ML14339A451

Beaver Valley, Unit 2, Licensing Requirements Manual (Lrm), Revision 81

ML14339A451
Person / Time
Site:	Beaver Valley
Issue date:	11/24/2014
From:	FirstEnergy Nuclear Operating Co
To:	Office of Nuclear Reactor Regulation
Shared Package
ML14339A419	List: L-14-360, Firstenergy Nuclear Operation Company, Quality Assurance Program Manual, Revision 19 ML14339A408 ML14339A410 ML14339A411 ML14339A412 ML14339A413 ML14339A414 ML14339A415 ML14339A416 ML14339A417 ML14339A418 ML14339A420 ML14339A429 ML14339A430 ML14339A431 ML14339A433 ML14339A434 ML14339A435 ML14339A437 ML14339A438 ML14339A439 ML14339A440 ML14339A451 ML14339A452 ML14339A453 ML14339A454
References
L-14-360
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{{#Wiki_filter:Unit 2 Licensing Requirements Manual (LRM) Quick Index1.0 USE AND APPLICATION 1.0-11.0.1 General Description 1.0-11.0.2 LRM Revisions 1.0-21.1 Definitions 1.1-11.2 Logical Connectors 1.2-11 .3 Completion Times 1.3-1'1 .4 Frequency 1.4-13.0 LR APPLICABILIW 3.0.13.0 LRS APPLICABILITY 3.0.33.1 REACTIVITY CONTROL SYSTEMS 3.1.1-13.1.1 Boration Flow Paths - Shutdown 3.1.1-13.1.2 Boration Flow Paths - Operating 3.1.2-13,1.3 Charging Pump - Shutdown 3.1.3-13.1.4 Charging Pumps - Operating 3.1.4-13.1.5 Boric Acid Transfer Pumps - Shutdown 3.1.5-13.1.6 Boric Acid Transfer Pumps - Operating 3.1.6-13.1.7 Borated Water Sources - Shutdown 3.1.7-13.1.8 Borated Water Sources - Operating 3.1.8-13.1.9 Rod Position Indication System - Shutdown 3.1.9.13.1.10 Boron Dilution 3.1.10-13.1.11 Rod Position lndication System - Shutdown TestExceptions 3.1.11-13.3 INSTRUMENTATION 3.3.1.13.3.1 Reactor Trip System Instrumentation ResponseTimes 3.3.1-13.3.2 Engineered Safety Features Response Times3.3.2-13.3.3 Meteorological Monitoring lnstrumentation 3.3.3-13.3.4 Axial Flux Difference (AFD) Monitor Alarm 3.3.4-13.3.5 Quadrant Power Tilt Ratio (OPTR) Monitor Alarm3.3.5-13.3.6 Seismic Monitoring lnstrumentation 3.3.6-13.3.7 Movable Jncore Detectors 3.3.7-13.3.8 Leading Edge Flow Meter 3.3.8-13.3.9 Turbine Overspeed Protection 3.3.9-13.3.10 RTS, ESFAS, and Loss of Power Trip Setpoints3.3.10-13.3.'11 Fuel Storage Pool Area Radiation Monitor3.3.11-13.3.12 Explosive Gas Monitoring Instrumentation3.3.12-13.3.13 Containment Hydrogen Analyzers 3.3.13-13.3.14 Control Room lsolation Rad Monitors 3.3.14-13.3.15 Containment Area Radiation Alarm 3.3.15-13.3.16 Accident Monitoring lnstrumentation 3.3.16-13.4 REACTOR COOLANT SYSTEM (RCSI 3.4.1.13.4.1 Loop lsolation Valves - Shutdown 3.4.1-13.4.2 Chemistry 3.4.2-13.4.3 Pressurizer 3.4.3-13.4.4 DELETED3.4.5 RCS Head Vents 3.4.5-13.4.6 Pressurizer Safety Valve Lift Involving Loop Sealor Water Discharge 3.4.6-13.4.7 RCS Pressure lsolation Valves 3.4.7-13.6 CONTATNMENT 3.6.1-13.6.1 Containment lsolation Valves 3.6.1-13.6.2 Containment Sump 3.6.2-13.7 PLANT SYSTEMS 3.7.1.13].1 Steam Generator Pff Limitation 3.7.1-13.7.2 Flood Protection 3.7.2-13.7.3 Sealed Source Contamination 3.7.3-13.7.4 Snubbers 3.7.4-13.7.5 Standby Service Water System (SWE) 3.7.5-13.7.6 Explosive Gas Mixture 3.7.6-13.7.7 SLCRS 3.7.7-13.8 ELECTRICAL POWER SYSTEMS 3.8.1.13.8.1 125V D.C. Battery Banks Maint Rqmnts 3.8.1-13.8.2 EDG 2000 Hour Rating Limit 3.8.2-13.8.3 Main Fuel Oil Strg Tank Maint. Rqmnts 3.8.3-13.9 REFUELING OPERATIONS 3.9.1.13.9.1 Crane Travel - Spent Fuel Strg Pool Bldg 3.9.1-13.9.2 Manipulator Crane 3.9.2-13.9.3 Decay Time 3.9.3-15.0 ADMINISTRATIVE CONTROLS 5.1.15.'1 Core Operating Limits Report 5.1-15.2 Pressure and Temperature Limits Report 5.2-i5.3 Procedure Review and Approval 5.3-15.4 Record Retention 5.4-1BASESB 3.0 LR Applicability B 3.0-1B 3.0 LRS Applicability B 3.0-5B 3.1.1 - B 3.1.8 Boration Systems B 3.1.1-1B 3.1.9 Rod Position Indication - Shutdown B 3.1.9-1B 3.'1.10 Boron Dilution B 3.1.10-1B 3.1.11 Rod Pstn lnd Sys - Shtdn Test Exc B 3.1.11-1B 3.3.3 Meteorological Mntrng Instrumtn B 3.3.3-1B 3,3.4 AFD Monitor Alarm B 3.3.4-1B 3.3.5 QPTR Monitor Alarm B 3.3.5-1B 3.3.6 Seismic Monitoring Instrumentation B 3.3.6-1B 3.3.7 Movable lncore Detectors B 3.3.7-1B 3.3.8 Leading Edge Flow Meter B 3.3.8-1B 3.3.9 Turbine Overspeed Protection B 3.3.9-1B 3.3.11 Fuel Strg Pool Area Rad Monitor B 3.3.11-1B 3.3.12 Explosive Gas Mntrng lnstrumtn 83.3.12-1B 3.3.13 Containment Hydrogen Analyzers B 3.3.13-1B 3.3.14 Control Room Area Rad. Monitors B 3.3.14-1B 3.3.15 Containment Area Radiation Alarm B 3.3.15-1B 3.3.16 Accident Monitoring lnstrumentation B 3.3.16-1B 3.4.1 Loop lsolation Valves - Shutdown B 3.4.1-1B 3.4.2 Chemistry B 3.4.2-1B 3.4.3 Pressurizer B 3.4.3-1B 3.4.4 DELETEDB 3.4.5 Reactor Coolant System Head Vents B 3.4.5-1B 3.4.6 Press Sfty Vlv Lift Inv Lp Sl or Wtr Dsc B 3.4.6-1B 3.6.1 Containment lsolation Valves B 3.6.1-1B 3.6.2 Containment Sump B 3.6.2-1B 3.7.1 SG Pressure/Temperature Limitation B 3.7.1-1B 3.7.2 Flood Protection B 3.7.2-1B 3.7.3 Sealed Source Contamination B 3.7.3-1B 3.7.4 Snubbers B 3.7.4-1B 3 7.5 Standby Service Water System (SWE) B 3.7.5-1B 3.7.6 Explosive Gas Mixture B 3.7.6-1B 3.7.7 SLCRS B 3.7.7-1B 3.8.1 125V DC Battery Bnks Maint Rqmnts B 3.8.1-1B 3.8.2 Emer DG 2000 Hour Rating Limit B 3.8.2-1B 3.8.3 Main Fuel Oil Strg Tnk Maint Rqmnts B 3.8.3-1B 3.9.1 Crane Trvl - Spnt Fuel Strg Pool Bldg B 3.9.1-1B 3.9.2 Manipulator Crane B 3.9.2-1B 3 9.3 Decay Time B 3.9.3-1Revision 1 BVPS.2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation Date8114-0993.3.16-13.3.16-23.3.16-35t9114 BVPS-2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation Date7914-0715.2-i5.2-15.2-25.2-35.2-45.2-5 5.2-65.2-75.2-B5.2-95.2-105.2-115.2-125,2-135.2-14 5.2-155.2-16 5.2-175.2-185.2-195.2-205.2-215.2-225.2-235.2-245.2-255.2-265.2-275.2-284t18t14BO14-0165.1-15.1 -25.1-35.1-45.1-55.1-6 5.1-75.1-85.1-95.1-105.1-1 15.1-12 5.1-1 3 5.1-14512114 BVPS.2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation Date7713-125B 3.7.2-191251137813-20413-172B 3.7.2-15.2-)5.2-15.2-2 5.2-35.2-45.2-55.2-65.2-75.2-85.2-95.2-105.2-115.2-125.2-135.2-145.2-155.2-165.2-175.2-185.2-195.2-205.2-215.2-225.2-235.2-245.2-255.2-265.2-275.2-281216113See next page for Revision 79. BVPS.2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation Date7412-1765.1-15.1-25.1-35.1-45.1-5 5.1-6 5.1-75.1-85.1-95.1-10 5.1-115.1-125.1-135.1-1410t8t127512-264B 3.3.8-23t15t137613-04113-04113-04113-04113-04113-04113-04113-041 & 13-08413-04113-04113-04113-041' 13-04113-04113-04113-04113-04113-04113-04113-04113-04113-04113-041 & 13-08413-04113-04113-04113-041 & 13-08413-04113-041 & 13-0845.2-a5.2-15.2-25.2-35.2-45.2-55.2-65.2-75.2-85.2-95.2-10 5.2-115.2-125.2-135.2-145.2-155.2-165.2-175.2-185.2-195.2-205.2-215.2-225.2-235.2-24 5.2-25 5.2-26 5.2-275.2-285t24t13 BVPS.2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation Date67(continued)10-069B 3.4.4-1B 3.4.5-1B 3.7.?-1B 3.7.4-1B 3.7.4-2B 3.7.5-1B 3.7.7-1B 3.9. 1-1B 3.9.2-112t22t146811-00211-0113.4.2-25.1-15.1-25.1-35.1-45.1-55.1-65.1-75.1-85.1-95.1-105.1-115.1-125.1-135.1-143t18t116911-0053.7.5-1B 3.7.5-13t31t117011-074B 3.9.3-16t24t117111-1013.3.9-27t1t117212-0435.2-43t 16t 127312-0905.1-12 5.1-13518112 BVPS-2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation Date67(continued)10-0693.3.9-13.3.11-13.3.13-13.3.14-13.3.15-1 3.3.16-13.4.2-1 3.4.4-13.4.5-13.4.5-23.4.6-13.7.2-13.7.4-1 3.7.4-23.7.5-13.7.7-13.7.7-23.9.1-13.9.2-13.9.2-2B-iB-iiB 3.0-1 B 3.0-2B 3.0-3B 3.0-4B 3.0-5B 3.0-6B 3.0-7B 3.0-8B 3.0-9B 3.0-10B 3.1.1-1B 3.1.1-2B 3.1 .11-1B 3.3.3-1B 3.3.4-1B 3.3.5-1B 3.3.6-1B 3.3.7-1B 3.3.8-1B 3.3.9-1B 3.3.11-1B 3.3.13-1 B 3.3.14-1B 3.3.15-1B 3.3.16-112t22t10 BVPS.2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation Date6609-01909-1 253.6.1-145.1-15.1-25.1-35.1-45.1-55.1-65.1-7 5.1-85.1-95.1-105.1-115.1-125.1-135.1-1410t29t496710-069TOC page iTOC page ii1.1-13.0-13.0-33.1.1-13.1.1-2 3.1.2-13.1.2-23.1.3-13.1.3-23.1.4-13.1.4-23.1.5-13.1.6-13.1.7-1 3.1.7-23.1.8-13.1.8-23.1.9-13.1.11-13.1.11-23.3.3-13.3.4-13.3.5-13.3.6-1 3.3.6-2 3.3.7-13.3.8-13.3.8-212t22110 BVPS-2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation Date6207 -12008-1 073.3.14-15.2-l5.2-15.2-25.2-35.2-45.2-5 5.2-65.2-7 5.2-B5.2-95.2-105.2-115.2-125.2-135.2-145.2-155.2-165.2-17 5.2-185.2-195.2-205.2-215.2-225.2-235.2-245.2-255.2-265.2-275,2-2810t9t086309-01809-0053.3.9-23.8.1-14t27 tAg6409-0975.1-115.1-125.1-138t6/096508-18708-1 653.3.10-33.6.1-1 53.6.1-1710122109 BVPS-2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation Date5507-10707-17507 -19208-0093.1.3-13.1.5-13.1.6-15.2-33.1.3-2B 3.7.1-1a2ua85607-01808-045 08-02108-0371.1-13.3.2-33.3.10-43.3.10-55.1-15.1-25.1-3 5.1-45.1-55.1-65.1-75.1-B5.1-95.1-105.1-115.1-125.1-135.1-144t24t085708-0653.1.11-15t2ta85808-090B 3.3.8-1u4rcg5908-1213.3.9-2g 11 ta86008-1513.3.9-29/18/086108-1 583.3.9-29t24108 BVPS.2LICENSING REQUIREMENTS MANUALREVISION STATUSRevision NumberLRM Request NumberPages lssuedlmplementation DateAll previous RevisionNumbersAll previous LRM RequestNumbersAll LRM pages inold formatPrior to 612A20AT522-07907 -046All LRM pages inlmproved TechnicalSpecification format3.0-16t23t2AO75307 -0972-0743.3.14-23.7.4-13.7.4-2B 3.7.4-1B 3.7.4-29t18t20475407 -1223.7.4-13.7.4-33.7 .4-43.7.4-53.7.4-63.7.4-7 3.7.4-83.7.4-93.7.4-103.7.4-113.7 .4-123.7.4-133.7 .4-14B 3.7.4-2B 3.7.4-3 B 3.7.4-4B 3.7.4-5B 3.7.4-6B 3.7.4-7B 3.7 .4-8B 3.7.4-9B 3.7.4-10B 3.7 .4-11B 3.7.4-12B 3.7.4-13B 3.7.4-141Alnl2007 LICENSING REQUIREMENTS MANUALTABLE OF CONTENTSPage No.1.01.0.11 .0.21.11.21.31.43.0 3.03.33.3.13.3.23.3.33.3.43.3.53.3.63.3.73.3.83.3.93.3.103.3.113.3.123.3.13 3.3.1 43 3.153.3.16USE AND APPLICATIONGeneral Description... .... 1.0-1LRM Revisions..... 1.4-2Definitions...... .1.1-1Logical Connectors..... ....1.2-1Completion Times ..... ..... 1.3-1Frequency..... 1.4-13.1 REACTIVITY CONTROL SYSTEMS3.1 .1 Boration Flow Paths - Shutdown .. ..3.1.1-13.1 .2 Boration Flow Paths - Operating ... .3.1.2-13.1 .3 Charging Pump - Shutdown .. . 3.1.3-13.1.4 Charging Pumps - Operating.... ......3.1.4-13. 1 .5 Boric Acid Transfer Pumps - Shutdown .. ....... 3.1 .5-13.1.6 Boric Acid Transfer Pumps - Operating.... ...... 3.1.6-13.1.7 Borated Water Sources - Shutdown... .... 3.1.7-13.1.8 Borated Water Sources - Operating... .... 3.1.8-13.1.9 Rod Position lndication System - Shutdown .. 3.1.9-13.1.10 BoronDilution .3.1.10-13.1 .1 1 Rod Position lndication System - Shutdown Test Exceptions.... .... 3.1.11-1LICENSING REQUIREMENT SURVEILLANCE (LRS) APPLICABILITYFuel Storage Pool Area Radiation Monitor..3.0-13.0-33.3.10,-13.3.1 1 -1INSTRU MENTATIONReactor Trip System Instrumentation Response Times .3.3.1-1Engineered Safety Features Response Times. ......3.3.2-1Meteorological Monitoring Instrumentation ... 3.3.3-1Axial Flux Difference (AFD) Monitor Alarm .... 3.3.4-1Quadrant Power Tilt Ratio (OPTR) Monitor Alarm . 3.3.5-1Seismic Monitoring Instrumentation ....... 3.3.6-1Movable lncore Detectors .. .3.3.7-1Leading Edge Flow Meter ...... 3.3.8-1Turbine Overspeed Protection ....... 3.3.9-1RTS, ESFAS, and Loss of Power Trip SetpointsExplosive Gas Monitoring Instrumentation .....3.3.12-1Containment Hydrogen Analyzers...... .... 3.3.13-1Control Room lsolation Radiation Monitors .... 3.3.14-1Containment Area Radiation Alarm .......3.3.15-13.4 REACTOR COOLANT SYSTEM (RCS)3.4.1 Loop lsolation Valves - Shutdown.. 3.4.1-13.4.2 Chemistry..... ...... j. ..3.4.2-13.4.3 Pressurizer.... . 3.4.3-13.4.4 DELETED..... ..3.4.4-1Beaver Valley Unit 2LRM Revision 67 LICENSING REQUIREMENTS MANUALTABLE OF CONTENTSPage No.3.4 REACTOR COOLANT SYSTEM (RCS) (continued)3.4.5 RCS Head Vents ....3.4.5-13.4.6 Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge..........3.4.6-13.4.7 RCS Pressure lsolation Valves ......3.4.7-13.6 CONTAINMENT3.6.1 Containment lsolation Valves... ......3.6.1-13.6.2 Containment Sump 3.6.2-13.7 PLANT SYSTEMS3.7 .1 Steam Generator Pressure/Temperature Limitation ......3.7.1-13.7.2 Flood Protection ..... 3.7.2-13.7 .3 Sealed Source Contamination 3.7 .3-13.7 .4 Snubbers..... ...3.7 .4-13.7 .5 Standby Service Water System (SWE) .. 3.7.5-13.7 .6 Explosive Gas Mixture.. .. 3.7.6-13.7 .7 Supplemental Leak Collection and Release System (SLCRS) ......3.7.7-13 8 ELECTRICAL POWER SYSTEMS3.8.1 125V D.C. Battery Banks Maintenance Requirements3.8.2 Emergency Diesel Generator (EDG) 2000 Hour Rating Limit3.8.3 Main Fuel Oil Storage Tank Maintenance Requirements3.9 REFUELING OPERATIONS3.9.1 Crane Travel - Spent Fuel Storage Pool Building3.9.2 Manipulator Crane3.9.3 Decay Time3.8.1-13.8.2-13.8.3-13.9.1-13.9.2-13.9.3-15.0 ADMINISTRATIVE CONTROLS5.1 Core Operating Limits Report. 5.1-15.2 Pressure and Temperature Limits Report ......5.2-i5.3 Procedure Review and Approval. ...5.3-15.4 Record Retention ...5.4-1Beaver Valley Unit 2LRM Revision 67 Licensing Requirements ManualGeneral Description1.0.11.0 USE AND APPLICATION1.0.1 General DescriptionChanges to the technical specifications may result in relocating various technical specificationitems to the UFSAR. This maintains control of the relocated items and allows changing theserequirements in accordance with the provisions of 10 CFR 50.59 without the need to process alicense amendment request. ltems relocated from the technical specifications and otherapplicable licensing requirements associated with the operation of structures, systems andcomponents are to be included in Section 16A of the UFSAR and are maintained in theLICENSING REQUIREMENTS MANUAL (LRM). Because the information removed from theTechnical Specifications is considered relocated to the UFSAR, this information is explicitly"incorporated by reference" into the UFSAR when it is placed into the LRM. For informationincorporated by reference, the information must be publicly available and is subject to theupdate and reporting requirements of 10 CFR 50.71(e) in addition to other change controls(e.9., 10 CFR 50.59 and 10 CFR 50.5a(a)).Other information placed into the LRM by BVPS that was previously not located within theTechnical Specifications is not considered part of the UFSAR and is not considered"incorporated by reference." This type of criteria in the LRM is self-imposed by the station andis included in the LRM for consistency with the other type of information included in the LRMand for the convenience of the station for the type of control offered by the LRM document. Thisself-imposed information is subject to the requirements of 10 CFR 50.59; however, it is notsubject to the requirements of 10 CFR 50.71(e). Other self-imposed information is listed inSection A below and is not listed in UFSAR Section 16,4.A. lnformation Not Incorporated by Reference from the UFSARNONEBeaver Valley Unit 21.0-1LRM Revision 52 Licensing Requirements ManualLRM Revisions1.4.21.0 USE AND APPLICATION1.0.2 LRM RevisionsModifications to the content of the LRM (including information such as the tables and reportsreferenced by the Technical Specifications) shall be processed in accordance with theprovisions of 10 CFR 50.59 as set forth in administrative procedures.Beaver Valley Unit 21.0-2LRM Revision 52 Licensing Requirements ManualUSE AND APPLICATIONDefinitions1.01.1Definitions1.1a)The defined terms contained in the Technical Specifications (TS) Section 1.1, "Definitions"apply to the requirements contained in the Licensing Requirements Manual (LRM). In theLRM, defined terms are shown in all capital letters, consistent with their use in theTechnical Specifications. Definitions specific to the LRM are defined as follows:TermDefinition- NOTE -Some components inthe LRM have bothLRM and TSfunctions andrequirements. Suchcomponents arerequired by the LRMto be FUNCTIONAL,and are also requiredby TSs to beOPERABLE. lnthese cases, if acomponent isOPERABLE, it will befunctional; however,if it is FUNCTIONAL.it may not beOPERABLE.FUNCTIONAL -FUNCTIONALlTYA structure, system or component (SSC), shall beFUNCTIONAL or have FUNCTIONALITY when it iscapable of performing its specified function(s) as setforth in the Current License Basis. FUNCTIONALITYdoes not apply to specified safety functions, but doesapply to the ability of non-TS SSCs to perform otherspecified functions that have a necessary supportfunction.POWER, as defined in Technical SpecificationThe value of RATED THERMALSection 1.1, is 2900 MWt.b)Beaver Valley Unit 21.1 -1LRM Revision 67 Licensing Requirements ManualLogical Connectors1.21.0 USE AND APPLICATION1.2 Logical ConnectorsThe explanation of the use of Logical Connectors contained in Technical SpecificationSection 1.2, "Logical Connectors" applies to the requirements contained in the LRM. LogicalConnectors in the LRM are applied in the same manner as in the Technical Specifications.Beaver Valley Unit 21.2-1LRM Revision 52 Licensing Requirements ManualCompletion Times1.31.01.3USE AND APPLICATIONCompletion TimesThe explanation of the use of Action Completion Times contained in Technical SpecificationSection 1.3, "Completion Times" applies to the requirements contained in the LRM. ActionCompletion Times in the LRM are applied in the same manner as in the TechnicalSpecifications.Beaver Valley Unit 21.3 - 1LRM Revision 52 1.01.4Licensing Requirements ManualFrequency1.4USE AND APPLICATIONFrequencyThe explanation of the use of surveilfance Frequencies contained in Technical SpecificationSection 1.4, "Frequency" applies to the Licensing Requirement Surveillances contained in theLRM. Surveillance Frequencies in the LRM are applied in the same manner as in the TechnicalSpecifications.Beaver Valley Unit 21.4-1LRM Revision 52 Licensing Requirements Manual3.0 LIcENSTNG REQUTREMENT (LR) AppLtCABlLrTyLR Applicability3.0LR 3.0.1LRs shall be met during the MODES or other specified conditions in theApplicability, except as provided in LR 3.0.2 and LR 3.0.6.LR 3.0.2Upon discovery of a failure to meet an LR, the Required Actions of theassociated Conditions shall be met, except as provided in LR 3.0.4.lf the LR is met or is no longer applicable prior to expiration of thespecified Completion Time(s), completion of the Required Action(s) is notrequired unless otherwise stated.LR 3.0.3When an LR and the associated ACTIONS are not met, an associatedACTION is not provided, or if directed by the associated ACTIONS, actionshall be initiated immediately to communicate the situation to the ShiftManager and document the condition in accordance with the FENOCCorrective Action Program. The safety significance of the condition shallbe evaluated per NOP-OP-1009 "Operability Determinations andFunctionality Assessments" and appropriate corrective actions i nitiated,within the time frame determined by the Shift Manager that shall notexceed 48 hours from the time of entry into LR 3.0.3. The time frame forcompletion of the corrective actions shall be commensurate with thesafety significance of the condition, consistent with the guidance ofNOP-OP-1009Where corrective measures are completed that permit operation inaccordance with the LR or ACTIONS, completion of the actions requiredby LR 3.0.3 is not required.LR 3 0.4Equipment removed from service or declared inoperable/Nonfunctional tocomply with ACTIONS may be returned to service under administrativecontrol solely to perform testing required to demonstrate its ,OPERABI LITY/FU NCTIO NAL ITY or the OPE RABI LITY/FU NCTIONALITYof other equipment. This is an exception to LR 3.0.2 for the systemreturned to service under administrative control to perform the testingreq u i red to demon strate O P E RAB I L ITY/FU NCTI O NALITY.Beaver Valley Unit 230-1LRM Revision 67 Licensing Requirements ManualLR Applicability3.03.0 LR Applicability (continued)LR 3.0.5 Requirements are specified in the LRM that are referenced from theTechnical Specifications. These requirements include the informationcontained in tables, reports, and figures (e.9., Instrumentation ResponseTimes and the COLR). Although these requirements are contained in theLRM, they are utilized by, and referenced from, the TechnicalSpecifications. The guidance in Section 3.0 of this manual for LRApplicability does not apply to the LRM requirements referenced by theTechnical Specifications. The failure to meet LRM requirementsreferenced by the Technical Specifications shall be controlled inaccordance with the applicable Technical Specifications.LR 3.0.6 Test Exception LR 3.1.11 allows the specified LR requirements to bechanged to permit performance of special tests and operations. Unlessotherwise specified, all other LR requirements remain unchanged.Compliance with Test Exception LRs is optional. When a Test ExceptionLR is desired to be met but is not met, the ACTIONS of the TestException LR shall be met. When a Test Exception LR is not desired tobe met, entry into a MODE or other specified condition in the Applicabilityshall be made in accordance with the other applicable LRs.Beaver Valley Unit 23.0-2LRM Revision 52 Licensing Requirements Manual3.0 LTCENSTNGREQUTREMENTSURVETLLANCE(LRS)APPLTCABTLTTYLRS Applicability3.0LRS 3.0.1LRS shall be met during the MODES or other specified conditions in theApplicability for individual LRs, unless othenruise stated in the LRS.Failure to meet an LRS, whether such failure is experienced during theperformance of the Surveillance or between performances of theSurveillance, shall be faifure to meet the LR. Failure to perform aSurveillance within the specified Frequency shall be failure to meet theLR except as provided in LRS 3.0.3. LRS do not have to be performedon inoperable/Nonfunctional equipment or variables outside specifiedlimits.LRS 3.0.2The specified Frequency for each LRS is met if the Surveillance isperformed within 1.25 times the interval specified in the Frequency, asmeasured from the previous performance or as measured from the time aspecified condition of the Frequency is met.For Frequencies specified as "once," the above interval extension doesnot apply.lf a Completion Time requires periodic performance on a "once per . ."basis, the above Frequency extension applies to each performance afterthe initial performance.Exceptions to this LRS are stated in the individual Surveillances.LRS 3.0.3lf it is discovered that a surveillance was not performed within its specifiedFrequency, then compliance with the requirement to declare the LR notmet may be delayed, from the time of discovery, up to 24 hours or up tothe limit of the specified surveillance interval, whichever is greater. Thisdelay period is permitted to allow performance of the surveillance. A riskevaluation shall be performed for any surveillance delayed greater than24 hours and the risk impact shall be managed.lf the surveillance is not performed within the delay period, the LR mustimmediately be declared not met, and the applicable ACTION(s) rnust beentered.When the surveillance is performed within the delay period and thesurveillance is not met, the LR must immediately be declared not met,and the applicable ACTION(s) must be entered.Beaver Valley Unit 230-3LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.1 Boration Flow Paths - ShutdownLR 3.1.1APPLICABlLITY:MODES 5 and 6.CONDITIONRequired flow pathNonfunctional.LRS 3.1 1 1One of the following boron injection flow paths shall be FUNCTIONAL:A flow path from the boric acid storage system via a boric acidtransfer pump to a charging pump to the Reactor Coolant Systemwhen the boric acid storage tank is required FUNCTIONAL inaccordance with LR 3.1.7 , orfhe flow path from the refueling water storage tank (RWST) via acharging pump or a low head safety injection pump (with an openRCS vent of greater than or equal to 3.14 square inches) to theReactor Coolant System when the RWST is requiredFUNCTIONAL in accordance with LR 3.1.7.SURVEILLANCECycle each testable power operated or automatic valvein the flow path through at least one complete cycle offull travel.Boration Flow Paths - Shutdown3.1.1COMPLETION TIMElmmediatelyFREQUENCY7 daysa.b.A.ACTIONSREQUIRED ACTIONA.1 Suspend all operationsinvolving COREALTERATIONS or positivereactivity changes.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2311-1LRM Revision 67 Licensing Requirements ManualLICENSING REQUIREMENT SURVEILLANCEScontinuedSU RVEILLANC ELRS 3.1 .1 .2Boration Flow Paths - Shutdown3.1.1FREQUENCYLRS 3.1.1.3. NOTE .Only required to be met when a flow path from the boricacid storage tanks is required FUNCTIONAL and theambient air temperature of the Auxiliary Building is< 650F.Verify the temperature of the heat traced portion of theflow path is > 65"F.Verify each valve (manual, power operated orautomatic) in the flow path that is not locked, sealed, orotherwise secured in position, is in its correct position.7 days31 daysBeaver Valley Unit 23.1 1-2LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.2 Boration Flow Paths - OperatingLR 3.1.2Boration Flow Paths - Operating3.1 .2a.b.Each of the following boron injection flow paths shall be FUNCTIONAL:The flow path from the boric acid tanks via a boric acid transferpump and one charging pump to the Reactor Coolant System,andThe flow path from the refueling water storage tank via onecharging pump to the Reactor Coolant System.. NOTES -With any non-isolated RCS cold leg temperature ( the OPPSenable temperature specified in the PTLR, one of the requiredcentrifugal charging pumps may be made incapable of injecting tosupport the requirements of LCO 3.4.12.With all non-isolated RCS cold leg temperatures > the OPPSenable temperature specified in the PTLR, one of the requiredcentrifugal charging pumps may be made incapable of injecting tosupport transition into or from the Applicability of LCO 3.4.12 forup to 4 hours or until the temperature of all non-isolated RCS coldlegs exceeds the OPPS enable temperature specified in the PTLRplus 25oF, whichever comes first.1.2.ABAPPLICABILITY:MODES 1,2,3, and 4.CONDITIONFlow path from the boricacid tanks Nonfunctional.Required Action, andassociated CompletionTime of Condition A notmet.COMPLETION TIME72 hourslmmediatelyACTIONSREQUIRED ACTIONA.1 Restore the flow path toFUNCTIONAL status.B 1 Apply LR 3.0.3.Beaver Valley Unit 23.1 2-1LRM Revision 67 C.D.Licensing Requirements ManualACTIONS (continuedCONDITIONFlow path from therefueling water storagetank Nonfunctional.Required Action andassociated CompletionTime of Condition C notmet.LRS 3.1 .2 1Boration Flow Paths - Operating3.1 .2COMPLET]ON TIMEt hour6 hours36 hoursFREQUENCY92 daysSU RVEILLANCECycle each testable power operated or automatic valvein the flow path through at least one complete cycle offull travel.- NOTE -Only required to be met when the ambient airtemperature of the Auxiliary Building is < 65"F.Verify the temperature of the heat traced portion of theflow path from the boric acid tanks is > 65"F.Verify each valve (manual, power operated orautomatic) in the flow path that is not locked, sealed, orotherwise secured in position, is in rts correct position.Cycle each power operated (excluding automatic) valvein the flow path that is not testable during plantoperation, through at least one complete cycle of fulltravel.LRS 3.1 2.2LRS 3 1 2.3LRS 3 1 2.47 days31 days18 months duringshutdownREQUIRED ACTIONC.1 Restore the flow path toFUNCTIONAL status.D.1 Be in MODE 3.ANDD.2 Be in MODE 5.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 231.2-2LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.3 Charging Pump - ShutdownLR 3.1.3APPLICABILITY:MODES 5 and 6.CONDITlONRequired pumpNonfunctional.LRS 3.1 .3.1LRS 3.1 3.2One of the following pumps shall be FUNCTIONAL as specified below:A charging pump in the boron injection flow path requiredFUNCTIONAL in accordance with LR 3.1.1 , orA low head safety injection pump (with an open Reactor CoolantSystem vent of 2 3.14 square inches).SURVEILLANCEThe required charging pump shall be demonstratedFUNCTlONAL pursuant to Technical SpecificationSurveillance SR 3.5.2.4.The required low head safety injection pump shall bedemonstrated FUNCTIONAL by:a. Verification of a FUNCTIONAL RWST pursuant toLRS 3.1 .7 .1 and LRS 3.1 .7 3.b. Verification of a FUNCTIONAL low head safetyinjection pump pursuant to Technical SpecificationSurveillance SR 3.5.2.4. andc. Verification that the vent is open in accordance withTechnical Specification Surveillance SR 3.4.12.3.Charging Pump - Shutdown3.1.3COMPLETION TIMElmmediatelyFREQUENCYln Accordancewith SR 3.5.2.4ln Accordancewith theapplicable SRs orLRSb.A.ACTIONSREQUIRED ACTIONA.1 Suspend all operationsinvolving COREALTERATIONS or positivereactivity changes.LICENSlNG REQUIREMENT SURVEILLANCESBeaver Valley Unit 2313-1LRM Revision 67 Licensing Requirements ManualLICENSING REQUIREMENT SURVEILLANCEScontinuedSU RVEILLANCE3.1.3.3Charging Pump - Shutdown3.1.3FREQUENCY- NOTE -Only required to be met when the low head safetyinjection pump is required FUNCTIONAL in accordancewith LR 3.1 .3.b.Verify a FUNCTIONAL low head safety injection flowpath from the RWST to the Reactor Coolant System.12 hoursBeaver Valley Unit 23.1.3 - 2LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.4 Charging Pumps - OperatingLR 3.1.4Charging Pumps - Operating3.1.41.2.Two charging pumps shall be FUNCTIONAL.. NOTES .With any non-isolated RCS cold leg temperature ( the OPPSenable temperature specified in the PTLR, one of the requiredcentrifugal charging pumps may be made incapable of injecting tosupport the requirements of LCO 3.4.12.With all non-isolated RCS cold leg temperatures > the OPPSenable temperature specified in the PTLR, one of the requiredcentrifugal charging pumps may be made incapable of injecting tosupport transition into or from the Applicability of LCO 3.4.12 forup to 4 hours or until the temperature of all non-isolated RCS coldlegs exceeds the OPPS enable temperature specified in the PTLRplus 25oF, whichever comes first.A.APPLICABILITY:MODES 1 ,2, 3, and 4.CONDITIONOne required chargingpump Nonfunctional.Required Action andassociated CompletionTime of Condition A notmet.COMPLETION TIME72 hourslmmediatelyB.ACTIONSREQUIRED ACTIONA.1 Restore the charging pumpto FUNCTIONAL status.8.1 Apply LR 3.0 3Beaver Valley Unit 23.1.4 - 1LRM Revision 67 LICENSING REQUIREMENT SURVEILLANCESLicensing Requirements ManualLRS 3 1 .4.1SU RVEILLANCEEach required charging pump shall be demonstratedFUNCTIONAL pursuant to Technical SpecificationSurveillance SR 3.5.2.4.Charging Pumps - Operating3.1.4FREQUENCYln Accordancewith SR 3.5.2.4Beaver Valley Unit 23.1.4 - 2LRM Revision 67 A.Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.5 Boric Acid Transfer Pumps - ShutdownLR 3.1.5APPLICABILITY:CONDITIONRequired boric acidtransfer pumpNonfunctional.LRS 3.1 .5.1Boric Acid Transfer Pumps - Shutdown3.1.5ln accordancewith the lnserviceTesting ProgramOne boric acid transfer pump shall be FUNCTIONAL.ln MODES 5 and 6 when the associated flow path from the boric acidstorage system is required FUNCTIONAL in accordance withLR 3.1.1.COMPLETION TIMElmmediatelySU RVEILLANC EFREQUENCYThe required boric acid transfer pump shall bedemonstrated FUNCTIONAL by verifying, that onrecirculation flow, the pump develops a differentialpressure of > 102 psid.ACTIONSREQUlRED ACTIONA.1 Suspend all operationsinvolving COREALTERATIONS or positivereactivity changes.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 231.5-1LRM Revision 67 B.Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.6 Boric Acid Transfer Pumps - OperatingLR 3.1 .6APPLICABILITY:CONDITlONRequired boric acidtransfer pumpNonfunctional.Required Action andassociated CompletionTime of Condition A notmet.LRS 3.1 6.1Boric Acid Transfer Pumps - Operating3.1.6ln Accordancewith the lnserviceTesting ProgramOne boric acid transfer pump shall be FUNCTIONAL.In MODES 1,2, 3, and 4 when the associated flow path from the boricacid tanks is required FUNCTIONAL in accordance with LR 3.1.2,COMPLETION TIME72 hourslmmediatelySURVEILLANCEFREQUENCYThe required boric acid transfer pump shall bedemonstrated FUNCTIONAL by verifying, that onrecirculation flow, the pump develops a differentialpressure of > 102 psid.ACTIONSREQUlRED ACTIONA.1 Restore the boric acidtransfer pump toFUNCTIONAL status.8.1 Apply LR 3.0.3.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.1 6-1LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.7 Borated Water Sources - ShutdownLR 3.1.7APPLICABILITY:MODES 5 and 6.CONDITIONRequired borated watersource Nonfunctional.LRS 3 1.7 1Borated Water Sources - Shutdown3.1.7COMPLETION TIMElmmediatelyFREQUENCYOne of the following borated water sources shalf be FUNCTIONAL:a. A boric acid storage system with:1. A minimum contained volume of 2315 gallons,2. Between 7000 and 7700 ppm of boron, and3. A minimum solution temperature of 65"F.b. The refueling water storage tank (RWST) with:1 . A minimum contained volume of 217,000 gallons,2. A minimum boron concentration of 240A ppm, and3. A minimum solution temperature of 45'F.ASU RVE ILLANCE- NOTE .Only required to be met when the outside ambient airtemperature is < 45"F.Verify the required RWST temperature.24 hoursACTIONSLREQUIRED ACTIONA.1 Suspend all operationsinvolving COREALTERATIONS or positivereactivity changes.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.1.7 - 1LRM Revision 67 Licensing Requirements ManualLICENSING REQUIREMENT SURVEILLANCEScontinuedSU RVEILLANCELRS 3.1.7 .2Borated Water Sources - Shutdown3.1.7FREQUENCY7 days7 daysLRS 3.1 .7 .3Verify the required boric acid storage tank solutiontemperature.The required borated water source shall bedemonstrated FUNCTIONAL by:a. Verifying the boron concentration of the water, andb. Verifying the water level of the tank.Beaver Valley Unit 23.1.7 - 2LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.8 Borated Water Sources - OperatingLR 3.1.8APPLICABILlTY:MODES 1 , 2, 3, and 4.CONDITIONBoric Acid Storage SystemNonfunctional.Required Action andassociated CompletionTime of Condition A notmet.Borated Water Sources - Operating3.1.8COMPLETION TIME72 hourslmmediatelyThe Boric Acid Storage System shall be FUNCTIONAL as required byLR 3.1.2 with:a. Minimum usable volume of 13,390 gallons,b. Between 7000 and 7700 ppm of boron, andc. A minimum solution temperature of 65"F.A.B.ACTIONSREQUIRED ACTIONA.1 Restore the storagesystem to FUNCTIONALstatus.B1 ApplyLR303.Beaver Valley Unit 23.1 8 - 1LRM Revision 67 LICENSI NG REQUIREMENT SURVEILLANCESLicensing Requirements ManualLRS 3.1 .8.1SURVEILLANCEThe Boric Acid Storage System shall be demonstratedFUNCTIONAL by:a. Verifying the boron concentration of the water,b. Verifying the water level of the tank, andc. Verifying the boric acid storage system solutiontemperature.Borated Water Sources - Operating3.1.8FREQUENCY7 daysBeaver Valley Unit 23.1 8 - 2LRM Revision 67 A.Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.9 Rod Position lndication System - ShutdownLR 3.1.9APPLICABILITY:CONDITIONRequired digital rodposition indicator(s)Nonfunctional.LRS 3 1.9.1Rod Position Indication System - Shutdown3.1.9ln accordancewith applicableSROne digital rod position indicator (excluding demand position indication)shall be FUNCTIONAL and capable of determining the control rodposition within + 12 steps for each shutdown or control rod not fullyinserted.MODES 3, 4, and 5 with the reactor trip system breakers in the closedposition.COMPLETION TIMElmmediatelySU RVEILLANC EFREQUENCYVerify required digital rod position indicator(s)FUNCTIONAL in accordance with TechnicalSpecification Surveillance SR 3.1.7 .2.1.ACTIONSREQUIRED ACTIONA.1 Open the reactor tripsystem breakers.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2319-1LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1 .1 0 Boron DilutionLR 3.1.10APPLICABILITY:CONDlTIONFlow rate of reactor coolantthrough the core< 3000 gpm.LRS 3.1.10.1The flow rate of reactor coolant through the core shall be > 3000 gpm.In all MODES when a reduction in Reactor Coolant System (RCS)boron concentration is being made.COMPLETION TIMEBoron Dilution3.1 .1 0lmmediatelyFREQUENCYPrior to the startof and at leastonce per hourduring a reductionin the RCS boronconcentrationA.SU RVEILLANCEThe flow rate of reactor coolant through the core shallbe determined to be > 3000 gpm by either:a. Verifying at least one reactor coolant pump is inoperation, orb. Verifying that at least one RHR pump is in operationand supplying > 3000 gpm through the core.ACTIONSREQUIRED ACT]ONA.1 Suspend all operationsinvolving a reduction inboron concentration of theRCS.LICENSING REQUI REMENT SURVEILLANCESBeaver Valley Unit 23.1 .10 - 1LRM Revision 52 Licensing Requirements ManualRod Position Indication System - Shutdown Test Exceptions3.1 .113.1 REACTIVITY CONTROL SYSTEMS3.1.11 Rod Position Indication System - Shutdown Test ExceptionsLR 3.1.11The limitations of LR 3.1.9 may be suspended during the performanceof individual full-length shutdown and control rod drop timemeasu reme nts provided :a. Only one shutdown or control bank is withdrawn from the fullyinserted position at a time, and. NOTE .The following requirement is not applicable during the initial calibrationof the Digital Rod Position Indication System provided: (1) K"6 ismaintained < 0.95, and (2) only one shutdown or control rod bank iswithdrawn from the fully inserted position at one time.b. The rod position indicator is FUNCTIONAL during the withdrawalof the rods.MODES 3, 4, and 5 during performance of rod drop timemeasurements.COMPLETION TIMEAAPPLlCABILITY:CONDITIONPosition IndicationSystems Nonfunctional orwith more than one bank ofrods withdrawn.lmmediatelyACTIONSREQUIRED ACTIONA.1 Open the Reactor tripbreakers.Beaver Valley Unit 23.1.11 - 1LRM Revision 67 Licensing Requirements ManualRod Position Indication System - Shutdown Test Exceptions3.1.11LRS 3.1.11.1SU RVEILLANC EThe Position Indication Systems shall be determined tobe FUNCTIONAL during rod drop time measurementsby verifying the Demand Position Indication System andthe Digital Rod Position Indication System agree:a. Within 12 steps when the rods are stationary, andb. Within 24 steps during rod motion.FREQUENCYWithin 24 hoursprior to the starlof rod drop timemeasurementsand at least onceper 24 hoursthereafterLICENSI NG REQU IREMENT SURVEILLANCESBeaver Valley Unit 23111 -2LRM Revision 67 Licensing Requirements ManualReactor Trip System Instrumentation Response Times3.3.13.3 INSTRUMENTATION3.3.1 Reactor Trip System lnstrumentation Response TimesLR 3.3.1APPLICABILITY:As specified in TS 3.3.1.Each reactor trip system instrumentation response time listed inTable 3.3.1-1 shall be maintained in the manner specified in TechnicalSpecification (TS) 3.3.1, Reactor Trip System Instrumentation.Beaver Valley Unit 23.3.1 - 1LRM Revision 52 Licensing Requirements Manual1.2.3.4.5.FUNCTIONManual Reactor TripPower Range, Neutron FluxPower Range, Neutron Flux, High Positive RateIntermediate Range, Neutron FluxSource Range, Neutron Flux(Below P-10)Overtemperature ATOverpower ATa. Pressurizer Pressure - Lowb. Pressurizer Pressure - HighPressurizer Water Level - HighReactor Coolant Flow - Lowa. Single loopb. Two loopsReactor Coolant Pump (RCP) Breaker Position TripUndervoltage-RCPsUnderfrequency-RCPsSteam Generator Water Level - Low LowTurbine Tripa. Emergency Trip HeaderLow Pressureb. Turbine Stop Valve ClosureSafety Injection Input from ESFASReactor Trip System lnterlocks9.10.11.12.13.14.15.Reactor Trip System Instrumentation Response Times3.3.1TABLE 3.3.1-1 (Page 1 of 2)REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES6.7.8.RESPONSE TIMENOT APPLICABLE< 0.5 second(1)NOT APPLICABLENOT APPLICABLENOT APPL]CABLEYu11"51"(txz)ysr-1s51s(tXz)< 2.4 seconds< 2.0 secondsNOT APPLICABLE< 1.0 second< 1.0 secondNOT APPLICABLE< 1.5 seconds< 0.9 second< 2.4 secondsNOT APPLICABLENOT APPLICABLENOT APPLICABLENOT APPLICABLE16.17.Beaver Valley Unit 23.3.1 - 2LRM Revision 52 Licensing Requirements Manual Reactor Trip System Instrumentation Response Times3.3.1TABLE 3.3.1-1 (Page 2 ot 2)REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES18. Reactor Trip Breakers (RTBs) NOT APPLICABLE19. RTB Undervoltage and Shunt Trip Mechanisms NOT APPLICABLE20. Automatic Trip Logic NOT APPLICABLETABLE NOTATION(1) Neutron detectors are exempt from response time testing. Response time shall bemeasured from detector output or input of first electronic component in channel.(2) Refer to Table 3.3.1 -1 .a for required response times.Beaver Valley Unit 23.3.1 - 3LRM Revision 52 Licensing Requirements ManualReactor Trip System lnstrumentation Response Times3.3.1TABLE 3.3.1-1.a (Page 1 of 1)Overtemperature Delta-T & Overpower Delta-T Response TimesThis table represents the maximum allowable plant testing, electronic response time acceptancecriteria based on measured RTD response time. All listed values are in seconds.To use this table, take the slowest measured RTD response time in a loop, round up to thenearest 1/10 second, and obtain the corresponding acceptance criteria.FinalAccept.CriteriaFinalAccept.CriteriaFinal Accept.CriteriaRTD TimeResponseOvertemperatureAT - Truo InputOverpowerAT - Truo InputMeasured AT -AT lnput2.02.8622.6439.8832.12.8402.6259.7772.22.8182.609L6722.32.7962.5929.5682.42.7752.5759.4642.52.7542.5599.3622.62.7332.5439.2602.72.7132.5279.1592.82.6932.5129.0592.92.6732.4978 9603.02.6542.4818.8613.12.6342.4678.7633.22.6152.4528.6663.32.5962.4388.5693.42.5782.4238.4733.52.5592.4098.3783.62.5412.3958.2833.72.5232.3828.1893.82.5052.3688.0963.92.4872.3548 0034.42.4692.3417.9114.12.4522.3287.8194.22.4342.3157.7284.32.4172.3027.6374.42.4002.2897.5474.52.3832.2767.457Pressurizer pressure i nput.Neutron detector input (for f(Al) penalty):Final Accept.CriteriaFinalAccept.CriteriaFinal Accept.CriteriaRTD TimeResponseOvertemperatureAT - T"uo InputOverpowerAT - T"uo InputMeasured AT -AT Input4.62.3662.2647.3674.72.3492.2517.2794.82.3332.2397.1904.92.3162.2267.1025.02.3002.2147.0145.12.2832.2426.9275.22.2672.1906.8405.32.2502.1786.7545.42.2352.1666.6685.52.2182.1546.5825.62.2422.1436.4975.72.1872.1316.4125.82.1712izA6.3275.92.1562.1086.2426.02.1402.4976.1586.12.0401.9976.0586.21.9441.8975.9586.31.8401.7975.8586.41.7401.6975.7586.51.6401.5975.6586.61_5401.4975.5586.71.4441.3975.4586.81.3441.2975.3586.91.2401.1975.2587.011441.0975.158< 2.0 seconds.< 2.0 seconds.The following are the response time acceptance criteria for the pressurizer pressure andneutron flux input to the Overtemperature AT function:All of the channel time responses noted above for the Overtemperature AT, Overpower AT, andmeasured AT channels are for all portions of the channel downstream of the RTD output (i.e.,includes channel electronics, trip breaker, and rod gripper release). The time responses arebased on all channel setpoints (i.e., all gains and time constants) implemented as per theLicensing Requirements Manual values.Beaver Valley Unit 23.3.1 - 4LRM Revision 52 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.2 Engineered Safety Features Response TimesLR 3.3.2Engineered Safety Features Response Times3.3.2Each engineered safety feature response time listed in Table 3.3.2-1shall be maintained in the manner specified in Technical Specification(TS) 3.3.2, Engineered Safety Feature Actuation Systemlnstrumentation and TS 3.3.5, Loss of Power Diesel Generator Startand Bus Separation lnstrumentation as applicable.APPLICABILITY: As specified in the applicable TS.Beaver Valley Unit 23.3.2 - 1LRM Revision 52 Licensing Requirements ManualINITIATING SIGNAL AND FUNCTION1. ManualEngineered Safety Features Response Times3.3.2TABLE 3.3.2-1 (Page 1 of 4)ENGINEERED SAFETY FEATURES RESPONSE TIMESContainment Pressure-Hiqha. Safety lnjection (ECCS)b. Reactor Trip (from Sl)c. Feedwater lsolationd. Containment lsolation-Phase "A"e. Auxiliary Feedwater Pumpsf. Service Water SystemSafety I njection (ECCS)Feedwater lsolationReactor Trip (Sl)Conta inment lsolation-Phase "A"Containment Vent and Purge lsolationAuxiliary Feedwater PumpsService Water SystemContainment Quench Spray PumpsContainment Quench Spray ValvesContainment lsolation-Phase "B"Containment lsolation-Phase "A"Control Room Ventilation lsolationRESPONSE TIME IN SECONDSNot ApplicableNot ApplicableNot ApplicableNot ApplicableNot ApplicableNot ApplicableNot Applicable Not ApplicableNot ApplicableNot ApplicableNot ApplicableNot Applicable< 27 .0(3)< 3.0< 7.0(6)< 61 .5(e)11 15.5(10)< 60.0< TZ.SQlll Bl .5(B)a.b.c.d.2.Beaver Valley Unit 23.3.2 - 2LRM Revision 52 Licensing Requirements ManualEngineered Safety Features Response Times3.3.2TABLE 3.3.2-1 (Page 2 of 4)ENGINEERED SAFETY FEATURES RESPONSE TIMESIN]TIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS3. Pressurizer Pressure-Lowa. Safety Injection (ECCS) < 17.0(1t)27.9{t)127.0$)b. Reactor Trip (from Sl) < 3.0c. Feedwater lsolation < 7.0(6)d. Containment lsolation-Phase "A" < 61 .0(e)/1 15.0(10)e. Auxiliary Feedwater Pumps < 60.0t. Service Water System < 72.0Q)1181 .0(8)4. Steam Line Pressure-Lowa. Safety Injection (ECCS)b. Reactor Trip (from Sl)c. Feedwater lsolationd. Containment lsolation-Phase "A"e. Auxiliary Feedwater Pumpsf . Service Water Systemg. Steam Line lsolation< 37.0(s)/27.A@)< 3.0< 7.0(6)< 61 .0(e)/1 1b.0(10)< 60.0< TZ.OQ)1181 .0(B)< 7.0(13)5. Containment Pressure-Hiqh Hiqha. Containment Quench Spray < 74.5o2)b. Containment lsolation-Phase "B" Not Applicablec. Control Room Ventilation lsolation (on CIB) < 22.0(e)177.A(o)d. Recirculation Spray Not Applicable I6. Steam Generator Water Level-Hiqh Hiqha. Turbine Trip Not Applicableb. Feedwater lsolation < 7.0(6)Beaver Valley Unit 23.3.2 - 3LRM Revision 56 Licensing Requirements ManualEngineered Safety Features Response Times3.3.2TABLE 3.3.2-1 (Page 3 of 4)ENGINEERED SAFETY FEATURES RESPONSE TIMESINITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS7. ContainmentPressure-lntermediateHiqhHiqha. Steam Line lsolation < 7.0(13)8. Steamline Pressure Rate-High Neqativea. Steamline lsolation< 7.0(13)9. Loss of Power (TS 3.3.5)a. 4.16kv Emergency Bus Undervoltage < 1.3 sec.(Loss of Voltage) (Trip Feeder)b. 4.16kv and 480v Emergency Bus 90 t 5 sec.Undervoltage (Degraded voltage)10. Steam Generator Water Level-Low Lowa. Motor-driven Auxiliary < 60.0Feedwater Pumps(1)b. Turbine-driven Auxiliary < 60.0Feedwater Pump(')11. Undervoltage RCPa. Turbine-driven AuxiliaryFeedwater Pump12. Trip of Main Feedwater Pumpsa. Motor-driven AuxiliaryFeedwater Pumps< 60.0< 60.0Beaver Vafley Unit 23.3.2 - 4LRM Revision 52 (4)Licensing Requirements ManualEngineered Safety Features Response Times3,3.2(1)(2)(3)TABLE 3.3.2-1 (Page 4 of 4)ENGINEERED SAFETY FEATURES RESPONSE TIMESon zt3 in zl3steam Generators TABLE NorATloNon 213 any Steam GeneratorDiesel generator starting and sequence loading delays included. Response time limitincludes opening of valves to establish Sl path and attainment of discharge pressure forcentrifugal charging pumps and Low Head Safety Injection pumps. Sequential transferof charging pump suction from the volume control tank (VCT) to the refueling waterstorage tank (RWST) (RWST valves open, then VCT valves close) is not included.Diesel generator starting and sequence loading delays not included. Offsite poweravailable. Response time limit includes opening of valves to establish Sl path andattainment of discharge pressure for centrifugal charging pumps. Sequential transfer ofcharging pump suction from the volume control tank (VCT) to the refueling waterstorage tank (RWST) (RWST valves open, then VCT valves close) is included.Diesel generator starting and sequence loading delays included. Response time limitincludes opening of valves to establish Sl path and attainment of discharge pressure forcentrifugal charging pumps. Sequential transfer of charging pump suction from thevolume control tank (VCT) to the refueling water storage tank (RWST) (RWST valvesopen, then VCT valves close) is included.Feedwater system overall response time shall include verification of valve stroke timesapplicable to the feedwater containment isolation valves for Train A and the mainfeedwater regulating valves and bypass valves for Train B. Valve isolation times shallbe limited such that when added to the actuation circuitry time the total response timedoes not exceed 7 seconds.Diesel generator starting and sequence loading delays included. Response time limitincludes attainment of discharge pressure for service water pumps.Diesel generator starting and sequence loading delays not included. Response timelimit only includes opening of valves to establish the flowpath to the diesel coolers.Diesel generator starting and sequence loading delays not included. Offsite poweravailable. Response time limit includes operation of valves/dampers.Diesel generator starting and sequence loading delays included. Response time limitincludes operation of valves/dampers.Diesel generator starting and sequence loading delays not included. Offsite poweravailable. Response time limit includes opening of valves to establish Sl path andattainment of discharge pressure for centrifugal charging pumps and Low Head Safetylnjection pumps. Sequential transfer of charging pump suction from the volume controltank (VCT) to the refueling water storage tank (RWST) (RWST valves open, then VCTvalves close) is not included.Diesel generator starting and sequence loading delays included. Response time doesnot include operation of the valves because Quench Spray valves are maintained open.The main steam isolation valve isolation time shall be limited to < 6 seconds.(5)(6)(7)(8)(e)(10)(11)(12)(13)Beaver Valley Unit 23.3.2 - 5LRM Revision 52 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.3 Meteorological Monitoring lnstrumentationLR 3.3.3APPLICABILITY:At all times.CONDITIONOne or more requiredmeteorolog ical mon itoringchannels Nonfunctional.One or more requiredmeteorolog ical monitorin gchannels Nonfunctional formore than 7 days.LRS 3 3.3.1LRS 3 3.3.2Meteorological Monitoring I nstrumentation3.3.3COMPLETION TIMElmmediately30 daysFREQUENCY24 hours1 84 daysThe meteorological monitoring instrumentation channels specifiedTable 3.3.3-1 shall be FUNCTIONAL.A.B.SU RVE ILLANC EPerform a CHANNEL CHECK on each requiredmeteorological monitoring instrument channel.Perform a CHANNEL CALIBRATION on each requiredmeteorolog ical mon itori n g instru ment chan nel.ACTIONSREQUlRED ACTIONA.1 Suspend all release ofgaseous radioactivematerial from the radwastegas decay tanks.8.1 Prepare and present areport to the onsite safetyreview committee for theirreview outlining the causeof the malfunction and theplans for restoring thechannel(s) toFUNCTIONAL status.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.3.3 - 1LRM Revision 67 Licensing Requirements Manual Meteorological Monitoring Instrumentation3.3.3TABLE 3.3.3-1 (Page 1 of 1)METEOROLOGICAL MONITORING INSTRUMENTATION1.INSTRUMENTWIND SPEEDINSTRUMENTMlNIMUMACCURACYt 0.5 mph*t 0.5 mph*+ 0.5 mph*+50+50+5"+ 0.1'c+ 0.1'cREQUIREDCHANNELSa.b.c.a.b.NominalNominalNominalElev. 500'Elev. 150'Elev. 35'AT- 35'- 35'2. WIND DIRECTIONa. Nominal Elev. 500'b. Nominal Elev. 150'c. Nominal Elev. 35'3. AIR TEMPERATUREAT Elev. 500'AT Elev. 150'.Starting speed of anemometer shall be < 1 mph.Beaver Valley Unit 23.3.3 - 2LRM Revision 52 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.4 Axial Flux Difference (AFD) Monitor AlarmLR 3.3.4APPLICABILITY:CONDITIONA. LR not met.LRS 3.3.4.1Axial Flux Difference (AFD) Monitor Alarm3.3.4Once per hour for24 hoursANDOnce per 30minutes thereafterAFD shall be monitored and logged.When the AFD monitor alarm is Nonfunctional and power is > 50o/oRTP.COMPLETION TIMElmmediatelySU RVE lLLANC EFREQUENCYMonitor and log the indicated AFD for eachFUNCTIONAL channel.ACTIONSREQUIRED ACTION4.1 Apply LR 3.0.3.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2334-1LRM Revision 67 Licensing Requirements ManualQuadrant Power Tilt Ratio (OPTR) Monitor Alarm3.3.53.3 INSTRUMENTATION3.3.5 Quadrant Power Tilt Ratio (OPTR) Monitor AlarmLR 3.3.5APPLICABILlTY:CONDITIONA. LR not met.QPTR shall be verified within the limits.When the QPTR monitor alarm is Nonfunctional and power is > 50o/oRTP.COMPLETION TIMElmmediatelySU RVEILLANCEFREQUENCYLRS 3.3.5.1Verify QPTR is within the limits.12 hoursACTIONSREQUIRED ACTION,A.1 Apply LR 3.0.3.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.35-1LRM Revision 67 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.6 Seismic Monitoring lnstrumentationLR 3.3.6APPLICABILITY:At all times.CONDITIONOne or more requiredseismic monitoringinstru ments Nonfu nctional.One or more requiredseismic monitoringinstru ments Nonfu nctionalfor more than 30 days.Seismic Monitoring Instrumentation3.3.6COMPLETION TIME30 days10 daysThe seismic monitoring instrumentation specified in Table 3.3.6-1 shallbe FUNCTIONAL.A.B.ACTIONSREQUIRED ACTIONA.1 Restore the Nonfunctionalinstrument(s) toFUNCTIONAL status.8.1 Prepare and present areport to the onsite safetyreview committee for theirreview outlining the causeof the malfunction and theplans for restoring theinstrument(s) toFUNCTlONAL status.Beaver Valley Unit 233.6-1LRM Revision 67 Licensing Requirements ManualACTIONS (continuedCONDITIONC. Seismic event > 0.029.LRS 3.3.6 1LRS 3.3.6.2LRS 3.3.6.3SU RVE ILLANC EPerform a CHANNEL CHECK as specified in Table3.3.6-2.Perforrn a CHANNEL OPERATIONAL TEST asspecified in Table 3.3.6-2.Perform a CHANNEL CALIBRATION as specified inTable 3.3.6-2.Seismic Monitoring Instrumentation3.3.6COMPLETION TIME24 hours30 days30 daysFREQUENCYln accordancewith Table 3.3.6-2ln accordancewith Table 3.3.6-2In accordancewith Table 3.3.6-2REQUIRED ACTIONC.1 Report to NRC.ANDRestore actuatedinstruments toFUNCTIONAL status.Perform CHANNELCALI BRATION on actuatedinstruments.ANDC.4 Retrieve and analyze datafrom actuated instrumentsto determine magnitude ofvibratory ground motionand prepare and submit aspecial report inaccordance with 10 CFR50.4 describing themagnitude, frequencyspectrum and resultanteffect upon facility featuresimportant to safety.L]CENSING REQU IREMENT SURVEILLANCESBeaver Valley Unit 23.36-2LRM Revision 67 Licensing Requirements ManualSeismic Monitoring I nstrumentation3.3.6(Page 1 of 1)INSTRUMENTATIONTABLE 3.3.6-1SElSMIC MONITORINGINSTRUMENTS AND SENSOR LOCATIONS1. TRIAXIAL TlME-HISTORYACCELEROGRAPHS (2)(3)(4)a. Containment Mat (2ERS-ACS-1)b. Containment Operating Floor (2ERS-ACS-2)c. Switchyard (2ERS-ACS-3)d. ContainmentBuilding(2ERS-RRA-1)e. Aux. Building Mat (2ERS-RRA-2)f. Aux. Building (2ERS-RRA-3)2. TRIAXIAL PEAK ACCELEROGRAPHSa. Containment Building - RHS heat exchanger(2ERS-PRA-1)b. Containment Building - Six lnch Sl Pipe(2ERS-PRA-2)c. Aux. Building (2ERS-PRA-3)3. RESPONSE SPECTRUM ANALYZERa. Control RoomNOTESMEASUREMENTRANGE(1)i1gt1gt1gi1gt1gt1gt2gt2gt5gN/AREQUIREDINSTRUMENTS(1)(2)(3)(4)Measurement range tolerance is + 5% of upper range value.Units a, b, c arg wired to accelerograph recorders in the Control Room. Units d, e, and fare self-contained units.Each accelerograph trigger setpoint is set at < 0.029 except for item "b"Triaxial time-history accelerograph - Units a and c are input directly to the responsespectrum analyzer in the Control Room.Beaver Valley Unit 23.3.6 - 3LRM Revision 52 Licensing Requirements ManualSeismic Monitoring Instrumentation3.3.6TABLE 3.3.6-2 (Page 1 of 1)SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTSCHANNELCHANNEL CHANNEL OPERATIONALINSTRUMENTS AND SENSOR LOCAT]ONS CHECK CALIBRATION TEST1. TRIAXIALTIME.HISTORYACCELEROGRAPHSa. Containment Mat (2ERS-ACS-1) Mb. Containment Operating floor M(2ERS-ACS-z)c. Switchyard (2ERS-ACS-3) M Rd. Containment Building (2ERS-RRA-1) N/A Re. Aux. Building Mat (2ERS-RRA-2) M Rf. Aux. Building (2ERS-RRA-3)2. TRIAXIAL PEAK ACCELEROGRAPHSa. Containment Building - RHS heat N/A Rexchanger (2ERS-PRA-1 )b. Containment Building - Six inch Sl N/A Rpipe (2ERS-PRA-2)c. Aux. Building (2ERS-PRA-3)3. RESPONSE SPECTRUM ANALYZERa. Control RoomM = 31 daysR = 18 monthsSA = 184 daysRRSASASASA SASAN/AN/AN/ARN/A RN/A N/ABeaver Valley Unit 23.3.6 - 4LRM Revision 52 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.7 Movable Incore DetectorsLR 3.3.7APPLICABILITY:CONDITIONMovable incore detectionsystem Nonfunctional.LRS 3.3.7 .1The movable incore detection system shall be FUNCTIONAL with:a. At least 75o/o of the detector thimbles,b. A minimum of 2 detector thimbles per core quadrant, andc. Sufficient movable detectors, drive, and readout equipment tomap these thimbles.When the movable incore detection system is used for:a. Recalibration of the axial flux offset detection system,b. Monitoring the QUADRANT POWER TILT RATIO, orc. Measurement of FIX and Fq(Z).COMPLETION TIMEMovable Incore Detectors3.3.7lmmediatelyFREQUENCYWithin 24 hoursprior to useA.SU RVEILLANCEThe incore movable detection system shall bedemonstrated FUNCTIONAL by normalizing eachdetector output to be used for:a. Recalibration of the excore axial flux offset detectionsystem, orMonitoring the QUADRANT POWER TILT RATIO, orMeasurement of FIX and Fq(Z).b.c.ACTIONSREQUIRED ACTIONA.1 Suspend use of the systemfor the above applicablemonitoring or calibrationfunctions.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.3.7 - 1LRM Revision 67 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.8 Leading Edge Flow MeterLR 3.3.8APPLlCABILITY:CONDITIONA. LEFM Nonfunctional.B. Required Action andassociated CompletionTime not met.Leading Edge Flow Meter3.3.8A FUNCTIONAL Leading Edge Flow Meter (LEFM) shall be used in theperformance of the daily calorimetric heat balance measurements todetermine steady-state THERMAL POWER as required by TechnicalSpecification Surveillance SR 3 .3.1 .2.MODE 1 when steady-state THERMAL POWER is > 98.6% of RTP.COMPLETION TIMEPrior to the nextrequired dailycalorimetric heatbalancemeasurement.t hourIn accordance with therequirements ofsR 3.3.1 .2Until the LEFM isrestored toFUNCT]ONAL statusand the calorimetricheat balancemeasurement hasbeen performed usingthe LEFMACTIONSREQUIRED ACTIONA.1 Restore LEFM toFUNCTIONAL status.Reduce steady-stateTHERMAL POWER to< 98.6% of RTP.8.2 Perform the calorimetricheat balance measurementusing the feedwater flowventuris and ResistanceTemperature Detector(RTD) indications.Maintain THERMALPOWER at < 98.6% ofRTP steady state.Beaver Valley Unit 2338-1LRM Revision 67 LICENSI NG REQU I REMENT SURVEILLANCESLicensing Requirements ManualLRS 3.3.8.1LRS 3.3.8.2SU RVEILLANCEThe LEFM shall be demonstrated to be FUNCTIONALby using the self-diagnostic features of the LEFM.The LEFM shall be demonstrated to be FUNCTIONALby performing the periodic maintenance and inspectionsrecommended by the manufacturer.Leading Edge Flow Meter3.3.8FREQUENCY24 hours18 monthsBeaver Valley Unit 233.8-2LRM Revision 67 Licensing Requirements ManualTurbine Overspeed Protection3.3.93.3 INSTRUMENTATION3.3.9 Turbine Overspeed ProtectionLR 3.3.9 At least one Turbine Overspeed Protection System shall beFUNCTIONAL.APPLICABILITY: MODE 1,MODES 2 and 3 except when all main steam isolation valves andassociated bypass valves are in the closed position and all othersteam flow paths to the turbine are isolated.ACTIONSCONDITIONREQUIRED ACTIONCOMPLETION TIMEA. One throttle valve or onegovernor valve per highpressure turbine steam lineNonfunctional and/or withone reheat stop valve orone reheat intercept valveper low pressure turbinesteam line Nonfunctional.A.1 Restore the Nonfunctionalvalve(s) to FUNCTIONALstatus.72 hoursB. Required Action andassociated CompletionTime of Condition A notmet.8.1 Close at least one valve inthe affected steam line(s).OR8.2 lsolate the turbine from thesteam supply.OR8.3 Apply LR 3.0.3.6 hours6 hours6 hoursC. Turbine OverspeedProtection SystemNonfunctional for reasonsother than Condition A.c.1ORc.2lsolate the turbine from thesteam supply.Apply LR 3.0 3.6 hours6 hoursBeaver Valley Unit 23.3.9 - 1LRM Revision 67 LICENSING REQUIREMENT SURVEILLANCESLicensing Requirements ManualTurbine Overspeed Protection3.3.9FREQUENCYSURVEILLANCE. NOTE .Not required to be performed untilT2hours afterentering MODE 3 during station startup with any steamflow path to the turbine not isolated.Cycle each of the following valves through at least onecomplete cycle from the running position:a. Four high pressure turbine throttle valves.b. Four high pressure turbine governor valves.. NOTE -Not required to be performed untilT2hours afterentering MODE 3 during station startup with any steamflow path to the turbine not isolated.Directly observe the movement of each of the followingvalves through one complete cycle from the runningposition:a. Four high pressure turbine throttle valves.b. Four high pressure turbine governor valves.- NOTE -Not required to be performed untilT2 hours afterentering MODE 3 during station startup with any steamflow path to the turbine not isolated.Cycle each of the following valves through at least onecomplete cycle from the running position:a. Four low pressure turbine reheat stop valves.b. Four low pressure turbine reheat intercept valves.LRS 3.3.9.1LRS 3.3.9.2LRS 3.3.9.36 months6 months18 monthsBeaver Valley Unit 23.3.9 - 2LRM Revision 71 Licensing Requirements ManualLICENSING REQUIREM ENT SURVEILLANCEScontinuedSURVEILLANCELRS 3.3.9.4Turbine Overspeed Protection3.3.9FREQUENCYLRS 3.3.9.5LRS 3.3.9.6- NOTE.Not required to be performed until72 hours afterentering MODE 3 during station startup with any steamflow path to the turbine not isolated.Directly observe the movement of each of the followingvalves through one complete cycle from the runningposition:a. Four low pressure turbine reheat stop valves.b. Four low pressure turbine reheat intercept valves.Perform a CHANNEL CALIBRATION on the turbineoverspeed protection systems.Disassemble at least one of each of the above valvesand perform a visual and surface inspection of valveseats, disks, and stems and verify no unacceptableflaws or excessive corrosion. lf unacceptable flaws orexcessive corrosion are found, all other valves of thattype shall be inspected unless the nature of the problemcan be directly attributed to a service condition specificto that valve.18 months18 months40 monthsOR. NOTE -Only applicable toreheat stop andintercept valvesprovided there isno indication ofoperationaldistress.60 monthsBeaver Valley Unit 23.3.9 - 3LRM Revision 52 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints3.3.1 03.3 INSTRUMENTATION3.3.10 RTS, ESFAS, and Loss of Power Trip SetpointsLR 3.3.10.1 Each Reactor Trip System Instrumentation Trip Setpoint listed inTable 3.3.10-1 shall be maintained in the manner specified in TechnicalSpecification (TS) 3.3.1, Reactor Trip System Instrumentation.LR 3.3.10.2 Each Engineered Safety Features Actuation System InstrumentationTrip Setpoint listed in Table 3.3.10-2 shall be maintained in the mannerspecified in TS 3.3.2, Engineered Safety Feature Actuation SystemInstrumentation.LR 3.3.10.3 Each Loss of Power Instrumentation Trip Setpoint listed inTable 3.3.10-3 shall be maintained in the manner specified in TS 3.3.5,Loss of Power Diesel Generator Start and Bus SeparationInstrumentation.APPLICABILITY: As specified in the applicable TS.Beaver Valley Unit 23.3.10 - 1LRM Revision 52 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints3.3.10TABLE 3.3.10-1 (Page 1 of 2)REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS1.2.FUNCTIONManual Reactor TripPower Range, Neutron Fluxa. High Setpointb. Low SetpointPower Range, Neutron Flux High PositiveRatelntermediate Range, Neutron FluxSource Range, Neutron FluxOvertemperature ATOverpower ATPressurizera. Pressure-Lowb. Pressure-HighPressurizer Water Level-Hig hReactor Coolant Flow-LowReactor Coolant Pump (RCP) BreakerPosition TripUndervoltage - RCPsUnderfrequency - RCPsSteam Generator Water Level-Low LowNOMINAL TRIP SETPOINT(")N.A.109% of RATED THERMAL POWER25O/O RATED THERMAL POWER5% of RATED THERMAL POWER with atime constant > 2 seconds25% RATED THERMAL POWER10s counts per secondSee Technical Specification TableNotation 3 on Table 3.3.1-1See Technical Specification TableNotation 4 on Table 3.3.1-11945 psig(o)2375 psig92% of instrument span90% of indicated loop flowN.A.3120 V57.5 Hz205% of narrow range instrument span(")3.4.5.6.7.B.9.10.11.12.13.14.(a)(b)(c)The Unit 2 Setpoint Methodology used to establish the Reactor Trip System Setpoints is definedin WCAP-1 1366.Time constants utilized in the lead-lag controller for Pressurizer Pressure-Low are ) 2 secondsfor lead and < 1 second for lag. Channel calibration shall ensure that these time constants areadjusted for those values.The predefined as-found acceptance criteria band, and as-left setpoint tolerance band is+ 0.5% span.Beaver Valley Unit 23.3.1 0 - 2LRM Revision 52 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints3.3.10TABLE 3.3.1 0-1 (Pag e 2 of 2)REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTSFUNCTION NOMINAL@i TRIP SETPOINT(")15. Turbine Tripa. Emergency Trip Header Low Pressure 1013 psig Ib. Turbine Stop Valve Closure 2 1o/o open16. Safety lnjection Input from ESFAS N.A.17. Reactor Trip System Interlocksa. lntermediate Range Neutron Flux, P-6 I x 10-10 ampsb. Low Power Reactor Trips Block, P7 N.A.c. Power Range Neutron Flux, P-8 30% of RATED THERMAL POWERd. Power Range Neutron Flux, P-9 49% of RATED THERMAL POWERe. Power Range Neutron Flux, P-10 10% of RATED THERMAL POWERt. Turbine First Stage Pressure, P-13 1A% of RATED THERMAL POWER TurbineFirst Stage Pressure Equivalent18. Reactor Trip Breakers (RTBs) N.A.19. RTB Undervoltage and Shunt Trip N.A.Mechanisms24. Automatic Trip Logic N.A.(a) The Unit 2 Setpoint Methodology used to establish the Reactor Trip System Setpoints is definedin WCAP-11366.(d) With the exception of Functional Unit number 15.b.Beaver Valley Unit 23.3.10 - 3LRM Revision 65 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints3.3.10TABLE 3.3.10-2 (Page 1 of 3)ENGINEERED SAFETY FEATURES ACTUATION SYSTEMlNSTRUMENTATION TRIP SETPOINTSNOM INAL TRIP SETPOINT(")1.FUNCTIONSAFETY INJECTION AND FEEDWATERISOLATIONa. Manual Initiationb. Automatic Actuation Logic and ActuationRelaysc. Containment Pressure - Highd. Pressurizer Pressure - Lowe. Steamline Pressure - LowCONTAINMENT SPRAY SYSTEMSa. Quench Spray1. Manual lnitiation2. Automatic Actuation Logic and ActuationRelays3. Containment Pressure-High Highb. Recirculation Spray1- Automatic Actuation Logic and ActuationRelays2. Refueling Water Storage Tank (RWST)Level Low Coincident withContainment Pressure High-H ighCONTAINMENT ISOLATIONa. Phase "A" lsolation1. Manual lnitiation2. Automatic Actuation Logic andActuation Relays3. Safety lnjectionN.A.N.A.5.0 psig(b)1856 psig500 psig(")N.A.N.A.1 1.1 psig(b)N.A.32 feet 9 inches(d)11.1 psig(b)N.A.N.A.See Function 1. above for all Safetylnjection Trip Setpoints.2.3.(a) The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature ActuationSystem Setpoints is defined in WCAP-1 1366.(b) The predefined as-found acceptance band, and the as-left tolerance band is + 0.3 psig.(c) Time constants utilized in the lead-lag controllers for Steam Line Pressure-Low are11 > 50 seconds and 12 < 5 seconds. CHANNEL CALIBRATION shall ensure that these timeconstants are adjusted to these values.(d) The predefined as-found acceptance band, and the as-lefttolerance band is

• 1".Beaver Valley Unit 23.3.10 - 4LRM Revision 56 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints3.3.10TABLE 3.3.10-2 (Page 2 of 3)ENGINEERED SAFETY FEATURES ACTUATION SYSTEMINSTRUMENTATION TRIP SETPOINTSNOM INAL TRIP SETPOTNT(U)3.FUNCTIONCONTAINM ENT ISOLATION (continued)b. Phase "8" lsolation1. Manual lnitiation2. Automatic Actuation Logic andActuation Relays3. Containment Pressure-High HighSTEAM LINE ISOLATIONa. Manual lnitiationb. Automatic Actuation Logic and ActuationRelaysc. Containment Pressure-lntermediateHigh Highd. Steam Line Pressure1. Low2. Negative Rate - HighN.A.N.A.11.1 psig(b)N.A.N.A.7.0 psig(b)500 psig(')100 psi with a time constant > 50 seconds92.2% of narrow range instrument span(d)See Function 1. above for all Safetylnjection Trip Setpoints.4.5.TURBINE TRIP & FEEDWATER ISOLATIONa. Automatic Actuation Logic and Actuation N.A.Relaysb. Steam Generator Water Level-HighHigh, P-14c. Safety lnjection(a)(b)(c)The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature ActuationSystem Setpoints is defined in WCAP-1 1366.The predefined as-found acceptance band, and the as-left tolerance band is +0.3 psig.Time constants utilized in the lead-lag controllers for Steam Line Pressure-Low aret1 > 50 seconds and q < 5 seconds. CHANNEL CALIBRATION shall ensure that these timeconstants are adjusted to these values.The predefined as-found acceptance criteria band, and as-left setpoint tolerance band is+ 0.5% span.(d)Beaver Valley Unit 23.3.10 - 5LRM Revision 56 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints3.3.10TABLE 3.3.1 0-2 (Page 3 of 3)ENGINEERED SAFETY FEATURES ACTUATION SYSTEMINSTRUMENTATION TRIP SETPOINTS6.FUNCTIONAUXILIARY FEEDWATERa. Automatic Actuation Logic and Actuation N.A.Relaysb. Steam Generator Water Level-Low Lowc. Safety lnjection (Start All AuxiliaryFeedwater Pumps)d. Undervoltage - RCP (Start Turbine DrivenPump)e. Trip of Main Feedwater Pumps (StartMotor Driven Pumps)AUTOMATIC SW]TCHOVER TOCONTAINMENT SUMPAutomatic Actuation LogicRefueling Water Storage Tank Level -Extreme LowCoincident with Safety InjectionESFAS ]NTERLOCKSa. Reactor Trip, P-4b. Pressurizer Pressure, P-1 1c. Tavg - Low-Low, P-12NOMINAL TRIP SETPOINT(")20.5o/o of narrow range instrument span(d)See Function 1. above for all SafetyInjection Trip Setpoints.3120 VN.A.N.A.31 feet 9 inches(")See Function 1. above for all Safetylnjection Trip Setpoints.N.A.2000 psig541"F7.a.b.8.(d)(e)(a) The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature ActuationSystem Setpoints is defined in WCAP-1 1366.The predefined as-found acceptance criteria band, and as-left setpoint tolerance band ist 0.5% span.The predefined as-found acceptance band, and the as-left tolerance band is
• 1".Beaver Valley Unit 23.3.10 - 6LRM Revision 52 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints3.3.10TABLE 3.3.10-3 (Page 1 of 1)LOSS OF POWERD]ESEL GENERATOR START AND BUS SEPARATIONINSTRUM ENTATION TRIP SETPOINTSFUNCTIONLOSS OF VOLTAGE1. 4160V Emergency Bus DG Start2. 4160V Emergency Bus SeparationDEGRADED VOLTAGE3. 4160V Emergency Bus Separation4. 480V Emergency Bus SeparationNOMINAL TRIP SETPOINT(U)3120 V with a time delay of 0.33 I 0.03seconds312A V with a I + 0.1 second time delay3885.4 V with a 90 + 5 second time delay448.3 V with a 90 + 5 second time delay(a) The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature ActuationSystem Setpoints is defined in WCAP-1 1366.Beaver Valley Unit 23.3.10 - 7LRM Revision 52 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.11 Fuel Storage Pool Area Radiation MonitorLR 3.3.11APPLICABILITY:CONDITIONA. Setpoint not within limit.B. Required monitorNonfunctional.Fuel Storage Pool Area Radiation Monitor3.3.11The Fuel Storage Pool Area Radiation Monitor (2RMF-RO202) shall beFUNCTIONAL with:a. Setpoint of < 75.8 mR/hr above background, andb. Measurement range of 10 104 mR/hr.With fuel in the storage pool or building.COMPLETION TIME4 hours4 hoursOnce per 24 hoursSU RVE ILLANC EFREQUENCYLRS 3.3.11.1Perform a CHANNEL CHECK.12 hoursLRS 3.3.11 .2Perform a CHANNEL OPERATIONAL TEST.31 daysLRS 3.3.11 3Perform a CHANNEL CALIBRATION.18 monthsACTIONSREQUIRED ACTIONA.1 Adjust the setpoint to withinthe limit.OR4.2 Declare the monitorNonfunctional.8.1 Perform area surveys ofthe monitored area withportable monitoringinstrumentation.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23311-1LRM Revision 67 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.12 ExplosiveGasMonitoring InstrumentationLR 3.3.12Explosive Gas Monitoring Instrumentation3.3.12APPLlCABILITY:ACTIONSTwo channels of the Gaseous Waste System Surge Tank DischargeOxygen Monitor (2GWS-OA100A&B) shall be OPERABLE withAlarm/Trip Setpoints set to ensure the limits of LR 3.7.6 are notexceeded.- NOTE .The requirements of LR 3.3.12 are part of the Technical Specification5.5.8, "Explosive Gas and Storage Tank Radioactivity MonitoringProgram."During waste gas decay tank filling operation.COMPLETION TIMEA.B.CONDITIONOne or more requiredchannels with Alarm/Tripsetpoint less conservativethan required.One required channelinoperable.lmmediatelyOnce per 24 hours30 daysREQUIRED ACT]ONA.1 Declare the affectedchannel(s) inoperable,8.1 Take and analyze grabsamples.8.2 Restore inoperablechannel to OPERABLEstatus.Beaver Valley Unit 23.3.12 - 1LRM Revision 52 Licensing Requirements ManualACTIONS (continuedCONDITIONC. Two required channelsinoperable.Required Action andassociated CompletionTime not met.SURVEILLANCELRS 3.3.12.1Perform CHANNEL CHECK.LRS 3.3.12.2Perform CHANNEL OPERATIONAL TEST.LRS 3.3.12.3Explosive Gas Monitoring Instrumentation3.3.12COMPLETION TIMEOnce per 4 hoursduring degassingoperationsANDOnce per 24 hoursduring otheroperations30 days30 daysFREQUENCY24 hours31 daysD.. NOTEThe CHANNEL CALIBRATION shall include the use ofstandard gas samples containing a nominal:1. One volume percent oxygen, balance nitrogen, and2. Four volume percent oxygen, balance nitrogen.Perform CHANNEL CALIBRATION.92 daysREQUIRED ACTIONC.1 Take and analyze grabsamples.ANDC.2 Restore inoperablechannels to OPERABLEstatus.D.1 Prepare and submit aSpecial Report inaccordance with 10 CFR50.4 to explain why theinoperability was notcorrected in a timelymanner.LICENSING REQUIREM ENT SURVEILLANCESBeaver Valley Unit 23.3.1 2 - 2LRM Revision 52 Licensing Requirements ManualLRS 3 3 13.13.3 INSTRUMENTATION3.3.13 ContainmentHydrogenAnalyzersLR 3.3.13APPLICABILITY:MODES 1 and 2.SU RVEILLANCEPerform a CHANNEL CALIBRATION using samplegases containing:1. One volume percent hydrogen, balance nitrogen, and2. Four volume percent hydrogen, balance nitrogen.Two separate and independent wide-range containment hydrogenanalyzers shall be FUNCTIONAL.Containment Hydrogen Analyzers3.3.13FREQUENCY46 days on aSTAGGEREDTEST BASISACTIONSCONDlTIONREQUIRED ACT]ONCOMPLETION TlMEA. One wide-range hydrogenanalyzer Nonfu nctiona LA.1 Restore the Nonfunctionalanalyzer to FUNCTIONALstatus.30 daysB. Two wide-range hydrogenanalyzers N onfunctional.8.1 Restore at least one wide-range hydrogen analyzer toFUNCTIONAL status.72 hoursC. Required Action andassociated CompletionTime not met.C.1 Apply LR 3.0.3.lmmediatelyLICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 233.13-1LRM Revision 67 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.14 Control Room lsolation Radiation MonitorsLR 3.3.14Control Room lsolation Radiation Monitors3.3.14Monitors (2RMC-RQ201 & 202)background, andmR/hr.Two Control Room lsolation Radiationshall be FUNCTIONAL with:a. Setpoint of < 0.476 mR/hr aboveb. Measurement range of 10 103MODES 1,2,3, and 4.APPLICABILITY:ACTIONSCONDITIONREQUIRED ACTIONCOMPLETION TIMEA. Setpoint not within limit.A.1 Adjust the setpoint to withinthe limit.ORA.2 Declare the monitorNonfunctional.4 hourshoursB. One monitor Nonfunctional8.1 Restore the Nonfunctionalmonitor to FUNCTIONALstatus.OR8.2 lsolate the combinedcontrol room by closing allseries normal air intakeand exhaust isolatrondampers for both Unit 1and Unit 2.7 days7 daysC. Two monitorsNonfunctional.C.1 Restore one monitor toFUNCTIONAL status.ORC.2 lsolate the combinedcontrol room by closing allseries normal air intakeand exhaust isolationdampers for both Unit 1and Unit 2.hourhourBeaver Valley Unit 23.3.14 - 1LRM Revision 67 LICENSI NG REQUIREMENT SURVEILLANCESLicensing Requirements ManualSURVEILLANCELRS 3.3.14.1Perform a CHANNEL CHECK.LRS 3.3.14.2Perform a CHANNEL OPERATIONAL TEST.LRS 3.3.14.3Perform a CHANNEL CALIBRATION.Control Room lsolation Radiation Monitors3.3.1 4FREQUENCYBeaver Valley Unit 23.3.1 4 - 2LRM Revision 53 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.15 Containment Area Radiation AlarmLR 3.3.15APPLICABILITY:MODES 1 , 2, 3, and 4.CONDITIONA. Setpoint(s) not within limit.One or more alarmchannels Nonfunctional.Containment Area Radiation Alarm3.3.15COMPLETION TIME4 hours4 hours72 hours72 hours30 daysln the next AnnualRadioactive EffluentRelease ReportTwo channels of Containment Area Radiation Alarms (2RMR-RQ206 &207) shall be FUNCTIONAL with:a. Setpoints of < 2.0 x 104 R/hr above background, andb. Measurement range of 1 to 107 R/hr.B.ACTIONSREQUIRED ACTIONA.1 Adjust the setpoint(s) towithin the limit.ORA.2 Declare the radiationmonitor alarmNonfunctional.Restore the Nonfunctionalalarm channel(s) toFUNCTIONAL status.lnitiate the preplannedalterirate method ofmonitoring the appropriateparameter(s).Restore the alarmchannel(s) toFUNCTIONAL status.OR8.2.3 Explain why theNonfunctionality was notcorrected in a timelymanner.Beaver Valley Unit 23.3.15 - 1LRM Revision 67 LICENSING REQUIREMENT SURVEILLANCESLicensing Req uirements ManualSURVEILLANCELRS 3.3.1 5.1Perform a CHANNEL CHECK.LRS 3.3.15.2Perform a CHANNEL OPERATIONAL TEST.LRS 3.3.1 5.3Perform a CHANNEL CALIBRATION.Containment Area Radiation Alarm3.3.15FREQUENCYBeaver Valley Unit 23.3.1 5 - 2LRM Revision 52 Licensing Requirements M anual3.3 INSTRUMENTATION3.3.16 Accident Monitoring InstrumentationLR 3.3.1 6APPLICABILITY: MODES 1,2, and 3.ACTIONSAccident Monitoring Instrumentation3.3.16The Accident Monitoring instrumentation for each Function inTable 3.3.16-1 shall be OPERABLE/FUNCTIONAL.1.2.. NOTES -Separate Condition entry is allowed for each Function.For Functions 2 and 3 refer to LCO 3.4.11, Pressurizer Power Operated Relief Valves, forthe appropriate ACTIONS in lieu of the LR 3.3.16 ACTIONS below.CONDITIONCOMPLETION TIMEOne or more Functionswith one required channelNonfunctional.7 daysRequired Action andassociated CompletionTime not met.lmmediatelyLICENSING REQUIREMENT SURVEILLANCESSU RVE ILLANCEFREQUENCYLRS 3.3.16.1Perform a CHANNEL CHECK.31 daysLRS 3.3.16.2- NOTE .Only applicable to the Reactor Coolant SystemSubcooling Margin Monitor Function.Perform a CHANNEL CALIBRATION.18 monthsA.B.REQUIRED ACTIONA.1 Restore the Nonfunctionalchannel to FUNCTIONALstatus.8.1 Apply LR 3.0.3.Beaver Valley Unit 23.3 16-1LRM Revision 81 Licensing Requirements ManualLICENSING REQUIREMENT SURVEILLANCEScontinuedSURVEILLANCELRS 3.3.16.3Accident Monitoring I nstrumentation3.3.16FREQUENCYOnly applicable to the following Functions:a. PORV Limit Switch Position Indicator.b. PORV Block Vafve Limit Switch Position Indicator.andc. Safety Valve Position Indicator.Perform a TADOT.18 monthsBeaver Valley Unit 23.3.16 - 2LRM Revision 81 Licensing Requirements Manual1.2.3.4.Table 3.3.16-1 (page 1 of 1)Accident Monitoring I nstrumentationFUNCTIONReactor Coolant System Subcooling Margin MonitorPORV Limit Switch Position IndicatorPORV Block Valve Limit Switch Position lndicatorSafety Valve Position lndicatorAccident Monitoring I nstrumentation3.3.16REQUIRED CHANNELS11 per valve1 per valve1 per valveBeaver Valley Unit 23.3.16 - 3LRM Revision 81 Licensing Requirements Manual3.4 REACTOR COOLANT SYSTEM (RCS)3.4.1 Loop lsolation Valves - ShutdownLR 3.4.1Loop lsolation Valves - Shutdown3.4.1APPLICABILITY:ACTlONSCONDITIONA. LR not met.LRS 3.4.1.1The loop isolation valves in an isolated RCS loop shall have powerremoved from the associated loop isolation valve operators.. NOTE .Power may be restored to the associated RCS isolated loop isolationvalve operator(s) provided the requirements of Technical SpecificationSurveillance 3.4.18.2 have been satisfied.ln MODES 5 and 6 when an RCS loop has been isolated.COMPLETION TIMESURVEILLANCEFREQUENCYVerify that power is removed from the RCS isolatedloop stop valve operators.7 daysREQUIRED ACTIONA.1 Remove power from theisolated loop isolation valveoperators.LICENSING REQUlREMENT SURVEILLANCESBeaver Valley Unit 23.4.1 - 1LRM Revision 52 Licensing Requirements ManualChemistry3.4.23.4 REACTOR COOLANT SYSTEM (RCS)3.4.2 ChemistryLR 3.4.2 The RCS chemistry shall be maintained within the limits specified inTable 3.4.2-1 .APPLICABILITY: At all times.ACTIONSCONDITIONREQUIRED ACTIONCOMPLETION TIMEA.. NOTE -Only applicable inMODES 1 , 2, 3, and 4 .One or more chemistryparameters in excess of itsSteady State Limit butwithin its Transient Limit.,A.1 Restore the Parameter towithin its Steady StateLimit.24 hoursB. Required Action andassociated CompletionTime of Condition A notmet.8.1 Apply LR 3.0 3.lmmediatelyC.. NOTE .Only,applicable inMODES 1 , 2, 3, and 4.One or more chemistryparameters in excess of itsTransient Limit.C.1 Apply LR 3.0.3lmmediatelyBeaver Valley Unit 23.4.2 - 1LRM Revision 67 Licensing Requirements ManualACTIONS (continuedCONDITION. NOTE .Not applicable inMODES 1 , 2, 3, and 4.Concentration of eitherchloride or fluoride in theRCS in excess of itsSteady State Limit for morethan 24 hours or in excessof its Transient Limit.. NOTE -Not applicable inMODES 1,2,3,4, 5 and 6.Unable to determine limitsof chloride or fluoride in theRCS due to the inability tosample the RCS.LRS 3.4.2.1S U RVE ILLANCEThe RCS chemistry shall be determined to be within thelimits specified in Table 3.4.2-1 by analysis.Chemistry3.4.2COMPLETION TIMEPrior to increasing thepressurizer pressureabove 500 psig orprior to proceeding toMODE 4lmmediatelyFREQUENCY72 hoursREQUIRED ACTIOND.1 Reduce the pressurizerpressure to < 500 psig, ifapplicable, and perform ananalysis to determine theeffects of the out-of-limitcondition on the structuralintegrity of the RCS;determine that the RCSremains acceptable forcontinued operations.. NOTE .Required Action E.1 is onlyapplicable when the abilityto sample the RCS isrestored.Initiate action to performLRS 3.4.2.1 .LICENSI NG REQU IREMENT SURVEILLANCESBeaver Valley Unit 23.4.2 - 2LRM Revision 68 Licensing Requirements ManualPARAMETERCHLORIDEFLUORIDE.Limit not applicable with Tuus S 250'F.Chemistry3.4.2TABLE 3.4.2-1 (Page 1 of 1)REACTOR COOLANT SYSTEM CHEMISTRY LIMITSSTEADY-STATELIMITDISSOLVED OXYGEN. < 0.10 ppm*TRANSIENTLIMIT< 1.00 ppm*< 1.50 ppm< 1.50 ppm< 0.15 ppm< 0.15 ppmBeaver Valley Unit 23.4.2 - 3LRM Revision 52 Licensing Requirements Manual3.4 REACTOR COOLANT SYSTEM (RCS)3.4.3 PressurizerLR 3.4.3 The pressurizer temperature shall be limited to:Pressurizer3.4.3APPLICABILITY:ACTlONSa. A maximum heatup of 100"F in any one hour period,b. A maximum cooldown of 2A0"F in any one hour period,c. A maximum normal spray water temperature differential of 320oF,andd. A maximum auxiliary spray water temperature differential of380'F.At all times.COMPLETION TIME30 minutesA.CONDITIONP ressu rizer te m pe ratu relimit(s) exceeded.Required Action andassociated CompletionTime not met.B.REQUIRED ACTIONRestore temperature towithin the limit(s).Perform an engineeringevaluation to determine theeffects of the out-of-limitcondition on the structuralintegrity of the pressurizer.Determine that thepressurizer remainsacceptable for continuedoperation.8.1 Be in MODE 3.AND8.2 Reduce the pressurizerpressure to less than500 psig.Beaver Valley Unit 23.4.3 - 1LRM Revision 52 LICENSING REQUIREMENT SURVEILLANCESLicensing Requirements ManualLRS 3.4.3.1LRS 3.4.3.2LRS 3.4.3.3SURVEILLANCEThe pressurizer temperatures shall be determined to bewithin the limits.The normal spray water temperature differential shall bedetermined to be within the limit.The auxiliary spray water temperature differential shallbe determined to be within the limit.Pressurizer3.4.3FREQUENCYOnce per30 minutes duringsystem heatup orcooldownOnce per30 minutes duringsystem heatup orcooldownOnce per30 minutes duringauxiliary sprayoperationBeaver Valley Unit 23.4.3 - 2LRM Revision 52 Licensing Requirements Manual3.4 REACTOR COOLANT SYSTEM (RCS)3.4.4 DELETED3.4.4Beaver Valley Unit 23.4.4 - 1LRM Revislon 67 Licensing Requirements Manual3.4 REACTOR COOLANT SYSTEM (RCS)3.4.5 RCS Head VentsLR 3.4.5RCS Head Vents3.4.5All power operated RCS head vent valves shall be FUNCTIONAL andclosed for each of the reactor vessel head vent paths.. NOTES -For purposes of this LR, a Nonfunctional vent valve is defined as:a valve which exhibits leakage in excess of LCO 3.4.13, "RCSOperational LEAKAGE," limits, or cannot be opened and closedon demand.The vent valves may be operated for required venting operationsand leak testing in MODES 3 and 4.1.2.A.APPLICABILITY:MODES 1 , 2, 3, and 4.CONDlTIONOne vent path from theabove locationFUNCTIONAL and one ormore power operated ventvalves Nonfunctional.COMPLETION TIMElmmediatelyACTIONSREQUIRED ACTION. NOTE -Power operation maycontinue and entry intoMODES 1-4 is notrestricted until the nextscheduled outage, at whichtime all RCS head ventvalves shall beFUNCTIONAL prior toentry into MODE 1 .Maintain the Nonfunctionalvalve(s) closed with powerremoved.Beaver Valley Unit 23.45-1LRM Revision 67 B.Licensing Requirements ManualACTIONS (continuedCONDITIONAll vent paths from theabove locationNonfunctional.LRS 3.4.5.1RCS Head Vents3.4.5COMPLETION TIMElmmediatelylmmediately72 hours72 hoursFREQUENCY18 monthsb.c.SU RVEILLANC EEach RCS head vent path shall be demonstratedFUNCTIONAL by:a. Verifying the manual isolation valve in the vent pathis locked or sealed in the open position.Cycling each valve in the vent path through at leqstone complete cycle of full travel from the controlroom.Verifying flow through the RCS Head vent path tothe Pressurizer Relief Tank.REQUIRED ACTION8.1 Maintain the Nonfunctionalvalves closed with powerremoved.OR8.2.1 Close the manual isolationvalves.AND8.2.2 Restore one vent path fromthe above locations toFUNCTIONAL status.OR8.3 Apply LR 3.0.3.LICENSlNG REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.4.5 - 2LRM Revision 67 Licensing Requirements ManualPressurizer Safety Valve Lift Involving Loop Seal or Water Discharge3.4.63.4 REACTOR COOLANT SYSTEM (RCS)3.4.6LR 3.4.6APPLICABILITY:- NOTE .Required Action A.3 shall becompleted whenever thisCondition is entered.A. One or more pressurizersafety valve(s) lift asindicated by the safetyvalve position indicator withloop seal or waterdischarge.Pressurizer Safety Valve Lift Involving Loop Seal or Water DischargeThe OPERABILITY of pressunzer safety valve(s) shall be evaluatedafter a lift involving loop seal or water discharge.MODES 1, 2, and 3,MODE 4 with all RCS cold leg temperatures > the enable temperaturespecified in the PTLR.CONDITIONCOMPLETION TIME6 hours24 hours30 hoursACTIONSREQUlRED ACTIONA.1 Be in MODE 3.4.2 Be in MODE 4 with anyRCS cold leg temperature< the enable temperaturespecified in the PTLR withRCS overpressureprotection provided inaccordance with therequirements of TechnicalSpecification 3.4.12.Initiate action to evaluatethe OPERABILITY of theaffected valve(s).Beaver Valley Unit 234.6-'rLRM Revision 67 LICENSING REQUIREMENT SURVEILLANCESLicensing Requirements ManualPressurizer Safety Valve Lift Involving Loop Seal or Water Discharge3.4.6SURVEILLANCEFREQUENCYLRS 3.4.6.1No additional requirements other than the applicablerequirements of the lnservice Testing Program.ln accordancewith the InserviceTesting Program.Beaver Valley Unit 23.4.6 - 2LRM Revision 52 Licensing Requirements Manual3.4 REACTOR COOLANT SYSTEM (RCS)3.4.7 RCS Pressure lsolation ValvesLR 3.4.7APPLICABILlTY:RCS Pressure fsolation Valves3.4.7Each Pressure lsolation Valve listed in Table 3.4.7-1 shall bemaintained OPERABLE in accordance with the requirements ofTechnical Specification (TS) 3.4.14, "RCS Pressure lsolation Valves(PlV) Leakage."As specified in TS 3.4.14.Beaver Valley Unit 23.4.7 - 1LRM Revision 52 Licensing Requirements ManualSYSTEMLoop 21, Cold leg, LHSILoop 22, Cold leg, LHSILoop 23, Cold leg, LHSICommon, Cold leg, LHSILoop 22, Hot leg, LHSILoop 23, Hot leg, LHSICommon, Hot leg, LHSILoop 21, Cold leg, SIACCLoop 22, Cold leg, SIACCLoop 23, Cold leg, SIACCLoop 21, Hot leg, RHS-ALoop 22, Cold legLoop 21, Hot leg, RHS-BLoop 23, Cold legNOTES:RCS Pressure lsolation Valves3.4.7TABLE 3.4.7-1 (Page 1 of 1)RCS PRESSURE ISOLATION VALVESVALVE NO.25rS-10725rS-10825rS-10925tS-13225tS-13325tS-12825tS-12925tS-13025rS-15125rS-14825lS-14525lS-14725rS-14125tS-1422RHS-M OV7O2A2RHS-MOV7O1A2RHS-MOV7zOA2RHS-MOV702B2RHS-MOV7O1B2RHS-MOV72OBNOTES(1X2)(1X2)(1 X2)(2)(2)(1)(1)(1 X2)(1 X2)(1)(1)(1)(1)(1)(1)1. Minimum test differential pressures shall not be less than 150 psid.2. Valve requires additional verification of leakage within the limit prior to entering MODE 2whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has notbeen performed in the previous 9 months as specified in SR 3.4.14.1.Beaver Valley Unit 23.4.7 - 2LRM Revision 52 Licensing Requirements Manual3.6 CONTAINMENT3.6.1 Containment lsolation ValvesLR 3.6.1APPLICABILITY:As specified in TS 3.6.3.Containment lsolation Valves3.6.1Each containment isolation valve listed in Table 3.6.1-1 shall bemaintained in the manner specified in Technical Specification (TS)3.6.3.Beaver Valley Unit 23.6.1 - 1LRM Revision 52 Nroc.o.cnc)ttJ{ I {{ 3Z v ZZ vOOOO(o (o co (oVVVV3$sdEfoc")=c\

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• E *8nE P I eE orE - e-'- (J-^- J C -A09U s P Eil-o* E F IgE; S E 3..i.P.q u h E-ac @ xEEE * ; H?il=.q) a 7, 'FtieT $ E c0;a E e *EfiE 3 9 *E6= al cu -9i,-c -oBe* i P *LiB=a 463= =t919TLtt.O(.)ro Lo ro rf)OOOOrrooooaaaaltll3383 p sNNNNZ.Z.c)f*aj --oi gE= 5:* EE f=El* sF 5:erH iru t=;lE f;l ftprr: irE =FElE 8;3 **o oE-q *s8 i: za A Efr -*ot-'7 E T3 i*:\l:0 o- e: F'-rb= 5 HE i-'lr-fr o- o: cnF-tlrFqlu i EE iF#l?zsH F g; ba5lTF.LZ E 3, = t.ritu : Y o:= g .oE"7 -5= 5 BEsE#c0Fz.z I ; ; ; *-'. >lro ! O O O d 3 u_t Jlo e q q q t= detlo @ A A i o- <lu:l-= 999 != ffi<31a ft ft ft Htq aBSl= or6x 'L--lv' a .E.>co alc=!-r-b 6 oEEig" b b b EEb:z rF ,.'- ,{- g 3 ei; E:H,Eg :i qd* ff H h H5E n^68_ = = = e;E R 5lFf n n A s;u !=31a $; 7, ?,7, EE,e etHl31 7 a a @ ,D;*; i ol.sl =EEr A; ft ft tu o='-=l -vo -oi0l e* e&8Yi.,lFull+lol f_zt=0)r9.?Gcoco$oacq)Ec'$coOOOOOMMcrid<<<<<omuor-r-lo ro ro Lo l.() roOOOOOOrrF-rooooooaaaa@@tllllla@aaaaaaaa@aNNNNNNofc$acoEc)!-'5gq)x.O)c'acq).(JJ Licensing Requirements Manual3.6 CONTAINMENT3.6.2 Containment SumpLR 3.6.2APPLICABlLITY:MODES 1,2,3, and 4.CONDITIONA. LR not met.LRS 3.6.2.1LRS 3.6.2.2The containment does not have loose debris present that could betransported to the containment sump and cause restriction of theEmergency Core Cooling System pump suctions during LOCAconditions.Containment Sump3.6.2COMPLETION TIMElmmediatelyFREQUENCYSU RVEILLANCE- NOTE .Only required to be performed if LRS 3.6.2.2 is not metfor each containment entry.Verify by visual inspection of all accessible areas of thecontainment that no loose debris (rags, trash, clothing,etc.) is present in the containment which could betransported to the containment sump and causerestriction of the Emergency Core Cooling Systempump suctions during LOCA conditions.Verify by visual inspection of the areas affected withincontainment that no loose debris (rags, trash, clothing,etc.) is present in the containment which could betransported to the containment sump and causerestriction of the Emergency Core Cooling Systempump suctions during LOCA conditions.Prior toestablishingcontainmentOPERABlLITYper TechnicalSpecification3.6.1At the completionof eachcontainment entryACTIONSREQUIRED ACTIONA.1 Apply the provisions ofLR 3.0.3.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.6.2 - 1LRM Revision 52 Licensing Requirements ManualSteam Generator Pressureffemperature Limitation3.7.13.7 PLANT SYSTEMS3.7.1 Steam Generator Pressure/Temperature LimitationLR 3.7.1 The pressure of the primary and secondary coolants in each steamgenerator shall be < 200 psig.APPLICABILITY:Whenever the temperature of the primary or secondary coolant in theassociated steam generator is < 70'F and the primary orsecondary systems of the associated steam generator arecapable of being pressurized.CONDITIONCOMPLETION TIMEA. LR not met.30 minutesPrior to increasing itstemperatures above200"FSU RVEILLANCEFREQUENCYLRS 3.7 .1 .1Verify the pressure in each side of the steam generatoris < 200 psig.Once per hourACTIONSREQUIRED ACTIONReduCe the steamgenerator pressure of theapplicable side to< 200 psig.AND4.2 Perform an analysis todetermine the effect of theoverpressurization on thestructural integrity of thesteam generator.Determine that the steamgenerator remainsacceptable for conti nuedoperation.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.7.1 - 1LRM Revision 52 Licensing Requirements Manual3.7 PLANT SYSTEMS3.7 .2 Flood ProtectionLR 3.7.2APPLICABILITY:At all times.LRS 3.7 .2.1LRS 3.7 .2.2Flood protection shall be provided for all safety related systems,components and structures when the water level of the Ohio Riverexceeds 695 Mean Sea Level at the intake structure.Flood Protection3.7.2FREQU ENCY24 hours2 hoursSU RVEILLANCEWhen the water level is < elevation 690 Mean SeaLevel, verify water level at the intake structure.When the water level is > elevation 690 Mean SeaLevel, verify water level at the intake structure.ACTIONSCONDITIONREQUIRED ACTIONCOMPLETION TIMEA. Water level at the intakestructure above elevation695 Mean Sea Level.A.1 Install and seal the flooddoors in the intakestructure.8 hoursB.- NOTE -Only applicable inMODES 1 , 2, 3, and 4.Water level at the intakestructu re above elevation695 Mean Sea Level.8.1 Confirm the actual OhioRiver level is < 700 MeanSea Level.AND8.2 Verify the forecasted peakOhio River level is < 700Mean Sea Level.lmmediately2 hoursC. Required Action andassociated CompletionTime of Condition A or Bnot met in MODES 1, 2, 3,and 4.C.1 Apply LR 3.0.3.lmmediatelyLICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.7.2 - 1LRM Revision 67 Licensing Requirements Manual3.7 PLANT SYSTEMS3.7.3 Sealed Source ContaminationLR 3.7.3APPLICABILITY:At all times.CONDITIONSealed source removablecontamination in excess ofthe limit.Sealed source or fissiondetector feakage testsreveal the presence of> 0.005 microcuries ofremovable contam ination.Each sealed source containing radioactive material either in excess of100 microcuries of beta and/or gamma-emitting material or5 microcuries of alpha-emitting material shall be free of> 0.005 microcuries of removable contamination.Sealed Source Contamination3.7.3COMPLETION TIMElmmediatelylmmediatelylmmediatelyOn an annual basisA.B.ACTIONSREQUIRED ACTIONA.1 Withdraw the sealedsource from use.AND4.2.1 Initiate action todecontaminate and repairthe sealed source.ORA.2.2 lnitiate action to dispose ofthe sealed source inaccordance withCommission Regulations.8.1 Prepare and submit aSpecial Report inaccordance with 10 CFR50.4.Beaver Valley Unit 23.7.3 - 1LRM Revision 52 1.2.Licensing Requirements ManualSealed Source Contamination3.7.3LICENSING REQUIREMENT SURVEILLANCES- NOTES .Each sealed source shall be tested for leakage and/or contamination by the licensee orother persons specifically authorized by the Commission or an Agreement State.The test method shall have a detection sensitivity of at least 0.005 microcuries per testsample.Startup sources and fission detectors previously subjected to core flux are excluded fromthe following test requirements.SURVEILLANCEFREQUENCYLRS 3.7.3.1For sealed sources in use containing radioactivematerials with a half-life > 30 days (excludingHydrogen 3) and in any form other than gas, verifyremovable contamination within the limit.LRS 3.7.3.2For stored sealed sources and fission detectors not inuse, verify removable contamination within the limit.LRS 3.7.3.3For sealed sources and fission detectors transferredwithout a certificate indicating the last test date, verifyremovable contamination within the limit.LRS 3.7.3.43.For sealed startup sources and fission detectors, verifyremovable contamination within the limit.6 monthsPrior to use ortransfer toanother licenseeunless testedwithin theprevious6 monthsPrior to use31 days prior tobeing installed inthe core orexposed to corefluxANDFollowing repairor maintenance tothe sourceBeaver Valley Unit 23.7.3 - 2LRM Revision 52 Licensing Requirements Manual3.7 PLANT SYSTEMS3.7.4 SnubbersLR 3.7.4 All snubbers shall be FUNCTIONAL.APPLICABILITY:CONDITIONOne or more requiredsnubbers Nonfunctional.Snubbers3.7.4A.. NOTE .Snubbers excluded from this LR are those installed on non-safety-related systems and then only if their failure or failure of the system onwhich they are installed, would have no adverse effect on any safety-related system.MODES 1,2, 3, and 4,MODES 5 and 6 for snubbers located on systems required OPERABLE/FUNCTIONAL in those MODES.. NOTE .The systems required in MODES 5 and 6 are defined as those portionsor subsystems required to prevent releases in excess of 10 CFR 50.67limits.COMPLETION TIMEln accordance withTable 3.7.4-1ln accordance withTable 3.7.4-1ACTIONSREQUIRED ACTIONA.1 Replace or restore theNonfunctional snubber(s)to FUNCTIONAL status.AND4.2.1 Perform an engineeringevaluation per ParagraphISTD-1800 of the ASMEOM Code on the supportedcomponent.ORBeaver Valley Unit 23.7.4 - 1LRM Revision 67 Licensing Requirements ManualACTIONScontinuedCONDITIONLRS 3.7.4.1Snubbers3.7.4SURVEILLANCEEach snubber shall be demonstrated FUNCTIONAL inaccordance with Subsection ISTD, "Preservice andlnservice Examination and Testing of DynamicRestraints (Snubbers) in Light-Water Reactor PowerPlants," ASME OM Code 2001 Edition up to andincluding the 2003 Addenda. Preservice and inserviceexamination of snubbers shall be performed using theVT-3 visual examination method described in IWA-2213of the ASME BPV Code, Section Xl. (

Reference:

Paragraph (b)(3Xv) of 10 CFR 50.55a, "Codes andStandards.")COMPLETION TIMEln accordance withTable 3.7.4-1FREQUENCYIn accordancewith SubsectionISTD of theASME OM Code2001 Edition up toand including the2003 AddendaREQUIRED ACTIONA.2.2 Declare the supportedsystem inoperable/Nonfunctional (asapplicable) and follow theappropriate ACTIONS forthat system.LICENSI NG REQUIREMENT SURVEI LLANCESBeaver Valley Unit 23.7.4 - 2LRM Revision 67

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ocE(D*aAE=aa6 e.t()&r-r-r ob3(/) rt>c.t OcEG)*aAE=aaMNodONulob3(f) -(>erocEQ)+$aE=aa6 o.to0!-oto-codrr)Oo*U)=aNcoo3omt-c)tr(D-c.*rr)Oro*U)=U)Ncoo3omod&I.IJ <b8(/) -t>c.t ocEO*aaE=@a6 crtodNru<b3(f) rt>elocEO*aaE=aaEorNr.rJ <b3U)-t->NocE(l)*aaE=av)MNoomNIIJ Mb8(l) -t>elocE O*au)E=a)a6orodotro*colr)Oo*@=ac!Co0)Ec)mc)tCIodmrf)oo*a=U'c\cCICI=oc0oGooJcso-OF-c{X:tr(f)0tEo!-\+-\vcCI!-tT{-c.9ca=U)COONXIaat-EoLrtsCI.go!--cO.9Ev)=U)(o-OrNXIU)U)tEorFo.Eoo)t-\U-c.C).9!a=a(orNxIa(/)tEol-rFq)cq)o)t-$-cO.aEa=v)(0rNXraaE.Eot*ocq)o)l-o-c().9oa=a(oNxICNv)E.Eot-rFoca)Ct)t-o-co.2cU)=U)(oNxIaU)tEoc).trc)O)t-$-cC).a!a=a(orNXIU)atEot-rFq)cc)o')t-Cg-c(J.9EU)=a(0coc\X-U)U)tEo!-o.EQ)o)!-(u-cC).9.E@=a(o-mNXIa@tEot-r+-o.Eol-$-c.().9. aa=a(orco-NX=U)@tEo!-rFCIcc)o)!-$-co.2EU)=U)COo(EooJEoollOl-f.-o_Qa(L6=aNmONNfLaaILI@=aNt-l-o_aCIo_Ia=aNNl-F.-(Laa(LIa=aNmNl-l'-L(f)QTLIa=@c!ccf,*1'-o_@ao_Ia=aNmcv)NN(LU)U)(LIa=U)N.f,f-t-o_aU) IL!a=U)NOc/)@o_aaILIU)=U)NNcf)@(L(/)a&Ia=@NmNCD@o_aaILIct)=0N Licensing Requirements Manual3.7 PLANT SYSTEMS3.7.5 Standby Service Water System (SWE)LR 3.7.5APPLICABILITY:MODES 1 , 2, 3, and 4.CONDITIONRequired SWE subsystemNonfunctional.Required Action andassociated CompletionTime not met.LRS 3.7.5.1LRS 3.7.5.2Standby Service Water System (SWE)3.7.5COMPLETION TIME7 dayslmmediatelyFREQUENCY92 days18 months on aSTAGGEREDTEST BASISAt least one of the two standby service water subsystems shall beFUNCTIONAL.A.B.SURVEILLANCEVerify that the required SWE pump develops at least109 psid differential pressure, while pumping through itstest flow line.Start the required SWE pump, shut down one ServiceWater System Pump, and verify that the SWEsubsystem provides at least 8584 gpm cooling water tothat portion of the Service Water System under test forat least 2 hours.ACTIONSREQUIRED ACTIONA.1 Restore at least onesubsystem toFUNCTIONAL status.8.1 Apply LR 3.0.3.LICENSING REQU I REMENT SURVEILLANCESBeaver Valley Unit 23.7.5 - 1LRM Revision 69 Licensi ng Requirements Manual3.7 PLANT SYSTEMS3.7.6 Explosive Gas MixtureLR 3.7.6Explosive Gas Mixture3.7.6The concentration of oxygen in the waste gas holdup system shall belimited to < 2% by volume whenever the hydrogen concentration is> 4o/o by volume.. NOTE .The requirements of LR 3.7.6 are part of the Technical Specification5.5.8, "Explosive Gas and Storage Tank Radioactivity MonitoringProgram."A.APPLICABILITY:At all times.CONDITIONConcentration of oxygen inthe waste gas holdupsystem > 2o/o by volumebut < 4% by volume.Concentration of oxygen inthe waste gas holdupsystem > 4o/o by volumeand the hydrogenconcentration > 4% byvolume.COMPLETION TIMElmmediately48 hourslmmediatelylmmediatelyB.ACTIONSREQUIRED ACT]ONA.1 Suspend all additions ofwaste gases to thegaseous waste decay tank.ANDA.2 Reduce the concentrationof oxygen to < 2o/o.B.1 Suspend all additions ofwaste gases to the affectedtank.AND8.2 Reduce the concentrationof oxygen to S 4o/o byvolume.Beaver Valley Unit 23.7.6 - 1LRM Revision 52 LICENSING REQUIREM ENT SURVEILLANCESLicensing Requirements ManualLRS 3.7.6.1SURVEILLANCEThe concentrations of oxygen in the waste gas holdupsystem shall be determined to be within the above limitsby continuously monitoring the waste gases in thewaste gas holdup system with the oxygen monitorsrequired OPERABLE by LR 3.3.12 or monitoring inconjunction with its associated ACTIONS.Explosive Gas Mixture3.7.6FREQUENCYln accordancewith LR 3.3.12Beaver Valley Unit 23.7.6 - 2LRM Revision 52 A.B.Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS)3.7.73.7 PLANT SYSTEMS3.7 .7 Supplemental Leak Collection and Release System (SLCRS)LR 3.7.7Two SLCRS exhaust air filter trains shall be FUNCTIONAL.APPLICABILITY:MODES 1,2,3, and 4.CONDITIONCOMPLETION TIMEOne SLCRS exhaust airfilter train Nonfu nctional.7 daysRequired Action andassociated CompletionTime not met.lmmediatelySU RVElLLANCEFREQUENCYLRS 3.7 .7 .1Initiate, from the control room, flow through the"standby" HEPA filter and charcoal adsorber train andverify that the train operates for at least 15 minutes withthe heater controls operational.31 daysACTIONSREQUIRED ACTIONA.1 Restore the Nonfunctionaltrain to FUNCTIONALstatus.B.1 Apply LR 3.0 3.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.7.7 - 1LRM Revision 67 Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS)3.7.7LICENSING REQUIREMENT SURVEILLANCEScontinuedSURVEILLANCEFREQUENCYLRS 3.7.7.2Each SLCRS exhaust air filter train shall bedemonstrated FU NCTIONAL:By verifying that the charcoal adsorbers remove> 99.95% of a halogenated hydrocarbon refrigeranttest gas when they are tested in-place inaccordance with ANSI N510-1980 while operatingthe ventilation system at a flow rate of 57,000 cfmL 10%.By verifying that the HEPA filter banks remove> 99.95% of the DOP when they are tested in-placein accordance with ANSI N510-1980 while operatingthe ventilation system at a flow rate of 57,000 cfmt 10olo.Within 31 days after removal, subjecting the carboncontained in at least one test canister or at least twocarbon samples removed from one of the charcoaladsorbers to a laboratory carbon sample analysisand verifying a removal efficiency of > 99% forradioactive methyl iodide at an air flow velocity of0.7 fUsec with an inlet methyl iodide concentration of1.75 mglm3, > 70% relative humidity, and 30'C;other test conditions including test parametertolerances shall be in accordance with ASTMD3803-1989. The carbon samples not obtainedfrom test canisters shall be taken with a slotted tubesampler in accordance with ANSI N509-1980.d. By verifying a system flow rate of 57,000 cfm + 10%during system operation.LRS 3.7 7 3Each SLCRS exhaust air filter train shall bedemonstrated FU NCT]ONAL:a. By verifying that the pressure drop across thecombined HEPA filters and charcoal adsorber banksis less than 6.8 inches Water Gauge while operatingthe ventilation system at a flow rate of 57,000 cfmt 10%.b. By verifying that the exhaust from the contiguousarea is diverted through the SLCRS filter train on aContainment lsolation - Phase "A" signal in lessthan 5 minutes.a.b.c.18 monthsANDAfter eachcomplete orpartialreplacement of aHEPA filter orcharcoal adsorberbankANDAfter anystructuralmaintenance onthe HEPA filter orcharcoal adsorberhousingsANDFollowingpainting, fire orchemical releasein any ventilationzonecommun icatingwith the system18 monthsBeaver Valley Unit 23.7.7 - 2LRM Revision 67 Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS)3.7.7LICENSING REQUIREM ENT SURVEILLANCEScontinuedSURVEILLANCEFREQUENCYLRS 3.7.7 .4Verify that the air flow distribution to each HEPA filterand charcoal adsorber is within x 20% of the averagedflow per unit.LRS 3.7.7.5Perform LRS 3.7.7.2c.After initialinstallationANDAfter anymaintenanceaffecting the flowdistributionOnce per4 months ofsystem operationBeaver Valley Unit 23.7.7 - 3LRM Revision 52 Licensing Requirements Manual125V D.C. Battery Banks Maintenance Requirements3.8.13.8 ELECTRICAL POWER SYSTEMS125V D.C. Battery Banks Maintenance RequirementsThe 125V D.C. battery banks (2-1,2-2,2-3, & 2-4) shall be maintainedin accordance with LRS 3.8.1.1 and LRS 3.8.1.2.When the battery bank(s) are required to be OPERABLE in accordancewith the Technical Specifications.CONDITIONCOMPLETION TIMEA. LR not met.lmmediatelySU RVEILLANCEFREQUENCYLRS 3.8.1.13.8.1LR 3.8.1APPLICABILITY:LRS 3.8.1.2Verify the following:Verify no visible corrosion at either terminals orconnectors. or the connection resistance of these itemsare within design specifications.a.The cells, cell plates, and battery racks show novisual indication of physical damage or abnormaldeterloration,The cell-to-cell and termrnal connections are clean,tight, and coated with anti-corrosion material, andThe resistance of ceff-to-cell and terminalconnections are within design specifications.Once per 92 daysANDWithin 7 daysafter a batterydischarge withbattery terminalvoltage below1 10V, or batteryovercharge withbattery terminalvoltage above1 50V1B monthsb.c.ACTIONSREQUIRED ACTIONA.1 Apply LR 3.0.3.LICENSING REQU I REMENT SURVEILLANCESBeaver Valley Unit 23.8.1 - 1LRM Revision 63 3.8.2LR 3.8.2Licensing Requirements ManualEDG 2000 Hour Rating Limit3.8.23.8 ELECTRICAL POWER SYSTEMSEmergency Diesel Generator (EDG) 2000 Hour Rating LimitThe auto-connected loads to each EDG shall not exceed the 2000 hourrating limit of 4,535 kw.APPLICABILITY:When the EDG is required to be OPERABLE in accordance with theTechnical Specifications.CONDITIONCOMPLETION TIMEA. LR not met.lmmediatelySURVEILLANCEFREQUENCYLRS 3.8.2.1Verify that the auto-connected loads to each EDG donot exceed the 2000 hour rating.18 months duringshutdownACTIONSREQUIRED ACTION4.1 Apply LR 3.0.3.LICENSING REQUI REMENT SURVElLLANCESBeaver Valley Unit 23.8.2 - 1LRM Revision 52 3.8.3LR 3.8.3Licensing Requirements ManualMain Fuel Oil Storage Tank Maintenance Requirements3.8.33.8 ELECTRICAL POWER SYSTEMSMain Fuel Oil Storage Tank Maintenance RequirementsMain Fuel Oil Storage Tanks shall be maintained in accordance withLRS 3.8.3.1.APPLICABILITY:When the associated Emergency Diesel Generator is requiredOPERABLE in accordance with Technical Specifications.CONDITIONCOMPLETION TIMEA. LR not met.lmmediatelySURVEILLANCEFREQUENCYLRS 3.8.3.1Drain each main fuel oil storage tank, remove theaccumulated sediment, and clean the tank using asodium hypochlorite solution or other appropriatecleaning solution.10 yearsACTIONSREQUIRED ACTION4.1 Apply LR 3.0.3.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.8.3 - 1LRM Revision 52 Licensing Requirements ManualCrane Travel - Spent Fuel Storage Pool Building3.9.13.9 REFUELING OPERATIONS3.9.1 Crane Travel - Spent Fuel Storage Pool BuildingLR 3.9.1Loads in excess of 2450 pounds shall be prohibited from travel over fuelassemblies in the storage pool.APPLICABILITY:With fuel assemblies in the storage pool.CONDITIONCOMPLETION TIMEA- LR not met,lmmediatelySU RVEILLANCEFREQUENCYLRS 3.9.1 .1Crane interlocks and physical stops which preventcrane travel with loads in excess of 245A pounds overfuel assemblies shall be demonstrated FUNCTIONAL.30 days prior tocrane usewhenever thecrane has beenidle for more than30 daysACTIONSREQUIRED ACT]ONA.1 Place the crane load in asafe condition.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2391-1LRM Revision 67 Licensing Requirements Manual3.9 REFUELING OPERATIONS3.9.2 Manipulator CraneLR 3.9.2APPLICABlLITY:CONDITIONRequirements for craneand/or hoistFUNCTIONALITY not metA.The manipulator crane and auxiliary hoist shall be used for movementof control rods or fuel assemblies and shall be FUNCTIONAL with:a. The manipulator crane used for movement of fuel assemblieshaving:1 . A minimum capacity of 3250 pounds, and2. An overload cut off limit <2700 pounds.b. The auxiliary hoist used for movement of control rods having:1. A minimum capacity of 700 pounds, and2. A load indicator which shall be used to prevent lifting loads inexcess of 600 pounds.During movement of control rods or fuel assemblies within the reactorpressure vessel.COMPLETION TIMElmmediatelyManipulator Crane3.9.2ACTIONSREQUIRED ACTIONA.1 Suspend use of anyNonfunctional manipulatorcrane and/or auxiliary hoistfrom operations involvingthe movement of controlrods and fuel assemblieswithin the reactor pressurevessel.Beaver Valley Unit 23.9.2 - 1LRM Revision 67 Licensing Requirements ManualLRS 3.9.2.1LRS 3.9.2.2SURVEILLANCEEach manipulator crane used for movement of fuelassemblies within the reactor pressure vessel shall bedemonstrated FUNCTIONAL by performing a load testof at least 3250 pounds and demonstrating anautomatic load cut off when the crane load exceeds2700 pounds.Each auxiliary hoist and associated load indicator usedfor movement of control rods within the reactor pressurevessel shall be demonstrated FUNCTIONAL byperforming a load test of at least 700 pounds.Manipulator Crane3.9.2FREQUENCYOnce within150 hours prior tothe start of fuelassemblymovementOnce within150 hours prior tothe start of controlrod movementLICENSI NG REQUIREMENT SURVEI LLANCESBeaver Valley Unit 23.9.2 - 2LRM Revision 67 Licensing Requirements Manual3.9 REFUELING OPERATIONS3.9.3 Decay TimeLR 3.9.3APPLICABILITY:CONDITIONReactor subcritical for lessthan 100 hours.LRS 3.9.3.1The reactor shall be subcritical for at least 100 hours.During movement of irradiated fuel assemblies in the reactor pressurevessel.COMPLETION TIMEDecay Time3.9.3lmmediatelyFREQUENCYPrior tomovement ofirradiated fuelassemblies in thereactor pressurevesselSURVEILLANCEThe reactor shall be determined to have beensubcritical for at least 100 hours by verification of thedate and time of subcriticality.ACTIONSREQUIRED ACTION4.1 Suspend all operationsinvolving movement ofirradiated fuel assembliesin the reactor pressurevessel.LICENSI NG REQUIREMENT SURVEILLANCESBeaver Valley Unit 23.9.3 - 1LRM Revision 52 5.15.0ADMINISTRATIVE CONTROLSCore Operating Limits ReportThis Core Operating Limits Report provides the cycle specific parameter limits developed inaccordance with the NRC approved methodologies specified in Technical SpecificationAdministrative Control 5.6.3.Licensing Requirements ManualCore Operating Limits Report5.1SL 2.1.1 Reactor Core Safetv LimitsSee Figure 5.1-1.SHUTDOWN MARGIN (SDM)a. In MODES 1,2, 3, and 4, SHUTDOWN MARGIN shall be > 1.77o/o Aldk.(1)b. Prior to manually blocking the Low Pressurizer Pressure Safety InjectionSignal, the Reactor Coolant System shall be borated to > the MODE 5boron concentration and shall remain > this boron concentration at all timeswhen this signal is blocked.c. In MODE 5, SHUTDOWN MARGIN shall be > 1.Oo/o Ak/k.L9O 3.1.3 Moderator Temperature Coefficient (MTC)a. Upper Limit - MTC shall be maintained within the acceptable operation limitspecified in Technical Specification Figure 3.1.3-1.b. Lower Limit - MTC shall be maintained less negative than - 4.29 x 10-aaldld'F at RATED THERMAL POWER.c. 300 ppm Surueillance Limit: (- 35 pcm/"F)d. 60 ppm Surveillance Limit: (- 41 pcm/"F)LCO 3.1.5 Shutdown Bank Insertion LimitsThe Shutdown Banks shall be withdrawn to at least 225 steps.(2)LCO 3.1.6 Control Bank Insertion Limitsa. Control Banks A and B shall be withdrawn to at least 225 steps.(2)b. Control Banks C and D shall be limited in physical insertion as shown inFigure 5.1-2.\2)Sequence Limits - The sequence of withdrawal shall be A, B, C and Dbank, in that order.Overlap Limits(2) - Overlap shall be such that step 129 on banks A, B, and Ccorresponds to step 1 on the following bank. When C bank is fullywithdrawn, these limits are verified by confirming D bank is withdrawn atleast to a position equal to the all-rods-out position minus 128 steps.The MODE 1 and MODE 2 with k"n z 1.0 SDM requirements are included to address SDMrequirements (e.g., MODE 1 Required Actions to verify SDM) that are not within theapplicability of LCO 3.1.1, SHUTDOWN MARGIN (SDM).As indicated by the group demand counter5.1.15.1 .25.1.35.1.45.1.5c.d.(1)(2)COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 -1 Licensing Requirements Manual5.1 Core Operating Limits ReportCore Operating Limits Report5.15.1.6 LCO 3.2.1 Heat Flux Hot Channel Factor (Fo(Z))The Heat Flux Hot Channel Factor - Fo(Z) limit is defined by:I cen-]FnG) < I :l-: l. x(z) for p > o.s\'r' I P lIcPolF.'G) =l=l.x(z) forP< 0.51't l 0.5 l 'Where: CFQ = 2.40 t =K(Z) = the function obtained from Figure 5.1-3.Ffi(z) = F3 (z) .1 0815r$ rzl = F3 (z) . w(z)W(Z) values are provided in Table 5.1-1. The W(Z) values are generatedassuming that they will be used for a full power surveillance. When a part powersurveillance is performed, the W(Z) values should be multiplied by the factor 1lP,when P > 0.5. When P is < 0.5, the W(Z) values should be multiplied by thefactor 1/(0.5), or 2.0. This is consistent with the adjustment in the Fo(Z) limit atpart power conditions.The Fq(Z) penalty function, applied when the analytic Fq(Z) function increasesfrom one monthly measurement to the next, is provided in Table 5.1-2.5.1.7 LCO 3.2.2 Nuclear Enthalpy Rise Hot Channel Factot t *lrl- < cr . (1+ PF (1- P))AN AH AHWhere: CFo, = 1.62PF = 0.3AHr-} - THERMAL POWERr RATED THERMAL POWER5.1.8 LCO 3.2.3 Axial Flux Difference (AFD)The AFD acceptable operation limits are provided in Figure 5.1-4.COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 -2 Licensing Requirements Manual5.1 Core Operating Limits ReportCore Operating Limits Report5.15.1.9LCO 3.3.1 Reactor Trip System Instrumentation - Overtemperature andOverpower AT Parameter Values from Table Notations 3 and 4a. Overtemperature AT Setpoint Parameter Values:ParameterOvertemperature AT reactor trip setpointOvertemperature AT reactor trip setpoint TavgcoefficientOvertemperature AT reactor trip setpoint pressurecoefficientTavg at RATED THERMAL POWERNominal pressurizer pressureMeasured reactor vessel AT lead/lag time constants(* The response time is toggled off to meet the analysisvalue of zero.)Measured reactor vesselMeasured reactor vesseltime constantsMeasured reactor vesselconstantAT lag time constantaverage temperature lead/lagaverage temperature lag timeValueK1 < 1.239K2 >_ 0.0183/'FK3 > 0.001/psiaT', < 574.20p(lP'> 2250 psiaTr = 0 sec*Tz= A sec*ts < 6 secsta > 30 secsrs < 4 secsra < 2 secsf (Al) is a function of the indicated difference between top and bottomdetectors of the power-range nuclear ion chambers; with gains to beselecteci based on measured instrument response during plant startup testssuch that:(i) For q1 - qo between -37o/o and + 15o , f1(Al) = 0, where Q1 ?nd Q5 orepercent RATED THERMAL POWER in the top and bottom halves ofthe core respectively, and Qt + Qu is total THERMAL POWER inpercent of RATED THERMAL POWER.(1) T' represents the cycle-specific Full Power Tavg value used in core design.COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 -3 Licensing Requirements Manual5.1 Core Operating Limits ReportCore Operating Limits Report5.1(ii) For each percent that the magnitude of (q1 - qp) exceeds -37%, the ATtrip setpoint shall be automatically reduced by 2.52% of its value atRATED THERMAL POWER.(iii) For each percent that the magnitude of (q1 - q5) exceeds +15o/o, the ATtrip setpoint shall be automatically reduced by 1.47% of its value atRATED THERMAL POWER.b. Overpower AT Setpoint Parameter Values:Parameter ValueOverpower AT reactor trip setpoint K4 < 1.094Overpower AT reactor trip setpoint Tavg K5 > A.02l"F for increasingrate/lag coefficient average temperatureK5 = 0/'F for decreasingaverage temperatureOverpower AT reactor trip setpoint Tavg K6 > 0.0021/"F for T > T"heatup coefficient K6 = 0/'F for T < T"Tavg at RATED THERMAL POWER T" < 574.2o7tt)Measured reactor vessel AT lead/lag rr = 0 sec*time constants tz = A sec*(. The response time is toggled off to meet the analysis value of zero.)Measured reactor vessel AT lag time te < 6 secsconstantMeasured reactor vessel average ra < 2 secstemperature lag time constantMeasured reactor vessel average q > 10 secstemperature rate/lag time constant(1) T" represents the cycle-specific Full Power Tavg value used in core design.COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 -4 Licensing Requirements Manual5.1 Core Operating Limits ReportCore OperatingReport5.15.1.10LCO 3.4.1. RCS Pressure, Temperature, and Flow Departure from NucleateBoilinq (DNB) LimitsParameterReactor Coolant System TavgPressurizer PressureReactor Coolant System Total Flow Ratelndicated ValueTavg < 577.8F1d)Pressure > 2214 psia(2)Ffow > 267 3A0 gp*(t)(1) The Reactor Coolant System (RCS) indicated Tavg value is determined by adding theappropriate allowances for rod control operation and verification via control boardindication (3.6'F) to the cycle specific full power Tavg used in the core design.The pressurizer pressure value includes allowances for pressurizer pressure controloperation and verification via control board indication.The RCS total flow rate includes allowances for normalizatio'n of the cold leg elbow tapswith a beginning of cycle precision RCS flow calorimetric measurement and verification ona periodic basis via control board indication.(2)(3)COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 -5 Licensing Requirements Manual5.1 Core Operating Limits ReportCore Operating Limits Report5.15.1.11LCO 3.9.1 Boron Concentration (MODE 6)The boron concentration of the Reactor Coolant System, the refueling canal, andthe refueling cavity shall be maintained > 2400 ppm. This value includes a50 ppm conservative allowance for uncertainties.COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 -6 Licensing Requirements Manual5.1 Core Operating Limits ReportCore Operating Limits Report5.15.1.12 References1. WCAP-9272.P-A,WESTINGHOUSE RELOAD SAFETY EVALUATIONMETHODOLOGY," July 1 985 (Westinghouse Proprietary).2. WCAP-8745-P-A, "Design Bases for the Thermal Overtemperature AT andThermal Overpower AT Trip Functions," September 1986.3. WCAP-12945-P-A, Volume 1 (Revision 2) and Volumes 2 through 5(Revision 1), "Code Qualification Document for Best Estimate LOCAAnalysis," March 1998 (Westinghouse Proprietary).4, WCAP-1 021 6-P-A, Revision 1A, "Relaxation of Constant Axial OffsetControl-Fq Surveillance Technical Specification," February 1 994.5. WCAP-14565-P-A, "VIPRE-01 Modeling and Qualification for PressurizedWater Reactor Non-LOCA Thermal-Hydraulic Safety Analysis,"October 1999.WCAP-12610-P-A, "VANTAGE+ Fuel Assembly Reference Core Report,"April 1995 (Westinghouse Proprietary).WCAP-1 5025-P-A, "Modified WRB-2 Correlation, WRB-2M, for PredicatingCritical Heat Flux in 17x17 Rod Bundles with Modified LPD Mixing VaneGrids," April 1999.Caldon, Inc. Engineering Report-80P, "lmproving Thermal Power Accuracyand Plant Safety While Increasing Operating Power Level Using theLEFMfM System," Revision 0, Marcfr t ggZ.Caldon, Inc. Engineering Report-160P, "Supplement to Topical ReportER-80P: Basis for a Power Uprate With the LEFMI/"u'System," Revision 0,May 2000.6.7.8.9.COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 -7 e 63050AIJ;6F 6zaLicensing Requirements ManualCore Operating Limits Report5.1243s PSIA2250 PSIA2000 PSIALINACCEPTAB LE OPERATIONACCEPTABLE OPERATION0.2 0.4 0.6 0.8 rFRACTION OF RATED THERMAL POWERFigure 5.1-1 (Page 1 of 1)REACTOR CORE SAFETY LIMITTHREE LOOP OPERATION(Technical Specification Safety Limit 2.1.1)1.4t.2COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 -8 Licensing Requirements Manual225200175150125100755025c3(Itc-c=ao-0)gzoEaoo_YzmootCore Operating Limits Report8090100102A 30 40 50 60 7APERCENT OF RATED THERMAL POWERFigure 5.1-2 (Page 1 of 1)CONTROL ROD INSERTION LIMITS AS AFUNCTION OF RATED POWER LEVEL//y ru;53,225\tlrlBANK Ct---llrc,l//////7/4)--_lBA- lNKDI-////////F:0)COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 -9 Licensing Requirements ManualCore Operating Limits Report5.1I 06Figure 5.1-3 (Page 1 of 1)FoT NORMALTZED OPERATING ENVELOPE, K(Z)COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 - 10 Licensing Requirements ManualL20110'l nn908o70ctu5040302010U- 60-50 -40Core Operating Limits Repofi5.1o3o(L(soFEo(Etros:30 10 0 10Axial Flux Difference (Delta l)%Figure 5.1-4 (Page 1 of 1)AXIAL FLUX DIFFERENCE LIMITS AS A FUNCTION OFPERCENT OF RATED THERMAL POWER FOR RAOC1(nB,1o)-1+8I00).tI\:E PTABtAT IO]-lI.-[_*lUNCCPEBPTRATt"."L_nAB LEroNUNAC COPE:LE\IACCOPIEP TAB:]RAT IOLEtrIVI\II\\II\'l(-25, 5)(22,0)ilclCOLR Cycle 1BLRM Revision 80Beaver Valley5.1 - 11 Licensing Requirements ManualCore OperatingReport5.1Table 5.1-1Fq Surveillance W(Z)(Page 1 of 2\Function versus BurnupExclusionZoneAxPoalntElevation(feet)150(M\ /D/MTU)3000(MWD/MTU)8000(MWDTMTU)12AAA(MWD/MTU)1 6000(MWD/MTU)*112.11.00001.00001.00001.00001.0000*211.91.00001.00001.00001.00001.0000*311.71.00001.00001.00001.00001.0000*411.51.00001.00001.00001.00001.0000*511.31.00001.00001.00001.00001.0000*611.11.00001.00001.00001.00001.0000*710.91.00001.00001.00001.00001.0000B10.71.15061.19281.23221.22961.2203I10.51.14461 .1 8601.22471.22351.21051010.31.13901.17831.21621.21621.20531110.11.13471.17441.24841.20841 .1 995129.91.13451 .161 81.20271.20001.1931139.71.13781.15701.19711 .1 9091.1852149.51.14181 .1 5611.19071 .18151.1798159.31.14401.15421.18571.17191.1813169.11.14721 .15181.18501.16071.1864178.91 .1 5931 .1 5561.19051.15971.1883188.71.17581.16641.20131.16471.1929198.51.18841.17451.20821 J75A1.20452A8.31.19871.18071.21301.18251.2133218.11.20661.18491.21571 .1 8801.2196227.91.21211.18721.216:21.19171.2239237.61.21551.18781.21481 .1 9361.2264247.41.21681.1 8681.21151.19371.2260257.21.21611.18431.20631.19221.2239267.41.21331 .18131.20021 .1 8891.2197276.81.20861 .17711.19311.18491.2142286.61.20211.17121.18451 .1 8031.2080296.41 .1 9401 .1 6391.17451.17401.200030o.z1.18421.1 5531.16301.16621.1901316.01.17321.14561.15041.15711 .1 790325.81.16051.13451 .1 3651.14681.1657Note: Top and Bottom 1A% ExcludedCOLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 - 12 Licensing Requirements ManualNote. Top and Bottom 10% ExcludedCore Operating Limits Report5.1TABLE 5.1-1 (Page 2 of 2)Fq Surveillance W(Z) Function versus BurnupExclusionZoneAxialPointElevation(feet)150(MWD/MTU)3000(MWD/MTU)8000(MWD/MTU)1 2000{MWD/MTU)1 6000(MWDTMTU)335.61.14771.12291.12331.13541.1523345.41 .1 3861.11411.11381.12431.1447355.21.13081.11041.10361.11631.1414365.01.12581.10921.09631.11121.1382374.81.12331 .1 0891.CI9241.10781.1336384.61.12061 .1 0981.08851.10471.1283394.41.11721 .1 1061.08491.10111.1222404.21.11671.11121.08101.09701.1155414.41.11941.11141.47731.A9271.1484423.81.12341.11 191.07491.08811.1009433.61.12661.11411.07461.08341.0933443.41.12941 .1 1681.07431.07991.0860453.21 .1 3291.11961.07471.07751.A773463.01.13771 .1 2661.07761.07901.0747472.81.14661.14261.08931.09121.0839482.61.16421.16731.10681.10501.09904g2.41 .1 8551.19271.12511.11921.1143502.21.20751.21801.14341.13371.1296512.01.22941.24331.16191.14811.1447521.81.25001.26801.18001.16221.1595531.61.27011.29171.19761.17601.1739541.41.28871.31351.21391 .1 8881.1876551.21.00001.00001.00001.00001.0000561.01.00001.00001.00001.00001.0000570.81.00001.00001.00001.00001.0000580.61.00001.00001.00001.00001.0000590.41.00001.00001.00001.00001.0000604.21.00001.00001.00001.00001.0000610.01.00001.00001.00001.00001.0000COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 - 13 Licensing Requirements ManualCore Operating Limits Report5.1Table 5.1-2 (Page 1 of 1)FaG) Penalty Factor versus BurnupCvcle Burnup (MWD/MTU)F o(Z\ Penaltv Factor>01.0200Note: The Penalty Factor, to be applied to Fq(Z) in accordance with Technical SpecificationSurueillance Requirement (SR) 3.2.1.2, is the maximum factor by which Fo(Z) isexpected to increase over a 39 Effective Fulf Power Day (EFPD) interval (surveillanceinterval of 31 EFPD plus the maximum allowable extension not to exceed 25% of thesurveillance interval per Technical Specification SR 3.0.2) starting from the burnup atwhich the Fq(Z) was determined.COLR Cycle 18LRM Revision 80Beaver Valley Unit 25.1 - 14 Licensing Requirements ManualADMINISTRATIVE CONTROLSPressure and Temperature Limits ReportPressure and Temperature Limits Report5.25.05.2BVPS-2 Technical Specification to PTLR Cross-ReferenceTechnicalSpecificationPTLRSectionFiqureTable3.4.35.2.1.15.2-15.2-25.2-35.2-45.2-55.2-6N/A3.4.6N/AN/A5.2-33.4.7N/AN/A5.2-33.4.10N/AN/A5.2-33.4.125.2.1.25.2.1.35.2-85.2-33.5.2N/AN/A5.2-3BVPS-2 Licensing Requirement to PTLR Cross-ReferenceLicensingRequirementPTLRSectionFiqureTableLR 3.1 .2N/AN/A5.2-3LR 3.1 .4N/AN/A5.2-3LR 3.4.6N/AN/A5.2-3PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2-i Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report5.25.2Reactor Coolant Svstem (RCS) Pressure and Temperature Limits Report (PTLR)The PTLR for Unit 2 has been prepared in accordance with the requirements ofTechnical Specification 5.6.4. Revisions to the PTLR shall be provided to theNRC after issuance.The Technical Specifications (TS) and Licensing Requirements (LR) addressed,or made reference to, in this report are listed below:1. LCO 3.4.3 Reactor Coolant System Pressure and Temperature (P/T)Limits,LCO 3.4.6 RCS Loops - MODE 4,LCO 3.4.7 RCS Loops - MODE 5, Loops Filled,LCO 3.4.10 Pressurizer Safety Valves,LCO 3.4.12 Overpressure Protection System (OPPS),LCO 3.5.2 ECCS - Operating,LR 3.1.2 Boration Flow Paths - Operating,LR 3.1.4 Charging Pump - Operating, andLR 3.4.6 Pressurizer Safety Valve Lift Involving Loop Seal or WaterDischarge5.2.1 Operatinq LimitsThe PTLR limits for Beaver Valley Power Station (BVPS) Unit 2 were developedusing a methodology specified in the Technical Specifications. The methodologylisted in Reference 1 was used with two exceptions:a) Use of ASME Code Case N-640, "Alternative Reference FractureToughness for Development of P-T Limits for Section Xl, Dlvision 1," andb) Use of methodology of the 1996 version of ASME Section Xl, Appendix G,"Fracture Toughness Criteria for Protection Against Failure."5.2.1.1RCS Pressure and Temperature (P/T) Limits (LCO 3.4.3)The RCS temperature rate-of-change limits defined in Reference 14 are.A maximum heatup of 60'F in any one hour period.A maximum cooldown of 100"F in any one hour period, anda.b.PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2-1 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report5.2c. A maximum temperature change of less than or equal to 5"F in any onehour period during inservice hydrostatic testing operations above systemdesign pressure.The RCS PIT limits for heatup, leak testing, and criticality are specified byFigure 5.2-1 and Table 5.2-1. The RCS P/T limits for cooldown are shown inFigures 5.2-2 through 5.2-6 and Table 5.2-2. These limits are defined inReference 14. Consistent with the methodology described in Reference 1,including the exceptions as noted in Section 5.2.1, the RCS P/T limits for heatupand cooldown shown in Figures 5.2-1 through 5.2-6 are provided without marginsfor instrument error. The criticality limit curve specifies pressure-temperaturelimits for core operation to provide additional margin during actual powerproduction as specified in 10 CFR 50, Appendix G. The heatup and cooldowncurves also include the effect of the reactor vessel flange.The P/T limits for core operation (except for low power physics testing) are thatthe reactor vessel must be at a temperature equal to or higher than the minimumtemperature required for the inservice hydrostatic test, and at least 40"F higherthan the minimum permissible temperature in the corresponding P/T curve forheatup and cooldown.The pressure-temperature limit curve shown in Figure 5.2-7 was developed forthe limiting ferritic steel component within an isolated reactor coolant loop. Thelimiting component is the steam generator channel head to tubesheet region.This figure provides the ASME lll, Appendix G limiting curve whlch is used todefine operational bounds, such that when operating with an isolated loop theanalyzed pressure-temperature limits are known. The temperature rangeprovided bounds the expgcted operating range for an isolated loop and CodeCase N-640.. NOTE -Pressure limits are considered to be met for pressures that are below 0 psig(i.e., up to and including full vacuum conditions) since the resufting P/Tcombination is located in the region to the right and below the operating limitsprovided in Figures 5.2-1, 5.2-2, 5.2-3, 5.2-4, 5.2-5, 5.2-6, and 5.2-7 .Reference 13 provides an updated surveillance capsule credibility evaluation,updated Position 2.1 chemistry factor values, and an updated fluence evaluation.Therefore, the applicability of the P/T limit curves (Reference 14) was assessedbased on the revised information. Taking into account the updated surveillancedata credibility evaluation, the Position 2.1 chemistry factor values, and thefluence analysis summarized in Reference 13, the limiting material for the currentBVPS-2 P/T limits continues to be the intermediate shell plate 89004-1 at30 EFPY.PTLR Revision 7LRM Revision 79Beaver Valley Unlt 25.2-2 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report5.25.2.1.25.2.1.3Since the adjusted reference temperature (ART) calculation is not based onsurveillance data for this limiting material, only a fluence comparison is needed inorder to assess the applicability of the existing curves. Using the fluenceanalysis provided in Table 5-1 of Reference 13, the maximum neutron fluencevaf ue at 30 EFPY is 3.03 x 101e nlcm2 (E r 1 .0 MeV). This value was calculatedby interpolating the fluence at the 0' azimuthal position for BVPS-2from the endof Cycle 15 to the fluence value at the future projection out to 32 EFPY. Thefluence of 3.39 x 101e n/cm2 (E r 1.0 MeV) used to develop the 30 EFPY P/T limitcurves generated as a result of the Capsule X analysis (Reference 12), is moreconservative than the updated fluence of 3.03 x 101e nlcmz (E " 1 .0 MeV).Overpressure Protection Svstem (OPPS) Setpoints (LCO 3.4.12)The power operated relief valves (PORVs) shall each have a nominal maximumlift setting that varies with RCS temperature and which does not exceed the limitsin Figure 5.2-8 (Reference 9). The OPPS enable temperature is in accordancewith Table 5.2-3. The PORV lift setting provided is for the case with reactorcoolant pump (RCP) restrictions. These restrictions are shown in Table 5.2-4,which is taken from Reference 9. Due to the setpoint limitations as a result of thereactor vessel flange requirements, there is no operational benefit achieved byrestricting the number of RCPs running to less than two below an indicated RCStemperature of 137oF. Therefore, the PORV setpoints shown in Table 5.2-3 willprotect the Appendix G limits for the combinations shown.The PORV setpoint is based on P/T limits which were established in accordancewith 10 CFR 50, Appendix G without allowance for instrumentation error and inaccordance with the methodology described in Reference 1, including theexceptions noted in Section 5.2.1. The PORV lift setting shown in Figure 5.2-8accounts for appropriate instrument error.OPPS Enable Temperature (LCO 3.4.12)Two different temperatures are used to determine the OPPS enable temperature,they are the arming temperature and the calculated enable temperature. Thearming temperature (when the OPPS rendered operable) is established perASME Section Xl, Appendix G. At this temperature, a steam bubble would bepresent in the pressurizer, thus reducing the potential of a water hammerdischarge that could challenge the piping limits. Based on this method, thearming temperature with uncertainty is 237'F.PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2-3 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report5.25.2.1 .4The calculated enable temperature is based on either a RCS temperature of lessthan 200"F or materials concerns (reactor vessel metal temperature less thanRTruor + 50"F), whichever is greater. The calculated enable temperature doesnot address the piping limit attributed to a water hammer discharge. Thecalculated enable temperature is 240oF.As the calculated enable temperature is higher and, therefore, more conservativethan the arming temperature, the OPPS enable temperature, as shown inTable 5.2-3, is set to equal the calculated enable temperature.The calculation method governing the heatup and cooldown of the RCS requiresthe arming of the OPPS at and below the OPPS enable temperature specified inTable 5.2-3, and disarming of the OPPS above this temperature. The OPPS isrequired to be enabled, i.e., OPERABLE, when any RCS cold leg temperature isless than or equal to this temperature.The OPPS enable temperature, PORV setpoints, and RCP operating restrictionscontained in Tables 5.2-3 and 5.2-4 and Figure 5.2-8 are as described inReference 15, and are based upon analysis of Capsule X. The pressure-temperature limits provided in Reference 1 4 for Capsule X and setpointsevaluation per Reference 15 support the continued use of these existingOPPS/PORV setpoints and RCP operating restrictions for the period up to30 EFPY. As a result, Tables 5.2-3 and 5.2-4 and Figure 5.2-8 remain valid forCapsule X up to 30 EFPY.From a plant operations viewpoint the terms "armed" and "enabled" aresynonymous when it comes to activating the OPPS. As stated in the applicableoperating procedure, the OPPS is activated (armed/enabled) manually beforeentering the applicability of LCO 3.4.12. This is accomplished by placing twoswitches (one in each train) into their "ARM" position. Once OPPS is activated(armed/enabled) reactor coolant system pressure transmitters will signal a rise insystem pressure above the variable OPPS setpoint. This will initiate an alarm inthe control room and open the OPPS PORVS.Reactor Vessel' Boltup Temperature (LCO 3.4.3)The minimum boltup temperature for the Reactor Vessel Flange shall be > 60'F.Boltup is a condition in which the reactor vessel head is installed with tensionapplied to any stud, and with the RCS vented to atmosphere.PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2-4 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report5.25.2.25.2.3Reactor Vessel Material Surveillance ProqramThe reactor vessel material irradiation surveillance specimens shall be removedand analyzed to determine changes in material properties. The capsulewithdrawal schedule is provided in Table 5.3-6 of the UFSAR. Also, the resultsof these analyses shall be used to update Figures 5.2-1 through 5.2-6, andTables 5.2-1 and 5.2-2 in this report. The time of specimen withdrawal may bemodified to coincide with those refueling outages nearest the withdrawalschedule.The pressure vessel material surveillance program (References 4 and 13) is incompliance with Appendix H to 10 CFR 50, "Reactor Vessel RadiationSurveillance Program." The material test requirements and the acceptancestandards utilize the reference nil-ductility temperature, RTruor, which isdetermined in accordance with ASME, Section lll, NB-2331. The empiricalrelationship between RTxel and the fracture toughness of the reactor vessel steelis developed in accordance with Appendix G, "Protection Against Non-DuctileFailure," to Section Xl of the ASME Boiler and Pressure Vessel Code. Thesurveillance capsule removal schedule meets the requirements ofASTM E 185.82.Reference 10 is an NRC commitment made by FENOC to use only thecalculated vessel fluence values when performing future capsule surveillanceevaluations for BVPS Unit 2. This commitment is a condition of LicenseAmendment 138 and will remain in effect until the NRC staff approves analternate methodology to perform these evaluations. Best-estimate valuesgenerated using the FERRET Code may be provided for information only.Supplemental Data TablesThe following tables provide supplemental information on reactor vessel materialproperties and are provided to be consistent with Generic Letter 96-03. Some ofthe material property values shown were used as inputs to the P/T limits.Table 5.2-5, taken from Table 2-4 of Reference 13, shows the calculation of thesurveillance material chemistry factors using surveillance capsule data.Tabfe 5.2-6, taken from Table 2-1 of Reference 14, provides the reactor vesselbeltline materiaf property table.Tabfe 5.2-7, taken from Table 4-2 of Reference 13, provides the reactor vesselextended beltline material property table.Tabfe 5.2-8, taken from Tables 4-7 and 4-8 of Reference 14, provides a summaryof the Adjusted Reference Temperature (ARTs) for 30 EFPY.PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2-5 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report5.25.2.4Tabfe 5.2-9, taken from Tables 4-7 and 4-8 of Reference 14, shows thecalculation of ARTs for 30 EFPY.Table 5.2-10, taken from Table 6-3 of Reference 13, provides RTprs values forthe Beltline Region Materials at 54 EFPY.Tabfe 5.2-11, taken from Table 64 of Reference 13, provides RTprs values forthe Extended Beltline Region Materials at 54 EFPY.Note that Tables 5.2-5, 5.2-8 and 5.2-9 reflect Capsule X analysis and fluencedata.References1. WCAP-14040-A, Revision 4, "Methodology Used to Develop ColdOverpressure Mitigating System Setpoints and RCS Heatup and CooldownLimit Curves," J. D. Andrachek, et al., May 2004.(Deleted)(Deleted)WCAP-9615, Revision 1, "Duquesne Light Company, Beaver Valley UnitNo. 2 Reactor Vessel Radiation Surveillance Program," P. A. Peter,June 1995.WCAP-15676, "Evaluation of Pressurized Thermal Shock for Beaver ValleyUnit 2," J. H. Ledger, August zAU.10 CFR Part 50, Appendix G, "Fracture Toughness Requirements," FederalRegister, Volume 60, No. 243, December 19, 1995.10 CFR 50.61 , "Fracture Toughness Requirements for Protection AgainstPressurized Thermal Shock Events," May 15, 1991. (PTS Rule)Regulatory Guide 1 .99, Rev. 2, "Radiation Embritilement of Reactor VesselMaterials," U.S. Nuclear Regulatory Commission, May 1988.FENOC Calculation No. 10080-SP-2RCS-006, Revision 4, Addendum 1 ,"BV-Z LTOPS Setpoint Evaluation Capsule W for 22 EFPY ."FirstEnergy Nuclear Operating Company letter L-01-157, "Supplement toLicense Amendment Requests Nos . 295 and 167," dated December 21 ,2AU.2.3.4.5.6.7. 8.9.10.PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2-6 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report5.211. (Deleted)12. WCAP-1 6527 , Revision 0, "Analysis of Capsule X from FirstEnergy NuclearOperating Company Beaver Valley Unit 2 Reactor Vessel RadiationSurveillance Program," B. N. Burgos, J. Conermann, S. L. Anderson,March 2006.13. WCAP-1 6527 , Supplement 1 , Revision 1 , "Analysis of Capsule X fromFirstEnergy Nuclear Operating Company Beaver Valley Unit 2 ReactorVessel Radiation Surveillance Program," A. E. Freed, September 2411.14. WCAP-16528, Revision 1, "Beaver Valley Unit 2 Heatup and CooldownLimit Curves for Normal Operation," June 2008.15. Westinghouse Letter FENOC-}7-92, dated June 8,2007, LTOPS SetpointEvaluation for Beaver Valley Unit 2 Capsule X at22 and 30 EFPY.16. Westinghouse Letter MCOE-LTR-13-19, Revision 0, dated March 6,2013,"Acceptable Initial RTruor Values for the Beaver Valley Unit 2 ReactorVessel Inlet Nozzle Materials."PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 -7 Licensing Requirements ManualPressure and Temperature Limits Report5.2MATERIAL PROPERTY BASISLIMITING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4-1LIMITING ART VALUES AT 30 EFPY: 1Ar.143oF3t4T, 132"FCURVES APPLICABLE FOR HEATUP RATES UP TO 6O"F/HR FOR THE SERVICEPERIOD UP TO 30 EFPY.25002250200017501 50012541 0007505002500100 150 200 250 300 350 400I NDTCATED TEMPERATURE ("F)Figure 5.2-1 (Page 1 of 1)Reactor Coolant System HeatupLimitations Applicable for the First 30 EFPY (LCO 3.4.3)EaglrJtrfoouJu.o-oIJJFoozLeak Test LimitCriticality Limit based on inseMcehydrostatic test temperatue (199'F) forthe service period up to 30 EFPYBoltupTemperaturePTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2-8 Licensing Requirements ManualPressure and Temperature Limits Report5.2MATERIAL PROPERry BASISLIMITING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4-1Lf MITING ART VALUES AT 30 EFPY: 114T, 143"F314T, 1320FCURVE APPLICABLE FOR COOLDOWN RATES UP TO OOF/HR FOR THE SERVICEPERIOD UP TO 30 EFPY.25042250200017541 5001250100075450025400 50 100 150 200 250 300 350 400 450 500tNDtcATED TEMPERATURE ('F)Figure 5.2-2 (Page 1 of 1)Reactor Coolant System Cooldown (steady state - O"F/Hr.)Limitations Applicable for the First 30 EFPY (LCO 3.4 3)oag]Utr:)aaIIJtro-otuIozPTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2-9 Licensing Requirements ManualPressure and Temperature Limits Report5.2MATERIAL PROPERTY BASISLIMITING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4,1Lf MITING ART VALUES AT 30 EFPY: 114T, 143"F314T, 1320FCURVE APPLICABLE FOR COOLDOWN RATES UP TO 2O'FIHR FOR THE SERVICEPERIOD UP TO 30 EFPY.25002250200017501 50012s010007545002500100 150 200 250 300 350 400 450tNDtcATED TEMPERATURE ("F)Figure 5.2-3 (Page 1 of 1)Reactor Coolant System Cooldown (up to 20"F/Hr.)Limitations Applicable for the First 30 EFPY (LCO 3.4.3)IagIIJE,f,a@UJtr&ouJFIozPTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 10 Licensing Requirements ManualPressure and Temperature Limits Report5.2MATER]AL PROPERTY BASISLIMlTING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4-1Lf MITING ART VALUES AT 30 EFPY: 114T, 143"F3l4T , 1320FCURVE APPLICABLE FOR COOLDOWN RATES UP TO 4O'F/HR FOR THE SERVICEPERIOD UP TO 30 EFPY.2500225A20001 7501 500125010007505002500100 150 200 250 300 350 400 450INDTGATED TEMPERATURE ("F)Figure 5.2-4 (Page 1 of 1)Reactor Coolant System Cooldown (up to 40"FlHr.)Limitations Applicable for the First 30 EFPY (LCO 3.4.3)IagultrfaaIJJtro.olrJF()ozBeaver Valley Unit 2PTLR Revision 7LRM Revision 795.2 - 11 Licensing Requirements ManualPressure and Temperature Limits Report5.2MATERIAL PROPERTY BASISLIMITING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4-1LIMfTING ART VALUES AT 30 EFPY: 114T, 143'F314T, 1320FCURVE APPLICABLE FOR COOLDOWN RATES UP TO 6O"F/HR FOR THE SERVICEPERIOD UP TO 30 EFPY.20001750150012541 0007505002500100 150 200 250 300 350 400 450 500tNDtcATED TEMPERATURE ("F)Figure 5.2-5 (Page 1 of 1)Reactor Coolant System Cooldown (up to 60"F/Hr.)Limitations Applicable for the First 30 EFPY (LCO 3.4.3)oogUJtrfooIIJtr(LoIIJFooz50PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 12 Licensing Requirements Manual2s002250200017501 500125010007505002500Pressure and Temperature Limits Report5.2MATERIAL PROPERTY BASISLIMITING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4.1LIMITING ART VALUES AT 30 EFPY: 1Af .143"F3t4T, 132"FCURVE APPLICABLE FOR COOLDOWN RATES UP TO 1OO"F/HR FOR THESERVICE PERTOD UP TO 30 EFPY.EcngllJtr3U'outuo-oUJoozf U"acceptablelI Operation IlAcceptabl"lI operation It---Bortrt_l@Cooldown Rate 100"F/Hr100 150 200 250 300 350 400 450 500I NDTCATED TEMPERATURE ("F)Figure 5.2-6 (Page 1 of 1)Reactor Coolant System Cooldown (up to 10OoF/Hr.)Limitations Applicable for the First 30 EFPY (LCO 3.4.3)PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 13 Licensing Requirements Manual25002000s00an= 1500v)g[rJE,fa0UJG 1000o-Pressure and Temperature Limits Report5.2124110506080 90 100TEMPERATURE ("F)Figure 5.2-7 (Page 1 of 1)lsolated Loop Pressure - Temperature Limit Curve (LCO 3.4.3)PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 14 Licensing Requirements Manual725700675650625600575550525500475450Pressure and Temperature Limits Report5.2o6gz6(Llr,atr.oILz=ozUJtrt=oJJ=fEx=Ix=aLSee Table 5.24 for RCP restrictions.--IIIUnacceptableoperationIrcepterblePql50 75 100 125 15A 175 2A0 225 25A 275 300 325 350TRrD-AUCTl ONEERED LOW -M EAS URED RCS TEM P ERATURE (" FlFigure 5.2-8 (Page 1 of 1)Maximum Allowable Nominal PORV Setpoint for theOverpressure Protection System (LCO 3.4.12)PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 15 Licensing Requirements ManualPressure and Temperature Limits Report5.2Table 5.2-1 (Page 1 of 1)Heatup Curve Data Points for 30 EFPY (LCO 3.4.3)6O'F/HR HEATUP60'F/HR CRITICALITYLEAK TEST LIMITTemp.("F)Press.(psiq)Temp.('F)Press.(psig)Temp.("F)Press.(psig)60019901812000606211996211992485656211996217062119962175621199621806211996218562119962190621199621956211996211006211996211056211997771106211997931156211998131206211998351206211998611247771998891257931999211308131999571358352009961408612051 0401458892101 0891509212151143155957220120316099622512691651 04023013421701 0892351 42317511432401512180na3245161 1185126925017 1g19013422551840195142326419722001512265211820516112702280214171927524582151 8402241972225211823422802352458Beaver Valley Unit 25.2 - 16PTLR Revision 7LRM Revision 79 Licensing Requirements ManualPressure and Temperature Limits Report5.2Table 5.2-2 (Page 1 of 1)Cooldown Curve Data Points for 30 EFPY (LCO 3.4.3)O"F/HR20"F/HR40"F/HR6O"F/HR100.F/H RTemp.('F)Press.(psig)Press.(psig)Press.(psig)Press.(psis)Press.(psig)6000000606216216216025256562162162161253670621621621621548756216216216215628062162162162157885621621621621595906216216216216149562162162162162110062162162162162110562162162162162111062162162162162111562162162162162112062162162162162112462162162162162112089286784482278312591889687585582313094792790989386713598096294793491714010161 0019899809711451 05510441 0361 0311 0311501 0991492108710871087155114711441 144114411441601201120112011201120116512601260126012601260170132513251325.1 325132517513971397139713971397180147714771477147714771851 5651 5651 5651 5651 56519016621662166216621662195177417701770177017702401 8881 8881 8881 8881 888205202024202020202020202102165216521652165216521523252325232523252325Beaver Valley Unit 25.2 - 17PTLR Revision 7LRM Revision 79 Licensing Requirements ManualPressure and Temperature Limits Report5.2Table 5.2-3 (Page 1 of 1)Overpressure Protection System (OPPS) Setpoints (LCO 3.4.12')FUNCTIONSETPOINTOPPS Enable Temperature240"FPORV SetpointFiqure 5.2-8PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 18 Licensing Requirements ManualPressure and Temperature Limits Report5.2Table 5.24 (Page 1 of 1)Reactor Coolant Pump RestrictionsTncsRunninq RCPs< 1370F0-2> 1370F3PTLR Revision 7LRM Revision 79IBeaver Valley Unit 25.2 - 19 Licensing Requirements ManualPressure and Temperature Limits Report5.2Table 5.2-5 (Page 1 of 1)Calculation of Chemistry Factors Using Surveillance Capsule DataNotes:(a) f - calculated surveillance capsule neutron fluence (x 101e nlcm2, E > 1.0 MeV). Thesurveillance capsule fluence results are contained in Table 8-1 of Reference 13.FF = flUenCe faCtOr = f (0'28-0'1 .losf).ARTxpl values are the rrieasured 30 ft-lb shift values. The BVPS-2 ARTxel V?lues forthe surveillance weld data were not adjusted since the ratio was 0.91; therefore, aconservative value of 1.00 was used.The surveillance plate data is deemed non-credible, per Appendix A of Reference 13.The surveillance weld data is deemed credible, per Appendix A of Reference 13.(b)(c)(d)(e)MaterialCapsuleCapsule fl")pp{o)ARTppl(")FF*ARTlrorFF2IntermediateShell Plate89004-2(d)(Longitudinal)U0.6150.86424.420.730.746V2.641.26056.070.541.587W3.611.33471.094.681.778X5.631.42598.0139.652.431IntermediateShell Plate89004-2(d)(Transverse)U0.6150.86417.715.294.746V2.641.26046.158.071.587W3.611.33463.484.551.778X5.631.425144.1148.342.031SUM:631.8712.284CF = t(FF

• ARTpel) + f(FF2)= (631.87) + (2.284) = 51.4oFBeaver ValleyUnit 2SurveillanceWeld Metal(u)(Heat #83642)U0.6150.8644.13.540.746V2.641.26025.732.371.587W3.611.3346.08.001.778X5.631.425?2.932.632.031SUM:76.556.142CF = I(FF
• ARTr'uor) + >(FF) = (76.55) = (6.142) = 12.5FPTLR Revision 7LRM Revision 79Beaver Vafley Unit 25.2 - 20 Licensing Requirements ManualPressure and Temperature Limits Report5.2Table 5.2-6 (Page 1 of 1)Reactor Vessel Beltline Material PropertiesThe initial RTl,ror values for all of the beltline materials are based on measured data.According to the BVPS-2 reactor vessel CMTRs and MISC-PENG-ER-O21, the material forthe closure head flange (89002-1) and vessel flange (89001-1) forgings are ASTM ,4508Class 2. The ASTM A508 material specification does not require analysis of coppercontent. The importance of copper content in the irradiation embrittlement of ferriticpressure vessel steel was not recognized or regulated by the NRC or nuclear steamsupply system (NSSS) vendors when the BVPS-2 reactor vessel was constructed. Eventhough the material specification did not require analysis of copper content for ASTM 4508Class 2 material, check analyses on chemistry measurements (including copper) werereported in MISC-PENGER-021. The copper values reported for both the closure headflange (89002-1) and the vessel flange (89001-1) was 0.06%.The initial RT5p1 value is determined in accordance with the requirements ofSubparagraph NB-2331 of Section lll of the ASME B&PV Code, as specified byParagraph ll - D of 10 CFR Part 50, Appendix G. These fracture toughness requirementsare also summarized in Branch Technical Position MTEB Section ll.5-2 ("FractureToughness") of the NRC Regulatory Standard Review Plan. Following these requirements,along with the Charpy data reported in Table 3-3 of WCAP-9615 and the Tppl value of-30"F defined on page 3-14 of WCAP-9615, the initial RTl,ror value is concluded to beequal to Txpl (i.e., -30.0"F).Notes:(a)(b)(c)PTLR Revision 7LRM Revision 79MaterialCu(wt%)Ni(wt%)Initial RTr..ror(F1t"tClosure Head Flange 89002-10.06(b)4.74-10Vessel Fange 89001-10.06(b)0.730lntermedate Shell Plate 89004-10.0650.5560lntermedate Shefl Plate 89004-20.060.5740Lower Shell Plate 89005-10.080.5828Lower Shell Plate 89005-20.070.5733lntermedate to Lower Shell Weld 101-171 (Heat 83642)0.0460.086-30lntermedate Longitudinal Weld 101-124 A & B (Heat 83642)0.0460.086-30Lower Longitudinal Weld 101-1 42 A & B (Heat 83642)0.0460.086-30Plate Surveillance Material 89004-20.060.5740Surveillance Weld (Heat 83642)0.0650.065-30(")Beaver Valley Unit 25.2 - 21 Licensing Requirements ManualNotes.Pressure and Temperature Limits Report5.2fable 5.2-7 (Page 1 of 1)Reactor Vessel Extended Beltline Material Properties (")(a)(b)(c)Materials information taken from Reference 13Based on Reference 13, the generic Initial RT1ror values were determined in accordance withNUREG-0800 and the 10 CFR 50.61.As described in Reference 16, the reactor vessel initial RTr,ror values for the inlet nozzles areconservatively assigned values. The actual initial RTnror values for the reactor vessel inletnozzles are located in BVPS-2 UFSAR Table 5.3-1.MaterialDescriptionMaterialIDHeat NumberWt%Cuwt%NilnitialRTruor('F)(b)Upper Shell89003-1A9406-10.130.6050B9003-284431-20.120.606089003-3A9406-20.130.6050Upper ShellLongitudinal Welds101-1224101-122B101-122C51912 (3490)0.1560.059-5051912 (3536)0.1560.059-70EAIB0.420.9810 (Gen)IAGA0.030.98-30BOHB0.051.0010 (Gen)BAOED0.021.00-50Upper Shell toIntermediate ShellGirth Weld143-1214P5174 fi122\0.091.00-5051922 (3489)0.051.00-56 (Gen)AAGC0.030.98-74KOIB0.030.97-60Inlet Nozzles89011-12V2436-01-0020.110.8560("'89011-22V2437-02-0010.130.8860("'(Gen)89011-32V2445-02-0030.130.8470\Inlet Nozzle Welds105-1214105-121B,105-121C4P5174 (122\0.091.00-50LOHB0.031.03-60HABJC0.021.42-74BABBD0.021.04-74FABGC0.031.42-80EOBC4.020.96-60FAAFC0.071.04-60CCJC0.020.99-60FAGB0.021.06-30BAOED0.021.00-50Outlet Nozzles89012-1AV8080-2E95580.13a.72-1089412-2AV8120-2E95600.130.74-1089012-34V8097-2E95590.130.70-10Outlet Nozzle Welds147-1214107-121B,107-121CBABBD0.021.44-70FAAFC0.071.04-60HAAEC0.031.03-80HABJC0.021.42-70HAGB0.021.04-44GACJC0.031.00-80JAHB0.030.97-44PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 22 Licensing Requirements Manual Pressure and Temperature Limits Report5.2Table 5.2-B (Page 1 of 1)Summary of Adjusted Reference Temperature (ARTs) for 30 EFPY(.)Material DescriptionMethod Used ToCalculate the CF(b)30 EFPY ART1t4T ART ("F)3l4T ART ("F)Intermediate Shell Plate 89004-1Position 1.1143132Intermediate Shell Plate 89004-2Position 1.1119109Position 2.1119106Lower Shell Plate 89005-1Position 1.1123110Lower Shell Plate 89005-2Position 1.1120109Vessel Beltline Welds(")Position 1.15335Position 2.10-6Notes:(a) Table reflects Capsule X analysis per Reference 14.(b) Regulatory Guide 1.99, Revision 2.(c) All Beltline Welds are from Heat #83642, Linde 0091, Flux Lot #3536.PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 23 Licensing Requirements Manual Pressure and Temperature Limits Report5.2Table 5.2-9 (Page 1 of 1)Calculation of Adjusted Reference Temperatures (ARTs) for 30 EFPY(")PARAMETERVALUESOperating Time30 EFPYMaterial - Intermediate Shell Plate89004-189004-1Location1t4T3t4TChemistry Factor, CF ('F)40.540.5Fluence, (0, (101e n/cm2;(ul2.1130.8215Fluence Factor, FF1.2030.9448ARTppl=CFxFF('F)48.7438.27Intitial RTpp1, l("F)6060Margin, M("F)3434ART, per Regulatory Guide 1.99, Revision 2143132Notes:(a) Table reflects Capsule X analysis per Reference 14.(b) Ftuence (0, is based upon f,u,r (101e n/cm2, E > 1.0 MeV) = 3.39 at 30 EFPY. TheBeaver Valley Unit 2 reactor vessel wall thickness is 7.875 inches at the beltlineregion.PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 24 f- O)cr-og'6 .9'= .ao>trPEnJ>IsK)c{Ic\{LON=cf0)(Ut-o$oc0SE$OE ,*--.-\tit l^\-,a$i,:c Fs ocsrgEgEtE= r] 0) (l){ H*E(/): q<$'O* xm=otso 6g df TE.*^8 F:c!> = -dT EEUts 9 =. l-_ t'ui6' .gE.P".i E8-$ (E tt(/)(o tr gEC9 L GJb@ Q a=6 tu =ee r4=E P6I gg 5f ry 9:e*;*?rst5*'.6ocNrs o+.=6s=gEsEEEstEi :' -o-=: fi-E:(nE U)$o (l) (l)xP ,t, .5=65*^ i E;3ETtr= Eb5g :":HElr; fi #eEilgs? E 9 gPgmE;H a.-E"rteE b s?u-h 3b bSEE H: I 6i = E b SEEE-b. EIg::E q j "'"'.-Ef s-* g:f*_rr14efrrt,. E E " +'P b F:,td f, c Q > k F .e I EotPIa'ti ^il o-ocrat(DC<r)Lrv-an,I FE.Iro(oNn(o$q(r)cr)oiC\qt-(oc!tr)roojltIqO)sIIl,cgrF$$cf)$(f)$CO!tcf)tifcf)rf)d$qf-\o)(f)a$oqO)ooq$oo l't-f-f--f-f-N-fN@do)ote\lf-o)o,e\{

f-.r lr{-oOOOOoOOOOOoIa[-,^ir LLFot-vrlt-()c.ilf)nNf-qf-c.i (orr)d$(ol\-f-o)cf)n$oqo)(f)LO+-eO f a'F 9tLcF <-/4OCOO.itOtf@Ncf)cf)ocf)Io cf,Io cf)IO c)Iocf)Iocf)I..ao ^rE LLd ,S g.--c t-t-OroO.trf-Cf)gLr)-LO$$n$cr)qNq$coqN.q$coLOc-ioP 6aL#vO()LL=csu_I rr-c!O)OnNo)OnrNO)on$On$o-nNO)OnrNO)oRr$rOlr)-rsrOroIo)(oLO-O)(0LOI-o!- c{EeFo E--(gLL ==xJ.Va@1.c,*,f,)@trirnrf)Nrri@rd@rri(o\(0\F\rf-\t_uoOQotrzI(u(UEIIINs(0ca@$(trNsCOco@o)(g(6c\I$(ooo @N(U(U'=qo(trI$OOo)coNI$OO o)m:ocad)*9n$UdFgt-(uoc$c)g=aq)-oE0)LOIcoco)a-'a:)tIIrf)OO O)mNILooC) o,mrf-r1rOEq)(Jcs'oL$Smro{5<ooC)c-$'oNJmroS5<ECI()c(Io1-co=o-'=(J(nCIOCS'=0)+.$(1)_c ago)$==tuoO-ELo-q)(go-o-caL(lJ=oJQ)(udc)caLc)=oJOla-io;=Et*o9EC-baEfaoEEoC) o)c'affIaq;A-c (1)a=o-EEEEbPcoJ6c)-o1lCIL()o)c'afTIU'Ec)P=cn 16r-C9rl':Jo.=JO)c oJJaoIE()t-C)ct)c'a:fAtIEc{arriIIq)v-a==L=of$oo-EoFE(0o-tagaoFO-t! tLt.u$rOvc.9acoXLUO/^.--Jl+- +'o$rCoar .9lFt\ t-.rr- G)-:.- #II fi';>c,{, .o-' O)r{, oat-oo$cl .-a)mr_oc.9(U=C)NOaf,Ft(s=c$avcoEq)L'=u0)x.o)c'@co.(JJ t\ O)c l'-oc'6 .9.'= .a(I)tPt-J>Ig(oc{Ic.lLON.=l-e$r-q)$CIcooA^trLL,* otrdlf,)q?(odro(o(o(o$qN@(ocf)aocf)q(oIqrr)Oq$(oc'lcQIoq(o\cf)O)qc\Ioc.i=.Ec') LL!-o$v$cf)\rcf)$ cf)(orr)(ororoolifncf)cr)qrr)(oqNNq(oroqrf,)(oncf,cf)nCO(f)@(oOcj\ifqrc{ooFf-f-rf-@N@Nqr\(o\f-Nq@Nf-lt-Nl-(o\(on@qOt{)o._r l!(JoOc)oOoFOt-rool-oOOl-OIs)l-,^(rLLl-ot4-+t-(oIt-(o+l-O(oO (oOc.iNqcf)cf)RroroqNNqO) O)aLOroqcaCf)ncr)cr)oq(ogNqN-{tfit F-i 9lrCF i--trOroO(oorooroIof-IuoOCOIT'oOro1OroIro(oroIOl-IOCOIO(o-c:oO(oof--#!-.QoEE !L1l (E i.--cLLOq-o)Oc.jcoqro)rf-c)N-f-c.jf-ql-Norsq@(oOIt-NqNNrqa(oqsq$qFt*q(0O)q(oo)oP baL#vO()LL=(oLLIlJ-f-$@Of-$@Of-s@OF-$@Ol-s@Of-soqOf-$r-oqOf-$roqOl-$r@c;l-$oq Of-$r@c;f-voqOl-$oqO@@c\{O@@c'lO@@NoI5 8s.c*E63Fa2;5Erorlr)Ol{)rloOlJ)rU?ororqoLO-tr)Orf,loo1r)rU?Otr)rooLOrqolorrf)OroLOOtr)lr) oLOrrq(f@o,NqO@OJNqO@O)c\ qOgbF-O=*23ErJ-I(,oO$O)NIrcf)$smNI(0O$o)OO)$coNro)rLO(oc)rococ!-O)tr)mIIJm-ocoou_Jom$f-rLOo-$NNq)roC)t,moYc!OOIrOI(ocf)tNc{OOINOlf-cf)$NNcr)OOIc!OI()$$Nc{o(E'r--q)NrIcf)OOO)mNIcf)OOO)mCOIcoOOO)mC\NNC!NNrrttlrrOOOrrNlc9OIrOO)mNI-oO)meoIrroOJmc.ovo_'=(JaOCI(E'=c)oao'H$0_o-caLc)o_o_faao:>-c. -(/)NLLqEL.t- -to-tf 'cl,coJ0)PN-= L.';' c)E=!-gF-(,9-!-Oo-co_u)o_:)ac)NNoz#c)cENgriota.=E:c)f(ut-oo_Ec)FEcoo=aaot-0_oo-LLIU$lr)c.9@-oxI.IJq):(s6(/).F .(Uobr#OEa1(UrO-oo)!--CI5(o{oLo .gOF-o 0)omt-'ECIEa-oXuor+-coo()(gOa-o_Ft(sJ(oocc)Ec).=fuCIto,c'@co.c)J l- Otcl-oc'6 .9'= .ao>tpg;IEN.=c:)o($t-CI$c)mortLF</tr.qcr)c.isIc\l@lr)IN@roIc.i(oIc\l@\rI.q@Ic!@!tIe\l @ICrl @cf)IIt-c!f-q(0c!c!(oIq?c{cf)Ic\la;(oIc\lc{(oIe\lc{0.,Ic!dCOIc\I*;NIo.co, LLl-o$vf'-(oc{ootO)riqrf)qO)qltr)@dNqroqroqroloc"jqcf)l{)c.jq0.)\cf)qrf)o,c.jq cf)qroqlr)-< LL\JOCACAtf,)+OcfiOc.jlJ)$qcf)nOoc"jO c.jO c"joq(ooq(ol-(oq@(oacaqqo c.jq CA.? LLLJOooOooOOOOOoooOoooOO(foU)hCl-ot-v\(0Nq(I,qroo)rooo;O)rooqoNqroqlf)O)d1r)c"jqcf)qcf)qCO\C9qlr)qcoo,c"jo)r;o)ri-oftl F-'.= 9 tt-'- F- g--trOLOIO(oIOf-Io f-Io @Io(oIO(oIo(oIOcf)IoroIOrIOIOIOt-to(oIo6tOf-IO$IoOIOtitI-+, l_.9o^EEILnO:-itLOqNc{q$Olt-c{qf-Nqr$ql-NqroO)qf-Nqf-Nqf-C\tq$O)q$o)roc.jO)qt-NqroO)q$qt-Nqf-Nq-$qrifo.^o =^\., _oL+ivOC)LLf(ulrE lr-@@No@@c.lo@@ryO@@c!O@*rc!O@@rc\O@@c.lO@@rNO@@NO@@rc\Oo$$rOO$srOOtftfroO$$oos$rc;c)s.ifoO.t$oO$$OO$ $c;O$$OI5 8: ,c*863Fa2# 5E@OJNqO@O)Nqo@O)NOO@o) N qO@O,NOc;@O)NqO@o)NOO@O)NqO@O)NqO@O) c! qOrlr)rOOrr)qOrrorqc)rorOOrlf)-qolr)OOros-OOrlJ)o ororOc;LO\-qO!-'^8F-!-J'zEqI3$f-ro0_$mIoJO-m=om comC)OcoLLC)moLUC)LLLLO-)OOcoOll-<o[Uoco@rolr)o)I.IJNIO@O@OCOrr)O)LUNIOcv@O)rf)lJ)O)LIJNIl-O)O@OmmmC)ltIIC)LUr()--)mrmC)rO-O(,mI-o(uL(D+r(uNNNrrlllro ro LoOOO rrrINOO)mNINoOlmcoIN-OO)m<morrrNNNs-t-rtttf- f- f-OOOrrcg'E O_LE(J=Eo(l)NNaolCZa)6=c@(I)NNoz(l)foq)NXo;E:e-@5=oEN3riov.a.=E:ot-f+t(ol-c)o_EoFcc(sc)L5aaot-(Loo-TLUJ$lf)c.9occ)xtIlo:(EAU),ts .(U.iECI*O, I$.-o_doTtr c.l CIlr).cOF-o G)(uc0l-'EoT)coXLUt-o\Fco(UJ(J(UOaFo_Ft(sJ(s0gCIEot-'=oq)E.o)c'aco.c) J Licensing Requirements ManualPressure and Temperature Limits Report5.2Table 5.2-11 (Page 3 of 3)RTprs Calculation for Extended Beltline Region Materials at Life Extension (54 EFPY;t"tNotes:(a) Data obtained from Table 6-4 of Reference 13.(b) FF = fluence factor = 1(o'ze - 0'1 los (r)).(c) Initial RTruor values are measured values, unless othenruise noted.(d) Initial RTr,ror values are generic.(e) ARTprs = CF

• FF.(0 M=2*(or'+ oo'lt.(g) RTprs = lnitial RTruor + ARTprs + Margin.(h) As described in Reference 16, the reactor vessel initial RTllor values for the inlet nozzlesare conservatively assigned values. The actual initial RTr.ror values for the reactor vesselinlet nozzles are located in BVPS-2 UFSAR Table 5.3-1.PTLR Revision 7LRM Revision 79Beaver Valley Unit 25.2 - 28 Licensing Requirements Manual5.3ADM I N ISTRAT]VE CONTROLSProcedure Review and ApprovalProcedure Review and Approval5.35.0Each procedure or revision thereto of Technical Specification 5.4.1 shall be reviewed andapproved, as described below, prior to implementation.Each procedure or revision thereto shall be reviewed by an lndependent Qualified Reviewer(lQR), who is knowledgeable in the functional area affected. This IQR is not the individual whoprepared the procedure or associated procedure revision. The IQR shall ensure that crossdisciplinary reviews of new procedures and procedure revisions are completed prior to approvalof the procedure.The responsible IQR shall ensure each procedure or revision thereto includes a determinationof whether a procedure requires a 10 CFR 50.59 evaluation. lf a procedure or revision theretorequires a 10 CFR 50.59 evaluation, the Responsible Discipline Manager or his designee shallensure that the procedure, with the associated 10 CFR 50.59 evaluation, is fonruarded to thePlant Operations Review Committee for review. Pursuant to 10 CFR 50.59, NRC approval ofitems involving unreviewed safety questions shall be obtained prior to approval of the procedureor revision thereto for implementation. Final procedure approval shall be by the ResponsibleDiscipline Manager or his designee, as specified in administrative procedures.lQRs shall meet the applicable qualifications as delineated in plant procedures.Temporary changes to procedures will be approved as described in the FENOC QAPM,Regulatory Guide 1 .33 conformance description.Beaver Valley Unit 25.3-1LRM Revision 52 Licensing Requirements ManualRecord Retention5.45.0 ADMINISTRATIVE CONTROLS5.4 Record RetentionThe following records shall be retained for at least five (5) years:1. Records and logs of facility operation covering the time interval at each powerlevel.Records and logs of principal maintenance activities, inspections, repair andreplacement of principal items of equipment related to nuclear safety.Alf reportable events of the type described in 10 CFR 54.rc.Records of surveillance activities, inspections and calibrations required by theTechnical Specifications.5. Records of reactor tests and experiments.6. Records of changes made to operating procedures.7. Records of radioactive shipments.B. Records of sealed source leak tests and results.9. Records of annual physical inventory of all sealed source material of record.The following records shall be retained for the duration of the Facility Operating License:1. Records and drawing changes reflecting facility design modifications made tosystems and equipment described in the Final Safety Analysis Report.Records of new irradiated fuel inventory, fuel transfers and assernbly burnuphistories.Records of facility radiation and contamination surveys.Records of radiation exposure for all individuals entering radiation control areas.Records of gaseous and liquid radioactive material released to the environs.Records of transient or operational cycles for those facility components designedfor a limited number of transients or cycles.Records of training and qualification for current numbers of the plant staff.Records of in-service inspections performed pursuant to the TechnicalSpecifications.2.3.4.2.3.4.5.6.7.8.Beaver Valley Unit 25.4-1LRM Revision 52 Licensing Requirements Manual5.4 Record RetentionRecord Retention5.49. Records of Quality Assurance activities required by the QA Manual.10. Records of reviews performed for changes made to procedures or equipment orreviews of tests and experiments pursuant to 10 CFR 50.59.11. Records of meetings of the onsite review committee and the independent reviewboard.12. Records of the service lives of all hydraulic and mechanical snubbers including thedate at which the service life commences and associated installation andmaintenance records.13. Records of analyses required by the Radiological Environmental MonitoringProgram.14. Records of reviews performed for changes made to the Offsite Dose CalculationManual and the Process Control Program.Beaver Valley Unit 25.4-2LRM Revision 52 LICENSING REQUIREMENTS MANUALBASES TABLE OF CONTENTSPage No.B 3.0 LTCENSTNG REQUTREMENT (LR) APPLTCABTLTTY B 3.0-1B 3.0 LTCENSTNG REQUTREMENT SURVETLLANCE (LRS) APPLTCABTLTTY . B 3.0-5B 3.1 REACTIVITY CONTROL SYSTEMSB 3.1 .1 - B 3.1.8 Boration SystemsB 3.1 .1 -1B 3.1.9 Rod Position Indication - Shutdown.. . B 3.1.9-1B 3.1 .1 0 Boron Dilution ..... B 3.1 .1 0-1B 3.1.1 1 Rod Position lndication System - Shutdown Test Exception...... . B 3.1 .11-1B 3.3 INSTRUMENTATIONB 3.3.3B 3.3.4B 3.3.5B 3.3.6B 3.3.7B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.1 Loop lsolation Valves - Shutdown...Meteorological Monitoring Instrumentation B 3.3.3-1Axial Flux Difference (AFD) Monitor Alarm . B 3.3.4-1Quadrant Power Tilt Ratio (OPTR) Monitor Alarm ...... B 3.3.5-1Seismic Monitoring Instrumentation ... B 3.3.6-1Movable Incore Detectors..... ...... B 3.3.7-1B 3.3.8 Leading Edge Flow Meter ... B 3.3.8-1B 3.3.9 Turbine Overspeed Protection .... B 3.3.9-1B 3.3.11 Fuel Storage Pool Area Radiation Monitor. . B 3.3.11-1B 3.3.12 Explosive Gas Monitoring Instrumentation .. B 3.3.12-1B 3.3.13 Containment Hydrogen Analyzers...... . B 3.3.13-1B 3.3.14 Control Room lsolation Radiation Monitors . B 3.3.14-1B 3.3.15 Containment Area Radiation Alarm ..... B 3.3.15-1B 3.3.16 Accident Monitoring lnstrumentation ... B 3.3.16-1B 3.4.1 -1Chemistry . .......8 3.4.2-1Pressurizer.... ...... B 3.4.3-1DELETED... .......83.4.4-1Reactor Coolant System Head Vents. B 3.4.5-1Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge....... B 3.4.6-1B 3.6 CONTAINMENTB 3.4.2B 3.4.3B 3.4.4B 3.4.5 B 3.4.6B 3.6.1B 3.6.2B 3.7.1B 3.7.2B 3.7.3B 3.7.6B 3.7.7Containment lsolation Valves... ... B 3.6.1-1Containment Sump ...... B 3.6.2-1B 3.7 PLANT SYSTEMSB 3.7.4 Snubbers..... B 3.7 .4-1B 3.7.5 Standby Service Water System (SWE) ....... B 3.7.5-1Steam Generator Pressure/Temperature Limitation ... B 3.7.1-1Flood Protection ..... ..... B 3.7.2-1Sealed Source Contamination ..... B 3.7.3-1Explosive Gas Mixture.. ....... B 3.7.6-1Supplemental Leak Collection and Release System (SLCRS) ...8 3.7.7-1Beaver Valley Unit 2B-iLRM Revision 67 LICENSING REQUIREMENTS MANUALBASES TABLE OF CONTENTSPage No.B 3.8 ELECTRICAL POWER SYSTEMSB 3.8.1 125V D.C. Battery Banks Maintenance RequirementsB 3.8.2B 3.8.33.9.23.9.3BBBB3.9 REFUELING OPERATIONS3.9.1 Crane Travel - Spent Fuel Storage Pool BuildingEmergency DG 2000 Hour Rating LimitMain Fuel Oil Storage Tank Maintenance RequirementsManipulator CraneDecay TimeB 3.8.1 -1B 3.8.2-1B 3.8.3-1B 3.9.1 -1B 3.9.2-1B 3.9.3-1B-iiBeaver Valley Unit 2LRM Revision 67 Licensing Requirements ManualB 3.0 LTCENSTNG REQUTREMENT (LR) AppLtCABtLrTyBASESLR ApplicabilityB 3.0LRsLR 3.0.1 through LR 3.0.3 establish the general requirements applicableto alf LRs and apply at all times, unless otherwise stated.LR 3.0.1LR 3.0.1 establishes the Applicability statement within each individual LRas the requirement for when the LR is required to be met (i.e., when theunit is in the MODES or other specified conditions of the Applicabilitystatement of each LR).LR 3.0.2LR 3.0.2 establishes that upon discovery of a failure to meet an LR, theassociated ACTIONS shall be met. The Completion Time of eachRequired Action for an ACTIONS Condition is applicable from the point intime that an ACTIONS Condition is entered. The Required Actionsestablish those remedial measures that must be taken within specifiedCompletion Times when the requirements of an LR are not met. ThisS pecification establishes that:Completion of the Required Actions within the specified CompletionTimes constitutes compliance with a Specification andCompletion of the Required Actions is not required when an LCO ismet within the specified Completion Time, unless othenryisespecified.There are two basic types of Required Actions. The first type of RequiredAction specifies a time limit in which the LR must be met. This time limitis the Completion Time to restore an inoperable/Nonfunctional system orcomponent to OPERABLE/FUNCTlONAL status or to restore variables towithin specified limits. lf this type of Required Action is not completedwithin the specified Completion Time, entry into LR 3.0.3 may berequired, or a shutdown may be required to place the unit in a MODE orcondition in which the LR is not applicable. (Whether stated as aRequired Action or not, correction of the entered Condition is an actionthat may always be considered upon entering ACTIONS.) The secondtype of Required Action specifies the remedial measures that permitcontinued operation of the unit that is not further restricted by theCompletion Time. In this case, compliance with the Required Actionsprovides an acceptable level of safety for continued operation.Completing the Required Actions is not required when an LR is met or isno longer applicable, unless otherwise stated in the individual LR.a.b.Beaver Valley Unit 2B3.0-1LRM Revision 67 Licensing Requirements ManualBASESLR ApplicabilityB 3.0LR 3.0.2 (continued)The nature of some Required Actions in some Conditions necessitatesthat, once the Condition is entered, the Required Actions must becompleted even though the associated Conditions no longer exist. Theindividual LR's ACTIONS specify the Required Actions where this is thecase.The Completion Times of the Required Actions are also applicable whena system or component is removed from service intentionally. Thereasons for intentionally relying on the ACTIONS include, but are notlimited to, performance of Surveillances, preventive maintenance,corrective maintenance, or investigation of operational problems.Entering ACTIONS for these reasons must be done in a manner thatdoes not compromise safety. lntentional entry into ACTIONS should notbe made for operational convenience. Additionally, if intentional entry intoACTIONS would result in redundant equipment beinginoperable/Nonfunctional, alternatives should be used instead. Doing solimits the time both subsystems/trains of a required function areinoperable/Nonfunctional and limits the time conditions exist which mayresult in LR 3.0.3 being entered. lndividual LRs may specify a time limitfor performing an LRS when equipment is removed from service orbypassed for testing. ln this case, the Completion Times of the RequiredActions are applicable when this time limit expires, if the equipmentremains removed from service or bypassed.When a change in MODE or other specified condition is required tocomply with Required Actions, the unit may enter a MODE or otherspecified condition in which another LR becomes applicable. In this case,the Completion Times of the associated Required Actions would applyfrom the point in time that the new LR becomes applicable, and theACTIONS Condition(s) are entered.LR 3 0.3LR 3.0.3 establishes the actions that must be implemented when an LRnot met and:The ACT]ONS require that LR 3.0.3 be entered;An associated Required Action and Completion Time is not met andno other Condition applies; orThe condition of the unit is not specifically addressed by theassociated ACTIONS. This means that no combination ofConditions stated in the ACTIONS can be made that exactlycorresponds to the actual condition of the unit.a.bc.Beaver Valley Unit 283.0-2LRM Revision 67 Licensing Requirements ManualBASESLR ApplicabilityB 3.0LR 3.0.3 (continued)This LR delineates the actions required when directed by the associatedACTIONS, or when operation cannot be maintained within the prescribedlimits as defined by the LR and its ACTIONS. lt is not intended to beused as an operational convenience that permits routine voluntaryremoval of redundant systems or components from service in lieu of otheralternatives that would not result in redundant systems or componentsbeing inoperable/Nonfu nctiona l.Upon entering LR 3.0.3, Action must be initiated to immediatelycommunicate the situation to the Shift Manager and document thecondition in accordance with the FENOC Corrective Action Program.Entry into LR 3.0.3 may result in the Unit being outside of itsdesign/licensing bases and therefore potentially reportable per 10 CFR50.72 and/or 50.73. The safety significance of the condition is required tobe evaluated per NOP-OP-1009 "Operability Determinations andFunctionality Assessments" (consistent with the guidance of NRCRegulatory lssue Summary 2005-20 (Revision 1), and as required byAppendix B of 10 CFR 50) and appropriate corrective actions are requiredto be initiated, within the time frame determined by the Shift Manager thatshall not exceed 48 hours from the time of entry into LR 3.0.3. The timeframe for completion of the corrective actions shall be commensurate withthe safety significance of the condition, consistent with the guidance ofNOP-OP-1009.The actions required by LR 3.0.3 may be terminated and LR 3.0.3 exitedif any of the following occurs:The LR is now met.The LR is no longer applicable,A Condition exists for which the Required Actions have now beenperformed, orACTIONS exist that do not have expired Completion Times. TheseCompletion Times are applicable from the point in time that theCondition is initially entered and not from the time LR 3.0.3 is exited.a.b.c.d.Beaver Valley Unit 2830-3LRM Revision 67 Licensing Requirements ManualBASESLR ApplicabilityB 3.0LR 3.0.4LR 3.0.4 establishes the allowance for restoring equipment to serviceunder administrative controls when it has been removed from service ordeclared inoperable/Nonfunctional to comply with ACTIONS. The solepurpose of this LR is to provide an exception to LR 3.0.2 (e.g., to notcomply with the applicable ACTIONS) to allow the performance ofrequired testing to demonstrate either:The OPERABILITY/FUNCTIONALITY of the equipment beingreturned to service: orThe OPERAB I LITY/FU NCTIONALITY of other eq u ipment.The administrative controls ensure the time the equipment is returned toservice in conflict with the requirements of the ACTIONS is limited to thetime absolutely necessary to perform the required testing to demonstrateOPERABILITY/FUNCTIONALITY. lf the OPERABILITY/FUNCTIONALITY of the affected equipment can not be demonstrated,the administrative controls will also ensure the equipmenUplant isrestored to the required condition in a timely manner. This LR does notprovide time to perform any other preventive or corrective maintenance.Minor corrections such as adjustments of limit switches to correct positionindication anomalies are considered within the scope of this LR.An example of demonstrating the OPERABILITY/FUNCTIONALITY of theequipment being returned to service is reopening a containment isolationvalve that has been closed to comply with ACTIONS and must bereopened to perform the surveillance requirements.An example of demonstrating the OPERABILITY/FUNCTIONALITY ofother equipment is taking an inoperable/Nonfunctional channel or tripsystem out of the tripped condition to prevent the trip function fromoccurring during the performance of a surveillance requirement onanother channel in the other trip system. A similar example ofdemonstrating the OPERABILITY/FUNCTIONALITY of other equipment istaking an inoperablelNonfunctional channel or trip system out of thetripped condrtion to permit the logic to function and indicate theappropriate response during the performance of a surveillancerequirement on another channel in the same trip system.a.b.LR305The purpose of LR 3.0.5 is to provide guidance that clarifies theappropriate action when LRM requirements specified in the TechnicalSpecifications such as those listed in the Tables containinglnstrumentation Response Times or in the COLR are not met. Theguidance of this LR is intended to prevent potential confusion ormisapplication of the provisions in the LRM to the requirements governedby Technical Specifications.Beaver Valley Unit 2830-4LRM Revision 67 Licensing Requirements ManualBASESLR ApplicabilityB 3.0LR 3.0.6There are certain special tests and operations required to be performed atvarious times over the life of the unit. These special tests and operationsare necessary to demonstrate select unit performance characteristics, toperform special maintenance activities, and to perform special evolutions.Test Exception LR 3.1.11 allows specified LR requirements to bechanged to permit performances of these special tests and operations,which othenruise could not be performed if required to comply with therequirements of the LR. Unless othennrise specified, all the other LRrequirements remain unchanged. This will ensure all appropriaterequirements of the MODE or other specified condition not directlyassociated with or required to be changed to perform the special test oroperation will remain in effect.The Appficability of a Test Exception LR represents a condition notnecessarily in compliance with the normal requirements of an LR.Compliance with Test Exception LRs is optional. A special operation maybe performed either under the provisions of the appropriate TestException LR or under the other applicable LR requirements. lf it isdesired to perform the special operation under the provisions of the TestException LR, the requirements of the Test Exception LR shall befollowed.Beaver Valley Unit 283.0-5LRM Revision 67 Licensing Requirements ManualB 3.0 LTCENSING REQUTREMENT SURVETLLANCE (LRS) APPLTCABTLTTYBASESLRS ApplicabilityB 3.0LRSsLRS 3.0.1 through LRS 3.0.3 establish the general requirementsapplicable to all Specifications and apply at all times, unless othenarisestated.LRS 3.0.1LRS 3.0.1 establishes the requirement that surveillances must be metduring the MODES or other conditions in the Applicability for which therequirements of the LR apply unless othenruise stated in an individualLRS. The purpose of this LRS is to ensure that surveillances areperformed to verify the OPERABILITY/FUNCTIONALITY of systems andcomponents and that parameters are within specified limits to ensure safeoperation of the facility when the plant is in a MODE or other specifiedcondition for which the associated LRs are applicable. Failure to meet aLRS within the specified Frequency, in accordance with LRS 3.0.2,constitutes a failure to meet a LR.Surveillances may be performed by means of any series of sequential,overlapping, or total steps provided the entire Surveillance is performedwithin the specified Frequency. Additionally, the definition related toinstrument testing (e.9., CHANNEL CALIBRATION) specify that thesetests are performed by means of any series of sequential, overlapping, ortotal steps.Systems and components are assumed to be OPERABLE/FUNCTIONALwhen the associated LRSs have been met. Nothing in this LR, however,is to be construed as implying that systems or components areOPERABLE/FUNCTIONAL when:The systems or components are known to beinoperable/Nonfunctional, although still meeting the LRSs; orThe requirements of the LRS(s) are known not to be met betweenrequired performance of LRSs.LRSs do not have to be performed when the facility is in a MODE or otherspecified condition for which the requirements of the associated LR arenot applicable unless otherwise specified. The LRSs associated with aTest Exception are only applicable when the Test Exception is used as anallowable exception to the requirements of an LR.Unplanned events may satisfy the requirements (including applicableacceptance criterla) for a given LRS. ln this case, the unplanned eventmay be credited as fulfilling the performance of the LRS. This allowanceincludes those LRSs whose performance is normally precluded in a givenMODE or other specified condition.a.bBeaver Valley Unit 2B3.0-6LRM Revision 67 Licensing Requirements ManualBASESLRS ApplicabilityB 3.0LRS 3.0.1 (continued)Surveillances, including surveillances invoked by Required Actions, donot have to be performed on inoperable/Nonfunctional equipmentbecause the ACTIONS define the remedial measures that apply.Surveillances have to be met and performed in accordance with LRS3.0.2, prior to returning equipment to OPERABLE/FUNCTIONAL status.Upon completion of maintenance, appropriate post maintenance testing isrequired to declare equipment OPERABLE/FUNCTIONAL. This includesensuring applicable LRSs are not failed and their most recentperformance is in accordance with LRS 3.0.2. Post maintenance testingmay not be possible in the current MODE or other specified conditions inthe Applicability due to the necessary unit parameters not having beenestablished. In these situations, the equipment may be consideredOPERABLE/FUNCTIONAL provided testing has been satisfactorilycompleted to the extent possible and the equipment is not othenruisebelieved to be incapable of performing its function. This will allowoperation to proceed to a MODE or other specified condition where othernecessary post maintenance tests can be completed.An example of this process is Auxiliary Feedwater (AFW) pump turbinemaintenance during refueling that requires testing at steam pressures ofgreater than 600 psig. lf other appropriate testing is satisfactorilycompleted, the AFW System can be considered OPERABLE. This allowsstartup and other necessary testing to proceed until the plant reaches thesteam pressure required to perform the testing.LRS 3.0.2LRS 3.0.2 establishes the requirements for meeting the specifiedFrequency for Surveillances and any Required Action with a CompletionTime that requires the periodic performance of the Required Action on a"once per . . ." interval.LRS 3.0.2 permits a 25o/o extension of the interval speci,fied in theFrequency. This extension facilitates Surveillance scheduling andconsiders plant operating conditions that may not be suitable forconducting the Surveillance (e.9., transient conditions or other ongoingSurveillance or maintenance activities).The 25o/o extension does not significantly degrade the reliability thatresults from performing the Surveillance at its specified Frequency. Thisis based on the recognition that the most probable result of any particularSurveillance being performed is the verification of conformance with theLRS. The exceptions to LRS 3.A.2 are those Surveillances for which the25o/a extension of the interval specified in the Frequency does not apply.Beaver Valley Unit 283.0-7LRM Revision 67 Licensing Requirements ManualBASESLRS ApplicabilityB 3.0LRS 3.0.2 (continued)These exceptions are stated in the individual LRs or LRS. Therequirements of regulations take precedence over the LRs. The LRscannot in and of themselves extend a test interval specified in theregulations.As stated in LRS 3.0.2, the 25o/o extension also does not apply to theinitial portion of a periodic Completion Time that requires performance ona "once per ..." basis. The 25o/o extension applies to each performanceafter the initial performance. The initial performance of the RequiredAction, whether it is a particular Surveillance or some other remedialaction, is considered a single action with a single Completion Time. Onereason for not allowing the 25o/o extension to this Completion Time is thatsuch an action usually verifies that no loss of function has occurred bychecking the status of redundant or diverse components or accomplishesthe function of the inoperable/Nonfunctional equipment in an alternativemanner.The provisions of LRS 3.0.2 are not rntended to be used repeatedlymerely as an operational convenience to extend Surveillance intervals(other than those consistent with refueling intervals) or periodicCompletion Time intervals beyond those specified.LRS 3.0.3LRS 3.0.3 establishes the flexibility to defer declaring affected equipmentinoperable/Nonfunctional or an affected variable outside the specifiedlimits when a surveillance has not been completed within the specifiedFrequency. A delay period of up lo 24 hours or up to the limit of thespecified Frequency, whichever is greater, applies from the point in timethat it is discovered that the surveillance has not been performed inaccordance with LRS 3 .0.2, and not at the time that the specifiedFrequency was not met.This delay period provides adequate time to complete surveillances thathave been missed. This defay period permits the completion of asurveillance before complying with Required Actions or other remedialmeasures that might preclude completion of the surveillance.The basis for this delay period includes consideration of unit conditions,adequate planning, availability of personnel, the time required to performthe surveillance, the safety significance of the delay in completing therequired surveillance, and the recognitron that the most probable result ofany particular surveillance being performed is the verification ofconformance with the requirements.Beaver Valley Unit 2830-8LRM Revision 67 Licensing Requirements ManualBASESLRS ApplicabilityB 3.0LRS 3.0.3 (continued)When a surveillance with a Frequency based not on time intervals, butupon specified unit conditions, operating situations, or requirements ofregulations (e.9., prior to being placed into use, or in accordance with 10CFR 50.4, etc.) is discovered to not have been performed when specified,LRS 3.0.3 allows the full delay period of up to the specified Frequency toperform the surveillance. However, since there is not a time intervalspecified, the missed surveillance should be performed at the firstreasonable opportunity.LRS 3.0.3 provides a time limit for, and allowances for the performanceof, surveillances that become applicable as a consequence of MODEchanges imposed by Required Actions.Failure to comply with specified Frequencies for LRSs is expected to bean infrequent occurrence. Use of the delay period established byLRS 3.0.3 is a flexibility which is not intended to be used as anoperational convenience to extend surveillance intervals. While up to24 hours or the limit of the specified surveillance interval is provided toperform the missed surveillance, it is expected that the missedsurveillance will be performed at the first reasonable opportunity. Thedetermination of the first reasonable opportunity should includeconsideration of the impact on plant risk (from delaying the surveillanceas well as any plant configuration changes required or shutting the plantdown to perform the surveillance) and impact on any analysisassumptions, in addition to unit conditions, planning, availability ofpersonnel, and the time required to perform the surveillance. This riskimpact should be managed through the program in place to implement 10CFR 50.65(a)(4) and its implementation guidance, NRC Regulatory Guide1.182, "Assessing and Managing Risk Before Maintenance Activities atNuclear Power Plants." This Regulatory Guide addresses considerationof temporary and aggregate risk impacts, determination of riskmanagement action thresholds, and rtsk management action up to andincluding plant shutdown. The missed surveillance should be treated asan emergent condition as discussed in the Regulatory Guide. The riskevaluation may use quantitative, qualitative, or blended methods. Thedegree of depth and rigor of the evaluation should be commensurate withthe importance of the component. Missed surveillances for importantcomponents should be analyzed quantitatively. lf the results of the riskevaluation determine the risk increase is significant, this evaluationshould be used to determine the safest course of action. All missedsurveillances will be placed in the Corrective Action Program.Beaver Valley Unit 283.0-9LRM Revision 67 Licensing Requirements ManualBASESLRS ApplicabilityB 3.0LRS 3.0.3 (continued)lf a surveillance is not completed within the allowed delay period, then theequipment is considered inoperable/Nonfunctional or the variable isconsidered outside the specified limits and the Completion Times of theRequired Actions for the applicable LR Action Condition beginsimmediately upon expiration of the delay period. lf a surveillance is failedwithin the delay period, then the equipment is inoperable/Nonfunctional,or the variable is outside the specified limits and the Completion Times ofthe Required Actions for the applicable LR Action Condition beginimmediately upon the failure of the surveillance.Completion of the surveillance within the delay period allowed by thisSpecification, or within the Allowed Outage Time of the applicableACTIONS, restores compliance with LRS 3.0.1.Beaver Valley Unit 2B 3.0 - 10LRM Revision 67 Licensing Requirements ManualB 3.1 REACTIVITY CONTROL SYSTEMSB 3.1.1 - B 3.1.8 Boration SystemsBASESBoration SystemsB 3.1.1 - B 3.1.8BACKGROUNDThe boron injection system ensures that negative reactivity control isavailable during each MODE of facility operation.With the RCS average temperature above 350'F, a minimum of twoboron injection flow paths are provided to ensure single functionalcapability in the event an assumed failure renders one of the flow pathsNonfunctional. Allowable out-of-service periods ensure that minorcomponent repair or corrective action may be completed without unduerisk to overall facility safety from injection system failures during the repairperiod.With the RCS average temperature less than 200"F, Low Head Safetylnjection pump may be used in lieu of the FUNCTIONAL charging pumpwith a minimum open RCS vent of 3.14 square inches. This will providelatitude for maintenance and lSl examinations on the charging system forrepair or corrective action and will ensure that boration and makeup areavailable when the charging pumps are out-of-service. An open ventinsures that RCS pressure will not exceed the shutoff head of the LowHead Safety Injection pumps.2SlS-MOV8888A and B are the Low Head Safety Injection Pumpdischarge isolation valves to the RCS cold legs, the valves must beclosed prior to reducing RCS pressure below the RWST head pressure toprevent draining into the RCS. Emergency backup power is not requiredsince these valves are outside containment and can be manuallyoperated if required, this will allow the associated diesel generator to betaken out of service for maintenance and testing.The Technical Specification limitations for a maximum of one centrifugalcharging pump to be OPERABLE and the Surveillance Requirement toverify all charging pumps except the required OPERABLE pump to beinoperable when less than or equal to the enable temperature set forth inthe PTLR provides assurance that a mass addition pressure transient canbe relieved by the operation of a single PORV. Substituting a Low HeadSafety Injection pump for a charging pump in MODES 5 and 6 will notincrease the probability of an overpressure event since the shutoff headof the Low Head Safety Injection pumps is below the setpoint of theoverpressure protection system.Beaver Valley Unit 28311-1LRM Revision 67 Licensing Requirements ManualBASESBoration SystemsB3.1.1 -83.1.8BACKGROUN D (continued)The boration capability of the boric acid storage system is sufficient toprovide a SHUTDOWN MARGIN from all operating conditions of 1 .77o/oAUk after xenon decay and cooldown to 200"F. The maximum borationcapability requirements occur at BOL from full power peak xenonconditions and requires 13,390 gallons of 7000 ppm borated water fromthe boric acid storage tanks.With the RCS temperature below 350'F, one boron injection flow path isacceptable without single failure consideration on the basis of the stablereactivity condition of the reactor and the additional restrictions prohibitingCORE ALTERATIONS and positive reactivity change in the event thesingle injection system becomes Nonfunctional.The boration capability required below 200'F is sufficient to provide aSHUTDOWN MARGIN of 1% Lklk after xenon decay and cooldown from200"F to 140'F. This condition requires either 2315 gallons of 7000 ppmborated water from the boric acid storage tanks or 10,196 gallons of2400 ppm borated water from the refueling water storage tank.Beaver Valley Unit 28 31.1 -2LRM Revision 67 Licensing Requirements ManualB 3.1 REACTIVITY CONTROL SYSTEMSB 3.1.9 Rod Position Indication - ShutdownBASESRod Position Indication - ShutdownB 3.1.9BACKGROUNDThe LR applies to the Unit 2 digital rod position indication. The rodposition indication system provides indication of rod position in the controlroom which is used to verify that the rods are correctly positioned. Inoperating MODES (1 and 2), this indication is used to verify rod insertionand alignment limits which are initial conditions of Design Basis Accidents(DBAs) are met and to verify that the rods are fully inserted following areactor trip. The requirements for Rod Position lndication in Modes 1 and2 are specified in the Technical Specifications. ln the shutdown MODESaddressed by this LR, rod position indication only provides information toverify rod position, and is not relied on to verify the initial conditions ofDBAs are met or to verify rod insertion after a reactor trip.Beaver Valley Unit 2B 3.1 .9LRM Revision 52 Licensing Requirements ManualB 3.1 REACTIVITY CONTROL SYSTEMSB 3.1 .10 Boron DilutionBASESBoron DilutionB 3.1 .10BACKGROUNDA minimum flow rate of at least 3000 GPM provides adequate mixing,prevents stratification and ensures that reactivity changes will be gradualduring boron concentration reductions in the Reactor Coolant System. Aflow rate of at least 3000 GPM will circulate an equivalent ReactorCoolant System volume of 9370 cubic feet in approximately 30 minutes.The reactivity change rate associated with boron reductions will,therefore, be within the capability for operator recognition and control.Beaver Valley Unit 2B 3.1.10 - 1LRM Revision 52 Licensing Requirements ManualRod Position Indication System - Shutdown Test ExceptionB 3.1.11B 3.1 REACTIVITY CONTROL SYSTEMSB 3.1.1 1 Rod Position Indication System - Shutdown Test ExceptionBASESBACKGROUNDThis test exception permits the Position Indication System to beNonfunctional during rod drop time measurements. The exception isrequired since the data necessary to determine the rod drop time arederived from the induced voltage in the position indicator coils as the rodis dropped. This induced voltage is small compared to the normal voltageand, therefore, cannot be observed if the Position Indication Systemsremain FUNCTIONAL.Beaver Valley Unit 2831.11 -1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.3 Meteorological Monitoring InstrumentationBASESMeteorological Mon itoring I nstrumentationB 3.3.3BACKGROUNDThe FUNCTIONALITY of the meteorological instrumentation ensures thatsufficient meteorological data is available for estimating potential radiationdoses to the public as a result of routine or accidental release ofradioactive materials to the atmosphere. This capability is required toevaluate the need for initiating protective measures to protect the healthand safety of the public and is consistent with the recommendations ofRegulatory Guide 1.23, "Onsite Meteorological Programs."Beaver Valley Unit 2B33.3-1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.4 Axial Flux Difference (AFD) Monitor AlarmBASESAFD Monitor AlarmB 3.3.4BACKGROUNDSurveillance of the AFD verifies that the AFD, as indicated by the Nuclearlnstrumentation System (NlS) excore channels, is within its limits. Duringoperation above 50o/o RATED THERMAL POWER, when the AFDmonitor alarm is Nonfunctional, additional surveillance criteria is requiredby the Licensing Requirements Manual beyond the surveillance criteriarequired by the Technical Specifications to detect operation outside of thelimits.Beaver Valley Unit 2B 3.3.4 - 1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.5 Quadrant Power Tilt Ratio (OPTR) Monitor AlarmBASESQPTR Monitor AlarmB 3.3.5BACKGROUNDSurveillance of the QPTR verifies that the QPTR, as indicated by theNuclear lnstrumentation System (NlS) excore channels, is within its limits.During operation above 50o/o RATED THERMAL POWER, when theQPTR monitor alarm is Nonfunctional, additional surveillance criteria isrequired by the Licensing Requirements Manual beyond the surveillancecriteria required by the Technical Specifications to detect any relativelyslow changes in QPTR. For those causes of core power tilt that occurquickly (e.g., a dropped rod), there are other indications of abnormalitythat prompt a verification of core power tilt.Beaver Valley Unit 2B33.5-1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.6 Seismic Monitoring lnstrumentationBASESSeismic Monitoring InstrumentationB 3.3.6BACKGROUNDThe FUNCTIONALITY of the seismic monitoring instrumentation ensuresthat sufficient capability is available to promptly determine the magnitudeof a seismic event and evaluate the response of those features importantto safety. This capability is required to permit comparison of themeasured response to that used in the design basis for the facility and isconsistent with the recommendations of Regulatory Guide 1.12," lnstrumentation for Earthquakes." Applicable guidance for performanceof CHANNEL CHECK, CHANNEL OPERATIONAL TEST ANd CHANNELCALIBRATION is provided in ANSI/ANS-2.2-1 978.The measurement ranges provided in Table 3.3.6-1 include themeasurement tolerance provided within Regulatory Guide 1.12 byreference to ANSI N18.5.Beaver Valley Unit 2B336-1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.7 Movable Incore DetectorsBASESMovable lncore DetectorsB 3.3.7BACKGROUNDThe FUNCTIONALITY of the movable incore detectors with the specifiedminimum complement of equipment ensures that the measurementsobtained from use of this system accurately represent the spatial neutronflux distribution of the reactor core. The FUNCTIONALITY of this systemis demonstrated by irradiating each detector used and determining theacceptability of its voltage curve. Guidance for changing incore detectorrequirements can be found in the NRC SER for License Amendments 233and 1 1 5, dated Septemb er 7 ,2000.For the purpose of measuring Fq(Z) or F[g, a full incore flux map is used.Quarter-core flux maps, as defined in WCAP-8648, June 1976, may beused in re-calibration of the excore neutron flux detection system, and fullincore flux maps or symmetric incore thimbles may be used for monitoringthe Quadrant Power Tilt Ratio when one Power Range Channel isinoperable.Beaver Valley Unit 2B 3.3.7 - 1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.8 Leading Edge Flow MeterBASESLeading Edge Flow MeterB 3.3.8BACKGROUNDThe Leading Edge Flow Meter (LEFM) is the preferred method ofobtaining the daily calorimetric heat balance measurements. A properlyoperating LEFM provides superior measurement accuracy, and morereliable assurance that the reactor is being operated at a power level thatis within the assumptions of the design basis accident analyses.The LEFM system provides measurements of feedwater mass flow andtemperature yielding a total power measurement uncertainty of betterthan t0.6% RTP at full power. This is more accurate than the venturi-based flow instrumentation. However, the accuracy of the LEFM is onlyvalid while the instrument is performing as designed. The on-lineverification and self-diagnostic features of the LEFM provides the ability toassure that the instrument is performing as designed.The Applicability Statement applies when performing calorimetric powermeasurements during MODE 1 operations at steady-state conditionsabove 98.6% of RTP. The Operating License limits the maximum steadystate power to 100% of RTP when calorimetric heat balancemeasurements are made daily using the LEFM.lf the LEFM is not FUNCTIONAL during the interval between requiredcalorimetric heat balance measurements, plant operation may continue at< 100% of RTP steady-state, using the existing Nuclear lnstrumentationSystem (NlS) indication until the next required performance of the dailypower calorimetric surveillance is due.lf the LEFM remains Nonfunctional at the time that the next requiredcalorimetric heat balance measurement is due, plant operation maycontinue at < 98.6or;u of RTP steady-state, by making calorimetricmeasurements using feedwater flow venturis and ResistanceTemperature Detector (RTD) indications. The requirement to reducepower within one hour is based upon comparison to similar actionstatements in the technical specifications. The increase in likelihood thatthe NIS will need renormalizing after 25 hours compared to after 24 hoursis considered negligible (or after 31 hours compared to after 30 hours ifTechnical Specification SR 3.0.2 is applied).It is preferable that the daily heat balance calculations be made using thesubroutine on the plant computer system (PCS). lf the PCS isunavailable, a manual calculation that accounts for steam generatorblowdown is acceptable, and may be performed in lieu of using the PCS.Beaver Valley Unit 2B 3.3.8 - 1LRM Revision 67 Licensing Requirements ManualBASESEdge Flow MeterB 3.3.8BACKGROU N D (continued)This surveillance is performed every 24 hours when power is above 5A%.The NIS excore power range channel indrcations are renormalized if theyare not found to be within +2o/o of the calorimetric measurement. Thisx2% requirement for renormalization is distinct from the allowance forcalorimetric uncertainty, and these allowances are handled asindependent contributions to determine the maximum power assumeddesign basis accident analyses.The plant may then be run for the next 24-hour period using thisnormalized NIS indication. Although calorimetric power indication may bemonitored continuously, it is not required to be consulted again until therequired daily calorimetric comparisons of NIS indication are performed.The surveillance requirement to perform planned maintenance andinspections every 18 months is based upon the manufacturer'srecommendations, and is consistent with the surveillance intervalsspecified for similar electronic apparatus.Additional guidance for determining steady-state THERMAL POWERtaken from NEI POSITION STATEMENT, "Guidance to Licensees onComplying with the Licensed Power Limit," dated June 12, 2AA8[ML081750537], endorsed by the NRC in Regulatory lssue Summary20A7-21, Revision 1, "Adherence to Licensed Power Limits," datedFebruary 9, 2009 [ML082690105], and is described in the BVPSOperating Manual.Beaver Valley Unit 2B 3.3.8 - 2LRM Revision 75 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.9 Turbine Overspeed ProtectionBASESTurbine Overspeed ProtectionB 3.3.9BACKGROUNDThis LR is provided to ensure that the turbine overspeed protectioninstrumentation and the turbine speed control valves are FUNCTIONALand will protect the turbine from excessive overspeed. Protection fromturbine excessive overspeed is required since excessive overspeed of theturbine could generate potentially damaging missiles which could impactand damage safety related components, equipment or structures.Surveillance test intervals for the turbine speed control valves areassumed in a turbine overspeed calculation discussed in the BeaverValley Power Station Unit No. 2 Updated Final Safety Analysis Report.The LRS note allows for entry into the applicability of LR 3.3.9 withoutLRS 3.3.9.1, 3.3.9.2, 3.3.9.3, and 3.3.9.4 being performed for up to72 hours after entry into MODE 3 during station startup under certainconditions. These conditions are after any steam flow path; i.e., one mainsteam isolation valve, one main steam bypass valve or any other steamflow path, to the turbine is not isolated during station startup. fhe 72 hourdelay will permit entry into MODE 3 during station startup to establishsteam conditions for valve testing. Testing the valve under steamconditions is more representative of plant conditions than testing whensteam is isolated. The valves may be considered FUNCTIONAL prior toentry into MODE 3 during station startup provided the testing has beensatisfactorily completed to the extent possible and the valves are nototherwise believed to be incapable of performing their function.Beaver Valley Unit 2B 3.3.9 - 1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.11 Fuel Storage Pool Area Radiation MonitorBASESFuel Storage Pool Area Radiation MonitorB 3.3.1 1BACKGROUNDThe Fuel Storage Pool Area Radiation Monitor functions to assurepersonnel safety around the fuel storage pool. The FUNCTIONALITY ofthis radiation monitor ensures that the radiation levels are continuallymeasured when fuel is present in the pool or in the building and that thealarm is initiated when the radiation level exceeds the monitor setpoint.Unit 1 currently has an exemption to the requirements of 10 CFR 70.24,"Criticality Accident Requirements" for a criticality monitor. In order tomeet the requirements for the exemption to 10 CFR 70.24, the Unit 1 FuelStorage Pool Area Radiation Monitor is required FUNCTIONAL. AsUnit 2 no longer has an exemption to 10 CFR 7A.24, Unit 2 must meet therequirements of 10 CFR 50.68, "Criticality Accident Requirements." TheUnit 2 Fuel Storage Pool Area Radiation Monitor is requiredFUNCTIONAL to meet the criteria set forth in 10 CFR 50.68.Beaver Valley Unit 2B33.11 -1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3-3.12 Explosive Gas Monitoring lnstrumentationBASESExplosive Gas Monitoring InstrumentationB 3.3.12BACKGROUNDThis instrumentation includes provisions for monitoring (and controlling)the concentrations of potentially explosive gas mixtures in the waste gasholdup system. The OPERABILITY and use of this instrumentation isconsistent with the requirements of General Design Criteria 60, 63 and 64of Appendix A to 10 CFR Part 50.Beaver Valley Unit 2B 3.3.12 - 1LRM Revision 52 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.13 Containment Hydrogen AnalyzersBASESContainment Hydrogen AnalyzersB 3.3.13BACKGROUNDThis LR is provided to ensure that the containment hydrogen analyzersare FUNCTIONAL and capable of measuring the hydrogen concentrationin the containment atmosphere during a beyond design basis accident(BDBA). 10 CFR 50,44 for combustible gas control in containment wasrevised, effective October 16, 2003. The revised 10 CFR 50.44 no longerdefines a design-basis LOCA hydrogen release and eliminated therequirements for hydrogen control systems to mitigate such a release.With the elimination of the design-basis LOCA hydrogen release, thehydrogen analyzers are no longer required to mitigate a design-basisaccident and were removed from the Technical Specifications by LicenseAmendments 259 (Unit 1)and 1a2 (Unit2). However, the hydrogenanalyzers are required to diagnose the course of a BDBA and implementsevere accident management strategies for hydrogen control.Maintaining requirements within the LRM for a hydrogen monitoringsystem capable of diagnosing BDBAs (as described in BVPS Letter to theNRC L-04-012, dated January 28,2004) is an NRC commitment.Beaver Valley Unit 2B 3.3'13 - 1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.14 Control Room lsolation Radiation MonitorsBASESControl Room lsolation Radiation MonitorsB 3.3.14BACKGROUNDThe Control Room lsolation Radiation Monitors provide a backup functionto isolate the control room. The primary means for automatic controlroom isolation is the containment phase B isolation signal. TheOPERABILITY requirements for the containment phase B isolation signalare specified in the technical specifications. The FUNCTIONALITY ofthese radiation monitors ensure that the radiation level in the control roomis continually measured (in MODES 1, 2, 3, and 4) and that the automaticfunction of the monitors is initiated when the radiation level exceeds themonitor setpoint.Beaver Valley Unit 2B33.14-1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.15 Containment Area Radiation AlarmBASESContainment Area Radiation AlarmB 3.3.15BACKGROUNDThis LR only addresses the alarm function of the containment arearadiation monitors. The indication provided by these monitors isaddressed in the Post Accident Monitoring Instrumentation TechnicalSpecification. The Containment Area Radiation Alarm provides a warningof high radiation in the containment. The FUNCTIONALITY of theseradiation monitors ensures that the radiation level in the containment iscontinually measured (in MODES 1 ,2, 3, and 4) and that the alarm isinitiated when the radiation level exceeds the monitor setpoint.Beaver Valley Unit 2B33.15-1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.16 Accident Monitoring InstrumentationBASESAccident Monitoring lnstrumentationB 3.3.16BACKGROUNDThe OPERABILITY/FUNCTIONALITY of the accident monitoringinstrumentation ensures that sufficient information is available on selectedplant parameters to monitor and assess these variables during andfollowing an accident. This capability is consistent with therecommendations of Regulatory Guide 1.97, "lnstrumentation for Light-Water-Cooled Nuclear Plants to Assess Plant Conditions During andFollowing an Accident," December 1975 and NUREG-0578, "TMl-2Lessons Learned Task Force Status Report and Short-TermRecommendations."Beaver Valley Unit 2B3316-1LRM Revision 67 Licensing Requirements ManualB 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.1 Loop lsolation Valves - ShutdownBASESLoop lsolation Valves - ShutdownB 3.4.1BACKGROUNDLR 3.4.1 ensures that power is removed from isolated loop isolation valveoperators when closed to perform maintenance in MODES 5 or 6 toprevent an inadvertent loop startup.LR 3.4.1 is applicable whenever an RCS loop has been isolated inMODES 5 and 6 with fuel in the reactor vessel. LR 3.4.1 is not applicablewhen there is no fuel in the reactor vessel.An RCS loop is considered isolated in MODES 5 and 6 whenever the hotand cold leg isolation valves on one RCS loop are both in a fully closedposition at the same time. One isolation valve may be stroked for testingin MODES 5 and 6 and the loop will not be considered isolated wheneither the hot leg or cold leg loop isolation valve remains open.lf power is inadvertently restored to one or more loop isolation valveoperators, the potential exists for accidental isolation of a loop with asubsequent inadvertent startup of the isolated loop. The loop isolationvalves have motor operators. Therefore, these valves will maintain theirlast position when power is removed from the valve operator. With powerapplied to the valve operators, only administrative controls prevent thevalve from being operated. Although operating procedures make theoccurrence of this event unlikely, the prudent action is to remove powerfrom the loop isolation valve operators. The completion time of t hour toremove power from the loop isolation valve operators is sufficientconsrdering the complexity of the task.LRS 3.4.1.1 is performed at least once per 7 days to ensure that the RCSloop isolation valves have power removed from the loop isolation valveoperators. The frequency of 7 days which ensures that the power isremoved from loop isolation valve operators, is based on engineeringjudgment, and has proven to be acceptable. Operating experience hasshown that the failure rate is so low that the 7 day frequency is justified.Beaver Valley Unit 2B 3.4.1 - 1LRM Revision 52 Licensing Requirements ManualB 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.2 ChemistryBASESChemistryB 3.4.2BACKGROUNDThe limitations on Reactor Coolant System chemistry ensure thatcorrosion of the Reactor Coolant System is minimized and reduces thepotential for Reactor Coolant System leakage or failure due to stresscorrosion. Maintaining the chemistry within the Steady State Limitsprovides adequate corrosion protection to ensure the structural integrity ofthe Reactor Coolant System over the life of the plant. The associatedeffects of exceeding the oxygen, chloride and fluoride limits are time andtemperature dependent. Corrosion studies show that operation may becontinued with contaminant concentration levels in excess of the SteadyState Limits, up to the Transient Limits, for the specified limited timeintervals without having a significant effect on the structural integrity of theReactor Coolant System. The time interval permitting continuedoperation within the restrictions of the Transient Limits provides time fortaking corrective actions to restore the contaminant concentrations towithin the Steady State Limits.The surveillance requirements provide adequate assurance thatconcentrations in excess of the limits will be detected in sufficient time totake corrective action.Beaver Valley Unit 2B 3.4.2 - 1LRM Revision 52 Licensing Requi rements ManualB 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.3 PressurizerBASESPressurizerB 3.4.3BACKGROUNDThe limitations imposed on the pressurizer heatup and cooldown ratesand auxiliary spray water temperature differential are provided to assurethat the pressurizer is operated within the design criteria assumed for thefatigue analysis performed in accordance with the ASME Coderequirements.Beaver Valley Unit 2B 3.4.3LRM Revision 52 Licensing Requirements ManualB 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 DELETEDBeaver Valley Unit 2B 3.4.4 - 1LRM Revision 67 Licensing Requirements ManualB 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.5 Reactor Coolant System Head VentsBASESReactor Coolant System Head VentsB 3.4.5BACKGROUNDReactor Coolant System Vents are provided to exhaust noncondensiblegases and/or steam from the primary system that could inhibit naturalcirculation core cooling. The FUNCTIONALITY of at least one reactorcoolant system vent path from the reactor vessel head or the pressurizersteam space via the PORV's ensures the capability exists to perform thisfunction.The valve redundancy of the Reactor Coolant System Head vent pathsserves to minimize the probability of inadvertent or irreversible actuationwhile ensuring that a single failure of a vent valve, power supply or controlsystem does not prevent isolation of the vent path.The function, capabilities, and testing requirements of the ReactorCoolant System vent systems are consistent with the requirements ofItem ll. B. 1 of N U REG-0737 , "Clarification of TM I Action PlanRequirements," November 1980. These specifications, includingtimeframes for the action statements, were previously included in planttechnical specifications based on a "model" provided in Generic Letter 83-37, "NUREG-0737 Technical Specifications." RCS vents are not modeledin the plant-specific probabilistic safety assessment and are not creditedin the Chapter 15 accident analyses, but are a safety related means forproviding letdown to achieve cold shutdown and for alternate shutdowncapability.Beaver Valley Unit 2B34.5-1LRM Revision 67 Licensing Requirements ManualPressurizer Safety Valve Lift Involving Loop Seal or Water DischargeB 3.4.6B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.6 Pressurizer Safety Valve Lift Involving Loop Seal or Water DischargeBASESBACKGROUNDThe purpose of this LR is to provide assurance that the safety valves areproperly maintained. The LR requires the unit be removed from theMODES where the safety valves are required OPERABLE after valveoperation involving liquid discharge. This requirement is to ensure asafety valve that has discharged liquid is evaluated and repaired ifnecessary. Although valve operation with liquid discharge does notimmediately imply a safety valve is inoperable, the LR requirement is aprudent precaution that provides additional assurance, beyond theinservice testing and inspection requirements, that the valves areevaluated for operability after a liquid discharge.Beaver Valley Unit 2B 3.4.6LRM Revision 52 Licensing Requirements ManualB 3.6 CONTAINMENTB 3.6.1 Containment lsolation ValvesBASESContainment lsolation ValvesB 3.6.1BACKGROUNDThere are two types of 'administrative controls' applicable to theContainment lsolation Valves listed in Table 3.6.1-1 of this LicensingRequirements Manual (LRM). The administrative controls which applywhen any locked or sealed closed Containment lsolation Valves areopened or when a penetration flow path isolated to comply with TechnicalSpecification action requirements for an inoperable containment isolationvalve is unisolated are defined in the Technical Specification Bases 3.6.3.The administrative controls for Containment lsolation Valves which haveNote (1) shown in Table 3.6.1-1 of this LRM are the procedures thatgovern the operation of these valves.Note (1) was originally used for the several BVPS Unit 1 MOVs in theoriginal BVPS Unit 1 Technical Specifications and in Amendment No. 1 ofthe BV-1 Technical Specifications where it was justified to allow thespecified valves to be opened on an intermittent basis underadministrative controls. The NRC Safety Evaluation for BVPS Unit 1Amendment No. 1 described the function of these valves as "required tobe opened on an intermittent basis to perform essential operatingfunctions" in Modes 1-4. The term'administrative controls'was notexplicitly defined or described in either BVPS Unit 1 original TechnicalSpecifications nor Amendment 1 correspondence. lt has been inferredsince BVPS Unit 1 Amendment No. 1 that the'administrative controls'were these valves' normal/emergency procedures and the plant'snormal/emergency operating controls because the'administrativecontrols'were not describedidefined and the documented basis discussedtheir essential operating functions. When BVPS Unit2 was initiallylicensed, the Unit 2 Technical Specifications were modeled after theUnit 1 Technical Specifications. Note (1)used forvalves in Penetrations28,46,55C, 57C,87, BB, 92, 93, 978, 1058 in the original BVPS Unit 2Technical Specifications followed this same justification as used for ClVsusing Note (1) in the BVPS Unit 1 Technical Specifications.Subsequently the Unit 2 containment air lock valves had Note (1) addedsince their operation basis was described in the UFSAR (similar to theUnit 1 containment air lock valves). A review/revision of Table 3.6.1-1was completed in 1997 to ensure that the use of Note (1) was correctlyapplied throughout the Table in accordance with the above basis. Someprevious changes to the CIV Table had not always followed thisunderstanding because the literal wording seemed to also fit otherapplications. [Note (1) only applies to those valves specified in theBeaver Valley Unit 2B 3.6.1 - 1LRM Revision 52 Licensing Requirements ManualBASESContainment lsolation ValvesB 3.6.1BACKGROU N D (continued)original BV-2 Technical Specifications, with the addition of thecontainment air lock valves as described in the BV-2 UFSAR. Note (1)does not apply to ClVs which are operated pursuant to other definedadministrative controls such as for normally locked or sealed closedClVs.lAmendment No. 66 to the BV-2 Technical Specifications added criteria toTechnical Specification 314.6.1.1 and 3/4.6.3.1 allowing a locked orsealed closed CIV to be opened without declaring the CIV inoperable, inaccordance with Generic Letter 91-08. Locked or sealed closed ClVsmay only be opened, without entering the LCO, if the administrativecontrols defined in Technical Specification Bases 3.6.3 is followed, inaccordance with Technical Specification 3.6.3. [The explicitly defined'administrative controls'which allow opening of locked or sealed closedClVs are not the same 'administrative controls'for opening ClVs perNote ( 1 ).1Amendment No. 143 to the BV-2 Technical Specifications allowedpenetration flow paths isolated to comply with action requirements forinoperable containment isolation valves to be unisolated on anintermittent basis under administrative controls. The administrativecontrols to be used when unisolating these penetrations are also thosedefined in the Technical Specification Bases 3.6.3.ClVs with an automatic closure feature upon generation of a containmentisolation signal or which meet General Design Criteria 57 may be openedwithout entering the Technical Specification only if the valve remainsOPERABLE.Beaver Valley Unit 2B 3.6.1 - 2LRM Revision 52 Licensing Requirements ManualB 3.6 CONTAINMENTB 3.6.2 Containment SumpBASESContainment SumpB 3.6.2BACKGROUNDThe purpose of this LR is to assure good housekeeping practice isapplied when maintenance or inspections are performed withincontainment. The requirements of this LR provide assurance that debrissuch as rags, trash, and clothing (i.e., items with the potential to clog thecontainment sump following a Loss of Coolant Accident (LOCA)) areremoved from the containment building. The presence of debris in thecontainment sump following a LOCA could interfere with the operation ofthe Emergency Core Cooling System pumps needed to mitigate theLOCA. The requirements of this LR include the performance of a visualinspection following containment entries for maintenance or inspection.Beaver Valley Unit 2B 3.6.2 - ILRM Revision 52 Licensing Requirements ManualB 3.7 PLANT SYSTEMSB 3.7 .1 Steam Generator Pressure/Temperature LimitationBASESSteam Gen erator Pressu relTem perature LimitationB 3.7.1BACKGROUNDLicensing Requirement 3.7.1 is applicable to each steam generatorindividually. The Applicability specifies the threshold conditions duringwhich a steam generator could be pressurized such that the maximumallowable fracture toughness stress limit could be exceeded.The limitation on steam generator pressure and temperature ensures thatthe pressure induced stresses in the steam generators do not exceed themaximum allowable fracture toughness stress limits. The limitations of70'F and 200 psig are based on a steam generator average impactvalues taken at 10'F and are sufficient to prevent brittle fracture.The applicability is limited to whenever the temperature of the primary orsecondary coolant of the associated steam generator is s 70"F and theprimary or secondary systems are capable of being pressurized. For thepurpose of this LR, the primary system is considered no longer capable ofbeing pressurized following depressurization to atmospheric conditionswith a vent path established and all flowpaths to the generator have beenisolated. The secondary side is considered no longer capable of beingpressurized following depressurization to atmospheric conditions and avent path via an open atmospheric steam dump valve/residual heatrelease valve and associated isolation valve, or removal of a steamgenerator manway or safety valve.Beaver Valley Unit 2B 3.7.1 - 1LRM Revision 55 Licensing Requirements ManualB 3.7 PLANT SYSTEMSB 3.7.2 Flood ProtectionBASESFlood ProtectionB 3.7.2BACKGROUNDThe limitation on flood level ensures that facility operation will beterminated in the event of flood conditions. The limit of elevation 695Mean Sea Level was selected on an arbitrary basis as an appropriateflood level at which to evaluate further plant operation and initiate floodprotection measures for safety related equipment. The LR limit on OhioRiver elevation of 700 Mean Sea Level (actual or projected) ensures thatappropriate actions are initiated per LR 3.0.3 prior to reaching an OhioRiver elevation of 705 Mean Sea Level. The Ohio River elevation of705 Mean Sea Level is the standard project flood design level for plantoperation.Ohio River elevation at the intake structure can be obtained from a levelinstrument at the intake structure, the Unit 1 plant computer, the elevationscale on the outside of the intake structure, or by using the MontgomeryLock and Dam tailwater level. The National Weather Service (NWS)website contains an Ohio River at Montgomery Lock and Dam trend ofdownstream pool level referred to as "tailwater." Tailwater level is theheight of the river above a reference elevation (gage zero). TheMontgomery Lock and Dam tailwater reference elevation is 652.5 feet.The elevation scale on the outside of the intake structure is approximatelyequal to the tailwater level plus the reference elevation (652.5 feet). TheMontgomery Lock and Dam tailwater level may also be obtained bycontacting the US Army Corps of Engineers or the Montgomery Lock andDam. Telephone numbers may be obtained from the EmergencyNotification Call List in the Emergency Preparedness implementingprocedures.Beaver Valley Unit 2B 3.7.2 - 1LRM Revision 78 Licensing Requirements ManualB 3.7 PLANT SYSTEMSB 3.7.3 Sealed Source ContaminationBASESSealed Source ContaminationB 3.7.3BACKGROUNDThe limitations on sealed source contamination ensure that the total bodyor individual organ irradiation does not exceed allowable limits in theevent of ingestion or inhalation of the source material. The limitations onremovable contamination for sources requiring leak testing, includingalpha emitters, is based on 10 CFR 70.39(c) limits for plutonium.Leakage of sources excluded from the requirements of this LR representless than one maximum permissible body burden for total body irradiationif the source material is inhaled or ingested.Sealed sources are classified into three groups according to their use,with surveillance requirements commensurate with the probability ofdamage to a source in that group. Those sources which are frequentlyhandled are required to be tested more often than those which are not.Sealed sources which are continuously enclosed within a shieldedmechanism (i.e., sealed sources within radiation monitoring or boronmeasuring devices) are considered to be stored and need not be testedunless they are removed from the shielded mechanism.Beaver Valley Unit 2B3.73-1LRM Revision 52 Licensing Requirements ManualB 3.7 PLANT SYSTEMSB 3.7.4 SnubbersBASESBACKGROUNDAll snubbers are required FUNCTIONAL to ensure that the structuralintegrity of the reactor coolant system and all other safety-related systemsis maintained during and following a seismic or other similar eventinitiating dynamic loads. Snubbers excluded from this inspection programare those installed on nonsafety-related systems and then only if theirfailure or failure of the system on which they are installed, would have noadverse effect on any safety-related system.Snubbers are to be demonstrated and maintained FUNCTIONAL throughperiodic visual examination, functional testing and service life monitoring.All three aspects are now to be performed in accordance with therequirements set forth in the ASME OM Code 20A1 Edition up to andincluding the 2003 Addenda, Subsection ISTD, "Preservice and lnserviceExamination and Testing of Dynamic Restraints (Snubbers) in Light-Water Reactor Power Plants," with additional visual examinationrequirements identified in the ASME BPV Code, Section Xl, paragraphlW A-2213, "Visual Examination VT-3."During the 1980's, snubber surveillance requirements were identified inthree documents: Section Xl of the ASME Boiler and Pressure Vessel(B&PV) Code, a plant's Technical Specifications and Part 4 of the ASMEOperation and Maintenance (OM) Code. The three documents weresimilar in purpose and concept - demonstrate and ensure snubberfunctional integrity through periodic visual examination, sample testingand service life monitoring. However, they varied enough in details tocause much confusion among utilities as to the proper requirements andcourse of action often resulting in redundant efforts and sometimesmissed requirements.Seeing a need for better clarity and standardization, industry leadersinitiated an effort to consolidate the surveillance requirements of the threedocuments into one comprehensive, single source document. The resultof this effort was the publication in 1990 of the ASME OM Code,Subsection ISTD, "Preservice and lnservice Examination and Testing ofDynamic Restraints (Snubbers) in Light-Water Reactor Nuclear PowerPlants." ln 1999, the NRC endorsed the use of ISTD requirements in lieuof the snubber surveillance requirements identified in Section Xl or aplant's Technical Specifications or licensee controlled documents[10 CFR 50.55a(bX3Xv)]Beaver Valley Unit 2B 3.7.4 - 1LRM Revision 67 Licensing Requirements ManualBASESBACKGROU N D (continued)When a snubber is found Nonfunctional, an engineering evaluation isperformed, in addition to the determination of the snubber mode of failure,in order to determine if any safety-related component or system has beenadversely affected by the Nonfunctionality of the snubber. Theengineering evaluation shall determine whether or not the snubber modeof failure has imparted a significant effect or degradation on the supportedcomponent or system.LCO 3.0.8 specifies two Completion Times to restore a Nonfunctionalsnubber, depending on the type of system being supported. Therequirements are specified in LCO 3.0.8 and its Bases. Table 3.7.4-1provides information that ensures the Completion Times specified byLCO 3.0.8 are assigned to the appropriate snubber. Table 3.7.4-1identifies which snubbers provide support to safety related piping and theappropriate Completion Time of 12 or 72 hours. The table contains theidentification of the snubber, its system boundary, if LCO 3.0.8 applies,and the applicable Completion Time to restore the snubber toFUNCTIONAL. An entry of "No" in the LCO 3.0.8 Applicability columnmeans that the supported system's Completion Time applies.LCO 3.0.8 is not applicable to snubbers whose function is to arrest awater hammer event. The LCO for the system is applicable for waterhammer snubbers. Table B 3.7 .4-1 identifies water hammer snubbersand provides the basis for the Completion Time assignment.Tables 3.7.4-1 and B 3.7.4-1 are aids that eliminate the need to performan immediate. event driven assessment when a snubber is Nonfunctional.Beaver Valley Unit 2B 3.7.4 - 2LRM Revision 67 gnOf-* c'j:lmc(/)atUamfcaca)E11'l.=foq)t_()')c,acc).oJ$roc.9o't0)ttrJc{)In\

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LLl6q)Iaatb s/)gq,to)3E"*:XrL lll6q)=aat) s/,3q)to)o=r*:XrL LtI6oIU)aE.-} s/,g6tO)3F:*:Xr.L Lll6q)I@U)t)otrbt o)3Fof=xr.L Lu$Q)Ta@E.>U)trbtcDo=n-C-(J:XLl.rloq)rU)(f)t)s,9a)tr g)3ho5=XrL ltl$o-(/)(f)t) f/,9q,t O::Fof=XrL LU$0)Ia@tXotrbto)3f:*:XIL tU$q)-U)CNx.iP=G)tc')3f;ofi:XtL Lllt-octt-oGI3ozozozozozozozozozozozoctooJG'ooltNIt-(LaU)TLIa=U)NmONt-o_a(f)o_Ia=U)NrF-t\o_aQo_la=@NNNF-(Laao_Ia=CNNcoNf-N(Laa(Lt@=aNcoNf-o_aa(LIa=ac!mc9N F-o_cf)ao_Ia=aN$f-N0_aao-]a=U)c{Ocr)@(LCNU)LIa=@NNc/)@(Lcf)afLIa=aNcoNcr)ooTLU)(f)o-Ia=aNtIJtrnZSA.*- Fol-llCrt JrO-o>Prodo- (r)504$ LlJNm^:0t, ]tfr7w cJ)Jrvr- tLIaU)m Licensing Requirements ManualB 3.7 PLANT SYSTEMSB 3.7.5 Standby Service Water System (SWE)BASESStandby Service Water System (SWE)B 3.7.5BACKGROUNDThe FUNCTIONALITY of the SWE ensures that sufficient cooling capacityis available to bring the reactor to a cold shutdown condition in the eventthat a barge explosion at the station's intake structure or any otherextremely remote event would render all of the normal Service WaterSystem (SWS) supply pumps Nonfunctional. The scenario of a postulatedgasoline barge impact with the intake structure and coincident explosiondisabling the SWS is a low probability event. Nonetheless, the SWEprovides defense in-depth in assuring shutdown cooling capability. Therequirement to operate the SWE is not coincident with a postulatedDesign Basis Accident, but only for the postulated gasoline barge impactevent.Although the SWE is a non-safety system which is not required to meetsingle active failure criteria, the system is designed with redundant pumpsand valves on a header to accommodate a single active failure on start-up. This design criteria provides a defense in-depth in order to ensurethe system can adequately mitigate the consequences of the postulatedevent. An SWE pump can be manually started on the emergency busduring loss of offsite power afier the diesel loading sequence is complete.With no loss of power signal present, the SWE is automatically startedupon receipt of low service water header pressure signal. This feature isprovided to prevent inadvertent plant trip on loss of running service waterpump and is not required for the design basis event. lf there is a delay instarting the SWE, the auxiliary feedwater system is available to removereactor core decay heat for a short term period.The requirements for subsystem FUNCTIONALITY are similar to those ofthe SWS except that one subsystem is required to be FUNCTIONAL inthe MODES noted. The LR reflects the low risk of the postulated eventcompared to more stringent requirements associated with safety relatedsystems. The ACTION statement takes into account the low probability ofboth trains of SWS being disabled as a result of the postulated scenariocoincident with one of the SWE subsystems being FUNCTIONAL.The STAGGERED TEST BASIS for LRS 3.7.5.2 ensures that each SWEpump is periodically full flow tested.Beaver Valley Unit 2B 3.7.5 - 1LRM Revision 69 Licensing Requirements ManualB 3.7 PLANT SYSTEMSB 3.7.6 Explosive Gas MixtureBASESExplosive Gas MixtureB 3.7.6BACKGROUNDThis LR is provided to ensure that the concentration of potentiallyexplosive gas mixtures contained in the waste gas holdup system ismaintained below the flammability limits of hydrogen and oxygen.lsolation of the affected tank for purposes of purging andlor dischargepermits the flammable gas concentrations of the tank to be reducedbelow the lower explosive limit in a hydrogen rich system. Maintainingthe concentration of hydrogen and oxygen below their flammability limitsprovides assurance that the releases of radioactive materials will becontrolled in conformance with the requirements of General DesignCriterion 60 of Appendix A to 10 CFR Part 50.Beaver Valley Unit 2B37.6-1LRM Revision 52 Licensing Requirements ManualSupplemental Leak Collection and Release System (SLCRS)B 3.7.7B 3.7 PLANT SYSTEMSSupplemental Leak Collection and Release System (SLCRS)B 3.7.7BASESBACKGROUNDThe FUNCTIONALITY of the SLCRS provides for the filtering ofpostulated radioactive effluents resulting from leakage of loss of coolantaccident (LOCA) activity from systems outside of the ReactorContainment building, such as Engineered Safeguards Features (ESF)equipment, prior to their release to the environment. This system alsocollects potential leakage of LOCA activity from the Reactor Containmentbuilding penetrations into the contiguous areas ventilated by the SLCRSexcept for the Emergency Air Lock. No credit for SLCRS operation wastaken in the DBA LOCA analysis for collection and filtration of ReactorContainment building leakage and ESF leakage effluents even though anunquantifiable amount of contiguous area penetration leakage and ESFleakage effluents would in fact be coflected and filtered.Beaver Valley Unit 2B 3.7.7 - 1LRM Revision 67 Licensing Requirements Manual125V D.C. Battery Banks Maintenance RequirementsB 3.8.1B 3.8 ELECTRICAL POWER SYSTEMSB 3.8.1 125V D.C. Battery Banks Maintenance RequirementsBASESBACKGROUNDThe provisions of this LR require periodical maintenance/inspections tobe performed on the specified 125V DC battery banks. The LR includesrequirements for more routine battery maintenance than required in theTechnical Specifications. As such, this LR supplements the requirementsof the Technical Specifications to assure the performance of routinebattery maintenance.Beaver Valley Unit 2B 3.8.1 - 1LRM Revision 52 Licensing Requirements ManualB 3.8 ELECTRICAL POWER SYSTEMSB 3.8.2 Emergency DG 2000 Hour Rating LimitBASESEmergency DG 2000 Hour Rating LimitB 3.8.2BACKGROUNDThe provisions of this LR require a periodical verification that theEmergency Diesel Generator (EDG) 2000 hour rating limit continues to bemet. The verification required by this LR supplements the other EDGrequirements in the Technical Specification.Beaver Valley Unit 2B 3.8.2 - 1LRM Revision 52 Licensing Requirements ManualMain Fuel Oil Storage Tank Maintenance RequirementsB 3.8.3B 3.8 ELECTRICAL POWER SYSTEMSB 3.8.3 Main Fuel Oil Storage Tank Maintenance RequirementsBASESBACKGROUNDThe provisions of this LR require a periodic draining and cleaning of eachEmergency Diesel Generator (EDG) main fuel oil storage tank. Thepurpose of this LR is to assure a reliable supply of clean emergencydiesel generator (EDG) fuel oil is available. This LR supplements theEDG Technical Specification requirements and provides additionalassurance the EDG fuel oil supply is maintained with an acceptable levelof sediment that will not adversely affect EDG operation.Beaver Valley Unit 2B 3.8.3 - 1LRM Revision 52 Licensing Requirements ManualCrane Travel - Spent Fuel Storage Pool BuildingB 3.9.1B 3.9 REFUELING OPERATIONSB 3.9.1 Crane Travel - Spent Fuel Storage Pool BuildingBASESBACKGROUNDThe restriction on movement of loads in excess of the normal weight of afuel assembly and control rod assembly and associated handling toolover other fuel assemblies ensures that no more than the contents ofthose fuel assembly rods assumed in the fuel handling accident describedin Chapter 15 of the BVPS Unit 2 UFSAR will be ruptured. Thisassumption is consistent with the activity release assumed in the accidentanalyses.The frequency of LRS 3.9.1.1 FUNCTIONALITY demonstration is basedon the inspection frequency specified in ANSI 830.2-1976, paragraph2-2.1 .4.a for a crane other than a standby crane that has been idle for aperiod of one month or more, but less than one year.Beaver Valley Unit 2B3.9 1-1LRM Revision 67 Licensing Requirements ManualB 3.9 REFUELING OPERATIONSB 3.9.2 Manipulator CraneBASESManipulator CraneB 3.9.2BACKGROUNDThe FUNCTIONALITY requirements for the manipulator cranes ensurethat: 1) manipulator cranes will be used for movement of control rods andfuel assemblies; 2) each crane has sufficient load capacity to lift a controlrod or fuel assembly; and 3) the core internals and pressure vessef areprotected from excessive lifting force in the event they are inadvertentlyengaged during lifting operations.Beaver Valley Unit 2B 3.9.2 - 1LRM Revision 67 Licensing Requirements ManualB 3.9 REFUELING OPERATIONSB 3.9.3 Decay TimeBASESDecay TimeB 3.9.3BACKGROUNDThe minimum requirement for reactor subcriticality prior to movement ofirradiated fuel assemblies in the reactor vessel ensures that sufficienttime has elapsed to allow the radioactive decay of the short lived fissionproducts. This decay time is consistent with the assumptions used in theradiological accident analyses.Also, in order to meet the thermal-hydraulic design calculationassumptions for the fuel storage pool, movement of irradiated fuelassemblies from the reactor vessel to the fuel pool requires a minimumsubcritical decay time of 100 hours. This requirement is based on coolingwater inlet temperature to the fuel storage pool heat exchanger asdescribed in a BVPS letter to the NRC (L-01-113), dated October 29,zAU. After 100 hours, in order to maintain the fuel pool heat load withinthe assumptions of the analysis, irradiated fuel assembly movement fromthe vessel to the fuel pool is limited to a rate equivalent to six assembliesper hour.Beaver Valley Unit 2B 3.9.3 - 1LRM Revision 70}}