ML061010642
| ML061010642 | |
| Person / Time | |
|---|---|
| Site: | Susquehanna  |
| Issue date: | 04/03/2006 |
| From: | Susquehanna |
| To: | Gerlach R Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| Download: ML061010642 (34) | |
Text
Apr. 03, 2006 Page 1
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MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2006-16356 USER INFORMATION:
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ATTENTION:
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TSB2 -
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 03/16/2006 ADD MANUAL TABLE OF CONTENTS DATE: 03/31/2006 CATEGORY: DOCUMENTS TYPE: TSB2 i)t00(
Apr. 03, 2006 Page 2
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TEXT 3.3.8.1 REMOVE:
REV:1 ADD:
REV: 2 CATEGORY:
ID:
TEXT REMOVE:
DOCUMENTS TYPE: TSB2 3.8.7 REV:2 ADD:
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SSES MANUAL
- Manual Name:
TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL Table Of Contents Issue Date:
03/31/2006 Procedure Nime Rev TEXT LOES 69
Title:
LIST OF EFFECTIVE SECTIONS Issue Date 03/31/2006 Change ID Change Number TEXT TOC
Title:
TABLE OF CONTENTS 7
04/18/2005 TEXT 2.1.1 1
Title:
SAFETY LIMITS (SLS) REACTOR 10/27/2004 CORE SLS TEXT 2.1.2 0
Title:
SAFETY LIMITS (SLS) REACTOR 11/18/2002 COOLANT SYSTEM (RCS) PRESSURE SL TEXT 3.0 1
04/18/2005
Title:
LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY TEXT 3.1.1
Title:
REACTIVITY TEXT 3.1.2
Title:
REACTIVITY 1
a, 03/24/2005 CONTROL SYSTEMS SHUTDOWN MARGIN (SDM) 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:
REACTIVITY i
1 CONTROL SYSTEMS 2
CONTROL SYSTEMS 1
CONTROL SYSTEMS 07/06/2005 CONTROL ROD 07/06/2005 CONTROL ROD 07/06/2005 CONTROL ROD OPERABILITY SCRAM TIMES SCRAM ACCUMULATORS TEXT 3.1.6
Title:
REACTIVITY 2
CONTROL SYSTEMS 03/24/2005 ROD PATTER1N CONTROL Pagel of 8
Report Date: 03/31/06 Page 1 of 8 Report Date: 03/31/06
SSES MANUAL Manual Name:
TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL
'J TEXT 3.1.7
Title:
REACTIVITY CONTROL TEXT 3.1.8
Title:
REACTIVITY CONTROL TEXT 3.2.1
Title:
POWER DISTRIBUTION TEXT 3.2.2
Title:
POWER DISTRIBUTION 1
08/30/2005 SYSTEMS STANDBY LIQUID CONTROL (SLC) SYSTEM 1
10/19/2005 SYSTEMS SCRAM DISCHARGE VOLUME (SDV) VENT AND DRAIN VALVES 2
10/05/2005 LIMITS AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) 1 03/24/2005 LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)
TEXT 3.2.3 0
11/18/2002
Title:
POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE-LHGR "EXT 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
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
- I Page2 of 8 Report Date: 03/31/06 Page 2 of 8 Report Date: 03/31/06
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 (A'.'WS-RPT) INSTRUMENTATION TEXT 3.3.5.1
Title:
INSTRUMENTATION TEXT 3.3.5.2
Title:
INSTRUMENTATION TEXT 3.3.6.1 gap
Title:
INSTRUMENTATION TEXT 3.3.6.2
Title:
INSTRUMENTATION TEXT 3.3.7.1
Title:
INSTRUMENTATION INSTRUMENTATION 3
07/06/2005 EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION 0
11/18/2002 REACTOR CORE.ISOLATION COOLING (RCIC) SYSTEM INSTRUMENTATION 1
11/09/2004 PRIMARY CONTAINMENT ISOLATION INSTRUMENTATION 1
11/09/2004 SECONDARY CONTAINMENT ISOLATION INSTRUMENTATION 0
11/18/2002 CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS)
SYSTEM 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.
Page3 of 8 Report Date: 03/31/06 Page 3 of 8 Report Date: 03/31/06
SSES MANUAL Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL
!/
TEXT 3.4.3
Title:
REACTOR TEXT 3.4.4
Title:
REACTOR 1
01/16/2006 COOLANT SYSTEM (RCS) SAFETY/RELIEF VALVES (S/RVS) 0 11/18/2002 COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE TEXT 3.4.5 1
Title:
TEXT 3.4.6 1
Title:
TEXT 3.4.7 1
Title:
"EXT 3.4.8 1
Title:
HOT SHUTDOWN TEXT 3.4.9 0
Title:
COLD SHUTDOWN 01/16/2006 RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE 04/18/2005 RCS LEAKAGE DETECTION INSTRUMENTATION 04/18/2005 RCS SPECIFIC ACTIVITY 04/18/2005 RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM._J 11/18/2002 RESIDUAL HEAT REMOVAL (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 K>1 oe:
Page 4 of 8 Report Date: 03/31/06
SSES MANUAL
- Manual Name
- TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL k2jv TEXT 3.6.1.1 0
11/18/2002
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT TEXT 3.6.1.2 0
Title:
CONTAINMENT SYSTEMS PRIMARY 11/18/2002'-
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
Title:
CONTAINMENT TEXT 3.6.1.5
Title:
CONTAINMENT TEXT 3.6.1.6
< 2p
Title:
CONTAINMENT TEXT 3.6.2.1
Title:
CONTAINMENT TEXT 3.6.2.2
Title:
CONTAINMENT TEXT 3.6.2.3
Title:
CONTAINMENT TEXT 3.6.2.4
Title:
CONTAINMENT TEXT 3.6.3.1 0
11/18/2002 SYSTEMS CONTAINMENT-PRESSURE 1
10/05/2005 SYSTEMS DRYWELL AIR TEMPERATURE 0
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.
Title:
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS TEXT 3.6.3.2
Title:
CONTAINMENT -SYSTEMS 1
04/18/2005 DRYWELL AIR FLOW SYSTEM Page 5 of 8
R A.6-I Report Date: 03/31/06
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
Title:
PLANT SYSTEMS ULTIMATE HEAT 0
11/18/2002 '
RESIDUAL HEAT REMOVAL SERVICE WATER:(RHRSW) SYSTEM AND THE SINK (UHS)
TEXT 3.7.2
Title:
PLANT TEXT 3.7.3
Title:
PLANT TEXT 3.7.4
Title:
PLANT TEXT 3.7.5
Title:
PLANT TEXT 3.7.6
Title:
PLANT TEXT 3.7.7
Title:
PLANT TEXT 3.8.1 1
11/09/2004 SYSTEMS EMERGENCY SERVICE WATER '(ESW)
SYSTEM 0
11/18/2002 SYSTEMS CONTROL"ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS)
SYSTEM 0
11/18/2002 SYSTEMS CONTROL ROOM FLOOR'COOLING SYSTEM 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 Page 6 of 8 Report Date: 03/31/06
SSES MANUAL b Manual Name:
TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.8.2
Title:
ELECTRICAL POWER TEXT 3.8.3
Title:
ELECTRICAL POWER 0
11/18/2002 SYSTEMS AC SOURCES -
SHUTDOWN 0
SYSTEMS 11/18/2002.
DIESEL FUEL OIL, LUBE.OIL, AND STARTING'AIR TEXT 3.8.4
Title:
ELECTRICAL TEXT 3.8.5
Title:
ELECTRICAL TEXT 3.8.6
Title:
ELECTRICAL TEXT 3.8.7
Title:
ELECTRICAL TEXT 3.8.8
Title:
ELECTRICAL TEXT 3.9.1
Title:
REFUELING C TEXT 3.9.2
Title:
REFUELING C TEXT 3.9.3
Title:
REFUELING C TEXT 3.9.4
Title:
REFUELING C TEXT 3.9.5
Title:
REFUELING C POWER SYS]
POWER SYSI POWER SYSI POWER SYSI POWER SYSI
)PERATIONS
)PERATIONS
)PERATIONS
)PERATIONS
)PERATIONS 0
11/18/2002 7EMS DC SOURCES -
OPERATING 0
11/18/2002
'EMS DC SOURCES -
SHUTDOWN 0
11/18/2002
'EMS BATTERY CELL PARAMETERS 3
03/31/2006
'EMS DISTRIBUTION SYSTEMS -
OPERATING 0
11/18/2002
'EMS DISTRIBUTION SYSTEMS -
SHUTDOWN*
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 Page7 of 8
Report Date: 03/31/06 Page 7 of 8 Report Date: 03/31/06
SSES MANUAL Manual Name: TSB2 Manual
Title:
TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL I
)
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 v"EXT 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)
RE1-1OVAL -
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 PageB of 8
Report Date: 03/31/06 Page 8 of 8 Report Date: 03/31/06
SUSQUJEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Section Title TOC Table of Contents B 2.0 SAFETY LIMITS BASES Page TS / B 2.0-1 Page TS / B 2.0-2 Page TS / B 2.0-3 Page TS/B2.0-4 PageTS/B2.0-5 Pages B 2.0-6 through B 2.0-8 Revision 7
1 2
3 4
0 B 3.0 B 3.1 B3.2 LCO AND SR APPLICABILITY BASES Pages B 3.0-1 through B 3.0-4 Pages TS / B 3.0-5 through TS / B 3.0-7 Pages TS / B 3.0-8 through TS / B 3.0-9 Pages TS / B 3.0-10 through TS / B 3.0-12 Pages TS / B 3.0-13 through TS / B 3.0-154, Pages TS / B 3.0-16 and TS / B 3.0-17 REACTIVITY CONTROL BASES Pages B 3.1-1 through B 3.1-4 PageTS/B3.1-5 Pages TS / B 3.1-6 and TS B 3.1-79 Pages B 3.1-8 through B 3.1-13!'X.-
PageTS/B3.1-14
/KN '
Pages B 3.1-15 through B 3.1-22\\
Page TS / B 3.1-23 Pages B 3.1-24,throughB 3.1-27 Page TS/B,3.1s28 Page TS I 3.1-29-.,
Pages B-3:1-30 through B 3.1-33 Pages TS' B 3.1.34 through TS I B 3.1-36 PagelqTS / B13.1-37 Page 'TS/B 3.1-38 (Pages B 3.1-39 through B 3.1-44 (Page'TS / B 3.1-45 Pages B 3.146 and B 3.1-47 Pages TS / B 3.1-48 and TS / B 3.1-49 Page B 3.1-50 Page TS / B 3.1-51
./
Ny
\\
/
\\
N
N 0
1 2
I 2
0 0
1 2
0 1
0 1
0 2
1 0
1 2
2 0
1 0
1 0.
1 POWER DISTRIBUTION LIMITS BASES Pages TS / B 3.2-1 and TS / B 3.2-2 Page TS / B 3.2-3 Page TS/B 3.2-4 Pages TS / B 3.2-5 and TS / B 3.2-6 Page TS / B 3.2-7 Pages TS / B 3.2-8 and TS / B 3.2-9 I
3 I
3 2
3 SUSQIJEHANNA - UNIT 2 TS / B LOES-1 Revision 69
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/B3.3-6 1
Page TS / B 3.3-7 2
Pages TS / B 3.3-8 through TS / B 3.3-11 2
Page TS /B3.3-12 2
Page TS /B3.3-13 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/B3.3-32 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 /B3.3-64 and TS /B3.3-65 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 / 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 / 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 /B3.3-78 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 /B3.3-115 2
SUSQUEHANNA - UNIT 2 TS /B LOES-2 Revision 69
SUSQIJEHANNA STEAM ELECTRIC STATIONl LIST OF 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 /B3.3-123 1
Page TS /B3.3-124 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 /B3.3-132 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 /B3.3-178 2
Page TS / B 3.3-179 3
Page TS / B 3.3-179a 2
PageTS /B3.3-180 1
Page TS / B 3.3-181 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 3.3-209 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-l 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 / 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 / 8 3.4-32 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
SUSQUJEHANNA - UNIT 2 TS / B LOES-3 Revision 69
SUSQUEHANNA STEAM ELECTRIC STATION LIST CF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
Sectiori 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 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 / 8 3.5-3 through TS / 8 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 /B3.5-18 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 3.6-1 a 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 / B 3.6-18 and TS / B 3.6-19 1
Page TS / B 3.6-20 2
Page TS / B 3.6-21 3
Pages TS /B 3.6-21a and TS / B 3.6-21b 0
Pages TS / B 3.6-22 and TS / B 3.6-23 2
Pages TS / B 3.6-24 and TS / B 3.6-25 1
Page TS / B 3.6-26 2
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- UNIT 2 TSIBLOES-5 Revision 69 SUSQUEHANNA - UNIT 2 TS /B LOES-5 Revision 69
SUSQUEHANNA STEAM ELECTRIC STATIO1N LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)
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TSB2 LOES, 3/17106 SUSQUEHANNA
- UNIT 2 TS/BLOES-6 Revision '39 SUSQUEHANNA - UNIT 2
.TS/IB LOES-6 Revision 1D9
PPI Rev. 2 LOP Instrumentation B 3.3.8.1 B -3.3 INSTRUMENTATION B 3.3.8.1 Loss of Power (LOP) Instrumentation BASES BACKGROUND Successful operation of the required safety functions of the Emergency Core Cooling Systems (ECCS) is dependent upon the availability of adequate power sources for energizing the various components suzh as pump motors, motor operated valves, and the associated control components. The LOP instrumentation monitors the 4.16 kV emergency buses. Offsite power is the preferred source of power for the 4.16 kV emergency buses. If the monitors determine that insufficient power is available, the buses are disconnected from the offsite power sources and connected to the onsite diesel generator (DG) power sources.
Each 4.16 kV emergency bus has its own independent LOP instrumentation and associated trip logic. The voltage for each bus is monitored at three levels, which can be considered as three different undervoltage Functions: Loss of Voltage (< 20%), 4.16 kV Emergency Bus Undervoltage Degraded Voltage LOCA (< 93%), and 4.16 kV Emergency Bus Undervoltage Low Setting (Degraded Voltage) (< 65%).
Each Function, with the exception of the Loss of Voltage relays is monitored by two undervoltage relays for each emergency bus, whose outputs are arranged in a two-out-of-two logic configuration. The Loss of Voltage Function is monitored by one undervoltage relay for each emergency bus, whose output is arranged in a one-out-of-one logic configuration. When voltage degrades below the setpoint, the channel output relay actuates, which then outputs a LOP trip signal to the trip logic.
APPLICABLE SAFETY
- ANALYSES, LCO, and APPLICABILITY The LOP instrumentation is required for Engineered Safety Features to function in any accident with a loss of offsite power. The Unit I LOP instrumentation is required to be operable for Unit 2 when the associated Unit 1 4.16 kV emergency buses are required to be operable per Unit 2 T.S. 3.8.7 and 3.8.8. The required channels of LOP instrumentation ensure that the ECCS and other assumed systems powered from the DGs, provide plant protection in the event of any of the Reference 1 and 2 analyzed accidents in which a loss of offsite power is assumed. The initiation of the DGs on loss of offsite power, and subsequent initiation of the ECCS, ensure that the fuel peak cladding temperature remains below the limits of 10 CFR 50.46.
(continued)
SUSQUEHANNA - UNIT 2 TS I B 3.3-206 Revision I
PPL Rev. 2 LOP Instrumentation B 3.3.8.1 BASES APPLICABLE Accident analyses credit the loading of the DG based on the loss of offsite SAFETY power during a loss of coolant accident. The diesel starting and loading
- ANALYSES, times have been included in the delay time associated with each safety LCC), and system component requiring DG supplied power following a loss of Dffsite APPLICABILITY power.
(continued)
The LOP instrumentation satisfies Criterion 3 of the NRC Policy Statement. (Ref. 3)
The OPERABILITY of the LOP instrumentation is dependent upon the OPERABILITY of the individual instrumentation channel Functions specified in Table 3.3.8.1-1. Each Function must have a required number of OPERABLE channels per 4.16 kV emergency bus, with their setpoints within the specified Allowable Values. A channel is inoperable if its actual trip setpoint is not within its required Allowable Value. The actual setpoint is calibrated consistent with applicable setpoint methodology assumptions.
The Allowable Values are specified for each Function in the Table. Trip setpoints are specified in the system calculations. The setpoints are selected to ensure that the setpoints do not exceed the Allowable Value.
Operation with a trip setpoint less conservative than the nominal trip setpoint, but within the Allowable Value, is acceptable. Trip setpoin':s are those predetermined values of output at which an action should take place. The setpoints are compared to the actual process parameter (e.g.,
degraded voltage), and when the measured output value of the process parameter reaches the setpoint, the associated device changes state.
The Allowable Values are derived from the limiting values of the prowess parameters obtained from the safety analysis. The trip setpoints are then.
derived based on engineering judgment.
The specific Applicable Safety Analyses, LCO, and Applicability discussions are listed below on a Function by Function basis.
(continued)
SUSQUEHANNA - UNIT 2 B 3.3-2907 Revision 0
PPL. Rev. 2 LOP Instrumentation B 3.3.8.1 BASES APPLICABLE SAFETY
- ANALYSES, LC), and APPLICABILITY (continued)
- 1. 4.16 kV Emergency Bus Undervoltage (Loss of Voltage< 20%)
Loss of voltage on a 4.16 kV emergency bus indicates that offsite power may be completely lost to the respective emergency bus and is unable to supply sufficient power for proper operation of the applicable equipment.
Therefore, the power supply to the bus is transferred from offsite power to DG power when the voltage on the bus drops below the Loss of Voltage Function Allowable Values (loss of voltage with a short time delay). This ensures that adequate power will be available to the required equipment.
The Bus Undervoltage Allowable Values are low enough to prevent inadvertent power supply transfer, but high enough to ensure that power is available to the required equipment. The Time Delay Allowable \\Values are long enough to provide time for the offsite power supply to recover to normal voltages, but short enough to ensure that power is available to the required equipment.
One channel of 4.16 kV Emergency Bus Undervoltage (Loss of Voltage)
Function per associated emergency bus is required to be OPERABLE when the associated DG is required to be OPERABLE to ensure that no single instrument failure can preclude the DG function. 4.16 kV Emergency Bus Undervoltage (Loss of Voltage) relay controls and provides a permissive to allow closure of the associated alternate source breaker and the associated DG breaker. (one channel input to each of the four DGs.) Refer to LCO 3.8.1, "AC Sources-Operating," and 3.8.2, "AC Sources-Shutdown," for Applicability Bases for the DGs.
2., 3. 4.16 kV Emergency Bus Undervoltage (Degraded Voltaae)
A reduced voltage condition on a 4 kV emergency bus indicates that, while offsite power may not be completely lost to the respective emergency bus, available power may be insufficient for starting large ECCS motors without risking damage to the motors that could disable the ECCS function. Therefore, power supply to the bus is transferred from offsite power to onsite DG power when there is no offsite power or a degraded power supply to the bus. This transfer will occur only if the voltage of the primary and alternate power sources drop below the Degraded Voltage Function (continued)
SUS'QUEHANNA - UNIT 2 B 3.3-208 Revision 0
PPL Rev. 2 LOP Instrumentation B 3.3.8.1 BASSES APPLICABLE 2., 3. 4.16 kV Emergency Bus Undervoltage (Degraded Voltage)
SAFETY (continued)
- ANALYSES, LCCO, and Allowable Values (degraded voltage with a time delay) and the source APPLICABILITY breakers trip which causes the DG to start. This ensures that adequate power will be available to the required equipment.
Two Functions are provided to monitor degraded voltage at two different levels. These Functions are the Degraded Voltage LOCA (< 93%) and Degraded Voltage Low Setting (< 65%). These relays respond to degraded voltage as follows: 93% for approximately 5 minutes (when no LOCA signal is present) and approximately 10 seconds (with a LOCA signal present), and 65% (Degraded Voltage Low Setting). The Degraded Voltage LOCA Function preserves the assumptions of the LOCA analysis and the Degraded Voltage Low Setting Function preserves the assumptions of the accident sequence analysis in the FSAR. The circuitry is designed such that with the LOCA signal present, the non-LOCA time delay is physically bypassed.
The Bus Undervoltage Allowable Values are low enough to prevent inadvertent power supply transfer, but high enough to ensure that sufficient power is available to the required equipment. The Time Delay Allowable Values are long enough to provide time for the offsite power supply to recover to normal voltages, but short enough to ensure that sufficient power is available to the required equipment.
Two channels of 4.16 kV Emergency Bus Undervoltage (Degraded Voltage) per Function (Functions 2 and 3) per associated bus are required to be OPERABLE when the associated DG is required to be OPERABLE.
This ensures no single instrument failure can preclude the start of DGs (each logic inputs to each of the four DGs). Refer to LCO 3.8.1 and LCO 3.8.2 for Applicability Bases for the DGs.
ACTIONS A Note has been provided to modify the ACTIONS related to LOP 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 (con tinued)
SUSQUEHANNA - UNIT 2 B 3.3-209 Revision 0
PPL Rev. 2 LOP Instrumentation e 3.3.8.1 BASES ACTIONS (continued) 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 LOP instrumentation channels provide appropriate compensatory measures for separate inoperable channels. As such, a Note has been provided that allows separate Condition entry for each inoperable LOP instrumentation channel.
A.1 Required Action A.1 directs entry into the appropriate Condition referenced in Table 3.3.8.1-1 when LOP instrumentation channels are inoperable for reasons other than for the performance of SR 3.8.1.19 on Unit 1. The applicable Condition specified in the Table is Function dependent. Each time a channel associated with a Unit 1 4.16 kV ESS Bus since the Unit 1 4.16 kV ESS Buses power station common loads such as SGTS, CREOASS, and ESW or a Unit 2 4.16 ESS Bus is discovered inoperable, Condition A is entered for that channel and provides for transfer to the appropriate subsequent Condition.
B.1 I
With one or more required channels on the Unit 1 4.16 kV ESS Buses in one Division for the performance of SR 3.8.1.19 in Unit 1 inoperable but not resulting in a loss of safety function, the remaining channels 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 channels could result in the minimurm required ESF functions not being supported. Therefore, the required Unit 1 4.16 kV ESS Bus channels 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 />.
(continued)
SUSQUEHANNA - UNIT 2 TS /B 3.3-21 0 Revision 1
PPL. Rev. 2 LOP Instrumentation B 3.3.8.1 BASES ACTIONS C. 1l (continued)
With one or more channels of a Function inoperable, the Function is not capable of performing the intended function. Therefore, only 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is allowed to restore the inoperable channel to OPERABLE status. If the inoperable channel cannot be restored to OPERABLE status within the allowable out of service time, the channel must be placed in the tripped condition per Required Action C.1. Placing the inoperable channel in trip would conservatively compensate for the inoperability, restore capability to accommodate a single failure (within the LOP instrumentation), and allow operation to continue. Alternately, if it is not desired to place the channel in trip (e.g., as in the case where placing the channel in trip would result in a DG initiation), Condition E must be entered and its Required Action taken.
The Completion Time is intended to allow the operator time to evaluate and repair any discovered inoperabilities. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time is acceptable because it minimizes risk while allowing time for restoration or tripping of channels.
D.1 With one channel of the Function inoperable, the Function is not capable of performing the intended function. Therefore, only 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is alloWed to restore the inoperable channel to OPERABLE status. If the inoperable channel cannot be restored to OPERABLE status within the allowable out of service time, Condition E must be entered and its Required Acticn taken.
The Completion Time is intended to allow the operator time to evaluate and repair any discovered inoperabilities. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time is acceptable because it minimizes risk while allowing time for restoration of channels.
E. 1 If the Required Action and associated Completion Times of Conditions B, C, or D are not met, the associated Function is not capable of performing the intended function. Therefore, the associated DG(s) is declared inoperable immediately. This requires entry into applicable Conditions and Required Actions of LCO 3.8.1 and LCO 3.8.2, which provide appropriate actions for the inoperable DG(s).
(continued)
SUSQUEHANNA - UNIT 2 TS / B 3.3-21 1 Revision 1
PPL. Rev. 2 LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE As noted at the beginning of the SRs, the SRs for each LOP REQUIREMENTS instrumentation Function are located in the SRs column of Table 3.3.8.1-1.
The Surveillances are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains DG initiation capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken.
SR 3.3.8.1.1 Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the 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 oil an investigation of a combination of the channel instrument uncertainties may be used to support this parameter comparison and include indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.
The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal checks of channels during normal operational use of the displays associated with channels required by the LCO.
SR 3.3.8.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.
(continued)
SUSQUEHANNA - UNIT 2 TS /B 3.3-212 Re-vision 1
PPL. Rev. 2 LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE SR 3.3.8.1.2 (continued)
REQUIREMENTS The Frequency of 31 days is based on 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 a rare event.
SR 3.3.8.1.3 A CHANNEL CALIBRATION verifies that the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
The Frequency is based upon the assumption of an 24 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.
SR 3.3.8.1.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required actuation logic for a specific channel. The system functional testing performed in LCO 3.8.1 and LCO 3.8.2 overlaps this Surveillance to provide complete testing of the assumed safety functions.
The 24 month Frequency is based on the need to perform portions of this Surveillance under the conditions that apply during a plant outage end the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency.
REFERENCES
- 1. FSAR, Section 6.3.
- 2. FSAR, Chapter 15.
- 3. Final Policy Statement on Technical Specifications Improvements, July 22,1993 (58 FR 32193)
SUSQUEHANNA - UNIT 2 TS / B 3.3-213 Revision 1
PPI Rev. 3 Distribution Systems-Operating B 3.8.7 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.7 Distribution Systems-Operating BASES E__
BACKGROUND The onsite Class 1 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 1 electrical power distribution subsystems, the Unil: I 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. 3 Distribution Systems-Operating B 3.8.7 BASES APPLICABLE to provide sufficient capacity, capability, redundancy, and reliability to SAFETY ANALYSES ensure the availability of necessary power to ESF systems so that the (continued) fuel, Reactor Coolant System, and containment design limits anr not exceeded. These limits are discussed in more detail in the Bases for Section 3.2, Power Distribution Limits; Section 3.4, Reactor Coolant System (RCS); and Section 3.6 Containment Systems.
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 3.83-85 Revision 0
PPL Rev. 3 Distribution Systems-Operating B 3.8.7 BASES LCO subsystem is only considered Inoperable when the subsystem is not (continued) energized to its proper voltage.
APPLICABILITY 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 MODES 4 and 5 are covered in the Bases for LCO 3.8.8, "Distribution Systems -
Shutdown."
AC7IONS A.1 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 I 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)
SUS'QUEHANNA-UNIT 2 TS / B 3.8-86 Revision 1
PPL Rev. 3 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 F or G because Condition F and G 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. Condition F or G 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)
SUEQUEHANNA - UNIT 2 TS / B3.8-87 Revision 2
PPL Rev. 3 Distribution Systems-Operating B 3.8.7 BASES ACTIONS B.1 (continued)
With one or more Unit 2 DC buses inoperable, the remaining DCl 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 operators 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. Ta king 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)
SU,'QUEHANNA - UNIT 2 TS / B 3.8-88 Revision 1
PPL Rev. 3 Distribution Systems-Operating B 3.8.7 BASES AC-lIONS 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 du ation 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 F or G is applicable to an inoperable DG E DC electrical power subsystem.
This Completion Time allows for an exception to the normal "time 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 I AC electrical power distribution 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)
SUSQUEHANNA - UNIT 2 TS / B 3.8-89 Revision 1
PPI Rev. 3 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 With two required Unit 1 AC buses, load centers, motor control centers, or distribution panels inoperable for the performance of Unit 1 SR 3.8.1.19 but not resulting in a loss of safety function, 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 />.
E.1and E.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.
F.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 (continued)
SUSQUEHANNA - UNIT 2 TS / B 3.8-90 Revision 1
PPL. Rev. 3 Distribution Systems-Operating B 3.8.7 BASES ACTIONS F.1 (continued) 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.
G.1 If the Diesel Generator E is aligned to the class 1 E distribution system, the loss of Diesel Generator E DC power distribution subsystem will result in the loss of a on-site Class 1 E 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 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.
H.1 Condition H 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 G is not required if the loss of safety function is the result of entiy 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.
(continued)
SUS'QUEHANNA - UNIT 2 TS / B 3.8-91 Revision 1
PPL. Rev. 3 Distribution Systems-Operating B 3.8.7 BASES ACTIONS 1.1 (continued)
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 1.1 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 condition exists, Required Action 1.2 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.
J.I1 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 3.8-92 Revision 1
PPL Rev. 3 Distribution Systems-Operating B 3.8.7 BASES (continued)
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 VIDC 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.
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).
SUS'QUEHANNA - UNIT 2 TS / B 3.8-93 Revision 1