ML15317A010

Technical Specifications Bases Manual

ML15317A010
Person / Time
Site:	Susquehanna
Issue date:	11/05/2015
From:	Gerlach R Susquehanna
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
Download: ML15317A010 (45)

Text

Nov. 05, 2015 Page 1 of 2 MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2015-44707 USER INFORMATION:

GERLACH*ROSEY N EMPL#:028401 CA#: 0363 Address: NUCSA2 Phone#: 254-3194 TRANgMT'1'AT, TNFGRMATTfN*

TO: GERLACH*ROSEY N 11/05/2015 LOCATION: USNRC FROM: NUCLEAR RECORDS DOCUMENT CONTROL CENTER (NUCSA-2)

THE FOLLOWING CHANGES HAVE OCCURRED TO THE HARDCOPY OR ELECTRONIC MANUAL ASSIGNED TO YOU. HARDCOPY USERS MUST ENSURE THE DOCUMENTS PROVIDED MATCH THE INFORMATION ON THIS TRANSMITTAL. WHEN REPLACING THIS MATERIAL IN YOUR HARDCOPY MANUAL, ENSURE THE UPDATE DOCUMENT ID IS THE SAME DOCUMENT ID YOU'RE REMOVING FROM YOUR MANUAL. TOOLS FROM THE HUMAN PERFORMANCE TOOL BAG SHOULD BE UTILIZED TO ELIMINATE THE CHANCE OF ERRORS.

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

TSB2 - TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 08/05/2015 ADD MANUAL TABLE OF CONTENTS DATE: 11/04/2015 CATEGORY: DOCUMENTS TYPE: TSB2 AocD

Nov. 05, 2015 Page 2 of 2 ID: TEXT 3.4.10 ADD: REV: 4 REMOVE: REV:3 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.5.2 ADD: REV: 2 REMOVE: REV:I1 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.6.4.1 REMOVE: REV:II1 ADD: REV: 12 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT LOES ADD: REV: 125 REMOVE: REV:124 ANY DISCREPANCIES WITH THE MATERIAL PROVIDED, CONTACT DCS @ X3107 OR X3136 FOR ASSISTANCE. UPDATES FOR HARDCOPY MANUALS WILL BE DISTRIBUTED WITHIN 3 DAYS IN ACCORDANCE WITH DEPARTMENT PROCEDURES. PLEASE MAKE ALL CHANGES AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX UPON COMPLETION OF UPDATES. FOR ELECTRONIC MANUAL USERS, ELECTRONICALLY REVIEW THE APPROPRIATE DOCUMENTS AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX.

SSES MANUAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL Table Of Contents Issue Date: 11/04/2015 Pr~ocedure Name Rev Issue Date Change ID Change Number TEXT LOES 125 11/ 04/2 015

Title:

LIST OF EFFECTIVE SECTIONS TEXT T0C 22 07/02/2014

Title:

TABLE OF CONTENTS TEXT 2.1.1 5 01/22 /2 015

Title:

SAFETY LIMITS (SLS) REACTOR CORE SLS TEXT 2.1.2 1 10/04/2 007

Title:

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

Title:

LIMITING CONDITION FOR OPERATION (LC0) APPLICABILITY TEXT 3.1.1 1 03/24/2005

Title:

REACTIVITY CONTROL SYSTEMS SHUTDOWN MARGIN (SDM)

TEXT 3.1.2 0 11/18/2002

Title:

REACTIVITY CONTROL SYSTEMS REACTIVITY ANOMALIES TEXT 3.1.3 2 01/19/2009

Title:

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

Title:

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

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS TEXT 3.1.6 3 02/24/2014

Title:

REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Report Date: 11/05/15 Page !

Pagej. of of 8 Report Date: 11/05/15

SS~ES MANUAL Manual Name: TSB2 Manual

Title:

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

Title:

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

Title:

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

Title:

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

TEXT 3.2.2 3 05/06/2009

Title:

POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)

TEXT 3.2.3 2 05/06/2009

Title:

POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE LHGR TEXT 3.3.1.1 5 02/24/2014

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATION TEXT 3.3.1.2 2 01/19/2009

Title:

INSTRUMENTATION SOURCE RANGE MONITOR (SRM) INSTRUMENTATION TEXT 3.3.2.1 3 02/24/2014

Title:

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

Title:

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

Title:

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

Title:

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

Title:

INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATIONW Report Date: 11/05/15 Page2 Page ! of of *~.

Report Date: 11/05/15

SSES MANUAL Manual Name: TSB2 Manual

Title:

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

Title:

INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP (ATWS-RPT) INSTRUMENTATION TEXT 3.3.5.1 5 02/24/2014

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 7 03/31/2014

Title:

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

Title:

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

Title:

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

Title:

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

Title:

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

Title:

REACTOR COOLANT SYSTEM (RCS) RECIRCULATION LOOPS OPERATING TEXT 3.4.2 3 10/23/2013

Title:

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

Title:

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

TEXT 3.4.4 0 11/18/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE Report Date: 11/05/15 Page~

Page

• of of ~

Report Date: 11/05/15

SSES ANI JAI.

Manual Name: TSB2

i"Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.4.5 3 03/10/2010 Titles REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE TEXT 3.4.6 4 02/19/2014

Title:

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

--- Title :_REACT0RCOOLANT SYSTEM_(RCS) RCS*SPECIFIC ACTIVITY __

TEXT 3.4.8 2 03/28/2013

Title:

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

- HOT SHUTDOWN TEXT 3.4.9 103/28/2013

Title:

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

- COLD SHUTDOWN 4 11/04/2015 TEXT 3.4.10

Title:

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

Title:

REACTOR COOLANT SYSTEM (RCS) REACTOR STEAM DOME PRESSURE TEXT 3.5.1 4 07/16/2014

Title:

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

SYSTEM ECCS - OPERATING TEXT 3.5.2 2 11/04/2015

Title:

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

SYSTEM ECCS - SHUTDOWN TEXT 3.5.3 3 02/24/2014

Title:

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

SYSTEM RCIC SYSTEM TEXT 3.6.1.1 5 02/24/2014

Title:

PRIMARY CONTAINMENT TEXT 3.6.1.2 1 05/06/2009

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK Report Date: 11/05/15 Page4 Page A of of 8 Report Date: 11/05/15

SSES M~ANUJAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.6.1.3 14 07/02/2014

Title:

• CONTAINMYENT SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)

TEXT 3.6.1.4 1 05/06/2009

Title:

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

__-Title:

• CONTAINMENT _SYSTEMSDRYWELLAIR TEMPERATURE -__

TEXT 3.6.1.6 0 11/18/2002

Title:

. CONTAINMENT SYSTEMS SUPPRESSION CHAMBER-T0-DRYWELL VACUU/MBREAKERS TEXT 3.6.2.1 2 12/17/2007

Title:

• CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE TEXT 3.6.2.2 0 11/18/2002 Title : CONTAINMENT SYSTEMS SUPPRESSION POOL WATER LEVEL TEXT 3.6.2.3 1 01/16/2006 Title : CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL COOLING TEXT 3.6.2.4 0 11/18/2002 Title : CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL SPRAY TEXT 3.6.3.1 2 06/13/2006 Title : CONTAINMENT SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS TEXT 3.6.3.2 1 04/18/2005

Title:

• CONTAINMENT SYSTEMS DRYWELL AIR FLOW SYSTEM TEXT 3.6.3.3 1 02/28/2013 Title : CONTAINMENT SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION TEXT 3.6.4.1 12 11/04/2015

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT Report Date: 11/05/15 Pages Page

• of of 8 Report Date: 11/05/15

SSES MANUAL Manual Nanme: TSB2

[,Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.6.4.2 9 04/25/2014 Title* CONTAINMENT SYSTEMS SECONDARY CONTAINMThENT ISOLATION VALVES (SCIVS)

TEXT 3.6,4.3 4 09/21/2006

Title:

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

- Title :_PLANTSYSTEMS_ _RESIDUAL HEAThREMOVAL SERVICEWATER (RHRSWLmSYSTEMANDTHE ULTIMATE HEAT SINK (UBS)

TEXT 3.7.2 2 05/02/2008

Title:

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

Title:

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

Title:

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

Title:

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

Title:

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

Title:

PLANT SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL TEXT 3.7.8 0 05/06/2009

Title:

MAINE TURBINE PRESSURE REGULATION SYSTEM TEXT 3.8.1 9 02/24/2014

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING TEXT 3.8.2 0 11/18/2002

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - SHUTDOWN Report Date: 11/05/15 Page 6 Page of of 88 Report Date: 11/05/15

S.SES MANUITAL Manul Nme: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.8.3 4 10/23/2013

Title:

ELECTRICAL POWER SYSTEMS DIESEL FUEL OIL LUBE OIL AND STARTING AIR TEXT 3.8.4 3 01/19/2009

Title:

ELECTRICAL POWER SYSTEMS DC SOURCES - OPERATING TEXT 3.8.5 1 . 12/14/2006

__Title: ELECTRICALPOWERSYSTEMS DC S0lURCES_= SHUTDOWN ____-

TEXT 3.8.6 1 12/14/2006

Title:

ELECTRICAL POWER SYSTEMS BATTERY CELL PARAMETERS TEXT 3.8.7 4 10/05/2005

Title:

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

Title:

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

Title:

REFUELING OPERATIONS REFUELING EQUIPMENT INTERLOCKS TEXT 3.9.2 1 09/01/2010

Title:

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

Title:

REFUELING OPERATIONS CONTROL ROD POSITION TEXT 3.9.4 0 11/18/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/18/2002

Title:

REFUELING OPERATIONS CONTROL ROD OPERABILITY - REFUELING TEXT 3.9.6 1 10/04/2007

Title:

REFUELING OPERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL Report Date: 11/05/15 Page !7 Page of of S Report Date: 11/05/15

S.SES 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 (RER) - HIGH WATER LEVEL TEXT 3.9.8 0 11/18/2002

Title:

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

-Titl :_SPECIAL_ _OPERATIONS- INSERVICELEAK AND HYDROSTAT~IC TESTINGOPERATION TEXT 3.10.2 0 11/18/2002

Title:

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

Title:

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

Title:

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

Title:

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

Title:

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

Title:

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

Title:

SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING Report Date: 11/05/15 Pages Page 8 of of 8 Report Date: 11/05/15

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

Section Title Revision TOC Table of Contents 22 8 2.0 SAFETY LIMITS BASES Page TS I B 2.0-1 2 Pages TS I B 2.0-2 and TS / B 2.0-3 5 Page TS /B 2.0-4 7 Pages TS / 8 2.0-5 through TS I B 2.0-8 1 B 3.0 LCO AND SR APPLICABILITY BASES Page TS /B 3.0-1 1 Pages TS /8B3.0-2 through TS I B 3.0-4 0 Pages TS /8B3.0-5 through TS /8B3.0-7 1 Page TS /8B3.0-8 3 Pages TS / B 3.0-9 through Page TS I B 3.0-1: 2 Page TS /8B3.0-1 Ia 0 Page TS /8B3.0-12 1 Pages TS /8B3.0-13 through TS /8B3.0-1 2 Pages TS /8B3.0-16 and TS /8 3.0- ,,0 B 3.1 REACTIVITY CONTROL BASE  ;*

Pages B 3.1-1 through 8 3.1 *,,.0 Page TS /8B3.1-5 -* *1 Pages TS /8B3.1-6 an 2 Pages B3.1-8 throu *0 Page TS /8B3.1-1 * ,,0 PageTS/B3. I Page TS*/B*1-6 1 Pages 17,through TS /B 3.1-19 0 Pages Oand TS /B 3.1-21 1 o0 P /83.1-25 through TS /8B3.1-27 1 P!i;* TS;/83.1-28 2 P:*;;*e*TS /B 3.1-29 1 Pgs TS / B 3.1-30 through TS / B 3.1-33 0 Pages TS /8B 3.1.34 through TS /8B 3.1-36 1 Page TS /8B3.1-37 2 Page TS /8B3.1-38 3 Pages TS /8B3.1-39 and TS / B 3.1-40 2 Page TS /8B 3.1-40a 0 Page TS /8B3.1-41 1 Page TS / B 3.1-42 2 Revision 125 TS/BLOES-1 SUSQUEHANNA - UNIT-UNIT 22 TS / B LOES-1 Revision 125

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

Section Title Revision Pages TS / B 3.1-43 1 Page TS / B 3.1-44 0 Page TS I B 3.1-45 3 Page TS / B 3.1-46 through TS / B 3.1-49 1 Page TS / B 3.1-50 0 Page TS/!B 3.1-51 3 B 3.2 POWER DISTRIBUTION LIMITS BASES Pages TS / B 3.2-1 and TS / B 3.2-2 2 Page TS / B 3.2-3 4 Page TS / B 3.2-4 *1 Page TS / B 3.2-5 3 Page TS I B 3.2-6 "4

---

Page TS--B 3.2 - - -_- - -3 Pages TS / B 3.2-8 and TS / B 3.2-9 4 Pages TS / B 3.2-10 through TS I B 3.2-12 2 Page TS / B 3.2-13 1 B 3.3 INSTRUMENTATION Pages'TS / B 3.3-1 through TS / B 3.3-4 1 Page TS / B 3.3-5 2 Page TS / B 3.3-6 1 Page TS / B 3.3-7 3 Page TS I B 3.3-8 4 Pages TS I B 3.3-9 through TS / B 3.3-13 3 Page TS / B 3.3-14 4 Pages TS / B 3.3-15 and TS / B 3.3-16 2 Pages TS I B 3.3-17 through TS / B 3.3-21 3 Pages TS I B 3.3-22 through TS / B 3.3-27 2 Page TS / B 3.3-28 3 Page TS / B 3.3-29 4 Pages TS / B 3.3-30 and TS / B 3.3-31 3 Pages TS / B 3.3-32 and TS / B 3.3-33 4 Page TS / B 3.3-34 2 Pages TS / B 3.3-34a and TS / B 3.3-34b I Pages TS l B 3.3.34c and TS / B 3.3-34d 0 Page TS I B 3.3-34e I Pages TS / B 3.3-34f through TS / B 3.3-34i 0 Pages TS l B 3.3-35 and TS / B 3.3-36 2 Pages TS l B 3.3-37 and TS l B 3.3-38 1 LOES-2 Revision 125 TS/B SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-2 Revision 125

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

Section Title Revision Page TS / B 3.3-39 2 Pages TS / B 3.3-40 through TS / B 3.3-43 1 Pages TS / B 3.3-44 through TS / B 3.3-54 3 Pages TS / B 3.3-54a through TS I B 3.3-54d 0 Page TS I B 3.3.54e 1 Page TSI/B 3.3-55 2 Page TS I B 3.3-56 0 Page TS/1$ 3.3-57 1 Page TS / B 3.3-58 0 Page TS / B 3.3-59 1 Page TS / B 3.3-60 0 Page TS / B 3.3-61 1 Pages TS / B 3.3-62 and TS / B 3.3-63 0

....... -Pages TS-/-B 373-64-and-TS I B 3.3-65 .... . .. __ 2 -

Page TS / B 3.3-66 4 Page TS / B 3.3-67 3 Page TS / B 3.3-68 4 Page TS / B 3.3.69 5 Page TS / B3.3-70 4 Page TS I B 3.3-71 3 Pages TS /B 3.3-72 and TS I B 3.3-73 2 Page TS I B 3.3-74 3 Page TS I B 3.3-75 2 Pages TS / B 3.3-75a through TS I B 3.3-75c 6 Pages TS / B 3.3-76 and TS I B 3.3-77 0 Page TSI/B 3.3-78 1 Pages TS / B 3.3-79 through TS I B 3.3-81 0 Page TS / B 3.3-82 1 Page TS / B3.3-83 0 Pages TS / B 3.3-84 and TS I B 3.3-85 1 Page TS / B3.3-86 0 Page TS / B3.3-871 Page TS / B 3.3-88 0 Page TS I B 3.3-89 1 Pages TS I B 3.3-90 and TS I B 3.3-91 0 Pages TS / B 3.3-92 through TS /B 3.3-103 1 Page TS / B 3.3-104 3 Pages TS I B 3.3-105 and TS I B 3.3-106 1 Page TS I B 3.3-107 2 Page TS I B 3.3-108 1 Page TS I B 3.3-109 2 Pages TS /B 3.3-110 through TS/IB 3.3-112 1 Page TS I B 3.3-113 2 Revision 125 TS/BLOES-3 SUSQUEHANNA - UNIT-UNIT 2 2 TS / B LOES-3 Revision 125

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

Section Title Revision Page TS /8B3.3-114 1 Page TS /8B3.3-115 2 Page TS /8B3.3-116 3 Pages TS / B 3.3-117 and TS / B 3.3-118 2 Page TS / B 3.3-119 1 Page TS /8B3.3-120 2 Pages TS / B 3.3-121. and TS /83.3-122 3 Page TS / B3.3-123 1 Page TS /8B3.3-124 2 Page TS / B 3.3-124a 0 Page TS /8B3.3-125 1 Page TS / B3.3-126 2 Page TS / B 3.3-127 "3 Page TS-[-8-3_3-1 ... .. . .... . - 2_

Pages TS / B 3.3-129 through TS / B 3.3-131 1 Page TS /8B3.3-132 2 Pages TS / 8 3.3-133 and TS/B83.3-134 1 Pages TS / B 3.3-135 through TS / B 3.3-137 0 Page TS / B 3.3-138 1 Pages TS / 8 3.3-139 through TSI 83.3-146 0 Pages B 3.3-147 through B 3.3-1 49 0 Page TS /8B3.3-150 1 Pages TS / B 3.3-151 through TS /B 3.3-154 2 Page TS /8B3.3-155 1 Pages TS / B 3.3-156 through TS I B 3.3-158 2 Pages TS / B 3.3-159 through TSI 8 3.3-162 1 Pages TS / B 3.3-163 through TS I B 3.3-166 2 Pages TS / 8 3.3-167 and TS /8B3.3-168 1 Pages TS / 8 3.3-169 and TS /8B3.3-170 3 Pages TS / B 3.3-171 through TS / B 3.3-174 1 Page TS / B 3.3-174a 1 Pages TS/ B 3.3-1 75 through TS/IB 3.3-177 1 Page TS /8B3.3-178 2 Page TS /8B3.3-179 3 Page TS / B 3.3-179a 2 Page TS /8B3.3-180 1 Page TS /8B3.3-181 3 Page TS /8B3.3-182 1 Page TS /8B3.3-183 2 Page TS /8B3.3-184 1.

Page TS /8B3.3-185 4 Page TS / 8 3.3-1 86 1 Pages TS / 8 3.3-187 and TS /83.3-188 2 Pages TS / B 3.3-189 through TS /B 3.3-191 1 Page TS / B83.3-192 0 LOES-4 Revision 125 TS/B SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-4 Revision 125

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

Section Title Revision Page TS / B 3.3-193 I Pages TS I B 3.3-194 and TS / B 3.3-195 0 Page TS / B 3.3-196 2 Pages TS I B 3.3-197 through TS /B 3.3-205 0 Page TS / B 3.3-206 1 Pages B 3.3-207 through B 3.3-209 0 Page TS / B 3.3-210 1 Page TS /B 3.3-211 2 Pages TS / B 3.3-212 and TS I B 3.3-213 1 Pages B 3.3-214 through B 3.3-220 0 B 3.4 REACTOR COOLANT SYSTEM BASES

___Pages TS/B 3_.4_-1 and _TS /8_3.4-2 ___ _- -__2 Pages TS /8B3.4-3 through TS /8B3.4-5 4-,-

Pages TS /8B3.4-6 through TS /8B3.4-9 3 Page TS /8B3.4-10 1 Pages TS /8B3.4-11 and TS /8B3.4-12 0 Page TS / B 3.4-13 2 Page TS /8B3.4-14 1 Page TS/B83.4-15 2 Pages TS /8B3.4-16 and TS /8B3.4-17 4 Page TS /8B3.4-18 2 Pages B 3.4-19 through B 3.4-23 0 Pages TS /8B3.4-24 through TS /8B3.4-27 0 Page TS /8B3.4-28 1 Page TS /8B3.4-29 3 Page TS /8B3.4-30 2 Page TS /8B3.4-31 1 Pages TS /8B3.4-32 and TS /8B3.4-33 2 Page TS / B 3.4-34 1 Page TS / B 3.4-34a 0 Pages TS / B 3.4-35 and TS /8B3.4-36 1 Page TS /B 3.4-37 2 Page B 3.4-38 1 Pages B 3.4-39 and B 3.4-40 0 Page TS /8B3.4-41 2 Pages TS / B 3.4-42 through TSI/B 3.4-45 0 Page TS /8B3.4.4-46 1 Pages TS / B 3.4.4-47 and TS / B 3.4.4-48 0 Page TS /8B 3.4-493 Pages TS /8B3.4-50 and TS / B 3.4-51 2 Page TS /8B3.4-52 3 Page TS / B 3.4-52a 0 Pages TS /8B3.4-53 through TS / B 3.4-56 2 Page TS /8B3.4-57 3 Pages TS / B 3.4-58 through TS / B 3.4-60 1 SUSQUEHANNA - UNIT 2 TS / B LOES-5 Revision 125

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

Section Title Revision B 3.5 ECCS AND RCIC BASES Pages TS / B 3.5-1 and TS I B 3.5-2 1 Pages TS I B 3.5-3 and TS I B 3.5-4 2 Page TS /8B3.5-5 3 Page TS /8B3.5-6 2 Pages TS/I.B 3.5-7 through TS / B 3.5-10 1 Pages TS / B 3.5-11 and TS /8B3.5-12 2 Pages TS / B 3.5-13 and TS /8B3.5-14 1 Pages TS / 8 3.5-15 through TS / 8.3.5-17 3 Pages TS /8B3.5-18 through TS /8B3.5-21 1 Page TS /8B3.5-22 2 Page TS / 8.3.5-23 1

___Page B 3.5-24 0 Page TS /B 3.5-25 1 Pages TS /8B3.5-26 and TS /8B3.5-27 2 Page TS /8B3.5-28 0 Page TS / B 3.5-29 through TS I B 3.5-31 1 B 3.6 CONTAINMENT SYSTEMS BASES Page TS /8B3.6-1 2 Page TS /8B3.6-la 4 Page TS /8B3.6-2 4 Page TS /8B3.6-3 3 Page TS /B 3.6-4 4 Page TS /8B3.6-5 .3 Page TS /8B3.6-6 4 Page TS /B 3.6-6a 4 Page TS /8B 3.6-6b 3 Page TS /8B 3.6-6c 0 Page B 3.6 0 Page TS / 3.6-8 1 Pages B 3.6-9 through 8 3.6-14 0 Page TS /8B3.6-15 4 Page TS /8B 3.6-15a 0 Page TS /8B 3.6-15b 3 Pages TS /8B3.6-16 and TS /8B3.6-17 3 Page TS /8B 3.6-17a 1 Pages TS /8B3.6-18 and TS /8B3.6-19 1 Page TS /8B3.6-20 2 Page TS /8B3.6-21 3 LOES-6 Revision 125 TS/B SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 22 TS / B LOES-6 Revision 125

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

Section Titl__e Revision Pages TS I B 3.6-21a and TS I B 3.6-21b 0 Pages TS / B 3.6-22 and TS I B 3.6-23 2 Pages TS / B 3.6-24 and TS I B 3.6-25 1 Pages TS / B 3.6-26 and TS / B 3.6-27 3 Page TS I B 3.6-28 7 Page TS I B 3.6-29 5 Page TS /B 3.6-29a 0 Page TS / B 3.6-30 2 Page TS / B3.6-31 3 Pages TS / B 3.6-32 and TS / B 3.6-33 2 Page TS / B 3.6-34 1 Pages TS / B 3.6-35 and TS / B 3.6-36 3

__ Page TS /B 3.6-37 ___2 Page TS / B 3.6-38 3 Page TSI/B 3.6-39 7 Page TS / B 3.6-39a I Page TS/1. 3.6-40 1 Pages B 3.6-41 and B 3.6-42 0 Pages TS / B 3.6-43 and TS / B 3.6-44 1 Page TS / B 3.6-45 2 Pages TS / B 3.6-46 through TS / B 3.6-50 1 Page TS / B 3.6-51 2 Pages TS / B 3.6-52 through TS / B 3.6-55 0 Pages TS / B 3.6-56 and TS / B 3.6-57 2 Pages B 3.6-58 through B 3.6-62 0 Pages TS / B 3.6-63 and TS / B 3.6-64 1 Pages B 3.6-65 through B 3.6-68 0 Pages TS / B 3.6-69 through TS / B 3.6-71 1 Page TS I B 3.6-72 2 Pages TS / B 3.6-73 and TS / B 3.6-74 1 Pages B 3.6-75 and B 3.6-76 0 Page TS / B 3.6-77 1 Pages B 3.6-78 and B 3.6-79 0 Page TS / B 3.6-80 1 Pages TS / B 3.6-81 and TS / B 3.6-82 0 Page TS I B 3.6-83 4 Page TS I B 3.6-84 2 Page TS / B 3.6-85 4 Pages TS / B 3.6-86 and TS I B 3.6-87 2 Page TS /8B 3.6-87a 3 Page TSI/B 3.6-88 6 Page TS /8B3.6-89 4 Page TS /8B 3.6-89a 0 LOES-7 Revision 125 TSIB SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-7 Revision 125

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

Section Title Revision Pages TS / B 3.6-90 and TS / B 3.6-91 3 Page TS I B 3.6-92 2 Pages TS / B 3.6-93 through TS / B 3.6-95 1 Page TS / B 3.6-96 2 Page TS / B 3.6-97 1 Page TS / B3.6-98 2 Page TS / B 3.6-99 7 Page TS / B 3.6-99a 6 Page TS I B 3.6-99b 4 Page TS / B 3.6-99c 0 Pages TS / B 3.6-100 and TS / B 3.6-101 1 Pages TS / B 3.6-102 and TS / B 3.6-103 *2 Page TS / B 3.6-104 3 Page TS / B 3.6-105 -2 Page TS / B 3.6-106 3 B 3.7 PLANT SYSTEMS BASES Page TS / B3.7-1 3 Page TS / B 3.7-2 4 Pages TS / B 3.7-3 through TS I B 3.7-5 3 Page TS I B 3.7-5a 2 Page TS/B 3.7.-6 4 Page TSI!B 3.7-6a 3 Page TS / B 3.7-6b 2 Page TSI!B 3.7-6c 3 Page TS / B 3.7-7 3 Page TS I B 3.7-8 2 Pages B 3.7-9 through B 3.7-11 0 Pages TS / B 3.7-12 and TS I B 3.7-13 2 Pages TS / B 3.7-14 through TS / B 3.7-18 3 Page TS I B 3.7-18a I Pages TS / B 3.7-18B through TS I B 3.7-18E 0 Pages TS / B 3.7-19 through TS / B 3.7-24 1 Pages TS / B 3.7-25 and TS I B 3.7-26 0 Page TSI/B 3.7-27 4 Pages TS / B 3.7-28 and TS / B 3.7-29 3 Pages TS / B 3.7-30 and TS / B 3.7-31 1 Page TS I B 3.7-32 0 Page TSI/B 3.7-33 1 Pages TS / B 3.7-34 through TS / B 3.7-37 0 Revision 125 TS / B LOES-8 SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-8 Revision 125

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

Section Title Revision B 3.8 ELECTRICAL POWER SYSTEMS BASES Page TS / B 3.8-1 1 Pages B 3.8-2 and B 3.8-3 0 Page TS / B 3.8-4 1 Pages TS / B 3.8-4a and TS / B 3.8-4b 0 Pages TS / B 3.8-5 and TS / B 3.8-6 3 Page TS / B 3.8-6a 1 Pages B 3.8-7 and B 3.8-8 0 Page TS / B 3.8-9 2 Pages TS / B 3.8-10 and TS / B 3.8-11 1 Pages B 3.8-12 through B 3.8-18 0 Page TS / B 3.8-19 1 Pages B 3.8-20 through B 3.8-22 .... 0 Page TS / B 3.8-23 1 Page B 3.8-24 0 Pages TS / B 3.8-25 and TS I B 3.8-26 1 Pages B 3.8-27 through B 3.8-30 0 Page TS I B 3.8-31 1 Pages TS / B 3.8-32 through TS / B 3.8-35 0 Page TS I B 3.8-36 1 Page TS I B 3.8-37 0 Page TS / B 3.8-38 1 Pages B 3.8-39 through B 3.8-46 0 Page TS / B 3.8-47 3 Pages TS / B 3.8-48 through TS / B 3.8-50 0 Pages TS / B 3.8-51 and TS / B 3.8-52 3 Page TS / B 3.8-53 1 Page TS / B 3.8-54 0 Page TS / B 3.8-55 1 Pages TS / B 3.8-56 through TS I B 3.8-59 2 Pages TS / B 3.8-60 through TS / B 3.8-64 3 Page TS I B 3.8-65 4 Page TS / B3.8-66 5 Pages TS / B 3.8-67 and TS I B 3.8-68 4 Page TS I B 3.8-69 5 Pages TS / B 3.8-70 through TS / B 3.8-83 1 Pages TS I B 3.8-83A through TS I B 3.8-830 0 Pages B 3.8-84 through B 3.8-85 0 Page TS / B 3.8-86 1 Page TS / B 3.8-87 2 Pages TS / B 3.8-88 and TS I B 3.8-89 1 Page TS I B 3.8-90 2 Pages TS / B 3.8-91 through TS / B 3.8-93 1 Pages B 3.8-94 through B 3.8-99 0.

LOES-9 Revision 125 2 TSIB SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 TS / B LOES-9 Revision 125

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

Section. Title Revision B 3.9 REFUELING OPERATIONS BASES Pages TS / B 3.9-1 and TS / B 3.9-2 1 Page TS I B 3.9-2a I Pages TS / B 3.9-3 through TS I B 3.9-5 1 Pages TS /8B3.9-6 through TS I B 3.9-8 0 Pages B 3.9-9 through B 3.9-18 0 Pages TS /8B3.9-19 through TS /8B3.9-21 1 Pages B 3.9-22 through B 3.9-30 0 8 3.10 SPECIAL OPERATIONS BASES Page TS /8B3.10-1 *2

___Pages TS / B 3.10-2 through TSL/B 3.10-5 __ 1 Pages 8 3.10-6 through 8 3.10-32 0 Page TS /8B3.10-33 2 Page B 3.10-34 0 Page TS /8B3.10-35 1 Pages B 3.10-36 and B 3.10-37 0 Page TS /8B3.10-38 1 Page TS / 8 3.10-39 2 Revision 125 TS I B LOES-lO SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-10 Revision 125

Rev. 4 RCS P/T Limits B 3.4.10 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.10 RCS Pressure and Temperature (PIT) Limits BASES BACKGROUND All components of the RCS are designed to withstand effects of cyclic loads due to system pressure and temperature changes. These loads are introduced by startup (heatup) and shutdown (cooldown) operations, power transients, and reactor trips. This LCO limits the pressure and temperature changes during RCS heatup and cooldown, within the design assumptions and the stress limits for cyclic operation.

~This Specification contains P/T" limit curves for heatup, cooldown, and inservice leakage and hydrostatic testing, and limits for the maximum rate of

...... ....- change-of-reactor coolant-temperature. The heatup curve provides limits for

• both heatup and criticality.

Each P/T limit curve defines an acceptable region for normal operation. The usual use of the curves is operational guidance during heatup or cooldown maneuvering, when pressure and temperature indications are monitored and compared to the applicable curve to determine that operation is within the allowable region.

The LCO establishes operating limits that provide a margin to brittle failure of the reactor vessel and piping of the reactor coolant pressure boundary (RCPB). The vessel is the component most subject to brittle failure.

Therefore, the LCO limits apply mainly to the vessel.

10 CFR 50, Appendix G (Ref. 1), requires the establishment of P/T limits for material fracture toughness requirements of the RCPB materials.

Reference I requires an adequate margin to brittle failure during normal operation, anticipated operational occurrences, and system hydrostatic tests.

It mandates the use of the ASME Code, Section Xl, Appendix G (Ref. 2).

The actual shift in the RTNDT of the vessel material will be established periodically by removing and evaluating the irradiated reactor vessel material specimens, in accordance with ASTM E 185 (Ref. 3) and Appendix H of 10 CFR 50 (Ref. 4). The operating P/l" limit curves will be adjusted, as necessary, based on the evaluation findings and the recommendations of RG 1.99, "Radiation Embrittlement of Reactor Vessel Materials (Ref. 5).

The calculations to determine neutron fluence will be developed using the BWRVIP RAMA code methodology, which is NRC approved and meets the intent of RG 1.190, "Calculational and Dosimetry Methods for Determining Pressure Vessel Neutron Fluence" (Ref. 11). See FSAR Section 4.1.4.5 for determining fluence (Ref. 12).

(continued)

SUSQUEHANNA -UNIT 2 T / B 3.4-49 TS .- 9Rvso Revision 3

Rev. 4 RCS P/T" Limits B 3.4.10 BASES BACKGROUND The P/T limit curves are composite curves established by superimposing (continued) limits derived from stress analyses of those portions of the reactor vessel and head that are the most restrictive. At any specific pressure, temperature, and temperature rate of change, one location within the reactor vessel will dictate the most restrictive limit. Across the span of the P/T limit curves, different locations are more restrictive, and, thus, the curves are composites of the most restrictive regions.

The heatup curve used to develop the P/T limit curve composite represents a different set of restrictions than the cooldown curve used to develop the P/T limit curve composite because the directions of the thermal gradients through the vessel wall are reversed. The thermal gradient reversal alters the location of the tensile stress between the outer and inner walls.

The criti~lity limits incluide th* R~fer-n-ce- 1 requi~rnentth~t-th-ey be at le~t 40°F above the heatup curve or the cooldown curve and not lower than the minimum permissible temperature for the inservice leakage and hydrostatic testing.

The consequence of violating the LCO limits is that the RCS has been operated under conditions that can result in brittle failure of the RCPB, possibly leading to a nonisolable leak or loss of coolant accident. In the event these limits are exceeded, an evaluation must be performed to determine the effect on the structural integrity of the RCPB components.

ASME Code, Section Xl, Appendix E (Ref. 6), provides a recommended methodology for evaluating an operating event that causes an excursion outside the limits.

APPLICABLE The P/T limits are not derived from Design Basis Accident (DBA) analyses.

SAFETY They are prescribed during normal operation to avoid encountering pressure, ANALYSES temperature, and temperature rate of change conditions that might cause undetected flaws to propagate and cause nonductile failure of the RCPB, a condition that is unanalyzed. Reference 7 establishes the methodology for determining the P/T limits. Since the P/T limits are not derived from any DBA, there are no acceptance limits related to the P/T limits. Rather, the P/T limits are acceptance limits themselves since they preclude operation in an unanalyzed condition.

RCS P/T limits satisfy Criterion 2 of the NRC Policy Statement (Ref. 8).

The Effective Full Power Years (EFPY) shown on the curves are approxi-mations of the ratio of the energy that has been and is anticipated to be generated in a year to the energy that could have been generated ifthe unit ran at original thermal power rating of 3293 MWT for the entire year.

These values are based on fluence limits that are not to be exceeded.

(continued)

SUSQUEHANNA - UNIT 2TSIB345 TS / B 3.4-50 Revision 2

Rev. 4 RCS PIT Limits B 3.4.10 BASES. (continued)

LCO The elements of this LCO are:

a. RCS pressure and temperature are to the right of the applicable curves specified in Figures 3.4.10-1 through 3.4.10-3 and within the applicable heat-up or cool down rate specified in SR 3.4.10.1 during RCS heatup, cooldown, and inservice leak and hydrostatic testing;

b. The temperature difference between the reactor vessel bottom head coolant and the reactor pressure vessel (RPV) coolant is < 145°F during recirculation pump startup, and during increases in THERMAL POWER or loop flow while operating at low THERMAL POWER or loop flow;

c. -The-temperature difference between-the reactor-coolant-in-the respective---.

recirculation loop and in the reactor vessel is _< 50°F during recirculation pump startup, and during increases in THERMAL POWER or loop flow while operating at low THERMAL POWER or loop flow;

d. RCS pressure and temperature are to the right of the criticality limits specified in Figure 3.4.10-3 prior to achieving criticality; and

e. The reactor vessel flange and the head flange temperatures are >_700 F when tensioning the reactor vessel head bolting studs.

These limits define allowable operating regions and permit a large number of operating cycles while also providing a wide margin to nonductile failure.

The PIT limit composite curves are calculated using the worst case of material properties, stresses, and temperature change rates anticipated under all heatup and cooldown conditions. The design calculations account for the reactor coolant fluid temperature impact on the inner wall of the vessel and the temperature gradients through the vessel wall. Because these fluid temperatures drive the vessel wall temperature gradient, monitoring reactor coolant temperature provides a conservative method of ensuring the PIT limits are not exceeded. Proper monitoring of vessel temperatures to assure compliance with brittle fracture temperature limits and vessel thermal stress limits during normal heatup and cooldown, and during inservice leakage and hydrostatic testing, is established in PPL Calculation EC 062-0573 (Ref. 9). For PIT curves A, B, and C, the bottom head drain line coolant temperature should be monitored and maintained to the right of the most limiting curve.

(continued)

SUSQUEHANNA - UNIT 2 Sl34-1Rvso2 TS / B 3.4-51 Revision 2

Rev. 4 RCS P/T Limits B 3.4.10 BASES LCO Curve A must be used for any ASME Section III Design Hydrostatic Tests (continued) performed at unsaturated reactor conditions. Curve A may also be used for ASME Section Xl inservice leakage and hydrostatic testing when heatup and cooldown rates can be limited to 20°F in a one-hour period.

Curve A is based on pressure stresses only. Thermal stresses are assumed to be insignificant. Therefore, heatup and cooldown rates are limited to 20°F in a one-hour period when using Curve A to ensure minimal thermal stresses. The recirculation loop suction line temperatures should be monitored to determine the temperature change rate.

Curves B and C are to be used for non-nuclear and nuclear heatup and cooldown, respectively. In addition, Curve B may be used for ASME Section Xl inservice leakage and hydrostatic testing, but not for ASME Section III DesignHydrostatic Tests Performed at u~nsa~turated_ re~actor con~diti~ons._.

Heatup and cooldown rates are limited to 100°F in a one-hour period when using Curves B and C. This limits the thermal gradient through the vessel wall, which is used to calculate the thermal stresses in the vessel wall. Thus, the LCO for the rate of coolant temperature change limits the thermal stresses and ensures the validity of the P/T curves. The vessel belt-line fracture analysis assumes a 100°F/hr coolant heatup or cooldown rate in the beltline area. The 100°F limit in a one-hour period applies to the coolant in the beltline region, and takes into account the thermal inertia of the vessel wall. Steam dome saturation temperature (TSAT), as derived from steam dome pressure, should be monitored to determine the beltline temperature change rate at temperatures above 212°F. At temperatures below 212°F, the recirculation loop suction line temperatures should be monitored.

During heatups and cooldowns, the reactor vessel could experience a vacuum (negative pressure) at low temperatures (unsaturated conditions) and low rates of temperature change. Under a vacuum, the vessel wall would experience a uniform compressive loading, which would counteract the tensile stress due to any thermal gradients through the vessel wall. To ensure the margin to brittle fracture is no less than at any other pressure, Curves A, B, and C require a minimum vessel metal temperature of 70°F when the reactor vessel is at a negative pressure.

(continued)

SUSQUEHANNA - UNIT 2 TI345 TS / B 3.4-52 Revision 3

Rev. 4 RCS P/T Limits B 3.4.10 BASES LCD Violation of the limits places the reactor vessel outside of the bounds of the (continued) stress analyses and can increase stresses in other RCS components. The consequences depend on several factors, as follows:

a. The severity of the departure from the allowable operating pressure temperature regime or the severity of the rate of change of temperature;

b. The length of time the limits were violated (longer violations allow the temperature gradient in the thick vessel walls to become more pronounced); and

c. The existences, sizes, and orientations of flaws in the vessel material.

APPLICABILITY The potential for violating a P/T limit exists at all times. For example, P/T limit violations could result from ambient temperature conditions that result in the reactor vessel metal temperature being less than the minimum allowed temperature for boltup. Therefore, this LCO is applicable even when fuel is not loaded in the core.

ACTIONS A.1 and A.2 Operation outside the P/l" limits while in MODES 1, 2, and 3 must be corrected so that the RCPB is returned to a condition that has been verified by stress analyses.

The 30 minute Completion Time reflects the urgency of restoring the parameters to within the analyzed range. Most violations will not be severe, and the activity can be accomplished in this time in a controlled manner.

Besides restoring operation within limits, an evaluation is required to determine if RCS operation can continue. The evaluation must verify the RCPB integrity remains acceptable and must be completed if continued operation is desired. Several methods may be used, including comparison with pre-analyzed transients in the stress analyses, new analyses, or inspection of the components.

(continued)

SUSQUEHANNA - UNIT 2TS/B345aRvso0 TS / B 3.4-52a Revision 0

Rev. 4 RCS PIT" Limits B 3.4.10 BASES ACTIONS A.1 and A.2 (continued).

ASME Code, Section Xl, Appendix E (Ref. 6), may be used to support the evaluation. However, its use is restricted to evaluation of the vessel beitline.

The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time is reasonable to accomplish the evaluation of a mild violation. More severe violations may require special, event specific stress analyses or inspections. A favorable evaluation must be completed if continued operation is desired.

Condition A is modified by a Note requiring Required Action A.2 be

• completed whenever the Condition is entered. The Note emphasizes the

-- -___ -- need to-perform the evaluation of-the-effects of the excursion-outside the -

allowable limits. Restoration alone per Required Action A. 1 is insufficient because higher than analyzed stresses may have occurred and may have affected the RCPB integrity.

B.I and B.2 If a Required Action and associated Completion Time of Condition A are not met, the plant must be placed in a lower MODE because either the RCS remained in an unacceptable PIT region for an extended period of increased stress, or a sufficiently severe event caused entry into an unacceptable region. Either possibility indicates a need for more careful examination of the event, best accomplished with the RCS at reduced pressure and temperature. With the reduced pressure and temperature conditions, the possibility of propagation of undetected flaws is decreased.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.4-53 TS .- 3Rvso Revision 2

Rev. 4 RCS P/T Limits B 3.4.10 BASES ACTIONS B.1 and B.2 (continued)

Pressure and temperature are reduced by placing the plant in at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

C.1 and C.2 Operation outside the PIT limits in other than MODES 1, 2, and 3 (including defueled conditions) must be corrected so that the RCPB is returned to a condition that has been verified by stress analyses. The Required Action must be initiated without delay and continued until the limits are restored.

Besides restoring the PIT limit parameters to within limits, an evaluation is required to determine if RCS operation is allowed. This evaluation must verify that the RCPB integrity is acceptable and must be completed before approaching criticality or heating up to > 200°F. Several methods may be used, including comparison with pre-analyzed transients, new analyses, or inspection of the components. ASME Code, Section Xl, Appendix E (Ref. 6),

may be used to support the evaluation; however, its use is restricted to evaluation of the beltline.

SURVEILLANCE SR 3.4.10.1 REQUIREMENTS Verification that operation is within limits (i.e., to the right of the applicable curves in Figures 3.4.10-1 through 3.4.10-3) is required every 30 minutes when RCS pressure and temperature conditions are undergoing planned changes. This Frequency is considered reasonable in view of the control room indication available to monitor RCS status. Also, since temperature rate of change limits are specified in hourly increments, 30 minutes permits a reasonable time for assessment and correction of minor deviations.

Surveillance for heatup, cooldown, or inservice leakage and hydrostatic testing may be discontinued when the criteria given in the relevant plant procedure for ending the activity are satisfied.

This SR has been modified with a Note that requires this Surveillance to be performed only during system heatup and cooldown operations and inservice leakage and hydrostatic testing.

Notes to the acceptance criteria for heatup and cooldown rates ensure that more restrictive limits are applicable when the PIT"limits associated with hydrostatic and inservice testing are being applied.

(continued)

SUSQUEHANNA - UNIT 2TS34-4Rvso2TS / B 3.4-54 Revision 2

Rev. 4 RCS P/T" Limits B 3.4.10 BASES SURVEILLANCE SR 3.4.10.2 REQUIREMENTS (continued) A separate limit is used when the reactor is approaching criticality.

Consequently, the RCS pressure and temperature must be verified within the appropriate limits (i.e., to the right of the criticality curve in Figure 3.4.10-3) before withdrawing control rods that will make the reactor critical.

Performing the Surveillance within 15 minutes before control rod withdrawal for the purpose of achieving criticality provides adequate assurance that the limits will not be exceeded between the time of the Surveillance and the time of reactor criticality. Although no Surveillance Frequency is specified, the requirements of SR 3.4.10.2 must be met at all times when the reactor is critical.

SR 3.4.10.3 and SR 3.4.10.4 Differential temperatures within the applicable limits ensure that thermal stresses resulting from the startup of an idle recirculation pump will not exceed design allowances. In addition, compliance with these limits ensures that the assumptions of the analysis for the startup of an idle recirculation loop (Ref. 10) are satisfied.

Performing the Surveillance within 15 minutes before starting the idle recirculation pump provides adequate assurance that the limits will not be exceeded between the time of the Surveillance and the time of the idle pump start.

An acceptable means of demonstrating compliance with the temperature differential requirement in SR 3.4.10.4 is to compare the temperatures of the operating recirculation loop and the idle loop. If both loops are idle, compare the temperature difference between the reactor coolant within the idle loop to be started and coolant in the reactor vessel.

SR 3.4.10.3 has been modified by a Note that requires the Surveillance to be performed only in MODES 1, 2, 3, and 4. In MODE 5, the overall stress on limiting components is lower. Therefore, AT limits are not required. The Note also states the SR is only required to be met during a recirculation pump start-up, because this is when the stresses occur.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.4-55 TS .- 5Rvso Revision 2

Rev. 4 RCS P/I- Limits B 3.4.10 BASES SURVEILLANCE SR 3.4.10.5 and SR 3.4.10.6 REQUIREMENTS (continued) Differential temperatures within the applicable limits ensure that thermal stresses resulting from increases in THERMAL POWER or recirculation loop flow during single recirculation loop operation will not exceed design allowances. Performing the Surveillance within 15 minutes before beginning such an increase in power or flow rate provides adequate assurance that the limits will not be exceeded between the time of the Surveillance and the time of the change in operation.

An acceptable means of demonstrating compliance with the temperature differential requirement in SR 3.4.10.6 is to compare the temperatures of the operating recirculation loop and the idle loop.

- -Plant SlS*ific startup test data t~s-determined that the bottom head is not subject to temperature stratification at power levels > 27% of RTP and with single loop flow rate > 21,320 gpm (50% of rated loop flow). Therefore, SR 3.4.10.5 and SR 3.4.10.6 have been modified by a Note that requires the Surveillance to be met only under these conditions. The Note for SR 3.4.10.6 further limits the requirement for this Surveillance to exclude comparison of the idle loop temperature ifthe idle loop is isolated from the RPV since the water in the loop can not be introduced into the remainder of the Reactor Coolant System.

SR 3.4.10.7, SR 3.4.10.8. and SR 3.4.10.9 Limits on the reactor vessel flange and head flange temperatures are generally bounded by the other P/T limits during system heatup and cooldown. However, operations approaching MODE 4 from MODE 5 and in MODE 4 with RCS temperature less than or equal to certain specified values require assurance that these temperatures meet the LCO limits.

The flange temperatures must be verified to be above the limits 30 minutes before and while tensioning the vessel head bolting studs to ensure that once the head is tensioned the limits are satisfied. When in MODE 4 with RCS temperature _< 80°F, 30 minute checks of the flange temperatures are required because of the reduced margin to the limits. When in MODE 4 with RCS temperature __100°F, monitoring of the flange temperature is required every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> to ensure the temperature is within the specified limits.

The 30 minute Frequency reflects theurgency of maintaining the temperatures within limits, and also limits the time that the temperature limits could be exceeded. The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency is reasonable based on the rate of temperature change possible at these temperatures.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.4-56 TS .- 6Rvso Revision 2

Rev. 4 RCS P/T Limits B 3.4.10 BASES (continued )

REFERENCES 1. 10 CFR 50, Appendix G.

2. ASME, Boiler and Pressure Vessel Code,Section XI, Appendix G.

3. ASTM E 185-73

4. 10 CFR 50, Appendix H.

5. Regulatory Guide 1.99, Revision 2, May 1988.

6. ASME, Boiler and Pressure Vessel Code, Section Xl, Appendix E.

7. Licensed Topical Reports:

a. Structural Integrity Associates Report No. SIR-05-044, Revision 1-A, "Pressure-Temperature Limits Report Methodology for Boiling Water Reactors," June 2013.

b. Structural Integrity Associates Report No. 0900876.401, Revision 0-A, "Linear Elastic Fracture Mechanics Evaluation of GE BWR Water Level Instrument Nozzles for Pressure-Temperature Curve Evaluations," May 2013.

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

9. PPL Calculation EC-062-0573, "Study to Support the Bases Section of Technical Specification 3.4.10."

10. FSAR, Section 15.4.4.

11. Regulatory Guide 1.190, March 2001.

12 FSAR, Section 4.1.4.5.

SUSQUEHANNA -UNIT 2 T / B 3.4-57 TS .- 7Rvso Revision 3

Rev. 2 ECCS-Shutdown B 3.5.2 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM B 3.5.2 ECCS-Shutdown BASES BACKGROUND A description of the Core Spray (CS) System and the Low Pressure Coolant Injection (LPCI) mode of the Residual Heat Removal (RHR)

System is provided in the Bases for LCO 3.5.1, "ECCS-Operating."

APPLICABLE The ECCS performance is evaluated for the entire spectrum of break SAFETY sizes for-a postulated loss of coolant accident- (LOCA). -The long term A NA LYS ES cooling analysis following a design basis LOCA (Reference 1) demonstrates that only one low pressure ECCS injection /spray subsystem is required, post LOCA, to maintain adequate reactor vessel water level in the event of an inadvertent vessel draindown. It is reasonable to assume, based on engineering judgement, that while in MODES 4 and 5, one low pressure ECCS injection/spray subsystem can maintain adequate reactor vessel water level. To provide redundancy, a minimum of two low pressure ECCS injection/spray subsystems are required to be OPERABLE in MODES 4 and 5.

The low pressure ECCS subsystems satisfy Criterion 3 of the NRC Policy Statement (Ref. 2).

LCO Two low pressure ECCS injection/spray subsystems are required to be OPERABLE. The low pressure ECCS injection/spray subsystems consist of two CS subsystems and two LPCI subsystems. Each CS subsystem consists of two motor driven pumps, piping, and valves to transfer water from the suppression pool or condensate storage tank (CST) to the reactor pressure vessel (RPV). Each LPCI subsystem consists of one of the two motor driven pumps, piping, and valves to transfer water from the suppression pool to the RPV. Only a single LPCI pump is required per subsystem because of the larger injection capacity in relation to a CS subsystem. In MODES 4 and 5, the RHR System cross tie valves are not required to be closed.

(continued)

SUSQUEHANNA -UNIT 2 TSB5-9RvsoI TS / B 3.5-19 Revision 1

Rev. 2 ECCS-Shutdown B 3.5.2 BASES LCO LPCI subsystems may be aligned for decay heat removal and considered (continued) OPERABLE for the ECCS function, if they can be manually realigned (remote or local) to the LPCI mode and are not otherwise inoperable.

Because of low pressure and low temperature conditions in MODES 4 and 5, sufficient time will be available to manually align and initiate LPCI subsystem operation to provide core cooling prior to postulated fuel uncovery.

APPLICABILITY OPERABILITY of the low pressure ECCS injection/spray subsystems is required in MODES 4 and 5 to ensure adequate coolant inventory and sufficient heat removal capability for the irradiated fuel in .the core in case of an inadvertent draindown of the vessel. Requirements for ECCS OPERABILITY during MODES 1, 2, and 3 are discussed in the Applicability section of the Bases for LCO 3.5.1. ECCS subsystems are not required to be OPERABLE during MODE 5 with the spent fuel storage pool gates removed and the water level maintained at >_22 ft. above the RPV flange. This provides sufficient coolant inventory to allow operator action to terminate the inventory loss prior to fuel uncovery in case of an inadvertent draindown.

The Automatic Depressurization System is not required to be OPERABLE to be OPERABLE during MODES 4 and 5 because the RPV pressure is

• 150 psig, and the CS System and the LPCI subsystems can provide core cooling without any depressurization of the primary system.

The High Pressure Coolant Injection System is not required to be OPERABLE during MODES 4 and 5 since the low pressure ECCS injection/spray subsystems can provide sufficient flow to the vessel.

ACTIONS A.1 and B.1 If any one required low pressure ECCS injection/spray subsystem is inoperable, the inoperable subsystem must be restored to OPERABLE status in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. In this Condition, the remaining OPERABLE subsystem can provide sufficient vessel flooding capability to recover from an inadvertent (continued)

SUSQUEHANNA -UNIT 2T/B520RvsoI TS / B 3.5-20 Revision 1

Rev. 2 ECCS-Shutdown B 3.5.2 BASES ACTIONS A.1 and B.1 (continued)

Vessel draindown. However, overall system reliability is reduced because a single failure in the remaining OPERABLE subsystem concurrent with a vessel draindown could result in the ECCS not being able to perform its intended function. The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time for restoring the required low pressure ECCS injection/spray subsystem to OPERABLE status is based on engineering judgement that considered the remaining available subsystem and the low probability of a vessel draindown event.

With the inoperable subsystem not restored to OPERABLE status in the required Completion Time, action must be immediately initiated to suspend operations with a potential for draining the reactor vessel (OPDRVs) to minimize the probability of a vessel draindown and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended.

C.1, C.2, D.1, D.2, and D.3 With both of the required ECCS injectionlspray subsystems inoperable, all coolant inventory makeup capability may be unavailable. Therefore, actions must immediately be initiated to suspend OPDRVs to minimize the probability of a vessel draindown and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended.

One ECCS injection/spray subsystem must also 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 />.

If at least one low pressure ECCS injection/spray subsystem is not restored to OPERABLE status within the 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time, additional actions are required to minimize any potential fission product release to the environment. This includes ensuring secondary containment is OPERABLE; one standby gas treatment subsystem is OPERABLE; and secondary containment isolation capability (i.e., one isolation valve and associated instrumentation are OPERABLE or other acceptable administrative controls to assure isolation capability) in each secondary containment penetration flow path not isolated and required to be isolated to mitigate radioactivity releases. OPERABILITY may be verified by an administrative check, or by examining logs or other information, to determine whether the components are out of (continued)

SUSQUEHANNA - UNIT 2TSB.21RvsoI TS / B 3.5-21 Revision 1

Rev. 2 ECCS-Shutdown B 3.5.2 BASES ACTIONS C.1, C.2. D.1, D.2, and D.3 (continued)}

service for maintenance or other reasons. It is not necessary to perform the Surveillances needed to demonstrate the OPERABILITY of the components. If, however, any required component is inoperable, then it must be restored to OPERABLE status. In this case, the Surveillance may need to be performed to restore the component to OPERABLE status.

Actions must continue until all required components are OPERABLE.

The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time to restore at least one low pressure ECCS injection/spray subsystem to OPERABLE status ensures that prompt action will be taken to provide the required cooling capacity or to initiate actions to place the plant in a condition that minimizes any potential fission product release to the environment.

SURVEILLANCE REQUIRMENTSSR 3.5.2.1 and SR 3.5.2.2 The minimum water level of 20 ft. 0 inches required for the suppression pool is periodically verified to ensure that the suppression pool will provide adequate net positive suction head (NPSH) for the CS System and LPCI subsystem pumps, recirculation volume, and vortex prevention. With the suppression pool water level less than the required limit, all ECCS injection/spray subsystems are inoperable unless they are aligned to an OPERABLE CST.

When suppression pool level is < 20 ft. 0 inches, the CS System is considered OPEABLE only if it can take suction from the CST, and the CST water level is sufficient to provide the required NPSH for the CS pump. Therefore, a verification that either the suppression pool water level is Ž20 ft. 0 inches or that CS is aligned to take suction from the CST and the CST contains >Ž135,000 gallons of water, equivalent to 49% of capacity, ensures that the CS System can supply at least 135,000 gallons of makeup water to the RPV. However, as noted, only one required CS subsystem may take credit for the CST option during OPDRVs. During OPDRVs, the volume in the CST may not provide adequate makeup if the RPV were completely drained. Therefore, only one CS subsystem is allowed to use the CST. This ensures (continued)

SUSQUEHANNA - UNIT 2 TS /B5-2Rvso2

/ B 3.5-22 Revision 2

Rev. 2 ECCS-Shutdown B 3.5.2 BASES SURVEILLANCE REQUIRMENTSSR 3.5.2.1 and SR 3.5.2.2 (continued) the other required ECOS subsystem has adequate makeup volume.

The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency of these SRs was developed considering operating experience related to suppression pool water level and CST water level variations and instrument drift during the applicable MODES.

Furthermore, the 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-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 suppression pool or CST water level condition.

SR 3.5.2.3, SR 3.5.2.5, SR 3.5.2.6, and SR 3.5.2.7 The Bases provided for SR 3.5.1.1, SR 3.5.1.7, SR 3.5.1.10, and SR 3.5.1.13 are applicable to SR 3.5.2.3, SR 3.5.2.5, SR 3.5.2.6 and SR 3.5.2.7, respectively.

SR 3.5.2.4 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. The 31 day Frequency is appropriate because the valves are operated under procedural control and the probability of their being mispositioned during this time period is low.

In MODES 4 and 5, the RHR System may operate in the shutdown cooling mode to remove decay heat and sensible heat from the reactor. Therefore, RHR valves that are required for LPCI (continued)

SUSQUEHANNA -UNIT 2TSB35-3RvsoI TS / B 3.5-23 Revision 1

Rev. 2 ECCS-Shutdown B 3.5.2 BAS ES SURVEILLANCE SR 3.5.2.4 (continued)

REQUIREMENTS subsystem operation may be aligned for decay heat removal. Therefore, this SR is modified by a Note that allows LPCI subsystems of the RHR System to be considered OPERABLE for the ECCS function if all the required valves in the LPCI flow path can be manually realigned (remote or local) to allow injection into the RPV, and the systems are not otherwise inoperable. This will ensure adequate core cooling if an inadvertent RPV draindown should occur.

• REFERNCES 1. FSAR, Section 6.3.2.

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

SUSQUEHANNA -UNIT2 B2.-4Rvso B 3.5-24 Revision 0

Rev. 12 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 with 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. Certain plant piping systems (e.g., Service Water, RHR Service Water, Emergency Service Water, Feedwater, etc.) penetrate the secondary containment boundary. The intact piping within secondary containment provides a passive barrier which maintains secondary containment requirements. Breaches of these piping systems within secondary containment will be controlled to maintain secondary containment requirements. The secondary containment is divided into Zone I, Zone IIand Zone IlI, each of which must be OPERABLE depending on plant status and the alignment of the secondary containment boundary. Specifically, the Unit I secondary containment boundary can be modified to exclude Zone 11.Similarly, the Unit 2 secondary containment boundary can be modified to exclude Zone I. Secondary containment may consist of only Zone Ill when in MODE 4 or 5 during CORE ALTERATIONS, or during handling of irradiated fuel within the Zone ill secondary containment boundary.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.6-83 TS .- 3Rvso Revision 4

Rev. 12 Secondary Containment B 3.6.4.1 BASES BACKGROUND To prevent ground level exfiltration while allowing the secondary containment (continued) 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 There are two principal accidents for which credit is taken for secondary SAFETY containment OPERABILITY. These are a loss of coolant-accident (LOCA)

ANALYSES (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)

SUSQUEHANNA - UNIT 2 TTS / B 3.6-84

.- 4Rvso Revision 2

" Rev. 12 Secondary Containment B 3.6.4.1 BASES (continued)

APPLICABILITY 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 (OP DRVs),

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 Completion 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.

B.1 and B.2 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.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.6-85 TS .- 5Rvso Revision 4

Rev. 12 Secondary Containment B 3.6.4.1 BASES ACTIONS C.1, C.2, and C.3 (continued)

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 ifthe 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 probability 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 under expected wind conditions. Expected wind conditions are defined as sustained wind speeds of less than or equal to 16 mph at the 60m meteorological tower or less than or equal to 11 mph at the 10Om meteorological tower ifthe 60m tower wind speed is not available.

Changes in indicated reactor building differential pressure observed during periods of short-term wind speed gusts above these sustained speeds do not by themselves impact secondary containment integrity. However, if secondary containment integrity is known to be compromised, the LCO must be entered regardless of wind speed.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.6-86 TS .- 6Rvso Revision 2

Rev. 12 Secondary Containment B 3.6.4.1 BASES 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, removable 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.

Maintaining secondary containment OPERABILITY requires verifying one door in each access opening to secondary containment zones is closed.

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 Ill 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 Ill hatches and/or dampers are open to the railroad access shaft. When the railroad bay door (No. 101) is open; all Zone I and Ill 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 Ill.

(continued)

SUSQUEHANNA - UNIT22Sl .- 7Rvso TS / B 3.6-87 Revision 2

Rev. 12 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 required 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)

SUSQUEHANNA -UNIT 2TSIB368aRvso3 TS / B 3.6-87a Revision 3

Rev. 12 Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.4 and SR 3.6.4.1.5 REQUIREMENTS (continued) 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 containment boundary.

This is confirmed by demonstrating that one SGT subsystem will draw down the secondary containment to _>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 (CFM)

CONTAINMENT (SR 3.6.4.1.4 (SR 3.6.4.1.5 TEST CONFIGURATION ACCEPTANCE CRITERIA) ACCEPTANCE CRITERIA)

Group 1 Zones I, II and III (Unit 1 <*300 Seconds < 5400 CFM Railroad Bay aligned to (Zones 1,II, and III) (From Zones 1,I1,and IlI)

Secondary Containment).

Zones II and Ill (Unit 1 *<300 Seconds

• 4000 CFM Railroad Bay aligned to (Zones Il and Ill) (From Zones IIand Ill)

Zone Ill).

Group 2 Zones I, II and Ill (Unit 1 < 300 Seconds < 5300 CFM Railroad Bay not aligned to (Zones 1,II, and III) (From Zones 1,11,and III)

Secondary Containment).

Zones II and Ill (Unit 1 <*300 Seconds < 3900 CFM Railroad Bay not aligned to (Zones IIand III) (From Zones IIand Ill)

SecondaryContainment). ___________________

Only one of the above listed configurations needs to be tested to confirm secondary containment OPERABILITY.

(continued)

SUSQUEHANNA- UNIT 2TSB36-8Rvso6TS / B 3.6-88 Revision 6

Rev. 12 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.

The secondary containment testing configurations are discussed in further detail to ensure the appropriate configurations are tested,- Three zone testing (Zones, I,11 and Ill aligned to the recirculation plenum) should be performed with the Railroad Bay aligned to secondary containment and another test with the Railroad Bay not aligned to secondary containment.

Each test should be performed with each division on a STAGGERED TEST BASIS.

Two zone testing (Zones IIand Ill aligned to the recirculation plenum) should be performed with the Railroad Bay aligned to secondary containment and another test with the Railroad Bay not aligned to secondary containment.

Each test should be performed with each division on a STAGGERED TEST BASIS. The normal operating fans of the non-tested HVAC zone (Zone I fans 1V202A&B, 1V205A&B and 1V206A&B) should not be in operation.

Additionally, a controlled opening of adequate size should be maintained in Zone I Secondary Containment during testing to assure that atmospheric conditions are maintained in that zone.

The Unit 1 Railroad Bay can be aligned as a No Zone (isolated from secondary containment) or as part of secondary containment (Zone I or III).

Due to the different leakage pathways that exist in the Railroad Bay, the Railroad Bay should be tested when aligned to secondary containment and also not aligned to secondary containment. It is preferred to align the Railroad Bay to Zone IIl when testing with the Railroad Bay aligned to secondary containment since Zone Ill is included in all possible secondary containment isolation alignments. Note that when performing the three zone testing (Zones 1,II and Ill aligned to the recirculation plenum) aligning the Railroad Bay to either Zone I or III is acceptable since either zone is part of secondary containment. When performing the Zone II& Ill testing with the Railroad Bay aligned to secondary containment, the Unit 1 Railroad Bay must be aligned to Zone III.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.6-89 TS .- 9Rvso Revision 4

Rev. 12 Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.4 and SR 3.6.4.1.5 (continued)

REQU IREM ENTS 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_

REFERENCES- 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).

(continued)

SUSQUEHANNA -UNIT 2TSIB368aRvso0 TS / B 3.6-89a Revision 0

Nov. 05, 2015 Page 1 of 2 MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2015-44707 USER INFORMATION:

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

TSB2 - TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 08/05/2015 ADD MANUAL TABLE OF CONTENTS DATE: 11/04/2015 CATEGORY: DOCUMENTS TYPE: TSB2 AocD

Nov. 05, 2015 Page 2 of 2 ID: TEXT 3.4.10 ADD: REV: 4 REMOVE: REV:3 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.5.2 ADD: REV: 2 REMOVE: REV:I1 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT 3.6.4.1 REMOVE: REV:II1 ADD: REV: 12 CATEGORY: DOCUMENTS TYPE: TSB2 ID: TEXT LOES ADD: REV: 125 REMOVE: REV:124 ANY DISCREPANCIES WITH THE MATERIAL PROVIDED, CONTACT DCS @ X3107 OR X3136 FOR ASSISTANCE. UPDATES FOR HARDCOPY MANUALS WILL BE DISTRIBUTED WITHIN 3 DAYS IN ACCORDANCE WITH DEPARTMENT PROCEDURES. PLEASE MAKE ALL CHANGES AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX UPON COMPLETION OF UPDATES. FOR ELECTRONIC MANUAL USERS, ELECTRONICALLY REVIEW THE APPROPRIATE DOCUMENTS AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX.

SSES MANUAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL Table Of Contents Issue Date: 11/04/2015 Pr~ocedure Name Rev Issue Date Change ID Change Number TEXT LOES 125 11/ 04/2 015

Title:

LIST OF EFFECTIVE SECTIONS TEXT T0C 22 07/02/2014

Title:

TABLE OF CONTENTS TEXT 2.1.1 5 01/22 /2 015

Title:

SAFETY LIMITS (SLS) REACTOR CORE SLS TEXT 2.1.2 1 10/04/2 007

Title:

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

Title:

LIMITING CONDITION FOR OPERATION (LC0) APPLICABILITY TEXT 3.1.1 1 03/24/2005

Title:

REACTIVITY CONTROL SYSTEMS SHUTDOWN MARGIN (SDM)

TEXT 3.1.2 0 11/18/2002

Title:

REACTIVITY CONTROL SYSTEMS REACTIVITY ANOMALIES TEXT 3.1.3 2 01/19/2009

Title:

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

Title:

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

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS TEXT 3.1.6 3 02/24/2014

Title:

REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Report Date: 11/05/15 Page !

Pagej. of of 8 Report Date: 11/05/15

SS~ES MANUAL Manual Name: TSB2 Manual

Title:

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

Title:

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

Title:

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

Title:

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

TEXT 3.2.2 3 05/06/2009

Title:

POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)

TEXT 3.2.3 2 05/06/2009

Title:

POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE LHGR TEXT 3.3.1.1 5 02/24/2014

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATION TEXT 3.3.1.2 2 01/19/2009

Title:

INSTRUMENTATION SOURCE RANGE MONITOR (SRM) INSTRUMENTATION TEXT 3.3.2.1 3 02/24/2014

Title:

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

Title:

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

Title:

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

Title:

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

Title:

INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATIONW Report Date: 11/05/15 Page2 Page ! of of *~.

Report Date: 11/05/15

SSES MANUAL Manual Name: TSB2 Manual

Title:

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

Title:

INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP (ATWS-RPT) INSTRUMENTATION TEXT 3.3.5.1 5 02/24/2014

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 7 03/31/2014

Title:

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

Title:

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

Title:

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

Title:

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

Title:

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

Title:

REACTOR COOLANT SYSTEM (RCS) RECIRCULATION LOOPS OPERATING TEXT 3.4.2 3 10/23/2013

Title:

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

Title:

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

TEXT 3.4.4 0 11/18/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE Report Date: 11/05/15 Page~

Page

• of of ~

Report Date: 11/05/15

SSES ANI JAI.

Manual Name: TSB2

i"Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.4.5 3 03/10/2010 Titles REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE TEXT 3.4.6 4 02/19/2014

Title:

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

--- Title :_REACT0RCOOLANT SYSTEM_(RCS) RCS*SPECIFIC ACTIVITY __

TEXT 3.4.8 2 03/28/2013

Title:

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

- HOT SHUTDOWN TEXT 3.4.9 103/28/2013

Title:

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

- COLD SHUTDOWN 4 11/04/2015 TEXT 3.4.10

Title:

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

Title:

REACTOR COOLANT SYSTEM (RCS) REACTOR STEAM DOME PRESSURE TEXT 3.5.1 4 07/16/2014

Title:

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

SYSTEM ECCS - OPERATING TEXT 3.5.2 2 11/04/2015

Title:

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

SYSTEM ECCS - SHUTDOWN TEXT 3.5.3 3 02/24/2014

Title:

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

SYSTEM RCIC SYSTEM TEXT 3.6.1.1 5 02/24/2014

Title:

PRIMARY CONTAINMENT TEXT 3.6.1.2 1 05/06/2009

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK Report Date: 11/05/15 Page4 Page A of of 8 Report Date: 11/05/15

SSES M~ANUJAL Manual Name: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.6.1.3 14 07/02/2014

Title:

• CONTAINMYENT SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)

TEXT 3.6.1.4 1 05/06/2009

Title:

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

__-Title:

• CONTAINMENT _SYSTEMSDRYWELLAIR TEMPERATURE -__

TEXT 3.6.1.6 0 11/18/2002

Title:

. CONTAINMENT SYSTEMS SUPPRESSION CHAMBER-T0-DRYWELL VACUU/MBREAKERS TEXT 3.6.2.1 2 12/17/2007

Title:

• CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE TEXT 3.6.2.2 0 11/18/2002 Title : CONTAINMENT SYSTEMS SUPPRESSION POOL WATER LEVEL TEXT 3.6.2.3 1 01/16/2006 Title : CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL COOLING TEXT 3.6.2.4 0 11/18/2002 Title : CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL SPRAY TEXT 3.6.3.1 2 06/13/2006 Title : CONTAINMENT SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS TEXT 3.6.3.2 1 04/18/2005

Title:

• CONTAINMENT SYSTEMS DRYWELL AIR FLOW SYSTEM TEXT 3.6.3.3 1 02/28/2013 Title : CONTAINMENT SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION TEXT 3.6.4.1 12 11/04/2015

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT Report Date: 11/05/15 Pages Page

• of of 8 Report Date: 11/05/15

SSES MANUAL Manual Nanme: TSB2

[,Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.6.4.2 9 04/25/2014 Title* CONTAINMENT SYSTEMS SECONDARY CONTAINMThENT ISOLATION VALVES (SCIVS)

TEXT 3.6,4.3 4 09/21/2006

Title:

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

- Title :_PLANTSYSTEMS_ _RESIDUAL HEAThREMOVAL SERVICEWATER (RHRSWLmSYSTEMANDTHE ULTIMATE HEAT SINK (UBS)

TEXT 3.7.2 2 05/02/2008

Title:

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

Title:

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

Title:

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

Title:

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

Title:

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

Title:

PLANT SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL TEXT 3.7.8 0 05/06/2009

Title:

MAINE TURBINE PRESSURE REGULATION SYSTEM TEXT 3.8.1 9 02/24/2014

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING TEXT 3.8.2 0 11/18/2002

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - SHUTDOWN Report Date: 11/05/15 Page 6 Page of of 88 Report Date: 11/05/15

S.SES MANUITAL Manul Nme: TSB2 Manual

Title:

TECHNICAL SPECIFICATIONS BASES UNIT 2 MANUAL TEXT 3.8.3 4 10/23/2013

Title:

ELECTRICAL POWER SYSTEMS DIESEL FUEL OIL LUBE OIL AND STARTING AIR TEXT 3.8.4 3 01/19/2009

Title:

ELECTRICAL POWER SYSTEMS DC SOURCES - OPERATING TEXT 3.8.5 1 . 12/14/2006

__Title: ELECTRICALPOWERSYSTEMS DC S0lURCES_= SHUTDOWN ____-

TEXT 3.8.6 1 12/14/2006

Title:

ELECTRICAL POWER SYSTEMS BATTERY CELL PARAMETERS TEXT 3.8.7 4 10/05/2005

Title:

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

Title:

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

Title:

REFUELING OPERATIONS REFUELING EQUIPMENT INTERLOCKS TEXT 3.9.2 1 09/01/2010

Title:

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

Title:

REFUELING OPERATIONS CONTROL ROD POSITION TEXT 3.9.4 0 11/18/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/18/2002

Title:

REFUELING OPERATIONS CONTROL ROD OPERABILITY - REFUELING TEXT 3.9.6 1 10/04/2007

Title:

REFUELING OPERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL Report Date: 11/05/15 Page !7 Page of of S Report Date: 11/05/15

S.SES 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 (RER) - HIGH WATER LEVEL TEXT 3.9.8 0 11/18/2002

Title:

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

-Titl :_SPECIAL_ _OPERATIONS- INSERVICELEAK AND HYDROSTAT~IC TESTINGOPERATION TEXT 3.10.2 0 11/18/2002

Title:

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

Title:

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

Title:

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

Title:

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

Title:

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

Title:

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

Title:

SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING Report Date: 11/05/15 Pages Page 8 of of 8 Report Date: 11/05/15

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

Section Title Revision TOC Table of Contents 22 8 2.0 SAFETY LIMITS BASES Page TS I B 2.0-1 2 Pages TS I B 2.0-2 and TS / B 2.0-3 5 Page TS /B 2.0-4 7 Pages TS / 8 2.0-5 through TS I B 2.0-8 1 B 3.0 LCO AND SR APPLICABILITY BASES Page TS /B 3.0-1 1 Pages TS /8B3.0-2 through TS I B 3.0-4 0 Pages TS /8B3.0-5 through TS /8B3.0-7 1 Page TS /8B3.0-8 3 Pages TS / B 3.0-9 through Page TS I B 3.0-1: 2 Page TS /8B3.0-1 Ia 0 Page TS /8B3.0-12 1 Pages TS /8B3.0-13 through TS /8B3.0-1 2 Pages TS /8B3.0-16 and TS /8 3.0- ,,0 B 3.1 REACTIVITY CONTROL BASE  ;*

Pages B 3.1-1 through 8 3.1 *,,.0 Page TS /8B3.1-5 -* *1 Pages TS /8B3.1-6 an 2 Pages B3.1-8 throu *0 Page TS /8B3.1-1 * ,,0 PageTS/B3. I Page TS*/B*1-6 1 Pages 17,through TS /B 3.1-19 0 Pages Oand TS /B 3.1-21 1 o0 P /83.1-25 through TS /8B3.1-27 1 P!i;* TS;/83.1-28 2 P:*;;*e*TS /B 3.1-29 1 Pgs TS / B 3.1-30 through TS / B 3.1-33 0 Pages TS /8B 3.1.34 through TS /8B 3.1-36 1 Page TS /8B3.1-37 2 Page TS /8B3.1-38 3 Pages TS /8B3.1-39 and TS / B 3.1-40 2 Page TS /8B 3.1-40a 0 Page TS /8B3.1-41 1 Page TS / B 3.1-42 2 Revision 125 TS/BLOES-1 SUSQUEHANNA - UNIT-UNIT 22 TS / B LOES-1 Revision 125

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

Section Title Revision Pages TS / B 3.1-43 1 Page TS / B 3.1-44 0 Page TS I B 3.1-45 3 Page TS / B 3.1-46 through TS / B 3.1-49 1 Page TS / B 3.1-50 0 Page TS/!B 3.1-51 3 B 3.2 POWER DISTRIBUTION LIMITS BASES Pages TS / B 3.2-1 and TS / B 3.2-2 2 Page TS / B 3.2-3 4 Page TS / B 3.2-4 *1 Page TS / B 3.2-5 3 Page TS I B 3.2-6 "4

---

Page TS--B 3.2 - - -_- - -3 Pages TS / B 3.2-8 and TS / B 3.2-9 4 Pages TS / B 3.2-10 through TS I B 3.2-12 2 Page TS / B 3.2-13 1 B 3.3 INSTRUMENTATION Pages'TS / B 3.3-1 through TS / B 3.3-4 1 Page TS / B 3.3-5 2 Page TS / B 3.3-6 1 Page TS / B 3.3-7 3 Page TS I B 3.3-8 4 Pages TS I B 3.3-9 through TS / B 3.3-13 3 Page TS / B 3.3-14 4 Pages TS / B 3.3-15 and TS / B 3.3-16 2 Pages TS I B 3.3-17 through TS / B 3.3-21 3 Pages TS I B 3.3-22 through TS / B 3.3-27 2 Page TS / B 3.3-28 3 Page TS / B 3.3-29 4 Pages TS / B 3.3-30 and TS / B 3.3-31 3 Pages TS / B 3.3-32 and TS / B 3.3-33 4 Page TS / B 3.3-34 2 Pages TS / B 3.3-34a and TS / B 3.3-34b I Pages TS l B 3.3.34c and TS / B 3.3-34d 0 Page TS I B 3.3-34e I Pages TS / B 3.3-34f through TS / B 3.3-34i 0 Pages TS l B 3.3-35 and TS / B 3.3-36 2 Pages TS l B 3.3-37 and TS l B 3.3-38 1 LOES-2 Revision 125 TS/B SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-2 Revision 125

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

Section Title Revision Page TS / B 3.3-39 2 Pages TS / B 3.3-40 through TS / B 3.3-43 1 Pages TS / B 3.3-44 through TS / B 3.3-54 3 Pages TS / B 3.3-54a through TS I B 3.3-54d 0 Page TS I B 3.3.54e 1 Page TSI/B 3.3-55 2 Page TS I B 3.3-56 0 Page TS/1$ 3.3-57 1 Page TS / B 3.3-58 0 Page TS / B 3.3-59 1 Page TS / B 3.3-60 0 Page TS / B 3.3-61 1 Pages TS / B 3.3-62 and TS / B 3.3-63 0

....... -Pages TS-/-B 373-64-and-TS I B 3.3-65 .... . .. __ 2 -

Page TS / B 3.3-66 4 Page TS / B 3.3-67 3 Page TS / B 3.3-68 4 Page TS / B 3.3.69 5 Page TS / B3.3-70 4 Page TS I B 3.3-71 3 Pages TS /B 3.3-72 and TS I B 3.3-73 2 Page TS I B 3.3-74 3 Page TS I B 3.3-75 2 Pages TS / B 3.3-75a through TS I B 3.3-75c 6 Pages TS / B 3.3-76 and TS I B 3.3-77 0 Page TSI/B 3.3-78 1 Pages TS / B 3.3-79 through TS I B 3.3-81 0 Page TS / B 3.3-82 1 Page TS / B3.3-83 0 Pages TS / B 3.3-84 and TS I B 3.3-85 1 Page TS / B3.3-86 0 Page TS / B3.3-871 Page TS / B 3.3-88 0 Page TS I B 3.3-89 1 Pages TS I B 3.3-90 and TS I B 3.3-91 0 Pages TS / B 3.3-92 through TS /B 3.3-103 1 Page TS / B 3.3-104 3 Pages TS I B 3.3-105 and TS I B 3.3-106 1 Page TS I B 3.3-107 2 Page TS I B 3.3-108 1 Page TS I B 3.3-109 2 Pages TS /B 3.3-110 through TS/IB 3.3-112 1 Page TS I B 3.3-113 2 Revision 125 TS/BLOES-3 SUSQUEHANNA - UNIT-UNIT 2 2 TS / B LOES-3 Revision 125

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

Section Title Revision Page TS /8B3.3-114 1 Page TS /8B3.3-115 2 Page TS /8B3.3-116 3 Pages TS / B 3.3-117 and TS / B 3.3-118 2 Page TS / B 3.3-119 1 Page TS /8B3.3-120 2 Pages TS / B 3.3-121. and TS /83.3-122 3 Page TS / B3.3-123 1 Page TS /8B3.3-124 2 Page TS / B 3.3-124a 0 Page TS /8B3.3-125 1 Page TS / B3.3-126 2 Page TS / B 3.3-127 "3 Page TS-[-8-3_3-1 ... .. . .... . - 2_

Pages TS / B 3.3-129 through TS / B 3.3-131 1 Page TS /8B3.3-132 2 Pages TS / 8 3.3-133 and TS/B83.3-134 1 Pages TS / B 3.3-135 through TS / B 3.3-137 0 Page TS / B 3.3-138 1 Pages TS / 8 3.3-139 through TSI 83.3-146 0 Pages B 3.3-147 through B 3.3-1 49 0 Page TS /8B3.3-150 1 Pages TS / B 3.3-151 through TS /B 3.3-154 2 Page TS /8B3.3-155 1 Pages TS / B 3.3-156 through TS I B 3.3-158 2 Pages TS / B 3.3-159 through TSI 8 3.3-162 1 Pages TS / B 3.3-163 through TS I B 3.3-166 2 Pages TS / 8 3.3-167 and TS /8B3.3-168 1 Pages TS / 8 3.3-169 and TS /8B3.3-170 3 Pages TS / B 3.3-171 through TS / B 3.3-174 1 Page TS / B 3.3-174a 1 Pages TS/ B 3.3-1 75 through TS/IB 3.3-177 1 Page TS /8B3.3-178 2 Page TS /8B3.3-179 3 Page TS / B 3.3-179a 2 Page TS /8B3.3-180 1 Page TS /8B3.3-181 3 Page TS /8B3.3-182 1 Page TS /8B3.3-183 2 Page TS /8B3.3-184 1.

Page TS /8B3.3-185 4 Page TS / 8 3.3-1 86 1 Pages TS / 8 3.3-187 and TS /83.3-188 2 Pages TS / B 3.3-189 through TS /B 3.3-191 1 Page TS / B83.3-192 0 LOES-4 Revision 125 TS/B SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-4 Revision 125

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

Section Title Revision Page TS / B 3.3-193 I Pages TS I B 3.3-194 and TS / B 3.3-195 0 Page TS / B 3.3-196 2 Pages TS I B 3.3-197 through TS /B 3.3-205 0 Page TS / B 3.3-206 1 Pages B 3.3-207 through B 3.3-209 0 Page TS / B 3.3-210 1 Page TS /B 3.3-211 2 Pages TS / B 3.3-212 and TS I B 3.3-213 1 Pages B 3.3-214 through B 3.3-220 0 B 3.4 REACTOR COOLANT SYSTEM BASES

___Pages TS/B 3_.4_-1 and _TS /8_3.4-2 ___ _- -__2 Pages TS /8B3.4-3 through TS /8B3.4-5 4-,-

Pages TS /8B3.4-6 through TS /8B3.4-9 3 Page TS /8B3.4-10 1 Pages TS /8B3.4-11 and TS /8B3.4-12 0 Page TS / B 3.4-13 2 Page TS /8B3.4-14 1 Page TS/B83.4-15 2 Pages TS /8B3.4-16 and TS /8B3.4-17 4 Page TS /8B3.4-18 2 Pages B 3.4-19 through B 3.4-23 0 Pages TS /8B3.4-24 through TS /8B3.4-27 0 Page TS /8B3.4-28 1 Page TS /8B3.4-29 3 Page TS /8B3.4-30 2 Page TS /8B3.4-31 1 Pages TS /8B3.4-32 and TS /8B3.4-33 2 Page TS / B 3.4-34 1 Page TS / B 3.4-34a 0 Pages TS / B 3.4-35 and TS /8B3.4-36 1 Page TS /B 3.4-37 2 Page B 3.4-38 1 Pages B 3.4-39 and B 3.4-40 0 Page TS /8B3.4-41 2 Pages TS / B 3.4-42 through TSI/B 3.4-45 0 Page TS /8B3.4.4-46 1 Pages TS / B 3.4.4-47 and TS / B 3.4.4-48 0 Page TS /8B 3.4-493 Pages TS /8B3.4-50 and TS / B 3.4-51 2 Page TS /8B3.4-52 3 Page TS / B 3.4-52a 0 Pages TS /8B3.4-53 through TS / B 3.4-56 2 Page TS /8B3.4-57 3 Pages TS / B 3.4-58 through TS / B 3.4-60 1 SUSQUEHANNA - UNIT 2 TS / B LOES-5 Revision 125

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

Section Title Revision B 3.5 ECCS AND RCIC BASES Pages TS / B 3.5-1 and TS I B 3.5-2 1 Pages TS I B 3.5-3 and TS I B 3.5-4 2 Page TS /8B3.5-5 3 Page TS /8B3.5-6 2 Pages TS/I.B 3.5-7 through TS / B 3.5-10 1 Pages TS / B 3.5-11 and TS /8B3.5-12 2 Pages TS / B 3.5-13 and TS /8B3.5-14 1 Pages TS / 8 3.5-15 through TS / 8.3.5-17 3 Pages TS /8B3.5-18 through TS /8B3.5-21 1 Page TS /8B3.5-22 2 Page TS / 8.3.5-23 1

___Page B 3.5-24 0 Page TS /B 3.5-25 1 Pages TS /8B3.5-26 and TS /8B3.5-27 2 Page TS /8B3.5-28 0 Page TS / B 3.5-29 through TS I B 3.5-31 1 B 3.6 CONTAINMENT SYSTEMS BASES Page TS /8B3.6-1 2 Page TS /8B3.6-la 4 Page TS /8B3.6-2 4 Page TS /8B3.6-3 3 Page TS /B 3.6-4 4 Page TS /8B3.6-5 .3 Page TS /8B3.6-6 4 Page TS /B 3.6-6a 4 Page TS /8B 3.6-6b 3 Page TS /8B 3.6-6c 0 Page B 3.6 0 Page TS / 3.6-8 1 Pages B 3.6-9 through 8 3.6-14 0 Page TS /8B3.6-15 4 Page TS /8B 3.6-15a 0 Page TS /8B 3.6-15b 3 Pages TS /8B3.6-16 and TS /8B3.6-17 3 Page TS /8B 3.6-17a 1 Pages TS /8B3.6-18 and TS /8B3.6-19 1 Page TS /8B3.6-20 2 Page TS /8B3.6-21 3 LOES-6 Revision 125 TS/B SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 22 TS / B LOES-6 Revision 125

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

Section Titl__e Revision Pages TS I B 3.6-21a and TS I B 3.6-21b 0 Pages TS / B 3.6-22 and TS I B 3.6-23 2 Pages TS / B 3.6-24 and TS I B 3.6-25 1 Pages TS / B 3.6-26 and TS / B 3.6-27 3 Page TS I B 3.6-28 7 Page TS I B 3.6-29 5 Page TS /B 3.6-29a 0 Page TS / B 3.6-30 2 Page TS / B3.6-31 3 Pages TS / B 3.6-32 and TS / B 3.6-33 2 Page TS / B 3.6-34 1 Pages TS / B 3.6-35 and TS / B 3.6-36 3

__ Page TS /B 3.6-37 ___2 Page TS / B 3.6-38 3 Page TSI/B 3.6-39 7 Page TS / B 3.6-39a I Page TS/1. 3.6-40 1 Pages B 3.6-41 and B 3.6-42 0 Pages TS / B 3.6-43 and TS / B 3.6-44 1 Page TS / B 3.6-45 2 Pages TS / B 3.6-46 through TS / B 3.6-50 1 Page TS / B 3.6-51 2 Pages TS / B 3.6-52 through TS / B 3.6-55 0 Pages TS / B 3.6-56 and TS / B 3.6-57 2 Pages B 3.6-58 through B 3.6-62 0 Pages TS / B 3.6-63 and TS / B 3.6-64 1 Pages B 3.6-65 through B 3.6-68 0 Pages TS / B 3.6-69 through TS / B 3.6-71 1 Page TS I B 3.6-72 2 Pages TS / B 3.6-73 and TS / B 3.6-74 1 Pages B 3.6-75 and B 3.6-76 0 Page TS / B 3.6-77 1 Pages B 3.6-78 and B 3.6-79 0 Page TS / B 3.6-80 1 Pages TS / B 3.6-81 and TS / B 3.6-82 0 Page TS I B 3.6-83 4 Page TS I B 3.6-84 2 Page TS / B 3.6-85 4 Pages TS / B 3.6-86 and TS I B 3.6-87 2 Page TS /8B 3.6-87a 3 Page TSI/B 3.6-88 6 Page TS /8B3.6-89 4 Page TS /8B 3.6-89a 0 LOES-7 Revision 125 TSIB SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-7 Revision 125

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

Section Title Revision Pages TS / B 3.6-90 and TS / B 3.6-91 3 Page TS I B 3.6-92 2 Pages TS / B 3.6-93 through TS / B 3.6-95 1 Page TS / B 3.6-96 2 Page TS / B 3.6-97 1 Page TS / B3.6-98 2 Page TS / B 3.6-99 7 Page TS / B 3.6-99a 6 Page TS I B 3.6-99b 4 Page TS / B 3.6-99c 0 Pages TS / B 3.6-100 and TS / B 3.6-101 1 Pages TS / B 3.6-102 and TS / B 3.6-103 *2 Page TS / B 3.6-104 3 Page TS / B 3.6-105 -2 Page TS / B 3.6-106 3 B 3.7 PLANT SYSTEMS BASES Page TS / B3.7-1 3 Page TS / B 3.7-2 4 Pages TS / B 3.7-3 through TS I B 3.7-5 3 Page TS I B 3.7-5a 2 Page TS/B 3.7.-6 4 Page TSI!B 3.7-6a 3 Page TS / B 3.7-6b 2 Page TSI!B 3.7-6c 3 Page TS / B 3.7-7 3 Page TS I B 3.7-8 2 Pages B 3.7-9 through B 3.7-11 0 Pages TS / B 3.7-12 and TS I B 3.7-13 2 Pages TS / B 3.7-14 through TS / B 3.7-18 3 Page TS I B 3.7-18a I Pages TS / B 3.7-18B through TS I B 3.7-18E 0 Pages TS / B 3.7-19 through TS / B 3.7-24 1 Pages TS / B 3.7-25 and TS I B 3.7-26 0 Page TSI/B 3.7-27 4 Pages TS / B 3.7-28 and TS / B 3.7-29 3 Pages TS / B 3.7-30 and TS / B 3.7-31 1 Page TS I B 3.7-32 0 Page TSI/B 3.7-33 1 Pages TS / B 3.7-34 through TS / B 3.7-37 0 Revision 125 TS / B LOES-8 SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-8 Revision 125

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

Section Title Revision B 3.8 ELECTRICAL POWER SYSTEMS BASES Page TS / B 3.8-1 1 Pages B 3.8-2 and B 3.8-3 0 Page TS / B 3.8-4 1 Pages TS / B 3.8-4a and TS / B 3.8-4b 0 Pages TS / B 3.8-5 and TS / B 3.8-6 3 Page TS / B 3.8-6a 1 Pages B 3.8-7 and B 3.8-8 0 Page TS / B 3.8-9 2 Pages TS / B 3.8-10 and TS / B 3.8-11 1 Pages B 3.8-12 through B 3.8-18 0 Page TS / B 3.8-19 1 Pages B 3.8-20 through B 3.8-22 .... 0 Page TS / B 3.8-23 1 Page B 3.8-24 0 Pages TS / B 3.8-25 and TS I B 3.8-26 1 Pages B 3.8-27 through B 3.8-30 0 Page TS I B 3.8-31 1 Pages TS / B 3.8-32 through TS / B 3.8-35 0 Page TS I B 3.8-36 1 Page TS I B 3.8-37 0 Page TS / B 3.8-38 1 Pages B 3.8-39 through B 3.8-46 0 Page TS / B 3.8-47 3 Pages TS / B 3.8-48 through TS / B 3.8-50 0 Pages TS / B 3.8-51 and TS / B 3.8-52 3 Page TS / B 3.8-53 1 Page TS / B 3.8-54 0 Page TS / B 3.8-55 1 Pages TS / B 3.8-56 through TS I B 3.8-59 2 Pages TS / B 3.8-60 through TS / B 3.8-64 3 Page TS I B 3.8-65 4 Page TS / B3.8-66 5 Pages TS / B 3.8-67 and TS I B 3.8-68 4 Page TS I B 3.8-69 5 Pages TS / B 3.8-70 through TS / B 3.8-83 1 Pages TS I B 3.8-83A through TS I B 3.8-830 0 Pages B 3.8-84 through B 3.8-85 0 Page TS / B 3.8-86 1 Page TS / B 3.8-87 2 Pages TS / B 3.8-88 and TS I B 3.8-89 1 Page TS I B 3.8-90 2 Pages TS / B 3.8-91 through TS / B 3.8-93 1 Pages B 3.8-94 through B 3.8-99 0.

LOES-9 Revision 125 2 TSIB SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 TS / B LOES-9 Revision 125

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

Section. Title Revision B 3.9 REFUELING OPERATIONS BASES Pages TS / B 3.9-1 and TS / B 3.9-2 1 Page TS I B 3.9-2a I Pages TS / B 3.9-3 through TS I B 3.9-5 1 Pages TS /8B3.9-6 through TS I B 3.9-8 0 Pages B 3.9-9 through B 3.9-18 0 Pages TS /8B3.9-19 through TS /8B3.9-21 1 Pages B 3.9-22 through B 3.9-30 0 8 3.10 SPECIAL OPERATIONS BASES Page TS /8B3.10-1 *2

___Pages TS / B 3.10-2 through TSL/B 3.10-5 __ 1 Pages 8 3.10-6 through 8 3.10-32 0 Page TS /8B3.10-33 2 Page B 3.10-34 0 Page TS /8B3.10-35 1 Pages B 3.10-36 and B 3.10-37 0 Page TS /8B3.10-38 1 Page TS / 8 3.10-39 2 Revision 125 TS I B LOES-lO SUSQUEHANNA - UNIT SUSQUEHANNA -

UNIT 2 2 TS / B LOES-10 Revision 125

Rev. 4 RCS P/T Limits B 3.4.10 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.10 RCS Pressure and Temperature (PIT) Limits BASES BACKGROUND All components of the RCS are designed to withstand effects of cyclic loads due to system pressure and temperature changes. These loads are introduced by startup (heatup) and shutdown (cooldown) operations, power transients, and reactor trips. This LCO limits the pressure and temperature changes during RCS heatup and cooldown, within the design assumptions and the stress limits for cyclic operation.

~This Specification contains P/T" limit curves for heatup, cooldown, and inservice leakage and hydrostatic testing, and limits for the maximum rate of

...... ....- change-of-reactor coolant-temperature. The heatup curve provides limits for

• both heatup and criticality.

Each P/T limit curve defines an acceptable region for normal operation. The usual use of the curves is operational guidance during heatup or cooldown maneuvering, when pressure and temperature indications are monitored and compared to the applicable curve to determine that operation is within the allowable region.

The LCO establishes operating limits that provide a margin to brittle failure of the reactor vessel and piping of the reactor coolant pressure boundary (RCPB). The vessel is the component most subject to brittle failure.

Therefore, the LCO limits apply mainly to the vessel.

10 CFR 50, Appendix G (Ref. 1), requires the establishment of P/T limits for material fracture toughness requirements of the RCPB materials.

Reference I requires an adequate margin to brittle failure during normal operation, anticipated operational occurrences, and system hydrostatic tests.

It mandates the use of the ASME Code, Section Xl, Appendix G (Ref. 2).

The actual shift in the RTNDT of the vessel material will be established periodically by removing and evaluating the irradiated reactor vessel material specimens, in accordance with ASTM E 185 (Ref. 3) and Appendix H of 10 CFR 50 (Ref. 4). The operating P/l" limit curves will be adjusted, as necessary, based on the evaluation findings and the recommendations of RG 1.99, "Radiation Embrittlement of Reactor Vessel Materials (Ref. 5).

The calculations to determine neutron fluence will be developed using the BWRVIP RAMA code methodology, which is NRC approved and meets the intent of RG 1.190, "Calculational and Dosimetry Methods for Determining Pressure Vessel Neutron Fluence" (Ref. 11). See FSAR Section 4.1.4.5 for determining fluence (Ref. 12).

(continued)

SUSQUEHANNA -UNIT 2 T / B 3.4-49 TS .- 9Rvso Revision 3

Rev. 4 RCS P/T" Limits B 3.4.10 BASES BACKGROUND The P/T limit curves are composite curves established by superimposing (continued) limits derived from stress analyses of those portions of the reactor vessel and head that are the most restrictive. At any specific pressure, temperature, and temperature rate of change, one location within the reactor vessel will dictate the most restrictive limit. Across the span of the P/T limit curves, different locations are more restrictive, and, thus, the curves are composites of the most restrictive regions.

The heatup curve used to develop the P/T limit curve composite represents a different set of restrictions than the cooldown curve used to develop the P/T limit curve composite because the directions of the thermal gradients through the vessel wall are reversed. The thermal gradient reversal alters the location of the tensile stress between the outer and inner walls.

The criti~lity limits incluide th* R~fer-n-ce- 1 requi~rnentth~t-th-ey be at le~t 40°F above the heatup curve or the cooldown curve and not lower than the minimum permissible temperature for the inservice leakage and hydrostatic testing.

The consequence of violating the LCO limits is that the RCS has been operated under conditions that can result in brittle failure of the RCPB, possibly leading to a nonisolable leak or loss of coolant accident. In the event these limits are exceeded, an evaluation must be performed to determine the effect on the structural integrity of the RCPB components.

ASME Code, Section Xl, Appendix E (Ref. 6), provides a recommended methodology for evaluating an operating event that causes an excursion outside the limits.

APPLICABLE The P/T limits are not derived from Design Basis Accident (DBA) analyses.

SAFETY They are prescribed during normal operation to avoid encountering pressure, ANALYSES temperature, and temperature rate of change conditions that might cause undetected flaws to propagate and cause nonductile failure of the RCPB, a condition that is unanalyzed. Reference 7 establishes the methodology for determining the P/T limits. Since the P/T limits are not derived from any DBA, there are no acceptance limits related to the P/T limits. Rather, the P/T limits are acceptance limits themselves since they preclude operation in an unanalyzed condition.

RCS P/T limits satisfy Criterion 2 of the NRC Policy Statement (Ref. 8).

The Effective Full Power Years (EFPY) shown on the curves are approxi-mations of the ratio of the energy that has been and is anticipated to be generated in a year to the energy that could have been generated ifthe unit ran at original thermal power rating of 3293 MWT for the entire year.

These values are based on fluence limits that are not to be exceeded.

(continued)

SUSQUEHANNA - UNIT 2TSIB345 TS / B 3.4-50 Revision 2

Rev. 4 RCS PIT Limits B 3.4.10 BASES. (continued)

LCO The elements of this LCO are:

a. RCS pressure and temperature are to the right of the applicable curves specified in Figures 3.4.10-1 through 3.4.10-3 and within the applicable heat-up or cool down rate specified in SR 3.4.10.1 during RCS heatup, cooldown, and inservice leak and hydrostatic testing;

b. The temperature difference between the reactor vessel bottom head coolant and the reactor pressure vessel (RPV) coolant is < 145°F during recirculation pump startup, and during increases in THERMAL POWER or loop flow while operating at low THERMAL POWER or loop flow;

c. -The-temperature difference between-the reactor-coolant-in-the respective---.

recirculation loop and in the reactor vessel is _< 50°F during recirculation pump startup, and during increases in THERMAL POWER or loop flow while operating at low THERMAL POWER or loop flow;

d. RCS pressure and temperature are to the right of the criticality limits specified in Figure 3.4.10-3 prior to achieving criticality; and

e. The reactor vessel flange and the head flange temperatures are >_700 F when tensioning the reactor vessel head bolting studs.

These limits define allowable operating regions and permit a large number of operating cycles while also providing a wide margin to nonductile failure.

The PIT limit composite curves are calculated using the worst case of material properties, stresses, and temperature change rates anticipated under all heatup and cooldown conditions. The design calculations account for the reactor coolant fluid temperature impact on the inner wall of the vessel and the temperature gradients through the vessel wall. Because these fluid temperatures drive the vessel wall temperature gradient, monitoring reactor coolant temperature provides a conservative method of ensuring the PIT limits are not exceeded. Proper monitoring of vessel temperatures to assure compliance with brittle fracture temperature limits and vessel thermal stress limits during normal heatup and cooldown, and during inservice leakage and hydrostatic testing, is established in PPL Calculation EC 062-0573 (Ref. 9). For PIT curves A, B, and C, the bottom head drain line coolant temperature should be monitored and maintained to the right of the most limiting curve.

(continued)

SUSQUEHANNA - UNIT 2 Sl34-1Rvso2 TS / B 3.4-51 Revision 2

Rev. 4 RCS P/T Limits B 3.4.10 BASES LCO Curve A must be used for any ASME Section III Design Hydrostatic Tests (continued) performed at unsaturated reactor conditions. Curve A may also be used for ASME Section Xl inservice leakage and hydrostatic testing when heatup and cooldown rates can be limited to 20°F in a one-hour period.

Curve A is based on pressure stresses only. Thermal stresses are assumed to be insignificant. Therefore, heatup and cooldown rates are limited to 20°F in a one-hour period when using Curve A to ensure minimal thermal stresses. The recirculation loop suction line temperatures should be monitored to determine the temperature change rate.

Curves B and C are to be used for non-nuclear and nuclear heatup and cooldown, respectively. In addition, Curve B may be used for ASME Section Xl inservice leakage and hydrostatic testing, but not for ASME Section III DesignHydrostatic Tests Performed at u~nsa~turated_ re~actor con~diti~ons._.

Heatup and cooldown rates are limited to 100°F in a one-hour period when using Curves B and C. This limits the thermal gradient through the vessel wall, which is used to calculate the thermal stresses in the vessel wall. Thus, the LCO for the rate of coolant temperature change limits the thermal stresses and ensures the validity of the P/T curves. The vessel belt-line fracture analysis assumes a 100°F/hr coolant heatup or cooldown rate in the beltline area. The 100°F limit in a one-hour period applies to the coolant in the beltline region, and takes into account the thermal inertia of the vessel wall. Steam dome saturation temperature (TSAT), as derived from steam dome pressure, should be monitored to determine the beltline temperature change rate at temperatures above 212°F. At temperatures below 212°F, the recirculation loop suction line temperatures should be monitored.

During heatups and cooldowns, the reactor vessel could experience a vacuum (negative pressure) at low temperatures (unsaturated conditions) and low rates of temperature change. Under a vacuum, the vessel wall would experience a uniform compressive loading, which would counteract the tensile stress due to any thermal gradients through the vessel wall. To ensure the margin to brittle fracture is no less than at any other pressure, Curves A, B, and C require a minimum vessel metal temperature of 70°F when the reactor vessel is at a negative pressure.

(continued)

SUSQUEHANNA - UNIT 2 TI345 TS / B 3.4-52 Revision 3

Rev. 4 RCS P/T Limits B 3.4.10 BASES LCD Violation of the limits places the reactor vessel outside of the bounds of the (continued) stress analyses and can increase stresses in other RCS components. The consequences depend on several factors, as follows:

a. The severity of the departure from the allowable operating pressure temperature regime or the severity of the rate of change of temperature;

b. The length of time the limits were violated (longer violations allow the temperature gradient in the thick vessel walls to become more pronounced); and

c. The existences, sizes, and orientations of flaws in the vessel material.

APPLICABILITY The potential for violating a P/T limit exists at all times. For example, P/T limit violations could result from ambient temperature conditions that result in the reactor vessel metal temperature being less than the minimum allowed temperature for boltup. Therefore, this LCO is applicable even when fuel is not loaded in the core.

ACTIONS A.1 and A.2 Operation outside the P/l" limits while in MODES 1, 2, and 3 must be corrected so that the RCPB is returned to a condition that has been verified by stress analyses.

The 30 minute Completion Time reflects the urgency of restoring the parameters to within the analyzed range. Most violations will not be severe, and the activity can be accomplished in this time in a controlled manner.

Besides restoring operation within limits, an evaluation is required to determine if RCS operation can continue. The evaluation must verify the RCPB integrity remains acceptable and must be completed if continued operation is desired. Several methods may be used, including comparison with pre-analyzed transients in the stress analyses, new analyses, or inspection of the components.

(continued)

SUSQUEHANNA - UNIT 2TS/B345aRvso0 TS / B 3.4-52a Revision 0

Rev. 4 RCS PIT" Limits B 3.4.10 BASES ACTIONS A.1 and A.2 (continued).

ASME Code, Section Xl, Appendix E (Ref. 6), may be used to support the evaluation. However, its use is restricted to evaluation of the vessel beitline.

The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time is reasonable to accomplish the evaluation of a mild violation. More severe violations may require special, event specific stress analyses or inspections. A favorable evaluation must be completed if continued operation is desired.

Condition A is modified by a Note requiring Required Action A.2 be

• completed whenever the Condition is entered. The Note emphasizes the

-- -___ -- need to-perform the evaluation of-the-effects of the excursion-outside the -

allowable limits. Restoration alone per Required Action A. 1 is insufficient because higher than analyzed stresses may have occurred and may have affected the RCPB integrity.

B.I and B.2 If a Required Action and associated Completion Time of Condition A are not met, the plant must be placed in a lower MODE because either the RCS remained in an unacceptable PIT region for an extended period of increased stress, or a sufficiently severe event caused entry into an unacceptable region. Either possibility indicates a need for more careful examination of the event, best accomplished with the RCS at reduced pressure and temperature. With the reduced pressure and temperature conditions, the possibility of propagation of undetected flaws is decreased.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.4-53 TS .- 3Rvso Revision 2

Rev. 4 RCS P/T Limits B 3.4.10 BASES ACTIONS B.1 and B.2 (continued)

Pressure and temperature are reduced by placing the plant in at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

C.1 and C.2 Operation outside the PIT limits in other than MODES 1, 2, and 3 (including defueled conditions) must be corrected so that the RCPB is returned to a condition that has been verified by stress analyses. The Required Action must be initiated without delay and continued until the limits are restored.

Besides restoring the PIT limit parameters to within limits, an evaluation is required to determine if RCS operation is allowed. This evaluation must verify that the RCPB integrity is acceptable and must be completed before approaching criticality or heating up to > 200°F. Several methods may be used, including comparison with pre-analyzed transients, new analyses, or inspection of the components. ASME Code, Section Xl, Appendix E (Ref. 6),

may be used to support the evaluation; however, its use is restricted to evaluation of the beltline.

SURVEILLANCE SR 3.4.10.1 REQUIREMENTS Verification that operation is within limits (i.e., to the right of the applicable curves in Figures 3.4.10-1 through 3.4.10-3) is required every 30 minutes when RCS pressure and temperature conditions are undergoing planned changes. This Frequency is considered reasonable in view of the control room indication available to monitor RCS status. Also, since temperature rate of change limits are specified in hourly increments, 30 minutes permits a reasonable time for assessment and correction of minor deviations.

Surveillance for heatup, cooldown, or inservice leakage and hydrostatic testing may be discontinued when the criteria given in the relevant plant procedure for ending the activity are satisfied.

This SR has been modified with a Note that requires this Surveillance to be performed only during system heatup and cooldown operations and inservice leakage and hydrostatic testing.

Notes to the acceptance criteria for heatup and cooldown rates ensure that more restrictive limits are applicable when the PIT"limits associated with hydrostatic and inservice testing are being applied.

(continued)

SUSQUEHANNA - UNIT 2TS34-4Rvso2TS / B 3.4-54 Revision 2

Rev. 4 RCS P/T" Limits B 3.4.10 BASES SURVEILLANCE SR 3.4.10.2 REQUIREMENTS (continued) A separate limit is used when the reactor is approaching criticality.

Consequently, the RCS pressure and temperature must be verified within the appropriate limits (i.e., to the right of the criticality curve in Figure 3.4.10-3) before withdrawing control rods that will make the reactor critical.

Performing the Surveillance within 15 minutes before control rod withdrawal for the purpose of achieving criticality provides adequate assurance that the limits will not be exceeded between the time of the Surveillance and the time of reactor criticality. Although no Surveillance Frequency is specified, the requirements of SR 3.4.10.2 must be met at all times when the reactor is critical.

SR 3.4.10.3 and SR 3.4.10.4 Differential temperatures within the applicable limits ensure that thermal stresses resulting from the startup of an idle recirculation pump will not exceed design allowances. In addition, compliance with these limits ensures that the assumptions of the analysis for the startup of an idle recirculation loop (Ref. 10) are satisfied.

Performing the Surveillance within 15 minutes before starting the idle recirculation pump provides adequate assurance that the limits will not be exceeded between the time of the Surveillance and the time of the idle pump start.

An acceptable means of demonstrating compliance with the temperature differential requirement in SR 3.4.10.4 is to compare the temperatures of the operating recirculation loop and the idle loop. If both loops are idle, compare the temperature difference between the reactor coolant within the idle loop to be started and coolant in the reactor vessel.

SR 3.4.10.3 has been modified by a Note that requires the Surveillance to be performed only in MODES 1, 2, 3, and 4. In MODE 5, the overall stress on limiting components is lower. Therefore, AT limits are not required. The Note also states the SR is only required to be met during a recirculation pump start-up, because this is when the stresses occur.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.4-55 TS .- 5Rvso Revision 2

Rev. 4 RCS P/I- Limits B 3.4.10 BASES SURVEILLANCE SR 3.4.10.5 and SR 3.4.10.6 REQUIREMENTS (continued) Differential temperatures within the applicable limits ensure that thermal stresses resulting from increases in THERMAL POWER or recirculation loop flow during single recirculation loop operation will not exceed design allowances. Performing the Surveillance within 15 minutes before beginning such an increase in power or flow rate provides adequate assurance that the limits will not be exceeded between the time of the Surveillance and the time of the change in operation.

An acceptable means of demonstrating compliance with the temperature differential requirement in SR 3.4.10.6 is to compare the temperatures of the operating recirculation loop and the idle loop.

- -Plant SlS*ific startup test data t~s-determined that the bottom head is not subject to temperature stratification at power levels > 27% of RTP and with single loop flow rate > 21,320 gpm (50% of rated loop flow). Therefore, SR 3.4.10.5 and SR 3.4.10.6 have been modified by a Note that requires the Surveillance to be met only under these conditions. The Note for SR 3.4.10.6 further limits the requirement for this Surveillance to exclude comparison of the idle loop temperature ifthe idle loop is isolated from the RPV since the water in the loop can not be introduced into the remainder of the Reactor Coolant System.

SR 3.4.10.7, SR 3.4.10.8. and SR 3.4.10.9 Limits on the reactor vessel flange and head flange temperatures are generally bounded by the other P/T limits during system heatup and cooldown. However, operations approaching MODE 4 from MODE 5 and in MODE 4 with RCS temperature less than or equal to certain specified values require assurance that these temperatures meet the LCO limits.

The flange temperatures must be verified to be above the limits 30 minutes before and while tensioning the vessel head bolting studs to ensure that once the head is tensioned the limits are satisfied. When in MODE 4 with RCS temperature _< 80°F, 30 minute checks of the flange temperatures are required because of the reduced margin to the limits. When in MODE 4 with RCS temperature __100°F, monitoring of the flange temperature is required every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> to ensure the temperature is within the specified limits.

The 30 minute Frequency reflects theurgency of maintaining the temperatures within limits, and also limits the time that the temperature limits could be exceeded. The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency is reasonable based on the rate of temperature change possible at these temperatures.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.4-56 TS .- 6Rvso Revision 2

Rev. 4 RCS P/T Limits B 3.4.10 BASES (continued )

REFERENCES 1. 10 CFR 50, Appendix G.

2. ASME, Boiler and Pressure Vessel Code,Section XI, Appendix G.

3. ASTM E 185-73

4. 10 CFR 50, Appendix H.

5. Regulatory Guide 1.99, Revision 2, May 1988.

6. ASME, Boiler and Pressure Vessel Code, Section Xl, Appendix E.

7. Licensed Topical Reports:

a. Structural Integrity Associates Report No. SIR-05-044, Revision 1-A, "Pressure-Temperature Limits Report Methodology for Boiling Water Reactors," June 2013.

b. Structural Integrity Associates Report No. 0900876.401, Revision 0-A, "Linear Elastic Fracture Mechanics Evaluation of GE BWR Water Level Instrument Nozzles for Pressure-Temperature Curve Evaluations," May 2013.

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

9. PPL Calculation EC-062-0573, "Study to Support the Bases Section of Technical Specification 3.4.10."

10. FSAR, Section 15.4.4.

11. Regulatory Guide 1.190, March 2001.

12 FSAR, Section 4.1.4.5.

SUSQUEHANNA -UNIT 2 T / B 3.4-57 TS .- 7Rvso Revision 3

Rev. 2 ECCS-Shutdown B 3.5.2 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM B 3.5.2 ECCS-Shutdown BASES BACKGROUND A description of the Core Spray (CS) System and the Low Pressure Coolant Injection (LPCI) mode of the Residual Heat Removal (RHR)

System is provided in the Bases for LCO 3.5.1, "ECCS-Operating."

APPLICABLE The ECCS performance is evaluated for the entire spectrum of break SAFETY sizes for-a postulated loss of coolant accident- (LOCA). -The long term A NA LYS ES cooling analysis following a design basis LOCA (Reference 1) demonstrates that only one low pressure ECCS injection /spray subsystem is required, post LOCA, to maintain adequate reactor vessel water level in the event of an inadvertent vessel draindown. It is reasonable to assume, based on engineering judgement, that while in MODES 4 and 5, one low pressure ECCS injection/spray subsystem can maintain adequate reactor vessel water level. To provide redundancy, a minimum of two low pressure ECCS injection/spray subsystems are required to be OPERABLE in MODES 4 and 5.

The low pressure ECCS subsystems satisfy Criterion 3 of the NRC Policy Statement (Ref. 2).

LCO Two low pressure ECCS injection/spray subsystems are required to be OPERABLE. The low pressure ECCS injection/spray subsystems consist of two CS subsystems and two LPCI subsystems. Each CS subsystem consists of two motor driven pumps, piping, and valves to transfer water from the suppression pool or condensate storage tank (CST) to the reactor pressure vessel (RPV). Each LPCI subsystem consists of one of the two motor driven pumps, piping, and valves to transfer water from the suppression pool to the RPV. Only a single LPCI pump is required per subsystem because of the larger injection capacity in relation to a CS subsystem. In MODES 4 and 5, the RHR System cross tie valves are not required to be closed.

(continued)

SUSQUEHANNA -UNIT 2 TSB5-9RvsoI TS / B 3.5-19 Revision 1

Rev. 2 ECCS-Shutdown B 3.5.2 BASES LCO LPCI subsystems may be aligned for decay heat removal and considered (continued) OPERABLE for the ECCS function, if they can be manually realigned (remote or local) to the LPCI mode and are not otherwise inoperable.

Because of low pressure and low temperature conditions in MODES 4 and 5, sufficient time will be available to manually align and initiate LPCI subsystem operation to provide core cooling prior to postulated fuel uncovery.

APPLICABILITY OPERABILITY of the low pressure ECCS injection/spray subsystems is required in MODES 4 and 5 to ensure adequate coolant inventory and sufficient heat removal capability for the irradiated fuel in .the core in case of an inadvertent draindown of the vessel. Requirements for ECCS OPERABILITY during MODES 1, 2, and 3 are discussed in the Applicability section of the Bases for LCO 3.5.1. ECCS subsystems are not required to be OPERABLE during MODE 5 with the spent fuel storage pool gates removed and the water level maintained at >_22 ft. above the RPV flange. This provides sufficient coolant inventory to allow operator action to terminate the inventory loss prior to fuel uncovery in case of an inadvertent draindown.

The Automatic Depressurization System is not required to be OPERABLE to be OPERABLE during MODES 4 and 5 because the RPV pressure is

• 150 psig, and the CS System and the LPCI subsystems can provide core cooling without any depressurization of the primary system.

The High Pressure Coolant Injection System is not required to be OPERABLE during MODES 4 and 5 since the low pressure ECCS injection/spray subsystems can provide sufficient flow to the vessel.

ACTIONS A.1 and B.1 If any one required low pressure ECCS injection/spray subsystem is inoperable, the inoperable subsystem must be restored to OPERABLE status in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. In this Condition, the remaining OPERABLE subsystem can provide sufficient vessel flooding capability to recover from an inadvertent (continued)

SUSQUEHANNA -UNIT 2T/B520RvsoI TS / B 3.5-20 Revision 1

Rev. 2 ECCS-Shutdown B 3.5.2 BASES ACTIONS A.1 and B.1 (continued)

Vessel draindown. However, overall system reliability is reduced because a single failure in the remaining OPERABLE subsystem concurrent with a vessel draindown could result in the ECCS not being able to perform its intended function. The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time for restoring the required low pressure ECCS injection/spray subsystem to OPERABLE status is based on engineering judgement that considered the remaining available subsystem and the low probability of a vessel draindown event.

With the inoperable subsystem not restored to OPERABLE status in the required Completion Time, action must be immediately initiated to suspend operations with a potential for draining the reactor vessel (OPDRVs) to minimize the probability of a vessel draindown and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended.

C.1, C.2, D.1, D.2, and D.3 With both of the required ECCS injectionlspray subsystems inoperable, all coolant inventory makeup capability may be unavailable. Therefore, actions must immediately be initiated to suspend OPDRVs to minimize the probability of a vessel draindown and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended.

One ECCS injection/spray subsystem must also 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 />.

If at least one low pressure ECCS injection/spray subsystem is not restored to OPERABLE status within the 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time, additional actions are required to minimize any potential fission product release to the environment. This includes ensuring secondary containment is OPERABLE; one standby gas treatment subsystem is OPERABLE; and secondary containment isolation capability (i.e., one isolation valve and associated instrumentation are OPERABLE or other acceptable administrative controls to assure isolation capability) in each secondary containment penetration flow path not isolated and required to be isolated to mitigate radioactivity releases. OPERABILITY may be verified by an administrative check, or by examining logs or other information, to determine whether the components are out of (continued)

SUSQUEHANNA - UNIT 2TSB.21RvsoI TS / B 3.5-21 Revision 1

Rev. 2 ECCS-Shutdown B 3.5.2 BASES ACTIONS C.1, C.2. D.1, D.2, and D.3 (continued)}

service for maintenance or other reasons. It is not necessary to perform the Surveillances needed to demonstrate the OPERABILITY of the components. If, however, any required component is inoperable, then it must be restored to OPERABLE status. In this case, the Surveillance may need to be performed to restore the component to OPERABLE status.

Actions must continue until all required components are OPERABLE.

The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time to restore at least one low pressure ECCS injection/spray subsystem to OPERABLE status ensures that prompt action will be taken to provide the required cooling capacity or to initiate actions to place the plant in a condition that minimizes any potential fission product release to the environment.

SURVEILLANCE REQUIRMENTSSR 3.5.2.1 and SR 3.5.2.2 The minimum water level of 20 ft. 0 inches required for the suppression pool is periodically verified to ensure that the suppression pool will provide adequate net positive suction head (NPSH) for the CS System and LPCI subsystem pumps, recirculation volume, and vortex prevention. With the suppression pool water level less than the required limit, all ECCS injection/spray subsystems are inoperable unless they are aligned to an OPERABLE CST.

When suppression pool level is < 20 ft. 0 inches, the CS System is considered OPEABLE only if it can take suction from the CST, and the CST water level is sufficient to provide the required NPSH for the CS pump. Therefore, a verification that either the suppression pool water level is Ž20 ft. 0 inches or that CS is aligned to take suction from the CST and the CST contains >Ž135,000 gallons of water, equivalent to 49% of capacity, ensures that the CS System can supply at least 135,000 gallons of makeup water to the RPV. However, as noted, only one required CS subsystem may take credit for the CST option during OPDRVs. During OPDRVs, the volume in the CST may not provide adequate makeup if the RPV were completely drained. Therefore, only one CS subsystem is allowed to use the CST. This ensures (continued)

SUSQUEHANNA - UNIT 2 TS /B5-2Rvso2

/ B 3.5-22 Revision 2

Rev. 2 ECCS-Shutdown B 3.5.2 BASES SURVEILLANCE REQUIRMENTSSR 3.5.2.1 and SR 3.5.2.2 (continued) the other required ECOS subsystem has adequate makeup volume.

The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency of these SRs was developed considering operating experience related to suppression pool water level and CST water level variations and instrument drift during the applicable MODES.

Furthermore, the 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-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 suppression pool or CST water level condition.

SR 3.5.2.3, SR 3.5.2.5, SR 3.5.2.6, and SR 3.5.2.7 The Bases provided for SR 3.5.1.1, SR 3.5.1.7, SR 3.5.1.10, and SR 3.5.1.13 are applicable to SR 3.5.2.3, SR 3.5.2.5, SR 3.5.2.6 and SR 3.5.2.7, respectively.

SR 3.5.2.4 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. The 31 day Frequency is appropriate because the valves are operated under procedural control and the probability of their being mispositioned during this time period is low.

In MODES 4 and 5, the RHR System may operate in the shutdown cooling mode to remove decay heat and sensible heat from the reactor. Therefore, RHR valves that are required for LPCI (continued)

SUSQUEHANNA -UNIT 2TSB35-3RvsoI TS / B 3.5-23 Revision 1

Rev. 2 ECCS-Shutdown B 3.5.2 BAS ES SURVEILLANCE SR 3.5.2.4 (continued)

REQUIREMENTS subsystem operation may be aligned for decay heat removal. Therefore, this SR is modified by a Note that allows LPCI subsystems of the RHR System to be considered OPERABLE for the ECCS function if all the required valves in the LPCI flow path can be manually realigned (remote or local) to allow injection into the RPV, and the systems are not otherwise inoperable. This will ensure adequate core cooling if an inadvertent RPV draindown should occur.

• REFERNCES 1. FSAR, Section 6.3.2.

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

SUSQUEHANNA -UNIT2 B2.-4Rvso B 3.5-24 Revision 0

Rev. 12 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 with 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. Certain plant piping systems (e.g., Service Water, RHR Service Water, Emergency Service Water, Feedwater, etc.) penetrate the secondary containment boundary. The intact piping within secondary containment provides a passive barrier which maintains secondary containment requirements. Breaches of these piping systems within secondary containment will be controlled to maintain secondary containment requirements. The secondary containment is divided into Zone I, Zone IIand Zone IlI, each of which must be OPERABLE depending on plant status and the alignment of the secondary containment boundary. Specifically, the Unit I secondary containment boundary can be modified to exclude Zone 11.Similarly, the Unit 2 secondary containment boundary can be modified to exclude Zone I. Secondary containment may consist of only Zone Ill when in MODE 4 or 5 during CORE ALTERATIONS, or during handling of irradiated fuel within the Zone ill secondary containment boundary.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.6-83 TS .- 3Rvso Revision 4

Rev. 12 Secondary Containment B 3.6.4.1 BASES BACKGROUND To prevent ground level exfiltration while allowing the secondary containment (continued) 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 There are two principal accidents for which credit is taken for secondary SAFETY containment OPERABILITY. These are a loss of coolant-accident (LOCA)

ANALYSES (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)

SUSQUEHANNA - UNIT 2 TTS / B 3.6-84

.- 4Rvso Revision 2

" Rev. 12 Secondary Containment B 3.6.4.1 BASES (continued)

APPLICABILITY 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 (OP DRVs),

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 Completion 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.

B.1 and B.2 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.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.6-85 TS .- 5Rvso Revision 4

Rev. 12 Secondary Containment B 3.6.4.1 BASES ACTIONS C.1, C.2, and C.3 (continued)

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 ifthe 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 probability 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 under expected wind conditions. Expected wind conditions are defined as sustained wind speeds of less than or equal to 16 mph at the 60m meteorological tower or less than or equal to 11 mph at the 10Om meteorological tower ifthe 60m tower wind speed is not available.

Changes in indicated reactor building differential pressure observed during periods of short-term wind speed gusts above these sustained speeds do not by themselves impact secondary containment integrity. However, if secondary containment integrity is known to be compromised, the LCO must be entered regardless of wind speed.

(continued)

SUSQUEHANNA - UNIT 2 T / B 3.6-86 TS .- 6Rvso Revision 2

Rev. 12 Secondary Containment B 3.6.4.1 BASES 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, removable 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.

Maintaining secondary containment OPERABILITY requires verifying one door in each access opening to secondary containment zones is closed.

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 Ill 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 Ill hatches and/or dampers are open to the railroad access shaft. When the railroad bay door (No. 101) is open; all Zone I and Ill 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 Ill.

(continued)

SUSQUEHANNA - UNIT22Sl .- 7Rvso TS / B 3.6-87 Revision 2

Rev. 12 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 required 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.

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SUSQUEHANNA -UNIT 2TSIB368aRvso3 TS / B 3.6-87a Revision 3

Rev. 12 Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.4 and SR 3.6.4.1.5 REQUIREMENTS (continued) 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 containment boundary.

This is confirmed by demonstrating that one SGT subsystem will draw down the secondary containment to _>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 (CFM)

CONTAINMENT (SR 3.6.4.1.4 (SR 3.6.4.1.5 TEST CONFIGURATION ACCEPTANCE CRITERIA) ACCEPTANCE CRITERIA)

Group 1 Zones I, II and III (Unit 1 <*300 Seconds < 5400 CFM Railroad Bay aligned to (Zones 1,II, and III) (From Zones 1,I1,and IlI)

Secondary Containment).

Zones II and Ill (Unit 1 *<300 Seconds

• 4000 CFM Railroad Bay aligned to (Zones Il and Ill) (From Zones IIand Ill)

Zone Ill).

Group 2 Zones I, II and Ill (Unit 1 < 300 Seconds < 5300 CFM Railroad Bay not aligned to (Zones 1,II, and III) (From Zones 1,11,and III)

Secondary Containment).

Zones II and Ill (Unit 1 <*300 Seconds < 3900 CFM Railroad Bay not aligned to (Zones IIand III) (From Zones IIand Ill)

SecondaryContainment). ___________________

Only one of the above listed configurations needs to be tested to confirm secondary containment OPERABILITY.

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SUSQUEHANNA- UNIT 2TSB36-8Rvso6TS / B 3.6-88 Revision 6

Rev. 12 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.

The secondary containment testing configurations are discussed in further detail to ensure the appropriate configurations are tested,- Three zone testing (Zones, I,11 and Ill aligned to the recirculation plenum) should be performed with the Railroad Bay aligned to secondary containment and another test with the Railroad Bay not aligned to secondary containment.

Each test should be performed with each division on a STAGGERED TEST BASIS.

Two zone testing (Zones IIand Ill aligned to the recirculation plenum) should be performed with the Railroad Bay aligned to secondary containment and another test with the Railroad Bay not aligned to secondary containment.

Each test should be performed with each division on a STAGGERED TEST BASIS. The normal operating fans of the non-tested HVAC zone (Zone I fans 1V202A&B, 1V205A&B and 1V206A&B) should not be in operation.

Additionally, a controlled opening of adequate size should be maintained in Zone I Secondary Containment during testing to assure that atmospheric conditions are maintained in that zone.

The Unit 1 Railroad Bay can be aligned as a No Zone (isolated from secondary containment) or as part of secondary containment (Zone I or III).

Due to the different leakage pathways that exist in the Railroad Bay, the Railroad Bay should be tested when aligned to secondary containment and also not aligned to secondary containment. It is preferred to align the Railroad Bay to Zone IIl when testing with the Railroad Bay aligned to secondary containment since Zone Ill is included in all possible secondary containment isolation alignments. Note that when performing the three zone testing (Zones 1,II and Ill aligned to the recirculation plenum) aligning the Railroad Bay to either Zone I or III is acceptable since either zone is part of secondary containment. When performing the Zone II& Ill testing with the Railroad Bay aligned to secondary containment, the Unit 1 Railroad Bay must be aligned to Zone III.

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SUSQUEHANNA - UNIT 2 T / B 3.6-89 TS .- 9Rvso Revision 4

Rev. 12 Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.4 and SR 3.6.4.1.5 (continued)

REQU IREM ENTS 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_

REFERENCES- 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).

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SUSQUEHANNA -UNIT 2TSIB368aRvso0 TS / B 3.6-89a Revision 0