ML043570432

Technical Requirements Manual

ML043570432
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Site:	Susquehanna
Issue date:	12/15/2004
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Dec. 15, 2004

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THE FOLLOWING CHANGES HAVE OCCURRED TO THE HARDCOPY OR ELECTRONIC MANUAL ASSIGNED TO YOU:

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'nD MANUAL TABLE OF CONTENTS DATE: 12/14/2004

< ATEGORY: DOCUMENTS TYPE: TRM2 ID: TEXT 2.2 REMOVE: REV:2 ADD: REV: 3 CATEGORY: DOCUMENTS TYPE: TRM2 ID: TEXT 3.11.1.4 REMOVE: REV:O ADD: REV: 1 CATEGORY: DOCUMENTS TYPE: TRM2 ID: TEXT 3.11.2.6 REMOVE: REV:1 ADD: REV: 2 CATEGORY: DOCUMENTS TYPE: TRM2 ID: TEXT 3.11.4.2 REMOVE: REV:0 ADD: REV: 1 CATEGORY: DOCUMENTS TYPE: TRM2 ID: TEXT 3.3.10 REMOVE: REV:0 CATEGORY: DOCUMENTS TYPE: TRM2 ID: TEXT 3.4.4 REMOVE: REV:0

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Dec. 15, 2004 Page3 of 3 REMOVE: REV:0 ADD: REV: 1 CATEGORY: DOCUMENTS TYPE: TRM2 ID: TEXT B3.7.9 REMOVE: REV:0 ADD: REV: 1 CATEGORY: DOCUMENTS TYPE: TRM2 ID: TEXT LOES REMOVE: REV:8 ADD: REV: 9 CATEGORY: DOCUMENTS TYPE: TRM2 ID: TEXT TOC REMOVE: REV:3 ADD: REV: 4 UPDATES FOR HARD COPY MANUALS WILL BE DISTRIBUTED WITHIN 5 DAYS IN ACCORDANCE WITH DEPARTMENT PROCEDURES. PLEASE MAKE ALL CHANGES AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX UPON RECEIPT OF HARD COPY. FOR ELECTRONIC MANUAL USERS, ELECTRONICALLY VIEW THE APPROPRIATE DOCUMENTS AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX.

SSES MANUAL

- Manual Nxaee

-...T.E2

'ianual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 Table Of Contents Issue Date: 12/14/2004 Procedure Name Rev Issue Date Change Change Number

'D TRM2 N/A 08/01/2003

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT.2-(07/28/2003)

LDCN 3749 TEXT LOES 9 12/14/2004

Title:

LIST OF EFFECTIVE SECTIONS TEXT TOC 4 12/14/2004

Title:

TABLE OF CONTENTS TEXT 1.1 0 11/19/2002 1

Title:

USE AND APPLICATION DEFINITIONS -

TEXT 2.1 0 11/19/200)

Title:

PLANT PROGRAMS AND SETPOINTS/PLANT PROGRAMS TEXT 2.2 . 3/ 12/14/2004

Title:

PLANT PROGRAMS AND SETPOINTS'INSTRUMENT TRIP SETPOINT TABLE TEXT 3.0 e 0 J 11/19/2002

Title:

APPLICABILITY TECHNICAL REQUIREMENT FOR OPERATION (TRO) APPLICABILITY TEXT 3.1.1 A 0 11/19/2002

Title:

REACTIVITY CONTROL SYSTEMS ANTICIPATED TRANSIENT WITHOUT SCRAM ALTERNATE ROD INJECTIONW'(ATWS-ARI) INSTRUMENTATION TEXT 4.3 0 09/27/2003

Title:

ADMINISTRATIVE CONTROLS SAFETY LIMIT:VIOLATION TEXT 3.1.2 0 11/19/2002

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD DRIVE (CRD) HOUSING SUPPORT TEXT 3.1.3 0 11/19/2002

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD BLOCK INSTRUMENTATION Report Date: 12/14/04 Page I1 Page of of 14 14 Report Date: 12/14/04

SSES S'MANUAL Manual Name - . .TR2 A V Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 -'

TEXT 3.1.4 0 11/19/2002

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS INSTRUMENTATION AND CHECK VALVE TEXT 3.2.1 3. 11/22/2004

Title:

CORE OPERATING LIMITS CORE OPERATING LIMITS REPORT (COLR)

TEXT 3.3.1 0 11/19/2002

Title:

INSTRUMENTATION RADIATION MONITORING INSTRUMENTATION TEXT 3.3.2 0 11/19/2002

Title:

INSTRUMENTATION SEISMIC MONITORING INSTRUMENTATION TEXT 3.3.3 0 11/19/2002

Title:

INSTRUMENTATION METEOROLOGICAL MONITORING INSTRUMENTATION TEXT 3.3.4 0 11/19/2002

Title:

INSTRUMENTATION TRM POST-ACCIDENT MONITORING INSTRUMENTATION TEXT 3.3.5 0 11/19/2002

Title:

INSTRUMENTATION THIS PAGE INTENTIONALLY LEFT BLANK TEXT 3.3.6 - 1 10/22/2003-

Title:

INSTRUMENTATION TRM ISOLATION ACTUATION INSTRUMENTATION TEXT 3.3.7 -0 ;11/19/2002

Title:

INSTRUMENTATION MAIN TURBINE OVERSPEED PROTECTION SYSTEM TEXT 3.3.8 1 10/22/2003

Title:

INSTRUMENTATION TRM RPS INSTRUMENTATION TEXT 3.3.9  ; 1 11/22/2004

Title:

INSTRUMENTATION LPRM UPSCALE ALARM INSTRUMENTATION TEXT 3.3.10 . --- 12/14/2004

Title:

INSTRUMENTATION REACTOR RECIRCULATION PUMP MG SET STOPS Page 2 of 14- Report Date: 12/14/o42c

I 'SSESMA' NUAL Manual Name:- TRX2.

Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 -

TEXT 3.3.11 1 10/22/2003

Title:

INSTRUMENTATION MVP ISOLATION INSTRUMENTATION' TEXT 3.4.1 0 11/19/2002

Title:

REACTOR COOLANT SYSTEM REACTOR COOLANT SYSTEM CHEMISTRY TEXT 3.4.2 0 11/19/2002. I

Title:

REACTOR COOLANT SYSTEM STRUCTURAL'.INTEGRITY TEXT 3.4.3 0 11/19/2002

Title:

REACTOR COOLANT SYSTEM REACTOR COOLANT SYSTEM (RCS)

TEXT 3.4.4 1 12/14/2004

Title:

REACTOR COOLANT SYSTEM REACTOR RECIRCULATION FLOW AND ROD LINE LIMIT TEXT 3.4.5 0 11/18/2002

Title:

REACTOR COOLANT SYSTEM REACTOR VESSEL MATERIALS TEXT 3.5.1 0 11/19/2002'

Title:

ECCS AND RCIC ADS MANUAL INHIBIT TEXT 3.5.2 0 11/19/2002

Title:

ECCS AND RCIC ECCS AND RCIC SYSTEM MONITORING INSTRUMENTATION TEXT 3.5.3 0 11/19/2002 -,

Title:

ECCS AND RCIC LONG TERM NITROGEN'SUPPLY TO ADS TEXT 3.6.1 0 11/19/2002

Title:

CONTAINMENT VENTING OR PURGING TEXT 3.6.2 0 11/19/2002

Title:

CONTAINMENT SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKER POSITION INDICATION TEXT 3.6.3 0 11/19/2002

Title:

CONTAINMENT SUPPRESSION POOL ALARM INSTRUMENTATION Report Date: 12/14/04 Page33 Page -of of 14

14. Report Date: 12/14/04-

4 SSES MANUAL Manual Name- ..TBM- .I -I, v Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 ,

TEXT 3.6.4 0 11/19/2002

Title:

CONTAINMENT PRIMARY CONTAINMENT CLOSED SYSTEM BOUNDARIES TEXT 3.7.1 0 11/19/2002

Title:

PLANT SYSTEMS EMERGENCY SERVICE WATER SYSTEM (ESW) SHUTDOWN TEXT 3.7.2 0 11/19/2002

Title:

PLANT SYSTEMS ULTIMATE HEAT SINK (UHS) AND GROUND WATER LEVEL TEXT 3.7.3.1 0 11/19/2002

Title:

PLANT SYSTEMS FIRE SUPPRESSION WATER SUPPLY SYSTEM TEXT 3.7.3.2 0 11/19/2002

Title:

PLANT SYSTEMS SPRAY AND SPRINKLER SYSTEMS TEXT 3.7.3.3 0 11/19/2002

Title:

PLANT SYSTEMS C02 SYSTEMS TEXT 3.7.3.4 0 11/19/2002

Title:

PLANT SYSTEMS HALON SYSTEMS TEXT 3.7.3.5 0 11/19/2002

Title:

PLANT SYSTEMS FIRE-HOSESTATIONS TEXT 3.7.3.6 0 11/19/2002

Title:

PLANT SYSTEMS YARD FIRE HYDRANTS AND HYDRANT HOSE HOUSES TEXT 3.7.3.7 0 11/19/2002

Title:

PLANT SYSTEMS FIRE RATED ASSEMBLIES TEXT 3.7.3.8 1 01/12/2004

Title:

PLANT SYSTEMS FIRE DETECTION INSTRUMENTATION TEXT 3.7.4 0 11/19/2002

Title:

PLANT SYSTEMS SOLID RADWASTE SYSTEM Report Date: 12/14/04 Page44 _:

Page ;of 14

-of ,14, Report Date: 12/14/04 -

.SSES MANUAL

, Manual Name:--.TRRM2 Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 :

TEXT 3.7.5.1 0 11/19/2002  :

Title:

PLANT SYSTEMS MAIN CONDENSER OFFGAS HYDROGEN MONITOR TEXT 3.7.5.2 0 11/19/2002 ..

Title:

PLANT SYSTEMS MAIN CONDENSER OFFGAS EXPLOSIVE GAS MIXTURE TEXT 3.7.5.3 0 11/19/2002

Title:

PLANT SYSTEMS LIQUID HOLDUP TANKS - . .

TEXT 3.7.6 0 11/19/2002 -

Title:

PLANT SYSTEMS ESSW PUMPHOUSE VENTILATION TEXT 3.7.7 0 11/19/2002

Title:

PLANT SYSTEMS MAIN CONDENSER OFFGAS PRETREATMENT LOGARITHMIC RADIATION MONITORING INSTRUMENTATION TEXT 3.7.8 1 12/14/2004

\__1

Title:

PLANT SYSTEMS SNUBBERS TEXT 3.7.9 0 11/19/2002

Title:

PLANT SYSTEMS CONTROL STRUCTUREHVAC TEXT 3.7.10 1 12/14/2004

Title:

PLANT SYSTEMS SPENT FUELSTORAGE POOLS (SFSPS)'.

TEXT 3.8.1 0 11/19/2002 -

Title:

ELECTRICAL POWER PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES TEXT 3.8.2.1 1 12/14/2004 -

Title:

ELECTRICAL POWER MOTOR OPERATEDNVALVES (MOV) THERMAL OVERLOAD PROTECTION -

CONTINUOUS TEXT 3.8.2.2 2 12/14/2004-

Title:

ELECTRICAL POWER MOTOR OPERATED :VALVES-(MOV). THERMAL OVERLOAD PROTECTION -

AUTOMATIC TEXT 3.8.3 0 11/19/2002.

Title:

ELECTRICAL POWER DIESEL GENERATOR (DG) MAINTENANCE ACTIVITIES -

Report Date: 12/14/04 PageS5 Page of of 14.

14 e. Report Date: 12/14/04

SSES MANUAL Manual Names .T-MZ . i t.

-v Manual

Title:

TECHNICAL REQUIREMENTS MANUAL'UNIT 2:

TEXT 3.8.4 0 11/19/2002

Title:

ELECTRICAL POWER 24 VDC ELECTRICAL SUBSYSTEM TEXT 3.8.5 0 11/19/2002

Title:

ELECTRICAL POWER DEGRADED VOLTAGE PROTECTION TEXT 3.8.6 0 11/19/2002

Title:

ELECTRICAL POWER EMERGENCY SWITCHGEAR ROOM'COOLING TEXT 3.9.1 0 11/19/2002

Title:

REFUELING OPERATIONS DECAY TIME TEXT 3.9.2 0 11/19/2002

Title:

REFUELING OPERATIONS COMMUNICATIONS.

TEXT 3.9.3 0 11/19/2002

Title:

REFUELING OPERATIONS REFUELING PLATFORM TEXT 3.10.1 0 11/19/2002

Title:

MISCELLANEOUS SEALED SOURCE CONTAMINATION TEXT 3.10.2 0 11/19/2002

Title:

MISCELLANEOUS SHUTDOWN MARGIN TEST RPS INSTRUMENTATION TEXT 3.10.3 0 11/19/2002

Title:

MISCELLANEOUS INDEPENDENT SPENT FUEL STORAGE INSTALLATION-(ISFSI)

TEXT 3.10.4 0 11/19/2002

Title:

MISCELLANEOUS LEADING EDGE FLOW METER (LEFM)

TEXT 3.11.1.1 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS LIQUID EFFLUENTS CONCENTRATION TEXT 3.11.1.2 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS LIQUID EFFLUENTS DOSE Page 6 of 14 Report Date: 12/14/04

I .SSES MANUAL t Manual Name:_.-.RMH2 Manual

Title:

TECHNICAL REQUIREMENTS MANUAL'UNIT 2 TEXT 3.11.1.3 0 11/19/2002'

Title:

RADIOACTIVE EFFLUENTS LIQUID'WASTE-TREATMENT SYSTEM TEXT 3.11.1.4 1 12/14/2004

Title:

RADIOACTIVE EFFLUENTS LIQUID RADWASTE EFFLUENT MONITORING INSTRUMENTATION TEXT 3.11.4.2 1 12/14/2004

Title:

RADIOACTIVE EFFLUENTS LAND USE-CENSUS TEXT 3.11.4.3 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS INTERLABORATORY COMPARISON PROGRAM TEXT 3.12.1 0 11/19/2002

Title:

LOADS CONTROL PROGRAM CRANE TRAVEL-SPENT'FUEL STORAGE POOL:

TEXT 3.12.2 0 11/19/2002 -

\ a;

Title:

LOADS CONTROL PROGRAM HEAVY LOADS-REQUIREMENTS TEXT 3.12.3 0 11/19/2002

Title:

LOADS CONTROL PROGRAM LIGHT LOADS REQUIREMENTS TEXT B3.0 0 11/19/2002

Title:

APPLICABILITY BASES TECHNICAL REQUIREMENT FOR OPERATION (TRO) APPLICABILITY TEXT B3.1.1 0 11/19/2002

Title:

REACTIVITY CONTROL SYSTEM BASES ANTICIPATED TRANSIENT WITHOUT SCRAM ALTERNATE ROD INJECTION (ATWS-ARI) INSTRUMENTATION TEXT B3.1.2 0 11/19/2002

Title:

REACTIVITY CONTROL SYSTEM BASES CONTROL ROD DRIVE '(CRD) HOUSING SUPPORT TEXT B3.1.3 0 11/19/2002

Title:

REACTIVITY CONTROL SYSTEM BASES CONTROL ROD BLOCK INSTRUMENTATION '

TEXT B3.1.4 0 11/19/2002 '

Title:

REACTIVITY CONTROL SYSTEM BASES CONTROL ROD SCRAM ACCUMULATORS INSTRUMENTATION AND CHECK VALVE Report Date: 12/14/04 Page 77 Page .of 14 of 14 Report Date: 12/14/04

SSES MANUAL Manual Name---TSRV2 A, Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 TEXT B3.2.1 0 11/19/2002

Title:

CORE OPERATING LIMITS BASES CORE OPERATING LIMITS REPORT (COLR)

TEXT B3.3.1 0 11/19/2002

Title:

INSTRUMENTATION BASES RADIATION MONITORING INSTRUMENTATION TEXT B3.3.2 0 11/19/2002

Title:

INSTRUMENTATION BASES SEISMIC MONITORING INSTRUMENTATION TEXT B3.3.3 0 11/19/2002

Title:

INSTRUMENTATION BASES METEOROLOGICAL MONITORING INSTRUMENTATION TEXT B3.3.4 0 11/19/2002

Title:

INSTRUMENTATION BASES TRM POST ACCIDENT MONITORING (PAM) INSTRUMENTATION TEXT B3.3.5 0 11/19/2002

Title:

INSTRUMENTATION BASES THIS PAGE INTENTIONALLY LEFT BLANK TEXT B3.3.6 2 12/14/2004

Title:

INSTRUMENTATION BASES TRM ISOLATION ACTUATION INSTRUMENTATION TEXT B3.3.7 0 11/19/2002

Title:

INSTRUMENTATION BASES MAIN TURBINE OVERSPEED PROTECTION SYSTEM TEXT B3.3.8 1 10/22/2003

Title:

INSTRUMENTATION BASES TRM RPS INSTRUMENTATION TEXT B3.3.9 1 11/22/2004

Title:

INSTRUMENTATION BASES LPRM UPSCALE ALARM INSTRUMENTATION TEXT B3.3.10 0 11/19/2002

Title:

INSTRUMENTATION BASES REACTOR RECIRCULATION PUMP MG SET STOPS TEXT B3.3.11 1 10/22/2003

Title:

INSTRUMENTATION BASES MVP ISOLATION INSTRUMENTATION Report Date: 12/14/04 Page 88 of of 14 14 Report Date: 12/14/04

X. SSES MANUAL

- Manual Name .-TEM2 Manual

Title:

TECHNICAL REQUIREMENTS MANUAL-UNIT 2 TEXT B3.4.1 0 11/19/2002

Title:

REACTOR COOLANT SYSTEM BASES REACTOR COOLANT SYSTEM CHEMISTRY TEXT B3.4.2 0 11/19/2002

Title:

REACTOR COOLANT SYSTEM BASES STRUCTURAL INTEGRITY -

TEXT B3.4.3 0 11/19/2002

Title:

REACTOR COOLANT SYSTEM BASES HIGH/LOW PRESSURE INTERFACE LEAKAGE MONITOR TEXT B3.4.4 0 11/19/2002

Title:

REACTOR COOLANT SYSTEM BASES REACTOR RECIRCULATION FLOW AND ROD LINE LIMIT TEXT B3.4.5 0 11/19/2002

Title:

REACTOR COOLANT SYSTEM BASES REACTOR VESSEL MATERIALS TEXT B3.5.1 0 11/19/2002

Title:

ECCS AND RCIC BASES ADS MANUAL INHIBIT '

TEXT B3.5.2 0 11/19/2002

Title:

ECCS AND RCIC BASES ECCS AND RCIC'SYSTEM MONITORING INSTRUMENTATION TEXT B3.5.3 0 11/19/2002

Title:

ECCS AND RCIC BASES LONG TERM NITROGEN SUPPLY TO ADS TEXT B3.6.1 0 11/19/2002'

Title:

CONTAINMENT BASES VENTING OR PURGING -

TEXT B3.6.2 0 11/19/2002

Title:

CONTAINMENT BASES SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKER POSITION INDICATION TEXT B3.6.3 0 11/19/2002

Title:

CONTAINMENT BASES SUPPRESSION POOL'ALARM INSTRUMENTATION TEXT B3.6.4 1 12/14/2004

Title:

CONTAINMENT BASES PRIMARY CONTAINMENT CLOSED SYSTEM BOUNDARIES Report Date: 12/14/04 Page 9 of 14 14 Report Date: 12/14/04'

SSES MANUAL Manual Name:-.--TRU2 Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 TEXT B3.7.1 0 11/19/2002

Title:

PLANT SYSTEMS BASES EMERGENCY SERVICE WATER SYSTEM (SHUTDOWN)

TEXT B3.7.2 0 11/19/2002

Title:

PLANT SYSTEMS BASES ULTIMATE HEAT SINK (UHS) GROUND WATER LEVEL TEXT B3.7.3.1 0 11/19/2002

Title:

PLANT SYSTEMS BASES FIRE SUPPRESSION WATER SUPPLY SYSTEM TEXT B3.7.3.2 0 11/19/2002

Title:

PLANT SYSTEMS BASES SPRAY AND SPRINKLER SYSTEMS TEXT B3.7.3.3 0 11/19/2002

Title:

PLANT SYSTEMS BASES C02 SYSTEMS TEXT B3.7.3.4 0 11/19/2002

Title:

PLANT SYSTEMS BASES HALON SYSTEMS TEXT B3.7.3.5 0 11/19/2002

Title:

PLANT SYSTEMS BASES FIRE HOSE STATIONS TEXT B3.7.3.6 0 11/19/2002

Title:

PLANT SYSTEMS BASES YARD FIRE HYDRANTS AND HYDRANT HOSE HOUSES TEXT B3.7.3.7 0 11/19/2002

Title:

PLANT SYSTEMS BASES FIRE RATED ASSEMBLIES TEXT B3.7.3.8 1 01/12/2004

Title:

PLANT SYSTEMS BASES FIRE DETECTION INSTRUMENTATION TEXT B3.7.4 0 11/19/2002

Title:

PLANT SYSTEMS BASES SOLID RADWASTE SYSTEM TEXT B3.7.5.1 0 11/19/2002

Title:

PLANT SYSTEMS BASES MAIN CONDENSER OFFGAS HYDROGEN MONITOR Report Date: 12/14/04 Page 10 10 of of 14 14 Report Date: 12/14/04

-SSES MANUAL I Manual Name:--- .TF2 Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2' TEXT B3.7.5.2 0 11/19/2002

Title:

PLANT SYSTEMS BASES MAIN CONDENSER'OFFGAS EXPLOSIVE GAS MIXTURE TEXT B3.7.5.3 0 11/19/2002'"

Title:

PLANT SYSTEMS BASES LIQUID HOLDUP'TANKS-TEXT B3.7.6 0 11/19/2002

Title:

PLANT SYSTEMS BASES ESSW PUMPHOUSE VENTILATION TEXT B3.7.7 0 11/19/2002

Title:

PLANT SYSTEMS BASES MAIN CONDENSER OFFGAS PRETREATMENT LOGARITHMIC RADIATION MONITORING INSTRUMENTATION TEXT B3.7.8 1 12/14/2004 '

Title:

PLANT SYSTEMS BASES SNUBBERS' .. ,';

TEXT B3.7.9 1 12/14/2004 l

__/:

Title:

PLANT SYSTEMS BASES CONTROL STRUCTURE HVAC TEXT B3.7.10 1 12/14/2004 -

Title:

PLANT SYSTEMS BASES SPENT FUEL'STORAGE POOLS TEXT B3.8.1 0 11/19/2002 7

Title:

ELECTRICAL POWER BASES PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES TEXT B3.8.2.1 0 11/19/2002

Title:

ELECTRICAL POWER BASES MOTOR OPERATED VALVES (MOV)'THERMAL OVERLOAD PROTECTION -

CONTINUOUS TEXT B3.8.2.2 1 09/17/2004

Title:

ELECTRICAL POWER BASES MOTOR OPERATED VALVES (MOV) THERMAL OVERLOAD PROTECTION -

AUTOMATIC TEXT B3.8.3 0 11/19/2002

Title:

ELECTRICAL POWER BASES DIESEL GENERATOR (DG) MAINTENANCE ACTIVITIES TEXT B3.8.4 0 11/19/2002

Title:

ELECTRICAL POWER BASES 24 VDC ELECTRICAL POWER SUBSYSTEM Report Date: 12/14/04 Page 11 -_:

Page of of 14 14 Report Date: 12/14/04

I..

SSES MANUAL Manual Name: T- 2 Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 TEXT B3.8.5 0 11/19/2002

Title:

ELECTRICAL POWER BASES DEGRADED VOLTAGE PROTECTION TEXT B3.8.6 0 11/19/2002

Title:

ELECTRICAL POWER BASES EMERGENCY SWITCHGEAR ROOM COOLING TEXT B3.9.1 0 11/19/2002

Title:

REFUELING OPERATIONS BASES DECAY TIME TEXT B3.9.2 0 11/19/2002

Title:

REFUELING OPERATIONS BASES COMMUNICATIONS TEXT B3.9.3 0 11/19/2002

Title:

REFUELING OPERATIONS BASES REFUELING PLATFORM TEXT B3.10.1 0 11/19/2002

Title:

MISCELLANEOUS BASES SEALED SOURCE CONTAMINATION TEXT B3.10.2 0 11/19/2002

Title:

MISCELLANEOUS BASES SHUTDOWN MARGIN TEST RPS INSTRUMENTATION TEXT B3.10.3 0 11/19/2002

Title:

MISCELLANEOUS BASES INDEPENDENT SPENT FUEL STORAGE INSTALLATION (ISFSI)

TEXT B3.10.4 0 11/19/2002

Title:

MISCELLANEOUS BASES LEADING EDGE FLOW METER (LEFM)

TEXT B3.11.1-1 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS BASES LIQUID EFFLUENTS CONCENTRATION TEXT B3.11.1.2 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS BASES LIQUID EFFLUENTS DOSE TEXT B3.11.1.3 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS BASES LIQUID WASTE TREATMENT SYSTEM Report Date: 12/14/04 12 Page 12 of of 14 14 Report Date: 12/14/04

z.SSES MANUAL

^ Manual Name:-- -T2 Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 TEXT B3.11.1.4 0 11/19/2002' '

Title:

RADIOACTIVE EFFLUENTS BASES LIQUID RADWASTE EFFLUENT MONITORING INSTRUMENTATION TEXT B3.11.1.5 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS-BASES RADIOACTIVE LIQUID PROCESS MONITORING INSTRUMENTATION TEXT B3.11.2.1 1 12/14/2004-

Title:

RADIOACTIVE EFFLUENTS BASES DOSE'RATE TEXT B3.11.2.2 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS BASES DOSE - NOBLE GASES - -

TEXT B3.11.2.3 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS BASES .DOSE - IODINE, ,TRITIUM, AND RADIONUCLIDES IN PARTICULATES FORM TEXT B3.11.2.4 0 11/19/2002 '_

Title:

RADIOACTIVE EFFLUENTS BASES GASEOUS RADWASTE TREATMENT SYSTEM ' -

TEXT B3.11.2.5 2 10/27/2004

Title:

RADIOACTIVE EFFLUENTS BASES VENTILATION EXHAUST-TREATMENT SYSTEM TEXT B3.11.2.6 1 01/27/2004

Title:

RADIOACTIVE EFFLUENTS BASES RADIOACTIVE GASEOUS EFFLUENT-MONITORING INSTRUMENTATION LDCN 3614 TEXT B3.11.3 0 11/19/2002 -'

Title:

RADIOACTIVE EFFLUENTS BASES-TOTALDOSE.:

TEXT B3.11.4.1 1 12/14/2004',

Title:

RADIOACTIVE EFFLUENTS BASESMONITORING PROGRAM :

TEXT B3.11.4.2 0 11/19/2002 '

Title:

RADIOACTIVE EFFLUENTS BASES LAND USE CENSUS -

TEXT B3.11.4.3 0 11/19/2002

Title:

RADIOACTIVE EFFLUENTS BASES INTERLABORATORY COMPARISON PROGRAM Report Date:' 12/14/04 Page 13 Page 13 of of 14 14 - Report Date:'12/14/04

SSES MANUAL Manual Name:---.T Manual

Title:

TECHNICAL REQUIREMENTS MANUAL UNIT 2 TEXT B3.12.1 0 11/19/2002

Title:

LOADS CONTROL PROGRAM BASES CRANE TRAVEL-SPENT FUEL STORAGE POOL TEXT B3.12.2 0 11/19/2002

Title:

LOADS CONTROL PROGRAM BASES HEAVY LOADS REQUIREMENTS TEXT B3.12.3 0 11/19/2002

Title:

LOADS CONTROL PROGRAM BASES LIGHT LOADS REQUIREMENTS TEXT 3.11.2.1 1 01/27/2004

Title:

RADIOACTIVE EF 'FLUENTS DOSE RATE TEXT 3.11.2.6 2 12/14/2004

Title:

RADIOACTIVE EB'FLUENTS RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION LDCN 3614 TEXT 4.1 0 09/27/2003

Title:

ADMINISTRATIVE CONTROLS ORGANIZATION TEXT 4.2 0 09/27/2003

Title:

ADMINISTRATIVE CONTROLS REPORTABLE EVENT ACTION TEXT 4.4 0 09/27/2003

Title:

ADMINISTRATIVE CONTROLS PROCEDURES & PROGRAMS TEXT 4.5 0 09/27/2003

Title:

ADMINISTRATIVE CONTROLS REPORTING REQUIREMENTS TEXT 4.6 0 09/27/2003

Title:

ADMINISTRATIVE CONTROLS RADIATION PROTECTION PROGRAM TEXT 4.7 0 09/27/2003

Title:

ADMINISTRATIVE CONTROLS TRAINING Report Date: 12/14/04 Page 14 of of 14 14 Report Date: 12/14/04

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 9 UST.OF.9E-FECTAIE SECTIONS (TECHNICAL REQUIREMENTS MANUAL)

Section Title Effective Date TOC TABLE OF CONTENTS 11/15/2004 1.0 USE AND APPLICATION Page TRM /1.0-1 08/31/1998 Page TRM / 1.0-2 10/04/2002 Page TRM / 1.0-3 08/31/1998 2.0 PLANT PROGRAMS Page 2.0-1 08/31/1998 Pages TRM / 2.0-2 through TRM / 2.0-4 06/25/2002 Page TRM / 2.0-5 04/12/1999 Pages TRM / 2.0-6 and TRM / 2.0-7 \ 11/15/2004 Page TRM / 2.0-8 ) 12/03/2004 Pages TRM /2.0-9 through TRM 2.0-14 11/15/2004 3.0 APPLICABILITY Pages TRM / 3.0-1 and TRM / 3.0-2 04/08/1999 Page TRM / 3.0-3 03/15/2002 Page TRM / 3.0-4 04/08/1999 3.1 REACTIVITY CONTROL SYSTEMS Pages 3.1-1 through 3.1-6 ' 08/31/1998 Pages TRM /3.1-7 and TRM-/ 3.1-BJ 06/05/2002 Pages TRM / 3.1-9 and TR /J 3.i:9a 02/18/1999 Page TRM /3.1-10 02/18/1999 3.2 CORE OPERATING LIMITS REPORT Page 3.2-1 ' +/-¢ / 3.-3 08/31/1998 Pages TRM _2'through TRM / 3.2-38 11/15/2004 3.3 INSTRUMENTATION--"

Pages'tRM / 33,1i through TRM / 3.3-3 07/16/1999 (gps^3.3-5,through PageTRM /j3.3-4 3.3-8 Pages RM / 3.3-9 and TRM / 3.3-9a 11/28/2000 08/31/1998 12/17/1998 ages TRM / 3.3-10 and TRM / 3.3-11 12/17/1998 Page TRM / 3.3-12 03/30/2001 Pages TRM / 3.3-13 and TRM / 3.3-14 12/14/1998 Page TRM /3.3-15 10/22/2003 Page TRM /3.3-16 06/27/2001 Pages TRM / 3.3-17 and TRM / 3.3-18 06/14/2002 Pages TRM / 3.3-19 and TRM / 3.3-20 10122/2003 Page TRM / 3.3-21 11/15/2004 Pages TRM /3.3-21a through TRM / 3.3-21d 11/15/2004 Pages TRM /3.3-22 12/0312004 Pages TRM /3.3-23 and TRM / 3.3-24 05/16/2003 10/22/2003 I

Page TRM / 3.3-25 SUSQUEHANNA - UNIT 2 TRM / LOES-1 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 9 IST OF EFFECTIVESECTIONS (TECHNICAL REQUIREMENTS MANUAL)

Section Title Effective Date 3.4 REACTOR COOLANT SYSTEM Pages 3.4-1 through 3.4-5 10/23/1998 Pages 3.4-6 through 3.4-11 08/31/1998 Page TRM / 3.4-12 12/03/2004 Page 3.4-13 08/31/1998 3.5 EMERGENCY CORE COOLING AND RCIC Pages 3.5-1 through 3.5-3 08/31/1998 Page TRM / 3.5-4 04/17/2000 Pages 3.5-5 through 3.5-7 08/31/1998 3.6 CONTAINMENT Pages 3.6-1 through 3.6-4 08/31/1 998 Page TRM / 3.6-5 01/07/2002 Page 3.6-6 08/31/1998 Pages TRM / 3.6-7 through TRM / 3.6-9 12/31/2002 3.7 PLANT SYSTEMS Pages TRM / 3.7-1 and TRM /3.7-2 07/2911999 Page 3.7-3 08/31/1998 Pages TRM / 3.7-4 through TRM /3.7-10 08/02/1999 Page TRM / 3.7-11 01/21/2000 Pages TRM / 3.7-12 through TRM / 3.7-27 08/02/1999 Pages TRM / 3.7-28 through TRM / 3.7-31 11/16/2001 Page TRM / 3.7-32 01/09/2004 Page TRM / 3.7-33 10/05/2002 Pages TRM / 3.7-34 through TRM / 3.7-36 02/01/1999 Pages 3.7-37 through 3.7-39 08/31/1998 Pages TRM / 3.7-40 and TRM / 3.7-40a 08/11/2000 Pages 3.7-41 and 3.7-42 08/31/1998 Page TRM /3.7-43 12/03/2004 Pages 3.7-44 through 3.7-47 10/13/1998 Page TRM I 3.7-48 03/08/2003 Pages TRM / 3.7-49 and TRM / 3.7-50 03/09/2001 Page TRM / 3.7-51 12/03/2004 Page TRM / 3.7-52 04/15/2003 07/29/1999 I

Page TRM 1 3.7-53 3.8 ELECTRICAL POWER Pages TRM / 3.8-1 and TRM / 3.8-2 04/02/2002 Page 3.8-3 08/31/1998 Page TRM /3.8-4 *12/31/2002 Pages TRM / 3.8-5 and TRM I 3.8-6 04/02/2002 Pages TRM / 3.8-7 through TRM / 3.8-10 12/03/2004 I Page TRM / 3.8-11 08/10/2004 SUSQUEHANNA - UNIT 2 'TRM / LOES-2 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 9 LISTOF,E FECTIVE SECTIONS (TECHNICAL REQUIREMENTS MANUAL)

Section Title Effective Date Page TRM /3.8-12 12/03/2004 Pages 3.8-13 and 3.8-14 08/31/1998 Pages TRM /3.8-15 through TRM /3.8-17 04/02/2002 Page 3.8-18 02/01/1999 Page TRM /3.8-19 04/02/2002 Page TRM / 3.8-20 02/01/1999 Pages TRM / 3.8-21 through TRM I 3.8-23 06/06/1999 Pages 3.8-24 and 3.8-25 08/31/1998 3.9 REFUELING OPERATIONS Pages 3.9-1 through 3.9-3 08/31/1998 3;10 MISCELLANEOUS Pages 3.10-1 through 3.10-4 08/30/1998 Page TRM I 3.10-5 03/08/2003 Page TRM / 3.10-6 06/05/2002 Page TRM / 3.10-7 04/07/2000 Corrected Page TRM I 3.10-8 04/17/2002 3.11 RADIOACTIVE EFFLUENTS Pages 3.11-1 through 3.11-9 08/31/1998 Page TRM /3.11-10 *12/03/2004 Pages 3.11-11 and 3.11-12 08/31/1998 Page 3.11-13 09/01/1998 Page TRM /3.11-14 12/03/1004 Pages 3.11-15 and 3.11-16 09/01/1998 Pages 3.11-17 and 3.11-18 '08/31/1998 Page TRM /3.11-19 01/21/2004 Pages 3.11-20 and 3.11-21 08/31/1998 Pages TRM /3.11-22 through TRM /3.11-24 04/02/2002 Page 3.11-25 09/01/1998 Pages TRM /3.11-26 through TRM /3.11-28 01/21/2004 Page TRM /3.11-29 12/03/2004 Pages TRM 3.11-30 through TRM /3.11-32 01/21/2004 Pages 3.11-33 through 3.11-37 08/31/1998 Page TRM / 3.11-38 12/03/2004 Pages 3.11-39 through 3.11-44 08/31/1998 Page TRM/3.11-45 12/0312004 Pages 3.1146 and 3.11-47 08/31/1998 3.12 LOADS CONTROL PROGRAM Pages TRM / 3.12-1 through TRM / 3.12-5 02/05/1999 4.0. ADMINISTRATIVE CONTROLS Pages 4.0-1 through 4.0-8 08/31/1998 SUSQUEHANNA - UNIT 2 TRM / LOES-3 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION - PPL Rev. 9 LIST OFj gFFECTIVESECTIONS (TECHNICAL REQUIREMENTS MANUAL)

Section Title Effective Date B 3.0 APPLICABILITY BASES Pages B 3.0-1 through B 3.0-10 08/31/1998 Pages TRM / B 3.0-11 through TRM / B 3.0-15 03/15/2002 B3.1 REACTIVITY CONTROL SYSTEMS BASES Pages TRM / B 3.1-1 through TRM / B 3.1-3 07/13/1999 Page B 3.1-4 08/31/1998 Pages TRM / B 3.1-5 through TRM / B 3.1-7 07/13/1999 PageTRM/B3.1-8 02/18/1999 B3.2 CORE OPERATING LIMITS BASES Page B 3.2-1 08/31/1998 B3.3 INSTRUMENTATION BASES.

Page TRM/B 3.3-1 04/07/2000 Page B 3.3-2 08/31/1998 Pages TRM / B 3.3-3 and TRM / B 3.3-3A 12/29/2000 Pages TRM / B 3.34 through TRM / B 3.3-6 03/21/2003 Pages TRM / B 3.3-7 through TRM / B 3.3-9 03/30/2001 Pages B 3.3-10 through B 3.3-12 08/31/1998 Page TRM / B 3.3-13 12/03/2004 I Page TRM / B 3.3-14 06/25/2002 Page TRM / B 3.3-14a 06/14/2002 Page TRM / B 3.3-14b 06/14/2002 Page TRM / B 3.3-15 10/22/2003 Page TRM / B 3.3-16 10/22/2003 Page TRM / B 3.3-17 10/22/2003 Pages TRM / B 3.3-18 and TRM I B 3.3-19 11/15/2004 Pages TRM / B 3.3-19a through TRM / B 3.3.19e 11/15/2004 Pages TRM / B 3.3-20 and TRM / B 3.3-21. 05/16/2003 Page TRM / B3.3-22 10/22/2003 Page TRM / B3.3-23 05/16/2003 B 3.4 REACTOR COOLANT SYSTEM BASES Pages B 3.4-1 through B 3.4-4 08/31/1998 Page TRM / B 3.4-5 10/15/1999 Page B 3.4-6 08/31/1998 B 3.5 ECCS AND RCIC BASES Pages B 3.5-1 through B 3.5-5 08/31/1998 B 3.6 CONTAINMENT BASES Page TRM / B 3.6-1 07/26/2001 Page TRM / B 3.6-2 02/01/1999 Page B 3.6-3 08/31/1998 Page TRM / B 3.6-4 09/23/1999 Page TRM / B 3.6-5 01/07/2002 Page TRM / B 3.6-6 12/03/2004 Pages TRM / B 3.6-7 through TRM / B 3.6-11 12/31/2002 I SUSQUEHANNA - UNIT 2 TRM / LOES-4 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPI - Rev. 9 UST OFEFFECTIVESECTIONS (TECHNICAL REQUIREMENTS MANUAL)

Section Title Effective Date B3.7 PLANT SYSTEMS BASES Pages B 3.7-1 and B 3.7-2 08/31/1998 Pages TRM / B 3.7-3 through TRM I B 3.7-7 08/02/1999 Page TRM / B 3.7-7a 08/02/1999 Pages TRM / B 3.7-8 through TRM / B 3.7-10 08/02/1999 Page TRM / B 3.7-1 Oa 08/02/1999 Pages TRM / B 3.7-11 through TRMI B 3.7-14 08/02/1999 Page TRM / B 3.7-14a and TRM / B 3.7-14b 01/09/2004 Pages TRM I B 3.7-15 and TRM / B 3.7-16 02/01/1999 Pages B 3.7-17 through B 3.7-20 08/31/1998 Pages TRM / B 3.7-21 through TRM/B 3.7-21a 05/11/2001 Pages TRM/B 3.7-22 and TRM/B 3.7-23 04/07/2000 Page B 3.7-24 08/31/1998 Page TRM / B 3.7-25 12/03/2004 Pages B 3.7-26 through B 3.7-30 08/31/1998 Page TRM / B 3.7-31' 12/03/2004 Page TRM / B 3.7-32 03/09/2001 Page TRM / B 3.7-33 04/15/2003 Page TRM/B3.7-34 12/03/2004 Page TRM / B 3.7-35 07/05/2000 i B 3.8 ELECTRICAL POWER BASES Pages TRM / B 3.8-1 and TRM / B 3.8-2 04/02/2002 Page TRM / B 3.8-2a 04/02/2002 Page TRM / B 3.8-3 04/02/2002 Page TRM / B 3.8-3a 04/02/2002 Page TRM / B 3.8-4 04/02/2002 Page TRM / B 3.8-4a 08/10/2004 Page TRM / B 3.8-5 08/31/1998 Pages TRM / B 3.8-6 through TRM B 3.8-17 04/02/2002 B.3.9 REFUELING OPERATIONS BASES Pages B 3.9-1 and B 3.9-2 08/31/1998 Pages B 3.9-3 through B 3.9-7 10/23/1998

. B 3.10 MISCELLANEOUS BASES Pages B 3.10-1 through B 3.10-2 08/31/1998 Page TRM / B 3.10-3 03/08/2003 Pages TRM / B 3.10-4 and TRM / B 3.10-5 08/23/1999 Pages TRM / B 3.10-6 and TRM / 3.10-7 04/17/2002 SUSQUEHANNA - UNIT 2 TRM / LOES-5 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 9 LIST OFgFFECTWE SECTIONS (TECHNICAL REQUIREMENTS MANUAL)

Section Title Effective Date B 3.11 RADIOACTIVE EFFLUENTS BASES Pages B 3.11-1 through B 3.11-9 08/31/1998 Pages TRMIB 3.11-10 02/01/1999 Pages TRMIB 3.11 -11 and TRM/B 3.11-1 a 04/07/2000 Pages TRM/B 3.11-12 and TRM/B 3.11-13 02/01/1999 Page TRM / B 3.11-14 12/03/2004  !

Page TRM / B 3.11-15 02/01/1999 Pages B 3.11-16 through B 3.11-19 08/31/1998 Page TRM / B 3.11-20 04/02/2002 Page TRM / B 3.11-20a 04/02/2002 PageTRM/B3.11-21 10/15/2004 Page TRM / B 3.11-22 10/1512004 Page TRM / B 3.11.23 04/02/2002 Page TRM / B 3.11-23a 04/02/2002 Pages TRM / B 3.11-24 and TRM /B 3.11-25 01/21/2004 Pages B 3.11-26 through B 3.11-28. 08/31/1998 Page TRM / B 3.11-29 and TRM / B 3.11-30 12/03/2004 Pages B 3.11-31 through B 3.11-35 08/31/1998 PageTRM/B3.11-36 02/12/1999 B.3.12 LOADS CONTROL PROGRAM BASES Pages TRM / B 3.12-1 through TRM / B 3.12-3 02/05/1999 TF tWeLOESdoc 1 1I24104 . .1 SUSQUEHANNA - UNIT 2 TRM / LOES-6 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 4 TABLE. Q.CONTENTS (TECHNICAL REQUIREMENTS MANUAL)

SECTION TITLE PAGE 1.0 USE AND APPLICATION...' 1.0-1 1.1 Definitions .............. . .TRM/1 .02 2.0 PLANT PROGRAMS ............. ; 2.0-1 2.1 Plant Programs......................................................................................02. 1 2.2 Instrument Trip Setpoint Table ............. ..................... TRM/2.0-5 3.0 APPLICABILITY .................................. TRM/3.0-1 3.0 (TRO) - TR for Operation (TRO) Applicability ............................... TRM/3.0-1 3.0 (TRS) - TR Surveillance (TRS) Applicability .................................. TRMW3.0-3 3.1 REACTIVITY CONTROL SYSTEMS ................................... 3.1-1 3.1.1 Alternate Rod Injection ................................... 3.1-1 3.1.2 CRD Housing Support .................................. 3.1-4 3.1.3 Control Rod Block Instrumentation ........................ 3.1-5 3.1.4 Control Rod Scram Accumulators Instrumentation and Check Valve ............ TRM/3.1-9 3.2 CORE OPERATING LIMITS REPORT .................................... 3.2-1 3.2.1 Core Operating Limits Report .................................... 3.2-1 3.3 INSTRUMENTATION . ................... TRM/3.3-1 3.3.1 Radiation Monitoring Instrumentation .................................... TRM/3.3-1 3.3.2 Seismic Monitoring Instrumentation .................................... TRM/3.3-4 3.3.3 Meteorological Monitoring Instrumentation .................................... 3.3-7 3.3.4 TRM Post-Accident Monitoring Instrumentation ............................ TRM/3.3-9 3.3.5 Section Not Used ............................... TRM/3.3-12 3.3.6 TRM Containment Isolation Instrumentation ............................... TRM/3.3-13 3.3.7 Turbine Overspeed Protection System ............................... TRM/3.3-17 3.3.8 Section Not Used ............................... TRMt3.3-19 3.3.9. OPRM Instrumentation ............................... TRM/3.3-21 3.3.10 Reactor Recirculation Pump MG Set Electrical and Mechanical Stops .TRM/3.3-22 3.3.11 MVP Isolation Instrumentation .TRM/3.3-24 3.4 REACTOR COOLANT SYSTEM. 3.4-1 3.4.1 Reactor Coolant System Chemistry .3.4-1 3.4.2 Structural Integrity .3.4-6 3.4.3 High/Low Pressure Interface Leakage Monitors .................................... 3.4-9 3.4.4 Reactor Recirculation Flow and Rod Line Limit .TRM /3.4-12 3.4.5 Reactor Vessel Material Surveillances Program .3.4-13 3.5. EMERGENCY CORE COOLING AND RCIC . 3.5-1 3.5.1 ADS Manual Inhibit .3.5-1 3.5.2 ECCS and RCIC System Monitoring Instrumentation ............................ 3.5-3 3.5.3 Long Term Nitrogen Supply to ADS .................................. 3.5-6 TRM /TOC-1 EFFECTIVE DATE 12/0312004 SUSQUEHANNA UNIT 22 SUSQUEHANNA - UNIT TRM / TOC-1 . EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 4 TABLE. FQ:CONTENTS (TECHNICAL REQUIREMENTS MANUAL)

SECTION TITLE PAGE 3.6 CONTAINMENT .................................................................... _.................... 3.-1 3.6.1 VENTING or PURGING ... 3.1 3.6.2 Suppression Chamber-to-Drywell Vacuum Breaker Position Indication ....... 3.6-3 3.6.3 Suppression Pool Alarm Instrumentation . ...... 3.6-4 3.6.4 Primary Containment Closed System Boundaries ... .... TRM/3.6-7 3.7 PLANT SYSTEMS............................................................................... TRM/3.7-1 3.7.1 Emergency Service Water System (Shutdown) ... .... TRM/3.7-1 3.7.2 Ultimate Heat Sink and Ground Water Level ....................... .......... 3.7-3 3.7.3.1 Fire Suppression Water Supply System .TRM/3.7-4 3.7.3.2 Spray and Sprinkler Systems .TRM/3.7-8 3.7.3.3 C02 systems .TRM/3.7-12 3.7.3.4 Halon Systems . TRM/3.7-16 3.7.3.5 Fire Hose Stations .TRM/3.7-18 3.7.3.6 Yard Fire Hydrants and Hydrant.Hose Houses .TRM/3.7-22 3.7.3.7 Fire Rated Assemblies .TRM/3.7-24 3.7.3.8 Fire Detection Instrumentation .TRM/3.7-26 3.7.4 Solid Radwaste System .TRM/3.7-35 3.7.5.1 Main Condenser Offgas Hydrogen Monitor .3.7-38 3.7.5.2 Main Condenser Explosive Gas Mixture .3.7-39 3.7.5.3 Liquid Holdup Tanks ................................. TRM/3.7-40 3.7.6 ESSW Pumphouse Ventilation .. 3.7-41 3.7.7 Main Condenser Offgas Pretreatment Logarithmic Radiation Monitoring Instrumentation .................. 3.7-42 3.7.8 Snubbers .................. 3.7-44 3.7.9 Control Structure HVAC ................ TRM/3.7-50 3.7.10 Spent Fuel Storage Pools (SFSPs) ........ TRM/3.7-51 3.8 ELECTRICAL POWER ...... TRM/3.8-1 3.8.1 Primary Containment Penetration Conductor Overcurrent Protective Devices .TRM/3.8-1 3.8.2.1 Motor Operated Valves Thermal Overload Protection -

Continuous .:...... TRM/3.8-5 3.8.2.2 Motor Operated Valves Thermal Overload Protection -

Automatic ....... TRM/3.8-1 3.8.3 Diesel Generator (DG) Maintanence Activities ....... 3.8-13 3.8.4 24VDC Electrical Power Subsystem.............................................TRMW3.8-15 3.8.5 Degraded Voltage Protection ....... TRM/3.8-21 3.8.6 Emergency Switchgear Room Cooling ....... 3.8-24 3.9 . REFUELING OPERATIONS ....... 3.9-1 3.9.1 Decay Time. ....... 3.9-1 3.9.2 Communications ............ 3.9-2 3.9.3 Refueling Platform ............ 3.9-3 SUSQUEHANNA - UNIT 2 TRM / TOC-2 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 4 TABLE QERCONTENTS (TECHNICAL REQUIREMENTS MANUAL)

SECTION TITLE PAGE 3.10 MISCELLANEOUS ......................................... 3.10-1 3.10.1 Sealed Source Contamination .3.10-1 3.10.2 MODE 5 Shutdown Margin Test RPS Instrumentation. 3.10-4 3.10.3 Independent Spent Fuel Storage Installation (ISFSI) .TRM/3.10-7 3.10.4 Leading Edge Flow Meter (LEFM) .TRMI3.10-8 3.11 'RADIOACTIVE EFFLUENTS ........................ 3.11-1 3.11.1 Liquid Effluents .3.11-1 3.11.1.1 Liquid Effluents Concentration .3.11-1 3.11.1.2 Liquid Effluents Dose. 3.11-4 3.11.1.3 Liquid Waste Treatment System .......................................3.11-6 3.11.1.4 Liquid Radwaste Effluent Monitoring Instrumentation ............................. 3.11-8 3.11.1.5 Radioactive Liquid Process Monitoring Instrumentation ........................ 3.11-13 3.11.2 Gaseous Effluents ....................................... 3.11-17 3.11.2.1 Dose Rate ....................................... 3.11-17 3.11.2.2 Dose- Noble Gases ....................................... 3.11-20 3.11.2.3 Dose - Iodine, Tritium, and Radionuclides in Pirticulate Form ........ 3.11-21 3.11.2.4 Gaseous Radwaste Treatment System ........ TRM/3.11-22 3.11.2.5 Ventilation Exhaust Treatment System ........ TRM/3.11-23 3.11.2.6 Radioactive Gaseous Effluent Monitoring Instrumentation........ .3.11-26 3.11.3 Total Dose .......  : 3.11-33 3.11.4 Radiological Environmental Monitoring ...... 3.11-35 3.11.4.1 Monitoring Program ...... 3.11-35 3.11.4.2 Land Use Census ...... TRM13.11-45 3.11.4.3 Interlaboratory Comparison Program ...... 3.11-47 3.12 LOADS CONTROL PROGRAM ..................... TRM/3.12-1 3.12.1 Crane Travel - Spent Fuel Storage Pool.TRM/3.12-1

-3.12.2 Heavy Loads Requirements .TRM/3.12.3 3.12.3 Light Loads Requirements .TRM/3.12-5 4.0 4.1O ADMINISTRATIVE g nz to CONTROLS.4.0-1

.......................................................................................... 4.D 4.1 Organization.4.0-1 4.2 Reportable Event Action .4.0-2 4.3 Safety Limit Violation. 4.0-3 4.4 Procedures and Programs . 4.0-4 4.5 Reporting Requirements........................................................................4.-5 4.6 Radiation Protection Program................................................................4.0-7 4.7 Training....................4.............................................................. .............. 4.-8 SUSQUEHANNA - UNIT 2 TRM / TOCG3 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 4 TABLE.Q.QCONTENTS (TECHNICAL REQUIREMENTS MANUAL)

SECTION TITLE PAGE B 3.0 (TRO) - TR for Operation (TRO) Applicability .B 3.0-1 B 3.0 (TRS) - TR Surveillance (TRS) Applicability .................... .......... B 3.0-9 B 3.1.1 Alternate Rod Injection .............................. TRM/B 3.1-1 B 3.1.2 CRD Housing Support. .............................. B 3.1-4 B 3.1.3 Control Rod Block Instrumentation .............................. TRM/B 3.1-5 B 3.1.4 Control Rod Scram Accumulators Instrumentation and Check Valve .......................... TRM/B 3.1-8 B 3.2.1 Core Operating Limits Report (COLR) .......................... B 3.2-1 B 3.3.1 Radiation Monitoring Instrumentation .......................... TRM/B 3.3-1 B 3.3.2 Seismic Monitoring Instrumentation .......................... B 3.3-2 B 3.3.3 Meteorological Monitoring Instrumentation ................................. TRM/B 3.3-3 B 3.3.4 TRM Post-Accident Monitoring Instrumentation ........................... TRM/B 3.3-4 B 3.3.5 Section Not Used ................................. TRM/B 3.3-7 B 3.3.6 TRM Containment Isolation Instrumentation ................................. B 3.3-10 B 3.3.7 Turbine Overspeed Protection System ................................. TRM/B 3.3-14 B 3.3.8 Section Not Used ................................. TRM/B 3.3-15 B 3.3.9 OPRM Instrumentation . TRM/B 3.3-18 B 3.3.10 Reactor Recirculation Pump MG Set Electrical and Mechanical Stops ........................ TRM/B 3.3-20 B 3.3.11 MVP Isolation Instrumentation ........................ TRMJB 3.3-22 B 3.4.1 Reactor Coolant System Chemistry ........................ B 3.4-1 B3.4.2 Structural Integrity ............  ; B 3.4-2 B 3.4.3 High/Low Pressure Interface Leakage Monitors .................................... B 3.4-4 B 3.4.4 Reactor Recirculation Flow and Rod Line Limit ............................. TRM/B 3.4-5 B 3.4.5 Reactor Vessel Material Surveillances Program ................................... B 3.4-6 B 3.5.1 ADS Manual Inhibit ...................................... B 3.5-1 B 3.5.2 ECCS and RCIC System Monitoring Instrumentation .......................... B 3.5-3 B 3.5.3 Long Term Nitrogen Supply to ADS .................... .................. B 3.5-4 B 3.6.1 VENTING or PURGING ..................................... TRM/B 3.6-1 B3.6.2 Suppression Chamber-to-Drywell. Vacuum Breaker Position Indication ................................... B 3.6-3 B 3.6.3 Suppression Pool Alarm Instrumentation ................................... B 3.6-4 B 3.6.4 Primary Containment Closed System Boundaries ........................ TRM/B 3.6-6 B 3.7.1 Emergency Service Water System (Shutdown) .B 3.7-1 B 3.7.2 Ultimate Heat Sink and Ground Water Level .B 3.7-2 B 3.7.3.1 Fire Suppression Water Supply System .TRM/B 3.7-3 B 3.7.3.2 Spray and Sprinkler Systems .TRMB 3.7-5 B 3.7.3.3 C02 systems .TRM/B 3.7-7 B 3.7.3.4 Halon Systems . TRM/B 3.7-8 TRMITOC-4 EFFECTIVE DATE 12/03/2004 SUSQUEHANNA SUSQUEHANNA -UNIT

- UNIT 22 TRM / TOC 4 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 4 TABLE OI£ CONTENTS (TECHNICAL REQUIREMENTS MANUAL)

SECTION TITLE PAGE B 3.7.3.5 Fire Hose Stations ................................ TRM/B 3.7-10 B 3.7.3.6 Yard Fire Hydrants and Hydrant Hose Houses ............... =.......... TRM/B 3.7-11 B 3.7.3.7 Fire Rated Assemblies ................................ TRM/B 3.7-12 B 3.7.3.8 Fire Detection Instrumentation ................................ TRM/B 3.7-14 B 3.7.4 Solid Radwaste System ................................ TRM/B 3.7-15 B 3.7.5.1 Main Condenser Offgas Hydrogen Monitor ................................. B 3.7-17 B 3.7.5.2 Main Condenser Explosive Gas Mixture ............... .................. B 3.7-19 B 3.7.5.3 Liquid Holdup Tanks ................................. B 3.7-20 B 3.7.6 ESSW Pumphouse Ventilation ................................. TRM/B 3.7-21 B 3.7.7 Main Condenser Offgas Pretreatment Logarithmic Radiation Monitoring Instrumentation ................................ TRM/B 3.7-22 B 3.7.8 Snubbers ................................ B 3.7-24 B 3.7.9 Control Structure HVAC ................................ TRM/B 3.7-31 B 3.7.10 Spent Fuel Storage Pools ................................ TRM/B 3.7-33 B 3.8.1 Primary Containment Penetration Conductor Overcurrent Protective Devices ........... TRM/B 3.8-1 B 3.8.2.1 Motor Operated Valves Thermal Overload Protection -

Continuous .......  ; TRM/B 3.8-3 B 3.8.2.2 Motor Operated Valves Thermal Overload Protection -

Automatic .TRM/B 3.E4 B 3.8.3 Diesel Generator (DG) Maintanence Activities .TRMB 3.8-5 B 3.8.4 24VDC Electrical Power Subsystem .TRM/B 3.8-6 B 3.8.5 Degraded Voltage Protection .TRM/ 3.8-16 B 3.8.6 Emergency Switchgear Room Cooling .TRM/B 3.8-17 B.3.9.1 Decay Time ...........  ; B 3.9-1 B 3.9.2 Communications. ................:B 3.9-2 B 3.9.3 Refueling Platform .B 3.9-3 B 3.10.1 Sealed Source Contamination ................................... B 3.10-1 B 3.10.2 MODE 5 Shutdown Margin Test RPS Instrumentation ........................ B 3.10-2 B 3.10.3 Independent Spent Fuel Storage Installation (ISFSI) ................... TRM/B 3.10-4 B 3.10.4 Leading Edge Flow Meter (LEFM) ................................... TRM/B 3.10-6 B 3.11.1.1 Liquid Effluents Concentration ................................... B 3.11-1 B 3.11.1.2 Liquid Effluents Dose ................................... B 3.11-4 B 3.11.1.3 Liquid Waste Treatment System ........ ........................... B 3.11-6 B3.11.1.4 Liquid Radwaste Effluent Monitoring Instrumentation .......................... B 3.11-7 B 3.11.1.5 Radioactive Liquid Process Monitoring Instrumentation .TRM/B 3.11-10 B 3.11.2.1 Dose Rate.TRM/B 3.11-12 B 3.11.2.2 Dose - Noble Gases ............... ...... B 3.11-16 B 3.11.2.3 Dose - Iodine, Tritium, and Radionuclides in Particulate Form ..... B 3.11-18 B 3.11.2.4 Gaseous Radwaste Treatment System ./TRB 3.11-20 B 3.11.2.5 Ventilation Exhaust Treatment System .TRM/B 3.11-21 SUSQUEHANNA - UNIT 2 TRM / TOC-5 EFFECTIVE DATE 12/03/2004

SUSQUEHANNA STEAM ELECTRIC STATION PPL Rev. 4 TABLE. QFCONTENTS (TECHNICAL REQUIREMENTS MANUAL)

SECTION TITLE PAGE B 3.11.2.6 Radioactive Gaseous Effluent Monitoring Instrumentation ............................

_ TRM/B 3.11-24 B 3.11.3 Total Dose ........................................ B 3.11-26 B 3.11.4.1 Monitoring Program ......... B 3.11-28 B 3.11.4.2 Land Use Census ......... B 3.11-34 B 3.11.4.3 Interlaboratory Comparison Program ......... TRM/B 3.11-36 B 3.12 LOADS CONTROL PROGRAM ......... TRM/B 3.12-1 B.3.12.1 Crane Travel - Spent Fuel Storage Pool ........... TRM/B 3.12-1 B.3.12.2 Heavy Loads Requirements ........... TRMIB 3.12-2 B.3.12.3 Light Loads Requirements ..............................  ; .......... TRM/B 3.12-3 TRM2 Ted TOC .

11/23/04

'SUSQUEHANNA - UNIT 2 TRM I TOCG6 EFFECTIVE DATE 12/03/2004

Instrument Trip Setpoint Program PPL Rev. 3. 2.2 2.0 PLANT PROGRAMS AND SETPOINTS 2.2 Instrument Trip Setpoint Table The Instrument Trip Setpoint Limits in Table 2.2-1 are the Trip Setpoint value limits that were contained in the Instrumentation Setpoint tables for protection systems and other functions important to safety that were included in the scope of the original Standard Technical Specifications. Actual instrument setpoints are established utilizing the Allowable Values specified in the Technical Specifications and Technical Requirements. Allowable Values are established in the Reference LCOs and TROs identified in this Table. TRO references are enclosed in square brackets.

Instrumentation process setpoints for the listed subsystems and trip functions are set consistent with the Trip Setpoint Limit Column of Table 2.2-1. Actual setpoints are established in accordance with engineering procedures.

Alarm setpoints and other non-protection system trip settings as may be found in the Technical Specifications or in the Technical Requirements are not included in this table.

Reference NDAP-QA-1 104 Setpoint Change Control SUSQUEHANNA - UNIT 2 TRM / 2.0-5 EFFECTIVE DATE 04/02/1999

Instrument Trip Setpoint Program PPL Rev. 3._

. ._ . 4. ._

• 2.2 TABLE 2.2-1 (Page 1 of 8)

INSTRUMENTATION SETPOINTS SYSTEM/REFERENCE LCOS[TRO] TRIP FUNCTION TRIP SETPOINT 2.2.1 Reactor Protection 2.2.1.1 3.3.1.1 Intermediate Range Monitor, Neutron Flux - . *120/125 divisions of full High scale 2.2.1.2 3.3.1.1 Average Power Range Monitor, Neutron Flux

• 15% of RATED THERMAL POWER

- High Setdown 2.2.1.3 3.3.1.1 Average Power Range Monitor, Flow Biased See COLR - TRO 3.2 Simulated Thermal Power- High Two Loop Operation 2.2.1.4 3.3.1.1 Average Power Range Monitor, Flow Biased See COLR - TRO 3.2 Simulated Thermal Power - High Single Loop Operation 2.2.1.5 3.3.1.1 Average Power Range Monitor, Flow Biased

• 113.5% of RATED THERMAL Simulated Thermal Power - High Flow POWER Clamped 2.2.1.6 3.3.1.1 Average Power Range Monitor, Fixed Neutron

• 118% of RATED THERMAL POWER Flux - High 2.2.1.7 3.3.1.1 Reactor Vessel Steam Dome Pressure - High

• 1087 psig 2.2.1.8 3.3.1.1 Reactor Vessel Water Level - Low, Level 3 2 13.0 inches (

2.2.1.9 3.3.1.1 Main Steam Isolation Valve - Closure

• 10% closed 2.2.1.10 This Section Not Used 2.2.1.11 3.3.1.1 Drywell Pressure - High

• 1.72 psig 2.2.1.12 3.3.1.1 Scram Discharge Volume Water Level - High

• 65 gallons

- Level Transmitter 2.2.1.13 3.3.1.1 Scram Discharge Volume Water Level - High . - 61 gallons

- Float Switch 2.2.1.14 3.3.1.1 Turbine Stop Valve - Closure . *5.5% closed 2.2.1.15 3.3.1.1 -Turbine Control Valve Fast Closure, Trip 2 500 psig Oil Pressure - Low (continued)

(a) See Figure 2.2-1 SUSQUEHANNA - UNIT 2 TRM / 2.0-6 EFFECTIVE DATE 11/15/2004

Instrument Trip Setooint Program PPL Re_ 3.,. .I2.2 .

TABLE 2.2-1 (Page 2 of 8) I INSTRUMENTATION SETPOINTS SYSTEM/REFERENCE LCO [TRO] TRIP FUNCTION - TRIP SETPOINT 2.2.1.16 OPRM Instrumentation 2.2.1.16.1 3.3.1.3 Sp Cell Signal Amplitude See COLR -TRO 3.2 2.2.1.16.2 3.3.1.3 N2 Confirmation Count Permissive See COLR - TRO 3.2 2.2.1.16.3 [3.3.9] TOL Period Confirmation Tolerance 0.10 sec 2.2.1.16.4 [3.3.9] Ta Averaging Filter 5 sec 2.2.1.16.5 [3.3.9] Fc Conditioning Filter Cutoff Frequency 1.5 Hz 2.2.1.16.6 [3.3.9] Tmin Minimum Oscillation Period 1.0 sec 2.2.1.16.7 [3.3.9] Tmax Maximum Oscillation Period 3.5 sec 2.2.1.16.8 [3.3.9] Noise Floor Peak Discrimination Threshold 1 2.2.1.16.9 [3.3.9] Minimum LPRM/Cell Cell Operability 2 Requirement 2.2.1.16.10 [3.3.9] Si Peak Threshold Setpoint -1.20 2.2.1.16.11 13.3.9] S2 Valley Threshold Setpoint 0.85 2.2.1.16.12 [3.3.9] Smax Max. Amplitude Trip Setpoint 1.50 2.2.1.16.13 [3.3.9] DR3 Growth Rate Factor Setpoint 1.60 2.2.1.16.14 13.3.9] TI -o S1 to S2 Timer Range 0.5 sec 2.2.1.16.15 [3.3.9] T1 hi SI to S2 Timer Range 1.75 sec 2.2.1.16.16 [3.3.9] T2 lo S2 to(S3 or Smax) Timer Range 0.5 sec 2.2.1.16.17 [3.3.9] T2 hi S2 to(S3 or Smax) Timer Range 1.75 sec 2.2.2 Isolation Actuation Instrumentation 2.2.2.1 Primary Containment Isolation 2.2.2.1.1 3.3.6.1 Reactor Vessel Water Level Low, Level 3 213.0 inchesf')

2.2.2.1.2 3.3.6.1 Reactor Vessel Water Level Low Low, Level 2 . 2 -38.0 inches(a) 2.2.2.1.3 3.3.6.1 Reactor Vessel Water Level Low Low Low, 2 -129 inches(a)

Level I 2.2.2.1.4 3.3.6.1 Drywell Pressure - High s 1.72 psig 2.2.2.1.5 3.3.6.143.3.6] SGTS Exhaust Radiation - High s 23.0 mR/hr 2.2.2.1.6 [3.3.6] Main Steam Line Radiation - High High s 15 x full power background without hydrogen injection (continued)

SUSQUEHANNA - UNIT 2 TRM / 2.0-7 EFFECTIVE DATE 11/15/2004

Instrument Trip Setpoint Program PPL Rev. 3. 2.2 TABLE 2.2-1 (Page 3 of 8)

INSTRUMENTATION SETPOINTS SYSTEM/REFERENCE LCO

[TRO] , TRIP FUNCTION TRIP SETPOINT 2.2.2.2 Secondary Containment Isolation 2.2.2.2.1 *3.3.6.2 Reactor Vessel Water Level - Low Low, - -38.0 inches(a)

Level 2 2.2.2.22 3.3.6.2 Drywell Pressure - High s 1.72 psig 2.2.2.2.3 3.3.6.2 Refuel Floor High Exhaust Duct Radiation -

• 18 mR/hr High 2.2.2.2.4 3.3.6.2 Railroad Access Shaft Exhaust Duct s 5 mR/hr Radiation - High 2.2.2.25 3.3.6.2 Refuel Floor Wall Exhaust Duct Radiation - s 21 mR/hr High 2.2.2.3 Main Steam Line Isolation 2.2.2.3.1 3.3.6.1 Reactor Vessel Water Level - Low Low Low, 2-129 inches(')

Level 1 2.2.2.3.2 3.3.6.1 Main Steam Line Pressure - Low 2 861 psig 2.2.2.3.3 3.3.6.1 Main Steam Line Flow- High S 113 psid 2.2.2.3.4 3.3.6.1 Condenser Vacuum - Low Ž 9.0 inches Hg vacuum 2.2.2.3.5 3.3.6.1 Reactor Building Main Steam Une Tunnel s 1770F Temperature - High 2.2.2.3.6 This Section Not Used 2.2.2.3.7 [3.3.61 Reactor Building Main Steam Une Tunnel S 990F' A Temperature - High 2.2.2.3.8 [3.3.6] Turbine Building Main Steam Tunnel s 197'F Temperature - High 2.2.2.4 Reactor Water Cleanup System Isolation 2.2.2.4.1 3.3.6.1 Reactor Vessel Water Level - Low Low, Z-38 inches(')

Level 2 2.2.2.4.2 3.3.6.1 RWCU A Flow - High s59gpm 2.2.2.4.3 3.3.6.1 RWCU Flow - High s 462 gpm 2.2.2.4.4 3.3.6.1 RWCU Penetration Area Temperature - High S 131OF 2.2.2.4.5 [3.3.6] RWCU Penetration Room Area A Temperature S 69 0F

- High 2.2.2.4.6 3.3.6.1 RWCU Pump Area Temperature - High s 147 0F 2.2.2,4.7 [3.3.6] RWCU Pump Room Area A Temperature - S 69 8F High 2.2.2.4.8 3.3.6.1 RWCU Heat Exchanger Area Temperature -

• 147 0F High 2.2.2.4.9 [3.3.6] RWCU Heat Exchanger Room Area

• 69°F A Temperature - High (continued)

(a)See Figure 2.2-1 SUSQUEHANNA - UNIT 2 TRM / 2.0-8 EFFECTIVE DATE 12103/2004

Instrument Trip Setooint Program PPL Rev. 3.. 2.2 TABLE 2.2-1 (Page 4 of 8) I IMQTPI Kie TlMFMTATIOlK

.lxlvu -r Iv

.cs=TPr)1IMT5 v_ .r- -E SYSTEM/REFERENCE LCO

[TRO] TRIP FUNCTION TRIP SETPOINT 2.2.2.5 Reactor Core Isolation Cooling System Isolation 2.2.2.5.1 3.3.6.1 RCIC Steam Une A Pressure - High S 188 inches H20 2.2.2.5.2 3.3.6.1 RCIC Steam Supply Line Pressure - Low 2 60 psig 2.2.2.5.3 3.3.6.1 RCIC Turbine Exhaust Diaphragm Pressure s 10.0 psig

- High 2.2.2.5.4 3.3.6.1 RCIC Equipment Room Temperature - High s 167¶F 2.2.2.5.5 3.3.6.1 RCIC Pipe Routing Area Temperature - High s 167 0F 2.2.2.5.6 3.3.6.1 RCIC Emergency Area Cooler Temperature - S 1670 F High 2.2.2.5.7 3.3.6.1 Drywell Pressure - High s 1.72 psig -

2.2.2.5.8 [3.3.6] RCIC Equipment Room ATemperature - High s 894F 2.2.2.5.9 [3.3.6] RCIC Pipe Routing Area A Temperature - S 89 0F High 2.2.2.6 High Pressure Coolant Injection System Isolation 2.2.2.6.1 3.3.6.1 HPCI Steam Une A Pressure - High s 370 inches H20 2.2.2.6.2 3.3.6.1 HPCI Steam Supply Une Pressure - Low 2 104 psig 2.2.2.6.3 3.3.6.1 HPCI Turbine Exhaust Diaphragm Pressure - S 10 psig High

-,/ 2.2.2.6.4 3.3.6.1 HPCI Equipment Room Temperature - High s 167°F

• 2.2.2.6.5 *3.3.6.1 HPCI Emergency Area Cooler Temperature - s 167°F High 2.2.2.6.6 3.3.6.1 HPCI Pipe Routing Area Temperature - High s 1679F 2.22.6.7 3.3.6.1 Drywell Pressure - High s 1.72 psig 2.2.2.6.8 [3.3.6] HPCI Equipment Room A Temperature - High s 890F 2.2.2.6.9 [3.3.6] - HPCI Pipe Routing Area A Temperature - . 89°F High 2.2.2.7 Shutdown Cooling/System Isolation 2.2.2.7.1 3.3.6.1 Reactor Vessel Water Level - Low, Level 3 2 13.0 Inches(')

2.2.2.7.2 3.3.6.1 Reactor Vessel Steam Dome Pressure - High is 98 psig 2.2.2.7.3 [3.3.6] RHR Flow- High s 25,000 gpm 2.2.3 ECCS Actuation 2.2.3.1 Core Spray System 2.2.3.1.1 3.3.5.1 Reactor Vessel Water Level - Low Low Low, 2 -129 inches")

Level I 2.2.3.1.2 3.3.5.1 Drywell Pressure - High < 1.72 psig 2.2.3.1.3 3.3.5.1 Reactor Vessel Steam Dome Pressure - Low 2 413, S 427 psig injection permissive (continued)

(a)See Figure 2.2-1 SUSQUEHIANNA - UNIT 2 TRM I 2.0-9 EFFECTIVE DATE 11/1512004

Instrument Trip Setooint Program PPL Rev. 3. 2.2 TABLE 2.2-1 (Page 5 of 8) 1.

INSTRUMENTATION SETPOINTS SYSTEM/REFERENCE LCO

[TRO] TRIP FUNCTION TRIP SETPOINT 2.2.3.2 LPCI Mode of RHR System 2.2.3.2.1 3.3.5.1 Reactor Vessel Water Level - Low Low Low, 2 -129 inchest Level I 2.2.3.2.2 3.3.5.1 Drywell Pressure - High s 1.72 psig 2.2.3.2.3 3.3.5.1 Reactor Vessel Steam Dome Pressure - Low, 2 413, *427 psig injection permissive 2.2.3.2.4 3.3.5.1 Reactor Vessel Steam Dome Pressure - Low, 2Ž236 psig, decreasing Recirculation Discharge Valve permissive 2.2.3.3 HPCI System 2.2.3.3.1 3.3:5.1 Reactor Vessel Water Level - Low Low, 2 -38 Inches(a)

Level 2 2.2.3.3.2 3.3.5.1 Drywell Pressure - High

• 1.72 psig 2.2.3.3.3 3.3.5.1 Condensate Storage Tank Level - Low 'Z236.0 inches above tank bottom 2.2.3.3.4 3.3.5.1 Reactor Vessel Water Level - High, Level 8

• 54 Inches 2.2.3.4 Automatic Depressurization System (ADS)'

2.2.3.4.1 3.3.5.1 . Reactor Vessel Water Level - Low Low Low, - -129 inches Level I 2.2.3.4.2 3.3.5.1 Drywell Pressure - High . 1.72 psig 2.2.3.4.3 3.3.5.1 ADS Timer ' 102 seconds 2.2.3.4.4 3.3.5.1 Core Spray Pump Discharge Pressure - High . Ž 135, *155 psig 2.2.3.4.5 3.3.5.1 . Low Pressure Coolant Injection Pump - 121,

• 129 psig Discharge Pressure - High' 2.2.3.4.6 3.3.5.1 Reactor Vessel Water Level - Low, Level 3 ' 13 inches Confirmatory 2.2.3.4.7 3.3.5.1 ADS Drywell Pressure Bypass Timer . *420 seconds 2.2.3.5 Loss of Power - ECCS Actuation 2.2.3.5.1 4.16kv ESS Bus Undervoltage (Loss of Voltage < 20%)

2.2.3.5.1.1 3.3.8.1 Bus Undervoltage a 823.2, *856.8 Volts 2.2.3.5.1.2 3.3.8.1 Time delay '0.4,

• 0.6 seconds (continued)

') See Figure 22-1 SUSQUEHANNA - UNIT 2 ITRM / 2.0-10 EFFECTIVE DATE 11/15/2004

Instrument Trip Setpoint Program PPL Rev.I-3. -. .._ 2.2 TABLE 2.2-1 (Page 6 of 8)

INSTRUMENTATION SETPOINTS.

SYSTEMIREFERENCE LCO

[TRO] TRIP FUNCTION TRIP SETPOINT 2.2.3.5.2 4.16kV ESS Bus Undervoltage (Degraded Voltage < 65%)

2.2.3.5.2.1 3.3.8.1 Bus Undervoltage Ž2641.1,

• 2748.9 Volts 2.2.3.5.2.2 3.3.8.1 Time delay 2 2.7, s 3.3 seconds 2.2.3.5.3 4.16kV ESS Bus Undervoltage (Degraded Voltage, < 93%)

2.2.3.5.3.1 3.3.8.1 Bus Undervoltage 2Ž3829.3,

• 3906.7 Volts 2.2.3.5.3.2 3.3.8.1 Time Delay (Non-LOCA) 2 4 minute, 30 seconds

• 5 minute, 30 seconds 2.2.3.5.3.4 3.3.8.1 Time Delay (LOCA) 2Ž9,

• 11 seconds 2.2.3.5.4 480V ESS Bus OB565 Undervoltage (Degraded Voltage, < 65%)

2.2.3.5.4.1 [3.8.5] 480V Basis 2Ž308.9,

• 315.1 Volts 2.2.3.5.4.2 [3.8.5] Time Delay 24.5, s 5.5 seconds 2.2.3.5.5 480V ESS Bus OB565 Undervoltage (Degraded Voltage, < 92%)

2.2.3.5.5.1 [3.8.5] 480V Basis 2 437.6, *446.4 Volts 2.2.3.5.5.2 [3.8.5] Time Delay 2 9,* 11 seconds 2.2.4 ATWS Altemate Rod Injection and Recirculation Pump Trip 2.2.4.1 3.3.4.2/[3.1.1] Reactor Vessel, Water Level - Low Low, 2-38 inchesca)

Level 2 2.2.4.1 3.3.4.21[3.1.1] Reactor Vessel Steam Dome Pressure - High 51135 psig 2.2.5 End of Cycle Recirculation Pump Trip 2.2.5.1 3.3.4.1 Turbine Stop Valve-Closure

• 5.5% closed 2.2.5.2 3.3.4.1 Turbine Control Valve - Fast Closure Ž500 psig 2.2.6 Reactor Core Isolation Cooling System Actuation 2.2.6.1 3.3.5.2 Reactor Vessel Water Level - Low Low, 2-38 inches(')

Level 2 2.2.6.2 3.3.5.2 Reactor Vessel Water Level - High, Level .. 54 inches(')

8 2.2.6.3 3.3.5.2 Condensate Storage Tank Level - Low Ž36.0 inches above tank bottom

- (continued)

(a)See Figure 2.2-1 SUSQUEHANNA - UNIT 2 TRM 12.0-111 EFFECTIVE DATE 11/15/2004

Instrument Trip Setpoint Program PPL Rev.

3_

An_

2.2 TABLE 2.2-1 (Page 7 of 8) I INSTRUMENTATION SETPOINTS SYSTEMIREFERENCE LCO

[TRO] TRIP FUNCTION TRIP SETPOINT 2.2.7 Control Rod Block 2.2.7.1 Rod Block Monitor

• 2.2.7.1.1 3.3.2 Low Power Range Upscale - Two Loop S 0.58W + 52%

Operation 2.2.7.1.2 3.3.2 Low Power Range Upscale - Single Loop s0.58W +47%

Operation 2.2.7.1.3 Downscale 5%

2.2.7.2 APRM 2.2.7.2.1 [3.1.3] Flow Biased Simulated Thermal Power-High See COLR - TRO 3.2

- Two Loop Operation 2.2.7.2.2 [3.1.3] Flow Biased Simulated Thermnal Power High See COLR - TRO 3.2

- Single Loop Operation 2.2.7.2.3 [3.1.3] Flow Biased Simulated Thermal Power High < 108% of RATED THERMAL POWER

- High Flow Clamped 2.2.7.2.4 [3.1.3] Downscale 2 5% of RATED THERMAL POWER 2.2.7.2.5 [3.1.3] Neutron Flux - High Setdown s 12% of RATED THERMAL POWER 2.2.7.3 Source Range Monitors 2.2.7.3.1 [3.1.3]

Upscale s 2E5 cps 2.2.7.3.2 * [3.1.3] Downscale 2 0.7 cps°b 2.2.7.4 Intermediate Range Monitors 2.2.7.4.1 [3.1.3] Upscale s 1081125 divisions of full scale 2.2.7.4.2 13.1.3] Downscale 2 5/125 divisions of full scale 2.2.7.5 Scram Discharge Volume 2.2.7.5.1 [3.1.3] Water Level - High s 35.9 gallons 2.2.7.6 Reactor Coolant System Recirculation Flow 2.2.7.6.1 [3.1.3] Upscale 114%

2.2.7.6.2 [3.1.3] Comparator s 10% flow deviation (continued)

° Provided signal-to-noise ratio is 2 2. Otherwise, 2 3 cps.

SUSQUEHANNA - UNIT 2 TRM / 2.0-12 EFFECTIVE DATE 11/15/2004

Instrument Trip Setpoint Program PPL Rev. 3. 2.2 TABLE 2.2-1 (Page 8 of 8)

INSTRUMENTATION SETPOINTS SYSTEM/REFERENCE LCO

[TRO] TRIP FUNCTION TRIP SETPOINT 2.2.8 CREOASS 2.2.8.1 3.3.7.1 Main Control Room Outside Air Intake

• 5 mR/hr Radiation Monitor 2.2.8.1.1 3.3.7.1 Reactor Vessel Water Level - Low Low, 2 -38.0 Inches(a)

Level 2 2.2.8.1.2 3.3.7.1 Drywell Pressure - High

• 1.72 psig 2.2.8.1.3 3.3.7.1 Refuel Floor High Exhaust Duct Radiation

• 18 mR/hr

- High 2.2.8.1.4 3.3.7.1 Railroad Access Shaft Exhaust Duct *5 mR/hr Radiation - High 2.2.8.1.5 3.3.7.1 Refuel Floor Wall Exhaust Duct Radiation

• 21 mR/hr

-High 2.2.9 Feedwater/Main Turbine Trip System Actuation 2.2.9.1 3.3.2.2 Reactor Vessel Level - High - 54.0 inches(a) 2.2.10 MVP Isolation 2.2.10.1 [3.3.11] Main Steam Line Radiation- High High

• 15xfull power background without hydrogen injection (a)See Figure 2.2-1 SUSQUEHANNA - UNIT 2 TRM / 2.0-13 EFFECTIVE DATE 11/15/2004

Instrument Trip Setpoint Table PPL Rev. 3. 2.2

. .~* . . _ . .*

WATER L NOVELLTUR 800 o. .VESSEL ZERO READING So ( IN.

0-e2-t)

)

5

. \ \'A 8>

53-

{-' ()

(7).

581-.5 566.-

'+39

() . 557.5, +30

.  : .:

• 58i.5 (-8) ' +60

., -+60-~+60 &

. s -66 ~: TRRTTEAM FEED 48.5 .

589452) 6CLOSENGEIJ

.SPRY .(2) iNITIRTE RCIC. TO RDS 450~ >. Rs:: ^TRIPi REIRC PUPS 400 250- -385(1  ; 1,^ '9.. --129 3 .3N -0NITRITE TO RS

' ~_S -i . 3)

S>20

.. , _ ,I**  : * !y S 0I _  :

RYEReCITO VESL5 .: Z~EROLVE~

\ STEAK .SNOTE: SCRLE IN INCIES

~FIGURE 2.2-1.

m CFDEED F492... 9..... i..S. . ,

SUSQUEHANNA - UNIT 2 TRM / 2.0-14 EFFECTIVE DATE 11!15/2004

Reactor Recirculation Pump MG Set Stops PPL....

Rey. 1 3.3.10 3.3 Instrumentation 3.3.10 Reactor Recirculation Pump MG Set Stops TRO 3.3.10 Each Reactor Recirculation pump MG set scoop tube electrical and mechanical stop shall be OPERABLE with overspeed setpoints corresponding to a core flow of:

Electrical Stop:

• 109.5 million Ibm/hr, and I Mechanical Stop:

• 110.5 million Ibm/hr APPLICABILITY: MODES 1 and 2 ACTIONS i_-- ___-

l M v Kin g

c T

Separate Condition entry allowed for each recirculation pump MG set.

CONDITION REQUIRED ACTION COMPLETION TIME A. One electrical or . A.1 Restore the inoperable stop(s) Next scheduled mechanical stop for either to OPERABLE status. performance of or both reactor recirculation . TRS 3.3.10.1 pump MG set scoop tube(s) inoperable.

B. Both electrical and ---- NOTE-mechanical stops for either Scoop tube may be unlocked Reactor Recirculation pump intermittently under administrative MG set scoop tube control.

inoperable.

B.1 Initiate actions to lock the scoop Immediately tube on the affected Reactor Recirculation MG Set in place.

SUSQUEHANNA - UNIT 2 - TRM / 3.3-22 EFFECTIVE DATE 12103/2004

Reactor Recirculation Pump MG Set Stops PPL Rey. 1 - 3.3.10 TECHNICAL REQUIREMENT SURVEILLANCE SURVEILLANCE FREQUENCY TRS 3.3.10.1 Demonstrate each Reactor Recirculation pump MG 24 months set scoop tube electrical and mechanical stop to be OPERABLE.

.SUSQUEHANNA - UNIT 2 .TRM / 3.3-23 EFFECTIVE DATE 05/16/2003

Reactor Recirculation Flow and Rod Line Limit PPL Rey. 1 3.4.4 3.4 Reactor Coolant System (RCS) 3.4.4 Reactor Recirculation Flow and Rod Line Limit TRO 3.4.4 Operating loop flow rate shall be

• 50% of ratedloop flow rate and the reactor shall be operating at a THERMAL POWER/core flow condition below the 80% rod line shown in the Power Flow map specified in the COLR. I APPLICABILITY: MODES 1,2, 3, and 4 during recirculation pump start.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the TRO A.1 Restore parameter(s) to Prior to recirculation not met within limits pump start TECHNICAL REQUIREMENT SURVEILLANCE SURVEILLANCE FREQUENCY TRS 3.4.4.1 Verify the operating loop flow rate is

• 50% of rated Once within 15 loop flow rate and that the reactor is operating at a minutes prior to each THERMAL POWER/core flow condition below the recirculation pump 80% rod line shown the Power Flow map specified start in the COLR.

SUSQUEHANNA UNIT 2 - TRM / 3.4-12 EFFECTIVE DATE 12/03/2004

Snubbers PPL Rey. 1 3.7.8 3.7 Plant Systems 3.7.8 Snubbers TRO 3.7.8 All snubbers shall be OPERABLE APPLICABILITY: At all times ACTIONS K1 I Tr:

IM L - 1 r_-

Separate condition entry is allowed for each snubber CONDITION REQUIRED ACTION COMPLETION TIME A. NOTE---- A.1. Declare the supported 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Required Action A.2 shall system inoperable be completed if this Condition is entered. AND One or more snubbers. A.2 Perform an engineering 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable evaluation on the supported component OR A.3 If an engineering evaluation 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> has been performed on the supported component, replace or restore the-inoperable snubber(s) to OPERABLE status B. Required Action and B.1 Declare the supported Immediately associated Completion system inoperable Time of Condition A not met (continued)

SUSQUEHANNA - UNIT 2 TRM / 3.7-43 EFFECTIVE DATE 12/0312004

Snubbers PPL Rev. 1 3.7.8 Actions (continued) .

CONDITION REQUIRED ACTION COMPLETION TIME C Any snubber selected for C. - NOTE- Within the current functional testing either fails This action shall be inspection interval.

to activate or fails to move independent of the Testing due to manufacturer or Requirements for snubbers design deficiency. not meeting the functional test acceptance criteria per TRS 3.7.8.2 All snubbers of the same design subject to the same defect shall be functionally tested -

D. The snubber service life will D.1 Reevaluate the snubber Prior to exceeding be exceeded prior to the service life snubber service life next scheduled snubber service life review. OR D.2 Replace or recondition the Prior to exceeding snubber so as to extend its snubber service life service life beyond the date of the next scheduled service life review TECHNICAL REQUIREMENT SURVEILLANCE SURVEILLANCE FREQUENCY TRS 3.7.8.1 Demonstrate each snubber OPERABLE by As directed by performance of visual inspection Table 3.7.8-1 TRS 3.7.8.2 Perform functional test of a representative sampling 24 months of all snubbers per Table 3.7.8-3. . . ..

(continued)

SUSQUEHANNA - UNIT 2 TRM / 3.7-44 EFFECTIVE DATE 10/13/1998

Snubbers PPL Rey. 1 3.7.8 TECHNICAL REQUIREMENT SURVEILLANCE (continued).

SURVEILLANCE FREQUENCY TRS 3.7.8.3 --- NOTE - 24 months Documentation of critical parts replaced so that the maximum service life is not exceeded shall be retained as required by FSAR 17.2.17.

Monitor the installation and maintenance records for each snubber to ensure that the service life has not been exceeded and will not be exceeded prior to the next snubber surveillance inspection.

TRS 3.7.8.4 - N NOTE- - At the time of the Snubbers tested per this surveillance are in addition next functional to snubbers selected for the sample plan per TRS test.

3.7.8.2.

Test snubbers in locations of snubbers that failed the functional test during the previous test period.

TRS 3.7.8.5 An inspection shall be performed of all snubbers As necessary attached to sections of systems that have experienced unexpected, potentially damaging transients as determined from a review of operational data and a visual inspection of the systems within. .

SUSQUEHANNA - UNIT 2 TRM / 3.7-45 EFFECTIVE DATE 10/13/1998

Snubbers PPL Rey. I 3.7.8 Table 3.7.8-1 SNUBBER VISUAL INSPECTION INTERVAL Number Of Unacceptable Visually Inspected Inspection Interval Snubbers in Previous Inspection Interval

1. Equal to or less than the applicable May be twice the previous interval but not number in Table 3.7.8-2 Column A greater than 48 months

2. Equal to or less than the applicable Same as the previous interval number in Table 3.7.8-2 Column B but greater than the applicable number in Column A

3. Equal to or greater than the applicable Two-thirds of the previous interval number in Table 3.7.8-2 Column C.

4. Less than the applicable number in Table Equal to the previous interval (Ia.), reduced 3.7.8-2 Column C but greater than the proportionally by a factor that is one-third of applicable number in Column B the ratio of the difference between the number of unacceptable snubbers found during the previous interval (N- 1) and the number in Column B (NB) to the difference in the numbers in Columns C (N0) and B, or.

II 1 1- N)

" *cI' .N 4

SUSQUEHANNA - UNIT 2 TRM /3.7-46. EFFECTIVE DATE 10113/1998

Snubbers PPL Rev.1 3.7.8 TABLE 3.7.8-2 NUMBER OF UNACCEPTABLE SNUBBERS PREVIOUS SNUBBER VISUAL INSPECTION INTERVAL Population Column A Column B Column C

- 0 0 1 80 0 0 2 100 0 1 4 150 0 3 8 200 2 5 13 300 5 12 25 400 8 18 36 500 12 . 24 48 750 20 40 78 1,000 or greater 29 56 109 LI e%-Iftc'

- -IMILjI r- Z1%

1. Interpolation between population or category sizes and the number of unacceptable snubbers is permissible. Use next lower integer for the value of the limit for Columns A, B or C if that integer includes a fractional value of unacceptable snubbers as determined by interpolation.

2. The provisions of TRS 3.0.2 are applicable for all inspection intervals up to and including 48 months.

SUSQUEHANNA - UNIT 2 -TRM I 3.7-47 UEFFECTIVE DATE 10/13/1998

Snubbers PPL Rey. 1 3.7.8 TABLE 3.7.8-3 REPRESENTATIVE SAMPLING SAMPLE FAILED SNUBBERS REPRESENTATIVE SAMPLING (a)

1. Initial 0 10%

2. Re-Test >0 in initial sample Additional 5%°)for each failure

3. Continued Testing >0 In Re-test or Continued Additional 5% for each failure to Testing Samples 100%° (a) Percentage of the total population of each type of snubber (b) An engineering evaluation shall be made of each failure to meet the functional test acceptance criteria to determine the cause of the failure and to determine the OPERABILITY of other snubbers, irrespective of type, which may be subject to the same failure mode. The results of this evaluation shall be used, if applicable, in selecting snubbers to be tested. If additional sampling is required due to failure of only one type of snubber, additional samples should be limited to the type of snubber, which has failed the functional testing.

SUSQUEHANNA - UNIT 2 TRM /3.7-48 EFFECTIVE DATE 03/0812003

Spent Fuel Storage Pools (SFSPs)

PPL Rev. 1 3.7.10 3.7 Plant Systems 3.7.10 Spent Fuel Storage Pools (SFSPs)

TRO 3.7.10 The following conditions shall be met when the Unit 1 and Unit 2 SFSPs are not cross-connected through the Cask Storage Pit.

a. The Unit 2 SFSP water temperature is less than or equal to 115 OF.

b. Both subsystems of the ESW system must have at least one pump and the respective flow path to the Spent Fuel Storage Pool OPERABLE.

c. One RHR Fuel Pool Cooling subsystem must be OPERABLE. (Cannot be the same set of equipment used to meet item d.)

d. RHR must have one subsystem of Suppression Pool Cooling OPERABLE. (Cannot be the same set of equipment used to meet item c.)

e. Zone II is capable of being aligned to the Recirculation Plenum.

APPLICABILITY: MODES 1, 2, 3, and 4 when the analyzed nominal decay heat in one SFSP is

• 5.1 X106 BTU/hr concurrent with the analyzed nominal decay heat in the other SFSP

• 4.0 x 106 BTU/hr. I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel pool water A.1 Restore the temperature 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> temperature > 115 "F. *115 OF.

B. Less than two subsystems B.1 Restore two subsystems of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> of ESW with at least one ESW with at least one pump pump or the respective flow and the respective flow path path to the Spent Fuel to the Spent Fuel Storage Storage Pool OPERABLE. Pool to OPERABLE status.

C. No RHR Fuel Pool Cooling C.1 Restore one subsystem to 7 days subsystem's OPERABLE. OPERABLE status.

(continued)

SUSQUEHANNA - UNIT 2 TRM / 3.7-51 EFFECTIVE DATE 12/03/2004

4. - - -- - --

Spent Fuel Storage.Pools (SFSPs)

PPL Re.v. 1 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. No RHR Suppression D.1 Restore one subsystem 7 days Pool Cooling to OPERABLE status.

subsystem's OPERABLE.

E. Zone ll not capable of E.1 Restore alignment 7 days being aligned to the capability.

Recirculation plenum.

F. Required Actions and F.1 Initiate actions to cross- Immediately associated Completion connect the Unit 1 and Times not met. Unit 2 Spent Fuel Storage Pools through the Cask Storage Pit.

TECHNICAL REQUIREMENT SURVEILLANCE SURVEILLANCE FREQUENCY TRS 3.7.10.1 Verify the fuel pool temperature is less than or equal 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> I to 115 "F.

TRS 3.7.10.2 Verify both subsystems of ESW have at least one Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> pump and the respective flow path to the Spent Fuel after the SFSP is Storage Pool OPERABLE. isolated from the Cask Storage Pit AND Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter TRS 3.7.10.3 Verify that an RHR Fuel Pool Cooling subsystem is Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OPERABLE. after the SFSP is isolated from the Cask Storage Pit AND Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter (continued)

.1

.SUSQUEHANNA -UNIT 2 TRM / 3.7-52 UTEFFECTIVE DATE 04/15/20003

Spent Fuel Storage Pools (SFSPs)

PPL Rey. 1 3.7.10 TECHNICAL REQUIREMENT SURVEILLANCE (continued)

SURVEILLANCE FREQUENCY Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> TRS 3.7.10.4 Verify that RHR has one subsystem of after the SFSP is Suppression Pool Cooling OPERABLE. isolated from the Cask Storage Pit AND Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> TRS 3.7.10.5 Verify that Zone II is capable of being aligned to after the SFSP is the Recirculation Plenum. isolated from the Cask Storage Pit AND Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter SUSQUEHANNA - UNIT 2 TRM / 3.7-53 EFFECTIVE DATE 07/29/1999

'I

Motor Operated Valves Thermal Overload Protection - Continuous PPL Re.y. 1

.. ... A, 3.8.2.1 3.8 Electrical Power 3.8.2 Motor Operated Valves Thermal Overload Protection 3.8.2.1 Motor Operated Valves (MOV) Thermal Overload Protection - Continuous I TRO 3.8.2.1 Thermal overload protection for each valve in Table 3.8.2.1-1 shall be bypassed. 'I APPLICABILITY: When the motor operated valve is required to be OPERABLE unless otherwise specified.

ACTIONS

-NOTE-Separate Condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more valves with A.1 Declare affected valve(s) 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thermal overload protection inoperable.

not bypassed.

AND A.2 Enter applicable Conditions 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> and Required Actions for affected system(s).

. .'k

-11 '

SUSQUEHANNA - UNIT 2 3.8-5 EFFECTIVE DATE 04/02/2002

Motor Operated Valves Thermal Overload Protection - Continuous PPL Rev. 1 3.8.2.1 TECHNICAL REQUIREMENT SURVEILLANCE SURVEILLANCE FREQUENCY, TRS 3.8.2.1.1 Verify thermal overload protection for required valves 24 months is bypassed.

AND Following maintenance on motor starter I AND Following activities during which thermal overload I protection was temporarily placed in force SUSQUEHANNA - UNIT 2 3.8-6 EFFECTIVE DATE 04/02/2002

Motor Operated Valves Thermal Overload Protection - Continuous PPL Rey. 1 3.8.2.1 TABLE 3.8.2.1-1 (Page 1 of 4)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION - CONTINUOUS SYSTEM(S)-

VALVE NUMBER AFFECTED HV-21313 Cont. Isol.

HV-21314 Cont. Isol.

HV-21345 Cont. Isol.

HV-21346 Cont. Isol.

HV-22603 Cont. Isol.

HV-25766 Cont. Isol.

HV-25768 Cont. Isol.

HV-252-2F0OIA CS HV-252-2F001 B CS HV-252-2F004A CS HV-252-2F004B CS HV-252-2F005A CS HV-252-2F005B CS HV-252-2F015A CS HV-252-2F015B CS HV-252-2F031A CS HV-252-2F031 B . CS HV-08693A ESW HV-08693B ESW HV-21144A ESW HV-21144B ESW HV-255-2F001 HPCI HV-255-2F002 HPCI HV-255-2F003 HPCI HV-255-2F004 HPCI HV-255-2F006 HPCI HV-255-2F007 HPCI HV-255-2F008 HPCI HV-255-2F011 HPCI HV-255-2F012 HPCI HV-255-2F042 HPCI HV-255-2F059 HPCI HV-255-2F066 HPCI HV-255-2F075 HPCI HV-255-2F079 HPCI HV-241-2F016 NSSS HV-241-2F019 NSSS (continued)

SUSQUEHANNA-.UNIT2 TRM /3.8-7 EFFECTIVE DATE 12/03/2004

Motor Operated Valves Thermal Overload Protection - Continuous PPL Rey. 1 3.8.2.1 TABLE 3.8.2.1-1 (Page 2 of 4)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION - CONTINUOUS SYSTEM(S)

VALVE NUMBER AFFECTED HV-25012 RCIC HV-249-2F007 RCIC HV-249-2F008 RCIC HV-249-2F010 RCIC HV-249-2F012 . RCIC HV-249-2F013 RCIC HV-249-2F019 RCIC HV-249-2F022 RCIC HV-249-2F031 RCIC HV-249-2F045 RCIC HV-249-2F046 RCIC HV-249-2F059 RCIC HV-249-2F060 RCIC HV-249-2F062 RCIC HV-249-2F084 RCIC HV-25112 RHR HV-251-2F003A . RHR HV-251-2F003B- RHR HV-251-2F004A RHR HV-251-2F004B RHR HV-251-2F004C RHR HV-251-2F004D RHR HV-251-2F006A RHR HV-251-2F006B RHR HV-251-2F006C RHR HV-251-2F006D RHR HV-251-2F007A RHR HV-251-2F007B RHR HV-251-2F008 RHR HV-251-2F009 RHR HV-251-2FO0OA RHR HV-251-2F01OB RHR HV-251-2F015A RHR HV-251-2F01 5B RHR HV-251-2F016A RHR HV-251-2F016B . RHR HV-251-2F017A RHR HV-251-2F017B RHR HV-251-2F021A RHR HV-251-2F021 B RHR HV-251-2F022 RHR (continued)

SUSQUEHANNA - UNIT 2 TRM / 3.8-8 EFFECTIVE DATE 12/03/2004

Motor Operated Valves Thermal Overload Protection - Continuous PPL Rey, 1 3.8.2.1 TABLE 3.8.2.1-1 (Page 3 of 4)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION - CONTINUOUS SYSTEM(S)

VALVE NUMBER AFFECTED-HV-251-2F023 RHR HV-251-2F024A RHR HV-251-2F024B RHR HV-251-2F027A RHR HV-251-2F027B RHR HV-251-2F028A RHR HV-251-2F028B RHR HV-251-2F040 RHR HV-251-2F047A RHR HV-251-2F047B RHR HV-251-2F048A RHR HV-251-2F048B RHR HV-251-2F049 RHR HV-251-2F103A RHR HV-251-2F103B RHR HV-251-2F104A RHR HV-251-2F104B RHR HV-01201A1- RHRSW HV-01201A2 RHRSW HV-01201B1 RHRSW HV-01201B2 RHRSW HV-01222A RHRSW HV-01222B RHRSW HV-01224A1 RHRSW HV-01224A2 RHRSW HV-01224B1 RHRSW HV-01224B2 RHRSW HV-2.1210A RHRSW HV-21210B RHRSW HV-21215A RHRSW HV-21215B RHRSW HV-251-2F073A RHRSW HV-251-2F073B 'RHRSW HV-251-2F075A RHRSW HV-251-2F075B RHRSW HV-24182A RWCU HV-24182B RWCU HV-244-2F001 RWCU (continued).

SUSQUEHANNA - UNIT 2 TRM / 3.8-9 EFFECTIVE DATE 12/0312004

Motor Operated Valves Thermal Overload Protection - Continuous PPL Rey. 1 3.8.2.1 TABLE.3.8.2.1-1 (Page 4 of 4)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION - CONTINUOUS SYSTEM(S)-

VALVE NUMBER AFFECTED HV-244-2F004 RWCU HV-243-2F031A RX RECIRC HV-243-2F031 B RX RECIRC HV-243-2F032A RX RECIRC HV-243-2F032B RX RECIRC SUSQUEHANNA - UNIT 2 TRM / 3.8-10 EFFECTIVE DATE 12/03/2004

Motor Operated Valves Thermal Overload Protection - Automatic PPLRey.2 3.8.2.2 3.8.2 Motor Operated Valves Thermal Overload Protection 3.8.2.2 Motor Operated Valves (MOV) Thermal Overload Protection - Automatic TRO 3.8.2.2 Thermal overload protection for each valve in Table 3.8.2.2-1 shall have automatic bypass capability.

APPLICABILITY: When diesel generator (DG) E is not aligned to the Class 1E distribution system and the valve is open. I ACTIONS

-- NO r-Separate condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more MOVs A.1 Continuously bypass the 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> with automatic bypass thermal overload protection.

of thermal overload protection inoperable. OR A.2.1 Verify DG E is not running. 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> AND A.2.2 Verify the affected ESW flow 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> path is isolated.

TECHNICAL REQUIREMENT SURVEILLANCE SURVEILLANCE FREQUENCY TRS 3.8.2.2.1 Verify automatic bypass of MOV thermal 24 months overload protection is OPERABLE.

SUSQUEHANNA - UNIT 2 TRM / 3.8-11 EFFECTIVE DATE 09/03/2004

Motor Operated Valves Thermal Overload Protection - Automatic PPLRey.2 3.8.2.2 TABLE 3.8.2.2-1 MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION - AUTOMATIC SYSTEM VALVE NUMBER AFFECTED HV01 IOE ESW HV01 120E ESW HV1II12E ESW HV01 122E ESW SUSQUEHANNA - UNIT 2 TRM / 3.8-12 EFFECTIVE DATE 12/03/2004

Liquid Radwaste Effluent Monitoring Instrumentation PPL Rev. 1 3.11.1.4 3.11 Radioactive Effluents 3.11.1 Liquid Effluents 3.11.1.4 Liquid Radwaste Effluent Monitoring Instrumehtation TRO 3.11.1.4 The Radioactive Liquid Radwaste Effluent Monitoring Instrumentation channels shown inTable 3.11.1.4-1 shall be OPERABLE with their setpoints established in accordance with the ODCM to ensure that the alarm/trip will occur prior to exceeding the limits of TRO 3.11.1.1.

APPLICABILITY: At all times.

ACTIONS

___- INOTE-

1. Separate condition entry is allowed for each channel

2. The provisions of TRO 3.0.4 are not applicable CONDITION REQUIRED ACTION COMPLETION TIME A. One or more radioactive A.1 Suspend the release of Immediately liquid effluent monitoring radioactive liquid effluents instrumentation alarm/trip monitored by the affected channels setpoint less channel conservative than the limits OR allowed by TRO 3.11.1.1 - A.2 Declare the channel Immediately inoperable (continued)

SUSQUEHANNA - UNIT 2 3.11-8 EFFECTIVE DATE 08/31/1998

Liquid Radwaste Effluent Monitoring Instrumentation PPL Rev. 1 . . .s 3.11.1.4 ACTIONS (continued) - _

CONDITION REQUIRED ACTION COMPLETION TIME B. Liquid Radwaste releases B.1 Analyze at least two Prior to initiating are necessary and Effluent independent samples in each release.

Line Gross Radioactivity accordance with TRO 3.11.1.1 Monitoring Instrumentation AND inoperable.

B.2 Independently determine Prior to initiating release rates for samples each release.

analyzed per Action B.1 AND B.3 Perform and independently Prior to initiating verify discharge valve lineup each release.

AND B.4 Restore monitoring 14 days instrumentation C. Liquid Radwaste releases C.1 Maintain at least one isolation Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of are not in progress and the valve closed between each securing from Gross Radioactivity source of release and the release or Monitoring instrumentation liquid radwaste discharge discovery of is inoperable because the valve. inoperable inoperable channel is instrument.

caused by a discharge valve interlock in an off-normal condition or not functioning.

(continued)

SUSQUEHANNA - UNIT 2 3.11-9 EFFECTIVE DATE 08/31/1998

Liquid Radwaste Effluent Monitoring Instrumentation PPL Rev. 1 . . . . . . ..

3.11.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Liquid Radwaste releases D.A Estimate Flow Rate. _ Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> are necessary and Effluent during releases.

Line or Cooling Tower AND Blowdown Flow Monitoring Instrumentation inoperable. D.2 Restore Monitoring 30 days Instrumentation.

E. Liquid Radwaste releases E.1 Maintain at least one Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of are not in progress and isolation valve closed securing release or cooling tower blowdown between each source of discovery of flow monitoring release and the liquid inoperable instrument instrumentation is radwaste discharge valve.

inoperable because the inoperable channel is a discharge valve interlock in an off-normal condition or not functioning.

F. Required Action and F.1 NOTE--

Associated Completion Only applicable to Time of Conditions B, C, D, CodtnB or E not met Condiion_

Suspend release of Immediately radioactive effluents via this pathway AND F.2 Explain why the In the next inoperability was not  ; Radioactive Effluent I',

corrected in a timely Release Report per manner TS Section 5.6 SUSQUEHANNA - UNIT 2

• TRM /3.11-10 EFFECTIVE DATE 12103/2004

Liquid Radwaste Effluent Monitoring Instrumentation PPL Rev. 1 3.11.1.4 TECHNICAL REQUIREMENT SURVEILLANCE NOTE-Refer to Table 3.11.1.4-1 to determine which TRSs apply for each Monitoring Function.

SURVEILLANCE FREQUENCY TRS 3.11.1.4.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> TRS 3.11.1.4.2 Perform CHANNEL CHECK including a source Prior to check. commencing release TRS 3.11.1.4.3 Perform CHANNEL FUNCTIONAL TEST 92 days TRS 3.11.1.4.4 Perform CHANNEL CALIBRATION 24 months SUSQUEHANNA - UNIT 2 3.11-11 EFFECTIVE DATE 08/31/1998

Uquid Radwaste Effluent Monitoring Instrumentation PPL Rev. 1 3.11.1.4 TABLE 3.11.1.4-1 LIQUID RADWASTE EFFLUENT MONITORING INSTRUMENTATION REQUIRED SURVEILLANCE FUNCTION CHANNELS REQUIREMENTS

1. GROSS RADIOACTIVITY MONITORS PROVIDING AUTOMATIC TERMINATION OF RELEASE

a. Liquid Radwaste Effluent Line I TRS 3.11.1.4.2 TRS 3.11.1.4.3 TRS 3.11.1.4.4

2. FLOW RATE MEASUREMENT DEVICES

a. Liquid Radwaste Effluent Line 1 TRS 3.11.1.4.1(a)

-TRS 3.11.1.4.3 TRS 3.11.1.4.4

b. Cooling Tower Blowdown 1 TRS 3.11.1.4.1 (a)

TRS 3.11.1.4.3 TRS 3.11.1.4.4

') Only required when performing batch releases.

SUSQUEHANNA - UNIT 2 3.1 1-12 EFFECTIVE DATE 08/31/1998

Radioactive Liquid Process Monitoring Instrumentation PPL Rev. 1 3.11.1.5 3.11 Radioactive Effluents 3.11.1 Liquid Effluents 3.11.1.5 Radioactive Liquid Process Monitoring Instrumentation TRO 3.11.1.5 The Radioactive Liquid Process Monitoring Instrumentation channels shown in Table 3.11.1.5-1 shall be OPERABLE with their setpoints established in accordance with the ODCM to ensure the alarm will occur prior to exceeding the limits of TRO 3.11.1.1.

APPLICABILITY: As specified in Table 3.11.1.5-1.

ACTIONS

&1e%1Tr

[ML jI

1. Separate condition entry is allowed for each channel

2. The provisions of TRO 3.0.4 are not applicable CONDITION REQUIRED ACTION COMPLETION TIME A One or more Radioactive A.1 Suspend the release of liquid Immediately Liquid Process Monitoring effluents monitored by the Instrumentation alarm/trip affected channel channels setpoint less OR conservabive than the limits.

cllonservati ta the lim. A.2 Declare the channel . Immediately allowed byTRO 3.11(inoperablen (continued)

SUSQUEHANNA - UNIT 2 3.11-13 EFFECTIVE DATE 9/01/1998 l

Radioactive Liquid Process Monitoring Instrumentation PPL Rey. 1 - -

3.11.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.' Radioactive Liquid Process B.1.1 Suspend the release of Immediately Monitoring Instrumentation liquid effluents monitored by otherwise inoperable. the affected channel.

OR B.1.2 Analyze grab samples for Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> isotopic activity to the when the required LLDs for liquid associated pathway effluents (Table 3.11.1.1-1). is in service AND B.2 Restore monitoring 30 days instrumentation C. Required Action and C.1 Explain why the inoperability In the next Associated Completion was not corrected in a timely Radioactive I Time of Conditions B not manner Effluent Release met. Report per TS Section 5.6 D. RHR Heat Exchanger to be D.1 Analyze grab samples from Prior to draining drained to the spray pond. the RHR Heat Exchanger for RHR Heat isotopic activity to the required Exchanger to the LLDs for liquid effluents (Table spray pond.

3.11 .1.1-1).

SUSQUEHANNA - UNIT 2 TRM /3.11-14 EFFECTIVE DATE 12/03/2004

Radioactive'Liquid Process Monitoring Instrumentation PPL Ray. I 3.11.1.5 TECHNICAL REQUIREMENT SURVEILLANCE

-- NOTE Refer to Table 3.11.1.5-1 to determine which TRSs apply for each Monitoring Function.

SURVEILLANCE FREQUENCY TRS 3.11.1.5.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> TRS 3.11.1.5.2 Perform a Source Check 31 days TRS 3.11.1.5.3 Perform CHANNEL FUNCTIONAL TEST 92 days TRS 3.11.1.5.4 Perform CHANNEL CALIBRATION 24 months "I

SUSQUEHANNA - UNIT 2 3.11-15 EFFECTIVE DATE 9/01/1998

Radioactive Liquid Process Monitoring Instrumentation PPL Rev. 1 3.11.1.5 TABLE 3.11.1.5-1 RADIOACTIVE LIQUID PROCESS MONITORING INSTRUMENTATION REQUIRED SURVEILLANCE FUNCTION CHANNELS APPLICABILITY REQUIREMENTS GROSS RADIOACTIVITY MONITORS NOT PROVIDING AUTOMATIC TERMINATION OF RELEASE

1. Service Water System Effluent Line I (a) TRS 3.11.1.5.1 TRS 3.11.1.5.2 TRS 3.11.1.5.3 TRS 3.11.1.5.4

2. Supplemental Decay Heat Removal I (a) TRS 3.11.1.5.1 Service Water TRS 3.11.1.5.2 TRS 3.11.1.5.3 TRS 3.11.1.5.4

3. RHR Service Water System Effluent 1/Loop (b) TRS 3.11.1.5.1 Line. TRS 3.11.1.5.2 TRS 3.11.1.5.3 TRS 3.11.1.5.4 (a) System aligned through Fuel Pool Cooling Heat Exchanger. Alignment change between Service Water System Effluent Line and Supplemental Decay Heat Removal Service Water is not considered to be a change in the applicable condition.-

(b) At all times SUSQUEHANNA - UNIT 2 3.11-16 EFFECTIVE DATE 9/01/1998

Radioactive Gaseous Effluent Monitoring Instrumentation PPL Rey. 2 3.11.2.6 3.11 Radioactive Effluents 3.11.2 Gaseous Effluents 3.11.2.6 Radioactive Gaseous Effluent Monitoring Instrumentaion TRO 3.11.2.6 The radioactive gaseous effluent monitoring instrumentation channels shown in Table 3.11.2.6-1 shall be OPERABLE with their setpoints established in accordance with the ODCM to ensure that the limits of Requirement 3.11.2.1 are not exceeded.

APPLICABILITY: According to Table 3.11.2.6-1 ACTIONS

-NI Irt

1. Separate condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. Radioactive gaseous A.1 Suspend the release of Immediately effluent monitoring . radioactive gaseous effluents instrumentation channel monitored by the affected alarm/trip setpoint less channel conservative than OR required to ensure that the limits of Requirement A.2 Declare the channel Immediately 3.11.2.1 are not inoperable exceeded (continued)

SUSQUEHANNA - UNIT 2 3.1 1-25 EFFECTIVE DATE 9/01/1998

Radioactive Gaseous Effluent Monitoring Instrumentation PPL Rey. 2 3.112.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Reactor Building B.1 Take grab samples - Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Ventilation System Noble while release is in Gas Activity Monitor low progress.

range channel inoperable AND B.2 Analyze grab samples for Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of isotopic activity to the grab sample required LLDs for principal noble gas gamma emitters (Table 3.11.2.1-1)

AND B.3 Restore monitoring 30 days instrumentation.

C. Deleted I D. Reactor Building Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Ventilation Monitori ng D.1 Estimate flow rate, while release is in System Effluent System progress Flow Rate Monitor or Sampler Flow Rate AND Monitor inoperable R . 30 days D.2 Restore monitoring instrumentation.

(continued)

SUSQUEHANNA - UNIT 2 TRM /3.11-26 EFFECTIVE DATE 01/21/2004

Radioactive Gaseous Effluent Monitoring Instrumentation PPL Rev. 2

- . - - - . . 1 3.11.2.6 I

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Turbine Building Ventilation E.1 Verify mechanical vacuum- Immediately System Noble Gas Activity pump is not in operation.

Monitor low range channel AND inoperable E.2 Take grab samples. Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> while release is in AND progress E.3 Analyze grab samples for Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after isotopic activity to the sample required LLDs for principal noble gas gamma emitters (Table 3.11.2.1-1).

AND E.4 Restore monitoring 30 days instrumentation F. Deleted G. Turbine Building Ventilation G.1 Estimate flow rate. Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Monitoring System Effluent while release is in System Flow Rate Monitor progress.

or Sampler Flow Rate AND Monitor inoperable G.2 Restore monitoring 30 days instrumentation (continued)

SUSQUEHANNA - UNIT 2 TRM / 3.11-27 EFFECTIVE DATE 01/21/2004

Radioactive Gaseous Effluent Monitoring Instrumentation PPL Rey. 2 1 . .. .

3.11.2.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. Standby Gas Treatment H.1 Take grab samples. Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> System Noble Gas Activity AND while release is in Monitor low range channel progress.

inoperable H.2 Analyze grab samples for Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of isotopic activity to the required grab sample being LLDs for principal noble gas taken.

gamma emitters (Table

-3.1 1.2.1-1).

AND H.3 Restore monitoring 30 days instrumentation.

I. Deleted I

J. SGTS Ventilation J.1 Estimate flow rate. Once per4 hours Monitoring System Effluent while release is in flow rate monitor or sample progress.

flow rate monitor AND Inoperable.

J.2 Restore monitoring 30 days Instrumentation.

(continued)

SUSQUEHANNA - UNIT 2 TRM / 3.1 1-28 EFFECTIVE DATE 01/21/2004

Radioactive Gaseous Effluent Monitoring Instrumentation PPL Rey. 2 3.11.2.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME K. Required Actions and K.1 Explain why this inoperability- In the next Completion Times not was not corrected in a timely Radioactive Effluent I met for Conditions B manner. Release Report per through J. TS Section 5.6.

TECHNICAL REQUIREMENT SURVEILLANCE

-- NOTE Refer to Table 3.11.2.6-1 to determine which TRSs apply for each Monitoring Function.

SURVEILLANCE FREQUENCY TRS 3.11.2.6.1 Perform CHANNEL CHECK 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> TRS 3.11.2.6.2 Deleted TRS 3.11.2.6.3 Perform Source Check 31 days TRS 3.11.2.6.4 Perform CHANNEL FUNCTIONAL TEST 92 days TRS 3.11.2.6.5 Perform CHANNEL CALIBRATION 24 months I ..

SUSQUEHANNA - UNIT 2 TRM / 3.1 1-29 EFFECTIVE DATE 12/03/2004

Radioactive Gaseous Effluent Monitoring Instrumentation PPL Rey. 2 . .

3.11.2.6 TABLE 3.11.2.6-1 (Page 1 of 3)

RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION REQUIRED SURVEILLANCE FUNCTION APPLICABILITY CHANNELS REQUIREMENTS REACTOR BUILDING VENTILATION MONITORING SYSTEM

a. Noble Gas Activity Monitor At all Times 1 TRS 3.11.2.6.1 (Low Range) TRS 3.11.26.3 TRS 3.11.2.6.4 TRS 3.11.2.6.5

b. Deleted

c. Deleted d Effluent System Flow Rate Monitor At all Times 1 TRS 3.11.2.6.1 TRS 3.11.2.6.4 TRS 3.11.2.6.5

e. Sampler Flow Rate Monitor At all Times 1 TRS 3.11.2.6.1 TRS 3.11.26.4 TRS 3.11.2.6.5 (continued)

SUSQUEHANNA - UNIT 2 TRIV 1 3.1 1-30 EFFECTIVE DATE 01/21/2004

- Radioactive Gaseous Effluent Monitoring Instrumentation PPL Rev. 2 3.11.2.6 TABLE 3.11.2.6-1 (Page 2 of 3)

RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION REQUIRED SURVEILLANCE FUNCTION APPLICABILITY CHANNELS REQUIREMENTS

2. TURBINE BUILDING VENTILATION MONITORING SYSTEM

a. Noble Gas Act Monitor At all limes 1 TRS 3.11.2.6.1 (Low Range) TRS 3.11.2.6.3 TRS 3.11.2.6.4 TRS 3.11.2.6.5

b. Deleted

c. Deleted I

d. Effluent System Flow Rate Monitor At all limes 1 TRS 3.11.2.6.1 TRS 3.11.2.6.4 TRS 3.11.2.6.5

e. Sampler Flow Rate Monitor At all limes 1 TRS 3.11.2.6.1 TRS 3.11.2.6.4 TRS 3.11.2.6.5 (continued))

%- - , -- -- -1 SUSQUEHANNA - UNIT 2 TRM /3.11-31 EFFECTIVE DATE 01/21/2004

Radioactive Gaseous Effluent Monitorng Instrumentation PPL Rey.

2 3.11.2.6 TABLE 3.11.2.6-1 (Page 3 of 3)

RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION REQUIRED SURVEILLANCE FUNCTION APPLICABILITY CHANNELS REQUIREMENTS

3. STANDBY GAS TREATMENT SYSTEM (SGTS) MONITOR

a. Noble Gas Activity Monitor During I TRS 3.11.2.6.1 (Low Range) operation of TRS 3.11.2.6.3 SGTSe') TRS 3.11.2.6.4 TRS 3.11.2.6.5 b.' Deleted I

c. Deleted I

d. Effluent System Flow Rate Monitor During 1 TRS 3.11.2.6.1 operation of TRS 3.11.2.6.4 SGTSr( TRS 3.11.2.6.5

e. Sampler Flow Rate Monitor During I TRS 3.11.2.6.1 operation of TRS 3.11.2.6.4 SGTS(a)- TRS 3.11.2.6.5 (a) The provisions of TRO 3.0.4 are not applicable.

SUSQUEHANNA - UNIT 2 TRM /3.11-32 UEFFECTIVE DATE 01/21/2004

Monitoring Program PPL Rev. 1 3.11.4.1 3.11 Radioactive Effluents 3.11.4 Radiological Environmental Monitoring 3.11.4.1 Monitoring Program TRO 3.11.4.1 The radiological environmental monitoring program shall be conducted as specified in Table 3.11.4.1-1.

APPLICABILITY: At all times ACTIONS CONDITION REQUIRED ACTION . COMPLETION TIME A. Radiological environmental A.1 Report and describe the Annually monitoring program not events and any actions being conducted as taken to prevent their specified in Table recurrence in the Annual 3.11.4.1-1 Radiological Environmental Operating Report B. The average level of B.1 Prepare and submit a 30 days radioactivity over any Special Report to the calendar quarter as the Commission result of an individual radionuclide in plant effluents in a particular environmental exposure.

pathway in a particular environmental sampling medium, at a specified location exceeds the applicable reporting level of Table 3.11.4.1-2 (continued)

SUSQUEHANNA - UNIT 2 3.11-35 EFFECTIVE DATE 08131/1998

Monitoring Program PPL Rev. 1 3.11.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. More than one of the C.1 Prepare and submit a -30 days radionuclides in Table Special Report to the 3.11.4.1-2 are detected in a Commission particular environmental exposure pathway at a specified monitoring location and are the result of plant effluents AND The sum of the ratios of the quarterly average activity levels to their corresponding reporting levels of each detected radionuclide, from Table 3.11.4.1-2, is Ž1.0 (continued)

.. SUSQUEHANNA - UNIT 2 -3.11-36 EFFECTIVE DATE 08/31/1998

Monitoring Program PPL Rey. 1 - 3.11.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more D.1 Prepare and submit a 30 days Radionuclide(s) other than Special Report to the those in Table 3.11.4.1-2 Commission are detected in a particular environmental exposure pathway at a specified location and are the result of plant effluents AND The potential annual dose to a MEMBER OF THE PUBLIC from all detected radionuclides that are the result of plant effluents is greater than or equal to the calendar year limits of TROs 3.11.1.2, 3.11.2.2 .

and 3.11.2.3 E. The requirements for a E.1 Report and discuss the Annually Special Report per reasons for not attributing Conditions B, C, or D are identified radionuclides to met, but the radionuclides plant effluents in the that are detected are not Annual Radiological the result of plant effluents Environmental Operating Report (continued)

SUSQUEHANNA - UNIT 2 3.1 1-37 EFFECTIVE DATE 08/31/1998

Monitoring Program PPL Rey. 1 3.11.4.1 ACTIONS (continued) -

CONDITION REQUIRED ACTION COMPLETION TIME F. Milk or fresh leafy --- NOT E vegetable samples are The specific locations from which unavailable from one or samples were unavailable may then more of the sample be deleted from the monitoring locations required by Table program.

3.11.4.1-1 porm F.1 Identify locations for obtaining 30 days replacement samples and add them to the radiological environmental monitoring program AND F.2 Identify the cause of the Annually unavailability of samples and identify the new location(s) for obtaining replacement samples in the next Radioactive Effluent Release I

__ Report SUSQUEHANNA - UNIT 2 TRM / 3.11-38 EFFECTIVE DATE 12/03/2004

Monitoring Program PPL Rev. 1 3.11.4.1 TECHNICAL REQUIREMENT SURVEILLANCE SURVEILLANCE - FREQUENCY TRS 3.11.4.1.1 Collect the radiological environmental monitoring As required by samples pursuant to Table 3.11.4.1-1 Table 3.11.4.1-1 TRS 3.11.4.1.2 Analyze samples pursuant to the requirements of As required by Table 3.11.4.1-1 with equipment meeting the Table 3.11.4.1-1 detection capabilities required by Table 3.11.4.1-3 TRS 3.11.4.1.3 Determine annual cumulative potential dose Annually contributions from radionuclides detected in environmental samples in accordance with the methodology and parameters in the ODCM.

SUSQUEHANNA - UNIT 2 I 3.11 -39 EFFECTIVE DATE 08/31/1998

Monitoring Program PPL Rev. 1 3.11.4.1 TABLE 3.11.4.1-1 (Page 1 of 3)

RADIOLOGICAL ENVIRONMENTAL MONITORING PROGRAM NUMBER OF REPRESENTATIVE SAMPLING AND EXPOSURE PATHWAY SAMPLES AND COLLECTION TYPE AND FREQUENCY AND/OR SAMPLE SAMPLE LOCATIONS FREQUENCY OF ANALYSIS

1. DIRECT RADIATION 40 routine monitoring stations with two or Quarterly Gamma dose quarterly more dosimeters or with one instrument for measuring and recording dose rate continuously placed as follows:

1. An Inner ring of stations, one in each meteorological sector, in the general area of the SITE BOUNDARY

2. An outer ring of stations, one in each meteorological sector, in the 3 +

to 9 mile range from the site

3. The balance of the stations placed In special interest areas such as.

population centers, nearby residences, schools, and in I or 2 areas to serve as control stations

2. AIRBORNE Radioiodine and Samples from 5 locations Continual sampler Radioiodine Canister Parculates . sample from ose to each of the operation with 1-131 Analysis weekly a.sp* o BOUNDARY losations eh o sample collection 3 SITE BOUNDARY locations (in weekly, or more - Particulate SamDler different sectors) with the highest frequently if required Gross Beta.radio activity calculated annual average by dust loading analysis following filter groundlevel xIQ

• change(a) Gamma isotopic

b. I sample from the vicinity of the analysis of composite (by community having one of the location) quarterly highest calculated annual ground level XIQ

c. I sample from a control location, between 15 and 30 km distant and in the least prevalent wind direction of wind blowing from the plant (continued)

(') Airborne particulate sample filters shall be analyzed for gross beta radioactivity 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ormore after sampling to allow for radon and thom daughter decay. If gross beta activity in air particulate samples is greater than ten times the yearly mean of control samples, gamma isotopic analysis shall be performed on the Individual samples.

SUSQUEHANNA - UNIT 2 3.11-40 EFFECTIVE DATE 08/31/1998

Monitoring Program PPL Rev. 1 3.11.4.1 TABLE 3.11.4.1-1 (Page 2 of 3)

RADIOLOGICAL ENVIRONMENTAL MONITORING PROGRAM NUMBER OF REPRESENTATIVE SAMPLING AND TYPE AND EXPOSURE PATHIWAY SAMPLES AND COLLECTION FREQUENCY AND/OR SAMPLE SAMPLE LOCATIONS FREQUENCY OF ANALYSIS

3. WATERBORNE

a. Surface I sample upstream . Composite sample Gamma isotopic I sample downstream over one-month analysis period monthly.

Composite for tritium analyses quarterly

b. Ground Samples from I or 2 sources only if likely to be affected Quarterly Gamma Isotopic and tritium analyses quarterly

c. Drinking 1 sample from each of 1to 3 of the nearest water Composite sample 1-131 analysis supplies that could be affected by its discharge over 2-week period on each when 1-131 composite when I sample from a control location analysis is the dose performed, monthly calculated for composite the otherwise consumption of the water is greater than I mrem per year.

• -Composite for gross beta and gamma isotopic

- analyses monthly.

Composite for tritium analyses quarterly

d. Sediment 1 sample from downstream area with existing or Semiannually Gamma isotopic from potential recreational value analyses shoreline semiannually (continued)

SUSQUEHANNA - UNIT 2 3.11-41 EFFECTIVE DATE 08/31/1998

Monitoring Program PPL Rev. 1 3.11.4.1 TABLE 3.11.4.1-1 (Page 3 of 3)

RADIOLOGICAL ENVIRONMENTAL MONITORING PROGRAM SAMPLING NUMBER OF REPRESENTATIVE AND TYPE AND EXPOSURE PATHWAY SAMPLES AND COLLECTION FREQUENCY AND/OR SAMPLE SAMPLE LOCATIONS FREQUENCY OF ANALYSIS

4. INGESTION

a. Milk a. Samples from milking animals in 3 Semimonthly Gamma isotopic and locations within 5km from the plant when animals 1-131 analysis having the highest dose potential. If are on pasture, semimonthly when there are none, then, I sample from monthly at animals are on milking animals in each of 3 areas other times. pasture; monthly at between 5 and 8km distant where other times.

doses are calculated to be greater than 1 mrem per year.

1 sample from milking animals at a control location (between 15 and 30km from the plant preferably in the least prevalent direction for wind blowing from the plant).

b. Fish and/or b. I sample of each of two recreationally Sample in Gamma isotopic Invertebrates important species in vicinity of plant season, or analysis on edible discharge area. semiannually if portions.

they are not 1 sample of same species in areas not seasonal.

influenced by plant discharge.

c. Food c. 1 sample of each principal class of food At time of Gamma isotopic Products products from any area which is harvest analysis on edible irrigated by water in which liquid plant portions.

wastes have been discharged.

Samples of 3 different kinds of broad leaf vegetation grown nearest each of Monthly when Gamma isotopic and two different offsite locations of highest available 1-131 analysis.

predicted annual average ground level D/Q if milk sampling Is not performed.

1 sample of each of the similar broad Monthly when Gamma isotopic and leaf vegetation grown between 15 to available 1-131 analysis.

30km from the plant, preferably, in the least prevalent direction for wind blowing from the plant if milk sampling is not performed.

SUSQUEHANNA - UNIT 2 3.11-42 EFFECTIVE DATE 08/31/1998

• Monitoring Program

• PPL Rev, 1 3.11.4.1 TABLE 3.11.4.1-2 REPORTING LEVELS FOR RADIOACTIVITY CONCENTRATIONS INENVIRONMENTAL SAMPLES Reporting Levels _

Water Airborne Particulate Fish Milk Food Products Analysis (pCIA) or Gases (pCi/n 3 ) (pCi/kg, wet) (pCiA) (pCVkg, wet)

H-3 20,000(a)

Mn-54 1,000 30,000 Fe-59 400 10,000 Co-58 1,000 30,000 Co-60 300 10,000 Zn-65 300 20,000 Zr-Nb-95 400(b) 1-131 2 0.9 3 100 Cs-134 30 10 1,000 60 1,000 Cs-137 50 20 2,000 70 2,000 Ba-La-140 200°b. 300 (a) For drinking water samples. This is 40 CFR Part 141 value. If no drinking water pathway exists, a value of 30,000 pCi/A may be used.

° Total for parent and daughter.

SUSQUEHANNA -UNIT 2 3.1 1-43 EFFECTIVE DATE 08/31/1998

Monitoring Program PPL Rey. 1 3.11.4.1 TABLE 3.11.4.1-3 DETECTION CAPABILITIES FOR ENVIRONMENTAL SAMPLE ANALYSIS LOWER LIMIT OF DETECTION (LLD)

Water Airborne Fish Milk Food Sediments Analysis (pCUI) Particulate Or (pCikg, wet) CU1 Products (pCikg, dry)

Gas (pCu/ 3 ) (pi) (pCi/kg, wet)

Gross Beta 4 0.01 H-3 2000 Mn-54 15 130 Fe-59 30 260 Co-58,60 15 130 Zn-65 30 260 Zr-95 30 Nb-95 15 1-131 IN 0.07 1 60 Cs-134 15 0.05 .130 15 60 150 Cs-137 18 . 0.06 150 18 80 180 Ba-140 60 60 La-140 15 15 (a) LLD for drinking water samples.

SUSQUEHANNA - UNIT 2 3.11-44 EFFECTIVE DATE 08/31/1998

Land Use Census PPL Re.y. 1 3.11.4.2

- 3.11 Radioactive Effluents 3.11.4 Radiological Environmental Monitoring 3.11.4.2 Land Use Census TRO 3.11.4.2 A land use census shall be conducted.

APPLICABILITY: -At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Land use census identifies A.1 Identify the new As defined by the a location(s) which yields a location(s) in the next Radioactive Effluent calculated dose or dose Radioactive Effluent Release Report commitment greater than Release Report the values currently being calculated in Requirement 3.11.2.3 B. Land use census identifies B.1 Add the new location(s) 30 days a location(s) that yields a to the radiological calculated dose or dose environmental commitment (via the same monitoring program exposure pathway) 20 AND percent greater than at a location from which B.2 Identify the new As defined in Radioactive .1 samples are currently being location(s) in the next Effluent Release Report obtained in accordance Radioactive Effluent with Requirement 3.11.4.1 Release Report perTS Section 5.6 SUSQUEHANNA - UNIT 2 TRM / 3.11-45 EFFECTIVE DATE 12/03/2004

Land Use Census PPL Rey. 1

. ._ e 3.11.4.2 l TECHNICAL REQUIREMENT SURVEILLANCE SURVEILLANCE - FREQUENCY TRS 3.11.4.2.1 Conduct the land use census 12 months SUSQUEHANNA - UNIT 2 ,3.11-46 EFFECTIVE DATE 08/31/1998

TRM Isolation Actuation Instrumentation PPLRey.2 B 3.3.6 B 3.3.6 TRM Isolation Actuation Instrumentation BASES TRO The TRM Actuation instrumentation automatically initiates closure of appropriate primary containment isolation valves (PCIVs). The function of the PCIVs, in combination with other accident mitigation systems, is to limit fission product release during and following postulated Design Basis Accidents (DBAs)

(Reference 1). The TRM Isolation Actuation Instrument has been relocated from the Technical Specifications because the identified Function is not credited in the plant design basis to mitigate any plant event, but does provide a diverse means to initiate an Isolation Actuation.

The isolation instrumentation includes the sensors, relays, and instruments that are necessary to cause initiation of primary containment and reactor coolant pressure boundary (RCPB) isolation. When the setpoint is reached, the sensor actuates, which then outputs an isolation signal to the isolation logic. Monitoring a wide range of independent parameters provides functional diversity. The input parameters to the isolation logic are:

(a) Main steam line radiation, (b) Reactor Building Main Steam Differential Temperature - High, (c) Turbine Building Main Steam Line Tunnel Temperature - High, (d) HPCI Pipe Routing Area Differential Temperature - High,

.(e) HPCI Equipment Room Differential Temperature - High, (f) RCIC Pipe Routing Area Differential Temperature - High, (g) RCIC Equipment Room Differential Temperature - High, (h) RWCU Penetration Area Differential Temperature - High, (i) RWCU Pump Area Differential Temperature - High,

0) RWCU Heat Exchanger Area Differential Temperature - High, and (k) RHR Flow--High.

The valves associated with these trip channels are identified in Table B 3.3.6-1.

Each of these valves is also associated with other trip channels as identified in LCO Bases B 3.6.1.3:

Functions (d) and (f) trips will occur only after a 15 minute time delay; the other trips occur after a one second delay. See Tech Spec Basis B 3.3.6-1.

(continued)

SUSQUEHANNA - UNIT 2 TRM / B 3.3-1 0 EFFECTIVE DATE 08/31/1998

• TRM Isolation Actuation Instrumentation -

PPL Rey.

!-I_

e-2 B 3.3.6 B 3.3.6 TRM Isolation Actuation Instrumentation BASES (continued)

ACTIONS The Actions are defined to ensure proper corrective measures are taken in response to the inoperable components. The Actions are modified by Note 2, which identifies that if the degradation of any TRM Isolation Actuation Instrumentation impacts the OPERABILITY of any Technical Specification Isolation Instruments identified in LCO 3.3.6.1, "Primary Containment Isolation Instrumentation", the appropriate Technical Specification Actions must be taken.

This Note is necessary because the TRM Isolation Actuation Instrumentation can impact the capability of the Technical Specification Isolation Instrumentation. If this occurs, both the TRM and Technical Specification Required Actions must be taken to ensure proper compensatory actions are taken.

TRS The TRSs are defined to be performed at the specified Frequency to ensure that the TRM Isolation Actuation Instrumentation Functions are maintained OPERABLE. TRM Isolation Actuation Instrumentation Surveillances are performed consistent with the Bases for LCO 3.3.6.1 uIsolation Activation Instrumentation."

TRS 3.3.6.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific channel. The system functional testing performed on PCIVs in LCO 3.6.1.3 overlaps this surveillance to provide complete testing of the assumed safety function. The 24 month Frequency is based on the need to perform portions of this surveillance 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. Operating experience has shown these components usually pass the surveillance when performed at the 24 month Frequency.

TRS 3.3.6.6 Response time testing for the Function 1.a and Function 2.a < 10 second requirement per FSAR Table 7.3-29 is met by testing the channel for the < I second channel response time requirement per FSAR Table 7.3-29 for Function 1.a.

(continued)

SUSQUEHANNA - UNIT 2 TRM / B 3.3-11 EFFECTIVE DATE 08/31/1998

TRM Isolation Actuation Instrumentation I PPL Rey. 2 B 3.3.6 B 3.3.6 TRM Isolation Actuation Instrumentation

'BASES (continued)

REFERENCES 1. FSAR Section 7.3.1

2. NRC Inspection and Enforcement Manual, Part 9900: Technical Guidance, Standard Technical Specification Section 1.0 Definitions, Issue dated 12/8/96.

SUSQUEHANNA - UNIT 2 TRM / B 3.3-12 EFFECTIVE DATE 08/31/1998

TRM Isolation Actuation Instrumentation PPL Rev. 2 B 3.3.6 Table B 3.3.6-1 Primary Containment Isolation Valves (Page 1 of 1) _

Plant systems Valve Number Valve Description Isolation Signal Function No.

(Table.3.3.6-1)

Nuclear Boiler HV-241 F022A MSIV 1.a, 1.b HV-241F022B MSIV 1.a. 1.b HV-241F022C MSIV 1.a, 1.b HV-241 F022D MSIV . 1.a, 1.b HV-241F028A MSIV 1.a, 1.b HV-241F028B MSIV 1.a, 1.b HV-241 F028C MSIV 1.a, 1.b HV-241F028D MSIV l.a. 1.b HV-241F016 MSL Drain Isolation Valve 1.a, 1.b HV-241F019 MSL Drain Isolation Valve l.a. l.b Reactor Recirculation HV-243F019 Reactor Coolant Sample Valve 2.a HV-243F020 Reactor Coolant Sample Valve 2.a HPCI HV-255F002 HPCI Steam Supply Valve 3.a, 3.b HV-255F003 HPCI Steam Supply Valve 3.a, 3.b HV-255F100 HPCI Steam Supply Valve 3.a, 3.b HV-255F042 HPCI Suction Valve 3.a, 3.b RCIC HV-249F007 RCIC Steam Supply Valve 4.a, 4.b HV-249F008 RCIC Steam Supply Valve 4.a, 4.b HV-249F088 RCIC Steam Supply Valve 4.a, 4.b RWCU HV-244F001 RWCU Suction Valve 5.a, 5.b, 5.c HV-244F004. RWCU Suction Valve 5.a, 5.b, 5.c RHR HV-251 F022 RHR - Reactor Vessel Head Spray Valve . 6.a HV-251 F023 RHR - Reactor Vessel Head Spray Valve 6.a HV-251 F008 RHR - Shutdown Cooling Valve 6.a HV-251 F009 RHR - Shutdown Cooling Valve 6.a SUSQUEHANNA - UNIT 2 TRM / B 3.3-13 EFFECTIVE DATE 12/03/2004

Primary Containment Closed System Boundaries PPL Rev. 1 B 3.6.4 B 3.6.4 Primary Containment Closed System Boundaries BASES TRO A closed system used as a primary containment isolation boundary is defined as a piping system outside primary containment that does not communicate directly with the atmosphere outside primary containment, meets the design requirements of NUREG-75/087, (Reference 1), as described in FSAR Section 6.2.4 (Reference 2), and is considered an extension of primary containment.

The design of several containment penetrations relies upon a single Primary Containment Isolation Valve (PCIV) and a closed piping system outside primary containment (Primary Containment Closed System) as the two isolation barriers, as identified in Technical Specification (TS) Bases, Table B 3.6.1.3-1. For a given containment penetration that relies upon a closed system as the redundant containment isolation barrier, the closed system boundary is essentially equivalent to the ASME Class 2 boundary for the system/loop which contains the penetration. The closed system boundaries are defined by the Leakage Rate Test Program.

As a special case, the containment penetrations for the H202 analyzer lines also rely upon a closed system as the redundant containment isolation barrier, even though two PCIVs are provided for each of these penetrations. The PCIVs associated with these penetrations are identified in TS Bases Table B 3.6.1.3-1. The PCIVs in each H2 02 analyzer penetration are redundant to each other with regard to mechanical operation, but are not redundant with regard to electrical operation. Both PCIVs in each of these penetrations are powered from the same electrical division in order to prevent a single electrical failure from resulting in a loss of both divisions of H202 analyzers. This results in the valves being susceptible to a single electrical failure which could result in both valves failing open or failing to remain closed.

Because of this unique design consideration, the' H202 penetrations are equivalent to penetrations having a single PCIV, with the closed system providing the redundant isolation barrier.

Each division of the H202 analyzer piping has multiple flowpaths (e.g., upper drywell, lower drywell, drywell retum). These multiple flowpaths are interrelated and make up one closed system for each division. The tested closed system for each division is shown in the Leakage Rate Test Program.

For penetrations with a single PCIV, alteration of the corresponding closed system boundary during power operation is permitted provided that alteration does not impact the containment isolation function of the PCIV, [i.e., able to be closed (automatically or manually) or remain closed, and maintain leakage within that assumed in the design basis loss of coolant accident dose analysis.]

Conversely, if a PCIV is in a configuration where it is not capable of performing its containment isolation function (e.g., stuck open), then closed system integrity must be maintained in order to have at least one containment isolation barrier operable. These requirements also apply tothe H202 analyzer penetrations.

SUSQUEHANNA - UNIT 2 TRM I B 3.6-6 EFFECTIVE DATE 12/03/2004

Primary Containment Closed System Boundaries PPL Rey. 1 B 3.6.4 I I B 3.6.4 Primary Containment Closed System Boundaries BASES (continued)

TRO The APPLICABILITY is modified by a Note allowing Primary Containment I (continued) Closed System boundaries 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 communications with the control room. In this way, the Primary Containment Closed System can be rapidly Iisolated when a need for primary containment isolation is indicated.

Opening of closed system boundary valve periodically for specific activities that I require the valve to be opened (e.g., testing, venting) is not considered a breach of a closed system, provided the valve is operated under administrative control. Examples include the opening of a high point vent in the Core Spray system to verify that the system is filled with water or the opening of a H202 analyzer boundary valve to perform a functional test of the Post Accident Sampling System. Similarly, stroking of a boundary valve as part of restoration from maintenance activities associated with that valve does not constitute a breach of the closed system. Examples of this would be the stroking of a valve where the work that was done was replacement of the motor actuator, or other work where the pressure boundary of the valve was not violated. Also, the opening of a valve as a result of normal system operation/testing does not constitute a breach of the closed system.

SUSQUEHANNA - UNIT 2 TRM / B 3.6-7 EFFECTIVE DATE 12/31/2002

Primary Containment Closed System Boundaries PPL Rey. 1 B 3.6.4 B 3.6.4 Primary Containment Closed System Boundaries BASES (continued)

ACTIONS These ACTIONS are provided to address Conditions where Primary Containment Closed System boundaries are inoperable. When the Primary Containment Closed System boundaries are OPERABLE, but the associated PCIV(s) is inoperable, LCO 3.6.1.3, "Primary Containment Isolation Valves (PCIVs)," Condition C or Condition D would apply.

Note 1 has been added to provide clarification that, for the purpose of the TRO, separate Condition entry is allowed for each closed system. This is acceptable, since the Required Actions for each Condition provide appropriate compensatory actions for each inoperable closed system. Complying with Required Actions may allow for continued operation, and subsequent inoperable PCIVs or closed systems are governed by subsequent Condition entry and application of associated Required Actions.

The ACTIONS are modified by Notes 2 and 5. Note 2 ensures that appropriate remedial actions are taken, if necessary, if the affected system(s) are rendered inoperable by an inoperable closed system (e.g., an Emergency Core Cooling System subsystem is inoperable due to a failed open drain valve). Note 5 ensures appropriate remedial actions are taken when the primary containment leakage limits are exceeded. Pursuant to TRO 3.0.6, these actions are not required even when the associated TRO is not met. Therefore, Notes 2 and 5 are added to require the proper actions be taken when Primary Containment Closed System boundaries are inoperable.

Note 3 has been added to provide clarification that failing to complete the Required Actions results in a condition that could compromise Primary Containment Integrity and thus, place the plant in an unanalysed condition.

The ACTIONS are modified by Note 4 allowing penetration flow path(s) to be unisolated intermittently under administrative controls. This note applies to a condition where the closed system is inoperable. It does not apply to a situation where a penetration flowpath is normally open and the closed system is OPERABLE (such as the RHR and Core Spray minimum flow return lines),

since that represents the normal design configuration. Administrative 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.

SUSQUEHANNA -UNIT22 TRM / B 3.6-8 UTEFFECTIVE DATE 12/31/2002

Primary Containment Closed System Boundaries PPL Rey. 1 B 3.6.4 B 3.6.4 Primary Containment Closed System Boundaries BASES (continued)

ACTION A.1.1. A.1.2. A.2.1. and A.2.2 (continued)

With one or more penetration flow paths with its Primary Containment Closed System boundary inoperable, the affected portion of the closed system piping must be isolated from the rest of the closed system and the primary containment This Condition only applies when the associated PCIV for the penetration flow path is OPERABLE. For the penetration flow paths associated with the H2 02 analyzers, both PCIVs must be OPERABLE. The method of isolation must include the use of at least one isolation baruier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed arid de-activated automatic valve, a closed manual valve, and a blind flange. Closing an intervening valve' between the breach in the closed system and the open penetration is permitted when the penetration PCIV is OPERABLE. Ifno intervening valve exists between the closed system breach and the PCIV, then the PCIV must be closed and deactivated to ensure compliance with LCO 3.6.1.1, "Primary Containment." For the penetration flow paths associated with the H2 02 analyzers, one PCIV must be closed and deactivated. Deactivation of the H2 02 analyzer PCIVs is discussed in the TS Bases for LCO 3.6.1.3, Condition D.-

The Required Actions to isolate the closed system breach, or the penetration, 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. 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 consistent with LCO 3.6.1.3, Condition A, which applies to penetration flow paths with two PCIVs. The Primary Containment Closed System boundary is considered to be the functional equivalent to the ASME Class 2 boundary for the system/loop which contains the penetration. Because this boundary serves as the second barrier required by General Design Criteria 55 and 56 (Ref. 3) in lieu of a second isolation valve, the same Required Actions and associated Completion Times are appropriate.

For inoperable closed system boundaries where the breach has been isolated from the rest of the closed system and primary containment (Required Action A.1.1), or where the penetration has been isolated by a closed and deactivated PCIV (Required Action A.1.2), 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" is consistent with LCO 3.6.1.3, Condition A, and is appropriate because the devices are operated under administrative controls and the probability of their misalignment is low.

SUSQUEHANNA - UNIT 2 TRM / B3.6-9 EFFECTIVE DATE 12/31/2002

Closed System Boundaries Primary Containment I . .Primary Containment Closed System Boundaries PPL Rey. 1 B 3.6.4 B 3.6.4 Primary Containment Closed System Boundaries BASES (continued)

ACTION B.1 and B.2 (continued)

With one or more penetration flow paths with its Primary Containment Closed System boundary inoperable, 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 /> when the corresponding PCIV for the penetation flow path is also inoperable. For the penetration flow paths associated with the H202 analyzers, this Condition applies when one or both PCIVs are inoperable.

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 LCO 3.6.1.3, Condition B, which applies to penetration flow paths with two PCIVs, both of which are inoperable. Alternatively, immediate entry into the applicable Conditions and Required Actions of LCO 3.6.1.1 is permitted.

C.1 If the Required Actions and associated Completion Times of Conditions A or B cannot be met, immediate entry into LCO 3.6.1.3, Condition G or H, is directed.

The appropriate Condition to enter is determined by the operating MODE of the unit at the time of entry.

TRS TRS 3.6.4.1 The boundaries for water filled closed systems are verified to be intact by direct observation, during operator rounds, of the lack of leakage from the system (which is under pressure from the keepfill system), or by observed integrity during functional testing as required by the applicable LCO; and by the system boundary administrative controls (i.e., by procedure and checkoff lists for evolutions that affect the system boundary). The integrity of a closed system boundary, verified in accordance with the methodologies described above, is not compromised throughout the effective surveillance period by the subsequent isolation of the keepfill system and/or depressurization of a closed system.

The boundaries for air filled closed systems are verified to be intact by verification that no work has been performed since the last leak rate test in accordance with TRS 3.6.4.2, and by the system boundary administrative controls (i.e., procedure and checkoff lists for evolutions-that affect the system boundary).

The Frequency corresponds to the Inservice Testing Program requirements for performing valve testing at least once every 92 days.

SUSQUEHANNA - UNIT 2 TRM /B 3.6-10 EFFECTIVE DATE 12/31/2002

Primary Containment Closed System Boundaries PPL Rev. I B 3.6.4 B 3.6.4 Primary Containment Closed System Boundaries BASES (continued)

TRS TRS 3.6.4.2 (continued)

When restoring a closed system, testing must be performed to verify system integrity. Explicit quantification of the leakage is not required for water filled closed systems. However, testing must be sufficient to assure that an essentially leaktight barrier exists (no gross leakage). For air filled closed systems, explicit leakage quantification is required, and is performed in accordance with the Leakage Rate Test Program. I The Frequency of testing is in accordance with the Leakage Rate Test I Program.

REFERENCES 1. NUREG-75/087, Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants", September 1975.

2. FSAR Section 6.2.4, "Containment Isolation System."

3. 10 CFR 50, Appendix A, "General Design Criteria for Nuclear Power Plants."'

SUSQUEHANNA - UNIT 2 TRM / B3.6-11 EFFECTIVE DATE 12/31/2002

Snubbers PPL Rev. 1 B 3.7.8 B 3.7.8 . Snubbers BASES TRO All snubbers are required to be OPERABLE to ensure that the structural integrity of the reactor coolant system and all other safety-related systems is maintained during and following a seismic or other event initiating dynamic loads. Snubbers excluded from this inspection program are those installed on non-safety-related systems and then only if their failure or failure of the system on whicht they are installed would have no adverse effect on any safety-related system.

Snubbers are required to be OPERABLE whenever they are considered necessary to support equipment for the systems on which they are installed.

'Type' of snubber shall mean snubbers of the same design and manufacturer, irrespective of capacity. For example, mechanical snubbers utilizing the same design features of the 2-kip, and 100-kip capacity manufactured by Company 'A' are of the same type. The same design mechanical snubbers manufactured by company "B" for the purposes of this Technical Requirement would be of a different type, as would hydraulic snubbers from either manufacturer.

A list of individual snubbers with detailed information of snubber'

-location and size and of system affected shall be available at the plant in accordance with Section 50.71 (c) of 10 CFR part 50. The controlled list of plant snubbers is maintained in by the ISI Program. The addition or deletion of any snubber shall be made in accordance with Section 50.59 of 10 CFR Part 50.

(continued)

SUSQUEHANNA - UNIT 2 B 3.7-24 EFFECTIVE DATE 8131/1998

Snubbers PPL Rev. 1 B 3.7.8 B 3.7.8 Snubbers BASES (continued)

ACTIONS The Actions are defined to ensure proper corrective measures are taken in response to the inoperable components.

Condition A The removal or inoperability of one or more snubbers or one or more sets of parallel pair snubbers on an OPERABLE system requires the supported system to be immediately declared inoperable.

For the snubbers found inoperable, an engineering evaluation shall be performed on the components to which the inoperable snubbers are attached. The purpose of this engineering evaluation shall be to determine ifthe components to which the inoperable snubbers are attached were adversely affected by the inoperability of the snubbers in order to ensure that the component remains capable of meeting the designed service.

If prior to the removal or inoperability of one snubber or one set of parallel pair snubbers on an OPERABLE system, an engineering evaluation has been performed on the system to which the snubber is attached and the engineering evaluation determines that there are no adverse affects on the system with the snubber either removed or inoperable, then the removed or inoperable snubber must be repaired or replaced within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

Replacement snubbers and snubbers which have repairs which might affect the functional test shall be tested to meet the functional test criteria before installation in the unit Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service, and the freedom of motion test must have been performed within 12 months before being installed in the unit.

Condition D Potentially damaging transients are determined from a review of operational data and a visual inspection of the systems.

(continued)

SUSQUEHANNA - UNIT 2 TRM I B 3.7-25 EFFECTIVE DATE 12103/2004

Snubbers PPL Rev. 1 B 3.7.8 B 3.7.8 Snubbers BASES (continued)

TRS The TRSs are defined to be performed at the specified Frequency to ensure that the snubbers are maintained OPERABLE. Permanent or other exemptions from the surveillance program for individual snubbers may be granted by the Commission if a justifiable basis for exemption is presented and, if applicable, snubber life destructive testing was performed to qualify the snubbers for the applicable design conditions at either the completion of their fabrication or at a subsequent date.

Snubbers so exempted shall be listed in the list of individual snubbers indicating the extent of the exemptions.

TRS 3.7.8.1 The visual inspection frequency is based upon maintaining a constant level of snubber protection to systems. Therefore, the required inspection varies inversely with the observed snubber failures and is determined by the number of inoperable snubbers found during an inspection.. GenericLetter 90-09 provides a method for determining the next interval for the visual inspection of snubbers based upon the number of unacceptable snubbers found during the previous inspection, the total population or category size for each snubber type, and the previous inspection interval.

The visual inspection interval for a snubber population shall be determined based upon the previous inspection interval and the number of unacceptable snubbers found during that interval. Snubbers are categorized as inaccessible or accessible during reactor operation.

Each of these categories (inaccessible and accessible) may be inspected independently according to the schedule determined by Table 3.7.8-1. The visual inspection interval for each type of snubber shall be determined based upon the criteria provided in Table 3.7.8-1..

(continued)

SUSQUEHANNA - UNIT 2 B 3.7-26 EFFECTIVE DATE 8131/1998

Snubbers PPL Re.y. 1 B 3.7.8 B 3.7.8 Snubbers BASES (continued)

TRS (continued) Snubbers may be categorized, based upon their accessibility during power operation, as accessible or inaccessible, and are inspected on that basis: The snubber population, for the purpose of visual inspection, is determined either separately or jointly for accessible and inaccessible units. The results of snubber examinations are judged, per Table 3.7.8-2, in accordance with that population. The decision whether to combine the category populations or keep them separate must be documented before any inspection, and that decision shall be used as the basis upon which to determine the subsequent inspection interval for that category.

The accessibility of each snubber shall be determined and approved by the Plant Operations Review Committee. The determination shall be based upon the existing radiation levels and the expected time to perform a visual inspection upon the existing radiation levels and the expected time to perform a visual inspection in each snubber location as well as other factors associated with accessibility during plant operations (e.g. temperature, atmosphere, location, etc.), and the recommendations of Regulatory Guides 8.8 and 8.10.

Visual inspections shall verify that (1)the snubber has no visible indications of damage or impaired OPERABILITY, (2) attachments to the foundation or supporting structure are functional, and (3) fasteners for the attachment of the snubber to the component, and to the snubber anchorage are functional.

(continued)

SUSQUEHANNA - UNIT 2 B 3.7-27 EFFECTIVE DATE 8/31/1998

Snubbers PPL Rev. 1 B 3.7.8 B 3.7.8 Snubbers BASES (continued)

TRS (continued) Snubbers which appear inoperable as a result of visual inspections shall be classified as unacceptable and may be reclassified acceptable for the purpose of establishing the next visual inspection interval, provided that (1) the cause of the rejection is clearly established and remedied for that particular snubber and for other snubbers irrespective of type that may be generically susceptible; and (2) the affected snubber is functionally tested in the as-found condition and determined OPERABLE per TRS 3.7.8.2. A review and evaluation shall be performed and documented to justify continued operation with an unacceptable snubber. If continued operation cannot be justified; the snubber shall be declared inoperable and the ACTION requirements shall be met.

TRS 3.7.8.2 A representative sample of snubbers shall be tested for each type of snubber. The representative sample selected for the functional test sample plans shall be randomly selected from the snubbers of each type and reviewed before beginning the testing. The review shall ensure as far as practical that they are representative of the various configurations, operating environments, range of size, and capacity of snubbers of each type.

Functional Test Acceptance Criteria The snubber functional test shall verify that:

1. Activation (restraining action) is achieved within the specified range in both tension and compression;

2. Snubber bleed, or release rate where required, is present in both tension and compression, within the specified range; (continued)

SUSQUEHANNA - UNIT 2 .B 3.7-28 EFFECTIVE DATE 8/31/1998

Snubbers PPL Rey. 1 B 3.7.8 B 3.7.8 Snubbers BASES (continued)

TRS (continued) 3. Where required, the force required to initiate or maintain motion of the snubber is within the specified range in both directions of travel; and

4. For snubbers specifically required not to displace under continuous load, the ability of the snubber to withstand load without displacement.

Testing methods may be used to measure parameters indirectly or parameters other than those specified if those results can be correlated to the specified parameters through established methods.

TRS 3.7.8.3 The maximum, expected service life for various seals, springs, and other critical parts shall be determined and established based on engineering information and shall be extended or shortened based on monitored test results and failure history. Critical parts shall be replaced so that the maximum service life will not be'exceeded during a period when the snubber is required to be OPERABLE. The parts replacements shall be documented and the documentation shall be retained in accordance with FSAR 17.2.17.

The service life of a snubber is evaluated via manufacturer input and information through consideration of the snubber service conditions and associated installation and maintenance records (newly installed snubber, seal replaced, spring replaced, in high radiation area, in high temperature area, etc.). The requirement to monitor the snubber service life is included to ensure that the snubbers periodically undergo a performance evaluation in view of their age and operating conditions.

These records will provide statistical bases for future consideration of snubber service life.

(continued)

SUSQUEHANNA - UNIT 2 B 3.7-29 EFFECTIVE DATE 8/31/1998

Snubbers PPL Rey. I B 3.7.8 B 3.7.8 Snubbers BASES (continued)

TRS TRS 3.7.8.5 (continued)

The required inspection consists of the following elements:

1. Perform a visual inspection of all affected snubbers.

2. Verify freedom of motion of mechanical snubbers by manually induced snubber movement, or

3. Verify freedom of motion of mechanical snubbers by evaluation of in-place snubber piston setting, or Verify freedom of motion of mechanical snubbers by stroking the mechanical snubber through its full range of travel.

REFERENCES 1. Generic Letter 90-09 SUSQUEHANNA - UNIT 2 B 3.7-30 EFFECTIVE DATE 8131/1998

Control Structure HVAC PPL Rey. 1 B 3.7.9 B 3.7.9 Control Structure HVAC BASES TRO Control structure HVAC systems have safety related functions to maintain the required air pressure control in the building and maintain the heating and cooling of support equipment required to mitigate a Loss of Coolant Accident. The Control Structure and Computer Room ventilation fans are required to maintain the habitability envelope at a positive pressure (i.e., > 0" wc) and also to perform a heating and/or cooling function. The operation and surveillance requirements of the ventilation fans to maintain the habitability envelope at a positive pressure during CREOAS operation are discussed in TS 3.7.3. The heating and/or cooling function is addressed in this TRO. At least one train of each system is required for these purposes.

Technical Specification LCOs 3.7.3 and 3.7.4 address operating and surveillance requirements for the Control Room Emergency Outside Air Supply System and the Control Room Floor Cooling System.

The SGTS Room Cooling and Heating systems are essential to maintain the normal and post accident environment of the Control Structure Elevation 806 within acceptable design temperature limits.

CREQASS, SGTS, and Control Structure Chilled Water equipment is located on Control Structure Elevation 806.

The Computer Room Floor Cooling System's function is to maintain the computer room environment within acceptable design temperature limits. The system also maintains the habitability envelope pressure within limits. The Computer Room Floor Cooling System consists of two independent, redundant subsystems that provides cooling of recirculated computer room air. Each subsystem consists of cooling coils, fans, chillers, compressors, ductwork, dampers and instrumentation and controls to provide computer room temperature control.

The Control Structure Heating and Ventilation System serves all elevations of the control structure except the control room, TSC, and elevation 697'. The system's function is to maintain temperature and habitability envelope pressure within acceptable limits. The Control Structure Heating and Ventilation System consists of two independent, redundant subsystems that provides cooling of recirculated control structure air. Each subsystem consists of cooling coils, fans, chillers, compressors, ductwork, dampers and instrumentation and controls to provide temperature control.

(continued)

SUSQUEHANNA -UNIT 2 TRM / B3.7-31 EFFECTIVE DATE 12/03/2004

Control Structure HVAC PPL Rey. 1 B 3.7.9 B 3.7.9 Control Structure HVAC BASES (continued)

TRO The Control Structure Chilled Water System functions to transfer heat (continued) from the Control Room Floor Cooling System, Computer Room Floor Cooling System, Control Structure Heating and Ventilation System, and the Unit 1 ESGRC units to the ESW system. The Control Structure Chilled Water System consists of two independent, redundant subsystems consisting of a centrifugal compressor, a chilled water pump, one emergency condenser water pump, cooling coils, closed expansion tank, air separator, interconnecting piping, valves and instrumentation and controls.

The Battery Room Exhaust System functions to maintain the battery room design temperature, design pressure, and hydrogen concentration within limits. The Battery Room Exhaust System consists of two independent; redundant subsystems consisting of fans,.

ductwork, dampers and instrumentation and controls.

ACTIONS The Actions are defined to ensure proper corrective measures are taken in response to the inoperable components. With one of the HVAC subsystems inoperable, the inoperable HVAC subsystem must be restored to OPERABLE status within 30 days. With the unit in this condition, the remaining OPERABLE HVAC subsystem is adequate to perform the cooling and/or heating function. However, the overall reliability is reduced because a single failure in the OPERABLE subsystem results in the loss of the HVAC function. The 30 day Completion Time is based on the consideration that the remaining subsystem can provide the required protection, and the availability of alternate nonsafety cooling methods.

TRS The TRS assures sufficient system functionality to ensure operation when called upon to perform its safety related function.

REFERENCES 1. FSAR Section 9.4.1

2. FSAR Section 9.2.12.1

.SUSQUEHANNA -UNIT 2 TRIV / B 3.7-32 EFFECTIVE DATE 03/09/2001

Spent Fuel Storage Pools PPL Rev. I B 3.7.10 B 3.7.10 Spent Fuel Storage Pools BASES TRO The design and licensing basis of SSES assumes that the Unit 1 and Unit 2 Spent Fuel Storage Pools (SFSP) are cross-connected through the Cask Storage Pit. This allows either Unit's Fuel Pool Cooling system and RHR Fuel Pool Cooling subsystem to provide cooling to the spent fuel stored in both units SFSP. In addition, cross-connected SFSP's allow make up water to be added to either units SFSP. If the SFSP are not cross-connected through the Cask Storage Pit, certain conditions must be maintained to assure the fuel pools remain within analyzed conditions. This TRO defines the required conditions and the actions required should the conditions not be met The conditions applicable to SFSP's that are not cross-connected are:

a. The Unit 2 SFSP water temperature is less than or equal to 115 "F. The Fuel Pool Cooling system analyses assume the fuel pool temperature is less than or equal to 115 0F. Normally, the Fuel Pool Cooling system is used to maintain the fuel pool temperature less than or equal to 115 OF.

b. Both subsystems of the ESW system must have at least one pump and the respective flow path to the SFSP to be considered OPERABLE for the ESW system fuel pool supply function. The ESW system provides the only safety-related source of make-up water to the SFSP.

c. The RHR Fuel Pool Cooling subsystem provides a safety-related source of cooling to the SFSP. The RHR Fuel Pool Cooling subsystem is considered OPERABLE when one of the pumps, one of the heat exchangers, associated piping, valves, instrumentation and controls are OPERABLE. Note that this cannot be the same set of equipment (pump, heat exchanger, piping, valves etc.) credited for an OPERABLE RHR Suppression Pool Cooling subsystem.

(continued)

.SUSQUEHANNA - UNIT 2 TRM I B 3.7-33 EFFECTIVE DATE 04/15/2003

Spent Fuel Storage Pools PPL Rev, 1 B 3.7.10 B 3.7.10 Spent Fuel Storage Pools BASES (continued)

TRO d. RHR must have one subsystem of Suppression Pool Cooling (continued) OPERABLE. One subsystem of RHR Suppression Pool Cooling is considered OPERABLE when one of the pumps, one of the heat exchangers, associated piping, valves, instrumentation and controls are OPERABLE. Note that this cannot be the same set of equipment (pumps, heat exchanger, piping, valves etc.) credited for an OPERABLE RHR Fuel Pool Cooling subsystem. A subsystem of RHR Suppression Pool Cooling is required to be available post accident to provide cooling for the reactor vessel while RHR Fuel Pool Cooling is providing cooling to the fuel pool.

e. Zone II is capable of being aligned to the Recirculation Plenum.

Alignment of the Unit 2 Reactor Building to the recirculation plenum is assumed in the analyses. This assures adequate distribution of the refueling floor environment should the fuel pool temperature exceed 115 "F.

APPLICABILITY The APPLICABILITY is modified to permit isolating SFSPs from the cask storage pit when the analyzed nominal decay heat in one SFSP is

• 5.1 x 106 Btu/hr, concurrent with a nominal decay heat of

• 4.0 x 106 I Btu/hr in the other SFSP. For example, if the Unit 1 SFSP analyzed nominal decay heat is 4.5 X10 6 Btu/hr, then the Unit 2 SFSP analyzed nominal decay heat must be < 4.0 x 106 Btulhr in order for the SFSPs to I not be cross-connected through the cask storage pit The manner in which this value is determined is specified in Reference 1, and is consistent with the SSES design and licensing basis. With a SFSP nominal decay heat less than this value, sufficient time will exist to implement the actions required to cross-connect the SFSPs and prevent boiling in the event of a Design Basis Loss of SFP Cooling event. This also ensures compliance with licensing bases requirements regarding the evaluation of this event prior to isolating the SFSPs.

(continued)

SUSQUEHANNA - UNIT 2 .TRM / B 3.7-34 EFFECTIVE DATE 12/03/2004

Spent Fuel Storage Pools PPL Rev. 1 B 3.7.10 B 3.7.10 Spent Fuel Storage Pools BASES (continued)

ACTIONS The listed ACTIONS ensure that should the-fequired conditions not be maintained, the required conditions be restored in sufficient time to preclude fuel pool boiling and to minimize the impact of a fuel pool with water temperatures greater than 115 "F.

The completion time for Condition A of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is a reasonable time to restore adequate cooling to the SFSP and restore the fuel pool temperature less than or equal to the 115 0F limit. This 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> completion time takes into account the low probability of an event occurring during this period that could prevent reestablishing adequate fuel pool cooling.

The completion times specified for the Conditions B, C, D, and E account for the low probability of an event occurring during the period that could cause the loss of adequate fuel pool cooling. The completion time for Condition B is more restrictive since ESW is required to raise fuel pool level so that cooling systems can be operated.

ACTIONS Action F is required to be taken to cross-connect the SFSP's so that (continued) cooling can be provided should an event result in loss of fuel pool cooling.

TRS The TRS's are defined to be performed at the specified frequency to ensure that the required conditions are maintained while the SFSP's are not cross-connected.

REFERENCES 1. Safety Evaluation NL-00-029

2. FSAR Section 9.1.3 SUSQUEHANNA - UNIT 2 TRM I B 3.7-35 EFFECTIVE DATE 07/05/2000.

Dose Rate PPL Rev. 1 B 3.11.2.1 B 3.11.2.1 Dose Rate BASES TRO This requirement provides reasonable assurance that radioactive material discharged in gaseous effluents will not result in the exposure of a Member of the Public either within or outside the Site Boundary, in excess of the design objectives of Appendix I to 10CFR50. It provides operational flexibility for releasing gaseous effluents while satisfying section ll.B and I.C design

-objectives of Appendix I. For individuals who may at times be within the Site Boundary, the occupancy of the individual will usually be sufficiently low to compensate for any increase in atmospheric diffusion factor above that for the Site Boundary. The specified release rate limits restrict, at all times, the corresponding dose rates above background to a Member of the Public at or beyond the Site Boundary to less than or equal to 500 mrem/yr to the total body or to less than or equal to 3000 mrem/yr to the skin. These release rate limits also restrict, at all times, the corresponding thyroid dose rate above background to an individual via the inhalation pathway to less than or equal to 1500 mremnyr. These limits provide reasonable assurance that radioactive material discharged in gaseous effluents will not result in the exposure of a

• MEMBER OF THE PUBLIC either within or outside the SITE BOUNDARY, to annual average concentrations exceeding the limits specified in Appendix B, Table II of 10 CFR Part 20. (Reference 3)

This Requirement applies to the release of gaseous effluents from all reactors at the site.

This section of the TRM is also part of the ODCM (Reference 2).

(continued)

SUSQUEHANNA - UNIT 2 TRIVI/ B3.11-12 EFFECTIVE DATE 2101/1999

Dose Rate PPL Re.1. I B 3.11.2.1 B 3.11.2.1 Dose Rate BASES (continued)

Actions The Actions are defined to ensure proper corrective measures are taken in response to the limits being exceeded.

TRS The TRSs are defined to be performed at the specified Frequency to ensure that the dose rates are maintained within limits. Dose rates are determined in accordance with the methodology and parameters of the ODCM.

Table 3.11.2.1-1 defines Radioactive Gaseous Waste Sampling and Analysis Program. The lower limit of detection (LLD) is defined, for purposes of these requirement, as the smallest concentration of radioactive material in a sample that will yield a net count, above system background, that will be detected with 95% probability with only 5% probability of falsely concluding that a blank observation represents a "real" signal. For a particular measurement system, which may include radiochemical separation:

4.66Sb n=-=

E V 2.22E6* Y exp(-AAt)

Where:

LLD is the a porilower limit of detection as defined above (as microcuries per unit mass or volume),

Sb is the standard deviation of the background counting rate or of the counting rate of a blank sample as appropriate (as counts per minute),

E is the counting efficiency, as counts per disintegration, V is the sample size, in units of mass or volume, 2.22 E6 is the number of disintegrations per minute per microcurie, Y is the fractional radiochemical yield, when applicable, A is the radioactive decay constant for the particular radionuclide, and At for plant effluents is the elapsed time between the midpoint of sample collection and time of counting (for plant effluents, not environmental samples).

(continued)

SUSQUEHANNA - UNIT 2 TRM / B 3.11-13 EFFECTIVE DATE 2/01/1999

Dose Rate PPL Rev. 1 B 3.11.2.1 B 3.11.2.1 Dose Rate' BASES (continued)

TRS The value of Sb used in the calculation of the LLD fqr a detection system shall (continued) be based on the actual observed variance of the background counting rate or of the counting rate of the blank samples (as appropriate) rather than on an unverified theoretically predicted variance. Typical values of E, V, Y, and At shall be used in the calculation.

The principal gamma emitters for which the LLD specification applies include the following radionuclides: Kr-87, Kr-88, Xe-133, Xe-133m, Xe-135, Xe-135m and Xe-138 for gaseous emissions and Mn-54, Fe-59, Co-58, Co-60, Zn-65, Mo-99, Cs-134, Cs-137, Ce-141 and Ce-144 for particulate emissions. This list does not mean that only these nuclides are to be considered. Other gamma peaks which are identifiable, together with those of the above nuclides, shall also be analyzed and reported in the Radioactive Effluent Release Report.

-The design of the systems for the sampling of particulates and iodines provide for sample nozzle entry velocities which are approximately isokinetic with instack air velocities. Gaseous particulate and iodine samples are gathered continuously, with the sample size proportional to the stack emissions; a composite gaseous sample is a combination of all the particulate filters gathered in a sampling period.

Particulate or iodine sampling required to be in continuous service will be considered to remain and have been in continuous service when its service is interrupted for a time period not to exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per sampling period. For particulate and iodine sampling, this is a small fraction of the normal minimum analysis frequency.

The minimum Analysis Frequency as listed for the Composite Samples shall mean the minimum frequency for initiation of the required analyses, not completion of the analysis and evaluation of the results. Since the analysis

• involves sending the samples to an offsite laboratory and performance of involved sample preparation and wet chemical analyses, there will be a delay.

between initiation of the analysis and receipt of the results. The analysis initiation shall normally be done on a calendar quarter for a 92 day frequency.

(continued)

SUSQUEHANNA - UNIT 2 TRM/133.11-14 EFFECTIVE DATE 12/03/2004

Dose Rate PPL Rev. 1 B 3.11.2.1 B 3.11.2.1 Dose Rate BASES (continued)

REFERENCES 1. Technical Specification 5.5.4 - Radioactive Efluent Controls Program

2. Technical Specification 5.5.1 - Offsite Dose Calculation Manual

3. 10CFR Part 20 SUSQUEHANNA -,UNIT 2 TRM / B3.11-15 EFFECTIVE DATE 2/01/1999

Monitoring Program PPL Rey.1 B 3.11.4.1 B 3.11.4.1 Monitoring Program BASES TRO The radiological environmental monitoring-program required by this Requirement provides representative measurements of radiation and of radioactive materials in those environmental exposure pathways and for those radionuclides that lead to the highest potential radiation exposures of MEMBERS OF THE PUBLIC resulting from the station operation. This monitoring program thereby supplements the radiological effluent monitoring program by verifying that the measurable concentrations of radioactive materials and levels of radiation are not higher than expected on the basis of the effluent measurements and modeling of the environmental exposure pathways. Changes to the radiological environmental monitoring program specified in Table 3.11.4.1-1 may be made based on expected SSES operation and the results of radiological environmental monitoring during SSES operation.

The required detection capabilities for environmental sample analyses are tabulated in terms of the lower limits of detection (LLDs). The LLDs required by Table 3.11.4.1-3 are considered optimum for routine environmental measurements in industrial laboratories. It should be recognized that the LLD is defined as an a priori(before the fact) limit representing the capability of a measurement system and not as an a postefiori (after the fact) limit for a particular measurement.

Detailed discussion of the LLD, and other detection limits, can be found in H-IASL Procedures Manual, HASL-300 (revised annually); Currie, L. A., "Limits for Qualitative Detection and Quantitative Determination - Application to Radiochemistry" Anal. Chem. 40, 586-93 (1968); and Hartwell, J. K, "Detection Limits for Radioanalytical Counting Techniques," Atlantic Richfield Hanford Company Report ARH-SA-215 (June 1975). (Reference 1)

This section of the TRM is also part of the ODCM (Reference 2).

Actions The Actions are defined to ensure proper corrective measures are taken when

• requirements are not met.

(continued)

SUSQUEHANNA -UNIT 2 TRM / B3.11-28 EFFECTIVE DATE 8131/1998

Monitoring Program PPL Rey.1 B 3.11.4.1 B 3.11.4.1 Monitoring Program BASES (continued)

ACTIONS Per Action A.1, the Annual Radiological Environmental Operating Report shall (continued) provide a description of the reasons for not conducting the program as required and the plans for preventing a recurrence.

The Special Report submitted per Action B.1 shall identify the cause(s) for exceeding the limit(s) and define the corrective actions to be taken to reduce radioactive effluents so that the potential annual dose to a MEMBER OF THE PUBLIC is less than the calendaryear limits of Requirements 3.11.1.2, 3.11.2.2 and 3.11.2.3.

Include revised figure(s) and table for the ODCM reflecting the new locations for obtaining samples per Action F.1 in the next Radioactive Effluent Release ReporL TRS The TRSs are defined to be performed at the specified frequency to ensure that the requirements are implemented. Monitoring samples collected per TRS 3.11.4.1.1 shall be from the specific locations given in the table and figure in the ODCM. (Reference 2)

Table 3.11.4.1-1 Sample Locations Specific parameters of distance and direction sector from the centerline of one reactor, and additional description where pertinent, shall be provided for each and every sample location in this Table and in a table and figure(s) in the ODCM. Refer to NUREG-0133, "Preparation of Radiological Effluent Technical Specifications for Nuclear Power Plants," October 1978, and to Radiological Assessment Branch Technical Position, Revision 1, November 1979. (Reference 3) Deviations are permitted from the required sampling schedule if specimens are unobtainable due to hazardous conditions, seasonal unavailability, malfunction of automatic sampling equipment and other legitimate reasons. If specimens are unobtainable due to sampling equipment malfunction, every effort shall be made to complete corrective action prior to the end of the next sampling (continued)

SUSQUEHANNA - UNIT 2 TRM / B3.11-29 EFFECTIVE DATE 12/03/2004

Monitoring Program PPL Rey. 1 B 3.11.4.1 B 3.11.4.1 Monitoring Program BASES (continued)

TRS period. All deviations from the sampling schedule shall be documented in the (continued) Annual Radiological Environmental Operating Report. It is recognized that, at times, it may not be possible or practicable to continue to obtain samples of the media of choice at the most desired location or time.

In these instances suitable alternative media and locations may be chosen for the particular pathway in question and appropriate substitutions made within 30 days in the radiological environmental monitoring program. Identify the cause of the unavailability of samples for that pathway and identify the new location(s) for obtaining replacement samples in the next Radioactive Effluent Release Report and also include in the report a revised figure(s) and table for the ODCM reflecting the new location(s).

Direct Radiation One or more instruments, such as a pressurized ion chamber, for measuring and recording dose rate continuously may be used in place of, or in addition to, integrating dosimeters. For the purposes of this table, a thermoluminescent dosimeter (TLD) is considered to be one phosphor, two or more phosphors in a packet are considered as two or more dosimeters. Film badges shall not be used as dosimeters for measuring direct radiation.

Radioiodine and Particulates - Sampling and Collection Frequency The charcoal cartridges used in the airborne radioiodine sampling conducted as part of the radiological environmental monitoring program are designed and tested by the manufacturer to assure a high efficiency in-the capture of radioiodine. Certificates from the manufacturer of the cartridges are provided with each batch of cartridges certifying the percent retention of the radiodine for stated airflows.

Radioiodine and Particulates - Particulate SamDle: Waterbome -Surface.

Ground. Sediment: Food Products Gamma isotopic analysis means the identification and quantification of gamma- emitting radionuclides that may be' attributable to the effluents from the facility.

Waterbome - Surface The "upstream sample" shall be taken at a distance beyond significant influence of the discharge. The "downstream" sample shall be taken in the discharge line.

(continued)

SUSQUEHANNA - UNIT 2 ITRM / B3.11-30 EFFECTIVE DATE 12/03/2004

Monitoring Program PPL Rey.n 1

• _ e B 3.11.4.1 B 3.11.4.1 Monitoring Program BASES (continued)

TRS Waterbome - Drinking - Sampling and Collection Freauencv A composite (continued) sample is one in which the quantity (aliquot) of liquid sampled is proportional to the quantity of flowing liquid and in which the method of sampling employed results in a specimen that is representative of the liquid flow. In this program

• composite samples shall be collected at time intervals that are very short (e.g.,

hourly) relative to the compositing period (e.g., monthly) in order to assure obtaining a representative sample.

Waterbome - Ground - Samples and Sample Locations Groundwater samples shall be taken when this source is tapped for drinking or irrigation purposes in areas where the hydraulic gradient or recharge properties are suitable for contamination.

Drinking Water- 1-131 Analyses Calculation of the dose projected from. 1-131 in drinking water to determine if 1-131 analyses of the water are required shall be performed for the maximum organ and age group using the methodology and parameters of the ODCM.

Food Products - Sampling and Collection Frequency If harvest occurs more than once a year, sampling shall be performed during each discrete harvest If harvest occurs continuously, sampling shall be monthly. Attention shall be paid

• to including samples of tuborous and root food products.

Table 3.11.4.1-3 This list does not mean that only these nuclides are to be considered. Other peaks that are identifiable at 95% confidence level together with those of the above nuclides, shall also be analyzed and reported in the Annual Radiological Environmental Operating report.

Required detection capabilities for thermoluminescent dosimeters used for environmental measurements are given in Regulatory Guide 4.13.

(Reference 4)

(continued)

SUSQUEHANNA - UNIT 2 .TRM/ B3.11-31 EFFECTIVE DATE 813111998

Monitoring' Program PPLRev. I -B 3.11.4.1 B 3.11.4.1 Monitoring Program BASES (continued)

TRS The LLD is defined, for purpose of these Requirements, as the smallest (continued) concentration of radioactive material in a sample that will yield a net count (above system background) that will be detected with 95% probability with only 5% probability of falsely concluding that a blank observation represents a real" signal.

For a particular measurement system (which may include radiochemical separation):

LLD =

Ed V

• 2.22

• Y

• exp(-AAt)

Where:

LLD is the a priofi lower limit of detection as defined above (as picrocuries per unit mass or volume),

Sb is the standard deviation of the background counting rate or of the countingrate of a blank sample as appropriate (as counts per minute),

E is the counting efficiency, as counts per disintegration, V is the sample size, in units of mass or volume, 2.22 is the number of disintegrations per minute per picrocurie, Y is the fractional radiochemical yield, when applicable, X is the radioactive decay constant for the particular radionuclide, and At for environmental samples is the elapsed time between sample collection (or end of the sample collection period) and time of counting.

Typical values of E, V, Y, and At should be used in the calculation.

(continued)

SUSQUEHANNA - UNIT 2 TRM / B 3.1 1-32 EFFECTIVE DATE 8/31/1998

Monitoring Program PPL Rev. 1 B 3.11.4.1 B 3.11.4.1 Monitoring Program BASES (continued)

TRS It should be recognized that the LLD is defined as a priori (before the fact)

(continued limit representing the capability of a measurement system and not as an a posteriori (after the fact) limit for a particular measurement. Analyses shall be performed in such a manner that the stated LLDs will be achieved under routine conditions. Occasionally background fluctuations, unavoidably small sample sizes, the presence of interfering nuclides, or other uncontrollable circumstances may render these LLDS unachievable. In such cases, the contributing factors shall be identified and described in the Annual Radiological Environmental Operating Report.

REFERENCES 1. HASL Procedures Manual, HASL-300 (revised annually); Curie, LA.,

"Limits for Qualitative Detection and Quantitative Determination -

Application to Radiochemistry" Anal. Chem. 40, 586-93 (1968); and Hartwell, J. K, "Detection Limits for Radioanalytical Counting Techniques," Atlantic Richfield Hanford Company Report ARH-SA-215 (June 1975) Offsite Dose Calculation Manual.

2. Technical Specification 5.5.1 - Offsite Dose Calculation Manual

3. NUREG-0133, "Preparation of Radiological Effluent Technical Specifications for Nuclear Power Plants," October 1978, and to Radiological Assessment Branch Technical Position, Revision 1, November 1979

4. Regulatory Guide 4.13 SUSQUEHANNA - UNIT 2. TRM /B 3.11-33 EFFECTIVE DATE 8/31/1998