ML14339A451

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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:
References
L-14-360
Download: ML14339A451 (256)
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{{#Wiki_filter:Unit 2 Licensing Requirements Manual (LRM) Quick Index 1.0 USE AND APPLICATION 1.0-1 1.0.1 General Description 1.0-1 1.0.2 LRM Revisions 1.0-2 1.1 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 3.0.1 3.0 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 3.1.3-1 3.1.4 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 Test Exceptions 3.1.11-13.3 INSTRUMENTATION 3.3.1.13.3.1 Reactor Trip System Instrumentation Response Times 3.3.1-13.3.2 Engineered Safety Features Response Times 3.3.2-13.3.3 Meteorological Monitoring lnstrumentation 3.3.3-13.3.4 Axial Flux Difference (AFD) Monitor Alarm 3.3.4-1 3.3.5 Quadrant Power Tilt Ratio (OPTR) Monitor Alarm 3.3.5-13.3.6 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 Setpoints 3.3.10-13.3.'11 Fuel Storage Pool Area Radiation Monitor 3.3.11-13.3.12 Explosive Gas Monitoring Instrumentation 3.3.12-1 3.3.13 Containment Hydrogen Analyzers 3.3.13-1 3.3.14 Control Room lsolation Rad Monitors 3.3.14-1 3.3.15 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 3.6.1-1 3.6.2 Containment Sump 3.6.2-1 3.7 PLANT SYSTEMS 3.7.1.1 3].1 Steam Generator Pff Limitation 3.7.1-1 3.7.2 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 3.7.6-1 3.7.7 SLCRS 3.7.7-1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1.1 3.8.1 125V D.C. Battery Banks Maint Rqmnts 3.8.1-1 3.8.2 EDG 2000 Hour Rating Limit 3.8.2-1 3.8.3 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 3.9.1-1 3.9.2 Manipulator Crane 3.9.2-13.9.3 Decay Time 3.9.3-1 5.0 ADMINISTRATIVE CONTROLS 5.1.15.'1 Core Operating Limits Report 5.1-1 5.2 Pressure and Temperature Limits Report 5.2-i 5.3 Procedure Review and Approval 5.3-15.4 Record Retention 5.4-1 BASESB 3.0 LR Applicability B 3.0-1 B 3.0 LRS Applicability B 3.0-5 B 3.1.1 - B 3.1.8 Boration Systems B 3.1.1-1 B 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 3.3.4-1 B 3.3.5 QPTR Monitor Alarm B 3.3.5-1B 3.3.6 Seismic Monitoring Instrumentation B 3.3.6-1 B 3.3.7 Movable lncore Detectors B 3.3.7-1 B 3.3.8 Leading Edge Flow Meter B 3.3.8-1 B 3.3.9 Turbine Overspeed Protection B 3.3.9-1B 3.3.11 Fuel Strg Pool Area Rad Monitor B 3.3.11-1 B 3.3.12 Explosive Gas Mntrng lnstrumtn 83.3.12-1 B 3.3.13 Containment Hydrogen Analyzers B 3.3.13-1B 3.3.14 Control Room Area Rad. Monitors B 3.3.14-1 B 3.3.15 Containment Area Radiation Alarm B 3.3.15-1B 3.3.16 Accident Monitoring lnstrumentation B 3.3.16-1 B 3.4.1 Loop lsolation Valves - Shutdown B 3.4.1-1 B 3.4.2 Chemistry B 3.4.2-1B 3.4.3 Pressurizer B 3.4.3-1B 3.4.4 DELETED B 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 3.6.1-1 B 3.6.2 Containment Sump B 3.6.2-1 B 3.7.1 SG Pressure/Temperature Limitation B 3.7.1-1 B 3.7.2 Flood Protection B 3.7.2-1 B 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 3.7.5-1 B 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 3.8.1-1 B 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 3.8.3-1 B 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 3.9.3-1 Revision 1 BVPS.2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision NumberLRM Request Number Pages lssued lmplementation Date 81 14-099 3.3.16-1 3.3.16-2 3.3.16-3 5t9114 BVPS-2LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request NumberPages lssued lmplementation Date 79 14-071 5.2-i 5.2-1 5.2-2 5.2-3 5.2-4 5.2-5 5.2-6 5.2-7 5.2-B 5.2-9 5.2-10 5.2-11 5.2-12 5,2-13 5.2-14 5.2-15 5.2-16 5.2-17 5.2-18 5.2-19 5.2-20 5.2-21 5.2-22 5.2-23 5.2-24 5.2-25 5.2-26 5.2-27 5.2-28 4t18t14 BO 14-016 5.1-1 5.1 -2 5.1-3 5.1-4 5.1-5 5.1-6 5.1-7 5.1-8 5.1-9 5.1-10 5.1-1 1 5.1-12 5.1-1 3 5.1-14 512114 BVPS.2 LICENSING REQUIREMENTS MANUAL REVISION STATUSRevision NumberLRM Request NumberPages lssued lmplementation Date 77 13-125B 3.7.2-1 9125113 78 13-204 13-172B 3.7.2-1 5.2-)5.2-1 5.2-2 5.2-3 5.2-4 5.2-5 5.2-6 5.2-7 5.2-8 5.2-9 5.2-10 5.2-11 5.2-12 5.2-13 5.2-14 5.2-15 5.2-16 5.2-17 5.2-18 5.2-19 5.2-20 5.2-21 5.2-22 5.2-23 5.2-24 5.2-25 5.2-26 5.2-27 5.2-28 1216113 See next page for Revision

79.

BVPS.2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision NumberLRM Request NumberPages lssued lmplementation Date 74 12-176 5.1-1 5.1-2 5.1-3 5.1-4 5.1-5 5.1-6 5.1-7 5.1-8 5.1-9 5.1-10 5.1-11 5.1-12 5.1-13 5.1-14 10t8t12 75 12-264B 3.3.8-2 3t15t13 76 13-041 13-041 13-041 13-041 13-041 13-041 13-04113-041 & 13-084 13-041 13-041 13-041 13-041' 13-041 13-041 13-041 13-041 13-041 13-041 13-041 13-041 13-041 13-04113-041 & 13-084 13-041 13-041 13-041 13-041 & 13-084 13-041 13-041 & 13-084 5.2-a 5.2-1 5.2-2 5.2-3 5.2-4 5.2-5 5.2-6 5.2-7 5.2-8 5.2-9 5.2-10 5.2-11 5.2-12 5.2-13 5.2-14 5.2-15 5.2-16 5.2-17 5.2-18 5.2-19 5.2-20 5.2-21 5.2-22 5.2-23 5.2-24 5.2-25 5.2-26 5.2-27 5.2-28 5t24t13 BVPS.2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision NumberLRM Request Number Pages lssued lmplementation Date 67 (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 3.9.2-1 12t22t14 68 11-002 11-011 3.4.2-2 5.1-1 5.1-2 5.1-3 5.1-4 5.1-5 5.1-6 5.1-7 5.1-8 5.1-9 5.1-10 5.1-11 5.1-12 5.1-13 5.1-14 3t18t11 69 11-005 3.7.5-1 B 3.7.5-1 3t31t11 70 11-074B 3.9.3-1 6t24t11 71 11-101 3.3.9-2 7t1t11 72 12-043 5.2-4 3t 16t 12 73 12-090 5.1-12 5.1-13 518112 BVPS-2LICENSING REQUIREMENTS MANUALREVISION STATUS Revision NumberLRM Request NumberPages lssued lmplementation Date 67 (continued) 10-069 3.3.9-1 3.3.11-1 3.3.13-1 3.3.14-1 3.3.15-1 3.3.16-1 3.4.2-1 3.4.4-1 3.4.5-1 3.4.5-2 3.4.6-1 3.7.2-1 3.7.4-1 3.7.4-2 3.7.5-1 3.7.7-1 3.7.7-2 3.9.1-1 3.9.2-1 3.9.2-2 B-i B-iiB 3.0-1 B 3.0-2B 3.0-3B 3.0-4B 3.0-5B 3.0-6 B 3.0-7B 3.0-8B 3.0-9 B 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 3.3.16-1 12t22t10 BVPS.2LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision NumberLRM Request Number Pages lssued lmplementation Date 66 09-01909-1 25 3.6.1-14 5.1-1 5.1-2 5.1-3 5.1-4 5.1-5 5.1-6 5.1-7 5.1-8 5.1-9 5.1-10 5.1-11 5.1-12 5.1-13 5.1-14 10t29t49 67 10-069 TOC page i TOC page ii 1.1-1 3.0-1 3.0-3 3.1.1-1 3.1.1-2 3.1.2-1 3.1.2-2 3.1.3-1 3.1.3-2 3.1.4-1 3.1.4-2 3.1.5-1 3.1.6-1 3.1.7-1 3.1.7-2 3.1.8-1 3.1.8-2 3.1.9-1 3.1.11-1 3.1.11-2 3.3.3-1 3.3.4-1 3.3.5-1 3.3.6-1 3.3.6-2 3.3.7-1 3.3.8-1 3.3.8-2 12t22110 BVPS-2LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision NumberLRM Request NumberPages lssued lmplementation Date 62 07 -120 08-1 07 3.3.14-1 5.2-l 5.2-1 5.2-2 5.2-3 5.2-4 5.2-5 5.2-6 5.2-7 5.2-B 5.2-9 5.2-10 5.2-11 5.2-12 5.2-13 5.2-14 5.2-15 5.2-16 5.2-17 5.2-18 5.2-19 5.2-20 5.2-21 5.2-22 5.2-23 5.2-24 5.2-25 5.2-26 5.2-27 5,2-28 10t9t08 63 09-018 09-005 3.3.9-2 3.8.1-14t27 tAg 64 09-097 5.1-11 5.1-12 5.1-13 8t6/09 65 08-18708-1 65 3.3.10-33.6.1-1 5 3.6.1-17 10122109 BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision NumberLRM Request Number Pages lssued lmplementation Date 55 07-107 07-175 07 -192 08-009 3.1.3-1 3.1.5-1 3.1.6-1 5.2-3 3.1.3-2B 3.7.1-1 a2ua8 56 07-018 08-045 08-021 08-037 1.1-1 3.3.2-3 3.3.10-4 3.3.10-5 5.1-1 5.1-2 5.1-3 5.1-4 5.1-5 5.1-6 5.1-7 5.1-B 5.1-9 5.1-10 5.1-11 5.1-12 5.1-13 5.1-14 4t24t08 57 08-065 3.1.11-1 5t2ta8 58 08-090 B 3.3.8-1 u4rcg 59 08-121 3.3.9-2 g 11 ta8 60 08-151 3.3.9-2 9/18/08 6108-1 58 3.3.9-2 9t24108 BVPS.2LICENSING REQUIREMENTS MANUALREVISION STATUS Revision NumberLRM Request Number Pages lssued lmplementation Date All previous Revision Numbers All previous LRM Request NumbersAll LRM pages inold formatPrior to 612A20AT 52 2-079 07 -046All LRM pages inlmproved Technical Specification format 3.0-1 6t23t2AO7 53 07 -097 2-074 3.3.14-2 3.7.4-1 3.7.4-2 B 3.7.4-1 B 3.7.4-2 9t18t2047 54 07 -122 3.7.4-1 3.7.4-3 3.7 .4-4 3.7.4-5 3.7.4-6 3.7.4-7 3.7.4-8 3.7.4-9 3.7.4-10 3.7.4-11 3.7 .4-12 3.7.4-13 3.7 .4-14 B 3.7.4-2B 3.7.4-3 B 3.7.4-4B 3.7.4-5 B 3.7.4-6B 3.7.4-7 B 3.7 .4-8B 3.7.4-9B 3.7.4-10 B 3.7 .4-11 B 3.7.4-12 B 3.7.4-13B 3.7.4-14 1Alnl2007 LICENSING REQUIREMENTS MANUAL TABLE OF CONTENTSPage No.1.0 1.0.11 .0.2 1.1 1.2 1.3 1.4 3.0 3.0 3.3 3.3.1 3.3.2 3.3.3 3.3.4 3.3.5 3.3.6 3.3.7 3.3.8 3.3.9 3.3.10 3.3.11 3.3.12 3.3.13 3.3.1 43 3.15 3.3.16USE AND APPLICATIONGeneral Description... .... 1.0-1 LRM Revisions..... 1.4-2 Definitions...... .1.1-1 Logical Connectors..... ....1.2-1 Completion Times ..... ..... 1.3-1 Frequency..... 1.4-13.1 REACTIVITY CONTROL SYSTEMS 3.1 .1 Boration Flow Paths - Shutdown .. ..3.1.1-1 3.1 .2 Boration Flow Paths - Operating ... .3.1.2-13.1 .3 Charging Pump - Shutdown .. . 3.1.3-1 3.1.4 Charging Pumps - Operating.... ......3.1.4-1

3. 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... .... 3.1.8-1 3.1.9 Rod Position lndication System - Shutdown .. 3.1.9-1 3.1.10 BoronDilution .3.1.10-13.1 .1 1 Rod Position lndication System - Shutdown Test Exceptions.... .... 3.1.11-1 LICENSING REQUIREMENT SURVEILLANCE (LRS) APPLICABILITY Fuel Storage Pool Area Radiation Monitor.. 3.0-1 3.0-3 3.3.10,-1 3.3.1 1 -1 INSTRU MENTATIONReactor Trip System Instrumentation Response Times .3.3.1-1 Engineered Safety Features Response Times. ......3.3.2-1 Meteorological Monitoring Instrumentation ... 3.3.3-1Axial Flux Difference (AFD) Monitor Alarm .... 3.3.4-1 Quadrant Power Tilt Ratio (OPTR) Monitor Alarm . 3.3.5-1Seismic Monitoring Instrumentation ....... 3.3.6-1 Movable lncore Detectors .. .3.3.7-1 Leading Edge Flow Meter ...... 3.3.8-1 Turbine Overspeed Protection ....... 3.3.9-1 RTS, ESFAS, and Loss of Power Trip Setpoints Explosive 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.. 3.4.1-1 3.4.2 Chemistry..... ...... j. ..3.4.2-1 3.4.3 Pressurizer.... . 3.4.3-13.4.4 DELETED..... ..3.4.4-1 Beaver Valley Unit 2LRM Revision 67 LICENSING REQUIREMENTS MANUAL TABLE OF CONTENTS Page No.3.4 REACTOR COOLANT SYSTEM (RCS) (continued)3.4.5 RCS Head Vents ....3.4.5-1 3.4.6 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 CONTAINMENT 3.6.1 Containment lsolation Valves... ......3.6.1-1 3.6.2 Containment Sump 3.6.2-13.7 PLANT SYSTEMS 3.7 .1 Steam Generator Pressure/Temperature Limitation ......3.7.1-1 3.7.2 Flood Protection ..... 3.7.2-13.7 .3 Sealed Source Contamination 3.7 .3-1 3.7 .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 SYSTEMS 3.8.1 125V D.C. Battery Banks Maintenance Requirements 3.8.2 Emergency Diesel Generator (EDG) 2000 Hour Rating Limit3.8.3 Main Fuel Oil Storage Tank Maintenance Requirements3.9 REFUELING OPERATIONS 3.9.1 Crane Travel - Spent Fuel Storage Pool Building3.9.2 Manipulator Crane 3.9.3 Decay Time 3.8.1-1 3.8.2-1 3.8.3-1 3.9.1-1 3.9.2-1 3.9.3-15.0 ADMINISTRATIVE CONTROLS 5.1 Core Operating Limits Report. 5.1-15.2 Pressure and Temperature Limits Report ......5.2-i 5.3 Procedure Review and Approval. ...5.3-1 5.4 Record Retention ...5.4-1 Beaver Valley Unit 2LRM Revision 67 Licensing Requirements ManualGeneral Description 1.0.1 1.0 USE AND APPLICATION 1.0.1 General Description Changes to the technical specifications may result in relocating various technical specification items to the UFSAR. This maintains control of the relocated items and allows changing these requirements in accordance with the provisions of 10 CFR 50.59 without the need to process a license amendment request. ltems relocated from the technical specifications and other applicable licensing requirements associated with the operation of structures, systems and components are to be included in Section 16A of the UFSAR and are maintained in the LICENSING REQUIREMENTS MANUAL (LRM). Because the information removed from the Technical 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 information incorporated by reference, the information must be publicly available and is subject to the update 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 the Technical 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 UFSAR NONE Beaver Valley Unit 2 1.0-1 LRM Revision 52 Licensing Requirements Manual LRM Revisions 1.4.2 1.0 USE AND APPLICATION 1.0.2 LRM Revisions Modifications to the content of the LRM (including information such as the tables and reports referenced by the Technical Specifications) shall be processed in accordance with the provisions of 10 CFR 50.59 as set forth in administrative procedures.Beaver Valley Unit 2 1.0-2 LRM Revision 52 Licensing Requirements Manual USE AND APPLICATION Definitions 1.0 1.1 Definitions 1.1 a)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 the LRM, defined terms are shown in all capital letters, consistent with their use in the Technical Specifications. Definitions specific to the LRM are defined as follows: Term Definition- NOTE -Some components inthe LRM have both LRM and TS functions and requirements. Such components are required by the LRMto be FUNCTIONAL,and are also required by TSs to beOPERABLE. lnthese cases, if acomponent isOPERABLE, it will be functional; however,if it is FUNCTIONAL.it may not be OPERABLE.FUNCTIONAL -FUNCTIONALlTY A structure, system or component (SSC), shall be FUNCTIONAL 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 other specified functions that have a necessary support function.POWER, as defined in Technical SpecificationThe value of RATED THERMALSection 1.1, is 2900 MWt. b)Beaver Valley Unit 2 1.1 -1 LRM Revision 67 Licensing Requirements ManualLogical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors The 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 2 1.2-1 LRM Revision 52 Licensing Requirements Manual Completion Times 1.3 1.0 1.3USE AND APPLICATION Completion Times The explanation of the use of Action Completion Times contained in Technical SpecificationSection 1.3, "Completion Times" applies to the requirements contained in the LRM. Action Completion Times in the LRM are applied in the same manner as in the Technical Specifications. Beaver Valley Unit 2 1.3 - 1LRM Revision 52 1.0 1.4 Licensing Requirements Manual Frequency 1.4 USE AND APPLICATION Frequency The explanation of the use of surveilfance Frequencies contained in Technical SpecificationSection 1.4, "Frequency" applies to the Licensing Requirement Surveillances contained in the LRM. Surveillance Frequencies in the LRM are applied in the same manner as in the Technical Specifications. Beaver Valley Unit 2 1.4-1 LRM Revision 52 Licensing Requirements Manual 3.0 LIcENSTNG REQUTREMENT (LR) AppLtCABlLrTy LR Applicability 3.0 LR 3.0.1LRs shall be met during the MODES or other specified conditions in the Applicability, 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 the associated 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 3.0.3 When 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 and Functionality Assessments" and appropriate corrective actions i nitiated,within the time frame determined by the Shift Manager that shall not exceed 48 hours from the time of entry into LR 3.0.3. The time frame for completion of the corrective actions shall be commensurate with thesafety significance of the condition, consistent with the guidance of NOP-OP-1009Where corrective measures are completed that permit operation inaccordance with the LR or ACTIONS, completion of the actions required by LR 3.0.3 is not required.LR 3 0.4 Equipment removed from service or declared inoperable/Nonfunctional to comply 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 system returned 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 2 30-1 LRM Revision 67 Licensing Requirements ManualLR Applicability 3.03.0 LR Applicability (continued) LR 3.0.5 Requirements are specified in the LRM that are referenced from the Technical Specifications. These requirements include the informationcontained in tables, reports, and figures (e.9., Instrumentation Response Times and the COLR). Although these requirements are contained in the LRM, they are utilized by, and referenced from, the TechnicalSpecifications. The guidance in Section 3.0 of this manual for LR Applicability does not apply to the LRM requirements referenced by the Technical Specifications. The failure to meet LRM requirements referenced 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 Test Exception 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 2 3.0-2 LRM Revision 52 Licensing Requirements Manual 3.0 LTCENSTNGREQUTREMENTSURVETLLANCE(LRS)APPLTCABTLTTYLRS Applicability 3.0 LRS 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 the performance of the Surveillance or between performances of the Surveillance, 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 specified limits.LRS 3.0.2 The specified Frequency for each LRS is met if the Surveillance is performed 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 specified Frequency, then compliance with the requirement to declare the LR notmet may be delayed, from the time of discovery, up to 24 hours or up to the limit of the specified surveillance interval, whichever is greater. This delay 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 must immediately be declared not met, and the applicable ACTION(s) rnust be entered.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 2 30-3 LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 Boration Flow Paths - ShutdownLR 3.1.1 APPLICABlLITY:MODES 5 and 6. CONDITION Required flow path Nonfunctional.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 acid transfer pump to a charging pump to the Reactor Coolant System when the boric acid storage tank is required FUNCTIONAL inaccordance with LR 3.1.7 , or fhe flow path from the refueling water storage tank (RWST) via a charging pump or a low head safety injection pump (with an openRCS vent of greater than or equal to 3.14 square inches) to the Reactor Coolant System when the RWST is required FUNCTIONAL in accordance with LR 3.1.7. SURVEILLANCECycle each testable power operated or automatic valve in the flow path through at least one complete cycle of full travel.Boration Flow Paths - Shutdown 3.1.1 COMPLETION TIME lmmediately FREQUENCY7 days a.b.A.ACTIONS REQUIRED ACTIONA.1 Suspend all operationsinvolving CORE ALTERATIONS or positivereactivity changes. LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2 311-1 LRM Revision 67 Licensing Requirements Manual LICENSING REQUIREMENT SURVEILLANCES continuedSU RVEILLANC E LRS 3.1 .1 .2Boration Flow Paths - Shutdown 3.1.1 FREQUENCY LRS 3.1.1.3. NOTE .Only required to be met when a flow path from the boricacid storage tanks is required FUNCTIONAL and the ambient air temperature of the Auxiliary Building is< 650F.Verify the temperature of the heat traced portion of the flow path is > 65"F.Verify each valve (manual, power operated or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.7 days 31 daysBeaver Valley Unit 2 3.1 1-2LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.2 Boration Flow Paths - Operating LR 3.1.2Boration Flow Paths - Operating 3.1 .2 a.b.Each of the following boron injection flow paths shall be FUNCTIONAL: The flow path from the boric acid tanks via a boric acid transfer pump and one charging pump to the Reactor Coolant System, and The flow path from the refueling water storage tank via one charging pump to the Reactor Coolant System.. NOTES -With any non-isolated RCS cold leg temperature ( the OPPS enable temperature specified in the PTLR, one of the required centrifugal charging pumps may be made incapable of injecting to support the requirements of LCO 3.4.12. With all non-isolated RCS cold leg temperatures > the OPPS enable temperature specified in the PTLR, one of the required centrifugal charging pumps may be made incapable of injecting to support transition into or from the Applicability of LCO 3.4.12 forup to 4 hours or until the temperature of all non-isolated RCS cold legs exceeds the OPPS enable temperature specified in the PTLR plus 25oF, whichever comes first.1.2.A B APPLICABILITY: MODES 1,2,3, and 4.CONDITION Flow path from the boricacid tanks Nonfunctional. Required Action, and associated Completion Time of Condition A not met.COMPLETION TIME 72 hours lmmediately ACTIONS REQUIRED 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 Manual ACTIONS (continued CONDITION Flow path from the refueling water storagetank Nonfunctional. Required Action and associated Completion Time of Condition C not met.LRS 3.1 .2 1 Boration Flow Paths - Operating3.1 .2 COMPLET]ON TIME t hour 6 hours 36 hours FREQUENCY 92 daysSU RVEILLANCECycle each testable power operated or automatic valve in the flow path through at least one complete cycle of full 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 the flow 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, or otherwise secured in position, is in rts correct position.Cycle each power operated (excluding automatic) valve in the flow path that is not testable during plant operation, through at least one complete cycle of full travel.LRS 3.1 2.2 LRS 3 1 2.3 LRS 3 1 2.47 days31 days 18 months during shutdownREQUIRED ACTIONC.1 Restore the flow path toFUNCTIONAL status.D.1 Be in MODE 3. ANDD.2 Be in MODE 5.LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 31.2-2 LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Charging Pump - Shutdown LR 3.1.3 APPLICABILITY:MODES 5 and 6. CONDITlON Required pump Nonfunctional.LRS 3.1 .3.1 LRS 3.1 3.2 One 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 Coolant System vent of 2 3.14 square inches).SURVEILLANCE The required charging pump shall be demonstrated FUNCTlONAL pursuant to Technical Specification Surveillance SR 3.5.2.4. The required low head safety injection pump shall be demonstrated 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 safety injection pump pursuant to Technical SpecificationSurveillance SR 3.5.2.4. andc. Verification that the vent is open in accordance with Technical Specification Surveillance SR 3.4.12.3.

Charging Pump - Shutdown 3.1.3 COMPLETION TIME lmmediately FREQUENCYln Accordancewith SR 3.5.2.4ln Accordancewith the applicable SRs or LRS b.A.ACTIONS REQUIRED ACTIONA.1 Suspend all operationsinvolving COREALTERATIONS or positivereactivity changes. LICENSlNG REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 313-1 LRM Revision 67 Licensing Requirements Manual LICENSING REQUIREMENT SURVEILLANCES continued SU RVEILLANCE 3.1.3.3 Charging Pump - Shutdown 3.1.3 FREQUENCY- NOTE -Only required to be met when the low head safety injection pump is required FUNCTIONAL in accordancewith LR 3.1 .3.b. Verify a FUNCTIONAL low head safety injection flow path from the RWST to the Reactor Coolant System.12 hours Beaver Valley Unit 2 3.1.3 - 2 LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Charging Pumps - Operating LR 3.1.4 Charging Pumps - Operating 3.1.4 1.2.Two charging pumps shall be FUNCTIONAL.. NOTES .With any non-isolated RCS cold leg temperature ( the OPPS enable temperature specified in the PTLR, one of the required centrifugal 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 OPPS enable 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 cold legs exceeds the OPPS enable temperature specified in the PTLR plus 25oF, whichever comes first.A.APPLICABILITY:MODES 1 ,2, 3, and 4.CONDITION One required charging pump Nonfunctional. Required Action and associated Completion Time of Condition A not met.COMPLETION TIME 72 hours lmmediately B.ACTIONS REQUIRED ACTIONA.1 Restore the charging pump to FUNCTIONAL status.8.1 Apply LR 3.0 3 Beaver Valley Unit 2 3.1.4 - 1 LRM Revision 67 LICENSING REQUIREMENT SURVEILLANCES Licensing Requirements Manual LRS 3 1 .4.1 SU RVEILLANCE Each required charging pump shall be demonstrated FUNCTIONAL pursuant to Technical SpecificationSurveillance SR 3.5.2.4. Charging Pumps - Operating 3.1.4 FREQUENCY ln Accordancewith SR 3.5.2.4 Beaver Valley Unit 2 3.1.4 - 2 LRM Revision 67 A.Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Boric Acid Transfer Pumps - Shutdown LR 3.1.5 APPLICABILITY: CONDITION Required boric acid transfer pump Nonfunctional. LRS 3.1 .5.1 Boric Acid Transfer Pumps - Shutdown 3.1.5ln accordancewith the lnservice Testing ProgramOne boric acid transfer pump shall be FUNCTIONAL.ln MODES 5 and 6 when the associated flow path from the boric acid storage system is required FUNCTIONAL in accordance withLR 3.1.1.COMPLETION TIME lmmediatelySU RVEILLANC E FREQUENCYThe required boric acid transfer pump shall be demonstrated FUNCTIONAL by verifying, that on recirculation flow, the pump develops a differential pressure of > 102 psid.ACTIONS REQUlRED ACTION A.1 Suspend all operations involving COREALTERATIONS or positive reactivity changes.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2 31.5-1LRM Revision 67 B.Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1.6 Boric Acid Transfer Pumps - OperatingLR 3.1 .6 APPLICABILITY: CONDITlON Required boric acid transfer pump Nonfunctional. Required Action and associated Completion Time of Condition A not met.LRS 3.1 6.1 Boric Acid Transfer Pumps - Operating 3.1.6ln Accordancewith the lnservice Testing Program One 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 hours lmmediately SURVEILLANCE FREQUENCYThe required boric acid transfer pump shall bedemonstrated FUNCTIONAL by verifying, that on recirculation flow, the pump develops a differential pressure of > 102 psid.ACTIONSREQUlRED ACTIONA.1 Restore the boric acid transfer pump to FUNCTIONAL status.8.1 Apply LR 3.0.3.LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 23.1 6-1LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Borated Water Sources - Shutdown LR 3.1.7 APPLICABILITY: MODES 5 and 6.CONDITION Required borated watersource Nonfunctional.LRS 3 1.7 1Borated Water Sources - Shutdown 3.1.7 COMPLETION TIME lmmediately FREQUENCYOne 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.A SU RVE ILLANCE- NOTE .Only required to be met when the outside ambient air temperature is < 45"F.Verify the required RWST temperature.

24 hours ACTIONS L REQUIRED ACTION A.1 Suspend all operationsinvolving CORE ALTERATIONS or positive reactivity changes.LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 3.1.7 - 1 LRM Revision 67 Licensing Requirements Manual LICENSING REQUIREMENT SURVEILLANCES continued SU RVEILLANCE LRS 3.1.7 .2 Borated Water Sources - Shutdown 3.1.7 FREQUENCY7 days7 days LRS 3.1 .7 .3 Verify the required boric acid storage tank solution temperature.The required borated water source shall be demonstrated FUNCTIONAL by: a. Verifying the boron concentration of the water, andb. Verifying the water level of the tank.Beaver Valley Unit 2 3.1.7 - 2LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Borated Water Sources - Operating LR 3.1.8 APPLICABILlTY: MODES 1 , 2, 3, and 4.CONDITION Boric Acid Storage System Nonfunctional. Required Action and associated Completion Time of Condition A not met.Borated Water Sources - Operating 3.1.8 COMPLETION TIME72 hours lmmediately The Boric Acid Storage System shall be FUNCTIONAL as required by LR 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.ACTIONS REQUIRED ACTION A.1 Restore the storagesystem to FUNCTIONAL status.B1 ApplyLR303.Beaver Valley Unit 2 3.1 8 - 1 LRM Revision 67 LICENSI NG REQUIREMENT SURVEILLANCES Licensing Requirements Manual LRS 3.1 .8.1 SURVEILLANCEThe Boric Acid Storage System shall be demonstratedFUNCTIONAL by:

a. Verifying the boron concentration of the water, b. Verifying the water level of the tank, and c. Verifying the boric acid storage system solution temperature.Borated Water Sources - Operating 3.1.8 FREQUENCY 7 days Beaver Valley Unit 23.1 8 - 2 LRM Revision 67 A.Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS 3.1.9 Rod Position lndication System - Shutdown LR 3.1.9 APPLICABILITY:

CONDITION Required digital rod position indicator(s) Nonfunctional. LRS 3 1.9.1Rod Position Indication System - Shutdown 3.1.9ln accordance with applicable SROne digital rod position indicator (excluding demand position indication)shall be FUNCTIONAL and capable of determining the control rod position within + 12 steps for each shutdown or control rod not fully inserted.MODES 3, 4, and 5 with the reactor trip system breakers in the closed position.COMPLETION TIME lmmediatelySU RVEILLANC E FREQUENCY Verify required digital rod position indicator(s) FUNCTIONAL in accordance with Technical Specification Surveillance SR 3.1.7 .2.1.ACTIONSREQUIRED ACTION A.1 Open the reactor tripsystem breakers. LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 319-1LRM Revision 67 Licensing Requirements Manual3.1 REACTIVITY CONTROL SYSTEMS3.1 .1 0 Boron DilutionLR 3.1.10 APPLICABILITY: CONDlTION Flow rate of reactor coolant through 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 Dilution 3.1 .1 0 lmmediately FREQUENCY Prior to the startof and at least once per hourduring a reductionin the RCS boron concentration A.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 in operation, or b. Verifying that at least one RHR pump is in operationand supplying >

3000 gpm through the core.ACTIONSREQUIRED ACT]ON A.1 Suspend all operations involving a reduction inboron concentration of the RCS.LICENSING REQUI REMENT SURVEILLANCES Beaver Valley Unit 2 3.1 .10 - 1 LRM Revision 52 Licensing Requirements ManualRod Position Indication System - Shutdown Test Exceptions 3.1 .113.1 REACTIVITY CONTROL SYSTEMS 3.1.11 Rod Position Indication System - Shutdown Test Exceptions LR 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 fully inserted 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 is maintained < 0.95, and (2) only one shutdown or control rod bank is withdrawn 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 time measurements. COMPLETION TIME A APPLlCABILITY: CONDITION Position IndicationSystems Nonfunctional or with more than one bank ofrods withdrawn. lmmediately ACTIONSREQUIRED ACTIONA.1 Open the Reactor trip breakers.Beaver Valley Unit 2 3.1.11 - 1LRM Revision 67 Licensing Requirements Manual Rod Position Indication System - Shutdown Test Exceptions 3.1.11 LRS 3.1.11.1SU RVEILLANC E The Position Indication Systems shall be determined tobe FUNCTIONAL during rod drop time measurementsby verifying the Demand Position Indication System and the Digital Rod Position Indication System agree:

a. Within 12 steps when the rods are stationary, and
b. Within 24 steps during rod motion.

FREQUENCY Within 24 hours prior to the starl of rod drop time measurements and at least once per 24 hours thereafter LICENSI NG REQU IREMENT SURVEILLANCES Beaver Valley Unit 2 3111 -2 LRM Revision 67 Licensing Requirements ManualReactor Trip System Instrumentation Response Times 3.3.13.3 INSTRUMENTATION 3.3.1 Reactor Trip System lnstrumentation Response TimesLR 3.3.1 APPLICABILITY: As specified in TS 3.3.1.Each reactor trip system instrumentation response time listed in Table 3.3.1-1 shall be maintained in the manner specified in Technical Specification (TS) 3.3.1, Reactor Trip System Instrumentation. Beaver Valley Unit 2 3.3.1 - 1 LRM Revision 52 Licensing Requirements Manual 1.2.3.4.5.FUNCTION Manual Reactor Trip Power Range, Neutron Flux Power Range, Neutron Flux, High Positive Rate Intermediate Range, Neutron Flux Source Range, Neutron Flux (Below P-10)Overtemperature ATOverpower ATa. Pressurizer Pressure - Lowb. Pressurizer Pressure - High Pressurizer Water Level - High Reactor Coolant Flow - Lowa. Single loopb. Two loops Reactor Coolant Pump (RCP) Breaker Position Trip Undervoltage-RCPs Underfrequency-RCPs Steam Generator Water Level - Low Low Turbine Tripa. Emergency Trip HeaderLow Pressureb. Turbine Stop Valve ClosureSafety Injection Input from ESFAS Reactor Trip System lnterlocks 9.10.11.12.13.14.15.Reactor Trip System Instrumentation Response Times 3.3.1 TABLE 3.3.1-1 (Page 1 of 2)REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES 6.7.8.RESPONSE TIMENOT APPLICABLE < 0.5 second(1)NOT APPLICABLE NOT APPLICABLENOT APPL]CABLE Yu11"51"(txz) ysr-1s51s(tXz) < 2.4 seconds < 2.0 secondsNOT APPLICABLE < 1.0 second < 1.0 second NOT APPLICABLE < 1.5 seconds < 0.9 second < 2.4 secondsNOT APPLICABLE NOT APPLICABLE NOT APPLICABLENOT APPLICABLE 16.17.Beaver Valley Unit 2 3.3.1 - 2 LRM Revision 52 Licensing Requirements Manual Reactor Trip System Instrumentation Response Times 3.3.1 TABLE 3.3.1-1 (Page 2 ot 2)REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES 18. Reactor Trip Breakers (RTBs) NOT APPLICABLE

19. RTB Undervoltage and Shunt Trip Mechanisms NOT APPLICABLE
20. Automatic Trip Logic NOT APPLICABLE TABLE NOTATION (1) Neutron detectors are exempt from response time testing. Response time shall be measured 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 2 3.3.1 - 3 LRM Revision 52 Licensing Requirements Manual Reactor Trip System lnstrumentation Response Times 3.3.1 TABLE 3.3.1-1.a (Page 1 of 1)Overtemperature Delta-T & Overpower Delta-T Response Times This 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. Criteria FinalAccept. CriteriaFinal Accept. CriteriaRTD Time Response Overtemperature AT - Truo Input Overpower AT - Truo Input Measured AT -AT lnput 2.02.8622.643 9.883 2.12.8402.625 9.777 2.2 2.818 2.609 L672 2.3 2.796 2.592 9.568 2.4 2.775 2.575 9.464 2.5 2.754 2.559 9.362 2.6 2.733 2.543 9.260 2.7 2.713 2.527 9.159 2.8 2.693 2.512 9.059 2.92.6732.4978 960 3.02.6542.481 8.861 3.12.6342.467 8.763 3.2 2.615 2.452 8.666 3.3 2.596 2.438 8.569 3.4 2.578 2.423 8.473 3.5 2.559 2.409 8.378 3.62.5412.395 8.283 3.72.5232.382 8.189 3.8 2.505 2.368 8.096 3.9 2.487 2.3548 003 4.4 2.469 2.341 7.911 4.1 2.452 2.328 7.819 4.2 2.434 2.315 7.728 4.3 2.417 2.302 7.637 4.4 2.400 2.289 7.547 4.5 2.383 2.276 7.457 Pressurizer pressure i nput.Neutron detector input (for f(Al) penalty): Final Accept.Criteria FinalAccept. CriteriaFinal Accept. Criteria RTD Time Response Overtemperature AT - T"uo Input Overpower AT - T"uo Input Measured AT -AT Input 4.6 2.366 2.264 7.367 4.7 2.349 2.251 7.279 4.8 2.333 2.239 7.1904.92.316 2.226 7.102 5.0 2.300 2.214 7.014 5.1 2.283 2.242 6.927 5.2 2.267 2.190 6.840 5.3 2.250 2.178 6.754 5.4 2.235 2.166 6.668 5.5 2.218 2.154 6.582 5.6 2.242 2.143 6.497 5.7 2.187 2.131 6.412 5.8 2.171 2izA 6.327 5.9 2.156 2.108 6.242 6.0 2.140 2.497 6.158 6.1 2.040 1.997 6.058 6.2 1.944 1.897 5.958 6.3 1.840 1.797 5.858 6.41.7401.697 5.758 6.5 1.640 1.597 5.658 6.61_5401.497 5.558 6.7 1.444 1.397 5.458 6.8 1.344 1.297 5.358 6.9 1.240 1.197 5.258 7.011441.097 5.158< 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, and measured 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 the Licensing Requirements Manual values.Beaver Valley Unit 2 3.3.1 - 4 LRM Revision 52 Licensing Requirements Manual 3.3 INSTRUMENTATION 3.3.2 Engineered Safety Features Response TimesLR 3.3.2 Engineered Safety Features Response Times 3.3.2 Each 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 System lnstrumentation and TS 3.3.5, Loss of Power Diesel Generator Start and Bus Separation lnstrumentation as applicable. APPLICABILITY: As specified in the applicable TS.Beaver Valley Unit 2 3.3.2 - 1 LRM Revision 52 Licensing Requirements Manual INITIATING SIGNAL AND FUNCTION 1. Manual Engineered Safety Features Response Times 3.3.2 TABLE 3.3.2-1 (Page 1 of 4)ENGINEERED SAFETY FEATURES RESPONSE TIMES Containment Pressure-Hiqh

a. Safety lnjection (ECCS)b. Reactor Trip (from Sl)c. Feedwater lsolation d. Containment lsolation-Phase "A"e. Auxiliary Feedwater Pumps
f. Service Water SystemSafety I njection (ECCS)Feedwater lsolationReactor Trip (Sl)Conta inment lsolation-Phase "A"Containment Vent and Purge lsolation Auxiliary Feedwater PumpsService Water System Containment Quench Spray Pumps Containment Quench Spray ValvesContainment lsolation-Phase "B"Containment lsolation-Phase "A"Control Room Ventilation lsolation RESPONSE TIME IN SECONDSNot ApplicableNot ApplicableNot ApplicableNot ApplicableNot Applicable Not ApplicableNot Applicable

Not Applicable Not Applicable Not Applicable Not 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 2 3.3.2 - 2 LRM Revision 52 Licensing Requirements ManualEngineered Safety Features Response Times 3.3.2 TABLE 3.3.2-1 (Page 2 of 4)ENGINEERED SAFETY FEATURES RESPONSE TIMES IN]TIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS3. Pressurizer Pressure-Low

a. 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 < 60.0 t. Service Water System < 72.0Q)1181 .0(8)4. Steam Line Pressure-Low

a. Safety Injection (ECCS)b. Reactor Trip (from Sl)c. Feedwater lsolation d. Containment lsolation-Phase "A" e. Auxiliary Feedwater Pumpsf . Service Water System g. 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 Hiqh

a. Containment Quench Spray < 74.5o2)b. Containment lsolation-Phase "B" Not Applicable
c. Control Room Ventilation lsolation (on CIB) < 22.0(e)177.A(o)d. Recirculation Spray Not Applicable I6. Steam Generator Water Level-Hiqh Hiqh a. Turbine Trip Not Applicableb. Feedwater lsolation

< 7.0(6)Beaver Valley Unit 2 3.3.2 - 3 LRM Revision 56 Licensing Requirements ManualEngineered Safety Features Response Times 3.3.2 TABLE 3.3.2-1 (Page 3 of 4)ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 7. ContainmentPressure-lntermediateHiqhHiqh

a. Steam Line lsolation

< 7.0(13)8. Steamline Pressure Rate-High Neqative a. 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 Low a. Motor-driven Auxiliary < 60.0Feedwater Pumps(1)b. Turbine-driven Auxiliary < 60.0 Feedwater Pump(')11. Undervoltage RCPa. Turbine-driven Auxiliary Feedwater Pump 12. Trip of Main Feedwater Pumps a. Motor-driven Auxiliary Feedwater Pumps< 60.0< 60.0 Beaver Vafley Unit 2 3.3.2 - 4LRM Revision 52 (4)Licensing Requirements ManualEngineered Safety Features Response Times 3,3.2 (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 Generator Diesel generator starting and sequence loading delays included. Response time limit includes opening of valves to establish Sl path and attainment of discharge pressure for centrifugal charging pumps and Low Head Safety Injection pumps. Sequential transferof charging pump suction from the volume control tank (VCT) to the refueling water storage tank (RWST) (RWST valves open, then VCT valves close) is not included.Diesel generator starting and sequence loading delays not included. Offsite power available. Response time limit includes opening of valves to establish Sl path and attainment of discharge pressure for centrifugal charging pumps. Sequential transfer of charging pump suction from the volume control tank (VCT) to the refueling water storage tank (RWST) (RWST valves open, then VCT valves close) is included.Diesel generator starting and sequence loading delays included. Response time limit includes opening of valves to establish Sl path and attainment of discharge pressure for centrifugal charging pumps. Sequential transfer of charging pump suction from the volume control tank (VCT) to the refueling water storage tank (RWST) (RWST valves open, then VCT valves close) is included. Feedwater system overall response time shall include verification of valve stroke times applicable to the feedwater containment isolation valves for Train A and the main feedwater 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 limit includes attainment of discharge pressure for service water pumps.Diesel generator starting and sequence loading delays not included. Response time limit only includes opening of valves to establish the flowpath to the diesel coolers. Diesel generator starting and sequence loading delays not included. Offsite power available. Response time limit includes operation of valves/dampers. Diesel generator starting and sequence loading delays included. Response time limit includes operation of valves/dampers. Diesel generator starting and sequence loading delays not included. Offsite power available. Response time limit includes opening of valves to establish Sl path and attainment of discharge pressure for centrifugal charging pumps and Low Head Safety lnjection pumps. Sequential transfer of charging pump suction from the volume control tank (VCT) to the refueling water storage tank (RWST) (RWST valves open, then VCT valves close) is not included. Diesel generator starting and sequence loading delays included. Response time does not 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 2 3.3.2 - 5LRM Revision 52 Licensing Requirements Manual 3.3 INSTRUMENTATION 3.3.3 Meteorological Monitoring lnstrumentation LR 3.3.3 APPLICABILITY: At all times. CONDITIONOne or more required meteorolog ical mon itoring channels Nonfunctional. One or more required meteorolog ical monitorin g channels Nonfunctional for more than 7 days.LRS 3 3.3.1 LRS 3 3.3.2 Meteorological Monitoring I nstrumentation 3.3.3 COMPLETION TIME lmmediately30 days FREQUENCY 24 hours1 84 daysThe meteorological monitoring instrumentation channels specified Table 3.3.3-1 shall be FUNCTIONAL. A.B.SU RVE ILLANC E Perform 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 ACTION A.1 Suspend all release of gaseous radioactivematerial from the radwaste gas decay tanks.8.1 Prepare and present areport to the onsite safetyreview committee for theirreview outlining the causeof the malfunction and the plans for restoring the channel(s) to FUNCTIONAL status.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2 3.3.3 - 1LRM Revision 67 Licensing Requirements Manual Meteorological Monitoring Instrumentation 3.3.3TABLE 3.3.3-1 (Page 1 of 1)METEOROLOGICAL MONITORING INSTRUMENTATION 1.INSTRUMENT WIND SPEED INSTRUMENT MlNIMUM ACCURACYt 0.5 mph*t 0.5 mph*+ 0.5 mph*+50+50+5"+ 0.1'c+ 0.1'c REQUIRED CHANNELS a.b.c.a.b.Nominal Nominal Nominal Elev. 500'Elev. 150' Elev. 35'AT- 35'- 35'2. WIND DIRECTIONa. Nominal Elev. 500'b. Nominal Elev. 150'

c. Nominal Elev.

35'3. AIR TEMPERATURE AT Elev. 500'AT Elev. 150'.Starting speed of anemometer shall be < 1 mph.Beaver Valley Unit 2 3.3.3 - 2 LRM Revision 52 Licensing Requirements Manual

3.3 INSTRUMENTATION

3.3.4 Axial Flux Difference (AFD) Monitor Alarm LR 3.3.4 APPLICABILITY: CONDITION A. LR not met.LRS 3.3.4.1Axial Flux Difference (AFD) Monitor Alarm 3.3.4 Once per hour for 24 hours AND Once per 30 minutes thereafter AFD shall be monitored and logged.When the AFD monitor alarm is Nonfunctional and power is > 50o/o RTP.COMPLETION TIME lmmediatelySU RVE lLLANC E FREQUENCYMonitor and log the indicated AFD for each FUNCTIONAL channel.ACTIONSREQUIRED ACTION4.1 Apply LR 3.0.3.LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 334-1 LRM Revision 67 Licensing Requirements Manual Quadrant Power Tilt Ratio (OPTR) Monitor Alarm 3.3.53.3 INSTRUMENTATION 3.3.5 Quadrant Power Tilt Ratio (OPTR) Monitor Alarm LR 3.3.5 APPLICABILlTY: CONDITIONA. LR not met.QPTR shall be verified within the limits.When the QPTR monitor alarm is Nonfunctional and power is > 50o/o RTP.COMPLETION TIME lmmediatelySU RVEILLANCE FREQUENCY LRS 3.3.5.1 Verify QPTR is within the limits.12 hours ACTIONSREQUIRED ACTION,A.1 Apply LR 3.0.3.LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 3.35-1 LRM Revision 67 Licensing Requirements Manual3.3 INSTRUMENTATION 3.3.6 Seismic Monitoring lnstrumentation LR 3.3.6 APPLICABILITY: At all times. CONDITIONOne or more required seismic monitoring instru ments Nonfu nctional.One or more required seismic monitoring instru ments Nonfu nctional for more than 30 days. Seismic Monitoring Instrumentation 3.3.6 COMPLETION TIME30 days10 days The seismic monitoring instrumentation specified in Table 3.3.6-1 shall be FUNCTIONAL. A.B.ACTIONSREQUIRED ACTION A.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 the plans for restoring theinstrument(s) to FUNCTlONAL status.Beaver Valley Unit 2 33.6-1 LRM Revision 67 Licensing Requirements Manual ACTIONS (continued CONDITIONC. Seismic event > 0.029.LRS 3.3.6 1LRS 3.3.6.2 LRS 3.3.6.3SU RVE ILLANC EPerform a CHANNEL CHECK as specified in Table 3.3.6-2.Perforrn a CHANNEL OPERATIONAL TEST as specified in Table 3.3.6-2.Perform a CHANNEL CALIBRATION as specified inTable 3.3.6-2. Seismic Monitoring Instrumentation 3.3.6 COMPLETION TIME24 hours30 days30 days FREQUENCY ln accordancewith Table 3.3.6-2 ln accordancewith Table 3.3.6-2 In accordance with Table 3.3.6-2 REQUIRED ACTION C.1 Report to NRC.ANDRestore actuatedinstruments toFUNCTIONAL status.Perform CHANNEL CALI BRATION on actuated instruments. ANDC.4 Retrieve and analyze data from actuated instrumentsto determine magnitude of vibratory ground motion and prepare and submit a special report in accordance with 10 CFR 50.4 describing the magnitude, frequencyspectrum and resultanteffect upon facility featuresimportant to safety.L]CENSING REQU IREMENT SURVEILLANCESBeaver Valley Unit 2 3.36-2LRM Revision 67 Licensing Requirements Manual Seismic Monitoring I nstrumentation 3.3.6 (Page 1 of 1)INSTRUMENTATION TABLE 3.3.6-1SElSMIC MONITORING INSTRUMENTS AND SENSOR LOCATIONS

1. 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 ACCELEROGRAPHS
a. 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 ANALYZER
a. Control Room NOTES MEASUREMENT RANGE(1)i1g t1g t1g i1g t1g t1g t2g t2g t5g N/A REQUIRED INSTRUMENTS (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 response spectrum analyzer in the Control Room.Beaver Valley Unit 2 3.3.6 - 3LRM Revision 52 Licensing Requirements Manual Seismic Monitoring Instrumentation 3.3.6TABLE 3.3.6-2 (Page 1 of 1)SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL CHANNEL CHANNEL OPERATIONAL INSTRUMENTS AND SENSOR LOCAT]ONS CHECK CALIBRATION TEST 1. TRIAXIALTIME.HISTORY ACCELEROGRAPHS

a. Containment Mat (2ERS-ACS-1)

M b. 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 R f. Aux. Building (2ERS-RRA-3)2. TRIAXIAL PEAK ACCELEROGRAPHS

a. Containment Building - RHS heat N/A R exchanger (2ERS-PRA-1

)b. Containment Building - Six inch Sl N/A R pipe (2ERS-PRA-2)c. Aux. Building (2ERS-PRA-3)3. RESPONSE SPECTRUM ANALYZER

a. Control Room M = 31 days R = 18 months SA = 184 days R R SA SA SA SA SA SA N/A N/A N/A R N/A R N/A N/ABeaver Valley Unit 2 3.3.6 - 4LRM Revision 52 Licensing Requirements Manual3.3 INSTRUMENTATION 3.3.7 Movable Incore DetectorsLR 3.3.7 APPLICABILITY:

CONDITION Movable incore detection system 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 to map 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, or c. Measurement of FIX and Fq(Z). COMPLETION TIME Movable Incore Detectors

3.3.7 lmmediately

FREQUENCY Within 24 hours prior to use A.SU RVEILLANCEThe incore movable detection system shall be demonstrated FUNCTIONAL by normalizing eachdetector output to be used for:a. Recalibration of the excore axial flux offset detectionsystem, or Monitoring the QUADRANT POWER TILT RATIO, or Measurement of FIX and Fq(Z).b.c.ACTIONS REQUIRED ACTION A.1 Suspend use of the systemfor the above applicablemonitoring or calibration functions. LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 3.3.7 - 1 LRM Revision 67 Licensing Requirements Manual3.3 INSTRUMENTATION 3.3.8 Leading Edge Flow Meter LR 3.3.8 APPLlCABILITY: CONDITION A. LEFM Nonfunctional. B. Required Action and associated CompletionTime not met.Leading Edge Flow Meter 3.3.8A FUNCTIONAL Leading Edge Flow Meter (LEFM) shall be used in the performance 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 daily calorimetric heat balance measurement. t hour In accordance with therequirements of sR 3.3.1 .2Until the LEFM isrestored to FUNCT]ONAL statusand the calorimetricheat balance measurement has been performed usingthe LEFM ACTIONS REQUIRED ACTION A.1 Restore LEFM to FUNCTIONAL status.Reduce steady-state THERMAL POWER to< 98.6% of RTP.8.2 Perform the calorimetricheat balance measurement using the feedwater flowventuris and Resistance Temperature Detector (RTD) indications.Maintain THERMALPOWER at < 98.6% ofRTP steady state. Beaver Valley Unit 2 338-1LRM Revision 67 LICENSI NG REQU I REMENT SURVEILLANCES Licensing Requirements Manual LRS 3.3.8.1LRS 3.3.8.2 SU RVEILLANCEThe LEFM shall be demonstrated to be FUNCTIONALby using the self-diagnostic features of the LEFM.The LEFM shall be demonstrated to be FUNCTIONAL by performing the periodic maintenance and inspections recommended by the manufacturer.Leading Edge Flow Meter 3.3.8 FREQUENCY24 hours18 monthsBeaver Valley Unit 2 33.8-2LRM Revision 67 Licensing Requirements ManualTurbine Overspeed Protection 3.3.93.3 INSTRUMENTATION 3.3.9 Turbine Overspeed Protection LR 3.3.9 At least one Turbine Overspeed Protection System shall be FUNCTIONAL. APPLICABILITY: MODE 1,MODES 2 and 3 except when all main steam isolation valves and associated bypass valves are in the closed position and all othersteam flow paths to the turbine are isolated.ACTIONS CONDITIONREQUIRED ACTION COMPLETION TIME A. One throttle valve or one governor valve per high pressure turbine steam line Nonfunctional and/or withone reheat stop valve orone reheat intercept valve per low pressure turbine steam line Nonfunctional. A.1 Restore the Nonfunctional valve(s) to FUNCTIONAL status.72 hours B. Required Action and associated Completion Time of Condition A not met.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 Overspeed Protection System Nonfunctional for reasons other than Condition A.c.1 OR c.2lsolate the turbine from thesteam supply.Apply LR 3.0 3.6 hours6 hours Beaver Valley Unit 2 3.3.9 - 1LRM Revision 67 LICENSING REQUIREMENT SURVEILLANCES Licensing Requirements Manual Turbine Overspeed Protection 3.3.9 FREQUENCY SURVEILLANCE. NOTE .Not required to be performed untilT2hours after entering MODE 3 during station startup with any steam flow path to the turbine not isolated. Cycle each of the following valves through at least one complete 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 after entering MODE 3 during station startup with any steam flow path to the turbine not isolated. Directly observe the movement of each of the following valves through one complete 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 untilT2 hours afterentering MODE 3 during station startup with any steam flow 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 3.3.9.1 LRS 3.3.9.2 LRS 3.3.9.36 months 6 months 18 months Beaver Valley Unit 2 3.3.9 - 2 LRM Revision 71 Licensing Requirements ManualLICENSING REQUIREM ENT SURVEILLANCES continued SURVEILLANCELRS 3.3.9.4Turbine Overspeed Protection 3.3.9 FREQUENCYLRS 3.3.9.5LRS 3.3.9.6- NOTE.Not required to be performed until72 hours afterentering MODE 3 during station startup with any steam flow path to the turbine not isolated. Directly observe the movement of each of the following valves through one complete cycle from the running position:a. Four low pressure turbine reheat stop valves.b. Four low pressure turbine reheat intercept valves.Perform a CHANNEL CALIBRATION on the turbine overspeed protection systems.Disassemble at least one of each of the above valves and perform a visual and surface inspection of valve seats, disks, and stems and verify no unacceptable flaws or excessive corrosion. lf unacceptable flaws or excessive corrosion are found, all other valves of thattype shall be inspected unless the nature of the problem can be directly attributed to a service condition specificto that valve.18 months18 months40 months OR. NOTE -Only applicable to reheat stop and intercept valves provided there is no indication of operational distress.60 monthsBeaver Valley Unit 2 3.3.9 - 3LRM Revision 52 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints3.3.1 0 3.3 INSTRUMENTATION 3.3.10 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 Technical Specification (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 manner specified in TS 3.3.2, Engineered Safety Feature Actuation System Instrumentation.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 Separation Instrumentation. APPLICABILITY: As specified in the applicable TS.Beaver Valley Unit 2 3.3.10 - 1LRM Revision 52 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints 3.3.10 TABLE 3.3.10-1 (Page 1 of 2)REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS 1.2.FUNCTION Manual Reactor Trip Power Range, Neutron Fluxa. High Setpointb. Low Setpoint Power Range, Neutron Flux High Positive Rate lntermediate Range, Neutron FluxSource Range, Neutron Flux Overtemperature ATOverpower AT Pressurizer

a. Pressure-Lowb. Pressure-High Pressurizer Water Level-Hig h Reactor Coolant Flow-Low Reactor Coolant Pump (RCP) Breaker Position Trip Undervoltage - RCPs Underfrequency - RCPsSteam Generator Water Level-Low LowNOMINAL TRIP SETPOINT(")

N.A.109% of RATED THERMAL POWER 25O/O RATED THERMAL POWER 5% of RATED THERMAL POWER with a time constant > 2 seconds 25% RATED THERMAL POWER 10s counts per secondSee Technical Specification Table Notation 3 on Table 3.3.1-1See Technical Specification Table Notation 4 on Table 3.3.1-1 1945 psig(o)2375 psig92% of instrument span90% of indicated loop flow N.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 - 2 LRM Revision 52 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints 3.3.10 TABLE 3.3.1 0-1 (Pag e 2 of 2)REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS FUNCTION NOMINAL@i TRIP SETPOINT(")

15. Turbine Tripa. Emergency Trip Header Low Pressure 1013 psig Ib. Turbine Stop Valve Closure 2 1o/o open
16. 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 POWER t. Turbine First Stage Pressure, P-13 1A% of RATED THERMAL POWER TurbineFirst Stage Pressure Equivalent
18. Reactor Trip Breakers (RTBs) N.A.19. RTB Undervoltage and Shunt Trip N.A.Mechanisms
24. Automatic Trip Logic N.A.(a) The Unit 2 Setpoint Methodology used to establish the Reactor Trip System Setpoints is defined in WCAP-11366.(d) With the exception of Functional Unit number 15.b.Beaver Valley Unit 2 3.3.10 - 3LRM Revision 65 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints 3.3.10 TABLE 3.3.10-2 (Page 1 of 3)ENGINEERED SAFETY FEATURES ACTUATION SYSTEM lNSTRUMENTATION TRIP SETPOINTS NOM INAL TRIP SETPOINT(")

1.FUNCTION SAFETY INJECTION AND FEEDWATER ISOLATIONa. Manual Initiation

b. Automatic Actuation Logic and Actuation Relays c. Containment Pressure - Highd. Pressurizer Pressure - Low e. Steamline Pressure - Low CONTAINMENT SPRAY SYSTEMS
a. Quench Spray 1. Manual lnitiation
2. Automatic Actuation Logic and Actuation Relays 3. Containment Pressure-High Highb. Recirculation Spray 1- Automatic Actuation Logic and Actuation Relays2. Refueling Water Storage Tank (RWST)Level Low Coincident with Containment Pressure High-H igh CONTAINMENT ISOLATIONa. Phase "A" lsolation 1. Manual lnitiation2. Automatic Actuation Logic and Actuation Relays3. Safety lnjection N.A.N.A.5.0 psig(b)1856 psig 500 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 Safety lnjection Trip Setpoints.

2.3.(a) The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System 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 are 11 > 50 seconds and 12 < 5 seconds. CHANNEL CALIBRATION shall ensure that these time constants are adjusted to these values.(d) The predefined as-found acceptance band, and the as-lefttolerance band is

  • 1".Beaver Valley Unit 2 3.3.10 - 4 LRM Revision 56 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints 3.3.10 TABLE 3.3.10-2 (Page 2 of 3)ENGINEERED SAFETY FEATURES ACTUATION SYSTEMINSTRUMENTATION TRIP SETPOINTSNOM INAL TRIP SETPOTNT(U) 3.FUNCTION CONTAINM ENT ISOLATION (continued)b. Phase "8" lsolation 1. Manual lnitiation2. Automatic Actuation Logic andActuation Relays3. Containment Pressure-High High STEAM LINE ISOLATION
a. Manual lnitiation
b. Automatic Actuation Logic and Actuation Relays c. Containment Pressure-lntermediateHigh High d. Steam Line Pressure
1. Low2. Negative Rate - High N.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 ISOLATION a. Automatic Actuation Logic and Actuation N.A.Relays b. Steam Generator Water Level-HighHigh, P-14

c. Safety lnjection (a)(b)(c)The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System 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 are t1 > 50 seconds and q < 5 seconds. CHANNEL CALIBRATION shall ensure that these time constants 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 2 3.3.10 - 5LRM Revision 56 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints 3.3.10 TABLE 3.3.1 0-2 (Page 3 of 3)ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS 6.FUNCTION AUXILIARY FEEDWATER a. Automatic Actuation Logic and Actuation N.A.Relays b. Steam Generator Water Level-Low Low c. Safety lnjection (Start All AuxiliaryFeedwater Pumps)

d. Undervoltage - RCP (Start Turbine Driven Pump)e. Trip of Main Feedwater Pumps (StartMotor Driven Pumps)

AUTOMATIC SW]TCHOVER TO CONTAINMENT SUMPAutomatic Actuation LogicRefueling Water Storage Tank Level -Extreme LowCoincident with Safety Injection ESFAS ]NTERLOCKS

a. 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 Safety Injection Trip Setpoints. 3120 V N.A.N.A.31 feet 9 inches(")See Function 1. above for all Safety lnjection Trip Setpoints. N.A.2000 psig 541"F 7.a.b.8.(d)(e)(a) The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System Setpoints is defined in WCAP-1 1366.The predefined as-found acceptance criteria band, and as-left setpoint tolerance band is t 0.5% span.The predefined as-found acceptance band, and the as-left tolerance band is

  • 1".Beaver Valley Unit 2 3.3.10 - 6 LRM Revision 52 Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints 3.3.10 TABLE 3.3.10-3 (Page 1 of 1)LOSS OF POWER D]ESEL GENERATOR START AND BUS SEPARATIONINSTRUM ENTATION TRIP SETPOINTS FUNCTION LOSS OF VOLTAGE1. 4160V Emergency Bus DG Start 2. 4160V Emergency Bus Separation DEGRADED VOLTAGE3. 4160V Emergency Bus Separation
4. 480V Emergency Bus Separation NOMINAL TRIP SETPOINT(U)3120 V with a time delay of 0.33 I 0.03 seconds 312A 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 2 3.3.10 - 7LRM Revision 52 Licensing Requirements Manual3.3 INSTRUMENTATION 3.3.11 Fuel Storage Pool Area Radiation MonitorLR 3.3.11 APPLICABILITY: CONDITION A. Setpoint not within limit. B. Required monitor Nonfunctional.Fuel Storage Pool Area Radiation Monitor 3.3.11The 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 hours Once per 24 hours SU RVE ILLANC E FREQUENCY LRS 3.3.11.1 Perform a CHANNEL CHECK.12 hours LRS 3.3.11 .2 Perform a CHANNEL OPERATIONAL TEST.31 daysLRS 3.3.11 3 Perform a CHANNEL CALIBRATION.18 months ACTIONSREQUIRED ACTIONA.1 Adjust the setpoint to withinthe limit. OR4.2 Declare the monitor Nonfunctional.8.1 Perform area surveys ofthe monitored area with portable monitoring instrumentation. LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 3311-1LRM Revision 67 Licensing Requirements Manual3.3 INSTRUMENTATION 3.3.12 ExplosiveGasMonitoring Instrumentation LR 3.3.12Explosive Gas Monitoring Instrumentation 3.3.12 APPLlCABILITY: ACTIONS Two channels of the Gaseous Waste System Surge Tank DischargeOxygen Monitor (2GWS-OA100A&B) shall be OPERABLE with Alarm/Trip Setpoints set to ensure the limits of LR 3.7.6 are not exceeded.- NOTE .The requirements of LR 3.3.12 are part of the Technical Specification 5.5.8, "Explosive Gas and Storage Tank Radioactivity Monitoring Program."During waste gas decay tank filling operation. COMPLETION TIME A.B.CONDITION One or more requiredchannels with Alarm/Trip setpoint less conservativethan required.One required channel inoperable. lmmediately Once per 24 hours30 daysREQUIRED ACT]ONA.1 Declare the affected channel(s) inoperable,8.1 Take and analyze grab samples.8.2 Restore inoperablechannel to OPERABLE status.Beaver Valley Unit 2 3.3.12 - 1LRM Revision 52 Licensing Requirements Manual ACTIONS (continued CONDITIONC. Two required channels inoperable. Required Action and associated Completion Time not met.SURVEILLANCE LRS 3.3.12.1 Perform CHANNEL CHECK. LRS 3.3.12.2 Perform CHANNEL OPERATIONAL TEST.LRS 3.3.12.3 Explosive Gas Monitoring Instrumentation 3.3.12 COMPLETION TIME Once per 4 hours during degassing operations AND Once per 24 hours during other operations30 days30 days FREQUENCY24 hours31 days D.. NOTE The CHANNEL CALIBRATION shall include the use of standard 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 grab samples.ANDC.2 Restore inoperablechannels to OPERABLE status.D.1 Prepare and submit a Special Report in accordance with 10 CFR50.4 to explain why the inoperability was not corrected in a timely manner.LICENSING REQUIREM ENT SURVEILLANCES Beaver Valley Unit 2 3.3.1 2 - 2LRM Revision 52 Licensing Requirements Manual LRS 3 3 13.13.3 INSTRUMENTATION 3.3.13 ContainmentHydrogenAnalyzers LR 3.3.13 APPLICABILITY: MODES 1 and 2.SU RVEILLANCE Perform a CHANNEL CALIBRATION using sample gases containing:1. One volume percent hydrogen, balance nitrogen, and2. Four volume percent hydrogen, balance nitrogen.Two separate and independent wide-range containment hydrogen analyzers shall be FUNCTIONAL. Containment Hydrogen Analyzers 3.3.13 FREQUENCY46 days on a STAGGERED TEST BASIS ACTIONS CONDlTION REQUIRED ACT]ONCOMPLETION TlME A. One wide-range hydrogenanalyzer Nonfu nctiona LA.1 Restore the Nonfunctionalanalyzer to FUNCTIONAL status.30 daysB. Two wide-range hydrogen analyzers N onfunctional.8.1 Restore at least one wide-range hydrogen analyzer to FUNCTIONAL status.72 hours C. Required Action and associated Completion Time not met.C.1 Apply LR 3.0.3.lmmediately LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 33.13-1 LRM Revision 67 Licensing Requirements Manual3.3 INSTRUMENTATION3.3.14 Control Room lsolation Radiation MonitorsLR 3.3.14Control Room lsolation Radiation Monitors 3.3.14 Monitors (2RMC-RQ201 & 202)background, and mR/hr.Two Control Room lsolation Radiationshall be FUNCTIONAL with:a. Setpoint of < 0.476 mR/hr above

b. Measurement range of 10 103 MODES 1,2,3, and 4.APPLICABILITY:

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Setpoint not within limit.A.1 Adjust the setpoint to within the limit.OR A.2 Declare the monitor Nonfunctional. 4 hours hours B. One monitor Nonfunctional8.1 Restore the Nonfunctionalmonitor to FUNCTIONAL status.OR 8.2 lsolate the combined control room by closing all series normal air intakeand exhaust isolatron dampers for both Unit 1and Unit 2.7 days7 days C. Two monitors Nonfunctional.C.1 Restore one monitor toFUNCTIONAL status. ORC.2 lsolate the combined control room by closing all series normal air intakeand exhaust isolation dampers for both Unit 1and Unit 2.hour hour Beaver Valley Unit 2 3.3.14 - 1LRM Revision 67 LICENSI NG REQUIREMENT SURVEILLANCES Licensing Requirements Manual SURVEILLANCE LRS 3.3.14.1 Perform a CHANNEL CHECK.LRS 3.3.14.2 Perform a CHANNEL OPERATIONAL TEST. LRS 3.3.14.3 Perform a CHANNEL CALIBRATION. Control Room lsolation Radiation Monitors3.3.1 4 FREQUENCY Beaver Valley Unit 2 3.3.1 4 - 2LRM Revision 53 Licensing Requirements Manual3.3 INSTRUMENTATION 3.3.15 Containment Area Radiation AlarmLR 3.3.15 APPLICABILITY:MODES 1 , 2, 3, and 4. CONDITION A. Setpoint(s) not within limit.One or more alarm channels Nonfunctional. Containment Area Radiation Alarm 3.3.15 COMPLETION TIME 4 hours4 hours 72 hours72 hours 30 daysln the next AnnualRadioactive Effluent Release Report Two 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 ACTION A.1 Adjust the setpoint(s) to within the limit.ORA.2 Declare the radiation monitor alarm Nonfunctional. Restore the Nonfunctionalalarm channel(s) to FUNCTIONAL status.lnitiate the preplanned alterirate method ofmonitoring the appropriate parameter(s). Restore the alarm channel(s) toFUNCTIONAL status. OR8.2.3 Explain why the Nonfunctionality was not corrected in a timely manner.Beaver Valley Unit 2 3.3.15 - 1 LRM Revision 67 LICENSING REQUIREMENT SURVEILLANCES Licensing Req uirements Manual SURVEILLANCE LRS 3.3.1 5.1 Perform a CHANNEL CHECK.LRS 3.3.15.2 Perform a CHANNEL OPERATIONAL TEST.LRS 3.3.1 5.3 Perform a CHANNEL CALIBRATION. Containment Area Radiation Alarm 3.3.15 FREQUENCYBeaver Valley Unit 23.3.1 5 - 2 LRM Revision 52 Licensing Requirements M anual3.3 INSTRUMENTATION 3.3.16 Accident Monitoring Instrumentation LR 3.3.1 6 APPLICABILITY: MODES 1,2, and 3.ACTIONSAccident Monitoring Instrumentation 3.3.16 The Accident Monitoring instrumentation for each Function in Table 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, for the appropriate ACTIONS in lieu of the LR 3.3.16 ACTIONS below.CONDITION COMPLETION TIME One or more Functions with one required channel Nonfunctional. 7 days Required Action and associated CompletionTime not met.lmmediately LICENSING REQUIREMENT SURVEILLANCESSU RVE ILLANCE FREQUENCY LRS 3.3.16.1 Perform a CHANNEL CHECK.31 days LRS 3.3.16.2- NOTE .Only applicable to the Reactor Coolant SystemSubcooling Margin Monitor Function. Perform a CHANNEL CALIBRATION.18 months A.B.REQUIRED ACTION A.1 Restore the Nonfunctionalchannel to FUNCTIONAL status.8.1 Apply LR 3.0.3.Beaver Valley Unit 2 3.3 16-1 LRM Revision 81 Licensing Requirements Manual LICENSING REQUIREMENT SURVEILLANCES continued SURVEILLANCE LRS 3.3.16.3 Accident Monitoring I nstrumentation 3.3.16 FREQUENCYOnly 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 2 3.3.16 - 2 LRM Revision 81 Licensing Requirements Manual 1.2.3.4.Table 3.3.16-1 (page 1 of 1)Accident Monitoring I nstrumentation FUNCTION Reactor Coolant System Subcooling Margin Monitor PORV Limit Switch Position Indicator PORV Block Valve Limit Switch Position lndicatorSafety Valve Position lndicator Accident Monitoring I nstrumentation 3.3.16 REQUIRED CHANNELS 1 1 per valve 1 per valve 1 per valveBeaver Valley Unit 2 3.3.16 - 3 LRM Revision 81 Licensing Requirements Manual3.4 REACTOR COOLANT SYSTEM (RCS)3.4.1 Loop lsolation Valves - Shutdown LR 3.4.1Loop lsolation Valves - Shutdown 3.4.1 APPLICABILITY: ACTlONS CONDITION A. 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 isolation valve 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 TIME SURVEILLANCE FREQUENCY Verify that power is removed from the RCS isolated loop stop valve operators.7 daysREQUIRED ACTIONA.1 Remove power from theisolated loop isolation valve operators. LICENSING REQUlREMENT SURVEILLANCES Beaver Valley Unit 2 3.4.1 - 1LRM Revision 52 Licensing Requirements Manual Chemistry 3.4.23.4 REACTOR COOLANT SYSTEM (RCS)3.4.2 ChemistryLR 3.4.2 The RCS chemistry shall be maintained within the limits specified in Table 3.4.2-1 .APPLICABILITY: At all times. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.. NOTE -Only applicable in MODES 1 , 2, 3, and 4 .One or more chemistry parameters in excess of its Steady State Limit but within its Transient Limit.,A.1 Restore the Parameter towithin its Steady State Limit.24 hoursB. Required Action and associated Completion Time of Condition A not met.8.1 Apply LR 3.0 3.lmmediately C.. NOTE .Only,applicable in MODES 1 , 2, 3, and 4.One or more chemistry parameters in excess of its Transient Limit.C.1 Apply LR

3.0.3 lmmediately

Beaver Valley Unit 2 3.4.2 - 1 LRM Revision 67 Licensing Requirements Manual ACTIONS (continued CONDITION. NOTE .Not applicable in MODES 1 , 2, 3, and 4.Concentration of either chloride or fluoride in theRCS in excess of its Steady State Limit for more than 24 hours or in excessof its Transient Limit.. NOTE -Not applicable in MODES 1,2,3,4, 5 and 6.Unable to determine limitsof chloride or fluoride in the RCS due to the inability to sample 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. Chemistry 3.4.2 COMPLETION TIMEPrior to increasing the pressurizer pressureabove 500 psig or prior to proceeding to MODE 4 lmmediately FREQUENCY72 hoursREQUIRED ACTIOND.1 Reduce the pressurizer pressure to < 500 psig, ifapplicable, and perform ananalysis to determine theeffects of the out-of-limitcondition on the structural integrity of the RCS;determine that the RCS remains acceptable forcontinued operations.. NOTE .Required Action E.1 is onlyapplicable when the ability to sample the RCS is restored.Initiate action to performLRS 3.4.2.1 . LICENSI NG REQU IREMENT SURVEILLANCES Beaver Valley Unit 2 3.4.2 - 2 LRM Revision 68 Licensing Requirements Manual PARAMETER CHLORIDE FLUORIDE.Limit not applicable with Tuus S 250'F. Chemistry 3.4.2 TABLE 3.4.2-1 (Page 1 of 1)REACTOR COOLANT SYSTEM CHEMISTRY LIMITS STEADY-STATE LIMIT DISSOLVED OXYGEN. < 0.10 ppm*TRANSIENT LIMIT< 1.00 ppm*< 1.50 ppm< 1.50 ppm< 0.15 ppm< 0.15 ppmBeaver Valley Unit 2 3.4.2 - 3LRM Revision 52 Licensing Requirements Manual3.4 REACTOR COOLANT SYSTEM (RCS)3.4.3 Pressurizer LR 3.4.3 The pressurizer temperature shall be limited to: Pressurizer

3.4.3 APPLICABILITY

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, and d. A maximum auxiliary spray water temperature differential of 380'F.At all times. COMPLETION TIME 30 minutes A.CONDITIONP ressu rizer te m pe ratu re limit(s) exceeded.Required Action and associated CompletionTime not met.B.REQUIRED ACTION Restore temperature to within the limit(s).Perform an engineeringevaluation to determine theeffects of the out-of-limitcondition on the structuralintegrity of the pressurizer.Determine that the pressurizer remains acceptable for continued operation.8.1 Be in MODE 3. AND8.2 Reduce the pressurizer pressure to less than 500 psig.Beaver Valley Unit 2 3.4.3 - 1LRM Revision 52 LICENSING REQUIREMENT SURVEILLANCES Licensing Requirements Manual LRS 3.4.3.1LRS 3.4.3.2 LRS 3.4.3.3 SURVEILLANCE The pressurizer temperatures shall be determined to bewithin the limits.The normal spray water temperature differential shall be determined to be within the limit. The auxiliary spray water temperature differential shallbe determined to be within the limit. Pressurizer 3.4.3 FREQUENCY Once per30 minutes during system heatup or cooldown Once per30 minutes during system heatup or cooldown Once per30 minutes duringauxiliary spray operation Beaver Valley Unit 2 3.4.3 - 2 LRM Revision 52 Licensing Requirements Manual3.4 REACTOR COOLANT SYSTEM (RCS)3.4.4 DELETED 3.4.4Beaver Valley Unit 2 3.4.4 - 1LRM Revislon 67 Licensing Requirements Manual3.4 REACTOR COOLANT SYSTEM (RCS)3.4.5 RCS Head Vents LR 3.4.5 RCS Head Vents 3.4.5 All power operated RCS head vent valves shall be FUNCTIONAL and closed 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, "RCS Operational LEAKAGE," limits, or cannot be opened and closedon demand.The vent valves may be operated for required venting operations and leak testing in MODES 3 and 4.1.2.A.APPLICABILITY:MODES 1 , 2, 3, and 4.CONDlTIONOne vent path from theabove location FUNCTIONAL and one or more power operated ventvalves Nonfunctional. COMPLETION TIME lmmediately ACTIONS REQUIRED ACTION. NOTE -Power operation maycontinue and entry intoMODES 1-4 is not restricted until the next scheduled outage, at whichtime all RCS head ventvalves shall be FUNCTIONAL prior to entry into MODE 1 .Maintain the Nonfunctional valve(s) closed with power removed.Beaver Valley Unit 2 3.45-1 LRM Revision 67 B.Licensing Requirements Manual ACTIONS (continued CONDITIONAll vent paths from theabove location Nonfunctional. LRS 3.4.5.1RCS Head Vents 3.4.5 COMPLETION TIME lmmediately lmmediately72 hours72 hours FREQUENCY18 months b.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 control room.Verifying flow through the RCS Head vent path to the Pressurizer Relief Tank.

REQUIRED ACTION 8.1 Maintain the Nonfunctionalvalves closed with power removed.OR 8.2.1 Close the manual isolation valves.AND 8.2.2 Restore one vent path fromthe above locations to FUNCTIONAL status.OR 8.3 Apply LR 3.0.3. LICENSlNG REQUIREMENT SURVEILLANCESBeaver Valley Unit 2 3.4.5 - 2LRM Revision 67 Licensing Requirements Manual Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge 3.4.63.4 REACTOR COOLANT SYSTEM (RCS)3.4.6 LR 3.4.6 APPLICABILITY:- NOTE .Required Action A.3 shall be completed whenever this Condition is entered.A. One or more pressurizersafety valve(s) lift as indicated by the safety valve position indicator with loop seal or water discharge. 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 temperature specified in the PTLR.CONDITION COMPLETION TIME 6 hours24 hours 30 hours ACTIONSREQUlRED ACTIONA.1 Be in MODE 3. 4.2 Be in MODE 4 with any RCS cold leg temperature < the enable temperaturespecified in the PTLR with RCS overpressureprotection provided in accordance with therequirements of TechnicalSpecification 3.4.12. Initiate action to evaluatethe OPERABILITY of the affected valve(s).Beaver Valley Unit 2 34.6-'r LRM Revision 67 LICENSING REQUIREMENT SURVEILLANCES Licensing Requirements Manual Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge 3.4.6 SURVEILLANCE FREQUENCY LRS 3.4.6.1No additional requirements other than the applicable requirements of the lnservice Testing Program.ln accordance with the InserviceTesting Program. Beaver Valley Unit 2 3.4.6 - 2 LRM Revision 52 Licensing Requirements Manual 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.7 RCS Pressure lsolation Valves LR 3.4.7 APPLICABILlTY: RCS Pressure fsolation Valves 3.4.7Each Pressure lsolation Valve listed in Table 3.4.7-1 shall be maintained OPERABLE in accordance with the requirements of Technical Specification (TS) 3.4.14, "RCS Pressure lsolation Valves (PlV) Leakage." As specified in TS 3.4.14. Beaver Valley Unit 2 3.4.7 - 1 LRM Revision 52 Licensing Requirements Manual SYSTEM Loop 21, Cold leg, LHSI Loop 22, Cold leg, LHSI Loop 23, Cold leg, LHSI Common, Cold leg, LHSI Loop 22, Hot leg, LHSI Loop 23, Hot leg, LHSI Common, Hot leg, LHSI Loop 21, Cold leg, SIACC Loop 22, Cold leg, SIACC Loop 23, Cold leg, SIACC Loop 21, Hot leg, RHS-A Loop 22, Cold legLoop 21, Hot leg, RHS-B Loop 23, Cold leg NOTES:RCS Pressure lsolation Valves 3.4.7 TABLE 3.4.7-1 (Page 1 of 1)RCS PRESSURE ISOLATION VALVESVALVE NO.25rS-107 25rS-108 25rS-109 25tS-132 25tS-133 25tS-128 25tS-129 25tS-130 25rS-151 25rS-148 25lS-145 25lS-147 25rS-141 25tS-1422RHS-M OV7O2A 2RHS-MOV7O1A 2RHS-MOV7zOA 2RHS-MOV702B 2RHS-MOV7O1B 2RHS-MOV72OB NOTES (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 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months as specified in SR 3.4.14.1.Beaver Valley Unit 2 3.4.7 - 2 LRM Revision 52 Licensing Requirements Manual 3.6 CONTAINMENT 3.6.1 Containment lsolation Valves LR 3.6.1 APPLICABILITY:As specified in TS 3.6.3.Containment lsolation Valves 3.6.1Each 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 2 3.6.1 - 1 LRM Revision 52 N ro c.o.cn c)t t J{ I {{ 3 Z v ZZ v OOOO (o (o co (o VVVV 3$sdE foc")=c\ @s4'\-X d dB 'a y = ={'b * $5fr a\$ t 6a$r ltll f-O(o ro ro tr) lr) oooo llll (L(LIL(L OOOO OOO()NNNN mmd)m vv\-\zz 8s 8* 8{ 8*vZ vZ vZ vZ Z N t"i ca c{c6 TTTTP NO+(o l()rJ)rOrI)cOO cq oP oI oP oX A ch=F == =F =3 q2 I # E[a ,[,a -*a [a n - -R i 8[ 8[ 8d-* 8I a d(O NO NO NO N N = R'0RoR0R0R O 3 0 0 C)t-,'8_cE (J.=xr-'-c uEo+,XXcP Al.IJUJoc o;#-Fo IENoO u,9+.o9-o OIIOCP t-aa2tL oo-}=l=v.t-to-e;;98.=o+gyrr-0E E E E-c E -- { o :/o o o oE cu ; ,qd Z O O O O.X u I rl E LU "! ? 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  • LiB=a 463= =t919 TLtt.O(.)ro Lo ro rf)OOOO rr oooo aaaa ltll 3383 p s NNNNZ.Z.c)f*aj --o i gE= 5:* EE f=El* sF 5:er H iru t=;l E f;l ftprr: irE =FEl E 8;3 **o oE-q *s 8 i: z a A Efr -*ot-'7 E T3 i*:\l:0 o- e: F'-r b= 5 HE i-'l r-fr o- o: cnF-tl rF qlu i EE iF#l?z sH F g; ba5l TF.LZ E 3, = t.ritu : Y o:= g .oE"7 -5= 5 BEsE#c0F z.z I ; ; ; *-'. >lro ! O O O d 3 u_t Jl o e q q q t= detl o @ A A i o- <lu:l-= 999 != ffi<31 a ft ft ft Htq aBSl= or6x 'L--l v' a .E.>co al c=!-r-b 6 oEEig" b b b EEb:z rF ,.'- ,{- g 3 e i; E:H ,Eg :i q d* ff H h H5E n^68_ = = = e;E R 5lFf n n A s;u !=31 a $; 7, ?,7, EE,e etHl 31 7 a a @ ,D;*; i ol.sl =E Er A; ft ft tu o='-=l -vo -oi 0l e* e&8 Yi.,lF ull+l ol f_zt=0)r 9.?Gco c o$o a c q)E c'$c o O OOOOMM crid<<<<<omuor-r-lo ro ro Lo l.() ro OOOOOO rrF-r oooooo aaaa@@tlllll a@aaaa aaaa@a NNNNNN o f c$a c o E c)!-'5 g q)x.O)c'a c q).(J J Licensing Requirements Manual3.6 CONTAINMENT 3.6.2 Containment SumpLR 3.6.2 APPLICABlLITY:MODES 1,2,3, and 4.CONDITION A. LR not met.LRS 3.6.2.1LRS 3.6.2.2 The containment does not have loose debris present that could betransported to the containment sump and cause restriction of the Emergency Core Cooling System pump suctions during LOCA conditions.Containment Sump 3.6.2 COMPLETION TIME lmmediately FREQUENCY SU RVEILLANCE- NOTE .Only required to be performed if LRS 3.6.2.2 is not met for 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 System pump 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 System pump suctions during LOCA conditions.Prior to establishing containment OPERABlLITY per Technical Specification 3.6.1At the completionof eachcontainment entry ACTIONSREQUIRED ACTION A.1 Apply the provisions ofLR 3.0.3.LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2 3.6.2 - 1 LRM Revision 52 Licensing Requirements ManualSteam Generator Pressureffemperature Limitation 3.7.13.7 PLANT SYSTEMS 3.7.1 Steam Generator Pressure/Temperature Limitation LR 3.7.1 The pressure of the primary and secondary coolants in each steam generator shall be < 200 psig.APPLICABILITY:

Whenever the temperature of the primary or secondary coolant in theassociated steam generator is < 70'F and the primary or secondary systems of the associated steam generator arecapable of being pressurized. CONDITION COMPLETION TIMEA. LR not met.30 minutesPrior to increasing its temperatures above 200"FSU RVEILLANCE FREQUENCY LRS 3.7 .1 .1 Verify the pressure in each side of the steam generator is < 200 psig.Once per hour ACTIONSREQUIRED ACTIONReduCe the steam generator pressure of theapplicable side to< 200 psig.AND4.2 Perform an analysis todetermine the effect of the overpressurization on the structural integrity of the steam generator. Determine that the steam generator remains acceptable for conti nued operation. LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2 3.7.1 - 1LRM Revision 52 Licensing Requirements Manual3.7 PLANT SYSTEMS 3.7 .2 Flood Protection LR 3.7.2 APPLICABILITY: At all times.LRS 3.7 .2.1 LRS 3.7 .2.2 Flood protection shall be provided for all safety related systems, components and structures when the water level of the Ohio River exceeds 695 Mean Sea Level at the intake structure. Flood Protection 3.7.2 FREQU ENCY24 hours2 hours SU RVEILLANCE When 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. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Water level at the intake structure above elevation695 Mean Sea Level.A.1 Install and seal the flooddoors in the intake structure. 8 hours B.- NOTE -Only applicable in MODES 1 , 2, 3, and 4.Water level at the intakestructu re above elevation695 Mean Sea Level.8.1 Confirm the actual Ohio River level is < 700 MeanSea Level. AND8.2 Verify the forecasted peak Ohio River level is < 700Mean Sea Level.lmmediately 2 hours C. Required Action and associated Completion Time of Condition A or Bnot met in MODES 1, 2, 3, and 4.C.1 Apply LR 3.0.3. lmmediately LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2 3.7.2 - 1 LRM Revision 67 Licensing Requirements Manual3.7 PLANT SYSTEMS 3.7.3 Sealed Source Contamination LR 3.7.3 APPLICABILITY: At all times.CONDITION Sealed source removable contamination in excess of the limit.Sealed source or fission detector feakage tests reveal the presence of> 0.005 microcuries of removable 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 Contamination 3.7.3 COMPLETION TIME lmmediately lmmediately lmmediately On an annual basis A.B.ACTIONSREQUIRED ACTIONA.1 Withdraw the sealedsource from use. AND 4.2.1 Initiate action todecontaminate and repair the sealed source.ORA.2.2 lnitiate action to dispose ofthe sealed source in accordance withCommission Regulations. 8.1 Prepare and submit aSpecial Report inaccordance with 10 CFR 50.4.Beaver Valley Unit 2 3.7.3 - 1LRM Revision 52 1.2.Licensing Requirements ManualSealed Source Contamination 3.7.3 LICENSING REQUIREMENT SURVEILLANCES- NOTES .Each sealed source shall be tested for leakage and/or contamination by the licensee or other 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 test sample.Startup sources and fission detectors previously subjected to core flux are excluded fromthe following test requirements. SURVEILLANCE FREQUENCY LRS 3.7.3.1 For 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 3.7.3.2 For stored sealed sources and fission detectors not inuse, verify removable contamination within the limit.LRS 3.7.3.3 For sealed sources and fission detectors transferred without a certificate indicating the last test date, verify removable contamination within the limit. LRS 3.7.3.4 3.For sealed startup sources and fission detectors, verifyremovable contamination within the limit.6 monthsPrior to use ortransfer to another licenseeunless tested within the previous 6 monthsPrior to use31 days prior tobeing installed in the core or exposed to core flux ANDFollowing repairor maintenance tothe sourceBeaver Valley Unit 2 3.7.3 - 2 LRM Revision 52 Licensing Requirements Manual3.7 PLANT SYSTEMS 3.7.4 Snubbers LR 3.7.4 All snubbers shall be FUNCTIONAL. APPLICABILITY: CONDITION One or more required snubbers Nonfunctional. Snubbers 3.7.4 A.. 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 on which 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 50.67 limits.COMPLETION TIMEln accordance withTable 3.7.4-1ln accordance withTable 3.7.4-1 ACTIONS REQUIRED ACTIONA.1 Replace or restore the Nonfunctional snubber(s)to FUNCTIONAL status. AND4.2.1 Perform an engineering evaluation per Paragraph ISTD-1800 of the ASMEOM Code on the supported component. ORBeaver Valley Unit 2 3.7.4 - 1LRM Revision 67 Licensing Requirements Manual ACTIONS continued CONDITIONLRS 3.7.4.1 Snubbers 3.7.4 SURVEILLANCE Each snubber shall be demonstrated FUNCTIONAL inaccordance with Subsection ISTD, "Preservice andlnservice Examination and Testing of Dynamic Restraints (Snubbers) in Light-Water Reactor Power Plants," ASME OM Code 2001 Edition up to and including the 2003 Addenda. Preservice and inservice examination 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 and Standards.") COMPLETION TIMEln accordance withTable 3.7.4-1 FREQUENCY In accordancewith SubsectionISTD of the ASME OM Code 2001 Edition up to and including the 2003 AddendaREQUIRED ACTION A.2.2 Declare the supported system inoperable/ Nonfunctional (as applicable) and follow the appropriate ACTIONS forthat system. LICENSI NG REQUIREMENT SURVEI LLANCESBeaver Valley Unit 2 3.7.4 - 2 LRM Revision 67

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IL (f)Q (L I@I C)N m oO O c.)(L U)a o_I U)r C)GI X O (o CO L U) c/)o_I a=O N X cf)N (o o_a U)0_I a I O N (J lr)@CO (L U)U)(L I U)I C)c{o)l-@(L U)U)(L I U)c)o N o)N O (L a U)(L l C'o l.TJ N m O) N O (L a a o_I O o LrJ N c)O o_U)a (L t (, O LlJ N c)c9 O rL U)U}(L l o o uJ N N$O (L a a (L I CD o Lu c!m N.f, O (L a@(L I C)o tu C\lO)O O (L a a 0_I trl=IL N O r O o_a ct)(L I u=TL N$l.f)c)TL@@o_l ul=LL c{m s r()ca o_a U) TL t trl=TL N O O o_U)0 o-t a=].L N c\o O TL a a (L I a=TL N gn O l'-* c.i f c U)@t:f o 5 U)ul F-Z:o.*E oiJ NJ.r O-o)>so 3O To$[l JF;<UR J\J ma s?o z a t uJ m m f z a (s f c co a P c 0)E a)t-'5 ct o t O}c'a c o.9 J $ro c.9.9.o t t J gn Of-I c.i f c a a t f o 5 (f)trlF-z:o.*-E oix CDJ n't L Or>so 3O To\f, tlJ JF;<,,.O:o CO CD s?o z a t LrJ co m f z a N.=c l_o$L o$O!o o f c a P c o E o l-'=ct q)tr_o c'a c c).9 J o Ee cL.=EF o ()iE (Y)=o3 3<o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o o nt E o m E o o U'N (9 a*CN O t N od@N*U)=IL N c o q)=q)m c!C}ct)+(/)C)t N od@N*U)=LL C\t c c)o 3 o m r N o CN.*U)C)v.N*@N*(f)=tL N c o c)=a)m m r N o@*@c)E.c!od O)c!*U)=LL N c q)CI 3 c)m C)r c!o a.*a O t N*O cr)*a=LL N c q)c)E o m c\o U)l.a O t N od co N*U)=tL c!c o o E o co rO-t U)=tL N od rr)N I U)=TL N c (l)o 3 o co co rO I*c/)=IL N od (o N I a=tL N c o o E q)co d)lf)I.t U)=TL c!*(0 N!@=LL N c Q)c)3 0)co c\I a=LL N od co o)$C)tL*a=tL N c q)o E o fi)cf)F*I X c (l)(L E c O od r N o@*a O t N c c)q)3 q)m cf)I X c 0)TL E c O od r N o U)*@O t N c o q)3 o m cf)t\I X c c)o_E c O*N ()a*U)O E.N C CI o=o m ce F-I X c o (L E c C)od r N (, a*a O E.N c o q)=c)m co f.-I X c o o-E c O oU r N O a*@O t N c Q)O 3+t o m ct)T\I X c a)o-E c O*N o cr)+a O v.CN c q)o 3 o m c)t-I X c o L E C C)od N c)(f)+a O E.N c o CI E CI m\f, f-I X c q)o_+)E c O od co F-N O a*@O v.N c q)0)3 0)m$!X c o (L E c O od m r N (9 U)+a O t N c o)c)3 o m$I X c 0)o-E c O o0 m N o (f).t(U)C)v.N c c)c)3 o m o (u o o J c (!(L N O a o#q).g E o-:f a..>LL (o!-N C)a#q),g o-o-=a LL (o N C'a o a).s o_o_f a IL (0 r m r N o U)o q)._c o_o_f U)=tL (0 r O N (9 a o o.E o_o_f a LL (o r N C'(f)o 0).g o-o_f a=TL (0 r N o a o q).g o_o-f a->IL (o m r N C'a o q).s E o-f a TL (o co c\(, U)o O.tr o-o-f a LL (o c)N (, (f)o c).c o_o_f a LL (o N O Q E o r-o.g E$c)@.g N c)N (, a E o L 9-o.E E Q)a.c N cf)r N O (f)E!-o.=E (u a)a.g$N co N O U)E o t-q-o.g E$c)@.E (u c! c)N O a E o l-r+-c).g E$q)a.g N cr)r N TD a E o L a).g E al1 c)a.s$N co r N O a E o t-r+-.g E CU O U).g N CD m N (, a E o t-rts o.E E$o a.g$N c/)m r c!o a E o L c).E E$c)@.E$c!cq m r N (, U)E o t-c).g E$a)v).E o N c9 o (E o o J 6 o o lI.m N O O o_a@o_I a=LL N cr)O O o_a@o_I@=LL N m cr)O TL (f)a o_I a=TL N LO O o (L U)a o_I U>=TL N (o O O o_a a (L I a=tL N N O TL U)ct)(L I a=TL N (o O o-U)a o_I CN=TL N (o cf)O 0_U)a (L 1 a=IL N o)cf)O o-a a L I a=tL N O (0 O o_a a (L I a=TL N O O o_a a o_I@ CN N N O O o_a a o_I a a N co N O O (L a a L I a a N CA O O o_a a (L I a U)N co cr)O O o_ct)a o_I a a N rd)O O (L U)a IL I@@C\I (o O O (L a a (L I a a c!T\O O IL a a (L I a a N@O O (L U)a fL I a a N m@O O o_a cl>o_]v)U)N LO I n N c.j $lr)c.9.9.0)tr t J (o I n\c/)N=c f_0)$L CI c0 O co o Ee cL.=EF o (J iE (Y) =o3 9<o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z a o o E o m E o o.n t.c)f-I X Q)o_E c O od O N C}U)*a O tr N c o q)E c)co lJ)l-I X c c.)(L E c C)od C)r N c)a d a O t N c CI 0)3 (l)co r{)t-I X c o o_E c c)od O c\(D a*a O t N c q)o=#o m lf)t-I X c CI (L E c O*C)N C'a*a O t N c q)o E c)m E r E o q)a@cf)*o*(f)@c!c o o=o co E r E o c)a@ce od O r-o J(ct)@N c o c)B c)d)E I E$g a@co od r O o.l U)a N c o o 3 o m'ro I E o o a@cf)06 O o*a a N g q)o 3 o m!I E (U o a o cf)oo O o*a a N c o o 3 o m E-E o o U)@cf)od O r o*U)a c!c q)c)3 Q)co 3 r E$0)U)@cf)od.O, o*a a N c o o 3+J o m t-!I E$(l)U)@cf)od-O o*U)a N c q)o=CI m t-io I E N c)(f)@cf)oo r O o*@a N c c)q)3 c)m E I E (g o+, a@cf)od m O r o*(f)@N C Q)q)E o m c I E (tr c)+t a@cf)oU m O o*a a N c o o=q)co E I E$c)U)@cf)od m O o.*cf)@C\c q)o=0)m L ro I E$o a*(f)od m O o*U)a N c (l)o 3 o m t-E I E$c)a@cf)od m O r o+c/)(f)N c o c)E o m E:E E$o@@cf)od co o-o*a a N c (I)o=P o m o (U o o J (!rL O r N o a E o t-q-CI.E E (U G)a.E o c!c)O N c, Q E o t-a).g E o C)a.g o N cr)O N (9 ct)E L 5.E E fr CI CN.g o N cf)O N C)a E o L q-q),=E (0 q)U)._c (o N c)r N o a E o l-tF o.s E$o a.E N cf)N o U)E o t-o.g E o c/).g N N cf)N O a E o t-o.E E o 0)U).c_(o N co N O a E o!-q).E E o 0)CI._c CU N cf)r N O (f)E o q).s E o q)a.c G N cf)r c\I (, a E o l-o.5 E$q)v).E o N cf)r N o a E o!-rF q).g E (o q)a.c CO N cf)N C}a E o!-r.l-o._c E CU CI#a.c o N co c{c)a E o (l).g E$(l)v a.E o N cf)m N C)a E o t-!F CI.5 E$0)a.5 o N c9 m c!o (f)E o!-o.c E (U q)+t@c'(E N cf)c0 N O a E o t-o.E E$c)a.g$N Cq m N O a E L o.g E (u o (f).E o c{cf)m r N O a E o rF o.=E$o a.c$N c)d)N O a E o!-o.g E$q)a.g Co N c)o ([o o J G o o lJ.o)O IL a a o_I a a N r O IL Q (f)(L I U)U)N m-\-O (L a a (L I U)(f)N N O o_a a o_I a@C\.1 c)O (L U)@o_I U)(f)N N O 0_a a (L I a U)N@O (L U)U)(L I a a N co@O\-o-@a (L I U)@N O\-o_a a IL I cf)a c{r o_a a o_I cf)a N c0 r CL U)a o_I a a N N r fL a a (L 1 cf) U)N m N o_a U)(L I a a N$N (L a U)o_I U'a N@N o_a a o_I a a N m@c!r o_U)a (L I U)U)N O c.)L a a o-I v)a N co r o_@ a IL I U)a c\co cf)r TL@@o_!U}CN N E..q O l-* c'j:l c a U)x.f o 5@l.rlF-Z-o.,- E oiJ$J.r O-o)>so 3O TO r [lJ JF;s tUR ma fl?o z a t LlJ c0 co f z U)$f c N a P c c)E (l)t-'5 u 0)t o)c'a c q).9 J $r.()c.9.9, q)tr t J l-I n f*c.j N=c f_q)G t-o N o)m o Ee cL.=EF o o@iE (Y) =o&3<o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o o$E f o o E o+, o U'L E I E (U o U)@cf)od m O o*a CN c\l c o Q)=q)co t-c-E (u o@@co oo m O r o*a a N c Q)Q)3#a)m t-c I E$g@@c9 o0 C)O o.r a CI c\l c c)CI=P q)m!I E o c)a*c9 od O O o*a a N c q)o 3#0)m E I E N o Q o cf)od O r O o*U)a N c c)c)3 0)co p I E o c)a@co od C)-O o*U)a N c 0)o E o m a I E$g U)@cr)oU O r O o*@a C\I c q)a)E q)m E-E o o a O cf)od O-O o+U)v)N c q)q)E o ao E I E N o U)o cf)od O r O o+v)@N c o o 3 O co l-p I E N 0)#U)@cf)od O o r o+a a N c o o E 0)m o E$o-rF o E c o a o 3 o E q)c o N Q)E$o I ll-o ro c (l)a o=o o-c C)(u#c)E G o-rF o c c o a (U c)o+', E q)-c o$.{J+-, N c!h J(I.IJ=TL N od@*U)U)N-o CI 3 0)co o)o)r*(o o)r*00 In ol;^a=N>\Nr rlO dfl Qco EO CIaCO crt oo o)*m O o+c/)U)g N od m N (L*a a g N c o o E o m o o*a a a N od N (L*U)0 o N C 0)q)3 c)m*o)*O o*(f)U)g N*N IL*a U)g N c o O 3 O m o G'o o J G o-m N O U)E o t-O.=E N c)U).c o c{co m N o a E o!-rts c).S E$o-FJ v).c$cv CD O N O@E t-\F CI.g E$q)U).g (u c!c)()N O U)E O t-rts O.g E$0)a.c (u C\co O N o U)E o!-o.E E G o U).E o N c)O N C)a E o L q).g E o c)a.g d c!c9 ()c!O (t)E o t-F q).g E$c)a.c o N CD O e\t O a E o t-q-c).g E (o O'P a.g o c!co O N O a E o t-o.5 E$o U).g (u N cf)O N (9 a E o l-q).tr E (U q)a.S o N!-o (o c)=E$q)a@c)o c t-P a q)v.L c)E$q)r E (U o P a oo co o'tJ.E$i-a c)t!-c)$CI-E$0)a@co o c.(u!-P a (l)t o_E=(L=tL X f o q).5 o-o-:f a E:YN*YN 0t o-E f (L=tL X f o Q).g o-o-f, a E R o.r.YN aa-o c c)o)G-c o.9!a=@m N o_E f o_a@o o)c c)o)t-N O.9 c cr)=a N o-E f (L U)(f)g c)c O o)$-c C).9 E a=a r GI o_E:f TL (f)a o o (!o o J (U o a lJ.N cf) \-(L U)cf) o_I (f)U)N m N cf)r-o_cn a o_I U)U)N$$r 0_U>a o_I U)a N N$r rL a a o_1 U)U)N m F-$L U)a (L I a a N O)$I a@(L r a a N O rr)r 0_a@IL l a a N m O ()0_U)a o_I@a N r rr) r o_(f)@o-1 a a N m rlr)(L a U)IL 1 a a N$(o (L a U)(L I a U)N rr)(o r (L U)u)o_I a a N@(o (L@U)(L I U'a N (o l()$TL a a IL l@a N (o N\t&U)a (L I U)a C\r O r o_ v)@o_t a ct)a N O)N-o_U)a 0_I@@o N r cf)r o_a U)o_, cf)a a c!gn Of-* c'j iJ c U)a t f o 5 a lll F-z=o.-F oix loJ qO-o>Fo=O 5o$ lrl JF o"j<.,,O fo m-u)F<?o z (f)t tu c0 gj f z@$f c o a c q)E q)!-'5 (t c)t o)c'a c a).9 J $lr).o.cn o tr E.@I n\ca N=c=_(l)(o L o$o m o Ee cL.=EF o o c\N c!r*iE (Y) =oa 3<o z (t)o a o o 0)o z o z o z o z o z o z o z o z o z o z o z o z o z o z o z o o G E c J o o E o o a OD*m o o*a a g N od o N (L.x a a a c\c 0)o E q)co od m o N;o s<ao 91 crt R>6F ES sg m O N o*U)a g N od F cf)=t c (l)o E q)m ltr)ro$O (L*U)C)t N o O)c)E o 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z a CU f c$a c CI E C)!-'=o o t o)c'a c o.9) rf, ro c.9.9.o t t J EN Of-* c'j f, c a a t f o 5 a ul tr Cz-Q or-t5'o_(D-E6 go-O+Fr\k coo u1 o ia=a i<o z cf)t ul 00 ao f z@N=c f_9 t-o$c)c0 o:l c$a c O E O f o o t o)c'a c q).9 J$I n\co o Ee cL.=EF o (J@iE (Yt =o3 3<o z o z o z o z o z o z o z o z o z o z o z o o (E E o o E o o a od O&UJ C)t48 (/) r tr>o.r o cE (D*aA E=aa6 e.t ()&r-r-r o b3 (/) r t>c.t O cE G)*aA E=aa MN od O N ulo b3 (f) -(>ero cE Q)+$a E=aa6 o.t o0!-o t o-c od rr)O o*U)=a N c o o 3 o m t-c)tr (D-c.*rr)O r o*U)=U)N c o o 3 o m od&I.IJ <b8 (/) -t>c.t o cE O*aa E=@a6 crt od N ru<b3 (f) r t>elo cE O*aa E=aa Eor N r.rJ <b3 U)-t->No cE (l)*aa E=av)MN oo m N IIJ M b8 (l) -t>elo cE O*au)E=a)a 6or od o tr o*co lr)O o*@=a c!C o 0)E c)m c)t CI od m rf)o o*a=U'c\c CI CI=o c0 o G o o J c s o-O F-c{X:tr (f)0 t E o!-\+-\v c CI!-tT{-c.9 c a=U)CO O N X I a a t-E o L rts CI.g o!--c O.9 E v)=U)(o-O r N X I U)U)t E o rF o.E o o)t-\U-c.C).9!a=a (o r N x I a (/)t E o l-rF q)c q)o)t-$-c O.a E a=v)(0 r N X r a a E.E o t*o c q)o)l-o-c ().9 o a=a (o N x I CN v)E.E o t-rF o c a)Ct)t-o-c o.2 c U)=U)(o N x I a U)t E o c).tr c)O)t-$-c C).a!a=a (o r N X I U)a t E o t-rF q)c c)o')t-Cg-c (J.9 E U)=a (0 co c\X-U)U)t E o!-o.E Q)o)!-(u-c C).9.E@=a (o-m N X I a@t E o t-r+-o.E o l-$-c.().9. a a=a (o r co-N X=U)@t E o!-rF CI c c)o)!-$-c o.2 E U)=U)CO o (E o o J E o o ll O l-f.-o_Q a (L 6=a N m O N N fL a a IL I@=a N t-l-o_a CI o_I a=a N N l-F.-(L a a (L I a=a N m N l-l'-L (f)Q TL I a=@c!cc f,*1'-o_@a o_I a=a N m cv)N N (L U)U)(L I a=U)N.f, f-t-o_a U) IL!a=U)N O c/)@o_a a IL I U)=U)N N cf)@(L (/)a&I a=@N m N CD@o_a a IL I ct)=0 N Licensing Requirements Manual3.7 PLANT SYSTEMS 3.7.5 Standby Service Water System (SWE)LR 3.7.5 APPLICABILITY: MODES 1 , 2, 3, and 4. CONDITION Required SWE subsystem Nonfunctional. Required Action and associated Completion Time not met.LRS 3.7.5.1 LRS 3.7.5.2Standby Service Water System (SWE)3.7.5 COMPLETION TIME 7 days lmmediately FREQUENCY 92 days 18 months on a STAGGEREDTEST BASISAt least one of the two standby service water subsystems shall be FUNCTIONAL. A.B.SURVEILLANCE Verify that the required SWE pump develops at least 109 psid differential pressure, while pumping through itstest flow line.Start the required SWE pump, shut down one Service Water System Pump, and verify that the SWE subsystem provides at least 8584 gpm cooling water to that portion of the Service Water System under test forat least 2 hours.ACTIONSREQUIRED ACTIONA.1 Restore at least onesubsystem to FUNCTIONAL status.8.1 Apply LR 3.0.3. LICENSING REQU I REMENT SURVEILLANCESBeaver Valley Unit 2 3.7.5 - 1LRM Revision 69 Licensi ng Requirements Manual3.7 PLANT SYSTEMS 3.7.6 Explosive Gas Mixture LR 3.7.6 Explosive Gas Mixture 3.7.6 The concentration of oxygen in the waste gas holdup system shall be limited 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 Specification 5.5.8, "Explosive Gas and Storage Tank Radioactivity Monitoring Program." A.APPLICABILITY:At all times.CONDITION Concentration of oxygen inthe waste gas holdup system > 2o/o by volume but < 4% by volume. Concentration of oxygen in the waste gas holdup system > 4o/o by volumeand the hydrogen concentration > 4% by volume.COMPLETION TIME lmmediately48 hours lmmediately lmmediately B.ACTIONS REQUIRED ACT]ON A.1 Suspend all additions of waste gases to the gaseous waste decay tank.ANDA.2 Reduce the concentrationof oxygen to < 2o/o.B.1 Suspend all additions of waste gases to the affected tank.AND8.2 Reduce the concentration of oxygen to S 4o/o by volume.Beaver Valley Unit 2 3.7.6 - 1 LRM Revision 52 LICENSING REQUIREM ENT SURVEILLANCES Licensing Requirements ManualLRS 3.7.6.1 SURVEILLANCE The concentrations of oxygen in the waste gas holdupsystem shall be determined to be within the above limitsby continuously monitoring the waste gases in the waste gas holdup system with the oxygen monitors required OPERABLE by LR 3.3.12 or monitoring in conjunction with its associated ACTIONS.Explosive Gas Mixture 3.7.6 FREQUENCYln accordance with LR 3.3.12 Beaver Valley Unit 2 3.7.6 - 2LRM Revision 52 A.B.Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS)3.7.7 3.7 PLANT SYSTEMS 3.7 .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 TIME One SLCRS exhaust air filter train Nonfu nctional.7 days Required Action and associated Completion Time not met.lmmediatelySU RVElLLANCE FREQUENCY LRS 3.7 .7 .1 Initiate, from the control room, flow through the"standby" HEPA filter and charcoal adsorber train and verify that the train operates for at least 15 minutes with the heater controls operational. 31 days ACTIONSREQUIRED ACTION A.1 Restore the Nonfunctionaltrain to FUNCTIONAL status.B.1 Apply LR 3.0 3. LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 3.7.7 - 1LRM Revision 67 Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS)3.7.7 LICENSING REQUIREMENT SURVEILLANCES continued SURVEILLANCE FREQUENCY LRS 3.7.7.2 Each SLCRS exhaust air filter train shall bedemonstrated FU NCTIONAL:By verifying that the charcoal adsorbers remove> 99.95% of a halogenated hydrocarbon refrigerant test gas when they are tested in-place in accordance with ANSI N510-1980 while operating the 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-place in accordance with ANSI N510-1980 while operating the ventilation system at a flow rate of 57,000 cfmt 10olo.Within 31 days after removal, subjecting the carbon contained 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 obtained from test canisters shall be taken with a slotted tube sampler 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 3 Each SLCRS exhaust air filter train shall bedemonstrated FU NCT]ONAL:a. By verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banksis less than 6.8 inches Water Gauge while operating the 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 a Containment lsolation - Phase "A" signal in lessthan 5 minutes. a.b.c.18 months AND After eachcomplete or partialreplacement of aHEPA filter orcharcoal adsorber bank AND After any structuralmaintenance on the HEPA filter or charcoal adsorber housings AND Following painting, fire or chemical releasein any ventilation zone commun icating with the system 18 months Beaver Valley Unit 2 3.7.7 - 2 LRM Revision 67 Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS)3.7.7 LICENSING REQUIREM ENT SURVEILLANCES continued SURVEILLANCE FREQUENCYLRS 3.7.7 .4Verify that the air flow distribution to each HEPA filterand charcoal adsorber is within x 20% of the averaged flow per unit.LRS 3.7.7.5 Perform LRS 3.7.7.2c.After initial installation ANDAfter any maintenanceaffecting the flow distribution Once per 4 months ofsystem operationBeaver Valley Unit 2 3.7.7 - 3 LRM Revision 52 Licensing Requirements Manual125V D.C. Battery Banks Maintenance Requirements 3.8.13.8 ELECTRICAL POWER SYSTEMS 125V D.C. Battery Banks Maintenance RequirementsThe 125V D.C. battery banks (2-1,2-2,2-3, & 2-4) shall be maintained in accordance with LRS 3.8.1.1 and LRS 3.8.1.2.When the battery bank(s) are required to be OPERABLE in accordance with the Technical Specifications. CONDITION COMPLETION TIMEA. LR not met.lmmediately SU RVEILLANCE FREQUENCY LRS 3.8.1.1 3.8.1 LR 3.8.1 APPLICABILITY: LRS 3.8.1.2 Verify the following:Verify no visible corrosion at either terminals orconnectors. or the connection resistance of these items are within design specifications. a.The cells, cell plates, and battery racks show novisual indication of physical damage or abnormal deterloration,The cell-to-cell and termrnal connections are clean,tight, and coated with anti-corrosion material, andThe resistance of ceff-to-cell and terminal connections are within design specifications. Once per 92 days ANDWithin 7 days after a battery discharge with battery terminalvoltage below1 10V, or battery overcharge with battery terminal voltage above 1 50V1B months b.c.ACTIONSREQUIRED ACTION A.1 Apply LR 3.0.3. LICENSING REQU I REMENT SURVEILLANCESBeaver Valley Unit 2 3.8.1 - 1LRM Revision 63 3.8.2 LR 3.8.2 Licensing Requirements ManualEDG 2000 Hour Rating Limit 3.8.2 3.8 ELECTRICAL POWER SYSTEMS Emergency Diesel Generator (EDG) 2000 Hour Rating Limit The auto-connected loads to each EDG shall not exceed the 2000 hour rating limit of 4,535 kw. APPLICABILITY: When the EDG is required to be OPERABLE in accordance with the Technical Specifications. CONDITION COMPLETION TIMEA. LR not met.lmmediately SURVEILLANCE FREQUENCYLRS 3.8.2.1 Verify that the auto-connected loads to each EDG do not exceed the 2000 hour rating. 18 months during shutdown ACTIONS REQUIRED ACTION4.1 Apply LR 3.0.3. LICENSING REQUI REMENT SURVElLLANCESBeaver Valley Unit 2 3.8.2 - 1LRM Revision 52 3.8.3LR 3.8.3 Licensing Requirements ManualMain Fuel Oil Storage Tank Maintenance Requirements 3.8.3 3.8 ELECTRICAL POWER SYSTEMS Main 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. CONDITION COMPLETION TIMEA. LR not met.lmmediately SURVEILLANCE FREQUENCY LRS 3.8.3.1 Drain each main fuel oil storage tank, remove the accumulated sediment, and clean the tank using a sodium hypochlorite solution or other appropriate cleaning solution.10 years ACTIONSREQUIRED ACTION 4.1 Apply LR 3.0.3.LICENSING REQUIREMENT SURVEILLANCES Beaver Valley Unit 2 3.8.3 - 1 LRM Revision 52 Licensing Requirements ManualCrane Travel - Spent Fuel Storage Pool Building 3.9.13.9 REFUELING OPERATIONS 3.9.1 Crane Travel - Spent Fuel Storage Pool Building LR 3.9.1Loads in excess of 2450 pounds shall be prohibited from travel over fuel assemblies in the storage pool.APPLICABILITY:With fuel assemblies in the storage pool.CONDITION COMPLETION TIMEA- LR not met, lmmediately SU RVEILLANCE FREQUENCY LRS 3.9.1 .1Crane interlocks and physical stops which prevent crane travel with loads in excess of 245A pounds over fuel assemblies shall be demonstrated FUNCTIONAL. 30 days prior tocrane usewhenever the crane has been idle for more than30 days ACTIONSREQUIRED ACT]ONA.1 Place the crane load in asafe condition. LICENSING REQUIREMENT SURVEILLANCESBeaver Valley Unit 2 391-1LRM Revision 67 Licensing Requirements Manual3.9 REFUELING OPERATIONS 3.9.2 Manipulator Crane LR 3.9.2 APPLICABlLITY: CONDITION Requirements for craneand/or hoist FUNCTIONALITY not met A.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 assemblies having: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, and 2. 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 reactor pressure vessel.COMPLETION TIME lmmediatelyManipulator Crane 3.9.2 ACTIONS REQUIRED ACTION A.1 Suspend use of any Nonfunctional manipulator crane and/or auxiliary hoist from operations involvingthe movement of control rods and fuel assemblies within the reactor pressure vessel.Beaver Valley Unit 2 3.9.2 - 1LRM Revision 67 Licensing Requirements Manual LRS 3.9.2.1 LRS 3.9.2.2 SURVEILLANCEEach manipulator crane used for movement of fuelassemblies within the reactor pressure vessel shall be demonstrated FUNCTIONAL by performing a load testof at least 3250 pounds and demonstrating anautomatic load cut off when the crane load exceeds 2700 pounds.Each auxiliary hoist and associated load indicator usedfor movement of control rods within the reactor pressure vessel shall be demonstrated FUNCTIONAL by performing a load test of at least 700 pounds.Manipulator Crane 3.9.2 FREQUENCYOnce within 150 hours prior tothe start of fuel assembly movementOnce within150 hours prior tothe start of controlrod movement LICENSI NG REQUIREMENT SURVEI LLANCESBeaver Valley Unit 2 3.9.2 - 2LRM Revision 67 Licensing Requirements Manual3.9 REFUELING OPERATIONS3.9.3 Decay TimeLR 3.9.3 APPLICABILITY: CONDITION Reactor 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 pressure vessel.COMPLETION TIME Decay Time 3.9.3 lmmediately FREQUENCY Prior tomovement ofirradiated fuel assemblies in the reactor pressure vessel SURVEILLANCEThe reactor shall be determined to have been subcritical for at least 100 hours by verification of thedate and time of subcriticality. ACTIONSREQUIRED ACTION 4.1 Suspend all operations involving movement of irradiated fuel assembliesin the reactor pressure vessel.LICENSI NG REQUIREMENT SURVEILLANCESBeaver Valley Unit 2 3.9.3 - 1 LRM Revision 52 5.1 5.0 ADMINISTRATIVE CONTROLS Core Operating Limits Report This Core Operating Limits Report provides the cycle specific parameter limits developed in accordance with the NRC approved methodologies specified in Technical Specification Administrative Control 5.6.3. Licensing Requirements ManualCore Operating Limits Report 5.1SL 2.1.1 Reactor Core Safetv Limits See 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 times when 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 limit specified 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 Limits The 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 D bank, in that order.Overlap Limits(2) - Overlap shall be such that step 129 on banks A, B, and C corresponds to step 1 on the following bank. When C bank is fully withdrawn, 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 SDM requirements (e.g., MODE 1 Required Actions to verify SDM) that are not within the applicability of LCO 3.1.1, SHUTDOWN MARGIN (SDM).As indicated by the group demand counter 5.1.1 5.1 .2 5.1.3 5.1.4 5.1.5 c.d.(1)(2)COLR Cycle 18LRM Revision 80Beaver Valley Unit 2 5.1 -1 Licensing Requirements Manual 5.1 Core Operating Limits ReportCore Operating Limits Report 5.1 5.1.6 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 l IcPolF.'G) =l=l.x(z) forP< 0.5 1'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 0815 r$ 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 at part power conditions.The Fq(Z) penalty function, applied when the analytic Fq(Z) function increases from 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, = 1.62 PF = 0.3 AH r-} - THERMAL POWER r RATED THERMAL POWER 5.1.8 LCO 3.2.3 Axial Flux Difference (AFD)The AFD acceptable operation limits are provided in Figure 5.1-4.COLR Cycle 18 LRM Revision 80 Beaver Valley Unit 2 5.1 -2 Licensing Requirements Manual5.1 Core Operating Limits ReportCore Operating Limits Report 5.1 5.1.9 LCO 3.3.1 Reactor Trip System Instrumentation - Overtemperature and Overpower AT Parameter Values from Table Notations 3 and 4 a. Overtemperature AT Setpoint Parameter Values: ParameterOvertemperature AT reactor trip setpoint Overtemperature AT reactor trip setpoint Tavg coefficient Overtemperature AT reactor trip setpoint pressure coefficient Tavg at RATED THERMAL POWER Nominal pressurizer pressure Measured reactor vessel AT lead/lag time constants (* The response time is toggled off to meet the analysisvalue of zero.) Measured reactor vessel Measured reactor vessel time constantsMeasured reactor vessel constantAT lag time constantaverage temperature lead/lag average temperature lag time ValueK1 < 1.239 K2 >_ 0.0183/'FK3 > 0.001/psia T', < 574.20p(lP'> 2250 psia Tr = 0 sec*Tz= A sec* ts < 6 secs ta > 30 secs rs < 4 secs ra < 2 secs f (Al) is a function of the indicated difference between top and bottom detectors 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 ore percent RATED THERMAL POWER in the top and bottom halves ofthe core respectively, and Qt + Qu is total THERMAL POWER in percent of RATED THERMAL POWER. (1) T' represents the cycle-specific Full Power Tavg value used in core design.COLR Cycle 18LRM Revision 80 Beaver Valley Unit 2 5.1 -3 Licensing Requirements Manual5.1 Core Operating Limits ReportCore Operating Limits Report 5.1 (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 at RATED 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 temperature K5 = 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 secs constantMeasured reactor vessel average ra < 2 secs temperature 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 2 5.1 -4 Licensing Requirements Manual5.1 Core Operating Limits Report Core Operating Report 5.1 5.1.10 LCO 3.4.1. RCS Pressure, Temperature, and Flow Departure from Nucleate Boilinq (DNB) Limits Parameter Reactor Coolant System TavgPressurizer Pressure Reactor Coolant System Total Flow Rate lndicated Value Tavg < 577.8F1d)Pressure > 2214 psia(2)Ffow > 267 3A0 gp*(t)(1) The Reactor Coolant System (RCS) indicated Tavg value is determined by adding the appropriate 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 control operation and verification via control board indication. The RCS total flow rate includes allowances for normalizatio'n of the cold leg elbow taps with a beginning of cycle precision RCS flow calorimetric measurement and verification on a periodic basis via control board indication. (2)(3)COLR Cycle 18LRM Revision 80Beaver Valley Unit 2 5.1 -5 Licensing Requirements Manual 5.1 Core Operating Limits ReportCore Operating Limits Report 5.1 5.1.11 LCO 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 a 50 ppm conservative allowance for uncertainties.COLR Cycle 18 LRM Revision 80Beaver Valley Unit 2 5.1 -6 Licensing Requirements Manual 5.1 Core Operating Limits ReportCore Operating Limits Report 5.1 5.1.12 References1. WCAP-9272.P-A,WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY," July 1 985 (Westinghouse Proprietary).2. WCAP-8745-P-A, "Design Bases for the Thermal Overtemperature AT and Thermal 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 LOCA Analysis," 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 the LEFMfM 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 18 LRM Revision 80Beaver Valley Unit 2 5.1 -7 e 630 50 A IJ;6 F 6za Licensing Requirements ManualCore Operating Limits Report 5.1243s PSIA 2250 PSIA2000 PSIA LINACCEPTAB LE OPERATION ACCEPTABLE OPERATION0.2 0.4 0.6 0.8 r FRACTION OF RATED THERMAL POWER Figure 5.1-1 (Page 1 of 1)REACTOR CORE SAFETY LIMIT THREE LOOP OPERATION (Technical Specification Safety Limit 2.1.1) 1.4 t.2COLR Cycle 18LRM Revision 80Beaver Valley Unit 2 5.1 -8 Licensing Requirements Manual 225 200 175 150 125 100 75 50 25 c 3 (It c-c=a o-0)g z o E a o o_Y z m o o t Core Operating Limits Report 80 90 100 10 2A 30 40 50 60 7A PERCENT OF RATED THERMAL POWER Figure 5.1-2 (Page 1 of 1)CONTROL ROD INSERTION LIMITS AS AFUNCTION OF RATED POWER LEVEL//y ru;53,225\tl rlBANK C t---l l rc ,l//////7/4)--_l BA- lNKDI-////////F: 0)COLR Cycle 18 LRM Revision 80 Beaver Valley Unit 2 5.1 -9 Licensing Requirements ManualCore Operating Limits Report 5.1 I 06 Figure 5.1-3 (Page 1 of 1)FoT NORMALTZED OPERATING ENVELOPE, K(Z)COLR Cycle 18LRM Revision 80 Beaver Valley Unit 2 5.1 - 10 Licensing Requirements Manual L20 110'l nn 90 8o 70 ctu 50 40 30 20 10 U- 60-50 -40 Core Operating Limits Repofi 5.1 o 3 o (L (s o F E o (E tr o s: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 RAOC 1(n B, 1 o)-1+8 I 00).t I\:E PTABtAT IO]-l I.-[_*lUN CC PE BPT RAT t"."L_n AB LE roN UNAC C OPE: LE\I ACC OPIEP TAB:]RAT IO LE tr IV I\I I\\I I\'l(-25, 5)(22, 0)il c l COLR Cycle 1B LRM Revision 80Beaver Valley 5.1 - 11 Licensing Requirements Manual Core Operating Report 5.1 Table 5.1-1Fq Surveillance W(Z)(Page 1 of 2\Function versus Burnup Exclusion Zone Ax Po al nt Elevation (feet)150 (M\ /D/MTU)3000 (MWD/MTU)8000 (MWDTMTU)12AAA (MWD/MTU)1 6000 (MWD/MTU)*1 12.1 1.0000 1.0000 1.0000 1.0000 1.0000*2 11.9 1.0000 1.0000 1.0000 1.0000 1.0000*3 11.71.00001.0000 1.0000 1.0000 1.0000*4 11.5 1.0000 1.0000 1.00001.00001.0000

  • 5 11.31.00001.0000 1.0000 1.0000 1.0000*6 11.1 1.0000 1.0000 1.0000 1.0000 1.0000*7 10.91.00001.0000 1.0000 1.0000 1.0000 B 10.7 1.1506 1.1928 1.2322 1.2296 1.2203 I 10.5 1.14461 .1 860 1.2247 1.2235 1.2105 10 10.3 1.1390 1.1783 1.2162 1.2162 1.2053 11 10.1 1.1347 1.1744 1.2484 1.20841 .1 995 12 9.91.13451 .161 8 1.2027 1.2000 1.1931 13 9.7 1.13781.15701.1971 1 .1 909 1.1852 14 9.51.14181 .1 561 1.19071 .1815 1.1798 159.31.14401.1542 1.1857 1.1719 1.1813 16 9.1 1.14721 .1518 1.1850 1.1607 1.1864 17 8.91 .1 5931 .1 556 1.1905 1.1597 1.1883 18 8.7 1.1758 1.1664 1.2013 1.1647 1.1929 19 8.5 1.1884 1.1745 1.20821 J75A 1.2045 2A 8.3 1.1987 1.1807 1.2130 1.1825 1.2133 21 8.1 1.2066 1.1849 1.2157 1 .1 880 1.2196 22 7.9 1.2121 1.1872 1.216:2 1.1917 1.2239 23 7.6 1.2155 1.1878 1.21481 .1 936 1.2264 24 7.4 1.2168 1.1 868 1.2115 1.1937 1.2260 25 7.2 1.2161 1.1843 1.2063 1.1922 1.2239 26 7.4 1.21331 .1813 1.20021 .1 889 1.2197 27 6.8 1.20861 .1771 1.1931 1.1849 1.2142 28 6.6 1.2021 1.1712 1.1845 1 .1 803 1.2080 296.41 .1 940 1 .1 639 1.1745 1.1740 1.2000 30o.z1.18421.1 553 1.1630 1.1662 1.1901 31 6.0 1.1732 1.1456 1.1504 1.1571 1 .1 790 32 5.8 1.1605 1.1345 1 .1 365 1.1468 1.1657 Note: Top and Bottom 1A% Excluded COLR Cycle 18LRM Revision 80 Beaver Valley Unit 2 5.1 - 12 Licensing Requirements ManualNote. Top and Bottom 10%

ExcludedCore Operating Limits Report 5.1 TABLE 5.1-1 (Page 2 of 2)Fq Surveillance W(Z) Function versus Burnup Exclusion Zone Axial Point Elevation (feet)150 (MWD/MTU)3000 (MWD/MTU)8000 (MWD/MTU)1 2000{MWD/MTU)1 6000 (MWDTMTU)33 5.6 1.1477 1.1229 1.1233 1.1354 1.1523 34 5.41 .1 386 1.1141 1.1138 1.1243 1.1447 35 5.2 1.1308 1.1104 1.1036 1.1163 1.1414 36 5.0 1.1258 1.1092 1.0963 1.1112 1.1382 37 4.8 1.12331 .1 089 1.CI924 1.1078 1.1336 38 4.6 1.12061 .1 098 1.0885 1.1047 1.1283 39 4.4 1.11721 .1 106 1.0849 1.1011 1.1222 40 4.2 1.1167 1.1112 1.0810 1.0970 1.1155 41 4.4 1.1194 1.1114 1.4773 1.A927 1.1484 42 3.8 1.12341.11 19 1.0749 1.0881 1.1009 433.61.1266 1.1141 1.0746 1.0834 1.0933 44 3.4 1.12941 .1 168 1.0743 1.0799 1.0860 45 3.2 1 .1 329 1.1196 1.0747 1.0775 1.A773 46 3.0 1.13771 .1 266 1.0776 1.0790 1.0747 47 2.8 1.1466 1.1426 1.0893 1.0912 1.0839 48 2.6 1.1642 1.1673 1.1068 1.1050 1.0990 4g 2.4 1 .1 855 1.1927 1.1251 1.1192 1.1143 50 2.2 1.2075 1.2180 1.1434 1.1337 1.1296 51 2.0 1.2294 1.2433 1.1619 1.1481 1.1447 52 1.8 1.2500 1.2680 1.1800 1.1622 1.1595 53 1.6 1.2701 1.2917 1.1976 1.1760 1.1739 54 1.4 1.2887 1.3135 1.21391 .1 888 1.1876 55 1.2 1.0000 1.0000 1.0000 1.0000 1.0000 56 1.0 1.0000 1.0000 1.0000 1.0000 1.0000 57 0.8 1.0000 1.0000 1.0000 1.0000 1.0000 58 0.6 1.0000 1.0000 1.0000 1.0000 1.0000 59 0.4 1.0000 1.0000 1.0000 1.0000 1.0000 60 4.2 1.0000 1.0000 1.0000 1.0000 1.0000 61 0.0 1.0000 1.0000 1.0000 1.0000 1.0000 COLR Cycle 18LRM Revision 80Beaver Valley Unit 2 5.1 - 13 Licensing Requirements ManualCore Operating Limits Report 5.1 Table 5.1-2 (Page 1 of 1)FaG) Penalty Factor versus BurnupCvcle Burnup (MWD/MTU)F o(Z\ Penaltv Factor>0 1.0200 Note: The Penalty Factor, to be applied to Fq(Z) in accordance with Technical Specification Surueillance Requirement (SR) 3.2.1.2, is the maximum factor by which Fo(Z) is expected to increase over a 39 Effective Fulf Power Day (EFPD) interval (surveillance interval of 31 EFPD plus the maximum allowable extension not to exceed 25% of the surveillance interval per Technical Specification SR 3.0.2) starting from the burnup at which the Fq(Z) was determined.COLR Cycle 18LRM Revision 80 Beaver Valley Unit 2 5.1 - 14 Licensing Requirements Manual ADMINISTRATIVE CONTROLS Pressure and Temperature Limits ReportPressure and Temperature Limits Report 5.2 5.0 5.2BVPS-2 Technical Specification to PTLR Cross-Reference Technical Specification PTLRSectionFiqure Table 3.4.3 5.2.1.1 5.2-1 5.2-2 5.2-3 5.2-4 5.2-5 5.2-6 N/A 3.4.6 N/A N/A 5.2-3 3.4.7N/AN/A 5.2-3 3.4.10 N/A N/A 5.2-3 3.4.12 5.2.1.2 5.2.1.3 5.2-8 5.2-3 3.5.2 N/A N/A 5.2-3 BVPS-2 Licensing Requirement to PTLR Cross-Reference Licensing Requirement PTLR Section Fiqure TableLR 3.1 .2 N/A N/A 5.2-3LR 3.1 .4 N/A N/A 5.2-3LR 3.4.6 N/A N/A 5.2-3PTLR Revision 7LRM Revision 79 Beaver Valley Unit 2 5.2-i Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report 5.2 5.2Reactor Coolant Svstem (RCS) Pressure and Temperature Limits Report (PTLR)The PTLR for Unit 2 has been prepared in accordance with the requirements of Technical Specification 5.6.4. Revisions to the PTLR shall be provided to the NRC 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 Water Discharge 5.2.1 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 Fracture Toughness for Development of P-T Limits for Section Xl, Dlvision 1," and b) 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, and a.b.PTLR Revision 7 LRM Revision 79 Beaver Valley Unit 2 5.2-1 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report 5.2c. A maximum temperature change of less than or equal to 5"F in any one hour period during inservice hydrostatic testing operations above system design pressure.The RCS PIT limits for heatup, leak testing, and criticality are specified by Figure 5.2-1 and Table 5.2-1. The RCS P/T limits for cooldown are shown in Figures 5.2-2 through 5.2-6 and Table 5.2-2. These limits are defined in Reference

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 heatup and 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 power production 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 for heatup and cooldown.

The pressure-temperature limit curve shown in Figure 5.2-7 was developed for the 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 to define operational bounds, such that when operating with an isolated loop the analyzed pressure-temperature limits are known. The temperature range provided 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 limits provided 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 assessed based on the revised information.

Taking into account the updated surveillance data credibility evaluation, the Position 2.1 chemistry factor values, and the fluence 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 2 5.2-2 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report 5.2 5.2.1.2 5.2.1.3 Since the adjusted reference temperature (ART) calculation is not based on surveillance data for this limiting material, only a fluence comparison is needed in order to assess the applicability of the existing curves. Using the fluence analysis provided in Table 5-1 of Reference 13, the maximum neutron fluence vaf 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. The fluence of 3.39 x 101e n/cm2 (E r 1.0 MeV) used to develop the 30 EFPY P/T limit curves generated as a result of the Capsule X analysis (Reference 12), is more conservative 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 maximum lift 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 accordance with Table 5.2-3. The PORV lift setting provided is for the case with reactor coolant 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 the reactor vessel flange requirements, there is no operational benefit achieved by restricting the number of RCPs running to less than two below an indicated RCS temperature of 137oF. Therefore, the PORV setpoints shown in Table 5.2-3 will protect the Appendix G limits for the combinations shown.The PORV setpoint is based on P/T limits which were established in accordance with 10 CFR 50, Appendix G without allowance for instrumentation error and in accordance with the methodology described in Reference 1, including the exceptions noted in Section 5.2.1. The PORV lift setting shown in Figure 5.2-8 accounts 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. The arming temperature (when the OPPS rendered operable) is established per ASME Section Xl, Appendix G. At this temperature, a steam bubble would be present in the pressurizer, thus reducing the potential of a water hammer discharge that could challenge the piping limits. Based on this method, the arming temperature with uncertainty is 237'F.PTLR Revision 7 LRM Revision 79Beaver Valley Unit 2 5.2-3 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report 5.2 5.2.1 .4 The calculated enable temperature is based on either a RCS temperature of lessthan 200"F or materials concerns (reactor vessel metal temperature less than RTruor + 50"F), whichever is greater. The calculated enable temperature does not address the piping limit attributed to a water hammer discharge. The calculated enable temperature is 240oF.As the calculated enable temperature is higher and, therefore, more conservativethan the arming temperature, the OPPS enable temperature, as shown in Table 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 in Table 5.2-3, and disarming of the OPPS above this temperature. The OPPS is required to be enabled, i.e., OPERABLE, when any RCS cold leg temperature is less 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 in Reference 15, and are based upon analysis of Capsule X. The pressure-temperature limits provided in Reference 1 4 for Capsule X and setpoints evaluation per Reference 15 support the continued use of these existing OPPS/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 applicable operating procedure, the OPPS is activated (armed/enabled) manually before entering the applicability of LCO 3.4.12. This is accomplished by placing two switches (one in each train) into their "ARM" position. Once OPPS is activated (armed/enabled) reactor coolant system pressure transmitters will signal a rise in system 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 79 Beaver Valley Unit 2 5.2-4 Licensing Requirements Manual5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report 5.2 5.2.2 5.2.3 Reactor Vessel Material Surveillance ProqramThe reactor vessel material irradiation surveillance specimens shall be removed and analyzed to determine changes in material properties. The capsule withdrawal 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, and Tables 5.2-1 and 5.2-2 in this report. The time of specimen withdrawal may be modified to coincide with those refueling outages nearest the withdrawal schedule.The pressure vessel material surveillance program (References 4 and 13) is in compliance with Appendix H to 10 CFR 50, "Reactor Vessel Radiation Surveillance 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-Ductile Failure," to Section Xl of the ASME Boiler and Pressure Vessel Code. The surveillance capsule removal schedule meets the requirements of ASTM 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 values generated using the FERRET Code may be provided for information only.Supplemental Data TablesThe following tables provide supplemental information on reactor vessel material properties 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 the surveillance 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 vessel extended 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 7 LRM Revision 79 Beaver Valley Unit 2 5.2-5 Licensing Requirements Manual 5.2 Pressure and Temperature Limits Report Pressure and Temperature Limits Report 5.2 5.2.4 Tabfe 5.2-9, taken from Tables 4-7 and 4-8 of Reference 14, shows the calculation 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 for the 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 fluence data.References

1. WCAP-14040-A, Revision 4, "Methodology Used to Develop ColdOverpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit 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 Valley Unit 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 Vessel Materials," 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 79 Beaver Valley Unit 2 5.2-6 Licensing Requirements Manual 5.2 Pressure and Temperature Limits ReportPressure and Temperature Limits Report 5.2 11. (Deleted)12. WCAP-1 6527 , Revision 0, "Analysis of Capsule X from FirstEnergy Nuclear Operating 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 Cooldown Limit 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 Reactor Vessel Inlet Nozzle Materials."PTLR Revision 7 LRM Revision 79Beaver Valley Unit 2 5.2 -7 Licensing Requirements ManualPressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: INTERMEDIATE SHELL PLATE B9OO4-1 LIMITING ART VALUES AT 30 EFPY: 1Ar.143oF 3t4T, 132"F CURVES APPLICABLE FOR HEATUP RATES UP TO 6O"F/HR FOR THE SERVICE PERIOD UP TO 30 EFPY. 2500 2250 2000 1750 1 500 1254 1 000 750 500 250 0100 150 200 250 300 350 400 I 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)E a g lrJ tr f o o uJ u.o-o IJJ F o o zLeak Test Limit Criticality Limit based on inseMcehydrostatic test temperatue (199'F) forthe service period up to 30 EFPY Boltup TemperaturePTLR Revision 7LRM Revision 79Beaver Valley Unit 2 5.2-8 Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERry BASIS LIMITING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4-1 Lf MITING ART VALUES AT 30 EFPY: 114T, 143"F 314T, 1320F CURVE APPLICABLE FOR COOLDOWN RATES UP TO OOF/HR FOR THE SERVICE PERIOD UP TO 30 EFPY. 2504 2250 2000 17541 500 1250 1000 754 500 254 00 50 100 150 200 250 300 350 400 450 500 tNDtcATED 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)o a g]U tr:)a a IIJ tr o-o tu I o z PTLR Revision 7 LRM Revision 79 Beaver Valley Unit 2 5.2-9 Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4,1Lf MITING ART VALUES AT 30 EFPY: 114T, 143"F 314T, 1320F CURVE APPLICABLE FOR COOLDOWN RATES UP TO 2O'FIHR FOR THE SERVICE PERIOD UP TO 30 EFPY. 2500 2250 2000 17501 500 12s0 1000 754 500 250 0 100 150 200 250 300 350 400 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)I a g IIJ E, f, a@UJ tr&o uJ F I o zPTLR Revision 7LRM Revision 79Beaver Valley Unit 2 5.2 - 10 Licensing Requirements ManualPressure and Temperature Limits Report 5.2 MATER]AL PROPERTY BASIS LIMlTING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4-1Lf MITING ART VALUES AT 30 EFPY: 114T, 143"F 3l4T , 1320F CURVE APPLICABLE FOR COOLDOWN RATES UP TO 4O'F/HR FOR THE SERVICE PERIOD UP TO 30 EFPY. 2500 225A 20001 750 1 500 1250 1000 750 500 250 0 100 150 200 250 300 350 400 450 INDTGATED 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)I a g ul tr f a a IJJ tr o.o lrJ F ()o zBeaver Valley Unit 2PTLR Revision 7 LRM Revision 79 5.2 - 11 Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: INTERMEDIATE SHELL PLATE B9OO4-1 LIMfTING ART VALUES AT 30 EFPY: 114T, 143'F 314T, 1320F CURVE APPLICABLE FOR COOLDOWN RATES UP TO 6O"F/HR FOR THE SERVICE PERIOD UP TO 30 EFPY. 2000 1750 1500 12541 000 750 500 250 0 100 150 200 250 300 350 400 450 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)o o g UJ tr f o o IIJ tr (L o IIJ F o o z 50PTLR Revision 7LRM Revision 79 Beaver Valley Unit 2 5.2 - 12 Licensing Requirements Manual 2s00 2250 2000 17501 500 1250 1000 750 500 250 0Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL:INTERMEDIATE SHELL PLATE B9OO4.1 LIMITING ART VALUES AT 30 EFPY: 1Af .143"F3t4T, 132"F CURVE APPLICABLE FOR COOLDOWN RATES UP TO 1OO"F/HR FOR THE SERVICE PERTOD UP TO 30 EFPY. E cn g llJ tr 3 U'o ut u o-o UJ o o z f U"acceptablel I Operation I lAcceptabl"l I operation I t---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 2 5.2 - 13 Licensing Requirements Manual 2500 2000 s00 an= 1500 v)g[rJ E, f a 0 UJ G 1000 o-Pressure and Temperature Limits Report 5.2 124 110 50 60 80 90 100 TEMPERATURE ("F)Figure 5.2-7 (Page 1 of 1)lsolated Loop Pressure - Temperature Limit Curve (LCO 3.4.3)PTLR Revision 7 LRM Revision 79 Beaver Valley Unit 2 5.2 - 14 Licensing Requirements Manual 725 700 675 650 625 600 575 550 525 500 475 450Pressure and Temperature Limits Report 5.2 o 6 g z 6 (L lr, a tr.o IL z=o z UJ trt=o J J=f E x=I x=a LSee Table 5.24 for RCP restrictions.--I I I Unacc eptable ope ration Ir cepte rble Pql 50 75 100 125 15A 175 2A0 225 25A 275 300 325 350TRrD-AUCTl ONEERED LOW -M EAS URED RCS TEM P ERATURE (" Fl Figure 5.2-8 (Page 1 of 1)Maximum Allowable Nominal PORV Setpoint for theOverpressure Protection System (LCO 3.4.12)PTLR Revision 7 LRM Revision 79Beaver Valley Unit 2 5.2 - 15 Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-1 (Page 1 of 1)Heatup Curve Data Points for 30 EFPY (LCO 3.4.3)6O'F/HR HEATUP 60'F/HR CRITICALITY LEAK TEST LIMIT Temp.("F)Press.(psiq)Temp.('F)Press.(psig)Temp.("F)Press.(psig)60 0 199 0 181 2000 60 621 199 621 199 2485 65 621 199 621 70 621 199 621 75 621 199 621 80 621 199 621 85 621 199 621 90 621 199 621 95 621 199 621 100 621 199 621 105 621 199 777 110 621 199 793 115 621 199 813 120 621 199 835 120 621 199 861 124 777 199 889 125 793 199 921 130 813 199 957 135 835 200 996 140 861 2051 040 145 889 210 1 089 150 921 215 1143 155 957 220 1203 160 996 225 1269 165 1 040 230 1342 170 1 089 235 1 423 175 1143 240 1512 180 na3 245161 1 185 1269 25017 1g 190 1342 255 1840 195 1423 264 1972 200 1512 265 2118 205 1611 270 2280 214 1719 275 2458 2151 840 224 1972 225 2118 234 2280 235 2458 Beaver Valley Unit 2 5.2 - 16 PTLR Revision 7LRM Revision 79 Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-2 (Page 1 of 1)Cooldown Curve Data Points for 30 EFPY (LCO 3.4.3)O"F/HR 20"F/HR40"F/HR6O"F/HR100.F/H R Temp.('F)Press.(psig)Press.(psig)Press.(psig)Press.(psis)Press.(psig)60 0000 0 60621621621 602 525 65621621 621 612 536 70 621 621 621 621 548 75621621621621 562 80 621 621 621 621 578 85621621621 621 595 90 621 621 621 621 614 95 621621621621 621 100 621621621 621 621 105621621621621 621 110 621 621 621 621 621 115 621621621621 621 120621621621621 621 124621621 621 621 621 120892867 844 822 783 125 918 896 875 855 823 130 947 927 909 893 867 135 980 962 947 934 917 140 10161 001 989 980 971 145 1 055 1044 1 0361 0311 031 150 1 099 149210871087 1087 155 1147 11441 144 1144 1144 160 1201 1201 1201 1201 1201 16512601260 1260 1260 1260 170 1325 1325 1325.1 325 1325 175 139713971397 1397 1397 1801477147714771477 1477 1851 565 1 5651 5651 565 1 565 190 1662166216621662 1662 195 1774 177017701770 1770 2401 888 1 888 1 8881 888 1 888 205 2020 2420 2020 2020 2020 210 2165 2165 2165 2165 2165 215 2325232523252325 2325 Beaver Valley Unit 2 5.2 - 17PTLR Revision 7LRM Revision 79 Licensing Requirements ManualPressure and Temperature Limits Report 5.2 Table 5.2-3 (Page 1 of 1)Overpressure Protection System (OPPS) Setpoints (LCO 3.4.12')FUNCTION SETPOINT OPPS Enable Temperature 240"F PORV SetpointFiqure 5.2-8PTLR Revision 7 LRM Revision 79 Beaver Valley Unit 2 5.2 - 18 Licensing Requirements ManualPressure and Temperature Limits Report 5.2Table 5.24 (Page 1 of 1)Reactor Coolant Pump Restrictions TncsRunninq RCPs < 1370F 0-2> 1370F 3PTLR Revision 7LRM Revision 79 IBeaver Valley Unit 2 5.2 - 19 Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-5 (Page 1 of 1)Calculation of Chemistry Factors Using Surveillance Capsule Data Notes: (a) f - calculated surveillance capsule neutron fluence (x 101e nlcm2, E > 1.0 MeV). The surveillance 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, a conservative 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)Material CapsuleCapsule fl") pp{o)ARTppl(")FF*ARTlror FF2 IntermediateShell Plate 89004-2(d)(Longitudinal) U 0.615 0.864 24.4 20.73 0.746 V 2.64 1.260 56.0 70.54 1.587 W 3.61 1.334 71.0 94.68 1.778 X5.631.425 98.0 139.65 2.431 IntermediateShell Plate 89004-2(d)(Transverse) U 0.615 0.864 17.7 15.29 4.746 V 2.64 1.260 46.1 58.07 1.587 W 3.61 1.334 63.4 84.55 1.778 X 5.63 1.425 144.1 148.34 2.031 SUM: 631.87 12.284 CF = t(FF

  • ARTpel) + f(FF2)= (631.87) + (2.284) = 51.4oF Beaver ValleyUnit 2 SurveillanceWeld Metal(u)(Heat #83642)U 0.615 0.864 4.1 3.54 0.746 V 2.64 1.260 25.7 32.37 1.587 W 3.61 1.334 6.0 8.00 1.778 X5.631.425?2.9 32.63 2.031 SUM:76.556.142 CF = I(FF
  • ARTr'uor)

+ >(FF) = (76.55) = (6.142) = 12.5F PTLR Revision 7 LRM Revision 79Beaver Vafley Unit 2 5.2 - 20 Licensing Requirements ManualPressure and Temperature Limits Report 5.2 Table 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 ,4508 Class 2. The ASTM A508 material specification does not require analysis of copper content. The importance of copper content in the irradiation embrittlement of ferritic pressure vessel steel was not recognized or regulated by the NRC or nuclear steam supply system (NSSS) vendors when the BVPS-2 reactor vessel was constructed. Even though the material specification did not require analysis of copper content for ASTM 4508 Class 2 material, check analyses on chemistry measurements (including copper) were reported in MISC-PENGER-021. The copper values reported for both the closure head flange (89002-1) and the vessel flange (89001-1) was 0.06%.The initial RT5p1 value is determined in accordance with the requirements of Subparagraph NB-2331 of Section lll of the ASME B&PV Code, as specified by Paragraph ll - D of 10 CFR Part 50, Appendix G. These fracture toughness requirementsare also summarized in Branch Technical Position MTEB Section ll.5-2 ("Fracture Toughness") 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 be equal to Txpl (i.e., -30.0"F).Notes: (a)(b)(c)PTLR Revision 7LRM Revision 79 Material Cu (wt%)Ni (wt%)Initial RTr..ror (F1t"tClosure Head Flange 89002-1 0.06(b)4.74-10 Vessel F ange 89001-1 0.06(b)0.73 0 lntermed ate Shell Plate 89004-1 0.065 0.55 60 lntermed ate Shefl Plate 89004-2 0.06 0.57 40 Lower Shell Plate 89005-1 0.08 0.58 28 Lower Shell Plate 89005-2 0.07 0.57 33 lntermed ate to Lower Shell Weld 101-171 (Heat 83642)0.046 0.086-30 lntermed ate Longitudinal Weld 101-124 A & B (Heat 83642)0.046 0.086-30Lower Longitudinal Weld 101-1 42 A & B (Heat 83642)0.046 0.086-30Plate Surveillance Material 89004-2 0.06 0.57 40 Surveillance Weld (Heat 83642)0.065 0.065-30(")Beaver Valley Unit 2 5.2 - 21 Licensing Requirements Manual Notes.Pressure and Temperature Limits Report 5.2 fable 5.2-7 (Page 1 of 1)Reactor Vessel Extended Beltline Material Properties (")(a)(b)(c)Materials information taken from Reference 13 Based on Reference 13, the generic Initial RT1ror values were determined in accordance with NUREG-0800 and the 10 CFR 50.61.As described in Reference 16, the reactor vessel initial RTr,ror values for the inlet nozzles are conservatively assigned values. The actual initial RTnror values for the reactor vessel inlet nozzles are located in BVPS-2 UFSAR Table 5.3-1.Material Description Material IDHeat Number Wt%Cu wt%Ni lnitial RTruor ('F)(b)Upper Shell 89003-1 A9406-1 0.13 0.60 50 B9003-2 84431-2 0.12 0.60 60 89003-3 A9406-2 0.13 0.60 50 Upper Shell Longitudinal Welds 101-1224 101-122B 101-122C 51912 (3490)0.156 0.059-50 51912 (3536)0.156 0.059-70 EAIB 0.42 0.98 10 (Gen)IAGA 0.03 0.98-30 BOHB 0.05 1.00 10 (Gen)BAOED 0.02 1.00-50Upper Shell to Intermediate Shell Girth Weld 143-121 4P5174 fi122\0.09 1.00-50 51922 (3489)0.05 1.00-56 (Gen)AAGC 0.03 0.98-74KOIB0.03 0.97-60 Inlet Nozzles 89011-1 2V2436-01-002 0.11 0.85 60("'89011-2 2V2437-02-001 0.13 0.88 60("'(Gen) 89011-3 2V2445-02-003 0.13 0.84 70\Inlet Nozzle Welds 105-1214 105-121B, 105-121C 4P5174 (122\0.09 1.00-50LOHB0.03 1.03-60 HABJC 0.02 1.42-74 BABBD 0.02 1.04-74 FABGC 0.03 1.42-80 EOBC 4.02 0.96-60 FAAFC 0.07 1.04-60 CCJC 0.02 0.99-60FAGB0.02 1.06-30 BAOED 0.02 1.00-50Outlet Nozzles 89012-1 AV8080-2E9558 0.13 a.72-10 89412-2 AV8120-2E9560 0.13 0.74-10 89012-3 4V8097-2E9559 0.13 0.70-10 Outlet Nozzle Welds 147-1214 107-121B, 107-121C BABBD 0.02 1.44-70 FAAFC 0.07 1.04-60 HAAEC 0.03 1.03-80 HABJC 0.02 1.42-70 HAGB 0.02 1.04-44 GACJC 0.03 1.00-80 JAHB 0.03 0.97-44PTLR Revision 7LRM Revision 79 Beaver Valley Unit 2 5.2 - 22 Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-B (Page 1 of 1)Summary of Adjusted Reference Temperature (ARTs) for 30 EFPY(.) Material Description Method Used ToCalculate the CF(b)30 EFPY ART1t4T ART ("F)3l4T ART ("F)Intermediate Shell Plate 89004-1Position 1.1 143 132 Intermediate Shell Plate 89004-2 Position 1.1 119 109 Position 2.1 119 106 Lower Shell Plate 89005-1 Position 1.1 123 110 Lower Shell Plate 89005-2 Position 1.1 120 109 Vessel Beltline Welds(") Position 1.1 53 35Position 2.1 0-6 Notes: (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 79 Beaver Valley Unit 2 5.2 - 23 Licensing Requirements Manual Pressure and Temperature Limits Report 5.2Table 5.2-9 (Page 1 of 1)Calculation of Adjusted Reference Temperatures (ARTs) for 30 EFPY(") PARAMETER VALUES Operating Time 30 EFPY Material - Intermediate Shell Plate 89004-1 89004-1 Location 1t4T 3t4TChemistry Factor, CF ('F)40.5 40.5 Fluence, (0, (101e n/cm2;(ul 2.113 0.8215 Fluence Factor, FF 1.203 0.9448 ARTppl=CFxFF('F) 48.74 38.27 Intitial RTpp1, l("F)60 60Margin, M("F) 34 34 ART, per Regulatory Guide 1.99, Revision 2 143 132 Notes: (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. The Beaver Valley Unit 2 reactor vessel wall thickness is 7.875 inches at the beltline region.PTLR Revision 7LRM Revision 79Beaver Valley Unit 2 5.2 - 24 f- O)cr-og'6 .9'= .a o>trP En J>Is K)c{I c\{LO N=c f 0)(U t-o$o c0 SE$O E ,*--.-\tit l^\-, a$i,: c Fs o csrgE gEtE= r] 0) (l){ H*E(/): q<$'O* x m=ots o 6g df TE.*^8 F: c!> = -dT EE Uts 9 =. l-_ t'u i6' .gE.P".i E8-$ (E tt (/)(o tr g EC9 L GJ b@ Q a=6 tu =ee r4=E P6 I gg 5 f ry 9: e*;*?rst 5*'.6 ocN rs o+.=6s=g EsEE EstE i :' -o-=: fi-E: (nE U)$o (l) (l)x P ,t, .5=65*^ i E;3ET tr= E b5g :":HEl r; fi #eEilg s? E 9 gPgm E;H a.-E"rte E b s?u-h 3b bSEE H: I 6i = E b SEEE-b. EIg:: E q j "'"'.-Ef s-* g:f*_rr14efrr t,. E E " +'P b F: ,td f, c Q > k F .e I E ot PI a'ti ^il o-ocrat(DC<r) Lrv-an ,I F E.I ro (o N n (o$q (r)cr)oi C\q t-(o c!tr)ro oj lt I q O)s I I l, c grF$$cf)$(f)$CO!t cf)tif cf)rf)d$q f-\o)(f)a$oq O)oo q$oo l't-f-f--f-f-N-f N@d o)ot e\l f-o)o, e\{ f-.r lr{-o O OOO o OOOOO o I a[-,^ir LL Fo t-v r lt-()c.i lf)n N f-q f-c.i (o rr)d$(ol\-f-o)cf)n$oq o)(f)LO+-eO f a'F 9tL cF <-/4 O CO O.it O tf@N cf)cf)o cf)I o cf, I o cf)I O c)I o cf)I o cf)I..ao ^rE LL d ,S g.--c t-t-O ro O.tr f-Cf)g Lr)-LO$$n$cr)q N q$co q N.q$co LO c-i o P 6a L#v O()LL=csu_I rr-c!O)O n N o)O n r N O)o n$O n$o-n N O)O n r N O)o R r$rO lr)-r s rO ro I o)(o LO-O)(0 LO I-o!- c{EeF o E--(gLL ==x J.V a@1.c,*,f,)@tri r n rf)N rri@rd@rri (o\(0\F\r f-\t_uo OQ otr z I (u (U E I I I N s (0 ca@$(tr N s CO co@o)(g (6 c\I$(o oo @N (U (U'=qo (tr I$O O o)co N I$O O o)m: o c a d)*9 n$Ud F g t-(u o c$c)g=a q)-o E 0)L O I c o c o)a-'a:)t I I rf)O O O)m N I Lo o C) o, m r f-r 1 r O E q)(J c s'o L$Sm ro{5<o o C)c-$'o N Jm roS 5<E CI ()c (Io 1-c o=o-'=(J (n CI O CS'=0)+.$(1)_c a go)$==tu oO-E L o-q)(g o-o-c a L (lJ=o J Q)(u d c)c a L c)=o J O la-io;=Et*o 9E C-ba E f a o E E o C) o)c'a f f I a q;A-c (1)a=o-EE EE bP co J 6 c)-o 1l CI L ()o)c'a f T I U'E c)P=cn 16 r-C 9rl':J o.=JO)c o J J a o I E ()t-C)ct)c'a:f A t I Ec{arri II q)v-a==L=o f$o o-E o F E (0 o-t ag a o FO-t! tL t.u$rO v c.9 a c o X LU O/^.--J l+- +'o$rCo ar .9lFt\ t-.rr- G)-:.- #II fi';>c,{, .o-' O)r{, o at-oo$cl .-a)m r_o c.9 (U=C)N O a f, F t (s=c$a v c o E q)L'=u 0)x.o)c'@c o.(J J t\ O)c l'-oc'6 .9.'= .a (I)tP t-J>Ig (o c{I c.l LO N.=l-e$r-q)$CI co o A^trLL ,* o tr d lf,)q?(o d ro (o (o (o$q N@(o cf)a o cf)q (o I q rr)O q$(o c'l cQ I oq (o\cf)O)q c\I o c.i=.E c') LL!-o$v$cf)\r cf)$ cf)(o rr)(o ro ro o lif n cf)cr)q rr)(o q N N q (o ro q rf,)(o n cf, cf)n CO (f)@(o O cj\if q r c{ooFf-f-rf-@N@N q r\(o\f-N q@N f-lt-N l-(o\(o n@q O t{)o._r l!(Jo Oc)o O o F O t-r o o l-oOO l-O I s)l-,^(rLL l-o t4-+t-(o It-(o+l-O (o O (o O c.i N q cf)cf)R ro ro q N N q O) O)a LO ro q ca Cf)n cr)cr)oq (o g N q N-{t fit F-i 9lr CF i--tr O ro O (o o ro o ro I o f-I u o O CO I T'o O ro 1 O ro I ro (o ro I O l-I O CO I O (o-c:o O (o o f--#!-.QoEE !L 1l (E i.--cLL O q-o)O c.j co q r o)r f-c)N-f-c.j f-q l-N o r s q@(o O It-N q N N r q a (o q s q$q F t*q (0 O)q (o o)o P ba L#v O()LL=(oLL IlJ-f-$@O f-$@O f-s@O F-$@O l-s@O f-s oq O f-$r-oq O f-$r oq O l-$r@c;l-$oq O f-$r@c;f-v oq O l-$oq O@@c\{O@@c'l O@@N o I5 8s.c*E63F a2;5E ro r lr)O l{)r lo O lJ)r U?o ro r q o LO-tr)O rf, lo o 1r)r U?O tr)ro o LO r q o lo r rf)O ro LO O tr)lr) o LO r rq (f@o, N q O@OJ N q O@O)c\ q O gb F-O=*2 3E rJ-I (,o O$O)N I r cf)$s m N I (0 O$o)O O)$co N r o)r LO (o c)ro co c!-O)tr)m IIJ m-o co o u_J o m$f-r LO o-$N N q)ro C)t, m o Y c!O O I r O I (o cf)t N c{O O I N O l f-cf)$N N cr)O O I c!O I ()$$N c{o (E'r--q)N r I cf)O O O)m N I cf)O O O)m CO I co O O O)m C\NN C!NN rr ttl rr OOO rr N l c9 O I r O O)m N I-o O)m eo I r r o OJ m c.o v o_'=(J a O CI (E'=c)o a o'H$0_o-c a L c)o_o_f a a o:>-c. -(/)N LL qE L.t- -t o-t f 'cl, c o J 0)P N-= L.';' c)E=!-gF-(, 9-!-O o-c o_u)o_:)a c)N N o z#c)c EN gri o t a.=E: c)f (u t-o o_E c)F E c o o=a a o t-0_o o-LL IU$lr)c.9@-o x I.IJ q): (s 6(/).F .(U ob r#OE a1 (Ur O-o o)!--CI 5(o{o Lo .g OF-o 0)om t-'E CI E a-o X u o r+-c o o ()(g O a-o_F t (s J (o o c c)E c).=f u CI t o, c'@c o.c)J l- Ot cl-oc'6 .9'= .a o>tp g;IE N.=c:)o ($t-CI$c)m o rtL F</tr.q cr)c.i s I c\l@lr)I N@ro I c.i (o I c\l@\r I.q@I c!@!t I e\l @I Crl @cf)I It-c!f-q (0 c!c!(o I q?c{cf)I c\l a;(o I c\l c{(o I e\l c{0., I c!d CO I c\I*;N I o.c o, LL l-o$v f'-(o c{o ot O)ri q rf)q O)qltr)@d N q ro q ro q ro lo c"j q cf)l{)c.j q 0.)\cf)q rf)o, c.j q cf)q ro q lr)-< LL\JO CA CA tf,)+O cfi O c.jlJ)$q cf)n O o c"j O c.j O c"j oq (o oq (o l-(o q@(o a caqq o c.j q CA.? LL LJOoo Ooo OOOO O ooo O ooo O O (f o U)hC l-o t-v\(0 N q (I, q ro o)ro o o;O)ro oq o N q ro q lf)O)d 1r)c"j q cf)q cf)q CO\C9 qlr)q co o, c"j o)r;o)ri-o ftl F-'.= 9 tt-'- F- g--tr O LO I O (o I O f-I o f-I o @I o (o I O (o I o (o I O cf)I o ro I O r I O I O I O t-t o (o I o 6 t O f-I O$I o O I O tit I-+, l_.9o^EEIL nO:-itL O q N c{q$O lt-c{q f-N q r$q l-N q ro O)q f-N q f-N q f-C\t q$O)q$o)ro c.j O)q t-N q ro O)q$q t-N q f-N q-$q rif o.^o =^\., _o L+iv OC)LL f(ulr E lr-@@N o@@c.l o@@ry O@@c!O@*r c!O@@r c\O@@c.l O@@r N O@@N O@@r c\O o$$r O O$s r O O tf tf r o O$$o o s$r c;c)s.if o O.t$o O$$O O$ $c;O$$O I5 8: ,c*863F a2# 5E@OJ N q O@O)N q o@O)N O O@o) N q O@O, N O c;@O)N q O@o)N O O@O)N q O@O)N q O@O) c! q O r lr)r O O rr)q O r ro r q c)ro r O O r lf)-q o lr)O O ro s-O O r lJ)o o ro r O c;LO\-q O!-'^8F-!-J'z Eq I3$f-ro 0_$m I o J O-m=o m co m C)O co LL C)m o LU C)LL LL O-)O O co O ll-<o[U o co@ro lr)o)I.IJ N I O@O@O CO rr)O)LU N I O cv@O)rf)lJ)O)LIJ N I l-O)O@O m m m C)lt II C)LU r ()--)m r m C)r O-O (, m I-o (u L (D+r (u NNN rr lllro ro Lo OOO rr r I N O O)m N I N o Ol m co I N-O O)m<mo rrr NNN s-t-r tttf- f- f-OOO rr cg'E O_L E(J=E o (l)N Na olC Za)6=c@(I)N N o z (l)f o q)N Xo;E:e-@5=o EN 3ri o v.a.=E: o t-f+t (o l-c)o_E o F c c (s c)L 5 a a o t-(L o o-TL UJ$lf)c.9 o c c)x tIlo: (E AU),ts .(U.iE CI*O, I$.-o_d o Ttr c.l CI lr).c OF-o G)(uc0 l-'E o T)c o X LU t-o\F c o (U J (J (U O a F o_F t (s J (s 0 g CI E o t-'=o q)E.o)c'a c o.c) J Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-11 (Page 3 of 3)RTprs Calculation for Extended Beltline Region Materials at Life Extension (54 EFPY;t"t Notes: (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 2 5.2 - 28 Licensing Requirements Manual 5.3 ADM I N ISTRAT]VE CONTROLS Procedure Review and Approval Procedure Review and Approval 5.3 5.0 Each procedure or revision thereto of Technical Specification 5.4.1 shall be reviewed and approved, 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 who prepared the procedure or associated procedure revision. The IQR shall ensure that cross disciplinary 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 determination of whether a procedure requires a 10 CFR 50.59 evaluation. lf a procedure or revision thereto requires 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 the Plant 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 Responsible Discipline 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 2 5.3-1LRM Revision 52 Licensing Requirements ManualRecord Retention 5.4 5.0 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 power level.Records and logs of principal maintenance activities, inspections, repair and replacement 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 the Technical 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 to systems and equipment described in the Final Safety Analysis Report.Records of new irradiated fuel inventory, fuel transfers and assernbly burnup histories.

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 designed for 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 Technical Specifications. 2.3.4.2.3.4.5.6.7.8.Beaver Valley Unit 2 5.4-1 LRM Revision 52 Licensing Requirements Manual5.4 Record RetentionRecord Retention 5.4 9. Records of Quality Assurance activities required by the QA Manual.10. Records of reviews performed for changes made to procedures or equipment or reviews of tests and experiments pursuant to 10 CFR 50.59.11. Records of meetings of the onsite review committee and the independent review board.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 Monitoring Program.14. Records of reviews performed for changes made to the Offsite Dose Calculation Manual and the Process Control Program.Beaver Valley Unit 2 5.4-2LRM Revision 52 LICENSING REQUIREMENTS MANUAL BASES TABLE OF CONTENTSPage No.B 3.0 LTCENSTNG REQUTREMENT (LR) APPLTCABTLTTY B 3.0-1B 3.0 LTCENSTNG REQUTREMENT SURVETLLANCE (LRS) APPLTCABTLTTY . B 3.0-5 B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1 .1 - B 3.1.8 Boration SystemsB 3.1 .1 -1 B 3.1.9 Rod Position Indication - Shutdown.. . B 3.1.9-1 B 3.1 .1 0 Boron Dilution ..... B 3.1 .1 0-1 B 3.1.1 1 Rod Position lndication System - Shutdown Test Exception...... . B 3.1 .11-1B 3.3 INSTRUMENTATIONB 3.3.3 B 3.3.4 B 3.3.5 B 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 3.3.4-1 Quadrant 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 3.3.8-1 B 3.3.9 Turbine Overspeed Protection .... B 3.3.9-1B 3.3.11 Fuel Storage Pool Area Radiation Monitor. . B 3.3.11-1 B 3.3.12 Explosive Gas Monitoring Instrumentation .. B 3.3.12-1 B 3.3.13 Containment Hydrogen Analyzers...... . B 3.3.13-1B 3.3.14 Control Room lsolation Radiation Monitors . B 3.3.14-1 B 3.3.15 Containment Area Radiation Alarm ..... B 3.3.15-1 B 3.3.16 Accident Monitoring lnstrumentation

... B 3.3.16-1 B 3.4.1 -1Chemistry . .......8 3.4.2-1 Pressurizer.... ...... B 3.4.3-1 DELETED... .......83.4.4-1 Reactor Coolant System Head Vents. B 3.4.5-1 Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge....... B 3.4.6-1B 3.6 CONTAINMENTB 3.4.2B 3.4.3 B 3.4.4B 3.4.5 B 3.4.6 B 3.6.1 B 3.6.2 B 3.7.1 B 3.7.2 B 3.7.3 B 3.7.6B 3.7.7Containment lsolation Valves... ... B 3.6.1-1 Containment Sump ...... B 3.6.2-1 B 3.7 PLANT SYSTEMS B 3.7.4 Snubbers..... B 3.7 .4-1 B 3.7.5 Standby Service Water System (SWE) ....... B 3.7.5-1 Steam Generator Pressure/Temperature Limitation ... B 3.7.1-1Flood Protection ..... ..... B 3.7.2-1Sealed Source Contamination ..... B 3.7.3-1 Explosive Gas Mixture.. ....... B 3.7.6-1Supplemental Leak Collection and Release System (SLCRS) ...8 3.7.7-1Beaver Valley Unit 2 B-iLRM Revision 67 LICENSING REQUIREMENTS MANUALBASES TABLE OF CONTENTSPage No.B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.1 125V D.C. Battery Banks Maintenance RequirementsB 3.8.2 B 3.8.3 3.9.2 3.9.3 B B B B 3.9 REFUELING OPERATIONS 3.9.1 Crane Travel - Spent Fuel Storage Pool Building Emergency DG 2000 Hour Rating Limit Main Fuel Oil Storage Tank Maintenance Requirements Manipulator Crane Decay Time B 3.8.1 -1 B 3.8.2-1 B 3.8.3-1 B 3.9.1 -1 B 3.9.2-1 B 3.9.3-1 B-iiBeaver Valley Unit 2 LRM Revision 67 Licensing Requirements Manual B 3.0 LTCENSTNG REQUTREMENT (LR) AppLtCABtLrTy BASESLR ApplicabilityB 3.0 LRs LR 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 3.0.2 LR 3.0.2 establishes that upon discovery of a failure to meet an LR, the associated ACTIONS shall be met. The Completion Time of eachRequired Action for an ACTIONS Condition is applicable from the point in time that an ACTIONS Condition is entered. The Required Actionsestablish those remedial measures that must be taken within specified Completion Times when the requirements of an LR are not met. This S pecification establishes that: Completion of the Required Actions within the specified Completion Times constitutes compliance with a Specification and Completion of the Required Actions is not required when an LCO is met within the specified Completion Time, unless othenryise specified.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 limit is the Completion Time to restore an inoperable/Nonfunctional system orcomponent to OPERABLE/FUNCTlONAL status or to restore variables to within 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 action that may always be considered upon entering ACTIONS.) The second type of Required Action specifies the remedial measures that permitcontinued operation of the unit that is not further restricted by the Completion Time. In this case, compliance with the Required Actions provides 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 2 B3.0-1LRM Revision 67 Licensing Requirements Manual BASES LR ApplicabilityB 3.0 LR 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. The individual LR's ACTIONS specify the Required Actions where this is the case.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 not limited 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 not be made for operational convenience. Additionally, if intentional entry intoACTIONS would result in redundant equipment being inoperable/Nonfunctional, alternatives should be used instead. Doing so limits the time both subsystems/trains of a required function are inoperable/Nonfunctional and limits the time conditions exist which mayresult in LR 3.0.3 being entered. lndividual LRs may specify a time limit for performing an LRS when equipment is removed from service or bypassed 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 to comply 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 apply from the point in time that the new LR becomes applicable, and the ACTIONS 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 and no other Condition applies; orThe condition of the unit is not specifically addressed by theassociated ACTIONS. This means that no combination of Conditions stated in the ACTIONS can be made that exactly corresponds to the actual condition of the unit.a.b c.Beaver Valley Unit 2 83.0-2 LRM Revision 67 Licensing Requirements Manual BASES LR Applicability B 3.0 LR 3.0.3 (continued)This LR delineates the actions required when directed by the associated ACTIONS, 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 components being 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 its design/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 and Functionality Assessments" (consistent with the guidance of NRC Regulatory lssue Summary 2005-20 (Revision 1), and as required by Appendix B of 10 CFR 50) and appropriate corrective actions are requiredto be initiated, within the time frame determined by the Shift Manager that shall 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 of NOP-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 been performed, or ACTIONS exist that do not have expired Completion Times. TheseCompletion Times are applicable from the point in time that the Condition is initially entered and not from the time LR 3.0.3 is exited. a.b.c.d.Beaver Valley Unit 2 830-3 LRM Revision 67 Licensing Requirements Manual BASES LR Applicability B 3.0 LR 3.0.4 LR 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 sole purpose 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 of required testing to demonstrate either:The OPERABILITY/FUNCTIONALITY of the equipment being returned to service: or The 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 the time 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 is restored to the required condition in a timely manner. This LR does not provide time to perform any other preventive or corrective maintenance. Minor corrections such as adjustments of limit switches to correct position indication anomalies are considered within the scope of this LR.An example of demonstrating the OPERABILITY/FUNCTIONALITY of the equipment being returned to service is reopening a containment isolation valve that has been closed to comply with ACTIONS and must be reopened to perform the surveillance requirements. An example of demonstrating the OPERABILITY/FUNCTIONALITY of other equipment is taking an inoperable/Nonfunctional channel or trip system out of the tripped condition to prevent the trip function from occurring during the performance of a surveillance requirement onanother channel in the other trip system. A similar example of demonstrating the OPERABILITY/FUNCTIONALITY of other equipment is taking an inoperablelNonfunctional channel or trip system out of the tripped condrtion to permit the logic to function and indicate theappropriate response during the performance of a surveillance requirement on another channel in the same trip system.a.b.LR305 The purpose of LR 3.0.5 is to provide guidance that clarifies the appropriate action when LRM requirements specified in the Technical Specifications such as those listed in the Tables containinglnstrumentation Response Times or in the COLR are not met. The guidance of this LR is intended to prevent potential confusion or misapplication of the provisions in the LRM to the requirements governedby Technical Specifications.Beaver Valley Unit 2 830-4 LRM Revision 67 Licensing Requirements Manual BASES LR Applicability B 3.0LR 3.0.6 There are certain special tests and operations required to be performed at various times over the life of the unit. These special tests and operations are necessary to demonstrate select unit performance characteristics, to perform special maintenance activities, and to perform special evolutions. Test Exception LR 3.1.11 allows specified LR requirements to be changed to permit performances of these special tests and operations,which othenruise could not be performed if required to comply with the requirements of the LR. Unless othennrise specified, all the other LR requirements remain unchanged. This will ensure all appropriate requirements 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 not necessarily in compliance with the normal requirements of an LR.Compliance with Test Exception LRs is optional. A special operation may be 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 be followed.Beaver Valley Unit 2 83.0-5 LRM Revision 67 Licensing Requirements Manual B 3.0 LTCENSING REQUTREMENT SURVETLLANCE (LRS) APPLTCABTLTTY BASESLRS Applicability B 3.0 LRSs LRS 3.0.1 through LRS 3.0.3 establish the general requirements applicable to all Specifications and apply at all times, unless othenarise stated.LRS 3.0.1 LRS 3.0.1 establishes the requirement that surveillances must be met during the MODES or other conditions in the Applicability for which the requirements of the LR apply unless othenruise stated in an individual LRS. The purpose of this LRS is to ensure that surveillances are performed to verify the OPERABILITY/FUNCTIONALITY of systems and components and that parameters are within specified limits to ensure safe operation of the facility when the plant is in a MODE or other specifiedcondition for which the associated LRs are applicable. Failure to meet a LRS 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 performed within the specified Frequency. Additionally, the definition related to instrument testing (e.9., CHANNEL CALIBRATION) specify that these tests are performed by means of any series of sequential, overlapping, or total steps.Systems and components are assumed to be OPERABLE/FUNCTIONAL when 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 be inoperable/Nonfunctional, although still meeting the LRSs; or The requirements of the LRS(s) are known not to be met between required 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 are not applicable unless otherwise specified. The LRSs associated with a Test 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 applicable acceptance criterla) for a given LRS. ln this case, the unplanned eventmay be credited as fulfilling the performance of the LRS. This allowance includes those LRSs whose performance is normally precluded in a givenMODE or other specified condition. a.b Beaver Valley Unit 2 B3.0-6 LRM Revision 67 Licensing Requirements Manual BASES LRS Applicability B 3.0 LRS 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 LRS 3.0.2, prior to returning equipment to OPERABLE/FUNCTIONAL status.Upon completion of maintenance, appropriate post maintenance testing is required to declare equipment OPERABLE/FUNCTIONAL. This includes ensuring applicable LRSs are not failed and their most recent performance is in accordance with LRS 3.0.2. Post maintenance testing may not be possible in the current MODE or other specified conditions inthe Applicability due to the necessary unit parameters not having been established. In these situations, the equipment may be considered OPERABLE/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 other necessary 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 of greater 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 the steam pressure required to perform the testing. LRS 3.0.2 LRS 3.0.2 establishes the requirements for meeting the specified Frequency 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 the Frequency. This extension facilitates Surveillance scheduling and considers plant operating conditions that may not be suitable forconducting the Surveillance (e.9., transient conditions or other ongoing Surveillance or maintenance activities).The 25o/o extension does not significantly degrade the reliability that results 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 the 25o/a extension of the interval specified in the Frequency does not apply.Beaver Valley Unit 2 83.0-7 LRM Revision 67 Licensing Requirements Manual BASESLRS Applicability B 3.0 LRS 3.0.2 (continued) These exceptions are stated in the individual LRs or LRS. Therequirements of regulations take precedence over the LRs. The LRs cannot in and of themselves extend a test interval specified in the regulations.As stated in LRS 3.0.2, the 25o/o extension also does not apply to the initial portion of a periodic Completion Time that requires performance on a "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 by checking the status of redundant or diverse components or accomplishesthe function of the inoperable/Nonfunctional equipment in an alternative manner.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 equipment inoperable/Nonfunctional or an affected variable outside the specifiedlimits when a surveillance has not been completed within the specified Frequency. A delay period of up lo 24 hours or up to the limit of the specified Frequency, whichever is greater, applies from the point in time that it is discovered that the surveillance has not been performed in accordance 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 that have 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 of any particular surveillance being performed is the verification of conformance with the requirements.Beaver Valley Unit 2 830-8LRM Revision 67 Licensing Requirements Manual BASES LRS ApplicabilityB 3.0 LRS 3.0.3 (continued) When a surveillance with a Frequency based not on time intervals, butupon specified unit conditions, operating situations, or requirements of regulations (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 to perform the surveillance. However, since there is not a time intervalspecified, the missed surveillance should be performed at the first reasonable opportunity. LRS 3.0.3 provides a time limit for, and allowances for the performanceof, surveillances that become applicable as a consequence of MODE changes imposed by Required Actions. Failure to comply with specified Frequencies for LRSs is expected to bean infrequent occurrence. Use of the delay period established by LRS 3.0.3 is a flexibility which is not intended to be used as an operational convenience to extend surveillance intervals. While up to24 hours or the limit of the specified surveillance interval is provided to perform the missed surveillance, it is expected that the missed surveillance will be performed at the first reasonable opportunity. The determination of the first reasonable opportunity should include consideration of the impact on plant risk (from delaying the surveillanceas well as any plant configuration changes required or shutting the plant down to perform the surveillance) and impact on any analysisassumptions, in addition to unit conditions, planning, availability of personnel, 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 Guide 1.182, "Assessing and Managing Risk Before Maintenance Activities atNuclear Power Plants." This Regulatory Guide addresses considerationof temporary and aggregate risk impacts, determination of risk management action thresholds, and rtsk management action up to and including 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 with the importance of the component. Missed surveillances for important components should be analyzed quantitatively. lf the results of the risk evaluation determine the risk increase is significant, this evaluation should be used to determine the safest course of action. All missedsurveillances will be placed in the Corrective Action Program.Beaver Valley Unit 2 83.0-9 LRM Revision 67 Licensing Requirements Manual BASES LRS Applicability B 3.0 LRS 3.0.3 (continued) lf a surveillance is not completed within the allowed delay period, then theequipment is considered inoperable/Nonfunctional or the variable is considered outside the specified limits and the Completion Times of the Required Actions for the applicable LR Action Condition begins immediately upon expiration of the delay period. lf a surveillance is failed within 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 begin immediately upon the failure of the surveillance. Completion of the surveillance within the delay period allowed by this Specification, or within the Allowed Outage Time of the applicable ACTIONS, restores compliance with LRS 3.0.1. Beaver Valley Unit 2B 3.0 - 10 LRM Revision 67 Licensing Requirements Manual B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.1 - B 3.1.8 Boration Systems BASES Boration SystemsB 3.1.1 - B 3.1.8 BACKGROUND The boron injection system ensures that negative reactivity control is available during each MODE of facility operation.With the RCS average temperature above 350'F, a minimum of two boron 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 undue risk to overall facility safety from injection system failures during the repair period.With the RCS average temperature less than 200"F, Low Head Safety lnjection pump may be used in lieu of the FUNCTIONAL charging pumpwith a minimum open RCS vent of 3.14 square inches. This will provide latitude for maintenance and lSl examinations on the charging system for repair or corrective action and will ensure that boration and makeup areavailable when the charging pumps are out-of-service. An open vent insures 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 Pump discharge isolation valves to the RCS cold legs, the valves must be closed prior to reducing RCS pressure below the RWST head pressure to prevent draining into the RCS. Emergency backup power is not requiredsince these valves are outside containment and can be manually operated if required, this will allow the associated diesel generator to be taken out of service for maintenance and testing.The Technical Specification limitations for a maximum of one centrifugal charging 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 can be relieved by the operation of a single PORV. Substituting a Low Head Safety Injection pump for a charging pump in MODES 5 and 6 will not increase the probability of an overpressure event since the shutoff headof the Low Head Safety Injection pumps is below the setpoint of the overpressure protection system.Beaver Valley Unit 2 8311-1LRM Revision 67 Licensing Requirements Manual BASES Boration Systems B3.1.1 -83.1.8 BACKGROUN D (continued) The boration capability of the boric acid storage system is sufficient to provide a SHUTDOWN MARGIN from all operating conditions of 1 .77o/o AUk after xenon decay and cooldown to 200"F. The maximum borationcapability requirements occur at BOL from full power peak xenon conditions 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 stable reactivity 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 from 200"F to 140'F. This condition requires either 2315 gallons of 7000 ppmborated water from the boric acid storage tanks or 10,196 gallons of 2400 ppm borated water from the refueling water storage tank.Beaver Valley Unit 2 8 31.1 -2 LRM Revision 67 Licensing Requirements ManualB 3.1 REACTIVITY CONTROL SYSTEMSB 3.1.9 Rod Position Indication - Shutdown BASES Rod Position Indication - ShutdownB 3.1.9 BACKGROUND The LR applies to the Unit 2 digital rod position indication. The rod position indication system provides indication of rod position in the control room which is used to verify that the rods are correctly positioned. In operating MODES (1 and 2), this indication is used to verify rod insertion and alignment limits which are initial conditions of Design Basis Accidents (DBAs) are met and to verify that the rods are fully inserted following a reactor trip. The requirements for Rod Position lndication in Modes 1 and 2 are specified in the Technical Specifications. ln the shutdown MODESaddressed by this LR, rod position indication only provides information to verify rod position, and is not relied on to verify the initial conditions of DBAs are met or to verify rod insertion after a reactor trip.Beaver Valley Unit 2B 3.1 .9 LRM Revision 52 Licensing Requirements Manual B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1 .10 Boron Dilution BASESBoron DilutionB 3.1 .10 BACKGROUND A minimum flow rate of at least 3000 GPM provides adequate mixing, prevents stratification and ensures that reactivity changes will be gradual during 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 2 B 3.1.10 - 1 LRM Revision 52 Licensing Requirements ManualRod Position Indication System - Shutdown Test ExceptionB 3.1.11B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.1 1 Rod Position Indication System - Shutdown Test Exception BASES BACKGROUND This test exception permits the Position Indication System to be Nonfunctional during rod drop time measurements. The exception is required 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 2 831.11 -1 LRM Revision 67 Licensing Requirements Manual B 3.3 INSTRUMENTATION B 3.3.3 Meteorological Monitoring Instrumentation BASESMeteorological Mon itoring I nstrumentationB 3.3.3 BACKGROUNDThe FUNCTIONALITY of the meteorological instrumentation ensures that sufficient 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 to evaluate the need for initiating protective measures to protect the healthand safety of the public and is consistent with the recommendations of Regulatory Guide 1.23, "Onsite Meteorological Programs."Beaver Valley Unit 2 B33.3-1 LRM Revision 67 Licensing Requirements Manual B 3.3 INSTRUMENTATION B 3.3.4 Axial Flux Difference (AFD) Monitor Alarm BASESAFD Monitor Alarm B 3.3.4 BACKGROUNDSurveillance 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 AFD monitor 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 the limits.Beaver Valley Unit 2 B 3.3.4 - 1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATION B 3.3.5 Quadrant Power Tilt Ratio (OPTR) Monitor Alarm BASES QPTR Monitor Alarm B 3.3.5 BACKGROUNDSurveillance 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 the QPTR monitor alarm is Nonfunctional, additional surveillance criteria is required by the Licensing Requirements Manual beyond the surveillance criteria required by the Technical Specifications to detect any relatively slow changes in QPTR. For those causes of core power tilt that occurquickly (e.g., a dropped rod), there are other indications of abnormality that prompt a verification of core power tilt.Beaver Valley Unit 2 B33.5-1 LRM Revision 67 Licensing Requirements Manual B 3.3 INSTRUMENTATIONB 3.3.6 Seismic Monitoring lnstrumentation BASES Seismic Monitoring InstrumentationB 3.3.6 BACKGROUND The FUNCTIONALITY of the seismic monitoring instrumentation ensures that sufficient capability is available to promptly determine the magnitude of a seismic event and evaluate the response of those features important to safety. This capability is required to permit comparison of the measured response to that used in the design basis for the facility and is consistent with the recommendations of Regulatory Guide 1.12," lnstrumentation for Earthquakes." Applicable guidance for performance of 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 the measurement tolerance provided within Regulatory Guide 1.12 by reference to ANSI N18.5. Beaver Valley Unit 2 B336-1 LRM Revision 67 Licensing Requirements Manual B 3.3 INSTRUMENTATIONB 3.3.7 Movable Incore Detectors BASES Movable lncore DetectorsB 3.3.7 BACKGROUNDThe FUNCTIONALITY of the movable incore detectors with the specified minimum complement of equipment ensures that the measurements obtained from use of this system accurately represent the spatial neutron flux distribution of the reactor core. The FUNCTIONALITY of this system is demonstrated by irradiating each detector used and determining the acceptability of its voltage curve. Guidance for changing incore detector requirements can be found in the NRC SER for License Amendments 233 and 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 monitoring the Quadrant Power Tilt Ratio when one Power Range Channel is inoperable.Beaver Valley Unit 2 B 3.3.7 - 1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATION B 3.3.8 Leading Edge Flow Meter BASESLeading Edge Flow MeterB 3.3.8 BACKGROUNDThe Leading Edge Flow Meter (LEFM) is the preferred method ofobtaining the daily calorimetric heat balance measurements. A properly operating LEFM provides superior measurement accuracy, and more reliable assurance that the reactor is being operated at a power level that is within the assumptions of the design basis accident analyses.The LEFM system provides measurements of feedwater mass flow and temperature 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 steady state 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 required calorimetric heat balance measurements, plant operation may continue at< 100% of RTP steady-state, using the existing Nuclear lnstrumentation System (NlS) indication until the next required performance of the daily power 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 calorimetric measurements using feedwater flow venturis and Resistance Temperature Detector (RTD) indications. The requirement to reduce power within one hour is based upon comparison to similar action statements in the technical specifications. The increase in likelihood that the 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 the subroutine on the plant computer system (PCS). lf the PCS isunavailable, a manual calculation that accounts for steam generator blowdown is acceptable, and may be performed in lieu of using the PCS.Beaver Valley Unit 2B 3.3.8 - 1 LRM Revision 67 Licensing Requirements Manual BASES Edge Flow MeterB 3.3.8 BACKGROU 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 they are 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 as independent contributions to determine the maximum power assumed design basis accident analyses.The plant may then be run for the next 24-hour period using this normalized 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 and inspections every 18 months is based upon the manufacturer's recommendations, and is consistent with the surveillance intervals specified for similar electronic apparatus. Additional guidance for determining steady-state THERMAL POWERtaken from NEI POSITION STATEMENT, "Guidance to Licensees on Complying 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 BVPS Operating Manual.Beaver Valley Unit 2B 3.3.8 - 2 LRM Revision 75 Licensing Requirements ManualB 3.3 INSTRUMENTATION B 3.3.9 Turbine Overspeed Protection BASESTurbine Overspeed ProtectionB 3.3.9 BACKGROUNDThis LR is provided to ensure that the turbine overspeed protection instrumentation 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 Beaver Valley 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 to 72 hours after entry into MODE 3 during station startup under certain conditions. These conditions are after any steam flow path; i.e., one main steam isolation valve, one main steam bypass valve or any other steam flow path, to the turbine is not isolated during station startup. fhe 72 hourdelay will permit entry into MODE 3 during station startup to establish steam conditions for valve testing. Testing the valve under steam conditions is more representative of plant conditions than testing when steam is isolated. The valves may be considered FUNCTIONAL prior to entry 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 - 1 LRM Revision 67 Licensing Requirements Manual B 3.3 INSTRUMENTATION B 3.3.11 Fuel Storage Pool Area Radiation Monitor BASESFuel Storage Pool Area Radiation MonitorB 3.3.1 1 BACKGROUNDThe Fuel Storage Pool Area Radiation Monitor functions to assure personnel safety around the fuel storage pool. The FUNCTIONALITY ofthis radiation monitor ensures that the radiation levels are continually measured when fuel is present in the pool or in the building and that the alarm 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 to meet the requirements for the exemption to 10 CFR 70.24, the Unit 1 Fuel Storage Pool Area Radiation Monitor is required FUNCTIONAL. As Unit 2 no longer has an exemption to 10 CFR 7A.24, Unit 2 must meet the requirements of 10 CFR 50.68, "Criticality Accident Requirements." The Unit 2 Fuel Storage Pool Area Radiation Monitor is required FUNCTIONAL to meet the criteria set forth in 10 CFR 50.68. Beaver Valley Unit 2 B33.11 -1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATION B 3-3.12 Explosive Gas Monitoring lnstrumentation BASESExplosive Gas Monitoring InstrumentationB 3.3.12 BACKGROUNDThis instrumentation includes provisions for monitoring (and controlling)the concentrations of potentially explosive gas mixtures in the waste gas holdup system. The OPERABILITY and use of this instrumentation is consistent with the requirements of General Design Criteria 60, 63 and 64of Appendix A to 10 CFR Part 50.Beaver Valley Unit 2 B 3.3.12 - 1LRM Revision 52 Licensing Requirements Manual B 3.3 INSTRUMENTATION B 3.3.13 Containment Hydrogen Analyzers BASES Containment Hydrogen AnalyzersB 3.3.13 BACKGROUND This LR is provided to ensure that the containment hydrogen analyzers are FUNCTIONAL and capable of measuring the hydrogen concentration in the containment atmosphere during a beyond design basis accident (BDBA). 10 CFR 50,44 for combustible gas control in containment was revised, 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, the hydrogen 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 the NRC L-04-012, dated January 28,2004) is an NRC commitment.Beaver Valley Unit 2 B 3.3'13 - 1LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATION B 3.3.14 Control Room lsolation Radiation Monitors BASES Control Room lsolation Radiation Monitors B 3.3.14 BACKGROUND The Control Room lsolation Radiation Monitors provide a backup function to isolate the control room. The primary means for automatic control room isolation is the containment phase B isolation signal. TheOPERABILITY requirements for the containment phase B isolation signalare specified in the technical specifications. The FUNCTIONALITY of these 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 the monitor setpoint.Beaver Valley Unit 2 B33.14-1 LRM Revision 67 Licensing Requirements ManualB 3.3 INSTRUMENTATIONB 3.3.15 Containment Area Radiation Alarm BASES Containment Area Radiation Alarm B 3.3.15 BACKGROUNDThis LR only addresses the alarm function of the containment arearadiation monitors. The indication provided by these monitors is addressed in the Post Accident Monitoring Instrumentation Technical Specification. 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 2 B33.15-1 LRM Revision 67 Licensing Requirements Manual B 3.3 INSTRUMENTATIONB 3.3.16 Accident Monitoring Instrumentation BASES Accident Monitoring lnstrumentationB 3.3.16 BACKGROUND The OPERABILITY/FUNCTIONALITY of the accident monitoring instrumentation ensures that sufficient information is available on selectedplant parameters to monitor and assess these variables during and following an accident. This capability is consistent with the recommendations of Regulatory Guide 1.97, "lnstrumentation for Light-Water-Cooled Nuclear Plants to Assess Plant Conditions During and Following an Accident," December 1975 and NUREG-0578, "TMl-2 Lessons Learned Task Force Status Report and Short-Term Recommendations."Beaver Valley Unit 2 B3316-1 LRM Revision 67 Licensing Requirements ManualB 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.1 Loop lsolation Valves - Shutdown BASES Loop lsolation Valves - ShutdownB 3.4.1 BACKGROUNDLR 3.4.1 ensures that power is removed from isolated loop isolation valveoperators when closed to perform maintenance in MODES 5 or 6 to prevent an inadvertent loop startup.LR 3.4.1 is applicable whenever an RCS loop has been isolated in MODES 5 and 6 with fuel in the reactor vessel. LR 3.4.1 is not applicable when 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 closed position 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 valve operators, the potential exists for accidental isolation of a loop with a subsequent inadvertent startup of the isolated loop. The loop isolation valves have motor operators. Therefore, these valves will maintain their last position when power is removed from the valve operator. With power applied to the valve operators, only administrative controls prevent thevalve from being operated. Although operating procedures make the occurrence of this event unlikely, the prudent action is to remove powerfrom the loop isolation valve operators. The completion time of t hour to remove power from the loop isolation valve operators is sufficient consrdering 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 valve operators. The frequency of 7 days which ensures that the power is removed from loop isolation valve operators, is based on engineering judgment, and has proven to be acceptable. Operating experience has shown that the failure rate is so low that the 7 day frequency is justified.Beaver Valley Unit 2 B 3.4.1 - 1LRM Revision 52 Licensing Requirements ManualB 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.2 Chemistry BASES Chemistry B 3.4.2 BACKGROUNDThe limitations on Reactor Coolant System chemistry ensure that corrosion of the Reactor Coolant System is minimized and reduces the potential for Reactor Coolant System leakage or failure due to stress corrosion. Maintaining the chemistry within the Steady State Limits provides 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 and temperature dependent. Corrosion studies show that operation may be continued with contaminant concentration levels in excess of the Steady State Limits, up to the Transient Limits, for the specified limited timeintervals without having a significant effect on the structural integrity of the Reactor Coolant System. The time interval permitting continuedoperation within the restrictions of the Transient Limits provides time for taking corrective actions to restore the contaminant concentrations to within the Steady State Limits.The surveillance requirements provide adequate assurance that concentrations 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 Manual B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.3 Pressurizer BASES PressurizerB 3.4.3 BACKGROUNDThe limitations imposed on the pressurizer heatup and cooldown rates and auxiliary spray water temperature differential are provided to assurethat the pressurizer is operated within the design criteria assumed for the fatigue analysis performed in accordance with the ASME Code requirements.Beaver Valley Unit 2B 3.4.3 LRM 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 Manual B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.5 Reactor Coolant System Head Vents BASES Reactor Coolant System Head VentsB 3.4.5 BACKGROUND Reactor Coolant System Vents are provided to exhaust noncondensible gases 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 pressurizer steam space via the PORV's ensures the capability exists to perform this function.The valve redundancy of the Reactor Coolant System Head vent paths serves to minimize the probability of inadvertent or irreversible actuation while 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 Plan Requirements," November 1980. These specifications, including timeframes 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 modeled in the plant-specific probabilistic safety assessment and are not creditedin the Chapter 15 accident analyses, but are a safety related means for providing letdown to achieve cold shutdown and for alternate shutdown capability. Beaver Valley Unit 2 B34.5-1 LRM Revision 67 Licensing Requirements Manual Pressurizer 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 Discharge BASES BACKGROUND The purpose of this LR is to provide assurance that the safety valves are properly maintained. The LR requires the unit be removed from the MODES 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 if necessary. Although valve operation with liquid discharge does not immediately imply a safety valve is inoperable, the LR requirement is aprudent precaution that provides additional assurance, beyond the inservice testing and inspection requirements, that the valves areevaluated for operability after a liquid discharge.Beaver Valley Unit 2 B 3.4.6LRM Revision 52 Licensing Requirements Manual B 3.6 CONTAINMENTB 3.6.1 Containment lsolation Valves BASESContainment lsolation ValvesB 3.6.1 BACKGROUND There are two types of 'administrative controls' applicable to theContainment lsolation Valves listed in Table 3.6.1-1 of this Licensing Requirements 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 Technical Specification action requirements for an inoperable containment isolation valve is unisolated are defined in the Technical Specification Bases 3.6.3. The administrative controls for Containment lsolation Valves which have Note (1) shown in Table 3.6.1-1 of this LRM are the procedures that govern 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 the specified valves to be opened on an intermittent basis under administrative controls. The NRC Safety Evaluation for BVPS Unit 1 Amendment No. 1 described the function of these valves as "required tobe opened on an intermittent basis to perform essential operating functions" 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 inferred since BVPS Unit 1 Amendment No. 1 that the'administrative controls'were these valves' normal/emergency procedures and the plant's normal/emergency operating controls because the'administrativecontrols'were not describedidefined and the documented basis discussedtheir essential operating functions. When BVPS Unit2 was initially licensed, the Unit 2 Technical Specifications were modeled after theUnit 1 Technical Specifications. Note (1)used forvalves in Penetrations 28,46,55C, 57C,87, BB, 92, 93, 978, 1058 in the original BVPS Unit 2 Technical Specifications followed this same justification as used for ClVs using 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 the Unit 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 correctly applied throughout the Table in accordance with the above basis. Some previous changes to the CIV Table had not always followed this understanding because the literal wording seemed to also fit other applications. [Note (1) only applies to those valves specified in theBeaver Valley Unit 2 B 3.6.1 - 1LRM Revision 52 Licensing Requirements Manual BASESContainment lsolation ValvesB 3.6.1 BACKGROU N D (continued) original BV-2 Technical Specifications, with the addition of the containment air lock valves as described in the BV-2 UFSAR. Note (1)does not apply to ClVs which are operated pursuant to other defined administrative controls such as for normally locked or sealed closed ClVs.l Amendment No. 66 to the BV-2 Technical Specifications added criteria to Technical Specification 314.6.1.1 and 3/4.6.3.1 allowing a locked or sealed closed CIV to be opened without declaring the CIV inoperable, inaccordance with Generic Letter 91-08. Locked or sealed closed ClVs may only be opened, without entering the LCO, if the administrative controls 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 closed ClVs are not the same 'administrative controls'for opening ClVs per Note ( 1 ).1 Amendment No. 143 to the BV-2 Technical Specifications allowed penetration flow paths isolated to comply with action requirements for inoperable containment isolation valves to be unisolated on an intermittent basis under administrative controls. The administrative controls to be used when unisolating these penetrations are also those defined in the Technical Specification Bases 3.6.3.ClVs with an automatic closure feature upon generation of a containment isolation signal or which meet General Design Criteria 57 may be opened without entering the Technical Specification only if the valve remains OPERABLE.Beaver Valley Unit 2B 3.6.1 - 2LRM Revision 52 Licensing Requirements ManualB 3.6 CONTAINMENTB 3.6.2 Containment Sump BASES Containment SumpB 3.6.2 BACKGROUND The purpose of this LR is to assure good housekeeping practice isapplied when maintenance or inspections are performed within containment. The requirements of this LR provide assurance that debris such as rags, trash, and clothing (i.e., items with the potential to clog the containment sump following a Loss of Coolant Accident (LOCA)) areremoved from the containment building. The presence of debris in the containment 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 visual inspection following containment entries for maintenance or inspection. Beaver Valley Unit 2B 3.6.2 - I LRM Revision 52 Licensing Requirements ManualB 3.7 PLANT SYSTEMS B 3.7 .1 Steam Generator Pressure/Temperature Limitation BASESSteam Gen erator Pressu relTem perature LimitationB 3.7.1 BACKGROUND Licensing Requirement 3.7.1 is applicable to each steam generator individually. The Applicability specifies the threshold conditions during which a steam generator could be pressurized such that the maximum allowable fracture toughness stress limit could be exceeded.The limitation on steam generator pressure and temperature ensures that the pressure induced stresses in the steam generators do not exceed the maximum allowable fracture toughness stress limits. The limitations of 70'F and 200 psig are based on a steam generator average impact values taken at 10'F and are sufficient to prevent brittle fracture. The applicability is limited to whenever the temperature of the primary or secondary coolant of the associated steam generator is s 70"F and the primary or secondary systems are capable of being pressurized. For the purpose of this LR, the primary system is considered no longer capable of being pressurized following depressurization to atmospheric conditions with a vent path established and all flowpaths to the generator have been isolated. The secondary side is considered no longer capable of being pressurized following depressurization to atmospheric conditions and a vent path via an open atmospheric steam dump valve/residual heatrelease valve and associated isolation valve, or removal of a steam generator manway or safety valve.Beaver Valley Unit 2 B 3.7.1 - 1LRM Revision 55 Licensing Requirements Manual B 3.7 PLANT SYSTEMS B 3.7.2 Flood Protection BASES Flood ProtectionB 3.7.2 BACKGROUND The limitation on flood level ensures that facility operation will be terminated in the event of flood conditions. The limit of elevation 695 Mean Sea Level was selected on an arbitrary basis as an appropriate flood level at which to evaluate further plant operation and initiate flood protection measures for safety related equipment. The LR limit on Ohio River elevation of 700 Mean Sea Level (actual or projected) ensures that appropriate actions are initiated per LR 3.0.3 prior to reaching an Ohio River elevation of 705 Mean Sea Level. The Ohio River elevation of 705 Mean Sea Level is the standard project flood design level for plant operation. Ohio River elevation at the intake structure can be obtained from a level instrument at the intake structure, the Unit 1 plant computer, the elevation scale on the outside of the intake structure, or by using the Montgomery Lock and Dam tailwater level. The National Weather Service (NWS)website contains an Ohio River at Montgomery Lock and Dam trend of downstream pool level referred to as "tailwater." Tailwater level is the height 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 approximately equal to the tailwater level plus the reference elevation (652.5 feet). TheMontgomery Lock and Dam tailwater level may also be obtained by contacting 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 implementing procedures.Beaver Valley Unit 2 B 3.7.2 - 1LRM Revision 78 Licensing Requirements Manual B 3.7 PLANT SYSTEMS B 3.7.3 Sealed Source Contamination BASES Sealed Source ContaminationB 3.7.3 BACKGROUNDThe limitations on sealed source contamination ensure that the total body or individual organ irradiation does not exceed allowable limits in the event of ingestion or inhalation of the source material. The limitations on removable contamination for sources requiring leak testing, including alpha emitters, is based on 10 CFR 70.39(c) limits for plutonium. Leakage of sources excluded from the requirements of this LR represent less than one maximum permissible body burden for total body irradiation if 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 of damage to a source in that group. Those sources which are frequently handled are required to be tested more often than those which are not. Sealed sources which are continuously enclosed within a shielded mechanism (i.e., sealed sources within radiation monitoring or boron measuring devices) are considered to be stored and need not be tested unless they are removed from the shielded mechanism. Beaver Valley Unit 2 B3.73-1 LRM Revision 52 Licensing Requirements Manual B 3.7 PLANT SYSTEMS B 3.7.4 Snubbers BASES BACKGROUND All snubbers are required FUNCTIONAL to ensure that the structural integrity of the reactor coolant system and all other safety-related systemsis maintained during and following a seismic or other similar event initiating dynamic loads. Snubbers excluded from this inspection program are those installed on nonsafety-related systems and then only if their failure or failure of the system on which they are installed, would have no adverse effect on any safety-related system.Snubbers are to be demonstrated and maintained FUNCTIONAL through periodic visual examination, functional testing and service life monitoring. All three aspects are now to be performed in accordance with the requirements set forth in the ASME OM Code 20A1 Edition up to and including the 2003 Addenda, Subsection ISTD, "Preservice and lnservice Examination and Testing of Dynamic Restraints (Snubbers) in Light-Water Reactor Power Plants," with additional visual examination requirements identified in the ASME BPV Code, Section Xl, paragraph lW A-2213, "Visual Examination VT-3." During the 1980's, snubber surveillance requirements were identified in three documents: Section Xl of the ASME Boiler and Pressure Vessel (B&PV) Code, a plant's Technical Specifications and Part 4 of the ASME Operation and Maintenance (OM) Code. The three documents were similar in purpose and concept - demonstrate and ensure snubber functional integrity through periodic visual examination, sample testing and service life monitoring. However, they varied enough in details tocause much confusion among utilities as to the proper requirements and course of action often resulting in redundant efforts and sometimes missed requirements. Seeing a need for better clarity and standardization, industry leaders initiated an effort to consolidate the surveillance requirements of the threedocuments into one comprehensive, single source document. The result of this effort was the publication in 1990 of the ASME OM Code,Subsection ISTD, "Preservice and lnservice Examination and Testing of Dynamic Restraints (Snubbers) in Light-Water Reactor Nuclear Power Plants." ln 1999, the NRC endorsed the use of ISTD requirements in lieu of the snubber surveillance requirements identified in Section Xl or a plant's Technical Specifications or licensee controlled documents [10 CFR 50.55a(bX3Xv)]Beaver Valley Unit 2B 3.7.4 - 1LRM Revision 67 Licensing Requirements Manual BASES BACKGROU N D (continued)When a snubber is found Nonfunctional, an engineering evaluation is performed, in addition to the determination of the snubber mode of failure,in order to determine if any safety-related component or system has been adversely affected by the Nonfunctionality of the snubber. The engineering evaluation shall determine whether or not the snubber mode of failure has imparted a significant effect or degradation on the supported component or system. LCO 3.0.8 specifies two Completion Times to restore a Nonfunctional snubber, depending on the type of system being supported. The requirements are specified in LCO 3.0.8 and its Bases. Table 3.7.4-1 provides information that ensures the Completion Times specified by LCO 3.0.8 are assigned to the appropriate snubber. Table 3.7.4-1 identifies which snubbers provide support to safety related piping and the appropriate Completion Time of 12 or 72 hours. The table contains the identification of the snubber, its system boundary, if LCO 3.0.8 applies, and the applicable Completion Time to restore the snubber to FUNCTIONAL. An entry of "No" in the LCO 3.0.8 Applicability column means 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 water hammer snubbers. Table B 3.7 .4-1 identifies water hammer snubbers and 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 - 2 LRM Revision 67 gn Of-* c'j:lm c (/)a tU a m f c a c a)E 11'l.=f o q)t_()')c ,a c c).o J$ro c.9 o't 0)t tr J c{)I n\ cf)m N=c:f-0)(tr t-q)$o m.9, o IE o o E F c o+t g CL E o ()c=o E 3 o-o o a o_o o c=o E 3 o-o o U)o-o o c 3 o!3 o-o o a o-o o m c 3 o E 3 o-o (, (f)o-o o O c 3 o E=o_o (9 a a-o o o)c'o-'o-0)'a (g o)o ro o c'(o c$!c f!o tr o)c'o-'o-o o)L o-c o.9 E a o-E f o-o-C)O c o E E o O o)C.'o-'o-o (t)L o_c o-a E a o-E=o_(L O O c o E E o C)(t)c'o-'6_o ct)!-(tr_c ().2 E a o_E f, o_o-()O c o E E o O o)c'6.'o-o).E o)o ().c$t-c)C', c a ct) c'o-'a O).g O)t-$-O.g$t-c)o).g CN o)c'6_'o-i,E o_o o O o)c'o-'a iF o-o o (L C)t o.s (u F q)o).E a (L C)t o c'$!-F q)(').g@L o F E o L o o=o o CL l-o l-o N.9]f, o o r-c)E E$_c L o+t N=(l)o)!-G-c O-a ro c)$rF,.q CI t_o (E o fit=o z o z o z o z o z a q)o z o z o z z z o z o z o z z a CI o ct o o J G o o lJ-@(0@o_a U)o_I C}o co c!(0 I\@o_U)a a_I CI o m N F-(\CI)o_c/)q o_I o o m c\l ro.f, o)(L@U)o_I (, O m N f-$O)o_a a o_I (, O m N r O)(L a@o_I CN t m N cf)(L a a o_I o_O C)N f-r c)(L a a (L I (L O C)N m f-r c)o_a a o_I o_O O N (o O O o_a a 0_I a=O c!X rr)O 0_a@o_I a I O N X (o T-O o_@a fL 1 Q I O N X f-O (L a cf)L I a I O C\t\f, N O o_a a o_I a I O N ro N O o_a a o_t a I O N X ro N O o_a a o_I (f)I C)c{IU tr z Go b3-o_q>6',O (LO-a'tff s. 1g Nco c.j m m?ula J mtr<o FTL a@co gn Of-* c'j=m U)o tIla m$f c$a c o E a)!-'=o t o)c'a c CI.()J$ro c.9 o't o t t J$I=q\c)m N=c:)_9 N!-o$q)co.2 o (I, o o E tr c o o CL E o C)o o)t-G_c o.9 ro o-E f o_o).s o)o-O c a!-to cro=o YC)LJ -C o)c'a'a o-)<G o&O (.c o E E o O o)c'a'd_o-v, G q)TL O v.c o E E o c)o)c'd_'a iF o-o o co o)c'o-'a c 3 o p o.E (u o g).g a o-o o C).E o p o-o o o.c G l-C o!C:f,!o tr a)a.9 o+t o.E$o o).c a a)a.9 o+t o c'c q)o).g U'C)a.o o+t o.g o o ct).E U)o a.q)o c\I+t o.g$!-o o).g@o a.g o c{+t o.c o-(1)o).c@C)a.q o N+h o.c$!-o o).c@o_o o O TU TL rF o a.E o!-c G E c:)c o u o_o o O tIltL o a.c$c G!c f ro o t o G q, G'=o o o-F=ro f E.5-a!CO o L q)E E CU-c!-FO(u !-o!-o N.a a$o!-q)E E$-c!-q)o=o t-o N.9.E$O!-o E E o-c r-o+-)o=o l-f a o o o O o)t--c O.9 c o IU rF.q o)t o o')t-$-c O.2]J q)$r+-.o o)t o f a o O O LL o_'-F o_E:>(L a=LL CI t-f a o ()C)LL o_'=F o-E f (L U)=LL L o E E (u o ([=a q)a (t)a q)o z o z a o o z o z o z o z o z o z o z o z o z a 0)a 0)a 0)U)q)o (!o o J (!o o lL N ro N (L a (f)(L I a-O N@O c)o_U)a+U)I O N c0@O c)o_a (f)L I a I O N X O (.o CO (L a a (L I@r O N X cq}-(o (L a a (L I a I O N c)LO@(o (L@a o_I a I O N O)N@L U)U)o_I a o o N O)N O (L a cf)(L I O o tu N m O)N O o_U)U)(L I C'o UJ N co O (L a a o_I o o tIlN c)c9 O (L a@o_I (t O u N N w O o_v)@IL I (, o tll N m N$O o_a U)(L I O o u N O)O TL a a o_I tIl=LL N O r o_a 0 IL I tll=TL C\I$LO c'.)rL (f)U)TL I tu=tL N m$]J)co (L a a o_I tIJ=LL N r O O (L a cf)L I@=LL c!N O O o_v)@o_l a=LL Nl.rlF z Go r;-bq Nd g>6',O 0- c)_u)'r. 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tO)3F:*:Xr.L Lll 6 q)I@U)t)o trb t o)3F of=xr.L Lu$Q)T a@E.>U)trb tcD o=n-C-(J:X Ll.rl o q)r U)(f)t)s, 9a)tr g)3h o5=XrL ltl$o-(/)(f)t) f/, 9q, t O::F of=XrL LU$0)I a@t Xo trb to)3f:*:X IL tU$q)-U)CN x.iP=G)tc')3f;ofi:XtL Lll t-o ct t-o GI 3 o z o z o z o z o z o z o z o z o z o z o z o ct o o J G'o o lt N It-(L a U)TL I a=U)N m O N t-o_a (f)o_I a=U)N r F-t\o_a Q o_l a=@N N N F-(L a a o_I a=CN N co N f-N (L a a (L t@=a N co N f-o_a a (L I a=a c!m c9 N F-o_cf)a o_I a=a N$f-N 0_a a o-]a=U)c{O cr)@(L CN U)L I a=@N N c/)@(L cf)a fL I a=a N co N cr)oo TL U)(f)o-I a=a N tIJ tr nZ SA.*- F ol-ll Crt J rO-o>Pro do- (r)504$ LlJ Nm^:0 t, ]tfr7 w cJ)Jrvr- tL I a U)m Licensing Requirements Manual B 3.7 PLANT SYSTEMSB 3.7.5 Standby Service Water System (SWE)BASESStandby Service Water System (SWE)B 3.7.5 BACKGROUNDThe 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 other extremely remote event would render all of the normal Service Water System (SWS) supply pumps Nonfunctional. The scenario of a postulated gasoline barge impact with the intake structure and coincident explosiondisabling the SWS is a low probability event. Nonetheless, the SWE provides defense in-depth in assuring shutdown cooling capability. The requirement to operate the SWE is not coincident with a postulated Design Basis Accident, but only for the postulated gasoline barge impact event.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 ensure the system can adequately mitigate the consequences of the postulated event. 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 is provided to prevent inadvertent plant trip on loss of running service water pump 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 event compared to more stringent requirements associated with safety relatedsystems. The ACTION statement takes into account the low probability of both trains of SWS being disabled as a result of the postulated scenario coincident with one of the SWE subsystems being FUNCTIONAL. The STAGGERED TEST BASIS for LRS 3.7.5.2 ensures that each SWE pump is periodically full flow tested.Beaver Valley Unit 2B 3.7.5 - 1 LRM Revision 69 Licensing Requirements Manual B 3.7 PLANT SYSTEMS B 3.7.6 Explosive Gas Mixture BASES Explosive Gas MixtureB 3.7.6 BACKGROUNDThis LR is provided to ensure that the concentration of potentially explosive gas mixtures contained in the waste gas holdup system is maintained below the flammability limits of hydrogen and oxygen. lsolation of the affected tank for purposes of purging andlor discharge permits the flammable gas concentrations of the tank to be reduced below the lower explosive limit in a hydrogen rich system. Maintainingthe concentration of hydrogen and oxygen below their flammability limits provides assurance that the releases of radioactive materials will be controlled in conformance with the requirements of General DesignCriterion 60 of Appendix A to 10 CFR Part 50.Beaver Valley Unit 2 B37.6-1LRM Revision 52 Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS)B 3.7.7 B 3.7 PLANT SYSTEMSSupplemental Leak Collection and Release System (SLCRS)B 3.7.7 BASES BACKGROUNDThe FUNCTIONALITY of the SLCRS provides for the filtering of postulated radioactive effluents resulting from leakage of loss of coolant accident (LOCA) activity from systems outside of the Reactor Containment building, such as Engineered Safeguards Features (ESF)equipment, prior to their release to the environment. This system also collects potential leakage of LOCA activity from the Reactor Containment building 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 an unquantifiable amount of contiguous area penetration leakage and ESFleakage effluents would in fact be coflected and filtered.Beaver Valley Unit 2B 3.7.7 - 1 LRM Revision 67 Licensing Requirements Manual125V D.C. Battery Banks Maintenance Requirements B 3.8.1B 3.8 ELECTRICAL POWER SYSTEMSB 3.8.1 125V D.C. Battery Banks Maintenance Requirements BASES BACKGROUND The provisions of this LR require periodical maintenance/inspections to be performed on the specified 125V DC battery banks. The LR includes requirements for more routine battery maintenance than required in theTechnical Specifications. As such, this LR supplements the requirements of the Technical Specifications to assure the performance of routine battery maintenance. Beaver Valley Unit 2 B 3.8.1 - 1LRM Revision 52 Licensing Requirements ManualB 3.8 ELECTRICAL POWER SYSTEMS B 3.8.2 Emergency DG 2000 Hour Rating Limit BASESEmergency DG 2000 Hour Rating Limit B 3.8.2 BACKGROUND The provisions of this LR require a periodical verification that theEmergency Diesel Generator (EDG) 2000 hour rating limit continues to be met. The verification required by this LR supplements the other EDGrequirements in the Technical Specification.Beaver Valley Unit 2 B 3.8.2 - 1LRM Revision 52 Licensing Requirements ManualMain Fuel Oil Storage Tank Maintenance RequirementsB 3.8.3B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.3 Main Fuel Oil Storage Tank Maintenance Requirements BASES BACKGROUND The provisions of this LR require a periodic draining and cleaning of each Emergency Diesel Generator (EDG) main fuel oil storage tank. The purpose of this LR is to assure a reliable supply of clean emergency diesel generator (EDG) fuel oil is available. This LR supplements theEDG Technical Specification requirements and provides additional assurance the EDG fuel oil supply is maintained with an acceptable levelof sediment that will not adversely affect EDG operation. Beaver Valley Unit 2 B 3.8.3 - 1 LRM Revision 52 Licensing Requirements Manual Crane Travel - Spent Fuel Storage Pool BuildingB 3.9.1 B 3.9 REFUELING OPERATIONS B 3.9.1 Crane Travel - Spent Fuel Storage Pool Building BASES BACKGROUNDThe 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 accident analyses.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 a period of one month or more, but less than one year.Beaver Valley Unit 2 B3.9 1-1 LRM Revision 67 Licensing Requirements Manual B 3.9 REFUELING OPERATIONS B 3.9.2 Manipulator Crane BASES Manipulator CraneB 3.9.2 BACKGROUNDThe FUNCTIONALITY requirements for the manipulator cranes ensure that: 1) manipulator cranes will be used for movement of control rods and fuel assemblies; 2) each crane has sufficient load capacity to lift a control rod or fuel assembly; and 3) the core internals and pressure vessef are protected from excessive lifting force in the event they are inadvertently engaged during lifting operations. Beaver Valley Unit 2B 3.9.2 - 1LRM Revision 67 Licensing Requirements Manual B 3.9 REFUELING OPERATIONS B 3.9.3 Decay Time BASES Decay TimeB 3.9.3 BACKGROUNDThe minimum requirement for reactor subcriticality prior to movement of irradiated fuel assemblies in the reactor vessel ensures that sufficienttime has elapsed to allow the radioactive decay of the short lived fission products. This decay time is consistent with the assumptions used in the radiological accident analyses.Also, in order to meet the thermal-hydraulic design calculationassumptions for the fuel storage pool, movement of irradiated fuel assemblies from the reactor vessel to the fuel pool requires a minimum subcritical decay time of 100 hours. This requirement is based on cooling water 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 within the assumptions of the analysis, irradiated fuel assembly movement from the vessel to the fuel pool is limited to a rate equivalent to six assemblies per hour.Beaver Valley Unit 2 B 3.9.3 - 1LRM Revision 70}}

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