ML060870410
| ML060870410 | |
| Person / Time | |
|---|---|
| Site: | Susquehanna  |
| Issue date: | 03/17/2006 |
| From: | Susquehanna |
| To: | Gerlach R Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| Download: ML060870410 (34) | |
Text
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MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2006-12466 USE~RINO]ATIOWU GERLACH*RCSE M EMPL#:028401 CA#:
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TSB2 -
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 02/01/2006 ADD MANUAL TABLE OF CONTENTS DATE: 03/16/2006 CATEGORY: DOCUMENTS TYPE: TSB2
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SSES MANUAL r Manual Name:
TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL Table Of Contents Issue Date:
03/16/2006 Procedure Nane Rev TEXT LOES 68
Title:
LIST OF EFFECTIVE SECTIONS Issue Date 03/16/2006 Change ID Change Number TEXT TOC
Title:
TABLE OF CONTENTS 7
04/18/2005 TEXT 2.1.1 1
Title:
SAF'ETY LIMITS (SLS) REACTOR TEXT 2.1.2 0
Title:
SAFETY LIMITS (SLS) REACTOR TEXT 3.0 1
Title:
LIMITING CONDITION FOR.OPEPJ 10/27/2004 7
CORE SLS E
11/18/2002 COOLANT SYSTEM (RCS) PRESSURE SL 04/18/2005 ATION (LCO) APPLICABILITY Q
TEXT 3.1.1
Title:
REACTIVITY 1
CONTROL SYSTEMS 03/24/2005 SHUTDOWN MARGIN (SDM)
TEXT 3.1.2
Title:
REACTIVITY j
0 11/18/2002 CONTROL SYSTEMS REACTIVITY ANOMALIES TEXT 3.1.3
Title:
REACTIVITY TEXT 3.1.4
Title:
REACTIVITY TEXT 3.1.5
Title:
R1LACTIVITY 1
CONTROL SYSTEMS 2
CONTROL SYSTEMS 1
CONTROL SYSTEMS 07/06/2005 CONTROL ROD OPERABILITY 07/06/2005 CONTROL ROD SCRAM TIMES 07/06/2005 CONTROL ROD SCRAM ACCUMULATORS TEXT 3.1.6 2
03/24/2005
Title:
REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Pagel of 8 Report Date: 03/16/06 Page 1 of 8 Report Date: 03/16/06
SSES MANUAL Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL K>S TEXT 3.1.7 1
08/30/2005
Title:
REACTIVITY CONTROL SYSTEMS STANDBY LIQUID CONTROL TEXT 3.1.8 1
10/19/2005
Title:
REACTIVITY CONTROL SYSTEMS SCRAM DISCHARGE VOLUME (SLC)
SYSTEM (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)
TEX-T 3.2.3 0
11/18/2002
Title:
POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE LHGR TEXT 3.2.4
Title:
POWER DISTRIBUTION 1
07/06/2005 LIM1ITS AVERAGE POWER RANGE MONITOR (APRM) GAIN AND SETPOINTS G )
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
Title:
OPRM INSTRUMENTATION 0
11/22/2004 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 2
07/06/2005
Title:
INSTRUMENTATION POST ACCIDENT MONITORING (PAM) INSTRUMENTATION Page2 of 8 Report Date: 03/16/06 Page 2 of 8 Report Date: 03/16/06
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
Title:
INSTRUMENTATION 1
11/09/2004 PRIMARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.6.2 1
11/09/2004.
Title:
INSTRUMENTATION SECONDARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.7.1
Title:
INSTRUMENTATION INSTRUMENTATION TEXT 3.3.8.1
Title:
INSTRUMENTATION TEXT 3.3.8.2
Title:
INSTRUMENTATION TEXT 3.4.1
Title:
REACTOR COOLANT TEXT 3.4.2
Title:
11/18/2002 CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM 1
09/02/2004 LOSS OF POWER (LOP) INSTRUMENTATION 0
11/18/2002 REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORING 2
11/22/2004 SYSTEM (RCS) RECIRCULATION LOOPS OPERATING 0
11/18/2002 SYSTEM (RCS) JET PUMPS Pag 3 f E Reor Dae:
3/1/0 Page 3 of f;
Report Date: 03/16/06
SSES MIANUAL Manual Name:
TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL K>o TEXT 3.4.3
Title:
REACTOR TEXT 3.4.4
Title:
REACTOR TEXT 3.4.5
Title:
REACTOR 1
01/16/2006 COOLANT SYSTEM (RCS) SAFETY/RELIEF VALVES (S/RVS) 0 11/18/2002 COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE 1
01/16/2006 COOLANT SYSTEM (RCS) RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE TEXT 3.4.6
Title:
REACTOR TEXT 3.4.7
Title:
REACTOR I
COOLANT SYSTEM (RCS) 1 COOLANT SYSTEM (RCS) 04/18/2005 RCS LEAKAGE DETECTION INSTRUMENTATION 04/18/2005 RCS SPECIFIC ACTIVITY TEXT 3.4.8
Title:
REACTOR COOLANT HOT SHUTDOWN TEXT 3.4.9
Title:
REACTOR COOLANT COLD SHUTDOWN SYSTEM (RCS) 0 SYSTEM (RCS) 04/18/2005 RESIDUAL HEAT REMOVAL 11/18/2002 RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM-,-i (RHR) SHUTDOWN COOLING SYSTEM TEXT 3.4.10
Title:
REACTOR COOLANT TEXT 3.4.11
Title:
REACTOR COOLANT TEXT 3.5.1 0
11/18/2002 SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE (P/T) LIMITS 0
11/18/2002 SYSTEM (RCS)
REACTOR STEAM DOME PRESSURE 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 Page 4 of 8 Report Date: 03/16/06 Page 4 of 8 Report Date: 0 3/16/06
SSES MANUAL Manual Name:
TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.6.1.1
Title:
CONTAINMENT TEXT 3.6.1.2
Title:
CONTAINMENT o
11/18/2002 SYSTEMS PRIMARY CONTAINMENT 0
11/18/2002 SYSTEMS PRIMARY CONTAINMENT AIR LOCK TEXT 3.6.1.3
Title:
COTJTAINMENT 3
12/08/2005 SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)
TEXT 3.6.1.4
Title:
CONTAINMENT TEXT 3.6.1.5
Title:
CONTAINMENT TEXT 3.6.1.6
Title:
CONTAINMENT TEXT 3.6.2.1
Title:
CONTAINMENT TEXT 3.6.2.2
Title:
CONTAINMENT TEXT 3.6.2.3
Title:
CO7TAINMENT TEXT 3.6.2.4
Title:
CONTAINMENT TEXT 3.6.3.1
Title:
CONTAINMENT TEXT 3.6.3.2
Title:
CCNTAINMENT 0
11/18/2002 SYSTEMS CONTAINMENT PRESSURE 1
10/05/2005 SYSTEMS DRYWELL AIR TEMPERATURE o
11/18/2002 SYSTEMS SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKERS 0
11/18/2002.
SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE 0
11/18/2002 SYSTEMS SUPPRESSION POOL WATER LEVEL 1
01/16/2006 SYSTEMS RESIDUAL HEAT REMOVAL (RHR)
SUPPRESSION POOL COOLING 0
11/18/2002 SYSTEMS RESIDUAL HEAT REMOVAL (RHR)
SUPPRESSION POOL SPRAY 1
04/18/2005 SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS 1
04/18/2005 SYSTEMS DRYWELL AIR FLOW SYSTEM Page 5 of
Report Date: 03/16/06 Page 5 of X,
Report Date: 03/16/06
SSES MANUAL Manual Name:
TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL 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
Title:
PLANT TEXT 3.7.3
Title:
PLANT 1
11/09/2004 SYSTEMS EMERGENCY SERVICE WATER (ESW) SYSTEM 0
11/18/2002.
SYSTEMS CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM I
TEXT 3.7.4
Title:
PLANT SYSTEMS 0
11/18/2002 CONTROL ROOM FLOOR COOLING SYSTEM TEXT 3.7.5
Title:
PLANT TEXT 3.7.6
Title:
PLANT TEXT 3.7.7
Title:
PLANT TEXT 3.8.1 0
11/18/2002 SYSTEMS MAIN CONDENSER OFFGAS 1
01/17/2005 SYSTEMS MAIN TURBINE BYPASS SYSTEM 0
11/18/2002 SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL 3
10/05/2005
Title:
ELECTRICAL POWER SYSTEMS AC SOURCES -
OPERATING Pag 6
f 8R p r D t : 0 / 6 0 Page 6 of 8 Report Date: 03/16/06
SSES MANUAL kManual Name:
TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.8.2
Title:
ELE-TRICAL TEXT 3.8.3
Title:
ELECTRICAL TEXT 3.8.4
Title:
ELECTRICAL TEXT 3.8.5
Title:
ELECTRICAL TEXT 3.8.6
Title:
ELECTRICAL 0
11/18/2002 POWER SYSTEMS AC SOURCES -
SHUTDOWN 0
11/18/2002 POWER SYSTEMS DIESEL FUEL OIL, LUBE OIL, AND STARTING AIR 0
11/18/2002 POWER SYSTEMS DC SOURCES -
OPERATING 0
11/18/2002 POWER SYSTEMS DC SOURCES -
SHUTDOWN 0
11/18/2002 POWER SYSTEMS BATTERY CELL PARAMETERS
-EXT 3.8.7
- 4
Title:
ELECTRICAL 2
03/16/2006 POWER SYSTEMS DISTRIBUTION SYSTEMS -
OPERATING TEXT 3.8.8 0
11/18/2002.
Title:
ELECTRICAL POWER SYSTEMS.DISTRIBUTION SYSTEMS -
SHUTDOWN TEXT 3.9.1
Title:
REFUELING TEXT 3.9.2
Title:
REFUELING TEXT 3.9.3
Title:
REFUELING TEXT 3.9.4
Title:
REFUELING TEXT 3.9.5
Title:
RE-:UELING OPERATIONS OPERATIONS OPERATIONS OPERATIONS OPERATIONS 0
11/18/2002 REFUELING EQUIPMENT INTERLOCKS 0
11/18/2002 REFUEL POSITION ONE-ROD-OUT INTERLOCK 0
11/18/2002 CONTROL ROD POSITION 0
11/18/2002 CONTROL ROD POSITION INDICATION 0
11/18/2002 CONTROL ROD OPERABILITY -
REFUELING Pae7 o
eotDt:0/60 Page 7 of 8 Report Date: 03/16/06
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
Title:
SPECIAL TEXT 3.10.2
Title:
SPECIAL TEXT 3.10.3
Title:
SPECIAL TEXT 3.10.4
Title:
SPECIAL TEXT 3.10.5
Title:
SPECIAL TEXT 3.10.6
Title:
SPECIAL TEXT 3.10.7
Title:
SPECIAL TEXT 3.10.8
Title:
SPECIAL OPERATIONS OPERATIONS OPERATIONS OPERATIONS OPERATIONS OPERATIONS OPERATIONS OPERATIONS 0
11/18/2002 INSERVICE LEAK AND HYDROSTATIC TESTING.OPERATION 0
11/18/2002 REACTOR MODE SWITCH INTERLOCK TESTING 0
11/18/2002 SINGLE CONTROL ROD WITHDRAWAL -
HOT SHUTDOWN 0
11/18/2002 SINGLE CONTROL ROD WITHDRAWAL -
COLD SHUTDOWN 0
11/18/2002 SINGLE CONTROL ROD DRIVE (CRD)
REMOVAL -
REFUELING 0
11/18/2002 MULTIPLE CONTROL ROD WITHDRAWAL -
REFUELING 1
03/24/2005 CONTROL ROD TESTING -
OPERATING 1
03/24/2005 SHUTDOWN MARGIN (SDM) TEST -
REFUELING Q-Pa e 8 o
e o t D t :
0 /
6 0 Page 8 of 8 Report Date: 03/16/06
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision TOC Table of Contents 7
B 2.0 SAFETY LIMITS BASES Page TS / B 2.0-1 1
Page TS / B 2.0-2 2
Page TS / B 2.0-3 3
Page TS / B 2.0-4 4
Page TS/B2.0-5 1
Pages B 2.0-6 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
/ 4>
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 PagesTS/B3.0-16andTS/B3.0-17 7>
0 B 3.1 REACTIVITY CONTROL BASES Pages B 3.1-1 through B 3.1-4 Kt-\\ /
0 PageTS/B3.1-5 1
Pag'es TS / B 3.1-6 and TS,B 3.l-7 1
2 Pages B 3.1-8 through B 3i1-13'!.S--
0 Page TS / B 3.1 7<
1 Pages B 3.1-15 through B 3.1-22 0
Page TS/B3.1-23/
1 Pages B 3.1-241through.B 3.1-27 0
Page TS / B 3.1-28 ',,,
2 Page TS / 3.- 29.-__,
I Pages B 3.1-30 through B 3.1-33 0
PagestS7/ B 3.134 through TS / B 3.1-36 1
Page TS /_B,3.1-37 2
Page TS LB 3.1-38 2
(Pages'B 3.1-39 through B 3.1-44 0
Page-TS/B3.1-45 1
P~ages B 3.1-46 and B 3.1-47 0
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 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 I B 3.2-7 2
Pages TS / B 3.2-8 and TS / B 3.2-9 3
SUSQUEHANNA
- UNIT 2 TS I B LOES-1 Revision 68 SUSQUEHANNA - UNIT 2 TS I B LOES-1 Revision 68
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE 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
Page TS / B 3.3-7 2
Pages TS / B 3.3-8 through TS / B 3.3-11 2
Page 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
Page TS / B 3.3-68 4
Pages TS / B 3.3-69 and TS I B 3.3-70 3
Pages TS / B 3.3-71 3
Pages TS / B 3.3-72 through TS / B 3.3-75 2
Page TS I B 3.3-75a 4
Pages TS / B 3.3-75b and TS / B 3.3-75c 4
Pages B 3.3-76 through 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 TS / B 3.3-115 2
SUQJHNA-UI T/LE-eiin6 SUSQUEHANNA - UNIT 2 TS / B LOES-2 Revision 68
SUSQUEHANNA STEAM ELECTRIC STATION LIST CF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision 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
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 /B3.3-126 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 through TS / B 3.3-162 1
Page TS / B 3.3-163 2
Pages TS / B 3.3-164 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 /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 / B 3.3-191 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 3.3-220 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 / B 3.4-15 1
Pages TS /B3.4-16 through TS /B3.4-18 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 / B 3.4-37 1
Pages B 3.4-38 through B 3.4-40 0
Page TS /B 3.4-41 1
SUSQIJEHANNA
- UNIT 2 TS/BLOES-3 Revision 68 SUSQIJEHANNA - UNIT 2 TS / B LOES-3 Revisionl 68
SUSQUEHANNA STEAM ELECTRIC STATION LIST C'F EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title Revision Pages B 3.4-42 through B 3.4-48 0
Page TS / B 3.4-49 2
Page TS / B 3.4-50 1
Page TS / B 3.4-51 2
Pages TS / B 3.4-52 and TS / B 3.4-53 1
Pages TS / B 3.4-54 and TS / B 3.4-55 2
Pages TS / B 3.4-56 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 / 8 3.5-15 and TS / B.3.5-16 2
Page TS / B 3.5-17 3
Page TS / B 3.5-18 1
Pages B 3.5-19 through B 3.5-24 0
Pages TS / B 3.5-25 through TS / B 3.5-27
.1 Pages B 3.5-28 through B 3.5-31 0
B 3.6 CONTAINMENT SYSTEMS BASES Page TS/ B 3.6-1 2
Page TS / B 3.6-1a -
3 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 / B 3.6-6c 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 / B 3.6-16 1
Page TS / B 3.6-17 2
Page TS / B 3.6-17a 0
Pages TS /B3.6-18 and TS /B 3.6-19 1
Page TS / B 3.6-20 2
Page TS /B3.6-21 3
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SUQJHNA-UI T/LE-eiin6 SUSQUEHANNA - UNIT 2 TS I B LOES-4 Revision 68
SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
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SUSQUEHANNA
- UNIT 2 TS/B LOES-5 Revision 68 SUSQUJEHANNA - UNIT 2 TS /B LOES-5 Revision 68
SUSQUEHANNA STEAM ELECTRIC STATION LIST CF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
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TSB2 LOE:S 3/1106 SUQIEHNN
-UNT T/BOE-6Reiso_6 SUSQUEHANNA - UNIT 2 TS / B LOES-6 Revisionl 68
PPL Rev. 5 Secondary Containment B 3.6.4.1 B 3.6 CONTAINMENT SYSTEMS B 3.6.4.1 Secondary Containment BASES BACKGROUND The secondary containment structure completely encloses the primary containment structure such that a dual-containment design is utilized to limit the spread of radioactivity to the environment to within limits. The function of the secondary containment is to contain, dilute, and hold up fission products that may leak from primary containment into secondary containment following a Design Basis Accident (DBA). In conjunction vwith operation of the Standby Gas Treatment (SGT) System and closure, of certain valves whose lines penetrate the secondary containment, the secondary containment is designed to reduce the activity level of the fission products prior to release to the environment and to isolate and contain fission products that are released during certain operations that take place inside primary containment, when primary containment is not required to be OPERABLE, or that take place outside primary containment (Ref. 1).
The secondary containment is a structure that completely encloses the primary containment and reactor coolant pressure boundary components.
This structure forms a control volume that serves to hold up and dilute the fission products. It is possible for the pressure in the control volume to rise relative to the environmental pressure (e.g., due to pump and motor heat load additions).
The secondary containment boundary consists of the reactor building structure and associated removable walls and panels, hatches, doors, dampers, sealed penetrations and valves. The secondary containment is divided into Zone I, Zone II and Zone IlIl, each of which must be OPERABLE depending on plant status and the alignment of the secondary containment boundary. Specifically, the Unit 1 secondary containment boundary can be modified to exclude Zone II. Similarly, the Unit 2 secondary containment boundary can be modified to exclude Zone I. Secondary containment may consist of only Zone IlIl when in MOIDE 4 or 5 during CORE ALTERATIONS, or during handling of irradiated fuel within the Zone IlIl secondary containment boundary.
(continued)
I SUS'QUEHANNA - UNIT 2 TS / B 3.6-83 Revision 3
PPL. Rev. 5 Secondary Containment B 3.6.4.1 BASES BACKGROUND (continued)
To prevent ground level exfiltration while allowing the secondary containment to be designed as a conventional structure, the secondary containment requires support systems to maintain the control volume pressure at less than the external pressure. Requirements for the safety related systems are specified separately in LCO 3.6.4.2, "Secondary Containment Isolation Valves (SCIVs)," and LCO 3.6.4.3, "Standby Gas Treatment (SGT) System." When one or more zones are excluded from secondary containment, the specific requirements for support systems will also change (e.g., required secondary containment isolation valves).
APPLICABLE SAFETY ANALYSES There are two principal accidents for which credit is taken for secondary containment OPERABILITY. These are a loss of coolant accident (LOCA)
(Ref. 2) and a fuel handling accident inside secondary containment (Ref. 3). The secondary containment performs no active function in response to either of these limiting events; however, its leak tightness is required to ensure that the release of radioactive materials from the primary containment is restricted to those leakage paths and associated leakage rates assumed in the accident analysis and that fission products entrapped within the secondary containment structure will be treated by the SGT System prior to discharge to the environment.
Secondary containment satisfies Criterion 3 of the NRC Policy Statement (Ref. 4).
LCO An OPERABLE secondary containment provides a control volume into which fission products that bypass or leak from primary containment, or are released from the reactor coolant pressure boundary components located in secondary containment, can be diluted and processed prior to release to the environment. For the secondary containment to be considered OPERABLE, it must have adequate leak tightness to ensure that the required vacuum can be established and maintained. The leak tightness of secondary containment must also ensure that the release of radioactive materials to the environment is restricted to those leakage paths and associated leakage rates assumed in the accident analysis. For example, secondary containment bypass leakage must be restricted to the leakage rate required by LCO 3.6.1.3. The secondary containment boundary required to be OPERABLE is dependent on the operating status of both units, as well as the configuration of walls, doors, hatches, SCIVs, and available flow paths to the SGT System.
(continued)
SU'SQUEHANNA - UNIT 2 T S / B 3.6-84.
Revision 2
PPL Rev. 5 Secondary Containment B 3.6.4.1 BAS;ES (continued)
APF'LICABILITY In MODES 1, 2, and 3, a LOCA could lead to a fission product release to primary containment that leaks to secondary containment. Therefore, secondary containment OPERABILITY is required during the same operating conditions that require primary containment OPERABILITY.
In MODES 4 and 5, the probability and consequences of the LOCA are reduced due to the pressure and temperature limitations in these MODES.
Therefore, maintaining secondary containment OPERABLE is not required in MODE 4 or 5 to ensure a control volume, except for other situations for which significant releases of radioactive material 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.
ACTIONS A.1 If secondary containment is inoperable, it must be restored to OPERABLE status within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time provides a period of time to correct the problem that is commensurate with the importance of maintaining secondary containment during MODES 1, 2, and 3. This time
- period.also ensures that the probability of an accident (requiring secondary-containment OPERABILITY) occurring during periods where secondary containment is inoperable is minimal.
A temporary (one-time) Completion Time is connected to the Complation Time Requirements above (4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />) with an "OR" connector. The Temporary Completion Time is 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> and applies to the replacement of the Reactor Building Recirculating Fan Damper Motors. The Temporary Completion Time of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> may only be used once, and expires on December 31, 2005.
(continued)
SUSQUEHANNA - UNIT 2 TS / 8 3.6-85 Revision 3
PPL. Rev. 5 Secondary Containment B 3.6.4.1 BASES ACTIONS B.1 and B.2 (continued)
If secondary containment cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and to MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
C.1. C.2, and C.3 Movement of irradiated fuel assemblies in the secondary containment, CORE ALTERATIONS, and OPDRVs can be postulated to cause fission product release to the secondary containment. In such cases, the secondary containment is the only barrier to release of fission products to the environment. CORE ALTERATIONS and movement of irradiated fuel assemblies must be immediately suspended if the secondary containment is inoperable.
Suspension of these activities shall not preclude completing an action that involves moving a component to a safe position. Also, action must be immediately initiated to suspend OPDRVs to minimize the probabili y of a vessel draindown and subsequent potential for fission product release.
Actions must continue until OPDRVs are suspended.
Required Action C.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 irradiated fuel assemblies 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 3.6.4.1.1 REQUIREMENTS This SR ensures that the secondary containment boundary is sufficiently leak tight to preclude exfiltration.
(continued)
- SUSQUEHANNA - UNIT 2 TS / B 3.6-86 Revision 1
PPL Rev. 5 Secondary Containment B 3.6.4.1 BAS;ES SURVEILLANCE SR 3.6.4.1.1 (continued)
REQUIREMENTS The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Frequency of this SR was developed based on operating experience related to secondary containment vacuum variations during the applicable MODES and the low probability of a DBA occurring between surveillances.
Furthermore, the 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal secondary containment vacuum condition.
SR 3.6.4.1.2 and SR 3.6.4.1.3 Verifying that secondary containment equipment hatches, removabIl walls and one access door in each access opening required to be closed are closed ensures that the infiltration of outside air of such a magnitude as to prevent maintaining the desired negative pressure does not occur.
Verifying that all such openings are closed also provides adequate assurance that exfiltration from the secondary containment will not occur.
- In this.application, the term "sealed" has no connotation of leak tightness.
An access opening typically contains one inner and one outer door.
Maintairning secondary containment OPERABILITY requires verifying one door in each access opening to secondary containment zones is clcsed.
In some cases (e.g., railroad bay), secondary containment access openings are shared such that a secondary containment barrier may have multiple inner or multiple outer doors. The intent is to maintain the secondary containment barrier intact, which is achieved by maintaining the inner or outer portion of the barrier closed at all times. However, all secondary containment access doors are normally kept closed, except when the access opening is being used for entry and exit or when maintenance is being performed on an access opening.
When the railroad bay door (No. 101) is closed; all Zone I and III hatches, removable walls, dampers, and one door in each access opening connected to the railroad access bay are closed; *or, only Zone I removable walls and/or doors are open to the railroad access shaft; or, only Zone III hatches and/or dampers are open to the railroad access shaft. When the railroad bay door (No. 101) is open; all Zone I and IlIl hatches, removable walls, dampers, and one door in each access opening connected to the railroad access bay are closed. The truck bay hatch is closed and the truck bay door (No. 102) is closed unless Zone II is isolated from Zones I and l1l.
(continued)
SUS'QUEHANNA - UNIT 2 TS / B 3.6-87.
Revision 2
PPL Rev. 5 Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.2 and SR 3.6.4.1.3 (continued)
REQUIREMENTS When an access opening between secondary containment zones is being used for exit and entry, then at least one door (where two doors are provided) must remain closed. The access openings between secondary containment zones which are not provided with two doors are administratively controlled to maintain secondary containment integrity during exit and entry. This Surveillance is modified by a Note that allows access openings with a single door (i.e., no airlock) within the secondary containment boundary (i.e., between required secondary containment zones) to be opened for entry and exit. Opening of an access door for entry and exit allows sufficient administrative control by individual personnel making the entries and exits to assure the secondary containment function is not degraded. When one of the zones is not a zone required for secondary containment OPERABILITY, the Note allowance would not apply.
The 31 day Frequency for these SRs has been shown to be adequate, based on operating experience, and is considered adequate in view of the other indications of door and hatch status that are available to the operator.
(continued)
SU',QUEHANNA - UNIT 2 TS / B 3.6-87a Re-vision 2
PPL Rev. 5 Secondary Containment B 3.6.4.1 BASES SURVEILLANCE REOUIREMENTS SR 3.6.4.1.4 and SR 3.6.4.1.5 (continue d)
The SGT System exhausts the secondary containment atmosphere to the environment through appropriate treatment equipment. To ensure that all fission products are treated, SR 3.6.4.1.4 verifies that the SGT System will rapidly establish and maintain a pressure in the secondary containment that is less than the pressure external to the secondary containmen.:
boundary. This is confirmed by demonstrating that one SGT subsystem will draw down the secondary containment to 2 0.25 inches of vacuum water gauge in less than or equal to the maximum time allowed. This cannot be accomplished if the secondary containment boundary is not intact. SR 3.6.4.1.5 demonstrates that one SGT subsystem can maintain
> 0.25 inches of vacuum water gauge for at least 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> at less than or equal to the maximum flow rate permitted for the secondary containment configuration that is operable. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> test period allows secondary containment to be in thermal equilibrium at steady state conditions. As noted, both SR 3.6.4.1.4 and SR 3.6.4.1.5 acceptance limits are dependent upon the secondary containment configuration when testing is being performed. The acceptance criteria for the SRs based on secondary containment configuration is defined as follows:
SECONDARY MAXIMUM DRAWDOWN TIME(SEC)
MAXIMUM FLOW RATE (<FM)
CONTAINMENT (SR 3.6.4.1.4 (SR 3.6.4.1.5 TEST CONFIGURATION ACCEPTANCE CRITERIA)
ACCEPTANCE CRITERIA)
Zcnes I, II and III.
- 125 Seconds
< 4000 CFM (Zones I, II, and I11)
(From Zones I, II, and III)
Zcnes II and III.
- 118 Seconds
- 2960 CFM (Zones II and 1II)
(From Zones II and III)
Only one of the above listed configurations needs to be tested to confirm secondary containment OPERABILITY.
(continued)
I I
I
- SUS'QUEHANNA - UNIT 2 TS I B 3.6-88 Re-vision 3
PPL Rev. 5 Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.4 and SR 3.6.4.1.5 (continued)
REQUIREMENTS A Note also modifies the Frequency for each SR. This Note identifies that each configuration is to be tested every 60 months. Testing each configuration every 60 months assures that the most limiting configuration is tested every 60 months. The 60 month Frequency is acceptable because operating experience has shown that these components usually pass the Surveillance and all active components are tested more frequently. Therefore, these tests are used to ensure secondary containment boundary integrity.
Since these SRs are secondary containment tests, they need not be, performed with each SGT subsystem. The SGT subsystems are tested on a STAGGERED TEST BASIS, however, to ensure that in addition to the requirements of LCO 3.6.4.3, either SGT subsystem will perform SR 3.6.4.1.4 and SR 3.6.4.1.5. 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.
REzERENCES
- 1. FSAR,.Section 6.2.3.
- 2. FSAR, Section -15.6.
- 3. FSAR, Section 15.7.4.
- 4. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).
SUSQUEHANNA - UNIT 2 TS / B 3.6-89 Revision 2
PPL Rev. 2 Distribution Systems-Operating 13 3.8.7 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.7 Distribution Systems-Operating BASES E
BACKGROUND The onsite Class I E AC and DC electrical power distribution system is divided into redundant and independent AC and DC electrical power distribution subsystems and a DG E electrical power distribution subsystem.
The primary AC distribution system consists of four 4.16 kV Engineered Safeguards System (ESS) buses each having a primary and alternate offsite source of power as well as an onsite diesel generator (DG) source that supports one 4.16 kV ESS bus in each unit. Each 4.16 kV ESS bus is normally supplied by either Startup Transformer (ST) No. 10 or ST No. 20. ST No. 10 and ST No. 20 each provide the normal source of power to two of the four 4.16 kV ESS buses in each Unit and the alternate source of power to the remaining two 4.16 kV ESS buses in each Unit. If any 4.16 kV ESS bus loses power, an automatic transfer from the normal to the alternate occurs after the normal supply breaker trips. If both offsite sources are unavailable, the onsite emergency DGs supply power to the 4.16 kV ESS buses.
There are two 250 VDC. electrical power distribution subsystems; four 125 VDC electrical power distribution subsystems; and, and one 125 VDC DG E electrical power distribution subsystem, all of which support the necessary power for ESF functions.
In addition, some components required by Unit 2 receive power through Unit I electrical power distribution subsystems, the Unit 1 AC and DC electrical power distribution subsystems needed to support the required equipment are addressed in Unit 2 LCO 3.8.7.
Required distribution subsystems are listed in LCO 3.8.7, Table 3.8.7-1.
APPLICABLE The initial conditions of Design Basis Accident (DBA) and SAFETY ANALYSES transient analyses in the FSAR, Chapter 6 (Ref. 1) and Chapter 15 (Ref. 2), assume ESF systems are OPERABLE. The AC and DC electrical power distribution systems are designed (continued)
SUSQUEHANNA - UNIT 2 B 3.8-84 Revision 0
PPL Rev. 2 Distribution Systems-Operating B 3.8.7 BASES APPLICABLE to provide sufficient capacity, capability, redundancy, and reliab lity to SAFETY ANALYSES ensure the availability of necessary power to ESF systems so that the (continued) 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 Coclant System (RCS); and Section 3.6 Containment Systems.
The OPERABILITY of the AC and DC electrical power distribution 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 distribution systems OPERABLE during accident conditions in the event of:
- a.
An assumed loss of all offsite power or all onsite AC electrical power; and
- b.
A worst case single failure.
The AC and DC electrical power distribution system satisfies Criterion 3 of the NRC Policy Statement (Ref. 4).
LCO The required electrical power distribution subsystems listed in Table 3.8.7-1 ensure the availability of AC and DC electrical power for the systems required to. shut down the reactor and maintain it in a safe condition after an anticipated operational occurrence (AOO) or a postulated DBA. The AC and DC electrical power distribution subsystems are required to be OPERABLE.
Maintaining the AC and DC electrical power distribution subsystems OPERABLE ensures that the redundancy incorporated into the design of ESF is not defeated. Therefore, a single failure within any system or within the electrical power distribution subsystems will not prevent safe shutdown of the reactor.
AC electrical power distribution subsystems require the associated buses and electrical circuits to be energized to their proper voltages. DC electrical power distribution subsystems require the associated buses to be energized to their proper voltage from either the associated battery or charger. The AC and DC electrical power distribution (continued)
SU,'QUEHANNA - UNIT 2 B 3.8-85 Revision 0
PPL Rev. 2 Distribution Systems-Operating 13 3.8.7 BASES LCO subsystem is only considered Inoperable when the subsystem is not (continued) energized to its proper voltage.
APF'LICABILITY The electrical power distribution subsystems are required to be OPERABLE in MODES 1, 2, and 3 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
- b.
Adequate core cooling is provided, and containment OPERABILITY and other vital functions are maintained in the event of a postulated DBA.
Electrical power distribution subsystem requirements for MODE'S 4 and 5 are covered in the Bases for LCO 3.8.8, "Distribution Systems -
Shutdown."
ACTIONS A.
With one or more required Unit 2 AC buses, load centers, motor control centers, or distribution panels inoperable but not resulting in a loss of safety function, or two Unit 1 AC electrical power distribution subsystems on one Division inoperable for performance of Unit 1 SR 3.8.1.19, the remaining AC 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. The overall reliability is reduced, however, because a single failure in the remaining power distribution subsystems could result in the minimum required ESF functions not being supported. Therefore, the required AC buses, load centers, motor control centers, and distribution panels must be restored to OPERABLE status within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.
The Condition A worst scenario is one division without AC power (i.e., no offsite power to the division and the associated DG inoperable). In this Condition, the unit is more vulnerable to a complete loss of AC power. It is, therefore, imperative that the unit operators' attention be focused on minimizing the potential for loss of power to the remaining division by stabilizing the unit, and on restoring power to the affected division. The 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> time limit before (continued)
SUSDQUEHANNA-UNIT 2 TS / B 3.8-86 Revision I
PPL Rev. 2 Distribution Systems-Operating B 3.8.7 BASES ACTIONS A.1 (continued) requiring a unit shutdown in this Condition is acceptable because:
- a.
There is a potential for decreased safety if the attention of unit operators is diverted from the evaluations and actions necessary to restore power to the affected division to the actions associated with taking the unit to shutdown within this time limit.
- b.
The potential for an event in conjunction with a single failure of a redundant component in the division with AC power. (The redundant component is verified OPERABLE in accordance with Specification 5.5.11, "Safety Function Determination Program (SFDP).")
The second Completion Time for Required Action A.1 establishes a limit on the maximum time allowed for any combination of required distribution subsystems to be inoperable during any single continuous occurrence of failing to meet LCO 3.8.7. If Condition A is entered while, for instance, a DC bus is inoperable and subsequently returned OPERABLE, this LCO may already have been not met for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. This situation could lead to a total duration of 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />, since initial failure of the LCO, to restore the AC distribution system. At this time, a DC circuit could again become inoperable, and AC distribution could be restored OPERABLE. This could continue indefinitely.
This Completion Time allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." This results in establishing the "time zero" at the time this LCO was initially not met, instead of at the time Condition A was entered. The 16 hour1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> Completion Time is an acceptable limitation on this potential to fail to meet the LCO indefinitely. The completion time exception is not applicable to Condition E or F because Condition E and F are only applicable to DG E DC electrical power subsystem.
Condition A is modified by a Note that states that Condition A is not applicable to the DG E DC electrical power subsystem. Conditi:n E or F is applicable to an inoperable DG E DC electrical power subsystem.
Required Action A.1 is modified by a Note that requires the applicable Conditions and Required Actions of LCO 3.8.4 uDC Sources -
Operating," to be entered for DC subsystems made inoperable by inoperable AC electrical power distribution subsystems. This is an exception to LCO 3.0.6 and ensures the proper actions are taken for inoperable DC sources. Inoperability of a distribution subsystem can result in loss of charging power to batteries and eventual loss of DC power. This Note ensures that the appropriate attention is given to restoring charging power to batteries, if necessary, after loss of distribution systems.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-87 Revision 1
PPL Rev. 2 Distribution Systems-Operating B 3.8.7 BASES AC-TIONS B.1 (continued)
With one or more Unit 2 DC buses inoperable, the remaining DC; electrical power distribution subsystems may be 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.
The overall reliability is reduced, however, because a single failure in one of the remaining DC electrical power distribution subsystems could result in the minimum required ESF functions not being supported.
Therefore, the required DC buses must be restored to OPERABLE status within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> by powering the bus from the associated battery or charger.
Condition B represents one subsystem or multiple DC Buses without adequate DC power, potentially with both the battery significantly degraded and the associated charger non-functioning. In this situation, the plant is significantly more vulnerable to a loss of minimally required DC power. It is, therefore, imperative that the operator's attention focus on stabilizing the plant, minimizing the potential for loss of power to the remaining divisions, and restoring power to the affected division.
This 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limit is more conservative than Completion Times allowed for the majority of components that would be without power. Taking exception to LCO 3.0.2 for components without adequate DC power, which would have Required Action Completion Times shorter than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, is acceptable because of:
- a.
The potential for decreased safety when requiring a change in plant conditions (i.e., requiring a shutdown) while not allowing stable operations to continue;
- b.
The potential for decreased safety when requiring entry into numerous applicable Conditions and Required Actions for components without DC power, while not providing sufficient time for the operators to perform the necessary evaluations and actions for restoring power to the affected division;
- c.
The potential for an event in conjunction with a single failure of a redundant component.
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-88 Revision 1
PPL Rev. 2 Distribution Systems-Operating B 3.8.7 BASES ACTIONS B.1 (continued)
The 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Completion Time for DC buses is consistent with Regulatory Guide 1.93 (Ref. 3).
The second Completion Time for Required Action B.1 establishes a limit on the maximum time allowed for any combination of required distribution subsystems to be inoperable during any single continuous occurrence of failing to meet the LCO. If Condition C is entered while, for instance, an AC bus is inoperable and subsequently restored OPERABLE, the LCO may already have been not met for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. This situation could lead to a total duration of 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />, since initial failure of the LCO, to restore the DC distribution system. At this time, an AC division could again become inoperable, and DC distribution could be restored OPERABLE. This could continue indefinitely.
Condition B is modified by a Note that states that Condition B is not applicable to the DG E DC electrical power subsystem. Condition E or F is applicable to an inoperable DG E DC electrical power subsystem.
This Completion Time allows for an exception to the normal "tirme zero" for beginning the allowed outage time "clock." This allowance results in establishing the "time zero" at the time the LCO was initially not met, instead of at the time Condition C was entered. The 16 hour1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> Completion Time is an acceptable limitation on this potential of failing to meet the LCO indefinitely. The Completion Time exception is not applicable to Condition E and F because Condition E and F are only applicable to DG E DC electrical power subsystem.
C.1 With one Unit 1 AC electrical power subsystem that support Unit 2 inoperable, the remaining Unit 1 AC 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, the overall reliability is reduced because a single failure in the remaining AC electrical power distribution subsystem could result in the minimum required ESF functions not being supported. The Completion (continued)
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PPL Rev. 2 Distribution Systems-Operating B 3.8.7 BASES ACTIONS C.1 (continued)
Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is consistent with the Completion Times associated with LCOs for the Unit 2 and common equipment potentially affected by loss of a Unit 1 AC electrical power subsystem.
D.1 and D.2 If the inoperable distribution subsystem cannot be restored to OPERABLE status within the associated Completion Time, the unit 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 If Diesel Generator E is not aligned to the Class 1 E distribution system, the only supported safety function is for the ESW system. Therefore, under this condition, if Diesel Generator E DC power distribution subsystem is not OPERABLE, to ensure the OPERABILITY of the ESW'system, actions are taken to either restore the power distribution subsystem to OPERABLE status or shutdown Diesel Generator E and close the associated ESW valves. 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 power distribution subsystems and provides sufficient time to evaluate the condition and take the corrective actions.
F. 1 If the Diesel Generator E is aligned to the class I E distribution system, the loss of Diesel Generator E DC power distribution subsystem will result in the loss of a on-site Class 1E power source. Therefore, under.
this condition, if Diesel Generator E DC power distribution subsystem is not OPERABLE actions are taken to either restore the power distribution subsystem to OPERABLE status or declare Diesel Generator E inoperable and take Actions of LCO 3.8.1. The (continued)
SU!3QUEHANNA - UNIT 2 R 3.8-90 Revision 0
PPL Rev. 2 Distribution Systems-Operating B 3.8.7 BASES ACTIONS F.1 (continued) 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 and take the necessary corrective actions.
G.1 Condition G corresponds to a level of degradation in the electrical distribution system that causes a required safety function to be lost.
When more than one AC or DC electrical power distribution subsystem is lost, and this results in the loss of a required function, the plant is in a condition outside the accident analysis. Therefore, no additional time is justified for continued operation. LCO 3.0.3 must be entered immediately to commence a controlled shutdown. Entry into Condition F is not required if the loss of safety function is the result of entry into Condition A in combination with the loss of safety functions governed by LCOs other than LCO 3.8.7. In this case, enter LCO 3.8.7, Condition A, and the Condition for loss of function in the LCO that governs the safety function that is lost.
H.1 With one or more Unit 1 DC electrical 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, The overall reliability is reduced because a single failure in the remaining DC electrical power distribution subsystem 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 H.I causes Unit 1 loads to be powered from a Unit 2 DC electrical power subsystem.
Although the corresponding Unit 2 DC electrical power subsystem is evaluated for this condition, this condition is outside the design commitment to maintain DC power separation between units. To minimize the time this (continued)
SU BQUEHANNA - UNIT 2 a 3.-8-91 Re-vision 0
PPL. Rev. 2 Distribution Systems-Operating B 3.8.7 BASES ACTIONS H.1 (continued) condition exists, Required Action H.2 direct power to be restored from 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.
1.1 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 1 DC source becomes OPERABLE, the associated loads may be incapable of performing their intended function and must be declared inoperable immediately.
SURVEILLANCE SR 3.8.7.1 REQUIREMENTS This Surveillance verifies that the AC and DC, electrical power distribution systems are functioning properly, with the correct circuit breaker alignment. The correct breaker alignment ensures the appropriate independence of the electrical buses are maintained, and the appropriate voltage or indicated power is available to each required bus. This includes a verification that Unit 1 and common 125 VDC loads are aligned to a Unit 1 DC power distribution subsystem. The verification of voltage availability on the buses ensures that the required voltage is readily available for motive as well as control functions for critical system loads connected to these buses. The 7 day Frequency takes into account the redundant capability of the AC and DC electrical power distribution subsystems, and other indications available in the control room that alert the operator to subsystem malfunctions.
(continued)
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PPL Rev. 2 Distribution Systems-Operating B 3.8.7 BASES (continued)
REFERENCES
- 1.
FSAR, Chapter 6.
- 2.
FSAR, Chapter 15.
- 3.
Regulatory Guide 1.93, December 1974.
- 4.
Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).
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