ML16110A316

Technical Specification Bases Manual

ML16110A316
Person / Time
Site:	Susquehanna
Issue date:	04/14/2016
From:	Susquehanna
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
Download: ML16110A316 (57)

Text

Apr. 14, 2016 Page 1 of 2 MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2016-14 734 USER INFORMATION:

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

TO: GERLACH*ROSEY M 04/14/2016 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.

TSBl - TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 04/11/2016 ADD MANUAL TABLE OF CONTENTS DATE: 04/13/2016 CATEGORY: DOCUMENTS TYPE: TSBl

Apr. 14, 2016 Page 2 of 2 ID: TEXT 3.4.5 ADD: REV: 2 REMOVE: REV:l CATEGORY: DOCUMENTS TYPE: TSBl ID : TEXT 3 . 6 . 1. 3 REMOVE: REV: 11 ADD: REV: 12 CATEGORY: DOCUMENTS TYPE: TSBl ID: TEXT LOES REMOVE: REV:l22 ADD: REV: 123 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: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL Table Of Contents Issue Date: 04/13/2016 Procedure Name Rev Issue Date Change ID Change Number TEXT LOES 123 04/13/2016

Title:

LIST OF EFFECTIVE SECTIONS TEXT TOC 23 07 /0 2/2014

Title:

TABLE OF CONTENTS TEXT 2.1.1 6 01/22/2015

Title:

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

Title:

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

Title:

LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY TEXT 3.1.1 1 04/18/2006

Title:

REACTIVITY CONTROL SYSTEMS SHUTDOWN MARGIN (SDM)

TEXT 3.1.2 0 11/15/2002

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 /06/2 005

Title:

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

Title:

REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Page 1. of _a Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl I I Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3 .1. 7 3 04/23/2008

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 2 04/23/2008

Title:

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

TEXT 3.2.2 3 05 / 06 /2 009

Title:

POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)

TEXT 3.2.3 2 04/23/2008

Title:

POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE (LHGR)

j

* TEXT 3. 3 .1 .1 6 02 / 24 /2 014

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATION TEXT 3.3 . 1 .2 2 . 01 /1 9/2009

Title:

INSTRUMENTATION SOURCE RANGE MONITOR (SRM) INSTRUMENTATION TEXT 3.3.2.1 4 02 /24/2014

Title:

INSTRUMENTATION CONTROL ROD BLOCK INSTRUMENTATION TEXT 3.3.2.2 2 04 / 05 /2010

Title:

INSTRUMENTATION FEEDWATER MAIN TURBINE HIGH WATER LEVEL TRIP INSTRUMENTATION TEXT 3.3.3.l 9 02/28/2013

Title:

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

Title:

INSTRUMENTATION REMOTE SHUTDOWN SYSTEM TEXT 3.3.4.1 2 02/24/2014

Title:

INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATIO~

Page 2. of 1l. Report Date: 04 / 13 /16

SSES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.3.4.2 0 11/15/2002

Title:

INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP (ATWS-RPT} INSTRUMENTATION TEXT 3.3.5.l 3 08/20/2009

Title:

INSTRUMENTATION EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION TEXT 3.3.5.2 0 11/15/2002

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.l 2 12/17 /2007

Title:

INSTRUMENTATION LOSS OF POWER (LOP) INSTRUMENTATION TEXT 3.3.8.2 0 11/15/2002

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORING TEXT 3.4.1 4 04/27/2010

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 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE Page .l of Ji Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl

• -

• Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL

. j ~::-::. ~=:-.::

TEXT 3.4.5 2 04/13/2016

Title:

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:

REACTOR COOLANT 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 1 03/28/2013

Title:

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

- COLD SHUTDOWN

(~-:*=iF~ TEXT 3.4.10 4 11/04/2015 ,I

Title:

REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE (P/T) LIMITS TEXT 3.4.11 0 11/15/2002

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 0 11/15/2002

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 04/23/2008

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK Page 1. of Ji Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3 . 6 . 1. 3 12 04/13/2016

Title:

• CONTAINMENT SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)

TEXT 3 . 6 . 1. 4 1 04/23/2008

Title:

CONTAINMENT SYSTEMS CONTAINMENT PRESSURE TEXT 3 . 6 . 1. 5 1 10/05/2005

Title:

CONTAINMENT SYSTEMS DRYWELL AIR TEMPERATURE TEXT 3 . 6 . 1. 6 0 11/15/2002

Title:

CONTAINMENT SYSTEMS SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKERS TEXT 3~6.2.l 2 04/23/2008

Title:

CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE

, )~ TEXT 3 . 6 . 2 . 2 0 11/15/2002

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 11/15/2002

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 11 11/06/2014

• Title: CONTAINMENT SYSTEMS SECONDARY CONTAINMENT Page .5. of _a Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.6.4.2 10 02/02/2016

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT ISOLATION VALVES (SCIVS)

TEXT 3.6.4.3 4 09/21/2006

Title:

CONTAINMENT SYSTEMS STANDBY GAS TREATMENT (SGT) SYSTEM TEXT 3.7.1 4 04/05/2010

Title:

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

TEXT 3.7.2 2 02/11/2009

Title:

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

Title:

PLANT SYSTEMS CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM 0 11/15/2002

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 2 04/23/2008

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 .o 04/23/2008

Title:

PLANT SYSTEMS TEXT 3.8.1 7 02/24/2014

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING TEXT 3.8.2 0 11/15/2002

~~:~~-> :~

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - SHUTDOWN

." --:._~~-=-'

Page Q. of Ji Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 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:

ELECTRICAL POWER SYSTEMS DC SOURCES - SHUTDOWN TEXT 3.8.6 1 12/14/2006

Title:

ELECTRICAL POWER SYSTEMS BATTERY CEµL PARAMETERS TEXT 3.8.7 1 10/05/2005

Title:

ELECTRICAL POWER SYSTEMS DISTRIBUTION SYSTEMS - OPERATING TEXT 3.8.8 0 11/15/2002

Title:

ELECTRICAL POWER SYSTEMS DISTRIBUTION SYSTEMS SHUTDOWN TEXT 3.9.1 0 11/15/2002

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 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION TEXT 3.9.4 0 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/15/2002

Title:

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

Title:

REFUELING OPERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL Page 1. of _8_ Report Date: 04/13/16

.ssES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.9.7 0 11/15/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - HIGH WATER.LEVEL TEXT 3.9.8 0 11/15/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - LOW WATER LEVEL TEXT 3.10.l 1 01/23/2008 Titleg SPECIAL OPERATIONS INSERVICE LEAK AND HYDROSTATIC TESTING OPERATION TEXT 3.10.2 0 11/15/2002 Titleg SPECIAL OPERATIONS REACTOR MODE SWITCH INTERLOCK TESTING TEXT 3.10.3 0 11/15/2002 Titleg SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - HOT SHUTDOWN

~-

TEXT 3.10.4 0 11/15/2002

• - -P *i

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - COLD SHUTDOWN TEXT 3.10.5 0 11/15/2002 Titleg SPECIAL OPERATIONS SINGLE CONTROL ROD DRIVE (CRD) REMOVAL - REFUELING TEXT 3.10.6 0 11/15/2002

Title:

SPECIAL OPERATIONS MULTIPLE CONTROL ROD WITHDRAWAL - REFUELING TEXT 3.10.7 1 04/18/2006 Titleg SPECIAL OPERATIONS CONTROL ROD TESTING - OPERATING TEXT 3.10.8 1 04/12/2006 Titleg SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING Page .a of .a Report Date: 04/13/16

SUSQUEHANNA STEAM ELECTRIC STATI ON LIST OF EFFECTIVE SECTIONS (TECHNICAL SPEC IFICATIONS BASES)

Section Title Revision TOC Table of Contents 23 B 2.0 SAFETY LIMITS BASES Page TS I B 2.0-1 1 Page TS I B 2.0-2 3 Page TS I B 2.0-3 6 Page TS I B 2.0-4 4 Page TS I B 2.0-5 6 Page TS I B 2.0-6 1 Pages TS I B 2.0-7 through TS I 8 2.0-9 1 I

8 3.0 LCO AND SR APPLICABILITY BASES Page TS I B 3.0-1 1 Pages TS I B 3.0-2 through TS I B 3.0-4 0 Pages TS I B 3.0-5 through TS I 8 3.0-7 1 Page TS I B 3.0-8 3 Pages TS I B 3.0-9 through TS I 8 3.0-11 2 Page TS I B 3.0-11a 0 Page TS I B 3.0-12 1 Pages TS I B 3.0-13 through TS I B 3.0-15 2 Pages TS I B 3.0-16 and TS I B 3.0-17 0 B 3.1 REACTIVITY CONTROL BASES Pages B 3.1-1 through B 3.1-4 0 Page TS I 8 3.1-5 1 Pages TS I B 3.1 -6 and TS I 8 3.1-7 2 Pages 8 3.1-8 through B 3.1-13 0 Page TS I 8 3.1-14 1 Page B 3.1-15 0 Page TS I B 3.1-16 1 Pages B 3.1-17 through B 3.1-19 0 Pages TS I B 3.1-20 and TS I B 3.1-21 1 Page TS I B 3.1-22 0 Page TS I B 3.1-23 1 Page TS I 8 3.1-24 0 Pages TS I B 3.1-25 through TS I B 3.1-27 1 Page TS I B 3.1-28 2 Page TS I B 3.1-29 1 Pages B 3.1-30 through B 3.1-33 0 Pages TS I B 3.3-34 through TS I B 3.3-36 1 Page TS I B 3.1-37 2 Page TS I B 3.1-38 3 Pages TS I B 3.1 -39 and TS I B 3.1-40 2 Page TS I B 3.1-40a 0 Pages TS I B 3.1-41 and TS I B 3.1-42 2 SUSQUEHANNA - UNIT 1 TS I B LOES-1 Revision 123

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

Section Title Revision Page TS I B 3.1.43 1 Page TS I B 3.1-44 0 Page TS I B 3.1-45 3 Pages TS I B 3.1-46 through TS I B 3.1-49 1 Page TS I B 3.1-50 0 Page TS I B 3.1-51 3 B 3.2 POWER DISTRIBUTION LIMITS BASES Page TS I B 3.2-1 2 Pages TS I B 3.2-2 and TS I B 3.2-3 3 Pages TS I 8 3.2-4 and TS I B 3.2-5 2 Page TS I B 3.2-6 3 Page B 3.2-7 1 Pages TS I B 3.2-8 and TS I B 3.2-9 3.

Page TS I B 3.2.10 2 Page TS I B 3.2-11 3 Page TS I B 3.2-12 1 Page TS I B 3.2-13 2 B 3.3 INSTRUMENTATION Pages TS I B 3.3-1 through TS I B 3.3-4 1 Page TS I B 3.3-5 2 Page TS I B 3.3-6 1 Page TS I B 3.3-7 3 Page TS I B 3.3-7a 1 Page TS I B 3.3-8 5 Pages TS I B 3.3-9 through TS I B 3.3-12 3 Pages TS I B 3.3-12a 1 Pages TS I B 3.3-12b and TS I B 3.3-12c 0 Page TS I B 3.3-13 1 Page TS I B 3.3-14 3 Pages TS I B 3.3-15 and TS I B 3.3-16 1 Pages TS I B 3.3-17 and TS I B 3.3-18 4 Page TS I B 3.3-19 1 Pages TS I B 3.3-20 through TS I B 3.3-22 2 Page TS I B 3.3-22a 0 Pages TS I B 3.3-23 and TS I B 3.3-24 2 Pages TS I B 3.3-24a and TS I B 3.3-24b 0 Page TS I B 3.3-25 3 Page TS I B 3.3-26 2 Page TS I B 3.3-27 1 Page TS I B 3.3-28 3 Page TS I B 3.3-29 4 Page TS I B 3.3-30 3

• Page TS I B 3.3*30a 0 SUSQUEHANNA - UNIT 1 TS I B LOES~2 Revision 123

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

Section Title Revision Page TS I B 3.3-31 4 Page TS I B 3.3-32 5 Pages TS I B 3.3-32a 0 Page TS I B 3.3-32b 1 Page TS I B 3.3-33 5 Page TS I B 3.3-33a 0 Page TS I B 3.3-34 1 Pages TS I B 3.3-35 and TS I B 3.3-36 2 Pages TS I B 3.3-37 and TS I B 3.3-38 1 Page TS I B 3.3-39 2 Pages TS I B 3.3-40 through TS I B 3.3-43 1 Page TS I B 3.3-44 4 Pages TS I B 3.3-44a and TS I B 3.3-44b 0 Page TS I B 3.3-45 3 Pages TS I B 3.3-45a and TS I B 3.3-45b 0

• Page TS I B 3.3-46 3 Pages TS I B 3.3-47 2 Pages TS I B 3.3-48 through TS I B 3.3-51 3 Pages TS I B 3.3-52 and TS I B 3.3-53 2 Page TS I B 3-3-53a 0 Page TS I B 3.3-54 5 Page TS I B 3.3-55 2 Pages TS I B 3.3-56 and TS I B 3.3-57 1 Page TS I B 3.3-58 0 Page TS I B 3.3-59 1 Page TS I B 3.3-60 0 Page TS I B 3.3-61 1 Pages TS I B 3.3-62 and TS I B 3.3-63 0 Pages TS I B 3.3-64 and TS I B 3.3-65 2 Page TS I B 3.3-66 4 Page TS I B 3.3-67 3 Page TS I B 3.3-68 4 Page TS I 8 3.3-69 5 Pages TS I B 3.3-70 4 Page TS I B 3.3-71 3 Pages TS I 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 Page TS I B 3.3M75a 6 Page TS I B 3.3-75b 7 Page TS I B 3.3-75c 6 Pages B 3.3-76 through B 3.3-77 0 Page TS I B 3.3-78 1 SUSQUEHANNA - UNIT 1 TS I B LOES-3 Revision 123

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

Section Title Revision Pages B 3.3-79 through B 3.3~81 0 Page TS I B 3.3-82 2 Page B 3.3-83 0 Pages B 3.3-84 and B 3.3-85 1 Page B 3.3-86 0 Page B 3.3-87 1

• Page B 3.3-88 0 Page B 3.3-89 1 Page TS I B 3.3-90 1 Page B 3.3-91 0 Pages TS I B 3.3-92 through TS I B 3.3-100 1 Pages TS I B 3.3-101 through TS I B 3.3-103 0 Page TS I B 3.3-104 2 Pages TS I B 3.3-105 and TS I B 3.3-106 0 Page TS I B 3.3-107 1 Page TS I B 3.3-108 0 Page TS I B 3.3-109 1 Pages TS I B 3.3-110 and TS I B 3.3-111 0 Pages TS I B 3.3-112 and TS/ B 3.3-112a 1 Pages TS I B 3.3-113 through TS I B 3.3-115 1 Page TS I B 3.3-116 3 Page TS I B 3.3-117 1 Pages TS I B 3.3-118 through TS I B 3.3-122 0 Pages TS I B 3.3-123 and TS/ 8 3.3-124 1 Page TS I B 3.3-124a 0 Page TS I B 3.3-125 0 Pages TS I B 3.3-126 and TS I B 3.3-127 1 Pages TS I B 3,3-128 through TS/ B 3.3-130 0 Page TS I B 3.3-131 1 Pages TS I B 3.3-132 through TS I B 3.3-134 0 Pages B 3.3-135 through B 3.3-137 0 Page TS I B 3.3-138 1 Pages B 3.3-139 through B 3.3-149 0 Pages TS I B 3.3-150 and TS I B 3.3-151 1 Pages TS I B 3.3-152 through TS I B 3.3-154 2 Page TS I B 3.3-155 1 Pages TS I B 3.3-156 through TS I B 3.3-158 2 Pages TS I B 3.3-159 and TS I B 3.3-160 1 Page TS I B 3.3-161 2 Page TS I B 3.3-162 1 Page TS I B 3.3-163 2 Page* TS I B 3.3-164 1 Pages TS I B 3.3-165 through TS I B 3.3-167 2 SUSQUEHANNA - UNIT 1 TS/ B LOES-4 Revision 123

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

• - ~: ..~

'. Section Title Revision Pages TS I B 3.3-168 and TS I B 3.3-169 1 Page TS I B 3.3-170 3 Page TS I B 3.3-171 2 Pages TS I B 3.3-172 through TS I B 3.3-177 1 Pages TS I B 3.3-178 and TS I B 3.3-179 2 Page TS I B 3.3-179a 2 Pages TS I B 3.3-179b and TS I B 3.3-179c 0 Page TS/ .B 3.3-180 1 Page TS I B 3.3-181 3 Page TS I B 3.3-182 1 Page TS I B 3.3-183 2 Page TS I B 3.3-184 1 Page TS I B 3.3-185 4 Page TS I B 3.3-186 1 Pages TS I B 3.3-187 and TS I B 3.3-188 2 Pages TS I B 3.3-189 through TS I B 3.3-191 1 Page TS I B 3.3-192 0 Page TS I B 3.3-193 1 Pages TS I B 3.3-194 and TS I B 3.3-195 0 Page TS I B 3.3-196 2 Pages TS I B 3.3-197 through TS I B 3.3-204 0 Page TS I B 3.3-205 1 Pages B 3.3-206 through B 3.3-209 0

• --.~"?-~-~-

~ Page TS I B 3.3-210 1 Pages B 3.3-211throughB3.3-219 0 B 3.4 REACTOR COOLANT SYSTEM BASES Pages B 3.4-1 and B 3.4-2 0 Pages TS I B 3.4-3 and Page TS I B 3.4-4 4 Page TS I B 3.4-5 3 Pages TS I B 3.4-6 through TS I B 3.4-9 2 Page IS I B 3.4-10

• 1 Pages TS I 3.4-11 and TS I B 3.4-12 0 Page TS I B 3.4-13 2 Page TS I B 3.4-14 1 Page TS I B 3.4-15 2 Pages TS I B 3.4-16 and TS I B 3.4-17 4 Page TS I B 3.4-18 2 Pages 8 3.4-19 thr~ugh B 3.4-27 0 Page TS I B 3.4-28 1 Pages TS I B 3.4-29 and TS I B 3.4-30 2 Page TS I B 3.4-31 1 Pages TS I B 3.4-32 and TS I B 3.4-33 2 Page TS I B 3.4-34 1 Page TS I B 3.4-34a 0

~~~-;::" ' SUSQUEHANNA - UNIT 1 TS I B LOES-5 Revision 123

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

'.--::-:r. Section Title Revision

• Pages TS I B 3.4-35 and TS I B 3.4-36 1 Page TS I B 3.4-37 2 Page TS I B 3.4-38 1 Pages B 3.4-39 and B 3.4-40 0 Page TS I B 3.4-41 2 Pages TS I B 3.4-42 through TS I B 3.4-45 0 Page TS I B 3.4-46 1 Pages TS B 3.4-47 and TS I B 3.4-48 . 0 Page TS I B 3.4-49 3 Page TS I B 3.4-50 1 Page TS I B 3.4-51 3 Page TS I B 3.4-52 3 Page TS I B 3.4-52a 0 Pages TS I B 3.4-53 through TS I B 3.4-56 2 Page TS I B 3.4-57 4 Page TS I B 3.4-57a 0 Pages TS I B 3.4-58 through TS I B 3.4-60 1 B 3.5 ECCS AND RCIC BASES Pages B 3.5-1 and B 3.5-2 0 Page TS I B 3.5-3 3 Page TS I B 3.5-4 1 Page TS I B 3.5-5 2 Page TS I B 3.5-6 1 Pages B 3.5-7 through B 3.5-10 0 Page TS I B 3.5-11 1 Page TS I B 3.5-12 0 Page TS I B 3.5-13 2 Pages TS I B 3.5-14 and TS I B 3.5-15 0 Pages TS/ B 3.5-16 and TS I B 3.5-17 3 Page TS I B 3.5-18 1 Pages B 3.5-19 through B 3.5-24 0 Page TS I B 3.5-25 1 Page TS I B 3.5-26 and TS I B 3.5-27 2 Page TS I B 3.5-28 0 Page TS I B 3.5-29 1 Pages TS I B 3.5-30 and TS I B 3.5-31 0 83 ..6 CONTAINMENT SYSTEMS BASES Page TS I B 3.6-1 2 Page TS I B 3.6-1a 3 Page TS I B 3.6-2 4 Page TS I B 3.6-3 3 Page TS I B 3.6-4 4 Pages TS I B 3.6-5 and TS I B 3.6-6 3 SUSQUEHANNA - UNIT 1 TS I B LOES-6 Revision 123

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

Section Title Revision Page TS I B 3.6-6a 2 Page TS I B 3.6-6b 4 Page TS I B 3.6-6c 0 Page B 3.6-7 0 Page B 3.6-8 1 Pages B 3.6-9 through B 3.6-14 0 Page TS I B 3.6-15 3 Page TS I B 3.6-15a 0 Page TS I B 3.6-15b 3 Pages TS I B 3.6-16 and TS I B 3.6-17 2 Page TS I B 3.6-17a 1 Pages TS I B 3.6-18 and TS I B 3.6-19 0 Page TS I B 3.6-20 1 Page TS I B 3.6-21 2 Page TS I B 3.6-22 1 Page TS I B 3.6-22a 0 Page TS I B 3.6-23 1 Pages TS I B 3.6-24 and TS I B 3.6-25 0 Pages TS I B 3.6-26 and TS I B 3.6-27 2 Page TS I B 3.6-28 7 Page TS I B 3.6-29 2 Page TS I B 3.6-30 1 Page TS I B 3.6-31 3 Pages TS I B 3.6-32 and TS I B 3.6-33 1 Pages TS I B 3.6-34 and TS I B 3.6-35 0 Page TS I B 3.6-36 1 Page TS I B 3.6-37 0 Page TS I B 3.6-38 3 Page TS I B 3.6-39 2 Page TS I B 3.6-40 6 Page TS I B 3.6-40a 1 Page B 3.6-41 1 Pages B 3.6-42 and B 3.6-43 0 Pages TS I B 3.6-44 and TS I B 3.6-45 1 Page TS I B 3.6-46 2 Pages TS I B 3.6-47 through TS I B 3.6-51 1 Page TS I B 3.6-52 2 Pages TS I B 3.6-53 through TS I B 3.6-56 0 Page TS I B 3.6-57 1 Page TS I 3.6-58 2 Pages B 3.6-59 through B 3.6-63 0 Pages TS I B 3.6-64 and TS I B 3.6-65 1 Pages B 3.6-66 through B 3.6-69 0

~ SUSQUEHANNA - UNIT 1 TS I B LOES-7 Revision 123

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

Section Title Revision Pages TS I B 3.6-70 through TS I B 3.6-75 . 1 Pages B 3.6-76 and B 3.6-77 0 Page TS I B 3.6-78 1 Pages B 3.6-79 and B 3.3.6-80 0 Page TS I B 3.6-81 1 Pages TS I B 3.6-82 and TS I B 3.6-83 0 Page TS I B 3.6-84 4 Page TS I B 3.6-85 2 Page TS I B 3.6-86 4 Pages TS I B 3.6-87 through TS I B 3.6-88a 2 Page TS I B 3.6-89 6*

Page TS I B 3.6-90 4 Page TS I B 3.6-90a 0 Pages TS I B 3.6-91 and TS I B 3.6-92 3 Page TS I B 3.6-93 2 Pages TS I B 3.6-94 through TS I B 3.6-96 1 Page TS I B 3.6-97 2.

Page TS I B 3.6-98 1 Page TS I B 3.6-99 2 Pages TS I B 3.6-100 7 Page TS I B 3.6-100a 6 Page TS I B 3.6-100b 4 Page TS I B 3.6-100c 0 Pages TS I B 3.6-101 and TS I B 3.6-102 1 Pages TS I B 3.6-103 and TS I B 3.6-104 2 Page TS I B 3.6-105 3 Page TS I B 3.6-106 2 Page TS I B 3.6-107 3 B 3.7 PLANT SYSTEMS BASES Pages TS I B 3.7-1 3 Page TS I B 3.7-2 4 Pages TS I B 3.7-3 through TS I B 3.7-5 3 Page TS I B 3.7-Sa 1 Page TS I B 3.7-6 3 Page TS I B 3.7-6a 2 Page TS I B 3.7-6b

• 1 Page TS I B 3.7-6c 2 Page TS I B 3.7-7 3 Page TS I B 3.7-8 2 Pages TS I B 3.7-9 through TS I B 3.7-11 1 Pages TS I B 3.7-12 and TS I B 3.7-13 2 Pages TS I B 3.7-14 through TS I B 3.7-18 3 Page TS I B 3.7-18a . 1 Pages TS I B 3.7-18b through TS I B 3.7-18e 0 SUSQUEHANNA - UNIT 1 TS I B LOES-8 Revision 123

SUSQUEHANNA STEAM ELECTRIC STATION L/STOF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

"";:,..:** Section Title Revision Pages TS I B 3.7-19 through TS I B 3.7-23 1 Page TS I B 3.7-24 1 Pages TS I B 3.7-25 and TS I B 3.7-26 0 Pages TS I B 3.7-27 through TS I B 3.7-29 5 Page TS I B 3.7-30 2 Page TS I B 3.7-31 . 1 Page TS I B 3.7-32 0 Page TS I B 3.7-33 1 Pages TS I B 3.7-34 through TS I B 3.7-37 0 B3.8 ELECTRICAL POWER SYSTEMS BASES Page TS I B 3.8-1 3 Pages TS I B 3.8-2 and TS I B 3.8-3 2 Page TS I B 3.8-4 3 Pages TS I 8 3.8-4a and TS I 8 3.8-4b 0 Page TS I B 3.8-5 5 Page TS I 8 3.8-6 3 Pages TS I 8 3.8-7 through TS/B 3.8-8 2 Page TS I B 3.8-9 4 Page TS I B 3.8-10 3 Pages TS I B 3.8-11 and TS I B 3.8-17 2 Page TS I B 3.8-18 3 Pages TS I B 3.8-19 through TS I B 3.8-21 2 Pages TS I B 3.S:-22 and TS I 8 3.8-23 3 Pages TS I B 3.8-24 through TS I B 3.8-30 2 Pages TS I 8 3.8-31 and TS I B 3.8-32 3 Pages TS I B 3.8-33 through TS I B 3.8-37 2 Pages B 3.8-38 through B 3.8-44 0 Page TS I B 3.8-45 3 Pages TS I B 3.8-46 through TS I B 3.8-48 0 Pages TS I 8 3.8-49 and TS I B 3.8-50 3 Page TS I B 3.8-51 1 Page TS I B 3.8-52 0 Page TS I 8 3.8-53 1 Pages TS I 8 3.8-54 through TS I 8 3.8-57 2 Pages TS I B 3.8-58 through TS I 8 3.8-61 3 Pages TS I 8 3.8-62 and TS I B 3.8-63 5 Page TS I B 3.8-64 4 Page TS I B 3.8-65 5 Pages TS I B 3.8-66 through TS I 8 3.8-77 1 Pages TS I 8 3.8-77A through TS I B 3.8-77C 0 Pages B 3.8-78 through B 3.8-80 0 Page TS I 8 3.8-81 1 Pages B 3.8-82 through B 3.8-90 0 SUSQUEHANNA - UNIT 1 TS I B LOES-9 Revision 123

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

Section Title Revision B 3.9 REFUELING OPERATIONS BASES Pages TS I B 3.9-1 and TS I B 3.9-1a 1 Pages TS I B 3.9-2 through TS I B 3.9-5 1 Pages TS I B 3.9-6 through TS I B 3.9-8 0 Pages B 3.9-9 through B 3.9-18 0 Pages TS I B 3.9-19 through TS I B 3.9-21 1 Pages B 3.9-22 through B 3.9-30 0 B 3.10 SPECIAL OPERATIONS BASES Page TS I B 3.10-1 2 Pages TS I B 3.10-2 through TS I B 3.10-5 1 Pages B 3.10-6 through B 3.10-31 0 Page TS I B 3.10-32 2 Page B 3.10-33

• 0 Page TS I B 3.10-34 1 Pages B 3.10-35 and B 3.10-36 0 Page TS I B 3.10-37 1 Page TS I B 3.10-38 2 SUSQUEHANNA - UNIT 1 TS I B LOES-10 Revision 123

Rev. 2 RCS PIV Leakage B'3.4.5

.-;-f ~ . B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.5 RCS Pressure Isolation Valve (PIV) Leakage BASES BACKGROUND The function of RCS PIVs is to separate the high pressure RCS from an attached low pressure system. This protects the RCS pressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), and GDC 55of10 CFR 50, Appendix A (Refs. 1, 2, and 3). RCS PIVs are defined as any two normally closed valves in series within the reactor coolant pressure boundary (RCPB). PIVs are designed to meet the requirements of Reference 4. During their lives, these valves can produce varying amounts of reactor coolant leakage through either normal operational wear or mechanical deterioration.

The RCS PIV LCO allows RCS high pressure operation when leakage through these valves exists in amounts that do not compromise safety.

The PIV leakage limit applies to each individual valve. Leakage through these valves is not included in any allowable LEAKAGE specified in LCO 3.4.4, "RCS Operational LEAKAGE."

Although this specification provides a limit on allowable PIV leakage rate, its main purpose is to prevent overpressure failure of the low pressure portions of connecting systems. The leakage limit is an indication that the PIVs between the RCS and the connecting systems are degraded or degrading. PIV leakage could lead to overpressure of the low pressure piping or components. Failure consequences could be a loss of coolant accident (LOCA) outside of containment, an unanalyzed event that could degrade the ability for low pressure injection.

A study (Ref. 5) evaluated various PIV configurations to determine the probability of intersystem LOCAs. This study concluded that periodic leakage testing of the PIVs can substantially reduce intersystem LOCA probability.

(continued)

SUSQUEHANNA - UNIT 1 B 3.4-24 Revision 0

Rev. 2 RCS PIV Leakage B 3.4.5 BASES BACKGROUND PIVs are provided to isolate the RCS from the following typically (continued) connected systems:

a. Residual Heat Removal (RHR) System; and

b. Core Spray System.

The PIVs are listed in Table B 3.4.5-1 "Pressure Isolation Valve."

APPLICABLE Reference 5 evaluated various PIV configurations, leakage testing of the SAFETY valves, and operational changes to determine the effect on the probability ANALYSES of intersystem LOCAs. This study concluded that periodic leakage testing of the PIVs can substantially reduce the probability of an intersystem LOCA.

PIV leakage is not considered in any Design Basis Accident analyses.

This Specification provides for monitoring the condition of the RCPB to detect PIV degradation that has the potential to cause a LOCA outside of containment. RCS PIV leakage satisfies Criterion 2 of the NRC Policy Statement (Ref. 6).

LCO RCS*PIV leakage is leakage into closed systems connected to the RCS.

Isolation valve leakage is usually on the order of drops per minute.

Leakage that increases significantly suggests that something is operationally wrong and corrective action must be taken. Violation of this LCO could result in continued degradation of a PIV, which could lead to overpressurization of a low pressure system and the loss of the integrity of a fission product barrier.

The LCO PIV leakage limit is 0.5 gpm per nominal inch of valve size with a maximum limit of 5 gpm (Ref. 4).

APPLICABILITY In MODES 1, 2, and 3, this LCO applies because the PIV leakage potential is greatest when the RCS is pressurized. In MODE 3, valves in the RHR shutdown cooling flow path are not required to meet the requirements of this LCO when in, (continued)

SUSQUEHANNA- UNIT 1 B 3.4-25 Revision 0

Rev. 2 RCS PIV Leakage B 3.4.5 BASES APPLICABILITY or during transition to or from, the RHR shutdown cooling mode of (continued) operation. This is because RHR shutdown cooling will be placed in operation only below the current pressure permissive setpoint when the high to low pressure interface does not exist.

In MODES 4 and 5, leakage limits are not provided because the lower reactor coolant pressure results in a reduced potential for leakage and for a LOCA outside the containment. Accordingly, the potential for the consequences Of reactor coolant leakage is far lower during these MODES.

ACTIONS The ACTIONS are modified by two Notes. Note 1 has been provided to modify the ACTIONS related to RCS PIV flow paths. Section 1.3, Completion Times, specifies once a Condition has been entered, subsequent divisions, subsystems, components, or variables expressed in the Condition discovered to be inoperable or not within limits will not result in separate entry into*the Condition. Section 1.3 also specifies Required Actions of the Condition continue to apply for each additional failure, with Completion Times based on initial entry into the Condition. However, the Required Actions for the Condition of RCS plV leakage limits exceeded provide appropriate compensatory measures for separate affected RCS PIV flow paths. As such, a Note has been provided that allows separate Condition entry for each affected RCS PIV flow path. Note 2 requires an evaluation of affected systems if a PIV is inoperable. The leakage may have affected system OPERABILITY, or isolation of a leaking flow path with an alternate valve may have degraded the ability of the interconnected system to perform its safety function. As a result, the applicable Conditions and Required Actions for systems made inoperable by PIVs must be entered. This ensures appropriate remedial actions are taken, if necessary, for the affected systems.

If leakage from one or more RCS PIVs is not within limit, the flow path must be isolated by at least one closed manual, deactivated automatic, or check valve within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

(continued)

SUSQUEHANNA - UNIT 1 B 3.4-26 Revision O

Rev.2 RCS PIV Leakage B 3.4.5 BASES ACTIONS A.1 (continued)

Required Action A.1 is modified by a Note stating that the valves used for isolation must meet the same leakage requirements as the PIVs and must be on the RCPB or the high pressure portion of the system.

Four hours provides time to reduce leakage in excess of the allowable limit and to isolate the flow path if leakage cannot be 'reduced while corrective actions to reseat the leaking PIVs are taken. The 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> allows time for these actions and restricts the time of operation with leaking valves.

8.1 and B.2 If leakage cannot be reduced or the system isolated, 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 MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. This action may reduce the leakage and also reduces the potential for a LOCA outside the containment. The Completion Times are reasonable, based on operating experience, to achieve the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE REQUIREMENTS SR 3 .4* 5

• 1 Performance of leakage testing on each RCS PIV is required to verify that leakage is below the specified limit and to identify each leaking valve.

The leakage limit of 0.5 gpm per inch of nominal valve diameter up to 5 gpm maximum applies to each valve. Leakage testing requires a stable pressure condition. Forthe two PIVs in series, the leakage requirement applies to each valve individually and not to the combined leakage across both valves. If the PIVs are not individually leakage tested, one valve may have failed completely and not be detected if the other valve in series meets the leakage requirement. In this situation, the protection provided by redundant valves would be lost.

(continued)

SUSQUEHANNA - UNIT 1 B 3.4-27 Revision 0

Rev.2 RCS PIV Leakage B 3.4.5 BASES SURVEILLANCE REQUIREMENTS SR 3.4.5.1 (continued)

The 24 month Frequency required by the lnservice Testing Program is within the ASME OM Code Frequency requirement and is based on the need to perform this Surveillance during an outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

This SR is modified by a Note that states the leakage Surveillance is not required to be performed in MODE 3. Entry into MODE 3 is permitted for leakage testing at high differential pressures with stable conditions not possible in the lower MODES.

REFERENCES 1. 10 CFR 50.2.

2. 10 CFR 50.55a(c).

3. 10 CFR 50, Appendix A, GDC 55.

4. ASME Operation and Maintenance Code.

5. NUREG-0677, May 1980.

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

-:r:;,*-*._---=: SUSQUEHANNA - UNIT 1 TS I B 3.4-28 Revision 1

Rev. 2 RCS PIV Leakage B 3.4.5 BASES (continued)

TABLE B 3.4.5-1 REACTOR COOLANT SYSTEM PRESSURE ISOLATION VALVES 1st Isolation 2nd Isolation Service Valve(s) Number(s) Valve(s) Number(s)

HV-152F006A HV-152F005A Core Spray Injection HV-152F037A HV-152F006B HV-152F005B Core Spray Injection HV-152F037B HV-151 F050A HV-151 F015A LPCI Injection HV-151 F122A HV-151F050B HV-151F122B 151130 HV-151 F050B HV-151 F015B LPCI Injection HV-151F122B HV-151F050A HV-151 F122A 151130 HV-151 F022 HV-151F023 Head Spray HV-151F009 HV-151F008 Shutdown Cooling SUSQUEHANNA - UNIT 1 TS I B 3.4-29 Revision 2

Rev. 12 PCIVs*

B 3.6.1.3 B 3.6 CONTAINMENT SYSTEMS B 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

BASES BACKGROUND The function of the PC IVs, in combination with other accident mitigation systems, including secondary containment bypass valves that are not PCIVs, is to limit fission product release during and following postulated Design Basis Accidents (DBAs) to within limits. Primary containment isolation within the time limits specified for those isolation valves designed to close automatically ensures that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a OBA.

The OPERABILITY requirements for PCIVs help ensure that an adequate primary containment boundary is maintained during and after an accident by minimizing potential paths to the environment.

Therefore, the OPERABILITY requirements provide assurance that primary containment function assumed in the safety analyses will be maintained. For PCIVs, the primary containment isolation function is that the valve must be able to close (automatically or manually) and/or remain closed, and maintain leakage within that assumed in the DBA LOCA Dose Analysis. These isolation devices are either passive or active (automatic). Manual valves, de-activated automatic valves secured in their closed position (including check valves with flow through the valve secured), blind flanges, and closed systems are considered passive devices. The OPERABILITY requirements for closed systems are discussed in Technical Requirements Manual (TRM) Bases 3.6.4. Check valves, or other automatic valves designed to close without operator action following an accident, are considered active devices. Two barriers in series are provided for each penetration so that no single credible failure or malfunction of an active component can result in a loss of isolation or leakage that exceeds limits assumed in the safety analyses. One of these barriers may be a closed system.

For each division of H2 0 2 Analyzers, the lines, up to and including the first normally closed valves within the H20 2 Analyzer panels, are extensions of primary containment (i.e., closed system), and are required to be leak rate tested in (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-15. Revision 3

Rev. 12 PC IVs B 3.6.1.3 BASES BACKGROUND accordance with the Leakage Rate Test Program. The H2 0 2 (continued) Analyzer closed system boundary is identified in the Leakage Rate Test Program. The closed system boundary consists of those components, piping, tubing; fittings, and valves, which meet the guidance of Reference 6. The closed system provides a secondary barrier in the event of a single failure of the PCIVs, as described below. The closed system boundary between PASS and the H2 0 2 Analyzer system ends at the process sampling solenoid operated isolation valves between the systems (SV-12361, SV-12365, SV-12366, SV-12368, and SV-12369).

These solenoid operated isolation valves do not fully meet the guidance of Reference 6 for closed system boundary valves in that they are not powered from a Class 1E power source.

However, based upon a risk determination, operating these valves as closed system boundary valves is not risk significant. These valves also form the end of the Seismic Category I boundary between the systems. These process sampling solenoid operated isolation valves are normally closed and are required to be leak rate tested in accordance with the Leakage Rate Test Program as part of the closed system for the H2 0 2 Analyzer system. These valves are "closed system boundary valves" and may be opened under administrative control, as delineated in Technical Requirements Manual (TRM) Bases 3.6.4. Opening of these valves to permit testing of PASS in Modes 1, 2, and 3 is permitted in accordance with TRO 3.6.4.

Each Hz0 2 Analyzer Sampling line penetrating primary containment has two PCIVs, located just outside primary containment. While two PCIVs are provided on each line, a single active failure of a relay in the control circuitry for these valves, could result in both valves failing to close or failing to remain closed. Furthermore, a single failure (a hot short in the common raceway to all the valves) could simultaneously affect all of the PCIVs within a H2 Q2 Analyzer division. Therefore, the containment isolation barriers for these penetrations consist of two PCIVs and a closed system. For situations where one or both PCIVs are inoperable, the ACTIONS to be taken are similar to the ACTIONS for a single PCIV backed by a closed system.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-15a Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES BACKGROUND The drywell vent and purge lines are 24 inches in diameter; (continued) the suppression chamber vent and purge lines are 18 inches in diameter. The containment purge valves are normally maintained closed in MODES 1, 2, and 3 to ensure the primary containment boundary is maintained. The outboard isolation valves have 2 inch bypass lines around them for use during normal reactor operation.

The RHR Shutdown Cooling return line containment penetrations

{X-13A(B)}are provided with a normally closed gate valve

{HV-151 F015A(B)} and a normally open globe valve *

{HV-151F017A(B)} outside containment and a testable check valve {HV-151 F050A(B)} with a normally closed parallel air operated globe valve {HV-151 F122A(B)} inside containment. The gate valve is manually opened and automatically isolates upon a containment isolation signal from the Nuclear Steam Supply Shutoff System or RPV low level 3 when the RHR System is operated in the Shutdown Cooling Mode only. The LPCI subsystem is an operational mode of the RHR System and uses the same injection lines to the RPV as the Shutdown Cooling Mode.

The design of these containment penetrations is unique in that some valves are containment isolation valves while others perform the function of pressure isolation valves. In order to meet the 10 CFR 50 Appendix J leakage testing requirements, the

• HV-151 F015A(B) and the closed system outside containment are the only barriers tested in ?Ccordance with the Leakage Rate Test Program. Since these containment penetrations {X-13A and X-138} include a containment isolation valve outside containment that is tested in accordance with 10 CFR 50 Appendix J requirements and a closed system outside containment that meets the requirements of USNRC Standard Review Plan 6.2.4 (September 1975), paragraph 11.3.e, the containment isolation provisions for these penetrations provide an acceptable alternative to the explicit requirements of 10 CFR 50, Appendix A, GDC 55.

Containment penetrations X-13A(B) are also high/low pressure system interfaces. In order to meet the requirements to have two (2) isolation valves between the high pressure and low pressure systems, the HV-151F050A(B), HV-151F122A(B),

151130 and HV-151 F015A(B) valves are used to meet this requirement and are tested in accordance with the pressure test program.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-15b Revision 3

Rev. 12 PC IVs B 3.6.1.3 BASES APPLICABLE The PCtVs LCO was derived from the assumptions related SAFETY ANALYSES to minimizing the toss of reactor coolant inventory, and establishing the primary containment boundary during major accidents. As part of the primary containment boundary, PCIV OPERABILITY supports leak tightness of primary containment. Therefore, the safety analysis of any event requiring isolation of primary containment is applicable to this LCO.

The DBAs that result in a release of radioactive material within primary containment are a LOCA and a main steam tine break (MSLB). In the analysis for each of these accidents, it is assumed that PCIVs are either closed or close within the required isolation times following event initiation. This ensures that potential paths to the environment through PClVs (including primary containment purge valves) and secondary I containment bypass valves that are not PClVs are minimized. The closure time of the main steam isolation valves (MSlVs) for a MSLB outside primary containment is a significant variable from a radiological standpoint. The MSlVs are required to close within 3 to 5 seconds since the 5 second closure time is assumed in the analysis. The safety analyses assume that the purge valves were closed at event initiation.

Likewise, it is assumed that the primary containment is isolated such that release of fission products to the environment is controlled.

The OBA analysis assumes that within the required isolation time leakage is terminated, except for the maximum allowable leakage rate, La.

The single failure criterion required to be imposed in the conduct of unit safety analyses was considered in the original design of the primary containment purge valves. Two valves in series on each purge line provide assurance that both the supply and exhaust lines could be isolated even if a single failure occurred.

• The primary containment purge valves may be unable to close in the environment following a LOCA. Therefore, each of the purge valves is required to remain closed during MODES 1, 2, and 3 except as permitted under Note 2 of SR 3.6.1.3.1. In this case, the single failure criterion remains applicable to the primary containment purge valve (continued)

I 1-f SUSQUEHANNA- UNIT 1 TS I B 3.6-16 Revision 2

Rev. 12 PC IVs B 3.6.1.3 BASES APPLICABLE due to failure in the control circuit associated with each SAFETY ANALYSES valve. The primary containment purge valve design (continued) precludes a single failure from compromising the primary containment boundary as long as the system is operated in accordance with this LCO.

Both H2 0 2 Analyzer PCIVs may not be able to close given a single failure in the control circuitry of the valves. The single failure is caused by a "hot short" in the cables/raceway to the PC IVs that causes both PCIVs for a given penetration to remain open or to open when required to be closed. This failure is required to be considered in accordance with IEEE-279 as discussed in FSAR Section 7.3.2a. However, the single failure criterion for containment isolation of the H20 2 Analyzer penetrations is satisfied by virtue of the combination of the associated PCIVs and the closed system formed by the H2 0 2 Analyzer piping system as discussed in the BACKGROUND section above.

The closed system boundary between PASS and the H20 2 Analyzer system ends at the process sampling solenoid operated isolation valves between the systems (SV-12361, SV-12365, SV-12366, SV-12368, and SV-12369). The closed system is not fully qualified to the guidance of Reference 6 in that the closed system boundary valves between the H2 0 2 system and PASS are not powered from a Class 1E power source. However, based upon a risk determination, the use of these valves is considered to have no risk significance. This exemption to the requirement of Reference 6 for the closed system boundary is documented in

• License Amendment No. 195.

PCIVs satisfy Criterion 3 of the NRC Policy Statement. (Ref. 2)

LCO PCIVs form a part of the primary containment boundary, or in the case of SCBL valves limit leakage from the primary containment.

The PCIV safety function is related to minimizing the loss of reactor coolant inventory and establishing the primary containment boundary during a OBA.

The power operated, automatic isolation valves are required to have isolation times within limits and actuate on an automatic isolation signal. The valves covered by this LCO are listed in Table B 3.6.1.3-1 and Table B 3.6.1.3-2.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-17 Revision 2

Rev. 12 PC IVs B 3.6.1.3 BASES LCO (continued) The normally closed PCIVs, including secondary containment bypass valves listed in Table B 3.6.1.3-2 that are not PCIVs, are considered OPERABLE when manual valves are closed or open in accordance with appropriate administrative controls, automatic valves are in their closed position, blind flanges are in place, and closed systems are intact. These passive isolation valves and devices are those listed in Table B 3.6.1.3-1.

Leak rate testing of the secondary containment bypass valves listed in Table 3.6.1.3-2 is permitted in Modes 1, 2 & 3 as described in the Primary Containment Leakage Rate Testing Program.

Purge valves with resilient seals, secondary containment bypass valves, including secondary containment bypass valves listed in Table B 3.6.1.3-2 that are not PCIVs, MSIVs, and hydrostatically tested valves must meet additional leakage rate requirements. Other PCIV leakage rates are addressed by LCO 3.6.1.1, "Primary Containment," as Type B or C testing.

This LCO provides assurance that the PCIVs will perform their designed safety functions to minimize the loss of reactor coolant inventory and establish the primary containment boundary during accidents APPLICABILITY In MODES 1, 2, and 3, a OBA could cause a release of radioactive material to primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, most PCIVs are not required to be (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-17a Revision 1

Rev. 12 PC IVs B 3.6.1.3 BASES APPLICABILITY OPERABLE and the primary containment purge valves are (continued) not required to be closed in MODES 4 and 5. Certain valves, however, are required to be OPERABLE to prevent inadvertent reactor vessel draindown. These valves are those whose associated instrumentation is required to be OPERABLE per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation."

(This does not include the valves that isolate the associated instrumentation.)

ACTIONS The ACTIONS are modified by a Note allowing penetration flow path(s) to be unisolated intermittently under administrative controls. These controls consist of stationing a dedicated operator at the controls of the valve, who is in continuous communication with the control room. In this way, the penetration can be rapidly isolated when a need for primary containment isolation is indicated.

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

The ACTIONS are modified by Notes 3 and 4. Note 3 ensures that appropriate remedial actions are taken, if necessary, if the affected system(s) are rendered inoperable by an inoperable PCIV (e.g., an Emergency Core Cooling System subsystem is inoperable due to a failed open test return valve). Note 4 ensures appropriate remedial actions are taken when the primary containment leakage limits are exceeded. Pursuant to LCO 3.0.6, these actions are not required even when the associated LCO is not met. Therefore, Notes 3 and 4 are added to require the proper actions be taken.

A.1 and A.2 With one or more penetration flow paths with one PCIV inoperable except for purge valve leakage not within limit, (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-18 Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS A.1 and A.2 (continued) the affected penetration flow paths must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, a blind flange, and a check valve with flow through*

the valve secured. For a penetration isolated in accordance with Required Action A.1, the device used to isolate the penetration should be the closest available valve to the primary containment. The Required Action must be completed within the 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time (8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for main steam lines). The Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is reasonable considering the time required to isolate the penetration and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. For main steam lines, an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Completion Time is allowed. The Completion Time of 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for the main steam lines allows a period of time to restore the MSIVs to OPERABLE status given the fact that MSIV closure will result in isolation of the main steam line(s) and a potential for plant shutdown.

For affected penetrations that have been isolated in accordance with Required Action A.1, the affected penetration flow path(s) must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident, and no longer capable of being automatically isolated, will be in the isolation position should an event occur. This Required Action does not require any testing or device manipulation. Rather, it involves verification that those devices outside containment and capable of potentially being mispositioned are in the correct position. The Completion Time of "once per 31 days for isolation devices outside primary containment" is appropriate because the devices are operated under administrative controls and the probability of their misalignment is low. For the devices inside primary containment, the time period specified "prior to entering MODE 2 or 3 from MODE. 4, if primary containment was de-inerted while in MODE 4, if not performed within the

• previous 92 days" is based on engineering judgment and is considered reasonable in view of the inaccessibility of the devices and other administrative controls ensuring that device misalignment is an unlikely possibility.

(continued)

-.;:c*- - ~ - -

~.-_-_..._,~

SUSQUEHANNA - UNIT 1 TS I B 3.6-19 Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS A.1 and A.2 (continued)

Condition A is modified by a Note indicating that this Condition is only applicable to those penetration flow paths with two PCIVs except for the H20 2 Analyzer penetrations. For penetration flow paths with one PCIV, Condition C provides the appropriate Required Actions. For the H20 2 Analyzer Penetrations, Condition D provides the appropriate Required Actions.

Required Action A.2 is modified by a Note that applies to isolation devices located in high radiation areas, and allows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these* areas is typically restricted. Therefore, the probability of misalignment of these devices, once they have been verified to be in the proper position, is low.

With one or more penetration flow paths with two PCIVs inoperable except for purge valve leakage not within limit, either the inoperable PCIVs must be restored to OPERABLE status or the affected penetration flow path must be isolated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de--activated automatic valve, a closed manual valve, and a blind flange. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time is consistent with the ACTIONS of LCO 3.6.1.1.

Condition B is modified by a Note indicating this Condition is only applicable to penetration flow paths with two PC IVs except for the H20 2 Analyzer penetrations. For penetration flow paths with one PCIV, Condition C provides the appropriate Required Actions. For the H20 2 Analyzer Penetrations, Condition D provides the appropriate Required Actions.

C.1 and C.2 With one or more penetration flow paths with one PCIV inoperable, the inoperable valve must be restored to OPERABLE status or the affected penetration flow path (continued)

~

• ~~~~--' SUSQUEHANNA - UNIT 1 TS/ B 3.6-20 Rev.ision 1

Rev.12 PC IVs B 3.6.1.3 BASES ACTIONS C.1 and C.2 (continued) must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action C.1 must be completed within the 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the relative stability of the closed system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. The closed system must meet the requirements of Reference 6. For conditions where the PCIV and the closed system are inoperable, the Required Actions of TRO 3.6.4, Condition B apply. For the Excess Flow Check Valves (EFCV), the Completion Time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is reasonable considering the instrument and the small pipe diameter of penetration (hence, reliability) to act as a penetration isolation boundary and the small pipe diameter of the affected penetrations. In the event the affected penetration flow path is isolated in accordance with Required Action C.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident are isolated. The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the valves are operated under administrative controls and the probability of their misalignment is low.

Condition C is modified by a Note indicating that this Condition is only applicable to penetration flow paths with only one PCIV. For penetration flow paths with two PCIVs and the H20 2 Analyzer Penetration. Conditions A, B and D provide the appropriate Required Actions.

Required Action C.2 is modified by a Note that applies to valves and blind flanges located in high radiation areas and a*llows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted. Therefore, the probability of misalignment of these valves, once they have been verified to be in the proper position, is low.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-21 Revision 2

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS D.1 and D.2 (continued)

With one or more H20 2 Analyzer penetrations with one or both PCIVs inoperable, the inoperable valve(s) must be restored to OPERABLE status or the affected penetration flow path must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action D.1 must be completed within the 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the unique design of the H2 02 Analyzer penetrations. The containment isolation barriers for these penetrations consist of two PC IVs and a closed system. In addition, the Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the relative stability of the closed system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. In the event the affected penetration flow path is isolated in accordance with Required Action D.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident are isolated. The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the valves are operated under administrative controls and the probability of their misalignment is low.

When an H2 0 2 Analyzer penetration PCIV is to be closed and deactivated in accordance with Condition D, this must be accomplished by pulling the fuse for the power supply, and either determinating the power cables at the solenoid valve, or jumpering of the power side of the solenoid to ground.

The OPERABILITY requirements for the closed system are discussed in Technical Requirements Manual (TRM) Bases 3.6.4.

In the event that either one or both of the PCIVs and the closed system are inoperable, the Required Actions of TRO 3.6.4, Condition B apply.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-22 Revision 1

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS D.1 and D.2 (continued)

Condition D is modified by a Note indicating that this Condition is only applicable to the H2 0 2 Analyzer penetrations.

With the secondary containment bypass leakage rate not within limit, the assumptions of the safety analysis may not be met.

Therefore, the leakage must be restored to within limit within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. Restoration can be accomplished by isolating the penetration that caused the limit to be exceeded by use of one closed and de-activated automatic valve, closed manual valve, or blind flange. When a penetration is isolated, the leakage rate for the isolated penetration is assumed to be the actual pathway leakage through the isolation device. If two isolation devices are used to isolate the penetration, the leakage rate is assumed to be the lesser actual pathway leakage of the two devices. The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time is reasonable considering the time required to restore the leakage by isolating the penetration and the relative importance of secondary containment bypass leakage to the overall containment function.

F.1 In the event one or more containment purge valves are not within the purge valve leakage limits, purge valve leakage must be restored to within limits. The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Completion Time is reasonable, considering that one containment purge valve remains closed, except as controlled by SR 3.6.1.3.1 so that a gross breach of containment does not exist.

G.1 and G.2 If any Required Action and associated Completion Time cannot' be met in MODE 1, 2, or 3, 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 1 TS I B 3.6-22a Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS H.1 and H.2 (continued)

If any Required Action and associated Completion Time cannot be met, the unit must be placed in a condition in which the LCO does not apply. If applicable, 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 subsequent potential for fission product release. Actions must continue until OPDRVs are suspended or valve(s) are restored to OPERABLE status. If suspending an OPDRV would result in closing the residual heat removal (RHR) shutdown cooling isolation valves, an alternative Required Action is provided to immediately initiate action to restore the valve(s) to OPERABLE status. This allows RHR to remain in service while actions are being taken to restore the valve.

SURVEILLANCE SR 3.6.1.3.1 REQUIREMENTS This SR ensures that the primary containment purge valves are closed as required or, if open, open for an allowable reason. If a purge valve is open in violation of this SR, the valve is considered inoperable. If the inoperable valve is not otherwise known to have excessive leakage when closed, it is not considered to have leakage outside of limits. The SR is also modified by Note 1, stating that primary containment purge valves are only required to be closed in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, the purge valves may not be capable of closing before the pressure pulse affects systems downstream of the purge valves, or the release of radioactive material will exceed limits prior to the purge valves closing. At other times when the purge valves are required to be capable of closing (e.g., during handling of irradiated fuel), pressurization concerns are not present and the purge valves are allowed to be open. The SR is modified by Note 2 stating that the SR is not required to be met when the purge valves are open for the stated reasons. The Note states that these valves may be opened for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open. The vent and purge valves are capable of closing in the environment following a LOCA. Therefore, these valves are allowed to be open for (continued)

, I v SUSQUEHANNA - UNIT 1 TS I B 3.6-23 Revision 1

Rev. 12 PC IVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.1 (continued)

REQUIREMENTS limited periods of time. The 31 day Frequency is consistent with other PCIV requirements discussed in SR 3.6.1.3.2.

SR 3.6.1.3.2.

This SR verifies that each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits.

This SR does not require any testing or valve manipulation.

Rather, it involves verification that those PCIVs outside primary containment, and capable of being mispositioned, are in the correct position. Since verification of valve position for PCIVs outside primary containment is relatively easy, the 31 day Frequency was chosen to provide added assurance that the PCIVs are in the correct positions.

Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable since access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in the proper position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PC IVs are open. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.

SR 3.6.1.3.3 This SR verifies that each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-24 Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES.

SURVEILLANCE SR 3.6.1.3.3 (continued)

REQUIREMENTS secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits. For PCIVs inside primary containment, the Frequency defined as "prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days" is appropriate since these PCIVs are operated under administrative controls and the probability of their misalignment is low. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing. Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable since the primary containment is inerted and access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in their proper position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PCIVs are open.

SR 3.6.1.3.4 The traversing incore probe (TIP) shear isolation valves are actuated by explosive charges. Surveillance of explosive charge continuity provides assurance that TIP valves will actuate when required. Other administrative controls, such as those that limit the shelf life of the explosive charges, must be followed. The 31 day Frequency is based on operating experience that has demonstrated the reliability of the explosive charge continuity.

SR 3.6.1.3.5 Verifying the isolation time of each power operated and each automatic PCIV is within limits is required to demonstrate OPERABILITY. MSIVs may be excluded from this SR since MSIV (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-25 Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.5 (continued)

REQUIREMENTS full closure isolation time is demonstrated by SR 3.6.1.3.7. The isolation time test ensures that the valve will isolate in a time period less than or equal to that assumed in the Final Safety Analyses Report. The isolation time and Frequency of this SR are in accordance with the requirements of the lnservice Testing Program.

SR 3.6.1.3.6 For primary containment purge valves with resilient seals, the Appendix J Leakage Rate Test Interval of 24 months is sufficient.

The acceptance criteria for these valves is defined in the Primary Containment Leakage Rate Testing Program, 5.5.12.

The SR is modified by a Note stating that the primary containment purge valves are only required to meet leakage rate testing requirements in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, purge valve leakage must be minimized to ensure offsite radiological release is within limits.

At other times when the purge valves are required to be capable of closing (e.g., during handling of irradiated fuel), pressurization concerns are not present and the purge valves are not required to meet any specific leakage criteria.

SR 3.6.1.3. 7 Verifying that the isolation time of each MSIV is within the specified limits is required to demonstrate OPERABILITY. The isolation time test ensures that the MSIV will isolate in a time period that does not exceed the times assumed in the DBA analyses. This ensures that the calculated radiological consequences of these events remain within regulatory limits. The Frequency of this SR is in accordance with the requirements of the lnservice Testing Program.

(continued) 1* .' SUSQUEHANNA - UNIT 1 TS/ B 3.6-26 Revision 2

Rev. 12 PC IVs B 3.6.1.3 BASES SURVEILU\NCE SR 3.6.1.3.8 REQUIREMENTS (continued) Automatic PCIVs close on a primary containment isolation signal to prevent leakage of radioactive material from primary containment following a OBA. This SR ensures that each automatic PCIV will actuate to its isolation position on a primary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.1.5 overlaps this SR to provide complete testing of the safety function. The 24 month Frequency was developed considering it is prudent that some of these Surveillances be performed only during a unit outage since isolation of penetrations could eliminate cooling water flow and disrupt the normal operation of some critical components. Operating experience has shown that these components usually pass this Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.6.1.3.9 This SR requires a demonstration that a representative sample of reactor instrumentation line excess flow check valves (EFCV) are OPERABLE by verifying that the valve actuates to check flow on a simulated instrument line break. As defined in FSAR Section 6.2.4.3.5 (Reference 4), the conditions under which an EFCV will isolate, simulated instrument line break, are at flow rates, which develop a differential pressure of between 3 psid and 10 psid.

This SR provides assurance that the instrumentation line EFCVs will perform its design function to check flow. No specific valve leakage limits are specified because no specific leakage limits are defined in the FSAR. The 24 month Frequency is based on the need to perform some of these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. The representative sample consists of an approximate equal number of EFCVs such that each EFCV is tested at least once every 10 years (nominal). The nominal 1O year interval is based on other performance-based testing programs, such as lnservice Testing (snubbers) and Option B to 10 CFR 50, Appendix J. In addition, the EFCVs in the sample are representative of the various plant configurations, models, sizes and operating environments. This ensures that any potential common problems with a specific type or application of EFCV is detected at the earliest possible time. EFCV failures will be evaluated to determine if additional testing in that test interval is warranted to ensure overall reliability and that failures to isolate are very infrequent. Therefore, testing of a representative sample was concluded to be acceptable from a reliability standpoint (Reference 7).

(continued)

SUSQUEHANNA - UNIT 1 TS/ B 3.6-27 Revision 2

Rev.12 PC IVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.10 REQUIREMENTS (continued) The TIP shear isolation valves are actuated by explosive charges. An in place functional test is not possible with this design. The explosive squib is removed and tested to provide assurance that the valves will actuate when required. The replacement charge for the explosive squib shall be from the same manufactured batch as the one fired or from another batch that has been certified by having one of the batch successfully fired. The Frequency of 24 months on a STAGGERED TEST BASIS is considered adequate given the administrative controls on replacement charges and the frequent checks of circuit continuity (SR 3.6.1.3.4).

SR 3.6.1.3.11 This SR ensures that the leakage rate of secondary containment bypass leakage paths is less than the specified leakage rate. This provides assurance that the assumptions in the radiological evaluations of Reference 4 are met. The secondary containment leakage pathways and Frequency are defined by the Primary Containment Leakage Rate Testing Program. This SR simply imposes additional acceptance criteria.

A note is added to this SR, which states that these valves are only required to meet this leakage limit in MODES 1, 2, and 3. In the other MODES, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required.

SR 3.6.1.3.12 The analyses in References 1 and 4 are based on the specified leakage rate. Leakage through each MSIV must bes 100 scfh for any one MSIV and s 300 scfh for total leakage through the MSIVs combined with the Main Steam Line Drain Isolation Valve, HPCI Steam Supply Isolation Valve and the RCIC Steam Supply Isolation Valve. The MSIVs can be tested at either.:: Pt (24.3 psig) or Pa (48.6 psig). Main Steam Line Drain Isolation, HPCI and RCIC Steam Supply Line Isolation Valves, are tested at Pa (48.6 psig). A note is added to this SR, which states that these valves are only required to meet this leakage limit in MODES 1, 2, and 3.

In the other conditions, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required. The Frequency is required by the Primary Containment Leakage Rate Testing Program.

(continued)

SUSQUEHANNA - UNIT 1 TS/ B 3.6-28 Revision 7

Rev. 12 PC IVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.13 REQUIREMENTS (continued) Surveillance of hydrostatically tested lines provides assurance that the calculation assumptions of Reference 2 are met. The acceptance criteria for the combined leakage of all hydrostatically tested lines is 3.3 gpm when tested at 1.1 Pa, (53.46 psig). The combined leakage rates must be demonstrated in accordance with the leakage rate test Frequency required by the Primary Containment Leakage Testing Program.

As noted in Table B 3.6.1.3-1, PCIVs associated with this SR are not Type C tested. Containment bypass leakage is prevented since the line terminates below the minimum water level in the Suppression Chamber. These valves are tested in accordance with the IST Program. Therefore, these valves leakage is not included as containment leakage.

This SR has been modified by a Note that states that these valves are only required to meet the combined leakage rate in MODES 1, 2, and 3, since this is when the Reactor Coolant System is pressurized and primary containment is required. In some instances, the valves are required to be capable of automatically closing during MODES other than MODES 1, 2, and 3. However, specific leakage limits are not applicable in these other MODES or conditions.

REFERENCES 1. FSAR, Chapter 15.

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

3. 10 CFR 50, Appendix J, Option B.

4. FSAR, Section 6.2.

5. NED0-30851-P-A, "Technical Specification Improvement Analyses for BWR Reactor Protection System,"

March 1988.

6. Standard Review Plan 6.2.4, Rev. 1, September 1975

7. NED0-32977-A, "Excess Flow Check Valve Testing Relaxation," June 2000.

I. . SUSQUEHANNA - UNIT 1 TS/ B 3.6-29 Revision 2

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 1 of 11)

.. Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds)}

Containment 1-57-193 (d) ILRT Manual NIA Atmospheric 1-57-194 (d) ILRT Manual N/A Control HV-15703 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15704 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15705 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15711 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15713 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15714 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15721 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15722 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15723 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15724 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15725 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15766 (a) Suppression Pool Cleanup Automatic Valve 2.b, 2.d (30)

HV-15768 (a) Suppression Pool Cleanup Automatic Valve 2.b, 2.d (30)

SV-157100 A Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157100 B Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157101 A Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157101 B Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157102 A Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157102 B Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157103 A Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157103 B Containment Radiation Detection. Automatic Valve 2.b, 2.d Syst SV-157104 Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157105 Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157106 Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157107 Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-15734 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15734 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15736 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15736 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15737 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e SUSQUEHANNA - UNIT 1 TS I B 3.6-30 Revision 1

Rev.12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 2of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Containment SV-15738 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e Atmospheric SV-15740 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d Control SV-15740 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d (continued) SV-15742 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15742 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15750 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15750 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15752 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15752 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15767 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e SV-15774 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15774 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15776 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15776 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15780 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15780 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15782 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15782 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15789 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e Containment 1-26-072 (d) Containment Instrument Gas Manual Check N/A Instrument Gas 1-26-074 (d) Containment Instrument Gas Manual Check N/A 1-26-152 (d) Containment Instrument Gas Manual Check NIA 1-26-154 (d) Containment Instrument Gas Manual Check N/A 1-26-164 (d) Containment Instrument Gas Manual Check N/A HV-12603 Containment Instrument Gas Automatic Valve 2.c, 2.d (20)

SV-12605 Containment Instrument Gas Automatic Valve 2.c, 2.d SV-12651 Containment Instrument Gas Automatic Valve 2.c, 2.d SV-12654A Containment Instrument Gas Power Operated N/A SV-12654 B Containment Instrument Gas Power Operated N/A SV-12661 Containment Instrument Gas Automatic Valve 2.b, 2.d SV-12671 Containment Instrument Gas Automatic Valve 2.b, 2.d Core Spray HV-152F001 A (b)(c) CS Suction Valve Power Operated N/A HV-152F001 B (b)(c) CS Suction Valve Power Operated N/A HV-152F005 A CS Injection Power Operated N/A HV-152F005 B CS Injection Valve Power Operated N/A HV-152F006 A CS Injection Valve Air Operated Check N/A Valve HV-152F006 B CS Injection Valve Air Operated Check N/A Valve HV-152F015 A (b)(c) CS Test Valve Automatic Valve 2.c, 2.d (80)

HV-152F015 B (b)(c) CS Test Valve Automatic Valve 2.c, 2.d (80)

SUSQUEHANNA - UNIT 1 TS I B 3.6-31 Revision 3

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page3 of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Core Spray HV-152F031 A (b)(c) CS Minimum Recirculation Flow Power Operated NIA (continued) HV-152F031 B (b)(c) CS Minimum Recirculation Flow Power Operated NIA HV-152F037 A CS Injection Power Operated NIA (Air)

HV-152F037 B CS Injection !Power Operated NIA (Air)

XV-152F018 A Core Spray Excess Flow Check NIA Valve XV-152F018 B Core Spray Excess Flow Check NIA Valve HPCI 1-55-038 (d) HPCI Injection Valve Manual NIA 155F046 (b)(c)(d) HPCI Minimum Flow Check Valve Manual Check NIA 155F049 (a)(d) HPCI Turbine Exhaust Valve Manual Check NIA HV-155F002 HPCI Steam Supply Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g (50)

HV-155F003 HPCI Steam Supply Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g (50)

HV-155F006 HPCI Injection Valve Power Operated NIA HV-155F012 (b)(c) HPCI Minimum Flow Valve Power Operated NIA HV-155F042 (b)(c) HPCI Suction Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g (115)

HV-155F066 (a) HPCI Turbine Exhaust Valve Power Operated NIA HV-155F075 HPCI Vacuum Breaker Isolation Automatic Valve 3.b, 3.d (15)

Valve HV-155F079 HPCI Vacuum Breaker Isolation Automatic Valve 3.b, 3.d (15)

Valve HV-155F100 HPCI Steam Supply Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g (6)

XV-155F024 A HPCI Valve Excess Flow Check NIA Valve XV-155F024 B HPCI Valve Excess Flow Check NIA Valve XV-155F024 C HPCI Valve Excess Flow Check NIA Valve XV-155F024 D HPCI Valve Excess Flow Check NIA Valve Liquid Radwaste HV-16108 A1 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)

Collection HV-16108 A2 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)

HV-16116 A1 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)

HV-16116 A2 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)

Demin Water 1-41-017 (d) Demineralized Water Manual NIA 1-41-01 B (d) Demineralized Water Manual NIA Nuclear Boiler 141 F010 A ( d) Feedwater Isolation Valve Manual Check N/A 141F010 B (d) Feedwater Isolation Valve Manual Check NIA SUSQUEHANNA - UNIT 1 TS I B 3.6-32 Revision 1

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 4of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Nuclear Boiler 141 F039 A (d) Feedwater Isolation Valve Manual Check NIA (continued) 141 F039 B (d) Feedwater Isolation Valve Manual Check NIA 141818A(d) Feedwater Isolation Valve Manual Check NIA 141818B(d) Feedwater Isolation Valve Manual Check NIA HV-141 F016 MSL Drain Isolation Valve Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (10)

HV-141 F019 MSL Drain Isolation Valve Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (15)

HV-141F022A MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F022 B MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F022 C MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F022 D MSIV

• Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141F028A MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141F028 B MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F028 C MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141F028 D MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F032 A Feedwater Isolation Valve Power Operated NIA Check HV-141 F032 B Feedwater Isolation Valve Power Operated NIA Check XV-141F009 Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F070 A Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F070 B Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F070 C Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F070 D Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F071 A Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F071 B Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F071 C Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F071 D Nuclear Boiler EFCV Excess Flow Check NIA Valve SUSQUEHANNA - UNIT 1 TS I B 3.6-33 Revision 1

Rev. 12 PC IVs 83613 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 5 of 11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Nuclear Boiler XV-141 F072 A Nuclear Boiler EFCV Excess Flow Check NIA (continued) Valve XV-141 F072 B Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F072 C Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F072 D Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F073 A Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F073 B Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F073 C Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F073 D Nuclear Boiler EFCV Excess Flow Check NIA Valve Nuclear Boiler XV-14201 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Vessel Valve Instrumentation XV-14202 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F041 Nuclear Boiler Vessel Instrument Excess Flow Check* NIA Valve XV-142F043 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F043 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F045 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F045 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F047 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F047 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F051 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F051 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F051 C Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F051 D Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F053 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F053 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve SUSQUEHANNA - UNIT 1 TS/ B 3.6-34 Revision 0

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 6of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Nuclear Boiler XV-142F053 C Nuclear Boiler Vessel Instrument Excess Flow Check NIA Vessel Valve Instrumentation XV-142F053 D Nuclear Boiler Vessel Instrument Excess Flow Check NIA (continued) Valve XV-142F055 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F057 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 C Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 D Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 E Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 F Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 G Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 H Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 L Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 M Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 N Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 P Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 R Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 S Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 T Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 U Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F061 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve RBCCW HV-11313 RBCCW Automatic Valve 2.c, 2.d (30)

HV-11314 RBCCW Automatic Valve 2.c, 2.d (30)

HV-11345 RBCCW Automatic Valve 2.c, 2.d (30)

HV-11346 RBCCW Automatic Valve 2.c, 2.d (30) l' SUSQUEHANNA - UNIT 1 TS I B 3.6-35 Revision 0

Rev. 12 PC IVs 83613 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page7 of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

RCIC 1-49-020 (d) RCIC INJECTION Manual NIA 149F021 (b)(c)(d) RCIC Minimum Recirculation Flow Manual Check NIA 149F028 (a)(d) RCIC Vacuum Pump Discharge Manual Check NIA 149F040 (a)(d) RCIC Turbine Exhaust Manual Check NIA FV-149F019 (b)(c) RCIC Minimum Recirculation Flow Power Operated NIA HV-149F007 RCIC Steam Supply Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f, 4.g (20)

HV-149F008 RCIC Steam Supply' Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f, 4.g (20)

HV-149F013 RCIC Injection Power Operated NIA HV-149F031 (b)(c) RCIC Suction Power Operated NIA HV-149F059 (a) RCIC Turbine Exhaust Power Operated NIA HV-149F060 (a) RCIC Vacuum Pump Discharge Power Operated NIA HV-149F062 RCIC Vacuum Breaker Automatic Valve 4.b, 4.d (10)

HV-149F084 RCIC Vacuum Breaker Automatic Valve 4.b, 4.d (10)

HV-149F088 RCIC Steam Supply Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f, 4.g (12)

XV-149F044A RCIC Excess Flow Check NIA Valve XV-149F044 B RCIC Excess Flow Check NIA Valve XV-149F044 C RCIC Excess Flow Check NIA Valve XV-149F044 D RCIC Excess Flow Check NIA Valve RB Chilled HV-18781 A1 RB Chilled Water Automatic Valve 2.c, 2.d (40)

Water System HV-18781 A2 RB Chilled Water Automatic Valve 2.c, 2.d (40)

HV-18781 B1 RB Chilled Water Automatic Valve 2.c, 2.d (40)

HV-18781 B2 RB Chilled Water Automatic Valve 2.c, 2.d (40)

HV-18782 A1 RB Chilled Water Automatic Valve 2.c, 2.d (12)

HV-18782A2 RB Chilled Water Automatic Valve 2.c, 2.d (12)

HV-18782 B1 RB Chilled Water Automatic Valve 2.c, 2.d (12)

HV-18782 B2 RB Chilled Water Automatic Valve 2.c, 2.d (12)

HV-18791 A1 RB Chilled Water Automatic Valve 2.b, 2.d (15)

HV-18791 A2 RB Chilled Water Automatic Valve 2.b, 2.d (15)

HV-18791 B1 RB Chilled Water Automatic Valve 2.b, 2.d (15)

HV-18791 B2 RB Chilled Water Automatic Valve 2.b, 2.d (15)

HV-18792 A1 RB Chilled Water Automatic Valve 2.b, 2.d (8)

HV-18792A2 RB Chilled Water Automatic Valve 2.b, 2.d (8)

HV-18792 B1 RB Chilled Water Automatic Valve 2.b, 2.d (8)

HV-18792 B2 RB Chilled Water Automatic Valve 2.b, 2.d (8)

Reactor 143F013 A (d) Recirculation Pump Seal Water Manual Check NIA Recirculation 143F013 B (d) Recirculation Pump Seal Water Manual Check NIA SUSQUEHANNA - UNIT 1 TS I B 3.6-36 Revision 1

Rev. 12 PC IVs 83613 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 8of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Reactor XV-143F003A Reactor Recirculation Excess Flow Check NIA Recirculation Valve (continued) XV-143F003 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F004A Reactor Recirculation Excess Flow Check NIA Valve XV-143F004 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F009 A Reactor Recirculation Excess Flow Check NIA Valve XV-143F009 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F009 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F009 D Reactor Recirculation Excess Flow Check NIA Valve XV-143F010 A Reactor Recirculation Excess Flow Check NIA Valve XV-143F010 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F010 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F010 D Reactor Recirculation Excess Flow Check NIA Valve

~-143F011 A Reactor Recirculation Excess Flow Check NIA Valve*

XV-143F011 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F011 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F011 D Reactor Recirculation Excess Flow Check NIA Valve XV-143F012A Reactor Recirculation Excess Flow Check NIA Valve XV-143F012 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F012 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F012 D Reactor Recirculation Excess Flow Check NIA Valve XV-143F017 A Recirculation Pump Seal Water Excess Flow Check NIA Valve XV-143F017 B Recirculation Pump Seal Water Excess Flow Check NIA Valve XV-143F040 A Reactor Recirculation Excess Flow Check NIA Valve SUSQUEHANNA - UNIT 1 TS I B 3.6-37 Revision 0

Rev. 12 PC IVs 83613 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 9of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Reactor XV-143F040 B Reactor Recirculation Excess Flow Check NIA Recirculation Valve (continued) XV-143F040 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F040 D Reactor Recirculation Excess Flow Check NIA Valve XV-143F057 A Reactor Recirculation Excess Flow Check NIA Valve XV-143F057 B Reactor Recirculation Excess Flow Check NIA Valve HV-143F019 Reactor Coolant Sample Automatic Valve 2.b (9)

HV-143F020 Reactor Coolant Sample Automatic Valve 2.b (2)

Residual Heat HV-151 F004 A (b)(c) RHR - Suppression Pool Suction Power Operated NIA Removal HV-151 F004 B (b)(c) _RHR - Suppression Pool Suction Power Operated NIA HV-151 F004 C (b)(c) RHR - Suppression Pool Suction Power Operated NIA HV-151F004 D (b)(c) RHR - Suppression Pool Suction Power Operated NIA HV-151 FOO? A (b)(c) RHR-Minimum Recirculation Flow Power Operated NIA HV-151 FOO? B (b)(c) RHR-Minimum Recirculation Flow Power Operated 'NIA HV-151 FOOS RHR - Shutdown Cooling Suction Automatic Valve 6.a, 6.b, 6.c (52)

HV-151F009 RHR - Shutdown Cooling Suction Automatic Valve 6.a, 6.b, 6.c (52)

HV-151 F011 A (b)(d) RHR-Suppression Pool Manual NIA Cooling/Spray HV-151F011 B (b)(d) RHR-Suppression Pool Manual NIA Cooling/Spray HV-151 F015 A (f) RHR - Shutdown Cooling Power Operated NIA Return/LPCI Injection HV-151F015 B (f) RHR - Shutdown Cooling Power Operated NIA Return/LPCI Injection HV-151 F016 A (b) RHR - Drywell Spray Automatic Valve 2.c, 2.d (90)

HV-151 F016 B (b) RHR - Drywell Spray Automatic Valve 2.c, 2.d (90)

HV-151F022 RHR - Reactor Vessel Head Spray Automatic Valve 2.d, 6.a, 6.b, 6.c (30)

. HV-151F023 RHR - Reactor Vessel Head Spray Automatic Valve 2.d, 6.a, 6.b, 6.c (20)

HV-151F028 A (b) . RHR - Suppression Pool Automatic Valve 2.c, 2.d (90)

Cooling/Spray HV-151 F028 B (b) RHR - Suppression Pool Automatic Valve 2.c, 2.d (90)

Cooling/Spray HV-151 F050 A (g) RHR - Shutdown Cooling Air Operated Check NIA Return/LPCI Injection Valve Valve HV-151 F050 B (g) RHR - Shutdown Cooling Air Operated Check NIA Return/LPCI Injection Valve Valve HV-151F103 A (b) RHR Heat Exchanger Vent Power Operated NIA HV-151F103 B (b) RHR Heat Exchanger Vent Power Operated NIA SUSQUEHANNA - UNIT 1 TS I B 3.6-38 Revision 3

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 10of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Residual Heat HV-151F122 A (g) RHR - Shutdown Cooling Power Operated NIA Removal ReturnlLPCI Injection Valve (Air)

(continued) HV-151F122 B (g) RHR - Shutdown Cooling Power Operated NIA ReturnlLPCI Injection Valve (Air)

PSV-15106 A (b)(d) RHR - Relief Valve Discharge Relief Valve NIA PSV-15106 B (b)(d) RHR - Relief Valve Discharge Relief Valve NIA PSV-151F126 (d) RHR - Shutdown Cooling Suction Relief Valve NIA XV-15109A RHR Excess Flow Check NIA Valve XV-15109 B RHR Excess Flow Check NIA Valve XV-15109 C RHR Excess Flow Check NIA Valve XV-15109 D RHR Excess Flow Check NIA Valve RWCU HV-144F001 (a) RWCU Suction Automatic Valve 5.a, 5.b, 5.c, 5.d, 5.f, 5.g (30)

HV-144F004 (a) RWCU Suction Automatic Valve 5.a, 5.b, 5.c, 5.d, 5.e, 5.f, 5.g (30)

XV-14411 A RWCU Excess Flow Check NIA Valve XV-14411 B RWCU Excess Flow Check NIA Valve XV-14411 C RWCU Excess Flow Check NIA Valve XV-14411 D RWCU Excess Flow Check NIA Valve XV-144F046 RWCU Excess Flow Check NIA Valve HV-14182 A RWCU Return Isolation Valve Power Operated NIA HV-14182 B RWCU Return Isolation Valve Power Operated NIA SLCS 148F007 (a)(d) SLCS Manual Check NIA HV-148F006 (a) SLCS Power Operated NIA Check Valve TIP System C51-J004 A (Shear TIP Shear Valves Squib Valves NIA Valve)

C51-J004 B (Shear TIP Shear Valves Squib Valves NIA Valve)

C51-J004 C (Shear TIP Shear Valves Squib Valves NIA Valve)

C51-J004 D (Shear TIP Shear Valves Squib Valves NIA Valve)

C51-J004 E (Shear TIP Shear Valves Squib Valves NIA Valve)

SUSQUEHANNA - UNIT 1 TS I B 3.6-39 Revision 2

Rev. 12 PC IVs B 3.6.1 3 TableB 3.6.1.3-1 Primary Containment Isolation Valve (Page 11 of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

TIP System C51-J004 A (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

(continued) Valve)

C51-J004 B (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

C51-J004 C (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

C51-J004 D (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

C51-J004 E (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

(a) Isolation barrier remains water filled or a water seal remains in the line post-LOCA, isolation valve is tested with water. Isolation valve leakage is not included in 0.60 La total Type B and C tests.

(b) Redundant isolation boundary for this valve is provided by the closed system whose integrity is verified by the Leakage Rate Test Program. This footnote does not apply to valve 155F046 (HPCI) when the associated PCIV, HV155F012 is closed and deactivated. Similarly, this footnote does not apply to valve 149F021 (RCIC) when it's associated PCIV, FV149F019 is closed and deactivated.

(c) Containment Isolation Valves are not Type C tested. Containment bypass leakage is prevented since the line terminates below the minimum water level in the Suppression Chamber. Refer to the IST Program.

(d) LCO 3.3.3.1, "PAM Instrumentation," Table 3.3.3.1-1, Function 6, does not apply since these are relief valves, check valves, manual valves or deactivated and closed.

(e) The containment isolation barriers for the penetration associated with this valve consists of two PC IVs and a closed system. The closed system provides a redundant isolation boundary for both PC IVs, and its integrity is required to be verified by the Leakage Rate Test Program.

(f) Redundant isolation boundary for this valve is provided by the closed system whose integrity is verified by the Leakage Rate Test Program.

(g) These valves are not required to be 10 CFR 50, Appendix J tested since the HV-151 F015A(B) valves and a closed system form the 10 CFR 50, Appendix J boundary. These valves form a high/low pressure interface and are pressure tested in accordance with the pressure test program.

SUSQUEHANNA - UNIT 1 TS I B 3.6-40 Revision 6

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-2 Secondary Cont~inment Bypass Leakage Isolation Valves (Not PCIVs)

(Page 1 of 1)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Residual Heat HV-151 F040 RHR - RADWASTE LINE IB ISO Automatic Valve 2.a, 2.d (45)

Removal VLV HV-151F049 RHR- RADWASTE LINE OB ISO Automatic Valve 2.a, 2.d (20)

VLV 1-51-136 RHR - COND TRANSFER OB SCBL Check Valve NIA CHECK VALVE 1-51-137 RHR - COND TRANSFER IB SCBL Check Valve NIA CHECK VALVE SUSQUEHANNA - UNIT 1 TS I B 3.6-40a Revision 1

Apr. 14, 2016 Page 1 of 2 MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2016-14 734 USER INFORMATION:

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

TO: GERLACH*ROSEY M 04/14/2016 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.

TSBl - TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 04/11/2016 ADD MANUAL TABLE OF CONTENTS DATE: 04/13/2016 CATEGORY: DOCUMENTS TYPE: TSBl

Apr. 14, 2016 Page 2 of 2 ID: TEXT 3.4.5 ADD: REV: 2 REMOVE: REV:l CATEGORY: DOCUMENTS TYPE: TSBl ID : TEXT 3 . 6 . 1. 3 REMOVE: REV: 11 ADD: REV: 12 CATEGORY: DOCUMENTS TYPE: TSBl ID: TEXT LOES REMOVE: REV:l22 ADD: REV: 123 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: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL Table Of Contents Issue Date: 04/13/2016 Procedure Name Rev Issue Date Change ID Change Number TEXT LOES 123 04/13/2016

Title:

LIST OF EFFECTIVE SECTIONS TEXT TOC 23 07 /0 2/2014

Title:

TABLE OF CONTENTS TEXT 2.1.1 6 01/22/2015

Title:

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

Title:

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

Title:

LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY TEXT 3.1.1 1 04/18/2006

Title:

REACTIVITY CONTROL SYSTEMS SHUTDOWN MARGIN (SDM)

TEXT 3.1.2 0 11/15/2002

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 /06/2 005

Title:

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

Title:

REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Page 1. of _a Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl I I Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3 .1. 7 3 04/23/2008

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 2 04/23/2008

Title:

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

TEXT 3.2.2 3 05 / 06 /2 009

Title:

POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)

TEXT 3.2.3 2 04/23/2008

Title:

POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE (LHGR)

j

* TEXT 3. 3 .1 .1 6 02 / 24 /2 014

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATION TEXT 3.3 . 1 .2 2 . 01 /1 9/2009

Title:

INSTRUMENTATION SOURCE RANGE MONITOR (SRM) INSTRUMENTATION TEXT 3.3.2.1 4 02 /24/2014

Title:

INSTRUMENTATION CONTROL ROD BLOCK INSTRUMENTATION TEXT 3.3.2.2 2 04 / 05 /2010

Title:

INSTRUMENTATION FEEDWATER MAIN TURBINE HIGH WATER LEVEL TRIP INSTRUMENTATION TEXT 3.3.3.l 9 02/28/2013

Title:

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

Title:

INSTRUMENTATION REMOTE SHUTDOWN SYSTEM TEXT 3.3.4.1 2 02/24/2014

Title:

INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATIO~

Page 2. of 1l. Report Date: 04 / 13 /16

SSES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.3.4.2 0 11/15/2002

Title:

INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP (ATWS-RPT} INSTRUMENTATION TEXT 3.3.5.l 3 08/20/2009

Title:

INSTRUMENTATION EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION TEXT 3.3.5.2 0 11/15/2002

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.l 2 12/17 /2007

Title:

INSTRUMENTATION LOSS OF POWER (LOP) INSTRUMENTATION TEXT 3.3.8.2 0 11/15/2002

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORING TEXT 3.4.1 4 04/27/2010

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 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE Page .l of Ji Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl

• -

• Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL

. j ~::-::. ~=:-.::

TEXT 3.4.5 2 04/13/2016

Title:

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:

REACTOR COOLANT 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 1 03/28/2013

Title:

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

- COLD SHUTDOWN

(~-:*=iF~ TEXT 3.4.10 4 11/04/2015 ,I

Title:

REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE (P/T) LIMITS TEXT 3.4.11 0 11/15/2002

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 0 11/15/2002

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 04/23/2008

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK Page 1. of Ji Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3 . 6 . 1. 3 12 04/13/2016

Title:

• CONTAINMENT SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)

TEXT 3 . 6 . 1. 4 1 04/23/2008

Title:

CONTAINMENT SYSTEMS CONTAINMENT PRESSURE TEXT 3 . 6 . 1. 5 1 10/05/2005

Title:

CONTAINMENT SYSTEMS DRYWELL AIR TEMPERATURE TEXT 3 . 6 . 1. 6 0 11/15/2002

Title:

CONTAINMENT SYSTEMS SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKERS TEXT 3~6.2.l 2 04/23/2008

Title:

CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE

, )~ TEXT 3 . 6 . 2 . 2 0 11/15/2002

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 11/15/2002

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 11 11/06/2014

• Title: CONTAINMENT SYSTEMS SECONDARY CONTAINMENT Page .5. of _a Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.6.4.2 10 02/02/2016

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT ISOLATION VALVES (SCIVS)

TEXT 3.6.4.3 4 09/21/2006

Title:

CONTAINMENT SYSTEMS STANDBY GAS TREATMENT (SGT) SYSTEM TEXT 3.7.1 4 04/05/2010

Title:

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

TEXT 3.7.2 2 02/11/2009

Title:

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

Title:

PLANT SYSTEMS CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM 0 11/15/2002

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 2 04/23/2008

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 .o 04/23/2008

Title:

PLANT SYSTEMS TEXT 3.8.1 7 02/24/2014

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING TEXT 3.8.2 0 11/15/2002

~~:~~-> :~

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - SHUTDOWN

." --:._~~-=-'

Page Q. of Ji Report Date: 04/13/16

SSES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 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:

ELECTRICAL POWER SYSTEMS DC SOURCES - SHUTDOWN TEXT 3.8.6 1 12/14/2006

Title:

ELECTRICAL POWER SYSTEMS BATTERY CEµL PARAMETERS TEXT 3.8.7 1 10/05/2005

Title:

ELECTRICAL POWER SYSTEMS DISTRIBUTION SYSTEMS - OPERATING TEXT 3.8.8 0 11/15/2002

Title:

ELECTRICAL POWER SYSTEMS DISTRIBUTION SYSTEMS SHUTDOWN TEXT 3.9.1 0 11/15/2002

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 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION TEXT 3.9.4 0 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/15/2002

Title:

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

Title:

REFUELING OPERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL Page 1. of _8_ Report Date: 04/13/16

.ssES MANUAL Manual Name: TSBl Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.9.7 0 11/15/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - HIGH WATER.LEVEL TEXT 3.9.8 0 11/15/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - LOW WATER LEVEL TEXT 3.10.l 1 01/23/2008 Titleg SPECIAL OPERATIONS INSERVICE LEAK AND HYDROSTATIC TESTING OPERATION TEXT 3.10.2 0 11/15/2002 Titleg SPECIAL OPERATIONS REACTOR MODE SWITCH INTERLOCK TESTING TEXT 3.10.3 0 11/15/2002 Titleg SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - HOT SHUTDOWN

~-

TEXT 3.10.4 0 11/15/2002

• - -P *i

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - COLD SHUTDOWN TEXT 3.10.5 0 11/15/2002 Titleg SPECIAL OPERATIONS SINGLE CONTROL ROD DRIVE (CRD) REMOVAL - REFUELING TEXT 3.10.6 0 11/15/2002

Title:

SPECIAL OPERATIONS MULTIPLE CONTROL ROD WITHDRAWAL - REFUELING TEXT 3.10.7 1 04/18/2006 Titleg SPECIAL OPERATIONS CONTROL ROD TESTING - OPERATING TEXT 3.10.8 1 04/12/2006 Titleg SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING Page .a of .a Report Date: 04/13/16

SUSQUEHANNA STEAM ELECTRIC STATI ON LIST OF EFFECTIVE SECTIONS (TECHNICAL SPEC IFICATIONS BASES)

Section Title Revision TOC Table of Contents 23 B 2.0 SAFETY LIMITS BASES Page TS I B 2.0-1 1 Page TS I B 2.0-2 3 Page TS I B 2.0-3 6 Page TS I B 2.0-4 4 Page TS I B 2.0-5 6 Page TS I B 2.0-6 1 Pages TS I B 2.0-7 through TS I 8 2.0-9 1 I

8 3.0 LCO AND SR APPLICABILITY BASES Page TS I B 3.0-1 1 Pages TS I B 3.0-2 through TS I B 3.0-4 0 Pages TS I B 3.0-5 through TS I 8 3.0-7 1 Page TS I B 3.0-8 3 Pages TS I B 3.0-9 through TS I 8 3.0-11 2 Page TS I B 3.0-11a 0 Page TS I B 3.0-12 1 Pages TS I B 3.0-13 through TS I B 3.0-15 2 Pages TS I B 3.0-16 and TS I B 3.0-17 0 B 3.1 REACTIVITY CONTROL BASES Pages B 3.1-1 through B 3.1-4 0 Page TS I 8 3.1-5 1 Pages TS I B 3.1 -6 and TS I 8 3.1-7 2 Pages 8 3.1-8 through B 3.1-13 0 Page TS I 8 3.1-14 1 Page B 3.1-15 0 Page TS I B 3.1-16 1 Pages B 3.1-17 through B 3.1-19 0 Pages TS I B 3.1-20 and TS I B 3.1-21 1 Page TS I B 3.1-22 0 Page TS I B 3.1-23 1 Page TS I 8 3.1-24 0 Pages TS I B 3.1-25 through TS I B 3.1-27 1 Page TS I B 3.1-28 2 Page TS I B 3.1-29 1 Pages B 3.1-30 through B 3.1-33 0 Pages TS I B 3.3-34 through TS I B 3.3-36 1 Page TS I B 3.1-37 2 Page TS I B 3.1-38 3 Pages TS I B 3.1 -39 and TS I B 3.1-40 2 Page TS I B 3.1-40a 0 Pages TS I B 3.1-41 and TS I B 3.1-42 2 SUSQUEHANNA - UNIT 1 TS I B LOES-1 Revision 123

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

Section Title Revision Page TS I B 3.1.43 1 Page TS I B 3.1-44 0 Page TS I B 3.1-45 3 Pages TS I B 3.1-46 through TS I B 3.1-49 1 Page TS I B 3.1-50 0 Page TS I B 3.1-51 3 B 3.2 POWER DISTRIBUTION LIMITS BASES Page TS I B 3.2-1 2 Pages TS I B 3.2-2 and TS I B 3.2-3 3 Pages TS I 8 3.2-4 and TS I B 3.2-5 2 Page TS I B 3.2-6 3 Page B 3.2-7 1 Pages TS I B 3.2-8 and TS I B 3.2-9 3.

Page TS I B 3.2.10 2 Page TS I B 3.2-11 3 Page TS I B 3.2-12 1 Page TS I B 3.2-13 2 B 3.3 INSTRUMENTATION Pages TS I B 3.3-1 through TS I B 3.3-4 1 Page TS I B 3.3-5 2 Page TS I B 3.3-6 1 Page TS I B 3.3-7 3 Page TS I B 3.3-7a 1 Page TS I B 3.3-8 5 Pages TS I B 3.3-9 through TS I B 3.3-12 3 Pages TS I B 3.3-12a 1 Pages TS I B 3.3-12b and TS I B 3.3-12c 0 Page TS I B 3.3-13 1 Page TS I B 3.3-14 3 Pages TS I B 3.3-15 and TS I B 3.3-16 1 Pages TS I B 3.3-17 and TS I B 3.3-18 4 Page TS I B 3.3-19 1 Pages TS I B 3.3-20 through TS I B 3.3-22 2 Page TS I B 3.3-22a 0 Pages TS I B 3.3-23 and TS I B 3.3-24 2 Pages TS I B 3.3-24a and TS I B 3.3-24b 0 Page TS I B 3.3-25 3 Page TS I B 3.3-26 2 Page TS I B 3.3-27 1 Page TS I B 3.3-28 3 Page TS I B 3.3-29 4 Page TS I B 3.3-30 3

• Page TS I B 3.3*30a 0 SUSQUEHANNA - UNIT 1 TS I B LOES~2 Revision 123

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

Section Title Revision Page TS I B 3.3-31 4 Page TS I B 3.3-32 5 Pages TS I B 3.3-32a 0 Page TS I B 3.3-32b 1 Page TS I B 3.3-33 5 Page TS I B 3.3-33a 0 Page TS I B 3.3-34 1 Pages TS I B 3.3-35 and TS I B 3.3-36 2 Pages TS I B 3.3-37 and TS I B 3.3-38 1 Page TS I B 3.3-39 2 Pages TS I B 3.3-40 through TS I B 3.3-43 1 Page TS I B 3.3-44 4 Pages TS I B 3.3-44a and TS I B 3.3-44b 0 Page TS I B 3.3-45 3 Pages TS I B 3.3-45a and TS I B 3.3-45b 0

• Page TS I B 3.3-46 3 Pages TS I B 3.3-47 2 Pages TS I B 3.3-48 through TS I B 3.3-51 3 Pages TS I B 3.3-52 and TS I B 3.3-53 2 Page TS I B 3-3-53a 0 Page TS I B 3.3-54 5 Page TS I B 3.3-55 2 Pages TS I B 3.3-56 and TS I B 3.3-57 1 Page TS I B 3.3-58 0 Page TS I B 3.3-59 1 Page TS I B 3.3-60 0 Page TS I B 3.3-61 1 Pages TS I B 3.3-62 and TS I B 3.3-63 0 Pages TS I B 3.3-64 and TS I B 3.3-65 2 Page TS I B 3.3-66 4 Page TS I B 3.3-67 3 Page TS I B 3.3-68 4 Page TS I 8 3.3-69 5 Pages TS I B 3.3-70 4 Page TS I B 3.3-71 3 Pages TS I 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 Page TS I B 3.3M75a 6 Page TS I B 3.3-75b 7 Page TS I B 3.3-75c 6 Pages B 3.3-76 through B 3.3-77 0 Page TS I B 3.3-78 1 SUSQUEHANNA - UNIT 1 TS I B LOES-3 Revision 123

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

Section Title Revision Pages B 3.3-79 through B 3.3~81 0 Page TS I B 3.3-82 2 Page B 3.3-83 0 Pages B 3.3-84 and B 3.3-85 1 Page B 3.3-86 0 Page B 3.3-87 1

• Page B 3.3-88 0 Page B 3.3-89 1 Page TS I B 3.3-90 1 Page B 3.3-91 0 Pages TS I B 3.3-92 through TS I B 3.3-100 1 Pages TS I B 3.3-101 through TS I B 3.3-103 0 Page TS I B 3.3-104 2 Pages TS I B 3.3-105 and TS I B 3.3-106 0 Page TS I B 3.3-107 1 Page TS I B 3.3-108 0 Page TS I B 3.3-109 1 Pages TS I B 3.3-110 and TS I B 3.3-111 0 Pages TS I B 3.3-112 and TS/ B 3.3-112a 1 Pages TS I B 3.3-113 through TS I B 3.3-115 1 Page TS I B 3.3-116 3 Page TS I B 3.3-117 1 Pages TS I B 3.3-118 through TS I B 3.3-122 0 Pages TS I B 3.3-123 and TS/ 8 3.3-124 1 Page TS I B 3.3-124a 0 Page TS I B 3.3-125 0 Pages TS I B 3.3-126 and TS I B 3.3-127 1 Pages TS I B 3,3-128 through TS/ B 3.3-130 0 Page TS I B 3.3-131 1 Pages TS I B 3.3-132 through TS I B 3.3-134 0 Pages B 3.3-135 through B 3.3-137 0 Page TS I B 3.3-138 1 Pages B 3.3-139 through B 3.3-149 0 Pages TS I B 3.3-150 and TS I B 3.3-151 1 Pages TS I B 3.3-152 through TS I B 3.3-154 2 Page TS I B 3.3-155 1 Pages TS I B 3.3-156 through TS I B 3.3-158 2 Pages TS I B 3.3-159 and TS I B 3.3-160 1 Page TS I B 3.3-161 2 Page TS I B 3.3-162 1 Page TS I B 3.3-163 2 Page* TS I B 3.3-164 1 Pages TS I B 3.3-165 through TS I B 3.3-167 2 SUSQUEHANNA - UNIT 1 TS/ B LOES-4 Revision 123

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

• - ~: ..~

'. Section Title Revision Pages TS I B 3.3-168 and TS I B 3.3-169 1 Page TS I B 3.3-170 3 Page TS I B 3.3-171 2 Pages TS I B 3.3-172 through TS I B 3.3-177 1 Pages TS I B 3.3-178 and TS I B 3.3-179 2 Page TS I B 3.3-179a 2 Pages TS I B 3.3-179b and TS I B 3.3-179c 0 Page TS/ .B 3.3-180 1 Page TS I B 3.3-181 3 Page TS I B 3.3-182 1 Page TS I B 3.3-183 2 Page TS I B 3.3-184 1 Page TS I B 3.3-185 4 Page TS I B 3.3-186 1 Pages TS I B 3.3-187 and TS I B 3.3-188 2 Pages TS I B 3.3-189 through TS I B 3.3-191 1 Page TS I B 3.3-192 0 Page TS I B 3.3-193 1 Pages TS I B 3.3-194 and TS I B 3.3-195 0 Page TS I B 3.3-196 2 Pages TS I B 3.3-197 through TS I B 3.3-204 0 Page TS I B 3.3-205 1 Pages B 3.3-206 through B 3.3-209 0

• --.~"?-~-~-

~ Page TS I B 3.3-210 1 Pages B 3.3-211throughB3.3-219 0 B 3.4 REACTOR COOLANT SYSTEM BASES Pages B 3.4-1 and B 3.4-2 0 Pages TS I B 3.4-3 and Page TS I B 3.4-4 4 Page TS I B 3.4-5 3 Pages TS I B 3.4-6 through TS I B 3.4-9 2 Page IS I B 3.4-10

• 1 Pages TS I 3.4-11 and TS I B 3.4-12 0 Page TS I B 3.4-13 2 Page TS I B 3.4-14 1 Page TS I B 3.4-15 2 Pages TS I B 3.4-16 and TS I B 3.4-17 4 Page TS I B 3.4-18 2 Pages 8 3.4-19 thr~ugh B 3.4-27 0 Page TS I B 3.4-28 1 Pages TS I B 3.4-29 and TS I B 3.4-30 2 Page TS I B 3.4-31 1 Pages TS I B 3.4-32 and TS I B 3.4-33 2 Page TS I B 3.4-34 1 Page TS I B 3.4-34a 0

~~~-;::" ' SUSQUEHANNA - UNIT 1 TS I B LOES-5 Revision 123

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

'.--::-:r. Section Title Revision

• Pages TS I B 3.4-35 and TS I B 3.4-36 1 Page TS I B 3.4-37 2 Page TS I B 3.4-38 1 Pages B 3.4-39 and B 3.4-40 0 Page TS I B 3.4-41 2 Pages TS I B 3.4-42 through TS I B 3.4-45 0 Page TS I B 3.4-46 1 Pages TS B 3.4-47 and TS I B 3.4-48 . 0 Page TS I B 3.4-49 3 Page TS I B 3.4-50 1 Page TS I B 3.4-51 3 Page TS I B 3.4-52 3 Page TS I B 3.4-52a 0 Pages TS I B 3.4-53 through TS I B 3.4-56 2 Page TS I B 3.4-57 4 Page TS I B 3.4-57a 0 Pages TS I B 3.4-58 through TS I B 3.4-60 1 B 3.5 ECCS AND RCIC BASES Pages B 3.5-1 and B 3.5-2 0 Page TS I B 3.5-3 3 Page TS I B 3.5-4 1 Page TS I B 3.5-5 2 Page TS I B 3.5-6 1 Pages B 3.5-7 through B 3.5-10 0 Page TS I B 3.5-11 1 Page TS I B 3.5-12 0 Page TS I B 3.5-13 2 Pages TS I B 3.5-14 and TS I B 3.5-15 0 Pages TS/ B 3.5-16 and TS I B 3.5-17 3 Page TS I B 3.5-18 1 Pages B 3.5-19 through B 3.5-24 0 Page TS I B 3.5-25 1 Page TS I B 3.5-26 and TS I B 3.5-27 2 Page TS I B 3.5-28 0 Page TS I B 3.5-29 1 Pages TS I B 3.5-30 and TS I B 3.5-31 0 83 ..6 CONTAINMENT SYSTEMS BASES Page TS I B 3.6-1 2 Page TS I B 3.6-1a 3 Page TS I B 3.6-2 4 Page TS I B 3.6-3 3 Page TS I B 3.6-4 4 Pages TS I B 3.6-5 and TS I B 3.6-6 3 SUSQUEHANNA - UNIT 1 TS I B LOES-6 Revision 123

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

Section Title Revision Page TS I B 3.6-6a 2 Page TS I B 3.6-6b 4 Page TS I B 3.6-6c 0 Page B 3.6-7 0 Page B 3.6-8 1 Pages B 3.6-9 through B 3.6-14 0 Page TS I B 3.6-15 3 Page TS I B 3.6-15a 0 Page TS I B 3.6-15b 3 Pages TS I B 3.6-16 and TS I B 3.6-17 2 Page TS I B 3.6-17a 1 Pages TS I B 3.6-18 and TS I B 3.6-19 0 Page TS I B 3.6-20 1 Page TS I B 3.6-21 2 Page TS I B 3.6-22 1 Page TS I B 3.6-22a 0 Page TS I B 3.6-23 1 Pages TS I B 3.6-24 and TS I B 3.6-25 0 Pages TS I B 3.6-26 and TS I B 3.6-27 2 Page TS I B 3.6-28 7 Page TS I B 3.6-29 2 Page TS I B 3.6-30 1 Page TS I B 3.6-31 3 Pages TS I B 3.6-32 and TS I B 3.6-33 1 Pages TS I B 3.6-34 and TS I B 3.6-35 0 Page TS I B 3.6-36 1 Page TS I B 3.6-37 0 Page TS I B 3.6-38 3 Page TS I B 3.6-39 2 Page TS I B 3.6-40 6 Page TS I B 3.6-40a 1 Page B 3.6-41 1 Pages B 3.6-42 and B 3.6-43 0 Pages TS I B 3.6-44 and TS I B 3.6-45 1 Page TS I B 3.6-46 2 Pages TS I B 3.6-47 through TS I B 3.6-51 1 Page TS I B 3.6-52 2 Pages TS I B 3.6-53 through TS I B 3.6-56 0 Page TS I B 3.6-57 1 Page TS I 3.6-58 2 Pages B 3.6-59 through B 3.6-63 0 Pages TS I B 3.6-64 and TS I B 3.6-65 1 Pages B 3.6-66 through B 3.6-69 0

~ SUSQUEHANNA - UNIT 1 TS I B LOES-7 Revision 123

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

Section Title Revision Pages TS I B 3.6-70 through TS I B 3.6-75 . 1 Pages B 3.6-76 and B 3.6-77 0 Page TS I B 3.6-78 1 Pages B 3.6-79 and B 3.3.6-80 0 Page TS I B 3.6-81 1 Pages TS I B 3.6-82 and TS I B 3.6-83 0 Page TS I B 3.6-84 4 Page TS I B 3.6-85 2 Page TS I B 3.6-86 4 Pages TS I B 3.6-87 through TS I B 3.6-88a 2 Page TS I B 3.6-89 6*

Page TS I B 3.6-90 4 Page TS I B 3.6-90a 0 Pages TS I B 3.6-91 and TS I B 3.6-92 3 Page TS I B 3.6-93 2 Pages TS I B 3.6-94 through TS I B 3.6-96 1 Page TS I B 3.6-97 2.

Page TS I B 3.6-98 1 Page TS I B 3.6-99 2 Pages TS I B 3.6-100 7 Page TS I B 3.6-100a 6 Page TS I B 3.6-100b 4 Page TS I B 3.6-100c 0 Pages TS I B 3.6-101 and TS I B 3.6-102 1 Pages TS I B 3.6-103 and TS I B 3.6-104 2 Page TS I B 3.6-105 3 Page TS I B 3.6-106 2 Page TS I B 3.6-107 3 B 3.7 PLANT SYSTEMS BASES Pages TS I B 3.7-1 3 Page TS I B 3.7-2 4 Pages TS I B 3.7-3 through TS I B 3.7-5 3 Page TS I B 3.7-Sa 1 Page TS I B 3.7-6 3 Page TS I B 3.7-6a 2 Page TS I B 3.7-6b

• 1 Page TS I B 3.7-6c 2 Page TS I B 3.7-7 3 Page TS I B 3.7-8 2 Pages TS I B 3.7-9 through TS I B 3.7-11 1 Pages TS I B 3.7-12 and TS I B 3.7-13 2 Pages TS I B 3.7-14 through TS I B 3.7-18 3 Page TS I B 3.7-18a . 1 Pages TS I B 3.7-18b through TS I B 3.7-18e 0 SUSQUEHANNA - UNIT 1 TS I B LOES-8 Revision 123

SUSQUEHANNA STEAM ELECTRIC STATION L/STOF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

"";:,..:** Section Title Revision Pages TS I B 3.7-19 through TS I B 3.7-23 1 Page TS I B 3.7-24 1 Pages TS I B 3.7-25 and TS I B 3.7-26 0 Pages TS I B 3.7-27 through TS I B 3.7-29 5 Page TS I B 3.7-30 2 Page TS I B 3.7-31 . 1 Page TS I B 3.7-32 0 Page TS I B 3.7-33 1 Pages TS I B 3.7-34 through TS I B 3.7-37 0 B3.8 ELECTRICAL POWER SYSTEMS BASES Page TS I B 3.8-1 3 Pages TS I B 3.8-2 and TS I B 3.8-3 2 Page TS I B 3.8-4 3 Pages TS I 8 3.8-4a and TS I 8 3.8-4b 0 Page TS I B 3.8-5 5 Page TS I 8 3.8-6 3 Pages TS I 8 3.8-7 through TS/B 3.8-8 2 Page TS I B 3.8-9 4 Page TS I B 3.8-10 3 Pages TS I B 3.8-11 and TS I B 3.8-17 2 Page TS I B 3.8-18 3 Pages TS I B 3.8-19 through TS I B 3.8-21 2 Pages TS I B 3.S:-22 and TS I 8 3.8-23 3 Pages TS I B 3.8-24 through TS I B 3.8-30 2 Pages TS I 8 3.8-31 and TS I B 3.8-32 3 Pages TS I B 3.8-33 through TS I B 3.8-37 2 Pages B 3.8-38 through B 3.8-44 0 Page TS I B 3.8-45 3 Pages TS I B 3.8-46 through TS I B 3.8-48 0 Pages TS I 8 3.8-49 and TS I B 3.8-50 3 Page TS I B 3.8-51 1 Page TS I B 3.8-52 0 Page TS I 8 3.8-53 1 Pages TS I 8 3.8-54 through TS I 8 3.8-57 2 Pages TS I B 3.8-58 through TS I 8 3.8-61 3 Pages TS I 8 3.8-62 and TS I B 3.8-63 5 Page TS I B 3.8-64 4 Page TS I B 3.8-65 5 Pages TS I B 3.8-66 through TS I 8 3.8-77 1 Pages TS I 8 3.8-77A through TS I B 3.8-77C 0 Pages B 3.8-78 through B 3.8-80 0 Page TS I 8 3.8-81 1 Pages B 3.8-82 through B 3.8-90 0 SUSQUEHANNA - UNIT 1 TS I B LOES-9 Revision 123

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

Section Title Revision B 3.9 REFUELING OPERATIONS BASES Pages TS I B 3.9-1 and TS I B 3.9-1a 1 Pages TS I B 3.9-2 through TS I B 3.9-5 1 Pages TS I B 3.9-6 through TS I B 3.9-8 0 Pages B 3.9-9 through B 3.9-18 0 Pages TS I B 3.9-19 through TS I B 3.9-21 1 Pages B 3.9-22 through B 3.9-30 0 B 3.10 SPECIAL OPERATIONS BASES Page TS I B 3.10-1 2 Pages TS I B 3.10-2 through TS I B 3.10-5 1 Pages B 3.10-6 through B 3.10-31 0 Page TS I B 3.10-32 2 Page B 3.10-33

• 0 Page TS I B 3.10-34 1 Pages B 3.10-35 and B 3.10-36 0 Page TS I B 3.10-37 1 Page TS I B 3.10-38 2 SUSQUEHANNA - UNIT 1 TS I B LOES-10 Revision 123

Rev. 2 RCS PIV Leakage B'3.4.5

.-;-f ~ . B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.5 RCS Pressure Isolation Valve (PIV) Leakage BASES BACKGROUND The function of RCS PIVs is to separate the high pressure RCS from an attached low pressure system. This protects the RCS pressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), and GDC 55of10 CFR 50, Appendix A (Refs. 1, 2, and 3). RCS PIVs are defined as any two normally closed valves in series within the reactor coolant pressure boundary (RCPB). PIVs are designed to meet the requirements of Reference 4. During their lives, these valves can produce varying amounts of reactor coolant leakage through either normal operational wear or mechanical deterioration.

The RCS PIV LCO allows RCS high pressure operation when leakage through these valves exists in amounts that do not compromise safety.

The PIV leakage limit applies to each individual valve. Leakage through these valves is not included in any allowable LEAKAGE specified in LCO 3.4.4, "RCS Operational LEAKAGE."

Although this specification provides a limit on allowable PIV leakage rate, its main purpose is to prevent overpressure failure of the low pressure portions of connecting systems. The leakage limit is an indication that the PIVs between the RCS and the connecting systems are degraded or degrading. PIV leakage could lead to overpressure of the low pressure piping or components. Failure consequences could be a loss of coolant accident (LOCA) outside of containment, an unanalyzed event that could degrade the ability for low pressure injection.

A study (Ref. 5) evaluated various PIV configurations to determine the probability of intersystem LOCAs. This study concluded that periodic leakage testing of the PIVs can substantially reduce intersystem LOCA probability.

(continued)

SUSQUEHANNA - UNIT 1 B 3.4-24 Revision 0

Rev. 2 RCS PIV Leakage B 3.4.5 BASES BACKGROUND PIVs are provided to isolate the RCS from the following typically (continued) connected systems:

a. Residual Heat Removal (RHR) System; and

b. Core Spray System.

The PIVs are listed in Table B 3.4.5-1 "Pressure Isolation Valve."

APPLICABLE Reference 5 evaluated various PIV configurations, leakage testing of the SAFETY valves, and operational changes to determine the effect on the probability ANALYSES of intersystem LOCAs. This study concluded that periodic leakage testing of the PIVs can substantially reduce the probability of an intersystem LOCA.

PIV leakage is not considered in any Design Basis Accident analyses.

This Specification provides for monitoring the condition of the RCPB to detect PIV degradation that has the potential to cause a LOCA outside of containment. RCS PIV leakage satisfies Criterion 2 of the NRC Policy Statement (Ref. 6).

LCO RCS*PIV leakage is leakage into closed systems connected to the RCS.

Isolation valve leakage is usually on the order of drops per minute.

Leakage that increases significantly suggests that something is operationally wrong and corrective action must be taken. Violation of this LCO could result in continued degradation of a PIV, which could lead to overpressurization of a low pressure system and the loss of the integrity of a fission product barrier.

The LCO PIV leakage limit is 0.5 gpm per nominal inch of valve size with a maximum limit of 5 gpm (Ref. 4).

APPLICABILITY In MODES 1, 2, and 3, this LCO applies because the PIV leakage potential is greatest when the RCS is pressurized. In MODE 3, valves in the RHR shutdown cooling flow path are not required to meet the requirements of this LCO when in, (continued)

SUSQUEHANNA- UNIT 1 B 3.4-25 Revision 0

Rev. 2 RCS PIV Leakage B 3.4.5 BASES APPLICABILITY or during transition to or from, the RHR shutdown cooling mode of (continued) operation. This is because RHR shutdown cooling will be placed in operation only below the current pressure permissive setpoint when the high to low pressure interface does not exist.

In MODES 4 and 5, leakage limits are not provided because the lower reactor coolant pressure results in a reduced potential for leakage and for a LOCA outside the containment. Accordingly, the potential for the consequences Of reactor coolant leakage is far lower during these MODES.

ACTIONS The ACTIONS are modified by two Notes. Note 1 has been provided to modify the ACTIONS related to RCS PIV flow paths. Section 1.3, Completion Times, specifies once a Condition has been entered, subsequent divisions, subsystems, components, or variables expressed in the Condition discovered to be inoperable or not within limits will not result in separate entry into*the Condition. Section 1.3 also specifies Required Actions of the Condition continue to apply for each additional failure, with Completion Times based on initial entry into the Condition. However, the Required Actions for the Condition of RCS plV leakage limits exceeded provide appropriate compensatory measures for separate affected RCS PIV flow paths. As such, a Note has been provided that allows separate Condition entry for each affected RCS PIV flow path. Note 2 requires an evaluation of affected systems if a PIV is inoperable. The leakage may have affected system OPERABILITY, or isolation of a leaking flow path with an alternate valve may have degraded the ability of the interconnected system to perform its safety function. As a result, the applicable Conditions and Required Actions for systems made inoperable by PIVs must be entered. This ensures appropriate remedial actions are taken, if necessary, for the affected systems.

If leakage from one or more RCS PIVs is not within limit, the flow path must be isolated by at least one closed manual, deactivated automatic, or check valve within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

(continued)

SUSQUEHANNA - UNIT 1 B 3.4-26 Revision O

Rev.2 RCS PIV Leakage B 3.4.5 BASES ACTIONS A.1 (continued)

Required Action A.1 is modified by a Note stating that the valves used for isolation must meet the same leakage requirements as the PIVs and must be on the RCPB or the high pressure portion of the system.

Four hours provides time to reduce leakage in excess of the allowable limit and to isolate the flow path if leakage cannot be 'reduced while corrective actions to reseat the leaking PIVs are taken. The 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> allows time for these actions and restricts the time of operation with leaking valves.

8.1 and B.2 If leakage cannot be reduced or the system isolated, 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 MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. This action may reduce the leakage and also reduces the potential for a LOCA outside the containment. The Completion Times are reasonable, based on operating experience, to achieve the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE REQUIREMENTS SR 3 .4* 5

• 1 Performance of leakage testing on each RCS PIV is required to verify that leakage is below the specified limit and to identify each leaking valve.

The leakage limit of 0.5 gpm per inch of nominal valve diameter up to 5 gpm maximum applies to each valve. Leakage testing requires a stable pressure condition. Forthe two PIVs in series, the leakage requirement applies to each valve individually and not to the combined leakage across both valves. If the PIVs are not individually leakage tested, one valve may have failed completely and not be detected if the other valve in series meets the leakage requirement. In this situation, the protection provided by redundant valves would be lost.

(continued)

SUSQUEHANNA - UNIT 1 B 3.4-27 Revision 0

Rev.2 RCS PIV Leakage B 3.4.5 BASES SURVEILLANCE REQUIREMENTS SR 3.4.5.1 (continued)

The 24 month Frequency required by the lnservice Testing Program is within the ASME OM Code Frequency requirement and is based on the need to perform this Surveillance during an outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

This SR is modified by a Note that states the leakage Surveillance is not required to be performed in MODE 3. Entry into MODE 3 is permitted for leakage testing at high differential pressures with stable conditions not possible in the lower MODES.

REFERENCES 1. 10 CFR 50.2.

2. 10 CFR 50.55a(c).

3. 10 CFR 50, Appendix A, GDC 55.

4. ASME Operation and Maintenance Code.

5. NUREG-0677, May 1980.

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

-:r:;,*-*._---=: SUSQUEHANNA - UNIT 1 TS I B 3.4-28 Revision 1

Rev. 2 RCS PIV Leakage B 3.4.5 BASES (continued)

TABLE B 3.4.5-1 REACTOR COOLANT SYSTEM PRESSURE ISOLATION VALVES 1st Isolation 2nd Isolation Service Valve(s) Number(s) Valve(s) Number(s)

HV-152F006A HV-152F005A Core Spray Injection HV-152F037A HV-152F006B HV-152F005B Core Spray Injection HV-152F037B HV-151 F050A HV-151 F015A LPCI Injection HV-151 F122A HV-151F050B HV-151F122B 151130 HV-151 F050B HV-151 F015B LPCI Injection HV-151F122B HV-151F050A HV-151 F122A 151130 HV-151 F022 HV-151F023 Head Spray HV-151F009 HV-151F008 Shutdown Cooling SUSQUEHANNA - UNIT 1 TS I B 3.4-29 Revision 2

Rev. 12 PCIVs*

B 3.6.1.3 B 3.6 CONTAINMENT SYSTEMS B 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

BASES BACKGROUND The function of the PC IVs, in combination with other accident mitigation systems, including secondary containment bypass valves that are not PCIVs, is to limit fission product release during and following postulated Design Basis Accidents (DBAs) to within limits. Primary containment isolation within the time limits specified for those isolation valves designed to close automatically ensures that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a OBA.

The OPERABILITY requirements for PCIVs help ensure that an adequate primary containment boundary is maintained during and after an accident by minimizing potential paths to the environment.

Therefore, the OPERABILITY requirements provide assurance that primary containment function assumed in the safety analyses will be maintained. For PCIVs, the primary containment isolation function is that the valve must be able to close (automatically or manually) and/or remain closed, and maintain leakage within that assumed in the DBA LOCA Dose Analysis. These isolation devices are either passive or active (automatic). Manual valves, de-activated automatic valves secured in their closed position (including check valves with flow through the valve secured), blind flanges, and closed systems are considered passive devices. The OPERABILITY requirements for closed systems are discussed in Technical Requirements Manual (TRM) Bases 3.6.4. Check valves, or other automatic valves designed to close without operator action following an accident, are considered active devices. Two barriers in series are provided for each penetration so that no single credible failure or malfunction of an active component can result in a loss of isolation or leakage that exceeds limits assumed in the safety analyses. One of these barriers may be a closed system.

For each division of H2 0 2 Analyzers, the lines, up to and including the first normally closed valves within the H20 2 Analyzer panels, are extensions of primary containment (i.e., closed system), and are required to be leak rate tested in (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-15. Revision 3

Rev. 12 PC IVs B 3.6.1.3 BASES BACKGROUND accordance with the Leakage Rate Test Program. The H2 0 2 (continued) Analyzer closed system boundary is identified in the Leakage Rate Test Program. The closed system boundary consists of those components, piping, tubing; fittings, and valves, which meet the guidance of Reference 6. The closed system provides a secondary barrier in the event of a single failure of the PCIVs, as described below. The closed system boundary between PASS and the H2 0 2 Analyzer system ends at the process sampling solenoid operated isolation valves between the systems (SV-12361, SV-12365, SV-12366, SV-12368, and SV-12369).

These solenoid operated isolation valves do not fully meet the guidance of Reference 6 for closed system boundary valves in that they are not powered from a Class 1E power source.

However, based upon a risk determination, operating these valves as closed system boundary valves is not risk significant. These valves also form the end of the Seismic Category I boundary between the systems. These process sampling solenoid operated isolation valves are normally closed and are required to be leak rate tested in accordance with the Leakage Rate Test Program as part of the closed system for the H2 0 2 Analyzer system. These valves are "closed system boundary valves" and may be opened under administrative control, as delineated in Technical Requirements Manual (TRM) Bases 3.6.4. Opening of these valves to permit testing of PASS in Modes 1, 2, and 3 is permitted in accordance with TRO 3.6.4.

Each Hz0 2 Analyzer Sampling line penetrating primary containment has two PCIVs, located just outside primary containment. While two PCIVs are provided on each line, a single active failure of a relay in the control circuitry for these valves, could result in both valves failing to close or failing to remain closed. Furthermore, a single failure (a hot short in the common raceway to all the valves) could simultaneously affect all of the PCIVs within a H2 Q2 Analyzer division. Therefore, the containment isolation barriers for these penetrations consist of two PCIVs and a closed system. For situations where one or both PCIVs are inoperable, the ACTIONS to be taken are similar to the ACTIONS for a single PCIV backed by a closed system.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-15a Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES BACKGROUND The drywell vent and purge lines are 24 inches in diameter; (continued) the suppression chamber vent and purge lines are 18 inches in diameter. The containment purge valves are normally maintained closed in MODES 1, 2, and 3 to ensure the primary containment boundary is maintained. The outboard isolation valves have 2 inch bypass lines around them for use during normal reactor operation.

The RHR Shutdown Cooling return line containment penetrations

{X-13A(B)}are provided with a normally closed gate valve

{HV-151 F015A(B)} and a normally open globe valve *

{HV-151F017A(B)} outside containment and a testable check valve {HV-151 F050A(B)} with a normally closed parallel air operated globe valve {HV-151 F122A(B)} inside containment. The gate valve is manually opened and automatically isolates upon a containment isolation signal from the Nuclear Steam Supply Shutoff System or RPV low level 3 when the RHR System is operated in the Shutdown Cooling Mode only. The LPCI subsystem is an operational mode of the RHR System and uses the same injection lines to the RPV as the Shutdown Cooling Mode.

The design of these containment penetrations is unique in that some valves are containment isolation valves while others perform the function of pressure isolation valves. In order to meet the 10 CFR 50 Appendix J leakage testing requirements, the

• HV-151 F015A(B) and the closed system outside containment are the only barriers tested in ?Ccordance with the Leakage Rate Test Program. Since these containment penetrations {X-13A and X-138} include a containment isolation valve outside containment that is tested in accordance with 10 CFR 50 Appendix J requirements and a closed system outside containment that meets the requirements of USNRC Standard Review Plan 6.2.4 (September 1975), paragraph 11.3.e, the containment isolation provisions for these penetrations provide an acceptable alternative to the explicit requirements of 10 CFR 50, Appendix A, GDC 55.

Containment penetrations X-13A(B) are also high/low pressure system interfaces. In order to meet the requirements to have two (2) isolation valves between the high pressure and low pressure systems, the HV-151F050A(B), HV-151F122A(B),

151130 and HV-151 F015A(B) valves are used to meet this requirement and are tested in accordance with the pressure test program.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-15b Revision 3

Rev. 12 PC IVs B 3.6.1.3 BASES APPLICABLE The PCtVs LCO was derived from the assumptions related SAFETY ANALYSES to minimizing the toss of reactor coolant inventory, and establishing the primary containment boundary during major accidents. As part of the primary containment boundary, PCIV OPERABILITY supports leak tightness of primary containment. Therefore, the safety analysis of any event requiring isolation of primary containment is applicable to this LCO.

The DBAs that result in a release of radioactive material within primary containment are a LOCA and a main steam tine break (MSLB). In the analysis for each of these accidents, it is assumed that PCIVs are either closed or close within the required isolation times following event initiation. This ensures that potential paths to the environment through PClVs (including primary containment purge valves) and secondary I containment bypass valves that are not PClVs are minimized. The closure time of the main steam isolation valves (MSlVs) for a MSLB outside primary containment is a significant variable from a radiological standpoint. The MSlVs are required to close within 3 to 5 seconds since the 5 second closure time is assumed in the analysis. The safety analyses assume that the purge valves were closed at event initiation.

Likewise, it is assumed that the primary containment is isolated such that release of fission products to the environment is controlled.

The OBA analysis assumes that within the required isolation time leakage is terminated, except for the maximum allowable leakage rate, La.

The single failure criterion required to be imposed in the conduct of unit safety analyses was considered in the original design of the primary containment purge valves. Two valves in series on each purge line provide assurance that both the supply and exhaust lines could be isolated even if a single failure occurred.

• The primary containment purge valves may be unable to close in the environment following a LOCA. Therefore, each of the purge valves is required to remain closed during MODES 1, 2, and 3 except as permitted under Note 2 of SR 3.6.1.3.1. In this case, the single failure criterion remains applicable to the primary containment purge valve (continued)

I 1-f SUSQUEHANNA- UNIT 1 TS I B 3.6-16 Revision 2

Rev. 12 PC IVs B 3.6.1.3 BASES APPLICABLE due to failure in the control circuit associated with each SAFETY ANALYSES valve. The primary containment purge valve design (continued) precludes a single failure from compromising the primary containment boundary as long as the system is operated in accordance with this LCO.

Both H2 0 2 Analyzer PCIVs may not be able to close given a single failure in the control circuitry of the valves. The single failure is caused by a "hot short" in the cables/raceway to the PC IVs that causes both PCIVs for a given penetration to remain open or to open when required to be closed. This failure is required to be considered in accordance with IEEE-279 as discussed in FSAR Section 7.3.2a. However, the single failure criterion for containment isolation of the H20 2 Analyzer penetrations is satisfied by virtue of the combination of the associated PCIVs and the closed system formed by the H2 0 2 Analyzer piping system as discussed in the BACKGROUND section above.

The closed system boundary between PASS and the H20 2 Analyzer system ends at the process sampling solenoid operated isolation valves between the systems (SV-12361, SV-12365, SV-12366, SV-12368, and SV-12369). The closed system is not fully qualified to the guidance of Reference 6 in that the closed system boundary valves between the H2 0 2 system and PASS are not powered from a Class 1E power source. However, based upon a risk determination, the use of these valves is considered to have no risk significance. This exemption to the requirement of Reference 6 for the closed system boundary is documented in

• License Amendment No. 195.

PCIVs satisfy Criterion 3 of the NRC Policy Statement. (Ref. 2)

LCO PCIVs form a part of the primary containment boundary, or in the case of SCBL valves limit leakage from the primary containment.

The PCIV safety function is related to minimizing the loss of reactor coolant inventory and establishing the primary containment boundary during a OBA.

The power operated, automatic isolation valves are required to have isolation times within limits and actuate on an automatic isolation signal. The valves covered by this LCO are listed in Table B 3.6.1.3-1 and Table B 3.6.1.3-2.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-17 Revision 2

Rev. 12 PC IVs B 3.6.1.3 BASES LCO (continued) The normally closed PCIVs, including secondary containment bypass valves listed in Table B 3.6.1.3-2 that are not PCIVs, are considered OPERABLE when manual valves are closed or open in accordance with appropriate administrative controls, automatic valves are in their closed position, blind flanges are in place, and closed systems are intact. These passive isolation valves and devices are those listed in Table B 3.6.1.3-1.

Leak rate testing of the secondary containment bypass valves listed in Table 3.6.1.3-2 is permitted in Modes 1, 2 & 3 as described in the Primary Containment Leakage Rate Testing Program.

Purge valves with resilient seals, secondary containment bypass valves, including secondary containment bypass valves listed in Table B 3.6.1.3-2 that are not PCIVs, MSIVs, and hydrostatically tested valves must meet additional leakage rate requirements. Other PCIV leakage rates are addressed by LCO 3.6.1.1, "Primary Containment," as Type B or C testing.

This LCO provides assurance that the PCIVs will perform their designed safety functions to minimize the loss of reactor coolant inventory and establish the primary containment boundary during accidents APPLICABILITY In MODES 1, 2, and 3, a OBA could cause a release of radioactive material to primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, most PCIVs are not required to be (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-17a Revision 1

Rev. 12 PC IVs B 3.6.1.3 BASES APPLICABILITY OPERABLE and the primary containment purge valves are (continued) not required to be closed in MODES 4 and 5. Certain valves, however, are required to be OPERABLE to prevent inadvertent reactor vessel draindown. These valves are those whose associated instrumentation is required to be OPERABLE per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation."

(This does not include the valves that isolate the associated instrumentation.)

ACTIONS The ACTIONS are modified by a Note allowing penetration flow path(s) to be unisolated intermittently under administrative controls. These controls consist of stationing a dedicated operator at the controls of the valve, who is in continuous communication with the control room. In this way, the penetration can be rapidly isolated when a need for primary containment isolation is indicated.

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

The ACTIONS are modified by Notes 3 and 4. Note 3 ensures that appropriate remedial actions are taken, if necessary, if the affected system(s) are rendered inoperable by an inoperable PCIV (e.g., an Emergency Core Cooling System subsystem is inoperable due to a failed open test return valve). Note 4 ensures appropriate remedial actions are taken when the primary containment leakage limits are exceeded. Pursuant to LCO 3.0.6, these actions are not required even when the associated LCO is not met. Therefore, Notes 3 and 4 are added to require the proper actions be taken.

A.1 and A.2 With one or more penetration flow paths with one PCIV inoperable except for purge valve leakage not within limit, (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-18 Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS A.1 and A.2 (continued) the affected penetration flow paths must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, a blind flange, and a check valve with flow through*

the valve secured. For a penetration isolated in accordance with Required Action A.1, the device used to isolate the penetration should be the closest available valve to the primary containment. The Required Action must be completed within the 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time (8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for main steam lines). The Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is reasonable considering the time required to isolate the penetration and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. For main steam lines, an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Completion Time is allowed. The Completion Time of 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for the main steam lines allows a period of time to restore the MSIVs to OPERABLE status given the fact that MSIV closure will result in isolation of the main steam line(s) and a potential for plant shutdown.

For affected penetrations that have been isolated in accordance with Required Action A.1, the affected penetration flow path(s) must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident, and no longer capable of being automatically isolated, will be in the isolation position should an event occur. This Required Action does not require any testing or device manipulation. Rather, it involves verification that those devices outside containment and capable of potentially being mispositioned are in the correct position. The Completion Time of "once per 31 days for isolation devices outside primary containment" is appropriate because the devices are operated under administrative controls and the probability of their misalignment is low. For the devices inside primary containment, the time period specified "prior to entering MODE 2 or 3 from MODE. 4, if primary containment was de-inerted while in MODE 4, if not performed within the

• previous 92 days" is based on engineering judgment and is considered reasonable in view of the inaccessibility of the devices and other administrative controls ensuring that device misalignment is an unlikely possibility.

(continued)

-.;:c*- - ~ - -

~.-_-_..._,~

SUSQUEHANNA - UNIT 1 TS I B 3.6-19 Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS A.1 and A.2 (continued)

Condition A is modified by a Note indicating that this Condition is only applicable to those penetration flow paths with two PCIVs except for the H20 2 Analyzer penetrations. For penetration flow paths with one PCIV, Condition C provides the appropriate Required Actions. For the H20 2 Analyzer Penetrations, Condition D provides the appropriate Required Actions.

Required Action A.2 is modified by a Note that applies to isolation devices located in high radiation areas, and allows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these* areas is typically restricted. Therefore, the probability of misalignment of these devices, once they have been verified to be in the proper position, is low.

With one or more penetration flow paths with two PCIVs inoperable except for purge valve leakage not within limit, either the inoperable PCIVs must be restored to OPERABLE status or the affected penetration flow path must be isolated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de--activated automatic valve, a closed manual valve, and a blind flange. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time is consistent with the ACTIONS of LCO 3.6.1.1.

Condition B is modified by a Note indicating this Condition is only applicable to penetration flow paths with two PC IVs except for the H20 2 Analyzer penetrations. For penetration flow paths with one PCIV, Condition C provides the appropriate Required Actions. For the H20 2 Analyzer Penetrations, Condition D provides the appropriate Required Actions.

C.1 and C.2 With one or more penetration flow paths with one PCIV inoperable, the inoperable valve must be restored to OPERABLE status or the affected penetration flow path (continued)

~

• ~~~~--' SUSQUEHANNA - UNIT 1 TS/ B 3.6-20 Rev.ision 1

Rev.12 PC IVs B 3.6.1.3 BASES ACTIONS C.1 and C.2 (continued) must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action C.1 must be completed within the 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the relative stability of the closed system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. The closed system must meet the requirements of Reference 6. For conditions where the PCIV and the closed system are inoperable, the Required Actions of TRO 3.6.4, Condition B apply. For the Excess Flow Check Valves (EFCV), the Completion Time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is reasonable considering the instrument and the small pipe diameter of penetration (hence, reliability) to act as a penetration isolation boundary and the small pipe diameter of the affected penetrations. In the event the affected penetration flow path is isolated in accordance with Required Action C.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident are isolated. The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the valves are operated under administrative controls and the probability of their misalignment is low.

Condition C is modified by a Note indicating that this Condition is only applicable to penetration flow paths with only one PCIV. For penetration flow paths with two PCIVs and the H20 2 Analyzer Penetration. Conditions A, B and D provide the appropriate Required Actions.

Required Action C.2 is modified by a Note that applies to valves and blind flanges located in high radiation areas and a*llows them to be verified by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted. Therefore, the probability of misalignment of these valves, once they have been verified to be in the proper position, is low.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-21 Revision 2

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS D.1 and D.2 (continued)

With one or more H20 2 Analyzer penetrations with one or both PCIVs inoperable, the inoperable valve(s) must be restored to OPERABLE status or the affected penetration flow path must be isolated. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, a closed manual valve, and a blind flange. A check valve may not be used to isolate the affected penetration. Required Action D.1 must be completed within the 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the unique design of the H2 02 Analyzer penetrations. The containment isolation barriers for these penetrations consist of two PC IVs and a closed system. In addition, the Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering the relative stability of the closed system (hence, reliability) to act as a penetration isolation boundary and the relative importance of supporting primary containment OPERABILITY during MODES 1, 2, and 3. In the event the affected penetration flow path is isolated in accordance with Required Action D.1, the affected penetration must be verified to be isolated on a periodic basis. This is necessary to ensure that primary containment penetrations required to be isolated following an accident are isolated. The Completion Time of once per 31 days for verifying each affected penetration is isolated is appropriate because the valves are operated under administrative controls and the probability of their misalignment is low.

When an H2 0 2 Analyzer penetration PCIV is to be closed and deactivated in accordance with Condition D, this must be accomplished by pulling the fuse for the power supply, and either determinating the power cables at the solenoid valve, or jumpering of the power side of the solenoid to ground.

The OPERABILITY requirements for the closed system are discussed in Technical Requirements Manual (TRM) Bases 3.6.4.

In the event that either one or both of the PCIVs and the closed system are inoperable, the Required Actions of TRO 3.6.4, Condition B apply.

(continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-22 Revision 1

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS D.1 and D.2 (continued)

Condition D is modified by a Note indicating that this Condition is only applicable to the H2 0 2 Analyzer penetrations.

With the secondary containment bypass leakage rate not within limit, the assumptions of the safety analysis may not be met.

Therefore, the leakage must be restored to within limit within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. Restoration can be accomplished by isolating the penetration that caused the limit to be exceeded by use of one closed and de-activated automatic valve, closed manual valve, or blind flange. When a penetration is isolated, the leakage rate for the isolated penetration is assumed to be the actual pathway leakage through the isolation device. If two isolation devices are used to isolate the penetration, the leakage rate is assumed to be the lesser actual pathway leakage of the two devices. The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time is reasonable considering the time required to restore the leakage by isolating the penetration and the relative importance of secondary containment bypass leakage to the overall containment function.

F.1 In the event one or more containment purge valves are not within the purge valve leakage limits, purge valve leakage must be restored to within limits. The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Completion Time is reasonable, considering that one containment purge valve remains closed, except as controlled by SR 3.6.1.3.1 so that a gross breach of containment does not exist.

G.1 and G.2 If any Required Action and associated Completion Time cannot' be met in MODE 1, 2, or 3, 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 1 TS I B 3.6-22a Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES ACTIONS H.1 and H.2 (continued)

If any Required Action and associated Completion Time cannot be met, the unit must be placed in a condition in which the LCO does not apply. If applicable, 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 subsequent potential for fission product release. Actions must continue until OPDRVs are suspended or valve(s) are restored to OPERABLE status. If suspending an OPDRV would result in closing the residual heat removal (RHR) shutdown cooling isolation valves, an alternative Required Action is provided to immediately initiate action to restore the valve(s) to OPERABLE status. This allows RHR to remain in service while actions are being taken to restore the valve.

SURVEILLANCE SR 3.6.1.3.1 REQUIREMENTS This SR ensures that the primary containment purge valves are closed as required or, if open, open for an allowable reason. If a purge valve is open in violation of this SR, the valve is considered inoperable. If the inoperable valve is not otherwise known to have excessive leakage when closed, it is not considered to have leakage outside of limits. The SR is also modified by Note 1, stating that primary containment purge valves are only required to be closed in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, the purge valves may not be capable of closing before the pressure pulse affects systems downstream of the purge valves, or the release of radioactive material will exceed limits prior to the purge valves closing. At other times when the purge valves are required to be capable of closing (e.g., during handling of irradiated fuel), pressurization concerns are not present and the purge valves are allowed to be open. The SR is modified by Note 2 stating that the SR is not required to be met when the purge valves are open for the stated reasons. The Note states that these valves may be opened for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open. The vent and purge valves are capable of closing in the environment following a LOCA. Therefore, these valves are allowed to be open for (continued)

, I v SUSQUEHANNA - UNIT 1 TS I B 3.6-23 Revision 1

Rev. 12 PC IVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.1 (continued)

REQUIREMENTS limited periods of time. The 31 day Frequency is consistent with other PCIV requirements discussed in SR 3.6.1.3.2.

SR 3.6.1.3.2.

This SR verifies that each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits.

This SR does not require any testing or valve manipulation.

Rather, it involves verification that those PCIVs outside primary containment, and capable of being mispositioned, are in the correct position. Since verification of valve position for PCIVs outside primary containment is relatively easy, the 31 day Frequency was chosen to provide added assurance that the PCIVs are in the correct positions.

Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable since access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in the proper position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PC IVs are open. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.

SR 3.6.1.3.3 This SR verifies that each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-24 Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES.

SURVEILLANCE SR 3.6.1.3.3 (continued)

REQUIREMENTS secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits. For PCIVs inside primary containment, the Frequency defined as "prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days" is appropriate since these PCIVs are operated under administrative controls and the probability of their misalignment is low. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing. Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable since the primary containment is inerted and access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in their proper position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PCIVs are open.

SR 3.6.1.3.4 The traversing incore probe (TIP) shear isolation valves are actuated by explosive charges. Surveillance of explosive charge continuity provides assurance that TIP valves will actuate when required. Other administrative controls, such as those that limit the shelf life of the explosive charges, must be followed. The 31 day Frequency is based on operating experience that has demonstrated the reliability of the explosive charge continuity.

SR 3.6.1.3.5 Verifying the isolation time of each power operated and each automatic PCIV is within limits is required to demonstrate OPERABILITY. MSIVs may be excluded from this SR since MSIV (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.6-25 Revision 0

Rev. 12 PC IVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.5 (continued)

REQUIREMENTS full closure isolation time is demonstrated by SR 3.6.1.3.7. The isolation time test ensures that the valve will isolate in a time period less than or equal to that assumed in the Final Safety Analyses Report. The isolation time and Frequency of this SR are in accordance with the requirements of the lnservice Testing Program.

SR 3.6.1.3.6 For primary containment purge valves with resilient seals, the Appendix J Leakage Rate Test Interval of 24 months is sufficient.

The acceptance criteria for these valves is defined in the Primary Containment Leakage Rate Testing Program, 5.5.12.

The SR is modified by a Note stating that the primary containment purge valves are only required to meet leakage rate testing requirements in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, purge valve leakage must be minimized to ensure offsite radiological release is within limits.

At other times when the purge valves are required to be capable of closing (e.g., during handling of irradiated fuel), pressurization concerns are not present and the purge valves are not required to meet any specific leakage criteria.

SR 3.6.1.3. 7 Verifying that the isolation time of each MSIV is within the specified limits is required to demonstrate OPERABILITY. The isolation time test ensures that the MSIV will isolate in a time period that does not exceed the times assumed in the DBA analyses. This ensures that the calculated radiological consequences of these events remain within regulatory limits. The Frequency of this SR is in accordance with the requirements of the lnservice Testing Program.

(continued) 1* .' SUSQUEHANNA - UNIT 1 TS/ B 3.6-26 Revision 2

Rev. 12 PC IVs B 3.6.1.3 BASES SURVEILU\NCE SR 3.6.1.3.8 REQUIREMENTS (continued) Automatic PCIVs close on a primary containment isolation signal to prevent leakage of radioactive material from primary containment following a OBA. This SR ensures that each automatic PCIV will actuate to its isolation position on a primary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.1.5 overlaps this SR to provide complete testing of the safety function. The 24 month Frequency was developed considering it is prudent that some of these Surveillances be performed only during a unit outage since isolation of penetrations could eliminate cooling water flow and disrupt the normal operation of some critical components. Operating experience has shown that these components usually pass this Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.6.1.3.9 This SR requires a demonstration that a representative sample of reactor instrumentation line excess flow check valves (EFCV) are OPERABLE by verifying that the valve actuates to check flow on a simulated instrument line break. As defined in FSAR Section 6.2.4.3.5 (Reference 4), the conditions under which an EFCV will isolate, simulated instrument line break, are at flow rates, which develop a differential pressure of between 3 psid and 10 psid.

This SR provides assurance that the instrumentation line EFCVs will perform its design function to check flow. No specific valve leakage limits are specified because no specific leakage limits are defined in the FSAR. The 24 month Frequency is based on the need to perform some of these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. The representative sample consists of an approximate equal number of EFCVs such that each EFCV is tested at least once every 10 years (nominal). The nominal 1O year interval is based on other performance-based testing programs, such as lnservice Testing (snubbers) and Option B to 10 CFR 50, Appendix J. In addition, the EFCVs in the sample are representative of the various plant configurations, models, sizes and operating environments. This ensures that any potential common problems with a specific type or application of EFCV is detected at the earliest possible time. EFCV failures will be evaluated to determine if additional testing in that test interval is warranted to ensure overall reliability and that failures to isolate are very infrequent. Therefore, testing of a representative sample was concluded to be acceptable from a reliability standpoint (Reference 7).

(continued)

SUSQUEHANNA - UNIT 1 TS/ B 3.6-27 Revision 2

Rev.12 PC IVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.10 REQUIREMENTS (continued) The TIP shear isolation valves are actuated by explosive charges. An in place functional test is not possible with this design. The explosive squib is removed and tested to provide assurance that the valves will actuate when required. The replacement charge for the explosive squib shall be from the same manufactured batch as the one fired or from another batch that has been certified by having one of the batch successfully fired. The Frequency of 24 months on a STAGGERED TEST BASIS is considered adequate given the administrative controls on replacement charges and the frequent checks of circuit continuity (SR 3.6.1.3.4).

SR 3.6.1.3.11 This SR ensures that the leakage rate of secondary containment bypass leakage paths is less than the specified leakage rate. This provides assurance that the assumptions in the radiological evaluations of Reference 4 are met. The secondary containment leakage pathways and Frequency are defined by the Primary Containment Leakage Rate Testing Program. This SR simply imposes additional acceptance criteria.

A note is added to this SR, which states that these valves are only required to meet this leakage limit in MODES 1, 2, and 3. In the other MODES, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required.

SR 3.6.1.3.12 The analyses in References 1 and 4 are based on the specified leakage rate. Leakage through each MSIV must bes 100 scfh for any one MSIV and s 300 scfh for total leakage through the MSIVs combined with the Main Steam Line Drain Isolation Valve, HPCI Steam Supply Isolation Valve and the RCIC Steam Supply Isolation Valve. The MSIVs can be tested at either.:: Pt (24.3 psig) or Pa (48.6 psig). Main Steam Line Drain Isolation, HPCI and RCIC Steam Supply Line Isolation Valves, are tested at Pa (48.6 psig). A note is added to this SR, which states that these valves are only required to meet this leakage limit in MODES 1, 2, and 3.

In the other conditions, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required. The Frequency is required by the Primary Containment Leakage Rate Testing Program.

(continued)

SUSQUEHANNA - UNIT 1 TS/ B 3.6-28 Revision 7

Rev. 12 PC IVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.13 REQUIREMENTS (continued) Surveillance of hydrostatically tested lines provides assurance that the calculation assumptions of Reference 2 are met. The acceptance criteria for the combined leakage of all hydrostatically tested lines is 3.3 gpm when tested at 1.1 Pa, (53.46 psig). The combined leakage rates must be demonstrated in accordance with the leakage rate test Frequency required by the Primary Containment Leakage Testing Program.

As noted in Table B 3.6.1.3-1, PCIVs associated with this SR are not Type C tested. Containment bypass leakage is prevented since the line terminates below the minimum water level in the Suppression Chamber. These valves are tested in accordance with the IST Program. Therefore, these valves leakage is not included as containment leakage.

This SR has been modified by a Note that states that these valves are only required to meet the combined leakage rate in MODES 1, 2, and 3, since this is when the Reactor Coolant System is pressurized and primary containment is required. In some instances, the valves are required to be capable of automatically closing during MODES other than MODES 1, 2, and 3. However, specific leakage limits are not applicable in these other MODES or conditions.

REFERENCES 1. FSAR, Chapter 15.

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

3. 10 CFR 50, Appendix J, Option B.

4. FSAR, Section 6.2.

5. NED0-30851-P-A, "Technical Specification Improvement Analyses for BWR Reactor Protection System,"

March 1988.

6. Standard Review Plan 6.2.4, Rev. 1, September 1975

7. NED0-32977-A, "Excess Flow Check Valve Testing Relaxation," June 2000.

I. . SUSQUEHANNA - UNIT 1 TS/ B 3.6-29 Revision 2

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 1 of 11)

.. Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds)}

Containment 1-57-193 (d) ILRT Manual NIA Atmospheric 1-57-194 (d) ILRT Manual N/A Control HV-15703 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15704 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15705 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15711 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15713 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15714 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15721 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15722 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15723 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15724 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15725 Containment Purge Automatic Valve 2.b, 2.d, 2.e (15)

HV-15766 (a) Suppression Pool Cleanup Automatic Valve 2.b, 2.d (30)

HV-15768 (a) Suppression Pool Cleanup Automatic Valve 2.b, 2.d (30)

SV-157100 A Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157100 B Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157101 A Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157101 B Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157102 A Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157102 B Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157103 A Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157103 B Containment Radiation Detection. Automatic Valve 2.b, 2.d Syst SV-157104 Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157105 Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157106 Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-157107 Containment Radiation Detection Automatic Valve 2.b, 2.d Syst SV-15734 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15734 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15736 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15736 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15737 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e SUSQUEHANNA - UNIT 1 TS I B 3.6-30 Revision 1

Rev.12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 Primary Containment Isolation Valve (Page 2of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Containment SV-15738 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e Atmospheric SV-15740 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d Control SV-15740 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d (continued) SV-15742 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15742 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15750 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15750 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15752 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15752 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15767 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e SV-15774 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15774 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15776 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15776 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15780 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15780 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15782 A (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15782 B (e) Containment Atmosphere Sample Automatic Valve 2.b, 2.d SV-15789 Nitrogen Makeup Automatic Valve 2.b, 2.d, 2.e Containment 1-26-072 (d) Containment Instrument Gas Manual Check N/A Instrument Gas 1-26-074 (d) Containment Instrument Gas Manual Check N/A 1-26-152 (d) Containment Instrument Gas Manual Check NIA 1-26-154 (d) Containment Instrument Gas Manual Check N/A 1-26-164 (d) Containment Instrument Gas Manual Check N/A HV-12603 Containment Instrument Gas Automatic Valve 2.c, 2.d (20)

SV-12605 Containment Instrument Gas Automatic Valve 2.c, 2.d SV-12651 Containment Instrument Gas Automatic Valve 2.c, 2.d SV-12654A Containment Instrument Gas Power Operated N/A SV-12654 B Containment Instrument Gas Power Operated N/A SV-12661 Containment Instrument Gas Automatic Valve 2.b, 2.d SV-12671 Containment Instrument Gas Automatic Valve 2.b, 2.d Core Spray HV-152F001 A (b)(c) CS Suction Valve Power Operated N/A HV-152F001 B (b)(c) CS Suction Valve Power Operated N/A HV-152F005 A CS Injection Power Operated N/A HV-152F005 B CS Injection Valve Power Operated N/A HV-152F006 A CS Injection Valve Air Operated Check N/A Valve HV-152F006 B CS Injection Valve Air Operated Check N/A Valve HV-152F015 A (b)(c) CS Test Valve Automatic Valve 2.c, 2.d (80)

HV-152F015 B (b)(c) CS Test Valve Automatic Valve 2.c, 2.d (80)

SUSQUEHANNA - UNIT 1 TS I B 3.6-31 Revision 3

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page3 of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Core Spray HV-152F031 A (b)(c) CS Minimum Recirculation Flow Power Operated NIA (continued) HV-152F031 B (b)(c) CS Minimum Recirculation Flow Power Operated NIA HV-152F037 A CS Injection Power Operated NIA (Air)

HV-152F037 B CS Injection !Power Operated NIA (Air)

XV-152F018 A Core Spray Excess Flow Check NIA Valve XV-152F018 B Core Spray Excess Flow Check NIA Valve HPCI 1-55-038 (d) HPCI Injection Valve Manual NIA 155F046 (b)(c)(d) HPCI Minimum Flow Check Valve Manual Check NIA 155F049 (a)(d) HPCI Turbine Exhaust Valve Manual Check NIA HV-155F002 HPCI Steam Supply Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g (50)

HV-155F003 HPCI Steam Supply Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g (50)

HV-155F006 HPCI Injection Valve Power Operated NIA HV-155F012 (b)(c) HPCI Minimum Flow Valve Power Operated NIA HV-155F042 (b)(c) HPCI Suction Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g (115)

HV-155F066 (a) HPCI Turbine Exhaust Valve Power Operated NIA HV-155F075 HPCI Vacuum Breaker Isolation Automatic Valve 3.b, 3.d (15)

Valve HV-155F079 HPCI Vacuum Breaker Isolation Automatic Valve 3.b, 3.d (15)

Valve HV-155F100 HPCI Steam Supply Valve Automatic Valve 3.a, 3.b, 3.c, 3.e, 3.f, 3.g (6)

XV-155F024 A HPCI Valve Excess Flow Check NIA Valve XV-155F024 B HPCI Valve Excess Flow Check NIA Valve XV-155F024 C HPCI Valve Excess Flow Check NIA Valve XV-155F024 D HPCI Valve Excess Flow Check NIA Valve Liquid Radwaste HV-16108 A1 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)

Collection HV-16108 A2 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)

HV-16116 A1 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)

HV-16116 A2 Liquid Radwaste Isolation Valve Automatic Valve 2.b, 2.d (15)

Demin Water 1-41-017 (d) Demineralized Water Manual NIA 1-41-01 B (d) Demineralized Water Manual NIA Nuclear Boiler 141 F010 A ( d) Feedwater Isolation Valve Manual Check N/A 141F010 B (d) Feedwater Isolation Valve Manual Check NIA SUSQUEHANNA - UNIT 1 TS I B 3.6-32 Revision 1

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 4of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Nuclear Boiler 141 F039 A (d) Feedwater Isolation Valve Manual Check NIA (continued) 141 F039 B (d) Feedwater Isolation Valve Manual Check NIA 141818A(d) Feedwater Isolation Valve Manual Check NIA 141818B(d) Feedwater Isolation Valve Manual Check NIA HV-141 F016 MSL Drain Isolation Valve Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (10)

HV-141 F019 MSL Drain Isolation Valve Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (15)

HV-141F022A MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F022 B MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F022 C MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F022 D MSIV

• Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141F028A MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141F028 B MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F028 C MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141F028 D MSIV Automatic Valve 1.a, 1.b, 1.c, 1.d, 1.e (5)

HV-141 F032 A Feedwater Isolation Valve Power Operated NIA Check HV-141 F032 B Feedwater Isolation Valve Power Operated NIA Check XV-141F009 Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F070 A Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F070 B Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F070 C Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F070 D Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F071 A Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F071 B Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F071 C Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F071 D Nuclear Boiler EFCV Excess Flow Check NIA Valve SUSQUEHANNA - UNIT 1 TS I B 3.6-33 Revision 1

Rev. 12 PC IVs 83613 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 5 of 11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Nuclear Boiler XV-141 F072 A Nuclear Boiler EFCV Excess Flow Check NIA (continued) Valve XV-141 F072 B Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F072 C Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F072 D Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F073 A Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141 F073 B Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F073 C Nuclear Boiler EFCV Excess Flow Check NIA Valve XV-141F073 D Nuclear Boiler EFCV Excess Flow Check NIA Valve Nuclear Boiler XV-14201 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Vessel Valve Instrumentation XV-14202 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F041 Nuclear Boiler Vessel Instrument Excess Flow Check* NIA Valve XV-142F043 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F043 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F045 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F045 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F047 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F047 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F051 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F051 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F051 C Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F051 D Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F053 A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F053 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve SUSQUEHANNA - UNIT 1 TS/ B 3.6-34 Revision 0

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 6of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Nuclear Boiler XV-142F053 C Nuclear Boiler Vessel Instrument Excess Flow Check NIA Vessel Valve Instrumentation XV-142F053 D Nuclear Boiler Vessel Instrument Excess Flow Check NIA (continued) Valve XV-142F055 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F057 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059A Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 B Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 C Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 D Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 E Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 F Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 G Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 H Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 L Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 M Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 N Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 P Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 R Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 S Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 T Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F059 U Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve XV-142F061 Nuclear Boiler Vessel Instrument Excess Flow Check NIA Valve RBCCW HV-11313 RBCCW Automatic Valve 2.c, 2.d (30)

HV-11314 RBCCW Automatic Valve 2.c, 2.d (30)

HV-11345 RBCCW Automatic Valve 2.c, 2.d (30)

HV-11346 RBCCW Automatic Valve 2.c, 2.d (30) l' SUSQUEHANNA - UNIT 1 TS I B 3.6-35 Revision 0

Rev. 12 PC IVs 83613 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page7 of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

RCIC 1-49-020 (d) RCIC INJECTION Manual NIA 149F021 (b)(c)(d) RCIC Minimum Recirculation Flow Manual Check NIA 149F028 (a)(d) RCIC Vacuum Pump Discharge Manual Check NIA 149F040 (a)(d) RCIC Turbine Exhaust Manual Check NIA FV-149F019 (b)(c) RCIC Minimum Recirculation Flow Power Operated NIA HV-149F007 RCIC Steam Supply Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f, 4.g (20)

HV-149F008 RCIC Steam Supply' Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f, 4.g (20)

HV-149F013 RCIC Injection Power Operated NIA HV-149F031 (b)(c) RCIC Suction Power Operated NIA HV-149F059 (a) RCIC Turbine Exhaust Power Operated NIA HV-149F060 (a) RCIC Vacuum Pump Discharge Power Operated NIA HV-149F062 RCIC Vacuum Breaker Automatic Valve 4.b, 4.d (10)

HV-149F084 RCIC Vacuum Breaker Automatic Valve 4.b, 4.d (10)

HV-149F088 RCIC Steam Supply Automatic Valve 4.a, 4.b, 4.c, 4.e, 4.f, 4.g (12)

XV-149F044A RCIC Excess Flow Check NIA Valve XV-149F044 B RCIC Excess Flow Check NIA Valve XV-149F044 C RCIC Excess Flow Check NIA Valve XV-149F044 D RCIC Excess Flow Check NIA Valve RB Chilled HV-18781 A1 RB Chilled Water Automatic Valve 2.c, 2.d (40)

Water System HV-18781 A2 RB Chilled Water Automatic Valve 2.c, 2.d (40)

HV-18781 B1 RB Chilled Water Automatic Valve 2.c, 2.d (40)

HV-18781 B2 RB Chilled Water Automatic Valve 2.c, 2.d (40)

HV-18782 A1 RB Chilled Water Automatic Valve 2.c, 2.d (12)

HV-18782A2 RB Chilled Water Automatic Valve 2.c, 2.d (12)

HV-18782 B1 RB Chilled Water Automatic Valve 2.c, 2.d (12)

HV-18782 B2 RB Chilled Water Automatic Valve 2.c, 2.d (12)

HV-18791 A1 RB Chilled Water Automatic Valve 2.b, 2.d (15)

HV-18791 A2 RB Chilled Water Automatic Valve 2.b, 2.d (15)

HV-18791 B1 RB Chilled Water Automatic Valve 2.b, 2.d (15)

HV-18791 B2 RB Chilled Water Automatic Valve 2.b, 2.d (15)

HV-18792 A1 RB Chilled Water Automatic Valve 2.b, 2.d (8)

HV-18792A2 RB Chilled Water Automatic Valve 2.b, 2.d (8)

HV-18792 B1 RB Chilled Water Automatic Valve 2.b, 2.d (8)

HV-18792 B2 RB Chilled Water Automatic Valve 2.b, 2.d (8)

Reactor 143F013 A (d) Recirculation Pump Seal Water Manual Check NIA Recirculation 143F013 B (d) Recirculation Pump Seal Water Manual Check NIA SUSQUEHANNA - UNIT 1 TS I B 3.6-36 Revision 1

Rev. 12 PC IVs 83613 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 8of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Reactor XV-143F003A Reactor Recirculation Excess Flow Check NIA Recirculation Valve (continued) XV-143F003 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F004A Reactor Recirculation Excess Flow Check NIA Valve XV-143F004 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F009 A Reactor Recirculation Excess Flow Check NIA Valve XV-143F009 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F009 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F009 D Reactor Recirculation Excess Flow Check NIA Valve XV-143F010 A Reactor Recirculation Excess Flow Check NIA Valve XV-143F010 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F010 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F010 D Reactor Recirculation Excess Flow Check NIA Valve

~-143F011 A Reactor Recirculation Excess Flow Check NIA Valve*

XV-143F011 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F011 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F011 D Reactor Recirculation Excess Flow Check NIA Valve XV-143F012A Reactor Recirculation Excess Flow Check NIA Valve XV-143F012 B Reactor Recirculation Excess Flow Check NIA Valve XV-143F012 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F012 D Reactor Recirculation Excess Flow Check NIA Valve XV-143F017 A Recirculation Pump Seal Water Excess Flow Check NIA Valve XV-143F017 B Recirculation Pump Seal Water Excess Flow Check NIA Valve XV-143F040 A Reactor Recirculation Excess Flow Check NIA Valve SUSQUEHANNA - UNIT 1 TS I B 3.6-37 Revision 0

Rev. 12 PC IVs 83613 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 9of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Reactor XV-143F040 B Reactor Recirculation Excess Flow Check NIA Recirculation Valve (continued) XV-143F040 C Reactor Recirculation Excess Flow Check NIA Valve XV-143F040 D Reactor Recirculation Excess Flow Check NIA Valve XV-143F057 A Reactor Recirculation Excess Flow Check NIA Valve XV-143F057 B Reactor Recirculation Excess Flow Check NIA Valve HV-143F019 Reactor Coolant Sample Automatic Valve 2.b (9)

HV-143F020 Reactor Coolant Sample Automatic Valve 2.b (2)

Residual Heat HV-151 F004 A (b)(c) RHR - Suppression Pool Suction Power Operated NIA Removal HV-151 F004 B (b)(c) _RHR - Suppression Pool Suction Power Operated NIA HV-151 F004 C (b)(c) RHR - Suppression Pool Suction Power Operated NIA HV-151F004 D (b)(c) RHR - Suppression Pool Suction Power Operated NIA HV-151 FOO? A (b)(c) RHR-Minimum Recirculation Flow Power Operated NIA HV-151 FOO? B (b)(c) RHR-Minimum Recirculation Flow Power Operated 'NIA HV-151 FOOS RHR - Shutdown Cooling Suction Automatic Valve 6.a, 6.b, 6.c (52)

HV-151F009 RHR - Shutdown Cooling Suction Automatic Valve 6.a, 6.b, 6.c (52)

HV-151 F011 A (b)(d) RHR-Suppression Pool Manual NIA Cooling/Spray HV-151F011 B (b)(d) RHR-Suppression Pool Manual NIA Cooling/Spray HV-151 F015 A (f) RHR - Shutdown Cooling Power Operated NIA Return/LPCI Injection HV-151F015 B (f) RHR - Shutdown Cooling Power Operated NIA Return/LPCI Injection HV-151 F016 A (b) RHR - Drywell Spray Automatic Valve 2.c, 2.d (90)

HV-151 F016 B (b) RHR - Drywell Spray Automatic Valve 2.c, 2.d (90)

HV-151F022 RHR - Reactor Vessel Head Spray Automatic Valve 2.d, 6.a, 6.b, 6.c (30)

. HV-151F023 RHR - Reactor Vessel Head Spray Automatic Valve 2.d, 6.a, 6.b, 6.c (20)

HV-151F028 A (b) . RHR - Suppression Pool Automatic Valve 2.c, 2.d (90)

Cooling/Spray HV-151 F028 B (b) RHR - Suppression Pool Automatic Valve 2.c, 2.d (90)

Cooling/Spray HV-151 F050 A (g) RHR - Shutdown Cooling Air Operated Check NIA Return/LPCI Injection Valve Valve HV-151 F050 B (g) RHR - Shutdown Cooling Air Operated Check NIA Return/LPCI Injection Valve Valve HV-151F103 A (b) RHR Heat Exchanger Vent Power Operated NIA HV-151F103 B (b) RHR Heat Exchanger Vent Power Operated NIA SUSQUEHANNA - UNIT 1 TS I B 3.6-38 Revision 3

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-1 (continued)

Primary Containment Isolation Valve (Page 10of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Residual Heat HV-151F122 A (g) RHR - Shutdown Cooling Power Operated NIA Removal ReturnlLPCI Injection Valve (Air)

(continued) HV-151F122 B (g) RHR - Shutdown Cooling Power Operated NIA ReturnlLPCI Injection Valve (Air)

PSV-15106 A (b)(d) RHR - Relief Valve Discharge Relief Valve NIA PSV-15106 B (b)(d) RHR - Relief Valve Discharge Relief Valve NIA PSV-151F126 (d) RHR - Shutdown Cooling Suction Relief Valve NIA XV-15109A RHR Excess Flow Check NIA Valve XV-15109 B RHR Excess Flow Check NIA Valve XV-15109 C RHR Excess Flow Check NIA Valve XV-15109 D RHR Excess Flow Check NIA Valve RWCU HV-144F001 (a) RWCU Suction Automatic Valve 5.a, 5.b, 5.c, 5.d, 5.f, 5.g (30)

HV-144F004 (a) RWCU Suction Automatic Valve 5.a, 5.b, 5.c, 5.d, 5.e, 5.f, 5.g (30)

XV-14411 A RWCU Excess Flow Check NIA Valve XV-14411 B RWCU Excess Flow Check NIA Valve XV-14411 C RWCU Excess Flow Check NIA Valve XV-14411 D RWCU Excess Flow Check NIA Valve XV-144F046 RWCU Excess Flow Check NIA Valve HV-14182 A RWCU Return Isolation Valve Power Operated NIA HV-14182 B RWCU Return Isolation Valve Power Operated NIA SLCS 148F007 (a)(d) SLCS Manual Check NIA HV-148F006 (a) SLCS Power Operated NIA Check Valve TIP System C51-J004 A (Shear TIP Shear Valves Squib Valves NIA Valve)

C51-J004 B (Shear TIP Shear Valves Squib Valves NIA Valve)

C51-J004 C (Shear TIP Shear Valves Squib Valves NIA Valve)

C51-J004 D (Shear TIP Shear Valves Squib Valves NIA Valve)

C51-J004 E (Shear TIP Shear Valves Squib Valves NIA Valve)

SUSQUEHANNA - UNIT 1 TS I B 3.6-39 Revision 2

Rev. 12 PC IVs B 3.6.1 3 TableB 3.6.1.3-1 Primary Containment Isolation Valve (Page 11 of11)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

TIP System C51-J004 A (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

(continued) Valve)

C51-J004 B (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

C51-J004 C (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

C51-J004 D (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

C51-J004 E (Ball TIP Ball Valves Automatic Valve 7.a, 7.b (5)

Valve)

(a) Isolation barrier remains water filled or a water seal remains in the line post-LOCA, isolation valve is tested with water. Isolation valve leakage is not included in 0.60 La total Type B and C tests.

(b) Redundant isolation boundary for this valve is provided by the closed system whose integrity is verified by the Leakage Rate Test Program. This footnote does not apply to valve 155F046 (HPCI) when the associated PCIV, HV155F012 is closed and deactivated. Similarly, this footnote does not apply to valve 149F021 (RCIC) when it's associated PCIV, FV149F019 is closed and deactivated.

(c) Containment Isolation Valves are not Type C tested. Containment bypass leakage is prevented since the line terminates below the minimum water level in the Suppression Chamber. Refer to the IST Program.

(d) LCO 3.3.3.1, "PAM Instrumentation," Table 3.3.3.1-1, Function 6, does not apply since these are relief valves, check valves, manual valves or deactivated and closed.

(e) The containment isolation barriers for the penetration associated with this valve consists of two PC IVs and a closed system. The closed system provides a redundant isolation boundary for both PC IVs, and its integrity is required to be verified by the Leakage Rate Test Program.

(f) Redundant isolation boundary for this valve is provided by the closed system whose integrity is verified by the Leakage Rate Test Program.

(g) These valves are not required to be 10 CFR 50, Appendix J tested since the HV-151 F015A(B) valves and a closed system form the 10 CFR 50, Appendix J boundary. These valves form a high/low pressure interface and are pressure tested in accordance with the pressure test program.

SUSQUEHANNA - UNIT 1 TS I B 3.6-40 Revision 6

Rev. 12 PC IVs B 3.6.1.3 Table B 3.6.1.3-2 Secondary Cont~inment Bypass Leakage Isolation Valves (Not PCIVs)

(Page 1 of 1)

Isolation Signal LCO 3.3.6.1 Function No.

Plant System Valve Number Valve Description Type of Valve (Maximum Isolation Time (Seconds))

Residual Heat HV-151 F040 RHR - RADWASTE LINE IB ISO Automatic Valve 2.a, 2.d (45)

Removal VLV HV-151F049 RHR- RADWASTE LINE OB ISO Automatic Valve 2.a, 2.d (20)

VLV 1-51-136 RHR - COND TRANSFER OB SCBL Check Valve NIA CHECK VALVE 1-51-137 RHR - COND TRANSFER IB SCBL Check Valve NIA CHECK VALVE SUSQUEHANNA - UNIT 1 TS I B 3.6-40a Revision 1