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 / 8 3.6-23 2 Pages TS / B 3.6-24 and TS / B 3.6-25 1 Page TS / B 3.6-26 2 Page TS / B 3.6-27 3 Page TS / B 3.6-28 6 Page TS / B 3.6-29 3 SUSQUEHANNA - UNIT 2 TS / B LOES-4 Revision 73
SUSQUEHANNA STEAM ELECTRIC STATION LIST OFEFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Page TS / B 3.6-29a 0 Page TS / B 3.6-30 2 Page TS / B 3.6-31 3 Page TS / B 3.6-32 1 Page TS / B 3.6-33 2 Page TS / B 3.6-34 1 Pages TS / B 3.6-35 through TS / B 3.6-37 2 Page TS / B 3.6-38 1 Page TS / B 3.6-39 5 Pages B 3.6-40 through 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 / B3.6-51 2 Pages B 3.6-52 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 through TS / B 3.6-74 1 Pages B 3.6-75 and B 3.6-76 0 Page TS / B 3.6-77 1 Pages B 3.6-78 through B 3.6-82 0 Page TS / B 3.6-83 3 Page TS / B 3.6-84 2 Page TS / B 3.6-85 3 Page TS / B 3.6-86 1 Pages TS / B 3.6-87 and TS / B 3.6-87a 2 Page TS / B 3.6-88 3 Page TS / B 3.6-89 2 Page TS / B 3.3-90 3 Pages TS / B 3.6-91 through TS / B 3.6-95 1 Page TS / B 3.6-96 2 Pages TS / B 3.6-97 and TS / B 3.6-98 1 Page TS / B 3.6-99 2 Page TS / B 3.6-99a 0 Pages TS / B 3.6-100 and TS / B 3.6-101 1 Pages TS / B 3.6-102 and TS / B 3.6-103 2 Page TS / B 3.6-104 3 Pages TS / B 3.6-105 and TS / B 3.6-106 2 B 3.7 PLANT SYSTEMS BASES Pages TS / B 3.7-1 through TS / B 3.7-6 2 Page TS / B 3.7-6a 2 Pages TS / B 3.7-6b and TS / B 3.7-6c 0 Page TS / B 3.7-7 2 Page TS / B 3.7-8 1 SUSQUEHANNA - UNIT 2 TS / B LOES-5 Revision 73
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Pages B 3.7-9 through B 3.7-11 0 Pages TS / B 3.7-12 and TS / B 3.7-13 1 Pages TS / B 3.7-14 through TS / B 3.7-18 2 Page TS / B 3.7-18a 0 Pages TS / B 3.7-19 through TS / B 3.7-26 1 Pages B 3.7-24 through B 3.7-26 0 Pages TS / B 3.7-27 through TS / B 3.7-29 2 Page TS / B 3.7-30 1 Pages B 3.7-31 through B 3.7-33 0 B 3.8 ELECTRICAL POWER SYSTEMS BASES Pages B3.8-1 through 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 Page TS / B 3.8-6 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 3.8-37 0 Page TS / B 3.8-38 1 Pages TS / B 3.8-39 through TS / B 3.8-55 0 Pages TS / B 3.8-56 through TS / B 3.8-64 1 Page TS / B 3.8-65 2 Page TS / B 3.8-66 3 Pages TS / B 3.8-67 and TS / B 3.8-68 2 Page TS / B 3.8-69 3 Pages B 3.8-70 through B 3.8-85 0 Page TS / B 3.8-86 1 Page TS / B 3.8-87 2 Pages TS / B 3.8-88 through TS / 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 Page TS / B 3.9-2a 1 Pages TS / B 3.9-3 and TS / B 3.9-4 1 Pages B 3.9-5 through B 3.9-30 0 Revision 73 TSIB LOES-6 SUSQUEHANNA-UNIT2 SUSQUEHANNA - UNIT 2 TS / B LOES-6 Revision 73
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision B 3.10 SPECIAL OPERATIONS BASES Page TS / B3.10-1 1 Pages B 3.10-2 through B 3.10-32 0 Page TS / B 3.10-33 2 Pages B 3.10-34 through B 3.10-38 0 Page TS / B 3.10-39 2 TSB2 LOES, 5/30106 Revision 73 TS/B LOES-7 SUSQUEHANNA - UNIT SUSQUEHANNA -
UNIT 22 TS / B LOES-7 Revision 73
PPL Rev. 3 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 - UNIT 2 TS / B 3.3-64 Revision 2
PPL Rev. 3 PAM Instrumentation B 3.3.3.1 BASES APPLICABLE
- 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 to the two channel requirement is primary containment isolation valve (PCIV) position. In this case, the important 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. 3 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 pr6vided 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. 3 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-UNIT2 TS / B 3.3-67 Revision 3
PPL Rev. 3 PAM Instrumentation B 3.3.3.1 BASES LCO 5. Primary Containment High 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 1X1 08 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. 3 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) which consist of 6 channels that output to four control room recorders (one for channels A and C, one for channels B and D, one for channel E and one for channel F) provide reliable neutron flux measurement from 0% to 125% of full power. The PAM function for neutron flux is satisfied by any one channel of APRMs in each division (channels A,C, E comprise division one, channels B,D,F comprise division two). 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. I (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.3-69 Revision 4
PPL Rev. 3 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 in the control room on a back panel. 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 - UNIT 2 TS / B 3.3-70 Revision 3
PPL Rev. 3 PAM Instrumentation B 3.3.3.1 BASES (continued)
ACTIONS A Note has been provided to modify the ACTIONS related to PAM I 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._
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. 3 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.A 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. 3 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. 3 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 / B 3.3-74 Revision 3
PPL Rev. 3 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.
- 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. I Byram dated July 3, 1996.
SUSQUEHANNA - UNIT 2 TS / B 3.3-75 Revision 2
PPL Rev. 3 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 LP/PR-24201A PI-24202A Dome Pressure (blue pen)* PI-24202A1 PI-24204A N/A PT-24201 B LR/PR-24201 B PI-24202B (left side)
(blue pen)* PI-24202B1 (left side)
PI-24204B (left side)
- 2. Reactor Vessel N/A LT-24201A LR/PR-24201A LI-24201A (left side)
Water Level (Wide Range) (red pen)* LI-24201A1 (left side)
LI-24203A (left side)
N/A LT-24201 B LR/PR-24201 B LI-24201 B (left side)
(Wide Range) (red pen)* LI-24201 BI (left side)
LI-24203B (left side)
N/A LT-24203A N/A LI-24201A (right side)-()
(Extended Range) LI-24201A1 (right side)
LI-24203A (right side)
N/A LT-24203B N/A LI-24201B (right side)*(')
(Extended Range) LI-24201B1 (right side)
LI-24203B (right side)
N/A LT-24202A LR-24202 N/A (Fuel Zone Range) (red pen)*
N/A LT-24202B N/A LI-24205B*
(Fuel Zone Range)
- 3. Suppression N/A LT-25776A LR-25776A N/A Chamber Water Level (Wide Range) (red pen)
N/A LT-25776B LR-25776B N/A (Wide Range) (red pen)*
N/A LT-25775A LR-25776A LI-25775A (Narrow Range) (blue pen)
N/A LT-25775B LR-25776B LI-25775B (Narrow Range) (blue pen)
SUSQUEHANNA - UNIT 2 TS / B 3.3-75a Revision 4
PPL Rev. 3 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)
I N/A PT-25709B UR-25701 B (Dark Blue)* N/A (0 to 250 psig)
I N/A PT-25710A UR-25701A (Red)- N/A S(-15 to 65 psig)
I N/A PT-25710B UR-25701 B (Red)- N/A
(-15 to 65 psig)
- 5. Primary Containment RE-25720A RITS-25720A RR-25720A* N/A High Radiation RE-25720B RITS-25720B RR-25720B* N/A
- 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-A NR-C51-2R603A N/A (red pen)*
N/A APRM-B NR-C51-2R603B N/A (red pen)*
N/A APRM-C NR-C51-2R603A N/A (blue pen)*
N/A APRM-D NR-C51-2R603B N/A (blue pen)*
N/A APRM-E NR-C51-2R603C N/A (red pen)*
N/A APRM-F NR-C51-2R603D N/A (red pen)*
- 8. Containment AE-25745A AT-25745A UR-25701A (Blue Violet)* N/A Oxygen and (Hydrogen) UR-25701A (violet)-
Hydrogen Analyzer AE-25745B AT-25745B UR-25701B (Blue Violet)*
N/A (Hydrogen) UR-25701B (Violet)*
AE-25746A AT-25746A UR-25701A (Orange)* N/A (Oxygen)
AE-25746B AT-25746B UR-25701 B (Orange)* N/A
_(Oxygen)
SUSQUEHANNA 'UNIT 2 TS / B 3.3-75b Revision 4
PPL Rev. 3 PAM Instrumentation B 3.3.3.1 TABLE B 3.3.3.1-1 Post Accident Instruments (Page 3 of 3) "
Instrument/ariable Element Transmitter Recorder Indicator
- 9. Drywell Atmosphere TE-25790A TT-25790A UR-25701A (Brown)* N/A Temperature TR-25790A (point # 1)
TE-257908 TT-25790B UR-25701 B (Brown) N/A TR-25790B (point # 1)
- 10. Suppression Chamber TE-25753 TX-25751 N/A TIAH-25751*
Water Temperature TE-25755 TI-25751 TE-25757 TE-25759 TE-25763 TE-25765 TE-25767 TE-25769 TE-25752 TX-25752 N/A' TIAH-25752*
TE-25754 TI-25752 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-24201 B be used as acceptance criteria, however LI-24201A1, LI-24201 B1, LI-24203A. or LI-24203B may be used intheir 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 4
PPL Rev. 2 Not Used B 3.6.3.1 B 3.6 CONTAINMENT SYSTEMS B 3.6.3.1 Not Used I THIS PAGE INTENTIONALLY LEFT BLANK (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-69 Revision 1
PPL Rev. 2 Not Used B 3.6.3.1 THIS PAGE INTENTIONALLY LEFT BLANK (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-70 Revision 1
PPL Rev. 2 Not Used B 3.6.3.1 THIS PAGE INTENTIONALLYLEFT BLANK -
(continued)
SUSQUEHANNA - UNIT 2 TS / 13 3.6-71 Revision I
PPL Rev. 2 Not Used B 3.6.3.1 THIS PAGE INTENTIONALLY LEFT BLANK (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-72 Revision 2
PPL Rev. 2 Not Used B 3.6.3.1 THIS PAGE INTENTIONALLY LEFT BLANK (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.6-73 Revision 1
PPL Rev. 2 Not Used B 3.6.3.1 THIS PAGE INTENTIONALLY LEFT BLANK SUSQUEHANNA - UNIT 2 TS / B 3.6-74 Revision 1
PPL Rev. 1 DC. Sources-Operating B 3.8.4 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.4 DC Sources-Operating BASES BACKGROUND The DC electrical power system provides the AC emergency power system with control power. It also provides both motive and control power to selected safety related equipment. As required by 10 CFR 50, Appendix A, GDC 17 (Ref. 1), the DC electrical power system is designed to have sufficient independence, redundancy, and testability to perform its safety functions, assuming a single failure. The DC electrical power system also conforms to the recommendations of Regulatory Guide 1.6 (Ref. 2) and IEEE-308 (Ref. 3).
The Unit DC power sources provide both motive and control power to selected safety related equipment, as well as circuit breaker control power for the nonsafety related 13.8 kV, 4.16 kV, and 480 V and lower AC distribution systems. Each DC subsystem is energized by one 125/250 V battery and at least I Class 1E battery charger. The 250 V DC batteries for division I are supported by two half-capacity chargers; the 250 V DC batteries for division II are supported by a full capacity charger, and, the 125 V DC batteries are each supported by a single full capacity charger. Each battery is exclusively associated with a single 125/250 VDC bus and cannot be interconnected with any other 125/250 VDC subsystem. The chargers are supplied from the same AC load groups for which the associated DC subsystem supplies the control power. Transfer switches provide the capability to power Unit I and common DC loads from Unit 2 DC sources.
Diesel Generator (DG) E DC power sources provide control and instrumentation power for DG E.
During normal operation, the DC loads are powered from the battery chargers with the batteries floating on the system. In case of loss of normal power to the battery charger, the DC loads are automatically powered from the station batteries.
(continued)
SUSQUEHANNA-UNIT2 TS / B 3.8-56 Revision 1
PPL Rev. 1 DC Sources-Operating B 3.8.4 BASES BACKGROUND (continued) The DC power distribution system is described in more detail in Bases for LCO 3.8.7, "Distribution System-Operating," and LCO 3.8.8, "Distribution System-Shutdown."
Each battery has adequate storage capacity to carry the required load continuously for approximately 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
Each subsystem, including the battery bank, chargers and DC switchgear, is located in an area separated physically and electrically from the other subsystems to ensure that a single failure in one subsystem does not cause a failure in a redundant subsystem. There is no sharing between redundant Class I E subsystems such as
-batteries, or battery chargers.
The batteries for the electrical power subsystems are sized to produce required capacity at 80% of nameplate rating, corresponding to warranted capacity at end of life cycles and the 100% design demand.
The minimum design voltage limit is 105/210 V.
Each battery charger of DC electrical power subsystem has ample power output capacity for the steady state operation of connected loads required during normal operation, while at thesame time maintaining its battery bank fully charged. Each battery charger has sufficient capacity to restore the battery from the design minimum charge to its fully charged state within design basis requirements while supplying normal steady state loads (Ref. 3).
APPLICABLE The initial conditions of Design Basis Accident (DBA) and SAFETY ANALYSES transient analyses in the FSAR, Chapter 6 (Ref. 4) and Chapter 15 (Ref. 5), assume that Engineered Safety Feature (ESF) systems are OPERABLE. The DC electrical power system provides normal and emergency DC electrical power for the DGs, emergency auxiliaries, and control and switching during all MODES of operation. The OPERABILITY of the DC subsystems is consistent with the initial assumptions of the accident analyses and is based upon meeting the design basis of the unit. This includes maintaining DC sources OPERABLE (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-57 Revision 1
PPL Rev. I DC Sources-Operating B 3.8.4 BASES APPLICABLE during accident conditions in the event of:
SAFETY ANALYSES (continued) a. An assumed loss of all offsite AC power or all onsite AC power; and
- b. A worst case single failure.
The DC sources satisfy Criterion 3 of the NRC Policy Statement (Ref. 6).
LCO The DC electrical power subsystems are required to be OPERABLE to ensure the availability of the required power to shut down the reactor
-and maintain it in a safe condition after an anticipated operational occurrence (AOO) or a postulated DBA. Loss of any DC electrical power subsystem does not prevent the minimum safety function from being performed (Ref. 3).
The DC electrical power subsystems include:
a) each Unit 2 and Unit 1 DC electrical power subsystem identified in Table 3.8.4-1 including a 125 volt or 250 volt DC battery bank in parallel with a battery charger and the corresponding control equipment and interconnecting cabling supplying power to the associated bus; arid, b) the Diesel Generator E DC electrical power subsystem identified in Table 3.8.4-1 including a 125 volt DC battery bank in parallel with a battery charger and the corresponding control equipment and interconnecting cabling supplying power to the associated bus.
APPLICABILITY The DC electrical power sources are required to be OPERABLE in MODES 1, 2, and 3 to ensure safe unit operation and to ensure that:
- a. Acceptable fuel design limits and reactor coolant pressure boundary limits are not exceeded as a result of AOOs or abnormal transients; and (continued)
SUSQUEHANNA-UNIT2 TS / B 3.8-58 Revision 1
PPL Rev. 1 DC Sources-Operating B 3.8.4 BASES APPLICABILITY b. Adequate core cooling is provided, and containment integrity and (continued) other vital functions are maintained in the event of a postulated DBA.
The DC electrical power requirements for MODES 4 and 5 are addressed in the Bases for LCO 3.8.5, "DC Sources-Shutdown."
ACTIONS A.1 Condition A represents one subsystem with a loss of ability to completely respond to an event, and a potential loss of ability to remain energized during normal operation. It is therefore imperative that the operators attention focus on stabilizing the unit, minimizing the potential for complete loss of DC power to the affected division. The 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limit is consistent with the allowed time for an inoperable DC Distribution System division.
If one of the required DC electrical power subsystems is inoperable (e.g., inoperable battery, inoperable battery charger(s), or inoperable battery charger and associated inoperable battery), the remaining DC electrical power subsystems have the capacity to support a safe shutdown and to mitigate an accident condition. Since a subsequent worst case single failure could, however, result in the loss of minimum necessary DC electrical subsystems to mitigate a worst case accident, continued power operation should not exceed 2-hours. The 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Completion Time is based on Regulatory Guide 1.93 (Ref. 7) and reflects a reasonable time to assess unit status as a function of the inoperable DC electrical power subsystem and, if the DC electrical power subsystem is not restored to OPERABLE status, to prepare to effect an orderly and safe unit shutdown.
Condition A is modified by a Note that states that Condition A is not applicable to the DG E DC electrical power subsystem.
Condition C or D is applicable to an inoperable DG E DC electrical power subsystem.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-59 Revision 1
PPL Rev. 1 DC Sources-Operating B 3.8.4 BASES ACTIONS B.1 and B.2 (continued)
Ifthe Unit 2 DC electrical power subsystem cannot be restored to OPERABLE status within the required Completion Time, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the unit 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. The Completion Time to bring the unit to MODE 4 is consistent with the time required in Regulatory Guide 1.93 (Ref. 7).
C.1 If Diesel Generator E is not aligned to the class 1E distribution system, the only supported safety function is for the ESW system. Therefore, under this condition, if Diesel Generator E DC power subsystem is not OPERABLE actions are taken to either restore the battery to OPERABLE status or shutdown Diesel Generator E and close the associated ESW valves in order to ensure the OPERABILITY of the ESW system. The 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limit is consistent with the allowed time for other inoperable DC sources and provides sufficient time to evaluate the condition of the battery and take the corrective actions.
D.1 If the Diesel Generator is aligned to the class 1E distribution system, the loss of Diesel Generator E DC power subsystem will result in the loss of a on-site Class 1E power source. Therefore, under this condition, if Diesel Generator E DC power subsystem is not OPERABLE actions are taken to either restore the battery to OPERABLE status or declare Diesel Generator E inoperable and take Actions of LCO 3.8.1. The 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limit is consistent with the allowed time for other DC sources and provides sufficient time to evaluate the condition of the battery and take the necessary corrective actions.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-60 Revision 1
PPL Rev. 1 DC Sources-Operating B 3.8.4 BASES ACTIONS E.1 and E.2 (continued)
With one or more DC Unit I DC power subsystems inoperable, the remaining DC electrical power distribution subsystems are capable of supporting the minimum safety functions necessary to shut down the reactor and maintain it in a safe shutdown condition, assuming no single failure. However, overall reliability is reduced because a single failure in the remaining DC electrical power distribution subsystems could result in the minimum required ESF functions not being supported. The Completion Time of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> is consistent with the Completion Times associated with a loss of one or more DC distribution subsystems and will allow sufficient time to restore power.
Completion of Required Action E.1 causes Unit 1 loads to be powered from a Unit 2 DC electrical power subsystem. Although the corresponding Unit 2 DC electrical power subsystems are evaluated for this condition, the CONDITION violates a design commitment to maintain DC power separation between units. To minimize the time this condition exists, Required Action E.2 directs power to be restored to the corresponding Unit 1 .DC electrical power subsystem, which restores power to the common loads, or requires that the Unit 1 and common loads be declared inoperable. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> provides sufficient time to restore power and acknowledges the fact that the condition, although not consistent with all design requirements, maintains all required safety systems available. "
F.1 If Unit 1 and common loads required to support Unit 2 cannot be transferred to corresponding Unit 2 DC electrical power subsystem when Unit 1 DC sources are inoperable; or, cannot be transferred back to a Unit 1 DC source when the Unit I DC source becomes OPERABLE, the associated loads may be incapable of performing their intended function and must be declared inoperable immediately.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-61 Revision 1
PPL Rev. 1 DC Sources-Operating B 3.8.4 BASES (continued)
SURVEILLANCE SR 3.8.4.1 REQUIREMENTS Verifying battery terminal voltage while on float charge for the batteries helps to ensure the effectiveness of the charging system and the ability of the batteries to perform their intended function. Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery (or battery cell) and maintain the battery (or a battery cell) in a fully charged state. The voltage requirements are consistent with the initial voltages assumed in the battery sizing calculations. The SR must be performed every 7 days consistent with manufacturer recommendations and IEEE-450 (Ref. 8). However, this Frequency is modified by a Note that allows the Frequency to be extended for up to 14 days when the battery is on
-equalize charge or has been on equalize charge any time during the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
This change recognizes the routine 7 day Frequency must be extended until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after an equalize charge is completed so that meaningful results are obtained for this SR. The 14 day Frequency is not modified by the Note, therefore, the SR must be performed every 14 days regardless of how often the battery is placed on equalize charge.
SR 3.8.4.2 Visual inspection to detect corrosion of the battery cells and connections; or, measurement of the resistance of each inter-cell, inter-rack, inter-tier, and terminal connection with visible corrosion, provides an indication that there is no physical damage or abnormal deterioration that could potentially degrade battery performance.
The connection resistance limits established for this SR provide two acceptance limits for any connection where there is visible signs of corrosion. The first limit, if met, requires no additional actions and ensures the design capability of the battery is maintained. If the second limit is used, the calculated average resistance for the associated battery determined is SR 3.8.4.5 shall be recalculated using the new resistance value. Resistance valves shall be measured for only those connections where there is visible signs of corrosion. To determine the average connection resistance, data from the performance of SR 3.8.4.5 can be used for unaffected connections.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-62 Revision I
PPL Rev. 1 DC Sources-Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.2 (continued)
REQUIREMENTS The Frequency for these inspections, which can detect conditions that can cause power losses due to resistance heating, is 92 days. This Frequency is considered acceptable based on operating experience related to detecting corrosion trends.
SR 3.8.4.3 Visual inspection of the battery cells, cell plates, and battery racks provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance. The presence of physical damage or deterioration does not represent a failure of this SR, provided an evaluation determines that the physical damage or deterioration does not affect the OPERABILITY of the battery (its ability to perform its design function).
The Frequency of this SR is acceptable because other administrative controls ensure adequate battery performance during the 18 month interval. Furthermore, operating experience has shown these components usually pass the Surveillance when performed at the
.18 month Frequency; therefore, the Frequency is acceptable from a reliability standpoint.
SR 3.8.4.4 and SR 3.8.4.5 Visual inspection and resistance measurements of inter-cell, inter-rack, inter-tier, and terminal connections provides an indication of physical damage or abnormal deterioration that could indicate degraded battery condition. The anti-corrosion material is used to help ensure good electrical connections and to reduce terminal deterioration. The visual inspection for corrosion is not intended to require removal of and inspection under each terminal connection.
The removal of visible corrosion is a preventive maintenance SR. The presence of visible corrosion does not necessarily represent a failure of this SR, provided visible corrosion (continued)
SUSQUEHANNA-UNIT2 TS / B 3.8-63 Revision 1
PPL Rev. 1 DC Sources-Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.4 and SR 3.8.4.5 (continued)
REQUIREMENTS is removed during performance of this Surveillance. The connection resistance limits for this SR must be below the limits specified in the SR. The calculated average resistance limits ensures that the total voltage drop across the battery connections is consistent to those assumed in the battery calculations, while the upper limit for battery resistance prevents the possibility of battery discharge due to overheating of the connections.
The Frequency of this SR is acceptable because other administrative controls ensure adequate battery performance during the 18 month interval. Furthermore, operating experience has shown these components usually pass the Surveillance when performed at the 18 month Frequency; therefore, the Frequency is acceptable from a reliability standpoint.
SR 3.8.4.6 Battery charger capability requirements are based on the design capacity of the chargers (Ref. 3). According to Regulatory Guide 1.32 (Ref. 9), the battery charger supply is required to be based on the largest combined demands of the various steady state loads and the charging capacity to restore the battery from the design minimum charge state to the fully charged state, irrespective of the status of the unit during these demand occurrences. The minimum required amperes and duration ensures that these requirements can be satisfied.
The Frequency is acceptable, given the unit conditions required to perform the test and the other administrative controls existing to ensure adequate charger performance during these 24 month intervals. In addition, this Frequency is intended to be consistent with expected fuel cycle lengths.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-64 Revision 1
PPL Rev. I DC Sources-Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.7 REQUIREMENTS (continued) A battery service test is a special test of the battery's capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The test can be conducted using actual or simulated loads. The discharge rate and test length corresponds to the design duty cycle requirements as specified in Reference 12.
The Frequency of 24 months is consistent with the recommendations of Regulatory Guide 1.32 (Ref. 9) and Regulatory Guide 1.129 (Ref. 10), which state that the battery service test should be performed during refueling operations or at some other outage, with intervals between tests not to exceed 24 months.
This SR is modified by a Note which allows the performance of a modified performance discharge test in lieu of a service test once per 60 months.
A modified performance discharge test is a test of the battery capacity and its ability to provide a high rate, short duration load (usually the highest rate of the duty cycle). This will confirm the battery's ability to meet the critical period of the load duty cycle, in addition to determining its percentage of rated capacity. Initial conditions for the modified performance discharge test should be identical to those specified for a service test.
The modified performance discharge test is a test of simulated duty cycle consisting of two different discharge rates. The first discharge rate consists of the one minute published rate for the battery or the largest current loads of the duty cycle followed by a second discharge rate which employs the test rate for the performance discharge test.
These discharge rates envelope the duty cycle of the service test.
Since the ampere-hours removed by a published one minute discharge rate represent a very small portion of the battery capacity, the test rate can be changed to that for the performance discharge test without compromising the results of the performance discharge test. The battery terminal voltage for the modified performance discharge test should remain above the minimum battery terminal voltage specified in the service test.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-65 Revision 2
PPL Rev. 1 DC. Sources-Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.7 (continued)
REQUIREMENTS When the battery loads after the first minute exceeds the performance test discharge rate, the modified performance discharge test is performed by first conducting the service test, then adjusting the discharge rate to the constant current value normally used for the performance discharge test. This test is terminated when the specified minimum battery terminal voltage is reached.
When the battery loads after the first minute exceeds the performance discharge test rate, the battery capacity is calculated as follows:
% of rated capacity at 25 0C (77*F) =
K Ampere Hours]
Where:
K = Temperature Correction Factor from IEEE 450-1995 1,= Discharge Current in amps for n-th section -
t, = Duration of n-th section discharge in hour n = Section number for each portion of the discharge, including both service test and performance test portions This % of rated capacity equation uses the temperature corrected Ampere-Hours instead of the temperature corrected discharge rates as specified in IEEE 450-1995. It is not possible to temperature correct the discharge rate without impacting the service test.
The SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required DC electrical power subsystem from service, perturb the Electrical Distribution System, and challenge safety systems.
Since the Diesel Generator E DC electrical power subsystem does not support loads other than the Diesel Generator E required loads, the mode restriction note need not be applied to the Diesel Generator E subsystem unless it is aligned to the class 1E distribution subsystem.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-66 Revision 3
PPL Rev. 1 DC Sources-Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.7 (continued)
REQUIREMENTS The note does have applicability to the Diesel Generator E subsystem when the Diesel Generator E is substituted for one of the other Diesel Generators. When the Diesel Generator E is aligned to the class 11E distribution subsystem, the Diesel Generator E subsystem is required to support operability of the Diesel Generator E. Thus when in this configuration, the note does need to be applicable since performing the Surveillance would remove a required DC electrical power subsystem from service.
SR 3.8.4.8 A battery performance discharge test is a test of constant current
.capacity of a battery, normally done in the as found condition, after having been in service, to detect any change in the capacity determined by the acceptance test. The test is intended to determine overall battery degradation due to age and usage.
A battery modified performance discharge test is described in the Bases for SR 3.8.4.7. Either the battery performance discharge test or the modified performance discharge test is acceptable for satisfying SR 3.8.4.8; however, only the modified performance discharge test may be used to satisfy SR 3.8.4.8 while satisfying the requirements of SR 3.8.4.7 at the same time.
The acceptance criteria for this Surveillance is consistent with IEEE-450 (Ref. 8) and IEEE-485 (Ref. 11). These references recommend that the battery be replaced if its capacity is below 80% of the manufacturer's rating. A capacity of 80% shows that the battery rate of deterioration is increasing, even if there is ample capacity to meet the load requirements.
The Frequency for this test is normally 60 months. If the battery shows degradation, or if the battery has reached 85% of its expected service life and capacity is < 100% of the manufacturer's rating, the Surveillance Frequency is reduced to 12 months. However, if the battery shows no degradation but has reached 85% of its expected service life, the Surveillance Frequency is only reduced to 24 months for batteries that retain capacity > 100% of the manufacturer's rating.
Degradation is indicated, according to IEEE-450 (Ref. 8), when the battery capacity drops by more than 10% relative to its capacity on the previous performance test or when it is 10% below the manufacturer's rating. All these Frequencies are consistent with the recommendations in IEEE-450 (Ref. 8).
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-67 Revision 2
PPL Rev. I DC Sources-Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.8 (continued)
REQUIREMENTS The SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required DC electrical power subsystem from service, perturb the Electrical Distribution System, and challenge safety systems.
Since the Diesel Generator E DC electrical power subsystem does not support loads other than the Diesel Generator E required loads, the mode restriction note need not be applied to the Diesel Generator E subsystem unless it is aligned to the class 1E distribution subsystem.
The note does have applicability to the Diesel Generator E subsystem when the Diesel Generator E is substituted for one of the other Diesel Generators. When the Diesel Generator E is aligned to the class 1 E distribution subsystem, the Diesel Generator E subsystem is required to support operability of the Diesel Generator E. Thus when in this configuration, the note does need to be applicable since performing the Surveillance would remove a required DC electrical power subsystem from service.
SR 3.8.4.9 This Surveillance is provided to direct that Surveillances for the Unit 1 DC sources required to support Unit 2 are governed by the Unit 2 Technical Specifications. When Unit I DC Sources are required to be Operable to support Unit 2, the Unit 1 Surveillances must be met.
Performance of a Unit 1 Surveillance at the specified Frequency will satisfy Unit 2 requirements.
When Unit 1 is in MODE 4 or 5 or moving irradiated fuel assemblies in the secondary containment, a Note to SR 3.8.5.1 specifies that some SRs are required to be met but do not have to be performed. The Note to Unit 2 SR 3.8.5.1 states that the Note to Unit I SR 3.8.2.1 is applicable if Unit I is in MODE 4 or 5. This ensures that Unit 2 Technical Specifications do not require a Unit I SR to be performed, when the Unit 1 Technical Specifications does not require performance of a Unit 1 SR.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-68 Revision 2
PPL Rev. 1 DC Sources-Operating B 3.8.4 BASES (continued)
REFERENCES 1. 10 CFR 50, Appendix A, GDC 17.
- 4. FSAR, Chapter 6.
- 5. FSAR, Chapter 15.
- 6. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).
- 9. Regulatory Guide 1.32, February 1977.
- 10. Regulatory Guide 1.129, April 1977, February 1978.
- 11. IEEE Standard 485,1983.
- 12. FSAR Chapter 8, Section 8.3.2.1.1.6.
SUSQUEHANNA - UNIT 2 TS / B 3.8-69 Revision 3