Text

Rev. 99 to Licensing Requirements Manual
	ML22144A134
Person / Time
Site:	Beaver Valley
Issue date:	05/18/2022
From:	; Energy Harbor Nuclear Corp
To:	; Office of Nuclear Reactor Regulation
Shared Package
ML22144A115	List: L-22-058, Submittal of Revision 26 to Updated Final Safety Analysis Report; ML22144A114; ML22144A116; ML22144A117; ML22144A118; ML22144A119; ML22144A120; ML22144A121; ML22144A122; ML22144A123; ML22144A124; ML22144A126; ML22144A127; ML22144A128; ML22144A129; ML22144A130; ML22144A131; ML22144A132; ML22144A133; ML22144A134; ML22144A136;
References
	L-22-058
	Download: ML22144A134 (263)
	v • d • e

Unit 2 Licensing Requirements Manual (LRM) Quick Index 1.0 USE AND APPLICATION 1.0-1 3.7 PLANT SYSTEMS 3.7.1-1 1.0.1 General Description 1.0-1 3.7.1 Steam Generator P/T Limitation 3.7.1-1 1.0.2 LRM Revisions 1.0-2 3.7.2 Flood Protection 3.7.2-1 1.1 Definitions 1.1-1 3.7.3 Sealed Source Contamination 3.7.3-1 1.2 Logical Connectors 1.2-1 3.7.4 Snubbers 3.7.4-1 1.3 Completion Times 1.3-1 3.7.5 Standby Service Water System (SWE) 3.7.5-1 1.4 Frequency 1.4-1 3.7.6 Explosive Gas Mixture 3.7.6-1 3.7.7 SLCRS 3.7.7-1 3.0 LR APPLICABILITY 3.0-1 3.0 LRS APPLICABILITY 3.0-3 3.8 ELECTRICAL POWER SYSTEMS 3.8.1-1 3.8.1 125V D.C. Battery Banks Maint Rqmnts 3.8.1-1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1-1 3.8.2 EDG 2000 Hour Rating Limit 3.8.2-1 3.1.1 Boration Flow Paths - Shutdown 3.1.1-1 3.8.3 Main Fuel Oil Strg Tank Maint. Rqmnts 3.8.3-1 3.1.2 Boration Flow Paths - Operating 3.1.2-1 3.1.3 Charging Pump - Shutdown 3.1.3-1 3.9 REFUELING OPERATIONS 3.9.1-1 3.1.4 Charging Pumps - Operating 3.1.4-1 3.9.1 Crane Travel - Spent Fuel Strg Pool Bldg 3.9.1-1 3.1.5 Boric Acid Transfer Pumps - Shutdown 3.1.5-1 3.9.2 Manipulator Crane 3.9.2-1 3.1.6 Boric Acid Transfer Pumps - Operating 3.1.6-1 3.9.3 Decay Time 3.9.3-1 3.1.7 Borated Water Sources - Shutdown 3.1.7-1 3.1.8 Borated Water Sources - Operating 3.1.8-1 5.0 ADMINISTRATIVE CONTROLS 5.1-1 3.1.9 Rod Position Indication System - Shutdown 3.1.9.1 5.1 Core Operating Limits Report 5.1-1 3.1.10 Boron Dilution 3.1.10-1 5.2 Pressure and Temperature Limits Report 5.2-i 3.1.11 Rod Position Indication System - Shutdown Test 5.3 Procedure Review and Approval 5.3-1 Exceptions 3.1.11-1 5.4 Record Retention 5.4-1 3.3 INSTRUMENTATION 3.3.1-1 BASES 3.3.1 Reactor Trip System Instrumentation Response B 3.0 LR Applicability B 3.0-1 Times 3.3.1-1 B 3.0 LRS Applicability B 3.0-5 3.3.2 Engineered Safety Features Response Times B 3.1.1 - B 3.1.8 Boration Systems B 3.1.1-1 3.3.2-1 B 3.1.9 Rod Position Indication - Shutdown B 3.1.9-1 3.3.3 Meteorological Monitoring Instrumentation 3.3.3-1 B 3.1.10 Boron Dilution B 3.1.10-1 3.3.4 Axial Flux Difference (AFD) Monitor Alarm 3.3.4-1 B 3.1.11 Rod Pstn Ind Sys - Shtdn Test Exc B 3.1.11-1 3.3.5 Quadrant Power Tilt Ratio (QPTR) Monitor Alarm B 3.3.3 Meteorological Mntrng Instrumtn B 3.3.3-1 3.3.5-1 B 3.3.4 AFD Monitor Alarm B 3.3.4-1 3.3.6 Seismic Monitoring Instrumentation 3.3.6-1 B 3.3.5 QPTR Monitor Alarm B 3.3.5-1 3.3.7 Movable Incore Detectors 3.3.7-1 B 3.3.6 Seismic Monitoring Instrumentation B 3.3.6-1 3.3.8 Leading Edge Flow Meter 3.3.8-1 B 3.3.7 Movable Incore Detectors B 3.3.7-1 3.3.9 Turbine Overspeed Protection 3.3.9-1 B 3.3.8 Leading Edge Flow Meter B 3.3.8-1 3.3.10 RTS, ESFAS, and Loss of Power Trip Setpoints B 3.3.9 Turbine Overspeed Protection B 3.3.9-1 3.3.10-1 B 3.3.11 Fuel Strg Pool Area Rad Monitor B 3.3.11-1 3.3.11 Fuel Storage Pool Area Radiation Monitor B 3.3.12 Explosive Gas Mntrng Instrumtn B 3.3.12-1 3.3.11-1 B 3.3.13 Containment Hydrogen Analyzers B 3.3.13-1 3.3.12 Explosive Gas Monitoring Instrumentation B 3.3.14 Control Room Area Rad. Monitors B 3.3.14-1 3.3.12-1 B 3.3.15 Containment Area Radiation Alarm B 3.3.15-1 3.3.13 Containment Hydrogen Analyzers 3.3.13-1 B 3.3.16 Accident Monitoring Instrumentation B 3.3.16-1 3.3.14 Control Room Isolation Rad Monitors 3.3.14-1 B 3.4.1 Loop Isolation Valves - Shutdown B 3.4.1-1 3.3.15 Containment Area Radiation Alarm 3.3.15-1 B 3.4.2 Chemistry B 3.4.2-1 3.3.16 Accident Monitoring Instrumentation 3.3.16-1 B 3.4.3 Pressurizer B 3.4.3-1 B 3.4.4 DELETED 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1-1 B 3.4.5 Reactor Coolant System Head Vents B 3.4.5-1 3.4.1 Loop Isolation Valves - Shutdown 3.4.1-1 B 3.4.6 Press Sfty Vlv Lift Inv Lp Sl or Wtr Dsc B 3.4.6-1 3.4.2 Chemistry 3.4.2-1 B 3.6.1 Containment Isolation Valves B 3.6.1-1 3.4.3 Pressurizer 3.4.3-1 B 3.6.2 Containment Sump B 3.6.2-1 3.4.4 DELETED B 3.7.1 SG Pressure/Temperature Limitation B 3.7.1-1 3.4.5 RCS Head Vents 3.4.5-1 B 3.7.2 Flood Protection B 3.7.2-1 3.4.6 Pressurizer Safety Valve Lift Involving Loop Seal B 3.7.3 Sealed Source Contamination B 3.7.3-1 or Water Discharge 3.4.6-1 B 3.7.4 Snubbers B 3.7.4-1 3.4.7 RCS Pressure Isolation Valves 3.4.7-1 B 3.7.5 Standby Service Water System (SWE) B 3.7.5-1 B 3.7.6 Explosive Gas Mixture B 3.7.6-1 3.6 CONTAINMENT 3.6.1-1 B 3.7.7 SLCRS B 3.7.7-1 3.6.1 Containment Isolation Valves 3.6.1-1 B 3.8.1 125V DC Battery Bnks Maint Rqmnts B 3.8.1-1 3.6.2 Containment Sump 3.6.2-1 B 3.8.2 Emer DG 2000 Hour Rating Limit B 3.8.2-1 B 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 3.9.1-1 B 3.9.2 Manipulator Crane B 3.9.2-1 B 3.9.3 Decay Time B 3.9.3-1 Revision 1

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 98 21-067 5.1-1 10/20/21 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 5.1-15 5.1-16 5.1-17 99 22-003 3.3.14-2 2/3/22

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 95 20-029 3.0-1 4/21/20 5.3-1 B 3.0-3 20-031 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 5.1-15 5.1-16 20-043 3.3.9-3 B 3.3.9-1 20-044 3.3.6-4 B 3.3.6-1 96 20-095 3.3.3-1 11/24/20 97 19-102 3.6.1-2 5/5/21

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 87 16-048 3.7.7-3 4/8/16 88 16-039 3.3.8-2 4/26/16 89 16-050 3.9.2-2 6/10/16 90 17-041 5.1-1 5/4/17 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 5.1-15 5.1-16 91 18-017 3.7.4-2 4/13/18 92 18-009 B 3.7.7-1 6/14/18 93 18-097 3.7.4-2 9/27/18 18-122 B 3.7.4-1 94 18-120 5.1-1 11/1/18 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 5.1-15 5.1-16

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 81 14-099 3.3.16-1 5/9/14 3.3.16-2 3.3.16-3 82 14-286 5.1-1 11/14/14 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 83 15-015 3.7.7-1 2/13/15 3.7.7-2 3.7.7-3 B 3.7.7-1 84 15-063 3.7.4-2 4/17/15 B 3.7.4-1 85 15-139 5.1-1 10/14/15 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 5.1-15 5.1-16 86 16-014 3.3.7-1 1/28/16 3.3.7-2 5.1-2 5.1-3 5.1-4 5.1-5

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 79 14-071 5.2-i 4/18/14 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 80 14-016 5.1-1 5/2/14 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

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 77 13-125 B 3.7.2-1 9/25/13 78 13-204 B 3.7.2-1 12/6/13 13-172 5.2-i 5.2-1 5.2-2 5.2-3 5.2-4 5.2-5 5.2-6 5.2-7 5.2-8 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 See next page for Revision 79.

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 74 12-176 5.1-1 10/8/12 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 75 12-264 B 3.3.8-2 3/15/13 76 13-041 5.2-i 5/24/13 13-041 5.2-1 13-041 5.2-2 13-041 5.2-3 13-041 5.2-4 13-041 5.2-5 13-041 5.2-6 13-041 & 13-084 5.2-7 13-041 5.2-8 13-041 5.2-9 13-041 5.2-10 13-041 5.2-11 13-041 5.2-12 13-041 5.2-13 13-041 5.2-14 13-041 5.2-15 13-041 5.2-16 13-041 5.2-17 13-041 5.2-18 13-041 5.2-19 13-041 5.2-20 13-041 5.2-21 13-041 & 13-084 5.2-22 13-041 5.2-23 13-041 5.2-24 13-041 5.2-25 13-041 & 13-084 5.2-26 13-041 5.2-27 13-041 & 13-084 5.2-28

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 67 10-069 B 3.4.4-1 12/22/10 (continued) B 3.4.5-1 B 3.7.2-1 B 3.7.4-1 B 3.7.4-2 B 3.7.5-1 B 3.7.7-1 B 3.9.1-1 B 3.9.2-1 68 11-002 3.4.2-2 3/18/11 11-011 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 69 11-005 3.7.5-1 3/31/11 B 3.7.5-1 70 11-074 B 3.9.3-1 6/24/11 71 11-101 3.3.9-2 7/1/11 72 12-043 5.2-4 3/16/12 73 12-090 5.1-12 5/8/12 5.1-13

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 67 10-069 3.3.9-1 12/22/10 (continued) 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-ii B 3.0-1 B 3.0-2 B 3.0-3 B 3.0-4 B 3.0-5 B 3.0-6 B 3.0-7 B 3.0-8 B 3.0-9 B 3.0-10 B 3.1.1-1 B 3.1.1-2 B 3.1.11-1 B 3.3.3-1 B 3.3.4-1 B 3.3.5-1 B 3.3.6-1 B 3.3.7-1 B 3.3.8-1 B 3.3.9-1 B 3.3.11-1 B 3.3.13-1 B 3.3.14-1 B 3.3.15-1 B 3.3.16-1

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 66 09-019 3.6.1-14 10/29/09 09-125 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 67 10-069 TOC page i 12/22/10 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

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 62 07-120 3.3.14-1 10/9/08 08-107 5.2-i 5.2-1 5.2-2 5.2-3 5.2-4 5.2-5 5.2-6 5.2-7 5.2-8 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 63 09-018 3.3.9-2 4/27/09 09-005 3.8.1-1 64 09-097 5.1-11 8/6/09 5.1-12 5.1-13 65 08-187 3.3.10-3 10/22/09 08-165 3.6.1-15 3.6.1-17

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 55 07-107 3.1.3-1 3/20/08 3.1.5-1 3.1.6-1 07-175 5.2-3 07-192 3.1.3-2 08-009 B 3.7.1-1 56 07-018 1.1-1 4/24/08 08-045 3.3.2-3 08-021 3.3.10-4 3.3.10-5 08-037 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 57 08-065 3.1.11-1 5/2/08 58 08-090 B 3.3.8-1 9/4/08 59 08-121 3.3.9-2 9/11/08 60 08-151 3.3.9-2 9/18/08 61 08-158 3.3.9-2 9/24/08

BVPS-2 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date All previous Revision All previous LRM Request All LRM pages in Prior to 6/23/2007 Numbers Numbers old format 52 2-079 All LRM pages in 6/23/2007 Improved Technical Specification format 07-046 3.0-1 53 07-097 3.3.14-2 9/18/2007 2-074 3.7.4-1 3.7.4-2 B 3.7.4-1 B 3.7.4-2 54 07-122 3.7.4-1 10/12/2007 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 3.7.4-2 B 3.7.4-3 B 3.7.4-4 B 3.7.4-5 B 3.7.4-6 B 3.7.4-7 B 3.7.4-8 B 3.7.4-9 B 3.7.4-10 B 3.7.4-11 B 3.7.4-12 B 3.7.4-13 B 3.7.4-14

LICENSING REQUIREMENTS MANUAL TABLE OF CONTENTS Page No.

1.0 USE AND APPLICATION 1.0.1 General Description........................................................................................ 1.0-1 1.0.2 LRM Revisions ............................................................................................... 1.0-2 1.1 Definitions....................................................................................................... 1.1-1 1.2 Logical Connectors......................................................................................... 1.2-1 1.3 Completion Times .......................................................................................... 1.3-1 1.4 Frequency ...................................................................................................... 1.4-1 3.0 LICENSING REQUIREMENT (LR) APPLICABILITY ........................................... 3.0-1 3.0 LICENSING REQUIREMENT SURVEILLANCE (LRS) APPLICABILITY ............ 3.0-3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 Boration Flow Paths - Shutdown .................................................................... 3.1.1-1 3.1.2 Boration Flow Paths - Operating .................................................................... 3.1.2-1 3.1.3 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 ......................................................... 3.1.5-1 3.1.6 Boric Acid Transfer Pumps - Operating.......................................................... 3.1.6-1 3.1.7 Borated Water Sources - Shutdown............................................................... 3.1.7-1 3.1.8 Borated Water Sources - Operating ............................................................... 3.1.8-1 3.1.9 Rod Position Indication System - Shutdown .................................................. 3.1.9-1 3.1.10 Boron Dilution................................................................................................. 3.1.10-1 3.1.11 Rod Position Indication System - Shutdown Test Exceptions........................ 3.1.11-1 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System Instrumentation Response Times................................. 3.3.1-1 3.3.2 Engineered Safety Features Response Times............................................... 3.3.2-1 3.3.3 Meteorological Monitoring Instrumentation .................................................... 3.3.3-1 3.3.4 Axial Flux Difference (AFD) Monitor Alarm .................................................... 3.3.4-1 3.3.5 Quadrant Power Tilt Ratio (QPTR) Monitor Alarm ......................................... 3.3.5-1 3.3.6 Seismic Monitoring Instrumentation ............................................................... 3.3.6-1 3.3.7 Movable Incore Detectors .............................................................................. 3.3.7-1 3.3.8 Leading Edge Flow Meter .............................................................................. 3.3.8-1 3.3.9 Turbine Overspeed Protection ....................................................................... 3.3.9-1 3.3.10 RTS, ESFAS, and Loss of Power Trip Setpoints ........................................... 3.3.10-1 3.3.11 Fuel Storage Pool Area Radiation Monitor..................................................... 3.3.11-1 3.3.12 Explosive Gas Monitoring Instrumentation..................................................... 3.3.12-1 3.3.13 Containment Hydrogen Analyzers.................................................................. 3.3.13-1 3.3.14 Control Room Isolation Radiation Monitors.................................................... 3.3.14-1 3.3.15 Containment Area Radiation Alarm................................................................ 3.3.15-1 3.3.16 Accident Monitoring Instrumentation .............................................................. 3.3.16-1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Loop Isolation Valves - Shutdown .................................................................. 3.4.1-1 3.4.2 Chemistry ....................................................................................................... 3.4.2-1 3.4.3 Pressurizer ..................................................................................................... 3.4.3-1 3.4.4 DELETED....................................................................................................... 3.4.4-1 Beaver Valley Unit 2 i LRM 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.......... 3.4.6-1 3.4.7 RCS Pressure Isolation Valves ...................................................................... 3.4.7-1 3.6 CONTAINMENT 3.6.1 Containment Isolation Valves......................................................................... 3.6.1-1 3.6.2 Containment Sump......................................................................................... 3.6.2-1 3.7 PLANT SYSTEMS 3.7.1 Steam Generator Pressure/Temperature Limitation ...................................... 3.7.1-1 3.7.2 Flood Protection ............................................................................................. 3.7.2-1 3.7.3 Sealed Source Contamination........................................................................ 3.7.3-1 3.7.4 Snubbers ........................................................................................................ 3.7.4-1 3.7.5 Standby Service Water System (SWE) .......................................................... 3.7.5-1 3.7.6 Explosive Gas Mixture.................................................................................... 3.7.6-1 3.7.7 Supplemental Leak Collection and Release System (SLCRS) ...................... 3.7.7-1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 125V D.C. Battery Banks Maintenance Requirements .................................. 3.8.1-1 3.8.2 Emergency Diesel Generator (EDG) 2000 Hour Rating Limit ........................ 3.8.2-1 3.8.3 Main Fuel Oil Storage Tank Maintenance Requirements............................... 3.8.3-1 3.9 REFUELING OPERATIONS 3.9.1 Crane Travel - Spent Fuel Storage Pool Building .......................................... 3.9.1-1 3.9.2 Manipulator Crane.......................................................................................... 3.9.2-1 3.9.3 Decay Time .................................................................................................... 3.9.3-1 5.0 ADMINISTRATIVE CONTROLS 5.1 Core Operating Limits Report......................................................................... 5.1-1 5.2 Pressure and Temperature Limits Report ...................................................... 5.2-i 5.3 Procedure Review and Approval.................................................................... 5.3-1 5.4 Record Retention ........................................................................................... 5.4-1 Beaver Valley Unit 2 ii LRM Revision 67

Licensing Requirements Manual General 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. Items 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.g., 10 CFR 50.59 and 10 CFR 50.54(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 and is included in the LRM for consistency with the other type of information included in the LRM and for the convenience of the station for the type of control offered by the LRM document. This self-imposed information is subject to the requirements of 10 CFR 50.59; however, it is not subject to the requirements of 10 CFR 50.71(e). Other self-imposed information is listed in Section A below and is not listed in UFSAR Section 16A.

A. Information Not Incorporated by Reference from the UFSAR NONE Beaver Valley Unit 2 1.0 - 1 LRM Revision 52

Licensing Requirements Manual LRM Revisions 1.0.2 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 Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions 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 in the LRM have both LRM and TS functions and requirements. Such components are required by the LRM to be FUNCTIONAL, and are also required by TSs to be OPERABLE. In these cases, if a component is OPERABLE, it will be functional; however, if it is FUNCTIONAL, it may not be OPERABLE.

FUNCTIONAL - A structure, system or component (SSC), shall be FUNCTIONALITY FUNCTIONAL or have FUNCTIONALITY when it is capable of performing its specified function(s) as set forth in the Current License Basis. FUNCTIONALITY does not apply to specified safety functions, but does apply to the ability of non-TS SSCs to perform other specified functions that have a necessary support function.

b) The value of RATED THERMAL POWER, as defined in Technical Specification Section 1.1, is 2900 MWt.

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Licensing Requirements Manual Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors The explanation of the use of Logical Connectors contained in Technical Specification Section 1.2, "Logical Connectors" applies to the requirements contained in the LRM. Logical Connectors 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 USE AND APPLICATION 1.3 Completion Times The explanation of the use of Action Completion Times contained in Technical Specification Section 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 - 1 LRM Revision 52

Licensing Requirements Manual Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency The explanation of the use of surveillance Frequencies contained in Technical Specification Section 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 LR Applicability 3.0 3.0 LICENSING REQUIREMENT (LR) APPLICABILITY LR 3.0.1 LRs 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 3.0.2 Upon 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.

If the LR is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required unless otherwise stated.

LR 3.0.3 When an LR and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, action shall be initiated immediately to communicate the situation to the Shift Manager and document the condition in accordance with the Corrective Action Program. The safety significance of the condition shall be evaluated per NOP-OP-1009 Operability Determinations and Functionality Assessments and appropriate corrective actions initiated, within the time frame determined by the Shift Manager that shall not exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months from the time of entry into LR 3.0.3. The time frame for completion of the corrective actions shall be commensurate with the safety significance of the condition, consistent with the guidance of NOP-OP-1009.

Where corrective measures are completed that permit operation in accordance 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 administrative control solely to perform testing required to demonstrate its OPERABILITY/FUNCTIONALITY or the OPERABILITY/FUNCTIONALITY of other equipment. This is an exception to LR 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY/FUNCTIONALITY.

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Licensing Requirements Manual LR Applicability 3.0 3.0 LR Applicability (continued)

LR 3.0.5 Requirements are specified in the LRM that are referenced from the Technical Specifications. These requirements include the information contained in tables, reports, and figures (e.g., Instrumentation Response Times and the COLR). Although these requirements are contained in the LRM, they are utilized by, and referenced from, the Technical Specifications. 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 in accordance with the applicable Technical Specifications.

LR 3.0.6 Test Exception LR 3.1.11 allows the specified LR requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other LR requirements remain unchanged.

Compliance with Test Exception LRs is optional. When a Test Exception LR 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 to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable LRs.

Beaver Valley Unit 2 3.0 - 2 LRM Revision 52

Licensing Requirements Manual LRS Applicability 3.0 3.0 LICENSING REQUIREMENT SURVEILLANCE (LRS) APPLICABILITY LRS 3.0.1 LRS shall be met during the MODES or other specified conditions in the Applicability for individual LRs, unless otherwise 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 failure to meet the LR. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LR except as provided in LRS 3.0.3. LRS do not have to be performed on 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, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as "once," the above interval extension does not apply.

If a Completion Time requires periodic performance on a "once per . . ."

basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this LRS are stated in the individual Surveillances.

LRS 3.0.3 If it is discovered that a surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LR not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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 risk evaluation shall be performed for any surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

If the surveillance is not performed within the delay period, the LR must immediately be declared not met, and the applicable ACTION(s) must be entered.

When the surveillance is performed within the delay period and the surveillance is not met, the LR must immediately be declared not met, and the applicable ACTION(s) must be entered.

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Licensing Requirements Manual Boration Flow Paths - Shutdown 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 Boration Flow Paths - Shutdown LR 3.1.1 One of the following boron injection flow paths shall be FUNCTIONAL:

a. 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 in accordance with LR 3.1.7, or

b. The flow path from the refueling water storage tank (RWST) via a charging pump or a low head safety injection pump (with an open RCS 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.

APPLICABILITY: MODES 5 and 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required flow path A.1 Suspend all operations Immediately Nonfunctional. involving CORE ALTERATIONS or positive reactivity changes.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.1.1 Cycle each testable power operated or automatic valve 7 days in the flow path through at least one complete cycle of full travel.

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Licensing Requirements Manual Boration Flow Paths - Shutdown 3.1.1 LICENSING REQUIREMENT SURVEILLANCES (continued)

SURVEILLANCE FREQUENCY LRS 3.1.1.2 -------------------------------------------------------------------------

- NOTE -

Only required to be met when a flow path from the boric acid storage tanks is required FUNCTIONAL and the ambient air temperature of the Auxiliary Building is

< 65°F.

Verify the temperature of the heat traced portion of the 7 days flow path is 65°F.

LRS 3.1.1.3 Verify each valve (manual, power operated or 31 days automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.

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Licensing Requirements Manual Boration Flow Paths - Operating 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Boration Flow Paths - Operating LR 3.1.2 Each of the following boron injection flow paths shall be FUNCTIONAL:

a. The flow path from the boric acid tanks via a boric acid transfer pump and one charging pump to the Reactor Coolant System, and

b. The flow path from the refueling water storage tank via one charging pump to the Reactor Coolant System.

- NOTES -

1. 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.

2. 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 for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 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.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Flow path from the boric A.1 Restore the flow path to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months acid tanks Nonfunctional. FUNCTIONAL status.

B. Required Action, and B.1 Apply LR 3.0.3. Immediately associated Completion Time of Condition A not met.

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Licensing Requirements Manual Boration Flow Paths - Operating 3.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Flow path from the C.1 Restore the flow path to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months refueling water storage FUNCTIONAL status.

tank Nonfunctional.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition C not AND met.

D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.2.1 Cycle each testable power operated or automatic valve 92 days in the flow path through at least one complete cycle of full travel.

LRS 3.1.2.2 -------------------------------------------------------------------------

- NOTE -

Only required to be met when the ambient air temperature of the Auxiliary Building is < 65°F.

Verify the temperature of the heat traced portion of the 7 days flow path from the boric acid tanks is 65°F.

LRS 3.1.2.3 Verify each valve (manual, power operated or 31 days automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.

LRS 3.1.2.4 Cycle each power operated (excluding automatic) valve 18 months during in the flow path that is not testable during plant shutdown operation, through at least one complete cycle of full travel.

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Licensing Requirements Manual Charging Pump - Shutdown 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Charging Pump - Shutdown LR 3.1.3 One of the following pumps shall be FUNCTIONAL as specified below:

a. A charging pump in the boron injection flow path required FUNCTIONAL in accordance with LR 3.1.1, or

b. A low head safety injection pump (with an open Reactor Coolant System vent of 3.14 square inches).

APPLICABILITY: MODES 5 and 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required pump A.1 Suspend all operations Immediately Nonfunctional. involving CORE ALTERATIONS or positive reactivity changes.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.3.1 The required charging pump shall be demonstrated In Accordance FUNCTIONAL pursuant to Technical Specification with SR 3.5.2.4 Surveillance SR 3.5.2.4.

LRS 3.1.3.2 The required low head safety injection pump shall be In Accordance demonstrated FUNCTIONAL by: with the applicable SRs or

a. Verification of a FUNCTIONAL RWST pursuant to LRS LRS 3.1.7.1 and LRS 3.1.7.3,

b. Verification of a FUNCTIONAL low head safety injection pump pursuant to Technical Specification Surveillance SR 3.5.2.4, and

c. Verification that the vent is open in accordance with Technical Specification Surveillance SR 3.4.12.3.

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Licensing Requirements Manual Charging Pump - Shutdown 3.1.3 LICENSING REQUIREMENT SURVEILLANCES (continued)

SURVEILLANCE FREQUENCY LRS 3.1.3.3 -------------------------------------------------------------------------

- NOTE -

Only required to be met when the low head safety injection pump is required FUNCTIONAL in accordance with LR 3.1.3.b.

Verify a FUNCTIONAL low head safety injection flow 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months path from the RWST to the Reactor Coolant System.

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Licensing Requirements Manual Charging Pumps - Operating 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Charging Pumps - Operating LR 3.1.4 Two charging pumps shall be FUNCTIONAL.

- NOTES -

1. 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.

2. 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 for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 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.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required charging A.1 Restore the charging pump 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pump Nonfunctional. to FUNCTIONAL status.

B. Required Action and B.1 Apply LR 3.0.3. Immediately associated Completion Time of Condition A not met.

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Licensing Requirements Manual Charging Pumps - Operating 3.1.4 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.4.1 Each required charging pump shall be demonstrated In Accordance FUNCTIONAL pursuant to Technical Specification with SR 3.5.2.4 Surveillance SR 3.5.2.4.

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Licensing Requirements Manual Boric Acid Transfer Pumps - Shutdown 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Boric Acid Transfer Pumps - Shutdown LR 3.1.5 One boric acid transfer pump shall be FUNCTIONAL.

APPLICABILITY: In MODES 5 and 6 when the associated flow path from the boric acid storage system is required FUNCTIONAL in accordance with LR 3.1.1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required boric acid A.1 Suspend all operations Immediately transfer pump involving CORE Nonfunctional. ALTERATIONS or positive reactivity changes.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.5.1 The required boric acid transfer pump shall be In accordance demonstrated FUNCTIONAL by verifying, that on with the Inservice recirculation flow, the pump develops a differential Testing Program pressure of 102 psid.

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Licensing Requirements Manual Boric Acid Transfer Pumps - Operating 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Boric Acid Transfer Pumps - Operating LR 3.1.6 One boric acid transfer pump shall be FUNCTIONAL.

APPLICABILITY: In MODES 1, 2, 3, and 4 when the associated flow path from the boric acid tanks is required FUNCTIONAL in accordance with LR 3.1.2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required boric acid A.1 Restore the boric acid 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months transfer pump transfer pump to Nonfunctional. FUNCTIONAL status.

B. Required Action and B.1 Apply LR 3.0.3. Immediately associated Completion Time of Condition A not met.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.6.1 The required boric acid transfer pump shall be In Accordance demonstrated FUNCTIONAL by verifying, that on with the Inservice recirculation flow, the pump develops a differential Testing Program pressure of 102 psid.

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Licensing Requirements Manual Borated Water Sources - Shutdown 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Borated Water Sources - Shutdown LR 3.1.7 One of the following borated water sources shall 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, and

3. 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 2400 ppm, and

3. A minimum solution temperature of 45°F.

APPLICABILITY: MODES 5 and 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required borated water A.1 Suspend all operations Immediately source Nonfunctional. involving CORE ALTERATIONS or positive reactivity changes.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.7.1 --------------------------------------------------------------------------

- NOTE -

Only required to be met when the outside ambient air temperature is < 45°F.

Verify the required RWST temperature. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Beaver Valley Unit 2 3.1.7 - 1 LRM Revision 67

Licensing Requirements Manual Borated Water Sources - Shutdown 3.1.7 LICENSING REQUIREMENT SURVEILLANCES (continued)

SURVEILLANCE FREQUENCY LRS 3.1.7.2 Verify the required boric acid storage tank solution 7 days temperature.

LRS 3.1.7.3 The required borated water source shall be 7 days demonstrated FUNCTIONAL by:

a. Verifying the boron concentration of the water, and

b. Verifying the water level of the tank.

Beaver Valley Unit 2 3.1.7 - 2 LRM Revision 67

Licensing Requirements Manual Borated Water Sources - Operating 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Borated Water Sources - Operating LR 3.1.8 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, and

c. A minimum solution temperature of 65°F.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boric Acid Storage System A.1 Restore the storage 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Nonfunctional. system to FUNCTIONAL status.

B. Required Action and B.1 Apply LR 3.0.3. Immediately associated Completion Time of Condition A not met.

Beaver Valley Unit 2 3.1.8 - 1 LRM Revision 67

Licensing Requirements Manual Borated Water Sources - Operating 3.1.8 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.8.1 The Boric Acid Storage System shall be demonstrated 7 days FUNCTIONAL 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.

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Licensing Requirements Manual Rod Position Indication System - Shutdown 3.1.9 3.1 REACTIVITY CONTROL SYSTEMS 3.1.9 Rod Position Indication System - Shutdown LR 3.1.9 One 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.

APPLICABILITY: MODES 3, 4, and 5 with the reactor trip system breakers in the closed position.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required digital rod A.1 Open the reactor trip Immediately position indicator(s) system breakers.

Nonfunctional.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.9.1 Verify required digital rod position indicator(s) In accordance FUNCTIONAL in accordance with Technical with applicable Specification Surveillance SR 3.1.7.2.1. SR.

Beaver Valley Unit 2 3.1.9 - 1 LRM Revision 67

Licensing Requirements Manual Boron Dilution 3.1.10 3.1 REACTIVITY CONTROL SYSTEMS 3.1.10 Boron Dilution LR 3.1.10 The flow rate of reactor coolant through the core shall be 3000 gpm.

APPLICABILITY: In all MODES when a reduction in Reactor Coolant System (RCS) boron concentration is being made.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Flow rate of reactor coolant A.1 Suspend all operations Immediately through the core involving a reduction in

< 3000 gpm. boron concentration of the RCS.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.10.1 The flow rate of reactor coolant through the core shall Prior to the start be determined to be 3000 gpm by either: of and at least once per hour

a. Verifying at least one reactor coolant pump is in during a reduction operation, or in the RCS boron concentration

b. Verifying that at least one RHR pump is in operation and supplying 3000 gpm through the core.

Beaver Valley Unit 2 3.1.10 - 1 LRM Revision 52

Licensing Requirements Manual Rod Position Indication System - Shutdown Test Exceptions 3.1.11 3.1 REACTIVITY CONTROL SYSTEMS 3.1.11 Rod Position Indication System - Shutdown Test Exceptions LR 3.1.11 The limitations of LR 3.1.9 may be suspended during the performance of individual full-length shutdown and control rod drop time measurements 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 calibration of the Digital Rod Position Indication System provided: (1) Keff 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 withdrawal of the rods.

APPLICABILITY: MODES 3, 4, and 5 during performance of rod drop time measurements.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Position Indication A.1 Open the Reactor trip Immediately Systems Nonfunctional or breakers.

with more than one bank of rods withdrawn.

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Licensing Requirements Manual Rod Position Indication System - Shutdown Test Exceptions 3.1.11 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.11.1 The Position Indication Systems shall be determined to Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months be FUNCTIONAL during rod drop time measurements prior to the start by verifying the Demand Position Indication System and of rod drop time the Digital Rod Position Indication System agree: measurements and at least once

a. Within 12 steps when the rods are stationary, and per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter

b. Within 24 steps during rod motion.

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Licensing Requirements Manual Reactor Trip System Instrumentation Response Times 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System Instrumentation Response Times LR 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.

APPLICABILITY: As specified in TS 3.3.1.

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Licensing Requirements Manual Reactor Trip System Instrumentation Response Times 3.3.1 TABLE 3.3.1-1 (Page 1 of 2)

REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES FUNCTION RESPONSE TIME

1. Manual Reactor Trip NOT APPLICABLE

2. Power Range, Neutron Flux 0.5 second(1)

3. Power Range, Neutron Flux, High Positive Rate NOT APPLICABLE

4. Intermediate Range, Neutron Flux NOT APPLICABLE

5. Source Range, Neutron Flux NOT APPLICABLE (Below P-10)

6. Overtemperature T Variable(1)(2)

7. Overpower T Variable(1)(2)

8. a. Pressurizer Pressure - Low 2.0 seconds

b. Pressurizer Pressure - High 2.0 seconds

9. Pressurizer Water Level - High NOT APPLICABLE

10. Reactor Coolant Flow - Low

a. Single loop 1.0 second

b. Two loops 1.0 second

11. Reactor Coolant Pump (RCP) Breaker Position Trip NOT APPLICABLE

12. Undervoltage-RCPs 1.5 seconds

13. Underfrequency-RCPs 0.9 second

14. Steam Generator Water Level - Low Low 2.0 seconds

15. Turbine Trip

a. Emergency Trip Header NOT APPLICABLE Low Pressure

b. Turbine Stop Valve Closure NOT APPLICABLE

16. Safety Injection Input from ESFAS NOT APPLICABLE

17. Reactor Trip System Interlocks NOT APPLICABLE 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 of 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.

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Licensing Requirements Manual Reactor Trip System Instrumentation 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 acceptance criteria 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 the nearest 1/10 second, and obtain the corresponding acceptance criteria.

Final Accept. Final Accept. Final Accept. Final Accept. Final Accept. Final Accept.

Criteria Criteria Criteria Criteria Criteria Criteria RTD Time Overtemperature Overpower Measured T - RTD Time Overtemperature Overpower Measured T -

Response T - Tavg Input T - Tavg Input T Input Response T - Tavg Input T - Tavg Input T Input 2.0 2.862 2.643 9.883 4.6 2.366 2.264 7.367 2.1 2.840 2.625 9.777 4.7 2.349 2.251 7.279 2.2 2.818 2.609 9.672 4.8 2.333 2.239 7.190 2.3 2.796 2.592 9.568 4.9 2.316 2.226 7.102 2.4 2.775 2.575 9.464 5.0 2.300 2.214 7.014 2.5 2.754 2.559 9.362 5.1 2.283 2.202 6.927 2.6 2.733 2.543 9.260 5.2 2.267 2.190 6.840 2.7 2.713 2.527 9.159 5.3 2.250 2.178 6.754 2.8 2.693 2.512 9.059 5.4 2.235 2.166 6.668 2.9 2.673 2.497 8.960 5.5 2.218 2.154 6.582 3.0 2.654 2.481 8.861 5.6 2.202 2.143 6.497 3.1 2.634 2.467 8.763 5.7 2.187 2.131 6.412 3.2 2.615 2.452 8.666 5.8 2.171 2.120 6.327 3.3 2.596 2.438 8.569 5.9 2.156 2.108 6.242 3.4 2.578 2.423 8.473 6.0 2.140 2.097 6.158 3.5 2.559 2.409 8.378 6.1 2.040 1.997 6.058 3.6 2.541 2.395 8.283 6.2 1.940 1.897 5.958 3.7 2.523 2.382 8.189 6.3 1.840 1.797 5.858 3.8 2.505 2.368 8.096 6.4 1.740 1.697 5.758 3.9 2.487 2.354 8.003 6.5 1.640 1.597 5.658 4.0 2.469 2.341 7.911 6.6 1.540 1.497 5.558 4.1 2.452 2.328 7.819 6.7 1.440 1.397 5.458 4.2 2.434 2.315 7.728 6.8 1.340 1.297 5.358 4.3 2.417 2.302 7.637 6.9 1.240 1.197 5.258 4.4 2.400 2.289 7.547 7.0 1.140 1.097 5.158 4.5 2.383 2.276 7.457 The following are the response time acceptance criteria for the pressurizer pressure and neutron flux input to the Overtemperature T function:

Pressurizer pressure input: 2.0 seconds.

Neutron detector input (for f(I) penalty): 2.0 seconds.

All of the channel time responses noted above for the Overtemperature T, Overpower T, and measured T 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 are based 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 Engineered Safety Features Response Times 3.3.2 3.3 INSTRUMENTATION 3.3.2 Engineered Safety Features Response Times LR 3.3.2 Each engineered safety feature response time listed in Table 3.3.2-1 shall be maintained in the manner specified in Technical Specification (TS) 3.3.2, Engineered Safety Feature Actuation System Instrumentation and TS 3.3.5, Loss of Power Diesel Generator Start and Bus Separation Instrumentation as applicable.

APPLICABILITY: As specified in the applicable TS.

Beaver Valley Unit 2 3.3.2 - 1 LRM Revision 52

Licensing Requirements Manual Engineered Safety Features Response Times 3.3.2 TABLE 3.3.2-1 (Page 1 of 4)

ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS

1. Manual

a. Safety Injection (ECCS) Not Applicable Feedwater Isolation Not Applicable Reactor Trip (SI) Not Applicable Containment Isolation-Phase "A" Not Applicable Containment Vent and Purge Isolation Not Applicable Auxiliary Feedwater Pumps Not Applicable Service Water System Not Applicable

b. Containment Quench Spray Pumps Not Applicable Containment Quench Spray Valves Not Applicable Containment Isolation-Phase "B" Not Applicable

c. Containment Isolation-Phase "A" Not Applicable

d. Control Room Ventilation Isolation Not Applicable

2. Containment Pressure-High

a. Safety Injection (ECCS) 27.0(3)

b. Reactor Trip (from SI) 3.0

c. Feedwater Isolation 7.0(6)

d. Containment Isolation-Phase "A" 61.5(9)/115.5(10)

e. Auxiliary Feedwater Pumps 60.0

f. Service Water System 72.5(7)/181.5(8)

Beaver Valley Unit 2 3.3.2 - 2 LRM Revision 52

Licensing Requirements Manual Engineered Safety Features Response Times 3.3.2 TABLE 3.3.2-1 (Page 2 of 4)

ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS

3. Pressurizer Pressure-Low

a. Safety Injection (ECCS) 17.0(11)/27.0(3)/27.0(4)

b. Reactor Trip (from SI) 3.0

c. Feedwater Isolation 7.0(6)

d. Containment Isolation-Phase "A" 61.0(9)/115.0(10)

e. Auxiliary Feedwater Pumps 60.0

f. Service Water System 72.0(7)/181.0(8)

4. Steam Line Pressure-Low

a. Safety Injection (ECCS) 37.0(5)/27.0(4)

b. Reactor Trip (from SI) 3.0

c. Feedwater Isolation 7.0(6)

d. Containment Isolation-Phase "A" 61.0(9)/115.0(10)

e. Auxiliary Feedwater Pumps 60.0

f. Service Water System 72.0(7)/181.0(8)

g. Steam Line Isolation 7.0(13)

5. Containment Pressure-High High

a. Containment Quench Spray 74.5(12)

b. Containment Isolation-Phase "B" Not Applicable

c. Control Room Ventilation Isolation (on CIB) 22.0(9)/77.0(10)

d. Recirculation Spray Not Applicable

6. Steam Generator Water Level-High High

a. Turbine Trip Not Applicable

b. Feedwater Isolation 7.0(6)

Beaver Valley Unit 2 3.3.2 - 3 LRM Revision 56

Licensing Requirements Manual Engineered 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. Containment Pressure-Intermediate High High

a. Steam Line Isolation 7.0(13)

8. Steamline Pressure Rate-High Negative

a. Steamline Isolation 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 +/- 5 sec.

Undervoltage (Degraded voltage)

10. Steam Generator Water Level-Low Low

a. Motor-driven Auxiliary 60.0 Feedwater Pumps(1)

b. Turbine-driven Auxiliary 60.0 Feedwater Pump(2)

11. Undervoltage RCP

a. Turbine-driven Auxiliary 60.0 Feedwater Pump

12. Trip of Main Feedwater Pumps

a. Motor-driven Auxiliary 60.0 Feedwater Pumps Beaver Valley Unit 2 3.3.2 - 4 LRM Revision 52

Licensing Requirements Manual Engineered Safety Features Response Times 3.3.2 TABLE 3.3.2-1 (Page 4 of 4)

ENGINEERED SAFETY FEATURES RESPONSE TIMES TABLE NOTATION (1) on 2/3 in 2/3 Steam Generators (2) on 2/3 any Steam Generator (3) Diesel generator starting and sequence loading delays included. Response time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal charging pumps and Low Head Safety Injection 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.

(4) Diesel generator starting and sequence loading delays not included. Offsite power available. Response time limit includes opening of valves to establish SI 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.

(5) Diesel generator starting and sequence loading delays included. Response time limit includes opening of valves to establish SI 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.

(6) 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 shall be limited such that when added to the actuation circuitry time the total response time does not exceed 7 seconds.

(7) Diesel generator starting and sequence loading delays included. Response time limit includes attainment of discharge pressure for service water pumps.

(8) 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.

(9) Diesel generator starting and sequence loading delays not included. Offsite power available. Response time limit includes operation of valves/dampers.

(10) Diesel generator starting and sequence loading delays included. Response time limit includes operation of valves/dampers.

(11) Diesel generator starting and sequence loading delays not included. Offsite power available. Response time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal charging pumps and Low Head Safety Injection 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.

(12) Diesel generator starting and sequence loading delays included. Response time does not include operation of the valves because Quench Spray valves are maintained open.

(13) The main steam isolation valve isolation time shall be limited to 6 seconds.

Beaver Valley Unit 2 3.3.2 - 5 LRM Revision 52

Licensing Requirements Manual Meteorological Monitoring Instrumentation 3.3.3 3.3 INSTRUMENTATION 3.3.3 Meteorological Monitoring Instrumentation LR 3.3.3 The meteorological monitoring instrumentation channels specified in Table 3.3.3-1 shall be FUNCTIONAL.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Suspend all release of Immediately meteorological monitoring gaseous radioactive channels Nonfunctional. material from the radwaste gas decay tanks.

B. One or more required B.1 Apply LR 3.0.3. Immediately meteorological monitoring channels Nonfunctional for more than 7 days.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.3.1 Perform a CHANNEL CHECK on each required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months meteorological monitoring instrument channel.

LRS 3.3.3.2 Perform a CHANNEL CALIBRATION on each required 184 days meteorological monitoring instrument channel.

Beaver Valley Unit 2 3.3.3 - 1 LRM Revision 96

Licensing Requirements Manual Meteorological Monitoring Instrumentation 3.3.3 TABLE 3.3.3-1 (Page 1 of 1)

METEOROLOGICAL MONITORING INSTRUMENTATION INSTRUMENT MINIMUM REQUIRED INSTRUMENT ACCURACY CHANNELS

1. WIND SPEED

a. Nominal Elev. 500' +/- 0.5 mph* 1

b. Nominal Elev. 150' +/- 0.5 mph* 1

c. Nominal Elev. 35' +/- 0.5 mph* 1

2. WIND DIRECTION

a. Nominal Elev. 500' +/- 5° 1

b. Nominal Elev. 150' +/- 5° 1

c. Nominal Elev. 35' +/- 5° 1

3. AIR TEMPERATURE T

a. T Elev. 500' - 35' +/- 0.1°C 1

b. T Elev. 150' - 35' +/- 0.1°C 1

Starting speed of anemometer shall be < 1 mph.

Beaver Valley Unit 2 3.3.3 - 2 LRM Revision 52

Licensing Requirements Manual Axial Flux Difference (AFD) Monitor Alarm 3.3.4 3.3 INSTRUMENTATION 3.3.4 Axial Flux Difference (AFD) Monitor Alarm LR 3.3.4 AFD shall be monitored and logged.

APPLICABILITY: When the AFD monitor alarm is Nonfunctional and power is > 50%

RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LR not met. A.1 Apply LR 3.0.3. Immediately LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.4.1 Monitor and log the indicated AFD for each Once per hour for FUNCTIONAL channel. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND Once per 30 minutes thereafter Beaver Valley Unit 2 3.3.4 - 1 LRM Revision 67

Licensing Requirements Manual Quadrant Power Tilt Ratio (QPTR) Monitor Alarm 3.3.5 3.3 INSTRUMENTATION 3.3.5 Quadrant Power Tilt Ratio (QPTR) Monitor Alarm LR 3.3.5 QPTR shall be verified within the limits.

APPLICABILITY: When the QPTR monitor alarm is Nonfunctional and power is > 50%

RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LR not met. A.1 Apply LR 3.0.3. Immediately LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.5.1 Verify QPTR is within the limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Beaver Valley Unit 2 3.3.5 - 1 LRM Revision 67

Licensing Requirements Manual Seismic Monitoring Instrumentation 3.3.6 3.3 INSTRUMENTATION 3.3.6 Seismic Monitoring Instrumentation LR 3.3.6 The seismic monitoring instrumentation specified in Table 3.3.6-1 shall be FUNCTIONAL.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore the Nonfunctional 30 days seismic monitoring instrument(s) to instruments Nonfunctional. FUNCTIONAL status.

B. One or more required B.1 Prepare and present a 10 days seismic monitoring report to the onsite safety instruments Nonfunctional review committee for their for more than 30 days. review outlining the cause of the malfunction and the plans for restoring the instrument(s) to FUNCTIONAL status.

Beaver Valley Unit 2 3.3.6 - 1 LRM Revision 67

Licensing Requirements Manual Seismic Monitoring Instrumentation 3.3.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Seismic event 0.02g. C.1 Report to NRC. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND C.2 Restore actuated 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months instruments to FUNCTIONAL status.

AND C.3 Perform CHANNEL 30 days CALIBRATION on actuated instruments.

AND C.4 Retrieve and analyze data 30 days from actuated instruments to determine magnitude of vibratory ground motion and prepare and submit a special report in accordance with 10 CFR 50.4 describing the magnitude, frequency spectrum and resultant effect upon facility features important to safety.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.6.1 Perform a CHANNEL CHECK as specified in Table In accordance 3.3.6-2. with Table 3.3.6-2 LRS 3.3.6.2 Perform a CHANNEL OPERATIONAL TEST as In accordance specified in Table 3.3.6-2. with Table 3.3.6-2 LRS 3.3.6.3 Perform a CHANNEL CALIBRATION as specified in In accordance Table 3.3.6-2. with Table 3.3.6-2 Beaver Valley Unit 2 3.3.6 - 2 LRM Revision 67

Licensing Requirements Manual Seismic Monitoring Instrumentation 3.3.6 TABLE 3.3.6-1 (Page 1 of 1)

SEISMIC MONITORING INSTRUMENTATION MEASUREMENT REQUIRED INSTRUMENTS AND SENSOR LOCATIONS RANGE(1) INSTRUMENTS

1. TRIAXIAL TIME-HISTORY ACCELEROGRAPHS (2)(3)(4)

a. Containment Mat (2ERS-ACS-1) +/-1g 1

b. Containment Operating Floor (2ERS-ACS-2) +/-1g 1

c. Switchyard (2ERS-ACS-3) +/-1g 1

d. Containment Building (2ERS-RRA-1) +/-1g 1

e. Aux. Building Mat (2ERS-RRA-2) +/-1g 1

f. Aux. Building (2ERS-RRA-3) +/-1g 1

2. TRIAXIAL PEAK ACCELEROGRAPHS

a. Containment Building - RHS heat exchanger +/-2g 1 (2ERS-PRA-1)

b. Containment Building - Six Inch SI Pipe +/-2g 1 (2ERS-PRA-2)

c. Aux. Building (2ERS-PRA-3) +/-5g 1

3. RESPONSE SPECTRUM ANALYZER

a. Control Room N/A 1 NOTES (1) Measurement range tolerance is +/- 5% of upper range value.

(2) Units a, b, c are wired to accelerograph recorders in the Control Room. Units d, e, and f are self-contained units.

(3) Each accelerograph trigger setpoint is set at 0.02g except for item "b" (4) 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 - 3 LRM Revision 52

Licensing Requirements Manual Seismic Monitoring Instrumentation 3.3.6 TABLE 3.3.6-2 (Page 1 of 1)

SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL CHANNEL CHANNEL OPERATIONAL INSTRUMENTS AND SENSOR LOCATIONS CHECK CALIBRATION TEST

1. TRIAXIAL TIME-HISTORY ACCELEROGRAPHS

a. Containment Mat (2ERS-ACS-1) M R* SA

b. Containment Operating floor M R* SA (2ERS-ACS-2)

c. Switchyard (2ERS-ACS-3) M R* SA

d. Containment Building (2ERS-RRA-1) N/A R* SA

e. Aux. Building Mat (2ERS-RRA-2) M R* SA

f. Aux. Building (2ERS-RRA-3) M R* SA

2. TRIAXIAL PEAK ACCELEROGRAPHS

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

b. Containment Building - Six inch SI N/A R N/A pipe (2ERS-PRA-2)

c. Aux. Building (2ERS-PRA-3) N/A R N/A

3. RESPONSE SPECTRUM ANALYZER

a. Control Room N/A N/A R*

The channel calibrations and associated channel operational test will not be performed in April 2020 (2R21).

M = 31 days R = 18 months SA = 184 days Beaver Valley Unit 2 3.3.6 - 4 LRM Revision 95

Licensing Requirements Manual Movable Incore Detectors 3.3.7 3.3 INSTRUMENTATION 3.3.7 Movable Incore Detectors LR 3.3.7 The movable incore detection system shall be FUNCTIONAL with:

a. At least 38 detector thimbles,

b. A minimum of 2 detector thimbles per core quadrant, and

c. Sufficient movable detectors, drive, and readout equipment to map these thimbles.

- NOTE -

Except for flux maps during the startup physics program, up to and including the first full power flux map, the movable incore detector system will remain FUNCTIONAL with 37 but 25 detector thimbles, if there is a minimum of three detector thimbles per core quadrant and an additional uncertainty is applied to the measured values of FN H and FQ(Z) as specified in the COLR.

APPLICABILITY: 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 FN H and FQ(Z).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Movable incore detection A.1 Suspend use of the system Immediately system Nonfunctional. for the above applicable monitoring or calibration functions.

Beaver Valley Unit 2 3.3.7 - 1 LRM Revision 86

Licensing Requirements Manual Movable Incore Detectors 3.3.7 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.7.1 The incore movable detection system shall be Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months demonstrated FUNCTIONAL by normalizing each prior to use detector output to be used for:

a. Recalibration of the excore axial flux offset detection system, or

b. Monitoring the QUADRANT POWER TILT RATIO, or

c. Measurement of FN H and FQ(Z).

Beaver Valley Unit 2 3.3.7 - 2 LRM Revision 86

Licensing Requirements Manual Leading Edge Flow Meter 3.3.8 3.3 INSTRUMENTATION 3.3.8 Leading Edge Flow Meter LR 3.3.8 A FUNCTIONAL Leading Edge Flow Meter (LEFM) shall be used in the performance of the daily calorimetric heat balance measurements to determine steady-state THERMAL POWER as required by Technical Specification Surveillance SR 3.3.1.2.

APPLICABILITY: MODE 1 when steady-state THERMAL POWER is > 98.6% of RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LEFM Nonfunctional. A.1 Restore LEFM to Prior to the next FUNCTIONAL status. required daily calorimetric heat balance measurement.

B. Required Action and B.1 Reduce steady-state 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion THERMAL POWER to Time not met. 98.6% of RTP.

AND B.2 Perform the calorimetric In accordance with the heat balance measurement requirements of using the feedwater flow SR 3.3.1.2 venturis and Resistance Temperature Detector (RTD) indications.

AND B.3 Maintain THERMAL Until the LEFM is POWER at 98.6% of restored to RTP steady state. FUNCTIONAL status and the calorimetric heat balance measurement has been performed using the LEFM Beaver Valley Unit 2 3.3.8 - 1 LRM Revision 67

Licensing Requirements Manual Leading Edge Flow Meter 3.3.8 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.8.1 The LEFM shall be demonstrated to be FUNCTIONAL 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by using the self-diagnostic features of the LEFM.

LRS 3.3.8.2 The LEFM shall be demonstrated to be FUNCTIONAL 18 months by performing periodic maintenance and inspections based on the vendors recommendation.

Beaver Valley Unit 2 3.3.8 - 2 LRM Revision 88

Licensing Requirements Manual Turbine Overspeed Protection 3.3.9 3.3 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 other steam flow paths to the turbine are isolated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One throttle valve or one A.1 Restore the Nonfunctional 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months governor valve per high valve(s) to FUNCTIONAL pressure turbine steam line status.

Nonfunctional and/or with one reheat stop valve or one reheat intercept valve per low pressure turbine steam line Nonfunctional.

B. Required Action and B.1 Close at least one valve in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion the affected steam line(s).

Time of Condition A not met. OR B.2 Isolate the turbine from the 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months steam supply.

OR B.3 Apply LR 3.0.3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months C. Turbine Overspeed C.1 Isolate the turbine from the 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Protection System steam supply.

Nonfunctional for reasons other than Condition A. OR C.2 Apply LR 3.0.3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Beaver Valley Unit 2 3.3.9 - 1 LRM Revision 67

Licensing Requirements Manual Turbine Overspeed Protection 3.3.9 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.9.1 --------------------------------------------------------------------------

- NOTE -

Not required to be performed until 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 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 6 months complete cycle from the running position:

a. Four high pressure turbine throttle valves.

b. Four high pressure turbine governor valves.

LRS 3.3.9.2 --------------------------------------------------------------------------

- NOTE -

Not required to be performed until 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 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 6 months valves through one complete cycle from the running position:

a. Four high pressure turbine throttle valves.

b. Four high pressure turbine governor valves.

LRS 3.3.9.3 --------------------------------------------------------------------------

- NOTE -

Not required to be performed until 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 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 18 months complete cycle from the running position:

a. Four low pressure turbine reheat stop valves.

b. Four low pressure turbine reheat intercept valves.

Beaver Valley Unit 2 3.3.9 - 2 LRM Revision 71

Licensing Requirements Manual Turbine Overspeed Protection 3.3.9 LICENSING REQUIREMENT SURVEILLANCES (continued)

SURVEILLANCE FREQUENCY LRS 3.3.9.4 --------------------------------------------------------------------------

- NOTE -

Not required to be performed until 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 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 18 months 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.

LRS 3.3.9.5 Perform a CHANNEL CALIBRATION on the turbine 18 months overspeed protection systems.

LRS 3.3.9.6 Disassemble at least one of each of the above valves 54 months and perform a visual and surface inspection of valve seats, disks, and stems and verify no unacceptable OR flaws or excessive corrosion. If unacceptable flaws or ------------------------

excessive corrosion are found, all other valves of that - NOTE -

type shall be inspected unless the nature of the problem Only applicable to can be directly attributed to a service condition specific reheat stop and to that valve. intercept valves provided there is no indication of operational distress.

60 months Beaver Valley Unit 2 3.3.9 - 3 LRM Revision 95

Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints 3.3.10 3.3 INSTRUMENTATION 3.3.10 RTS, ESFAS, and Loss of Power Trip Setpoints LR 3.3.10.1 Each Reactor Trip System Instrumentation Trip Setpoint listed in Table 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 Instrumentation Trip 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 in Table 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 - 1 LRM 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 FUNCTION NOMINAL TRIP SETPOINT(a)

1. Manual Reactor Trip N.A.

2. Power Range, Neutron Flux

a. High Setpoint 109% of RATED THERMAL POWER

b. Low Setpoint 25% RATED THERMAL POWER

3. Power Range, Neutron Flux High Positive 5% of RATED THERMAL POWER with a Rate time constant 2 seconds

4. Intermediate Range, Neutron Flux 25% RATED THERMAL POWER

5. Source Range, Neutron Flux 105 counts per second

6. Overtemperature T See Technical Specification Table Notation 3 on Table 3.3.1-1

7. Overpower T See Technical Specification Table Notation 4 on Table 3.3.1-1

8. Pressurizer

a. Pressure-Low 1945 psig(b)

b. Pressure-High 2375 psig

9. Pressurizer Water Level-High 92% of instrument span

10. Reactor Coolant Flow-Low 90% of indicated loop flow

11. Reactor Coolant Pump (RCP) Breaker N.A.

Position Trip

12. Undervoltage - RCPs 3120 V

13. Underfrequency - RCPs 57.5 Hz

14. Steam Generator Water Level-Low Low 20.5% of narrow range instrument span(c)

(a) The Unit 2 Setpoint Methodology used to establish the Reactor Trip System Setpoints is defined in WCAP-11366.

(b) Time constants utilized in the lead-lag controller for Pressurizer Pressure-Low are 2 seconds for lead and 1 second for lag. Channel calibration shall ensure that these time constants are adjusted for those values.

(c) The predefined as-found acceptance criteria band, and as-left setpoint tolerance band is

+/- 0.5% span.

Beaver Valley Unit 2 3.3.10 - 2 LRM Revision 52

Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints 3.3.10 TABLE 3.3.10-1 (Page 2 of 2)

REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS FUNCTION NOMINAL(d) TRIP SETPOINT(a)

15. Turbine Trip

a. Emergency Trip Header Low Pressure 1013 psig

b. Turbine Stop Valve Closure 1% open

16. Safety Injection Input from ESFAS N.A.

17. Reactor Trip System Interlocks

a. Intermediate Range Neutron Flux, P-6 1 x 10-10 amps

b. Low Power Reactor Trips Block, P7 N.A.

c. Power Range Neutron Flux, P-8 30% of RATED THERMAL POWER

d. Power Range Neutron Flux, P-9 49% of RATED THERMAL POWER

e. Power Range Neutron Flux, P-10 10% of RATED THERMAL POWER

f. Turbine First Stage Pressure, P-13 10% of RATED THERMAL POWER Turbine First Stage Pressure Equivalent

18. Reactor Trip Breakers (RTBs) N.A.

19. RTB Undervoltage and Shunt Trip N.A.

Mechanisms

20. 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 - 3 LRM 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 INSTRUMENTATION TRIP SETPOINTS FUNCTION NOMINAL TRIP SETPOINT(a)

1. SAFETY INJECTION AND FEEDWATER ISOLATION

a. Manual Initiation N.A.

b. Automatic Actuation Logic and Actuation N.A.

Relays

c. Containment Pressure - High 5.0 psig(b)

d. Pressurizer Pressure - Low 1856 psig

e. Steamline Pressure - Low 500 psig(c)

2. CONTAINMENT SPRAY SYSTEMS

a. Quench Spray

1. Manual Initiation N.A.

2. Automatic Actuation Logic and Actuation N.A.

Relays

3. Containment Pressure-High High 11.1 psig(b)

b. Recirculation Spray

1. Automatic Actuation Logic and Actuation N.A.

Relays

2. Refueling Water Storage Tank (RWST) 32 feet 9 inches(d)

Level Low Coincident with Containment Pressure High-High 11.1 psig(b)

3. CONTAINMENT ISOLATION

a. Phase "A" Isolation

1. Manual Initiation N.A.

2. Automatic Actuation Logic and N.A.

Actuation Relays

3. Safety Injection See Function 1. above for all Safety Injection Trip Setpoints.

(a) The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System Setpoints is defined in WCAP-11366.

(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 1 50 seconds and 2 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-left tolerance 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 SYSTEM INSTRUMENTATION TRIP SETPOINTS FUNCTION NOMINAL TRIP SETPOINT(a)

3. CONTAINMENT ISOLATION (continued)

b. Phase "B" Isolation

1. Manual Initiation N.A.

2. Automatic Actuation Logic and N.A.

Actuation Relays

3. Containment Pressure-High High 11.1 psig(b)

4. STEAM LINE ISOLATION

a. Manual Initiation N.A.

b. Automatic Actuation Logic and Actuation N.A.

Relays

c. Containment Pressure-Intermediate 7.0 psig(b)

High High

d. Steam Line Pressure

1. Low 500 psig(c)

2. Negative Rate - High 100 psi with a time constant 50 seconds

5. TURBINE TRIP & FEEDWATER ISOLATION

a. Automatic Actuation Logic and Actuation N.A.

Relays

b. Steam Generator Water Level-High 92.2% of narrow range instrument span(d)

High, P-14

c. Safety Injection See Function 1. above for all Safety Injection Trip Setpoints.

(a) The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System Setpoints is defined in WCAP-11366.

(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 1 50 seconds and 2 5 seconds. CHANNEL CALIBRATION shall ensure that these time constants are adjusted to these values.

(d) The predefined as-found acceptance criteria band, and as-left setpoint tolerance band is

+/- 0.5% span.

Beaver Valley Unit 2 3.3.10 - 5 LRM Revision 56

Licensing Requirements Manual RTS, ESFAS, and Loss of Power Trip Setpoints 3.3.10 TABLE 3.3.10-2 (Page 3 of 3)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS FUNCTION NOMINAL TRIP SETPOINT(a)

6. AUXILIARY FEEDWATER

a. Automatic Actuation Logic and Actuation N.A.

Relays

b. Steam Generator Water Level-Low Low 20.5% of narrow range instrument span(d)

c. Safety Injection (Start All Auxiliary See Function 1. above for all Safety Feedwater Pumps) Injection Trip Setpoints.

d. Undervoltage - RCP (Start Turbine Driven 3120 V Pump)

e. Trip of Main Feedwater Pumps (Start N.A.

Motor Driven Pumps)

7. AUTOMATIC SWITCHOVER TO CONTAINMENT SUMP

a. Automatic Actuation Logic N.A.

b. Refueling Water Storage Tank Level - 31 feet 9 inches(e)

Extreme Low Coincident with Safety Injection See Function 1. above for all Safety Injection Trip Setpoints.

8. ESFAS INTERLOCKS

a. Reactor Trip, P-4 N.A.

b. Pressurizer Pressure, P-11 2000 psig

c. Tavg - Low-Low, P-12 541°F (a) The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System Setpoints is defined in WCAP-11366.

(d) The predefined as-found acceptance criteria band, and as-left setpoint tolerance band is

+/- 0.5% span.

(e) 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 DIESEL GENERATOR START AND BUS SEPARATION INSTRUMENTATION TRIP SETPOINTS FUNCTION NOMINAL TRIP SETPOINT(a)

LOSS OF VOLTAGE

1. 4160V Emergency Bus DG Start 3120 V with a time delay of 0.33 +/- 0.03 seconds

2. 4160V Emergency Bus Separation 3120 V with a 1 +/- 0.1 second time delay DEGRADED VOLTAGE

3. 4160V Emergency Bus Separation 3885.4 V with a 90 +/- 5 second time delay

4. 480V Emergency Bus Separation 448.3 V with a 90 +/- 5 second time delay (a) The Unit 2 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System Setpoints is defined in WCAP-11366.

Beaver Valley Unit 2 3.3.10 - 7 LRM Revision 52

Licensing Requirements Manual Fuel Storage Pool Area Radiation Monitor 3.3.11 3.3 INSTRUMENTATION 3.3.11 Fuel Storage Pool Area Radiation Monitor LR 3.3.11 The Fuel Storage Pool Area Radiation Monitor (2RMF-RQ202) shall be FUNCTIONAL with:

a. Setpoint of 75.8 mR/hr above background, and

b. Measurement range of 10 104 mR/hr.

APPLICABILITY: With fuel in the storage pool or building.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Setpoint not within limit. A.1 Adjust the setpoint to within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the limit.

OR A.2 Declare the monitor 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Nonfunctional.

B. Required monitor B.1 Perform area surveys of Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Nonfunctional. the monitored area with portable monitoring instrumentation.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.11.1 Perform a CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months LRS 3.3.11.2 Perform a CHANNEL OPERATIONAL TEST. 31 days LRS 3.3.11.3 Perform a CHANNEL CALIBRATION. 18 months Beaver Valley Unit 2 3.3.11 - 1 LRM Revision 67

Licensing Requirements Manual Explosive Gas Monitoring Instrumentation 3.3.12 3.3 INSTRUMENTATION 3.3.12 Explosive Gas Monitoring Instrumentation LR 3.3.12 Two channels of the Gaseous Waste System Surge Tank Discharge Oxygen 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.

APPLICABILITY: During waste gas decay tank filling operation.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare the affected Immediately channels with Alarm/Trip channel(s) inoperable.

setpoint less conservative than required.

B. One required channel B.1 Take and analyze grab Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable. samples.

AND B.2 Restore inoperable 30 days channel to OPERABLE status.

Beaver Valley Unit 2 3.3.12 - 1 LRM Revision 52

Licensing Requirements Manual Explosive Gas Monitoring Instrumentation 3.3.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Two required channels C.1 Take and analyze grab Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable. samples. during degassing operations AND Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months during other operations AND C.2 Restore inoperable 30 days channels to OPERABLE status.

D. Required Action and D.1 Prepare and submit a 30 days associated Completion Special Report in Time not met. accordance with 10 CFR 50.4 to explain why the inoperability was not corrected in a timely manner.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.12.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months LRS 3.3.12.2 Perform CHANNEL OPERATIONAL TEST. 31 days LRS 3.3.12.3 -------------------------------------------------------------------------

- NOTE -

The CHANNEL CALIBRATION shall include the use of standard gas samples containing a nominal:

1. One volume percent oxygen, balance nitrogen, and

2. Four volume percent oxygen, balance nitrogen.

Perform CHANNEL CALIBRATION. 92 days Beaver Valley Unit 2 3.3.12 - 2 LRM Revision 52

Licensing Requirements Manual Containment Hydrogen Analyzers 3.3.13 3.3 INSTRUMENTATION 3.3.13 Containment Hydrogen Analyzers LR 3.3.13 Two separate and independent wide-range containment hydrogen analyzers shall be FUNCTIONAL.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One wide-range hydrogen A.1 Restore the Nonfunctional 30 days analyzer Nonfunctional. analyzer to FUNCTIONAL status.

B. Two wide-range hydrogen B.1 Restore at least one wide- 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months analyzers Nonfunctional. range hydrogen analyzer to FUNCTIONAL status.

C. Required Action and C.1 Apply LR 3.0.3. Immediately associated Completion Time not met.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.13.1 Perform a CHANNEL CALIBRATION using sample 46 days on a gases containing: STAGGERED TEST BASIS

1. One volume percent hydrogen, balance nitrogen, and

2. Four volume percent hydrogen, balance nitrogen.

Beaver Valley Unit 2 3.3.13 - 1 LRM Revision 67

Licensing Requirements Manual Control Room Isolation Radiation Monitors 3.3.14 3.3 INSTRUMENTATION 3.3.14 Control Room Isolation Radiation Monitors LR 3.3.14 Two Control Room Isolation Radiation Monitors (2RMC-RQ201 & 202) shall be FUNCTIONAL with:

a. Setpoint of 0.476 mR/hr above background, and

b. Measurement range of 10 103 mR/hr.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Setpoint not within limit. A.1 Adjust the setpoint to within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the limit.

OR A.2 Declare the monitor 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Nonfunctional.

B. One monitor Nonfunctional. B.1 Restore the Nonfunctional 7 days monitor to FUNCTIONAL status.

OR B.2 Isolate the combined 7 days control room by closing all series normal air intake and exhaust isolation dampers for both Unit 1 and Unit 2.

C. Two monitors C.1 Restore one monitor to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Nonfunctional. FUNCTIONAL status.

OR C.2 Isolate the combined 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months control room by closing all series normal air intake and exhaust isolation dampers for both Unit 1 and Unit 2.

Beaver Valley Unit 2 3.3.14 - 1 LRM Revision 67

Licensing Requirements Manual Control Room Isolation Radiation Monitors 3.3.14 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.14.1 Perform a CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months LRS 3.3.14.2 Perform a CHANNEL OPERATIONAL TEST. 6 months on a STAGGERED TEST BASIS LRS 3.3.14.3 Perform a CHANNEL CALIBRATION. 18 months Beaver Valley Unit 2 3.3.14 - 2 LRM Revision 99

Licensing Requirements Manual Containment Area Radiation Alarm 3.3.15 3.3 INSTRUMENTATION 3.3.15 Containment Area Radiation Alarm LR 3.3.15 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, and

b. Measurement range of 1 to 107 R/hr.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Setpoint(s) not within limit. A.1 Adjust the setpoint(s) to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months within the limit.

OR A.2 Declare the radiation 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months monitor alarm Nonfunctional.

B. One or more alarm B.1 Restore the Nonfunctional 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months channels Nonfunctional. alarm channel(s) to FUNCTIONAL status.

OR B.2.1 Initiate the preplanned 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months alternate method of monitoring the appropriate parameter(s).

AND B.2.2 Restore the alarm 30 days channel(s) to FUNCTIONAL status.

OR B.2.3 Explain why the In the next Annual Nonfunctionality was not Radioactive Effluent corrected in a timely Release Report manner.

Beaver Valley Unit 2 3.3.15 - 1 LRM Revision 67

Licensing Requirements Manual Containment Area Radiation Alarm 3.3.15 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.15.1 Perform a CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months LRS 3.3.15.2 Perform a CHANNEL OPERATIONAL TEST. 31 days LRS 3.3.15.3 Perform a CHANNEL CALIBRATION. 18 months Beaver Valley Unit 2 3.3.15 - 2 LRM Revision 52

Licensing Requirements Manual Accident Monitoring Instrumentation 3.3.16 3.3 INSTRUMENTATION 3.3.16 Accident Monitoring Instrumentation LR 3.3.16 The Accident Monitoring instrumentation for each Function in Table 3.3.16-1 shall be OPERABLE/FUNCTIONAL.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

- NOTES -

1. Separate Condition entry is allowed for each Function.

2. 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 REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Restore the Nonfunctional 7 days with one required channel channel to FUNCTIONAL Nonfunctional. status.

B. Required Action and B.1 Apply LR 3.0.3. Immediately associated Completion Time not met.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.16.1 Perform a CHANNEL CHECK. 31 days LRS 3.3.16.2 --------------------------------------------------------------------------

- NOTE -

Only applicable to the Reactor Coolant System Subcooling Margin Monitor Function.

Perform a CHANNEL CALIBRATION. 18 months Beaver Valley Unit 2 3.3.16 - 1 LRM Revision 81

Licensing Requirements Manual Accident Monitoring Instrumentation 3.3.16 LICENSING REQUIREMENT SURVEILLANCES (continued)

SURVEILLANCE FREQUENCY LRS 3.3.16.3 --------------------------------------------------------------------------

- NOTE -

Only applicable to the following Functions:

a. PORV Limit Switch Position Indicator,

b. PORV Block Valve Limit Switch Position Indicator, and

c. Safety Valve Position Indicator.

Perform a TADOT. 18 months Beaver Valley Unit 2 3.3.16 - 2 LRM Revision 81

Licensing Requirements Manual Accident Monitoring Instrumentation 3.3.16 Table 3.3.16-1 (page 1 of 1)

Accident Monitoring Instrumentation FUNCTION REQUIRED CHANNELS

1. Reactor Coolant System Subcooling Margin Monitor 1

2. PORV Limit Switch Position Indicator 1 per valve

3. PORV Block Valve Limit Switch Position Indicator 1 per valve

4. Safety Valve Position Indicator 1 per valve Beaver Valley Unit 2 3.3.16 - 3 LRM Revision 81

Licensing Requirements Manual Loop Isolation Valves - Shutdown 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Loop Isolation Valves - Shutdown LR 3.4.1 The loop isolation valves in an isolated RCS loop shall have power removed 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 Specification Surveillance 3.4.18.2 have been satisfied.

APPLICABILITY: In MODES 5 and 6 when an RCS loop has been isolated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LR not met. A.1 Remove power from the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months isolated loop isolation valve operators.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.4.1.1 Verify that power is removed from the RCS isolated 7 days loop stop valve operators.

Beaver Valley Unit 2 3.4.1 - 1 LRM Revision 52

Licensing Requirements Manual Chemistry 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Chemistry LR 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. ----------------------------------- A.1 Restore the Parameter to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

- NOTE - within its Steady State Only applicable in Limit.

MODES 1, 2, 3, and 4.

One or more chemistry parameters in excess of its Steady State Limit but within its Transient Limit.

B. Required Action and B.1 Apply LR 3.0.3. Immediately associated Completion Time of Condition A not met.

C. ----------------------------------- C.1 Apply LR 3.0.3. Immediately

- NOTE -

Only applicable in MODES 1, 2, 3, and 4.

One or more chemistry parameters in excess of its Transient Limit.

Beaver Valley Unit 2 3.4.2 - 1 LRM Revision 67

Licensing Requirements Manual Chemistry 3.4.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. ----------------------------------- D.1 Reduce the pressurizer Prior to increasing the

- NOTE - pressure to 500 psig, if pressurizer pressure Not applicable in applicable, and perform an above 500 psig or MODES 1, 2, 3, and 4. analysis to determine the prior to proceeding to

effects of the out-of-limit MODE 4 condition on the structural Concentration of either integrity of the RCS; chloride or fluoride in the determine that the RCS RCS in excess of its remains acceptable for Steady State Limit for more continued operations.

than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or in excess of its Transient Limit.

E. ----------------------------------- E.1 -----------------------------------

- NOTE - - NOTE -

Not applicable in Required Action E.1 is only MODES 1, 2, 3, 4, 5 and 6. applicable when the ability

to sample the RCS is restored.

Unable to determine limits -----------------------------------

of chloride or fluoride in the RCS due to the inability to Initiate action to perform Immediately sample the RCS. LRS 3.4.2.1.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.4.2.1 The RCS chemistry shall be determined to be within the 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months limits specified in Table 3.4.2-1 by analysis.

Beaver Valley Unit 2 3.4.2 - 2 LRM Revision 68

Licensing Requirements Manual Chemistry 3.4.2 TABLE 3.4.2-1 (Page 1 of 1)

REACTOR COOLANT SYSTEM CHEMISTRY LIMITS STEADY-STATE TRANSIENT PARAMETER LIMIT LIMIT DISSOLVED OXYGEN* < 0.10 ppm* 1.00 ppm*

CHLORIDE < 0.15 ppm 1.50 ppm FLUORIDE 0.15 ppm 1.50 ppm

Limit not applicable with Tavg 250°F.

Beaver Valley Unit 2 3.4.2 - 3 LRM Revision 52

Licensing Requirements Manual Pressurizer 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Pressurizer LR 3.4.3 The pressurizer temperature shall be limited to:

a. A maximum heatup of 100°F in any one hour period,

b. A maximum cooldown of 200°F in any one hour period,

c. A maximum normal spray water temperature differential of 320°F, and

d. A maximum auxiliary spray water temperature differential of 380°F.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer temperature A.1 Restore temperature to 30 minutes limit(s) exceeded. within the limit(s).

AND A.2 Perform an engineering 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months evaluation to determine the effects of the out-of-limit condition on the structural integrity of the pressurizer.

AND A.3 Determine that the 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pressurizer remains acceptable for continued operation.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Reduce the pressurizer 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months pressure to less than 500 psig.

Beaver Valley Unit 2 3.4.3 - 1 LRM Revision 52

Licensing Requirements Manual Pressurizer 3.4.3 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.4.3.1 The pressurizer temperatures shall be determined to be Once per within the limits. 30 minutes during system heatup or cooldown LRS 3.4.3.2 The normal spray water temperature differential shall be Once per determined to be within the limit. 30 minutes during system heatup or cooldown LRS 3.4.3.3 The auxiliary spray water temperature differential shall Once per be determined to be within the limit. 30 minutes during auxiliary spray operation Beaver Valley Unit 2 3.4.3 - 2 LRM Revision 52

Licensing Requirements Manual 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 DELETED Beaver Valley Unit 2 3.4.4 - 1 LRM Revision 67

Licensing Requirements Manual RCS Head Vents 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Head Vents LR 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 -

1. 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 closed on demand.

2. The vent valves may be operated for required venting operations and leak testing in MODES 3 and 4.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One vent path from the A.1 ----------------------------------

above location - NOTE -

FUNCTIONAL and one or Power operation may more power operated vent continue and entry into valves Nonfunctional. MODES 1-4 is not restricted until the next scheduled outage, at which time all RCS head vent valves shall be FUNCTIONAL prior to entry into MODE 1.

Maintain the Nonfunctional Immediately valve(s) closed with power removed.

Beaver Valley Unit 2 3.4.5 - 1 LRM Revision 67

Licensing Requirements Manual RCS Head Vents 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. All vent paths from the B.1 Maintain the Nonfunctional Immediately above location valves closed with power Nonfunctional. removed.

OR B.2.1 Close the manual isolation Immediately valves.

AND B.2.2 Restore one vent path from 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months the above locations to FUNCTIONAL status.

OR B.3 Apply LR 3.0.3. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.4.5.1 Each RCS head vent path shall be demonstrated 18 months FUNCTIONAL by:

a. Verifying the manual isolation valve in the vent path is locked or sealed in the open position.

b. Cycling each valve in the vent path through at least one complete cycle of full travel from the control room.

c. Verifying flow through the RCS Head vent path to the Pressurizer Relief Tank.

Beaver Valley Unit 2 3.4.5 - 2 LRM Revision 67

Licensing Requirements Manual Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge LR 3.4.6 The OPERABILITY of pressurizer safety valve(s) shall be evaluated after a lift involving loop seal or water discharge.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures > the enable temperature specified in the PTLR.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

- NOTE -

Required Action A.3 shall be completed whenever this Condition is entered.

A. One or more pressurizer A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months safety valve(s) lift as indicated by the safety AND valve position indicator with loop seal or water A.2 Be in MODE 4 with any 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months discharge. RCS cold leg temperature the enable temperature specified in the PTLR with RCS overpressure protection provided in accordance with the requirements of Technical Specification 3.4.12.

AND A.3 Initiate action to evaluate 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months the OPERABILITY of the affected valve(s).

Beaver Valley Unit 2 3.4.6 - 1 LRM Revision 67

Licensing Requirements Manual Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge 3.4.6 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.4.6.1 No additional requirements other than the applicable In accordance requirements of the Inservice Testing Program. with the Inservice Testing Program.

Beaver Valley Unit 2 3.4.6 - 2 LRM Revision 52

Licensing Requirements Manual RCS Pressure Isolation Valves 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Pressure Isolation Valves LR 3.4.7 Each Pressure Isolation 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 Isolation Valves (PIV) Leakage."

APPLICABILITY: As specified in TS 3.4.14.

Beaver Valley Unit 2 3.4.7 - 1 LRM Revision 52

Licensing Requirements Manual RCS Pressure Isolation Valves 3.4.7 TABLE 3.4.7-1 (Page 1 of 1)

RCS PRESSURE ISOLATION VALVES SYSTEM VALVE NO. NOTES Loop 21, Cold leg, LHSI 2SIS-107 (1)(2)

Loop 22, Cold leg, LHSI 2SIS-108 (1)(2)

Loop 23, Cold leg, LHSI 2SIS-109 (1)(2)

Common, Cold leg, LHSI 2SIS-132 (2) 2SIS-133 (2)

Loop 22, Hot leg, LHSI 2SIS-128 (1)

Loop 23, Hot leg, LHSI 2SIS-129 (1)

Common, Hot leg, LHSI 2SIS-130 Loop 21, Cold leg, SIACC 2SIS-151 (1) 2SIS-148 Loop 22, Cold leg, SIACC 2SIS-145 (1)(2) 2SIS-147 Loop 23, Cold leg, SIACC 2SIS-141 (1)(2) 2SIS-142 Loop 21, Hot leg, RHS-A 2RHS-MOV702A (1) 2RHS-MOV701A (1)

Loop 22, Cold leg 2RHS-MOV720A (1)

Loop 21, Hot leg, RHS-B 2RHS-MOV702B (1) 2RHS-MOV701B (1)

Loop 23, Cold leg 2RHS-MOV720B (1)

NOTES:

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 Containment Isolation Valves 3.6.1 3.6 CONTAINMENT 3.6.1 Containment Isolation Valves LR 3.6.1 Each containment isolation valve listed in Table 3.6.1-1 shall be maintained in the manner specified in Technical Specification (TS)

3.6.3. APPLICABILITY

As specified in TS 3.6.3.

Beaver Valley Unit 2 3.6.1 - 1 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 1 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-1 Comp Cool from Res Heat Exch (B)2CCP-MOV157-2 < 60 (B)2CCP-MOV157-1 < 60 2CCP-RV105 N/A X-2 Comp Cool to Res Heat Exch (B)2CCP-MOV150-2 < 60 (B)2CCP-MOV150-1 < 60 2CCP-RV102 N/A X-4 Comp Cool to Res Heat Exch (B)2CCP-MOV151-2 < 60 (B)2CCP-MOV151-1 < 60 2CCP-RV103 N/A X-5 Comp Cool from Res (B)2CCP-MOV156-2 < 60 (B)2CCP-MOV156-1 < 60 Heat Exch 2CCP-RV104 N/A X-6 SPARE X-7 High Head Safety Injection (2) 2SIS-83 N/A (2)2SIS-MOV869A N/A X-9 SPARE X-11 Instrument Air (14)2IAC-MOV133 N/A (14)2IAC-MOV134 N/A X-13 SPARE X-14 Chill & Service Wtr to Cont. Air Recirc (3)(14)2SWS-MOV153-2 N/A (3)(14)2SWS-MOV153-1 N/A Cooling Coils 2SWS-RV153 N/A X-15 CHARGING (2)2CHS-31 N/A (2)2CHS-MOV289 < 10 X-16 SPARE Beaver Valley Unit 2 3.6.1 - 2 LRM Revision 97

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 2 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-17 High Head Safety Injection (2)2SIS-84 N/A (2)2SIS-MOV869B N/A X-19 Seal Water from Reactor Coolant (A)2CHS-MOV378 < 60 (A)2CHS-MOV381 < 60 Pump 2CHS-473 N/A X-20 Safety Injection Accumulator Makeup 2SIS-42 N/A 2SIS-41 N/A 2SIS-RV130 N/A X-21 Chill & Service Wtr from (B)2SWS-MOV155-2 < 60 (B)2SWS-MOV155-1 < 60 Cont. Air Recirc Cooling Coils 2SWS-RV155 N/A X-22 SPARE X-23 SPARE X-24 Residual Heat Removal to Refueling 2RHS-107 N/A 2RHS-15 N/A Water Tank 2RHS-RV100 N/A X-25 Chill & Service Wtr from Cont. Air (3)(14)2SWS-MOV154-2 N/A (3)(14)2SWS-MOV154-1 N/A Recirc Cooling Coils 2SWS-RV154 N/A X-27 Chill & Service Wtr to Cont. Air Recirc (B)2SWS-MOV152-2 < 60 (B)2SWS-MOV152-1 < 60 Cooling Coils 2SWS-RV152 N/A Beaver Valley Unit 2 3.6.1 - 3 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 3 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-28 Reactor Coolant Letdown (A)2CHS-AOV200A < 60 (A)2CHS-AOV204 < 60 (A)2CHS-AOV200B < 60 (A)2CHS-AOV200C < 60 (1)2CHS-HCV142 N/A 2CHS-RV203 N/A X-29 Pri Dr. Trans Pump Disch (A)2DGS-AOV108A < 60 (A)2DGS-AOV108B < 60 2DGS-RV115 N/A X-30 SPARE X-31 SPARE X-32 SPARE X-33 SPARE X-34 High Head Injection Line (2)2SIS-94 N/A (2)2SIS-MOV836 N/A (2)2SIS-MOV840 N/A X-35 Inj Seal Wtr to Reactor Coolant Pump (2)2CHS-474 N/A (2)2CHS-MOV308A N/A X-36 Inj Seal Wtr to Reactor Coolant Pump (2)2CHS-476 N/A (2)2CHS-MOV308B N/A X-37 Inj Seal Wtr to Reactor Coolant Pump (2)2CHS-475 N/A (2)2CHS-MOV308C N/A X-38 Sump Pump Discharge (A)2DAS-AOV100A < 60 (A)2DAS-AOV100B < 60 2DAS-RV110 N/A Beaver Valley Unit 2 3.6.1 - 4 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 4 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-39 St Gen Blowdown Closed System N/A (2)2BDG-AOV100A-1 < 60 X-40 St Gen Blowdown Closed System N/A (2)2BDG-AOV100B-1 < 60 X-41 St Gen Blowdown Closed System N/A (2)2BDG-AOV100C-1 < 60 X-42 Service Air 2SAS-15 N/A 2SAS-14 N/A X-43 Air Monitor Sample 2CVS-93 N/A (A)2CVS-SOV102 < 60 X-44 Air Monitor Sample (A)2CVS-SOV153B < 60 (A)2CVS-SOV153A < 60 X-45 Primary Grade Water 2RCS-72 N/A (A)2RCS-AOV519 < 60 2RCS-RV100 N/A X-46 Loop Fill (2)2CHS-472 N/A (1)(2)2CHS-FCV160 N/A X-47 SPARE X-48 Primary Vent Header (A)2VRS-AOV109A-2 < 60 (A)2VRS-AOV109A-1 < 60 X-49 Nitrogen Supply Manifold 2RCS-68 N/A (A)2RCS-AOV101 < 60 X-50 SPARE X-51 SPARE X-52 SPARE X-53 Nitrogen Manifold (A)2GNS-AOV101-2 < 10 (A)2GNS-AOV101-1 < 60 Beaver Valley Unit 2 3.6.1 - 5 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 5 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-55A Press Relief Tank (A)2SSR-SOV130A-1 < 60 (A)2SSR-SOV130A-2 < 60 X-55B Leakage Detection Open to Containment N/A (2)(16)(19)2LMS-SOV953 < 60(4)

X-55C Hydrogen Analyzer (1)2HCS-SOV136A N/A (1)2HCS-SOV136B N/A X-55D Accumulator Water Sample (A)2SSR-AOV109A-1 < 60 (A)2SSR-AOV109A-2 < 60 2SSR-RV117 N/A X-56A Blowdown Sample Closed System N/A (2)2SSR-AOV117A < 60 X-56B Hot Leg Sample (A)2SSR-SOV128A-1 < 60 (A)2SSR-SOV128A-2 < 60 2SSR-RV120 N/A X-56C Cold Leg Sample (A)2SSR-AOV102A-1 < 60 (A)2SSR-AOV102A-2 < 60 2SSR-RV118 N/A X-56D Pressurizer Liquid Space Sample (A)2SSR-AOV100A-1 < 60 (A)2SSR-AOV100A-2 < 60 2SSR-RV119 N/A X-57A Pressurizer Vapor Space Sample (A)2SSR-AOV112A-1 < 60 (A)2SSR-AOV112A-2 < 60 2SSR-RV121 N/A X-57B Leak Detection Open to Containment N/A (2)(16)(19)2LMS-SOV950 < 60(4)

X-57C Hydrogen Analyzer (1)2HCS-SOV135A N/A (1)2HCS-SOV135B N/A X-57D Blowdown Sample Closed System N/A (2)2SSR-AOV117B < 60 X-59 Instrument Air Containment 2IAC-22 N/A (A)2IAC-MOV130 < 60 Beaver Valley Unit 2 3.6.1 - 6 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 6 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-60 Low Head Safety Injection Discharge (2)2SIS-132 N/A (2)2SIS-MOV8888B N/A X-61 Low Head Safety Injection Discharge (2)2SIS-130 N/A (2)2SIS-MOV8889 N/A X-62 Low Head Safety Injection Discharge (2)2SIS-133 N/A (2)2SIS-MOV8888A N/A X-63 Quench Pump Discharge 2QSS-4 N/A (B)2QSS-MOV101A < 60(4) 2QSS-RV101A N/A X-64 Quench Pump Discharge 2QSS-3 N/A (B)2QSS-MOV101B < 60(4) 2QSS-RV101B N/A X-65 Fuel Transfer Tube (7)Flange N/A (6)2ISC-102 N/A X-66 Recirc Spray Pump Suction Open to Containment N/A (B)(2)2RSS-MOV155A < 60(4)

X-67 Recirc Spray Pump Suction Open to Containment N/A (B)(2)2RSS-MOV155C < 60(4)

X-68 Recirc Spray Pump Suction Open to Containment N/A (B)(2)2RSS-MOV155D < 60(4)

X-69 Recirc Spray Pump Suction Open to Containment N/A (B)(2)2RSS-MOV155B < 60(4)

X-70 Recirculation Pump Discharge (2)2RSS-29 N/A (B)(2)2RSS-MOV156A < 60(4)

(6) 2RSS-RV156A N/A Beaver Valley Unit 2 3.6.1 - 7 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 7 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-71 Recirculation Pump Discharge (2)2RSS-31 N/A (10)(B)(2)2RSS-MOV156C < 60(4)

(6)2RSS-RV156C N/A X-73 Main Steam System A Closed System N/A (2)2MSS-AOV101A 6(21)

Closed System N/A (2)2MSS-AOV102A N/A Closed System N/A (2)(17)2MSS-SOV105A N/A Closed System N/A (2)(15)2MSS-SOV120 N/A Closed System N/A (6)2MSS-SV101A N/A Closed System N/A (6)2MSS-SV102A N/A Closed System N/A (6)2MSS-SV103A N/A Closed System N/A (6)2MSS-SV104A N/A Closed System N/A (6)2MSS-SV105A N/A Steam Drains System Closed System N/A (2)2SDS-AOV111A-1 < 60 Closed System N/A (2)2SDS-AOV129B < 60 Steam Vent System Closed System N/A (6)2SVS-PCV101A N/A Closed System N/A (6)2SVS-HCV104 N/A Beaver Valley Unit 2 3.6.1 - 8 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 8 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-74 Main Steam System B Closed System N/A (2)2MSS-AOV101B 6(21)

Closed System N/A (2)2MSS-AOV102B N/A Closed System N/A (2)(17)2MSS-SOV105B N/A Closed System N/A (2)(15)2MSS-SOV120 N/A Closed System N/A (6)2MSS-SV101B N/A Closed System N/A (6)2MSS-SV102B N/A Closed System N/A (6)2MSS-SV103B N/A Closed System N/A (6)2MSS-SV104B N/A Closed System N/A (6)2MSS-SV105B N/A Steam Drains System Closed System N/A (2)2SDS-AOV111B-1 < 60 Closed System N/A (2)2SDS-AOV129B < 60 Steam Vent System Closed System N/A (6)2SVS-PCV101B N/A Closed System N/A (6)2SVS-HCV104 N/A Beaver Valley Unit 2 3.6.1 - 9 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 9 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-75 Main Steam System C Closed System N/A (2)2MSS-AOV101C 6(21)

Closed System N/A (2)2MSS-AOV102C N/A Closed System N/A (2)(17)2MSS-SOV105C N/A Closed System N/A (2)(15)2MSS-SOV120 N/A Closed System N/A (6)2MSS-SV101C N/A Closed System N/A (6)2MSS-SV102C N/A Closed System N/A (6)2MSS-SV103C N/A Closed System N/A (6)2MSS-SV104C N/A Closed System N/A (6)2MSS-SV105C N/A Steam Drains System Closed System N/A (2)2SDS-AOV111C-1 < 60 Closed System N/A (2)2SDS-AOV129B < 60 Steam Vent System Closed System N/A (6)2SVS-PCV101C N/A Closed System N/A (6)2SVS-HCV104 N/A X-76 Feedwater A Closed System N/A (2)2FWS-HYV157A 7(18)

(20)(6)2FWS-28 N/A Beaver Valley Unit 2 3.6.1 - 10 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 10 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-77 Feedwater B Closed System N/A (2)2FWS-HYV157B 7(18)

(20)(6)2FWS-29 N/A X-78 Feedwater C Closed System N/A (2)2FWS-HYV157C 7(18)

(20)(6)2FWS-30 N/A X-79 Aux Feed A Closed System N/A (2)2FWE-HCV100E N/A (20)(6)2FWE-99 (2)2FWE-HCV100F N/A (20)(6)2FWE-42A N/A (20)(6)2FWE-42B N/A X-80 Aux Feed B Closed System N/A (2)2FWE-HCV100C N/A (20)(6)2FWE-100 (2)2FWE-HCV100D N/A (20)(6)2FWE-43A N/A (20)(6)2FWE-43B N/A X-83 Aux Feed C Closed System N/A (2)2FWE-HCV100A N/A (20)(6)2FWE-101 (2)2FWE-HCV100B N/A (20)(6)2FWE-44A N/A (20)(6)2FWE-44B N/A X-87 Hydrogen Recombiner Open to Containment N/A (1)2HCS-MOV117 N/A Discharge 2HCS-111 N/A X-88 Hydrogen Recombiner Open to Containment N/A (1)2HCS-MOV116 N/A Discharge 2HCS-110 N/A X-89 SPARE X-90 Purge Duct Exhaust (5)(14)2HVR-MOD23B 10 (5)(14)2HVR-MOD23A 10 Beaver Valley Unit 2 3.6.1 - 11 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 11 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-91 Purge Duct Supply (5)(14)2HVR-MOD25B 10 (5)(14)2HVR-MOD25A 10 (5)(14)2HVR-DMP206 N/A X-92 Hydrogen Recombiner Open to Containment N/A (1)2HCS-SOV114B N/A Isolation (1)2HCS-SOV115B N/A Reactor Cont. Vacuum (A)2CVS-SOV151B <5 Pump Suction (A)2CVS-SOV152B <5 X-93 Hydrogen Recombiner Open to Containment N/A (1)2HCS-SOV114A N/A Isolation (1)2HCS-SOV115A N/A Reactor Cont. Vacuum (A)2CVS-SOV151A <5 Isolation (A)2CVS-SOV152A <5 X-94 Ejector Suction (14)2CVS-151 N/A (14)2CVS-151-1 N/A X-96 SPARE X-97A Leakage Detection Open to Containment N/A (2)(16)(19)2LMS-SOV952 < 60(4)

X-97B Hydrogen Analyzer (1)2HCS-SOV133B N/A (1)2HCS-SOV134B N/A X-97C Liquid Sample - Cont. (A)2SSR-SOV129A-1 < 60 (A)2SSR-SOV129A-2 < 60 Sump & RHS 2SSR-RV122 N/A X-97D Blowdown Sample Closed System N/A (2)2SSR-AOV117C < 60 Beaver Valley Unit 2 3.6.1 - 12 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 12 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-98 SPARE X-99 Hose Rack Supply 2FPW-761 N/A (A)2FPW-AOV206 < 60 X-100 SPARE X-101 Reactor Cont. Deluge - 2FPW-753 N/A (A)2FPW-AOV205 < 60 Cable Pent. Area & RHS Pump X-103 Reactor Cavity Purif Inlet 2FNC-121 N/A 2FNC-38 N/A X-104 Reactor Cavity Purif Outlet 2FNC-122 N/A 2FNC-9 N/A X-105A Post Accident Sampling (A)2PAS-SOV105A-1 < 60 (A)2PAS-SOV105A-2 < 60 X-105B Hydrogen Analyzer (1)2HCS-SOV133A N/A (1)2HCS-SOV134A N/A X-105C Leak Detection Open to Containment N/A (2)(16)(19)2LMS-SOV951 < 60(4)

X-105D Leak Detection Open to Containment N/A 2LMS-51 N/A 2LMS-52 N/A X-106 Safety Inj. Test Line (A)2SIS-MOV842 < 60 (A)2SIS-AOV889 < 60 2SIS-RV175 N/A X-108 SPARE Beaver Valley Unit 2 3.6.1 - 13 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 13 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-110A SPARE X-110B SPARE X-110C SPARE X-110D SPARE X-113 Safety Injection (2)2SIS-95 N/A (2)2SIS-MOV867C < 10(4)

(2)2SIS-MOV867D < 10(4)

X-114 Recirculation Pump (2)2RSS-32 N/A (10)(B)(2)2RSS-MOV156D < 60(4)

Discharge (6)2RSS-RV156D N/A X-115 Recirculation Pump (2)2RSS-30 N/A (B)(2)2RSS-MOV156B < 60(4)

Discharge (6)2RSS-RV156B N/A X-116 SPARE X-117 SPARE X-118A SPARE X-118B SPARE X-118C SPARE Beaver Valley Unit 2 3.6.1 - 14 LRM Revision 66

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 14 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

X-118D SPARE X-118E SPARE X-119A RVLIS (2)(12) N/A X-119B RVLIS (2)(12) N/A X-119C RVLIS (2)(12) N/A X-119D RVLIS (2)(12) N/A X-119E RVLIS (2)(12) N/A X-119F RVLIS (2)(12) N/A Beaver Valley Unit 2 3.6.1 - 15 LRM Revision 65

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 15 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

Primary Containment Personnel Air Lock 2PHS-PAL 1 Equalizing Valve (1)(7)2PHS-112 N/A Equalizing Valve (1)(7)2PHS-113 N/A Equalizing Valve (1)(7)2PHS-101 N/A Equalizing Valve (1)(7)2PHS-110 N/A Equalizing Valve (1)(7)2PHS-111 N/A Equalizing Valve (1)(7)2PHS-100 N/A Emergency Containment Air Lock 2PHS-EAL 1 Equalizing Valve (1)(7)2PHS-202 N/A Equalizing Valve (1)(7)2PHS-201 N/A NOTES:

(A) Containment Isolation Phase A.

(B) Containment Isolation Phase B.

(1) May be opened on an intermittent basis under administrative control.

(2) Not subject to Type C leakage tests.

(3) No credit is taken for the CIB actuation.

(4) Maximum opening time.

(5) When required by Technical Specification 3.9.3.

Beaver Valley Unit 2 3.6.1 - 16 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 16 of 17)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC)

NOTES (Continued):

(6) Not subject to the requirements of Specifications 3.6.1 and 3.6.3. Listed for information only.

(7) Tested under Type B testing.

(8) Not used.

(9) Not used.

(10) Auto close on Safety Injection recirculation signal.

(11) Not used.

(12) Isolation is provided by bellows operated hydraulic isolators.

(13) Not used.

(14) Valve will be locked shut in Modes 1, 2, 3 and 4.

(15) Auto open on Safety Injection Signal.

(16) Valve operability includes remote closure capability.

Beaver Valley Unit 2 3.6.1 - 17 LRM Revision 65

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 17 of 17)

CONTAINMENT PENETRATIONS NOTES (Continued):

(17) The downstream SOV in the steam supply line to the turbine driven AFW pump may be used as the containment isolation valve. The valves may be substituted as follows:

2MSS-SOV105D for 2MSS-SOV105A 2MSS-SOV105E for 2MSS-SOV105B 2MSS-SOV105F for 2MSS-SOV105C It is noted for reference that rendering one of the subject valves inoperable may also invoke additional restrictions per Technical Specification 3.7.5 for the steam driven AFW pump. The following criteria provides an acceptable interim arrangement to meet both Technical Specifications 3.6.3 and 3.7.5:

VALVE CLOSED INOPERABLE STEAM SUPPLY VALVE REQUIRED AND ISOLATED REQUIRED TO REMAIN TO REMAIN ADMIN.

INOPERABLE STEAM SUPPLY OPERABLE, 3.7.5 CONTROLLED OPEN 2MSS-SOV105A A B,C 2MSS-SOV105F 2MSS-SOV105D A B,C 2MSS-SOV105F 2MSS-SOV105B B A,C 2MSS-SOV105C 2MSS-SOV105E B A,C 2MSS-SOV105C 2MSS-SOV105C C A,B None 2MSS-SOV105F C A,B None (18) Feedwater isolation time specified includes signal processing time and valve closure time. Valve closure times shall be limited such that when added to the signal processing time the total isolation time specified on Table 3.6.1-1 is not exceeded. Valve closure time required within limit by Technical Specification SR 3.7.3.1.

(19) May be open as described in UFSAR.

(20) This valve is not a containment isolation valve as described in UFSAR Section 6.2.4.

(21) Valve isolation time required by Technical Specification SR 3.7.2.1.

Beaver Valley Unit 2 3.6.1 - 18 LRM Revision 52

Licensing Requirements Manual Containment Sump 3.6.2 3.6 CONTAINMENT 3.6.2 Containment Sump LR 3.6.2 The containment does not have loose debris present that could be transported to the containment sump and cause restriction of the Emergency Core Cooling System pump suctions during LOCA conditions.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LR not met. A.1 Apply the provisions of Immediately LR 3.0.3.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.6.2.1 -------------------------------------------------------------------------

- 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 the Prior to containment that no loose debris (rags, trash, clothing, establishing etc.) is present in the containment which could be containment transported to the containment sump and cause OPERABILITY restriction of the Emergency Core Cooling System per Technical pump suctions during LOCA conditions. Specification 3.6.1 LRS 3.6.2.2 Verify by visual inspection of the areas affected within At the completion containment that no loose debris (rags, trash, clothing, of each etc.) is present in the containment which could be containment entry transported to the containment sump and cause restriction of the Emergency Core Cooling System pump suctions during LOCA conditions.

Beaver Valley Unit 2 3.6.2 - 1 LRM Revision 52

Licensing Requirements Manual Steam Generator Pressure/Temperature Limitation 3.7.1 3.7 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 the associated steam generator is 70°F and the primary or secondary systems of the associated steam generator are capable of being pressurized.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LR not met. A.1 Reduce the steam 30 minutes generator pressure of the applicable side to 200 psig.

AND A.2 Perform an analysis to Prior to increasing its determine the effect of the temperatures above overpressurization on the 200°F structural integrity of the steam generator.

Determine that the steam generator remains acceptable for continued operation.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.7.1.1 Verify the pressure in each side of the steam generator Once per hour is 200 psig.

Beaver Valley Unit 2 3.7.1 - 1 LRM Revision 52

Licensing Requirements Manual Flood Protection 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Flood Protection LR 3.7.2 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.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Water level at the intake A.1 Install and seal the flood 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months structure above elevation doors in the intake 695 Mean Sea Level. structure.

B. ----------------------------------- B.1 Confirm the actual Ohio Immediately

- NOTE - River level is 700 Mean Only applicable in Sea Level.

MODES 1, 2, 3, and 4.

AND Water level at the intake B.2 Verify the forecasted peak 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months structure above elevation Ohio River level is 700 695 Mean Sea Level. Mean Sea Level.

C. Required Action and C.1 Apply LR 3.0.3. Immediately associated Completion Time of Condition A or B not met in MODES 1, 2, 3, and 4.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.7.2.1 When the water level is < elevation 690 Mean Sea 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Level, verify water level at the intake structure.

LRS 3.7.2.2 When the water level is elevation 690 Mean Sea 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Level, verify water level at the intake structure.

Beaver Valley Unit 2 3.7.2 - 1 LRM Revision 67

Licensing Requirements Manual Sealed Source Contamination 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Sealed Source Contamination LR 3.7.3 Each sealed source containing radioactive material either in excess of 100 microcuries of beta and/or gamma-emitting material or 5 microcuries of alpha-emitting material shall be free of 0.005 microcuries of removable contamination.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Sealed source removable A.1 Withdraw the sealed Immediately contamination in excess of source from use.

the limit.

AND A.2.1 Initiate action to Immediately decontaminate and repair the sealed source.

OR A.2.2 Initiate action to dispose of Immediately the sealed source in accordance with Commission Regulations.

B. Sealed source or fission B.1 Prepare and submit a On an annual basis detector leakage tests Special Report in reveal the presence of accordance with 10 CFR 0.005 microcuries of 50.4.

removable contamination.

Beaver Valley Unit 2 3.7.3 - 1 LRM Revision 52

Licensing Requirements Manual Sealed Source Contamination 3.7.3 LICENSING REQUIREMENT SURVEILLANCES

- NOTES -

1. 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.

2. The test method shall have a detection sensitivity of at least 0.005 microcuries per test sample.

3. Startup sources and fission detectors previously subjected to core flux are excluded from the following test requirements.

SURVEILLANCE FREQUENCY LRS 3.7.3.1 For sealed sources in use containing radioactive 6 months materials with a half-life > 30 days (excluding Hydrogen 3) and in any form other than gas, verify removable contamination within the limit.

LRS 3.7.3.2 For stored sealed sources and fission detectors not in Prior to use or use, verify removable contamination within the limit. transfer to another licensee unless tested within the previous 6 months LRS 3.7.3.3 For sealed sources and fission detectors transferred Prior to use without a certificate indicating the last test date, verify removable contamination within the limit.

LRS 3.7.3.4 For sealed startup sources and fission detectors, verify 31 days prior to removable contamination within the limit. being installed in the core or exposed to core flux AND Following repair or maintenance to the source Beaver Valley Unit 2 3.7.3 - 2 LRM Revision 52

Licensing Requirements Manual Snubbers 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Snubbers LR 3.7.4 All snubbers shall be FUNCTIONAL.

- 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.

APPLICABILITY: 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 portions or subsystems required to prevent releases in excess of 10 CFR 50.67 limits.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Replace or restore the In accordance with snubbers Nonfunctional. Nonfunctional snubber(s) Table 3.7.4-1 to FUNCTIONAL status.

AND A.2.1 Perform an engineering In accordance with evaluation per Paragraph Table 3.7.4-1 ISTD-1800 of the ASME OM Code on the supported component.

OR Beaver Valley Unit 2 3.7.4 - 1 LRM Revision 67

Licensing Requirements Manual Snubbers 3.7.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2.2 Declare the supported In accordance with system inoperable/ Table 3.7.4-1 Nonfunctional (as applicable) and follow the appropriate ACTIONS for that system.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.7.4.1 Each snubber shall be demonstrated FUNCTIONAL in In accordance accordance with Subsection ISTD, Preservice and with Subsection Inservice Examination and Testing of Dynamic ISTD of the Restraints (Snubbers) in Light-Water Reactor Power ASME OM Code Plants, ASME OM Code 2004 Edition up to and 2004 Edition up to including the 2006 Addenda. Preservice and inservice and including the examinations of snubbers shall be performed in 2006 Addenda.

accordance with ASME OM Code Subsection Inservice ISTD-4000. (

Reference:

Paragraph (b)(3)(v)(B) of examination 10 CFR 50.55a, Codes and Standards.) frequency may be extended in accordance with Code Case OMN-13, Rev. 0 (2004 Edition).

Beaver Valley Unit 2 3.7.4 - 2 LRM Revision 93

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 1 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2BDG-PSSP868 2" Steam Sample line from S/G 21A Between 2RCS*SG21A &2BDG*457 Yes 72 2BDG-PSSP876 2" Steam Sample line from S/G 21A Between 2BDG*457 & 2BDG*AOV102A1 Yes 72 Between 2BDG*AOV101B1 &

2BDG-PSSP927 3" line from S/G 21B to Tk21 2BDG*AOV101B2 Yes 72 2BDG-PSSP945 2" Steam Sample line from S/G 21C Between 2RCS*SG21C &2BDG*459 Yes 72 Between 2BDG*AOV102A1 &

2BDG-PSSP947 2" Steam sample line from S/G 21A 2SSR*AOV117A Yes 72 2" supply line to Degas Steam Heater, Between 2BRS*AOV106A/2BRS*1 &

2BRS-PSSP091Y E21A 2BRS*E21A Yes 72 Between 20 " CCP Hdr &

2CCP-PSSP301 20" CCP supply line to CCP Hx 21A 2CCP*DCV101A Yes 12 2CCP-PSSP317A 20" CCP supply header to CCP Hx's Between 2CCP*7, *27A & *DCV101A Yes 12 2CCP-PSSP317B 20" CCP supply header to CCP Hx's Between 2CCP*7, *27A & *DCV101A Yes 12 2CHS-PSSP006 3" Charging line from Regen Hx to Loop B Between 2CHS*871 & 2CHS*870 Yes 12 2CHS-PSSP015X 3" Charging line from Regen Hx to Loop B Between 2CHS*871 & 2CHS*870 Yes 12 2CHS-PSSP016X Loop C CHS Fill line Between 2CHS*170 & 2RCS*MOV556C Yes 72 2CHS-PSSP017X Loop A CHS Fill line Between 2CHS*170 & 2RCS*MOV556A Yes 72 2CHS-PSSP024 CHS Seal Water Injection to 2RCS*P21A Between 2CHS*181 & 2CHS*184 Yes 12 2CHS-PSSP025 CHS Seal Water Injection to 2RCS*P21A Between 2CHS*181 & 2CHS*184 Yes 12 2CHS-PSSP025X CHS Seal Water Injection to 2RCS*P21B Between 2CHS*182 & 2CHS*185 No Beaver Valley Unit 2 3.7.4 - 3 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 2 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time Between 2CHS*25/*MOV8132A &

2CHS-PSSP252Y 4" HHSI line to RCS loops MOV867B/869A&B Yes 12 2CHS-PSSP308A 3" CHS line to Seal Water Hx Between 2CHS*MOV381 & 2CHS*214 Yes 12 2CHS-PSSP308B 3" CHS line to Seal Water Hx Between 2CHS*MOV381 & 2CHS*214 Yes 12 2CHS-PSSP660X Loop B CHS Fill line Between 2CHS*170 & 2RCS*MOV556B Yes 72 2" Letdown line from Loop A to Regen 2CHS-PSSP673X Hx Between Loop A & 2CHS*1 Yes 12 2CHS-PSSP685C 2" Letdown line to Non-regen Hx Between 2CHS*AOV204 & Non-regen Hx No 2DGS-PSSP879 Loop C 2" drain line Between 2RCS*9 & 2DGS*300 Yes 72 2EDG-PSSP029A Diesel Gen 2EGS*EG2-1 exhaust hdr Exhaust Silencer 3A discharge to atmosphere Yes 12 2EDG-PSSP029B Diesel Gen 2EGS*EG2-1 exhaust hdr Exhaust Silencer 3A discharge to atmosphere Yes 12 2EDG-PSSP030Y Diesel Gen 2EGS*EG2-1 exhaust hdr Exhaust Silencer 3A discharge to atmosphere Yes 12 2EDG-PSSP033Y Diesel Gen 2EGS*EG2-2 exhaust hdr Exhaust Silencer 3B discharge to atmosphere Yes 12 2EDG-PSSP042A Diesel Gen 2EGS*EG2-2 exhaust hdr Exhaust Silencer 3B discharge to atmosphere Yes 12 2EDG-PSSP042B Diesel Gen 2EGS*EG2-2 exhaust hdr Exhaust Silencer 3B discharge to atmosphere Yes 12 2FWE-PSSP009 4" Aux Feed Water line to S/G 21C Between 2FWE*44B

2FWE*101 Yes 72 2FWE-PSSP010 4" Aux Feed Water line to S/G 21C Between 2FWE*44B

2FWE*101 Yes 72 2FWE-PSSP354A Aux FW Pump P22 6" discharge line Between 2FWE*P22 & 2FWE*FCV122 No 2FWE-PSSP354B Aux FW Pump P22 6" discharge line Between 2FWE*P22 & 2FWE*FCV122 No 2FWS-PSSP001 16" FW supply line to S/G 21A Between 2FWS*28 & 2RCS*SG21A No 2FWS-PSSP002A 16" FW supply line to S/G 21A Between 2FWS*28 & 2RCS*SG21A No Beaver Valley Unit 2 3.7.4 - 4 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 3 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2FWS-PSSP002B 16" FW supply line to S/G 21A Between 2FWS*28 & 2RCS*SG21A No 2FWS-PSSP003A 16" FW supply line to S/G 21A Between 2FWS*28 & 2RCS*SG21A No 2FWS-PSSP003B 16" FW supply line to S/G 21A Between 2FWS*28 & 2RCS*SG21A No 2FWS-PSSP005 16" FW supply line to S/G 21B Between 2FWS*29 & 2RCS*SG21B No 2FWS-PSSP006 16" FW supply line to S/G 21C Between 2FWS*30 & 2RCS*SG21C No 2FWS-PSSP012 16" FW supply line to S/G 21A Between 2FWS*28 & 2RCS*SG21A No 2FWS-PSSP016 16" FW supply line to S/G 21A Between 2FWS-25 & 2FWS*HYV157A No 2FWS-PSSP036 16" FW supply line to S/G 21B Between 2FWS-26 & 2FWS*HYV157B No 2FWS-PSSP039 16" FW supply line to S/G 21B Between 2FWS-26 & 2FWS*HYV157B No 2FWS-PSSP060 16" FW supply line to S/G 21C Between 2FWS*FCV498 & 2FWS-27 No 2MSS-PSSP001 32" Main Steam line from S/G 21A Between 2RCS*SG21A & Cnmt Pen X-73 No 2MSS-PSSP002A 32" Main Steam line from S/G 21A Between 2RCS*SG21A & Cnmt Pen X-73 No 2MSS-PSSP002B 32" Main Steam line from S/G 21A Between 2RCS*SG21A & Cnmt Pen X-73 No 2MSS-PSSP003A 32" Main Steam line from S/G 21A Between 2RCS*SG21A & Cnmt Pen X-73 No 2MSS-PSSP003B 32" Main Steam line from S/G 21A Between 2RCS*SG21A & Cnmt Pen X-73 No 2MSS-PSSP005 32" Main Steam line from S/G 21A Between 2RCS*SG21A & Cnmt Pen X-73 No 2MSS-PSSP006 32" Main Steam line from S/G 21A Between 2RCS*SG21A & Cnmt Pen X-73 No 2MSS-PSSP007 32" Main Steam line from S/G 21B Between 2RCS*SG21B & Cnmt Pen X-74 No 2MSS-PSSP008A 32" Main Steam line from S/G 21B Between 2RCS*SG21B & Cnmt Pen X-74 No 2MSS-PSSP008B 32" Main Steam line from S/G 21B Between 2RCS*SG21B & Cnmt Pen X-74 No Beaver Valley Unit 2 3.7.4 - 5 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 4 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2MSS-PSSP009 32" Main Steam line from S/G 21C Between 2RCS*SG21C & Cnmt Pen X-75 No 2MSS-PSSP011A 32" Main Steam line from S/G 21C Between 2RCS*SG21C & Cnmt Pen X-75 No 2MSS-PSSP011B 32" Main Steam line from S/G 21C Between 2RCS*SG21C & Cnmt Pen X-75 No 2MSS-PSSP012 32" Main Steam line from S/G 21C Between 2RCS*SG21C & Cnmt Pen X-75 No 2MSS-PSSP103 32" Main Steam line from S/G 21A Between 2MSS*AOV101A & 38" Steam Hdr No 2MSS-PSSP107 32" Main Steam line from S/G 21A Between 2MSS*AOV101A & 38" Steam Hdr No 2MSS-PSSP108A 32" Main Steam line from S/G 21A Between 2MSS*AOV101A & 38" Steam Hdr No 2MSS-PSSP108B 32" Main Steam line from S/G 21A Between 2MSS*AOV101A & 38" Steam Hdr No 2MSS-PSSP110 32" Main Steam line from S/G 21A Between 2MSS*AOV101A & 38" Steam Hdr No 2MSS-PSSP111A 32" Main Steam line from S/G 21A Between 2MSS*AOV101A & 38" Steam Hdr No 2MSS-PSSP111B 32" Main Steam line from S/G 21A Between 2MSS*AOV101A & 38" Steam Hdr No 2MSS-PSSP112A 32" Main Steam line from S/G 21A Between 2MSS*AOV101A & 38" Steam Hdr No 2MSS-PSSP112B 32" Main Steam line from S/G 21A Between 2MSS*AOV101A & 38" Steam Hdr No 2MSS-PSSP124 32" Main Steam line from S/G 21B Between 2MSS*AOV101B & 38" Steam Hdr No 2MSS-PSSP128A 32" Main Steam line from S/G 21B Between 2MSS*AOV101B & 38" Steam Hdr No 2MSS-PSSP128B 32" Main Steam line from S/G 21B Between 2MSS*AOV101B & 38" Steam Hdr No 2MSS-PSSP130 32" Main Steam line from S/G 21B Between 2MSS*AOV101B & 38" Steam Hdr No 2MSS-PSSP131A 32" Main Steam line from S/G 21B Between 2MSS*AOV101B & 38" Steam Hdr No 2MSS-PSSP131B 32" Main Steam line from S/G 21B Between 2MSS*AOV101B & 38" Steam Hdr No Beaver Valley Unit 2 3.7.4 - 6 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 5 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2MSS-PSSP132A 32" Main Steam line from S/G 21B Between 2MSS*AOV101B & 38" Steam Hdr No 2MSS-PSSP132B 32" Main Steam line from S/G 21B Between 2MSS*AOV101B & 38" Steam Hdr No 2MSS-PSSP144 32" Main Steam line from S/G 21C Between 2MSS*AOV101C & 38" Steam Hdr No 2MSS-PSSP147A 32" Main Steam line from S/G 21C Between 2MSS*AOV101C & 38" Steam Hdr No 2MSS-PSSP147B 32" Main Steam line from S/G 21C Between 2MSS*AOV101C & 38" Steam Hdr No 2MSS-PSSP149 32" Main Steam line from S/G 21C Between 2MSS*AOV101C & 38" Steam Hdr No 2MSS-PSSP150A 32" Main Steam line from S/G 21C Between 2MSS*AOV101C & 38" Steam Hdr No 2MSS-PSSP150B 32" Main Steam line from S/G 21C Between 2MSS*AOV101C & 38" Steam Hdr No 2MSS-PSSP151A 32" Main Steam line from S/G 21C Between 2MSS*AOV101C & 38" Steam Hdr No 2MSS-PSSP151B 32" Main Steam line from S/G 21C Between 2MSS*AOV101C & 38" Steam Hdr No 2MSS-PSSP164 Restraint to 38" Steam Header Attached to west end of Header No 2MSS-PSSP165 Restraint to 38" Steam Header Attached to west end of Header No 2MSS-PSSP168 Restraint to 38" Steam Header Attached to east end of Header No Steam supply line to Aux FW Pump 2MSS-PSSP456 P22 Between 2MSS*18 & 2FWE*TTV22 No Steam supply line to Aux FW Pump Between 2MSS*18/*196/*199 &

2MSS-PSSP476 P22 2SDS*251/*252 No 2QSS-PSSP101Y QSS Pump 21B SWS discharge line Between 2QSS*P21B & 2QSS*MOV101B/*9 No 2QSS-PSSP129Y QSS Pump 21A SWS discharge line Between 2QSS*P21A & 2QSS*MOV101A No 2QSS-PSSP131Y QSS Pump 21A SWS discharge line Between 2QSS*P21A & 2QSS*MOV101A/*98 No Beaver Valley Unit 2 3.7.4 - 7 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 6 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2QSS-PSSP138Y QSS Pump 21B SWS discharge line Between 2QSS*P21B & 2QSS*MOV101B/*9 No RWST supply to Refuel Wtr Cooling Between 2QSS*AOV120B &

2QSS-PSSP154X pumps 2QSS*AOV120A Yes 12 RWST supply to Refuel Wtr Cooling 2QSS-PSSP217X pumps Between RWST & 2QSS*AOV120B Yes 12 2RCS-PSSP001X 4" PZR Spray line from Loop A From Loop A cold leg to 2RCS*PCV455A Yes 12 2RCS-PSSP006A 6" PZR relief line to PORV's Between PZR & PORV's No 2RCS-PSSP007X 6" PZR relief line to PORV Between PZR & 2RCS*MOV536 No 2RCS-PSSP009A 6" PZR relief line from PORV Downstream of 2RCS*PCV456 No 2RCS-PSSP009B 6" PZR relief line from PORV Downstream of 2RCS*PCV456 No 2RCS-PSSP010A PZR Code Safety Valve discharge line Between 2RCS*RV551C & 12" Hdr to PRT No 2RCS-PSSP010B PZR Code Safety Valve discharge line Between 2RCS*RV551C & 12" Hdr to PRT No 2RCS-PSSP011X PZR Code Safety Valve discharge line Between 2RCS*RV551C & 12" Hdr to PRT No 2RCS-PSSP012A PZR Code Safety Valve discharge line Between 2RCS*RV551C & 12" Hdr to PRT No 2RCS-PSSP012B PZR Code Safety Valve discharge line Between 2RCS*RV551C & 12" Hdr to PRT No 2RCS-PSSP014A PZR Code Safety Valve discharge line Between 2RCS*RV551B & 12" Hdr to PRT No 2RCS-PSSP014B PZR Code Safety Valve discharge line Between 2RCS*RV551B & 12" Hdr to PRT No 2RCS-PSSP015X PZR Code Safety Valve discharge line Between 2RCS*RV551B & 12" Hdr to PRT No 2RCS-PSSP016X PZR Code Safety Valve discharge line Between 2RCS*RV551B & 12" Hdr to PRT No 2RCS-PSSP017X PZR Code Safety Valve discharge line Between 2RCS*RV551B & 12" Hdr to PRT No 2RCS-PSSP018X PZR Code Safety Valve discharge line Between 2RCS*RV551A & 12" Hdr to PRT No Beaver Valley Unit 2 3.7.4 - 8 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 7 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2RCS-PSSP019X PZR Code Safety Valve discharge line Between 2RCS*RV551A & 12" Hdr to PRT No 2RCS-PSSP020X PZR Code Safety Valve discharge line Between 2RCS*RV551A & 12" Hdr to PRT No 2RCS-PSSP021X PZR Code Safety Valve discharge line Between 2RCS*RV551A & 12" Hdr to PRT No 2RCS-PSSP022 Loop A 2" drain line Between 2RCS*5 & 2DGS*300 Yes 72 2RCS-PSSP022X 6" PZR relief line to PORV Between PZR & 2RCS*MOV535 No 2RCS-PSSP022Y 6" PZR relief line to PORV Between PZR & 2RCS*MOV535 No 2RCS-PSSP023X 3" PZR relief line to PORV Between 2RCS*MOV535 & 2RCS*PCV455C No 2RCS-PSSP026 Loop B 2" drain line Between 2RCS*7 & 2DGS*300 Yes 72 2RCS-PSSP026A 6" PZR relief line from PORV Between 2RCS*PCV455C & 12" Hdr to PRT No 2RCS-PSSP026B 6" PZR relief line from PORV Between 2RCS*PCV455C & 12" Hdr to PRT No 2RCS-PSSP028 Loop A 2" drain line Between 2RCS*5 & 2DGS*300 Yes 72 Between 2RCS*PCV455C/D & 12" Hdr to 2RCS-PSSP029X 6" PZR relief line from PORV's PRT No 2RCS-PSSP030 Loop B 2" drain line Between 2RCS*7 & 2DGS*300 Yes 72 2RCS-PSSP030X 6" PZR relief line to PORV Between PZR & 2RCS*MOV537 No 2RCS-PSSP031X 3" PZR relief line to PORV Between 2RCS*MOV537 & 2RCS*PCV455D No 2RCS-PSSP035 Loop C 2" drain line Between 2RCS*9 & 2DGS*300 Yes 72 2RCS-PSSP035X 12" Header from PZR to PRT Upstream of PRT No 2RCS-PSSP653 Loop B 2" drain line Between 2RCS*7 & 2DGS*300 Yes 72 2RCS-PSSP882 12" Header from PZR to PRT Upstream of PRT No Beaver Valley Unit 2 3.7.4 - 9 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 8 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2RCS-PSSP883A 12" Header from PZR to PRT Upstream of PRT No 2RCS-PSSP883B 12" Header from PZR to PRT Upstream of PRT No 2RCS-PSSP884A 12" Header from PZR to PRT Upstream of PRT No 2RCS-PSSP884B 12" Header from PZR to PRT Upstream of PRT No 2RCS-PSSP885 12" Header from PZR to PRT Upstream of PRT No 2RCS-PSSP887A PZR Code Safety Valve discharge line Between 2RCS*RV551C & 12" Hdr to PRT No 2RCS-PSSP887B PZR Code Safety Valve discharge line Between 2RCS*RV551C & 12" Hdr to PRT No 2RCS-PSSP890 6" PZR relief line from PORV Between 2RCS*PCV455C & 12" Hdr to PRT No 2RCS-PSSP891A 6" PZR relief line from PORV Between 2RCS*PCV455C & 12" Hdr to PRT No 2RCS-PSSP891B 6" PZR relief line from PORV Between 2RCS*PCV455C & 12" Hdr to PRT No 2RCS-PSSP892A 6" PZR relief line from PORV's Between PORV's & 12" Hdr to PRT No 2RCS-PSSP892B 6" PZR relief line from PORV's Between PORV's & 12" Hdr to PRT No 2RCS-PSSP893 6" PZR relief line from PORV's Between PORV's & 12" Hdr to PRT No 2RCS-PSSP894 6" PZR relief line from PORV Between 2RCS*PCV455D & 12" Hdr to PRT No 2RCS-PSSP896 6" PZR relief line from PORV Between 2RCS*PCV455D & 12" Hdr to PRT No 2RCS-PSSP897 6" PZR relief line from PORV Between 2RCS*PCV456 & 12" Hdr to PRT No 2RCS-PSSP898 3" PZR relief line to PORV Between 2RCS*MOV536 & 2RCS*PCV456 No Between RV's for RHS/CHS & 12" Hdr to 2RCS-PSSP906 6" relief line from four RV's to PRT PRT No 2RCS-SN21A10 Upper S/G Restraint 2RCS*SG21A No Beaver Valley Unit 2 3.7.4 - 10 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 9 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2RCS-SN21A12 Upper S/G Restraint 2RCS*SG21A No 2RCS-SN21B10 Upper S/G Restraint 2RCS*SG21B No 2RCS-SN21B12 Upper S/G Restraint 2RCS*SG21B No 2RCS-SN21C10 Upper S/G Restraint 2RCS*SG21C No 2RCS-SN21C12 Upper S/G Restraint 2RCS*SG21C No Between 2RHS*HCV758B &

2RHS-PSSP003 10" Return line from RHS Hx 21B 2RHS*MOV720B Yes 72 2RHS-PSSP005 6" RHS relief line to PRT Downstream from 2RHS*RV721A/*RV721B No 10" RHS Pump 21A SWS discharge 2RHS-PSSP007 line Between 2RHS*5 & 2RHS*E21A/*FCV605A Yes 72 Between 2RHS*HCV758A &

2RHS-PSSP008A 10" Return line from RHS Hx 21A 2RHS*MOV720A Yes 72 Between 2RHS*HCV758A &

2RHS-PSSP008B 10" Return line from RHS Hx 21A 2RHS*MOV720A Yes 72 2RHS-PSSP013X 6" RHS relief line to PRT Downstream from 2RHS*RV721B No 2RHS-PSSP521X 12" RHS supply line from RCS Between Loop A & 2RHS*MOV702A/B No Between 2RHS*MOV702A &

2RHS-PSSP522X 12" RHS supply line from RCS 2RHS*MOV701A No 2RSS-PSSP124A 12" RSS intake to RSS Hx 21A Between 2RSS*P21A & 2RSS*E21A No 2RSS-PSSP124B 12" RSS intake to RSS Hx 21A Between 2RSS*P21A & 2RSS*E21A No 2RSS-PSSP129A 12" RSS intake to RSS Hx 21C Between 2RSS*P21C & 2RSS*E21C No 2RSS-PSSP129B 12" RSS intake to RSS Hx 21C Between 2RSS*P21C & 2RSS*E21C No Beaver Valley Unit 2 3.7.4 - 11 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 10 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2RSS-PSSP134A 12" RSS intake to RSS Hx 21D Between 2RSS*P21D & 2RSS*E21D No 2RSS-PSSP134B 12" RSS intake to RSS Hx 21D Between 2RSS*P21D & 2RSS*E21D No 2RSS-PSSP139A 12" RSS intake to RSS Hx 21B Between 2RSS*P21B & 2RSS*E21B No 2RSS-PSSP139B 12" RSS intake to RSS Hx 21B Between 2RSS*P21B & 2RSS*E21B No 2RSS-PSSP465X RSS Hx 21D 12"SWS discharge line Between E21D & 2RSS*MOV156D No 2RSS-PSSP572A 4" recirc line to RSS Pump 21A Between 2RSS*5 & 2RSS*P21A Yes 72 2RSS-PSSP572B 4" recirc line to RSS Pump 21A Between 2RSS*5 & 2RSS*P21A Yes 72 2RSS-PSSP577 4" recirc line to RSS Pump 21D Between 2RSS*8 & 2RSS*P21D Yes 72 2RSS-PSSP579A 4" recirc line to RSS Pump 21B Between 2RSS*6 & 2RSS*P21B Yes 72 2RSS-PSSP579B 4" recirc line to RSS Pump 21B Between 2RSS*6 & 2RSS*P21B Yes 72 2SIS-PSSP006A 6" LHSI line to Loop A cold leg Between 2SIS*132/133 & 2SIS*107 Yes 12 2SIS-PSSP006B 6" LHSI line to Loop A cold leg Between 2SIS*132/133 & 2SIS*107 Yes 12 Between 2CHS*25/*MOV8132A &

2SIS-PSSP014A 4" HHSI line to RCS 2SIS*MOV869A Yes 72 Between 2CHS*25/*MOV8132A &

2SIS-PSSP014B 4" HHSI line to RCS 2SIS*MOV869A Yes 72 2SIS-PSSP208X 6" SIS line to Loop B cold leg Between 2SIS*108 & 2SIS*550 Yes 72 2SIS-PSSP209A 6" SIS line to Loop C cold leg Between 2SIS*109 & 2SIS*552 Yes 72 2SIS-PSSP209B 6" SIS line to Loop C cold leg Between 2SIS*109 & 2SIS*552 Yes 72 Between 2SIS*MOV8887A/B &

2SIS-PSSP301Y 10" LHSI to RCS hot legs 2SIS*MOV8889 Yes 12 Beaver Valley Unit 2 3.7.4 - 12 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 11 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time 2SIS-PSSP358Y 10" LHSI line from RSS Pump 21D Between 2RSS*E21D & 2SIS*46 No 2SIS-PSSP366Y LHSI Pump 21B 10" SWS discharge line Between 2SIS*P21B & 2SIS*7 No 2SIS-PSSP449A LHSI Pump 21A 10" SWS discharge line Between 2SIS*P21A & 2SIS*6 No 2SIS-PSSP449B LHSI Pump 21A 10" SWS discharge line Between 2SIS*P21A & 2SIS*6 No 2SIS-PSSP450X LHSI Pump 21A 10" SWS discharge line Between 2SIS*P21A & 2SIS*6 No 2SIS-PSSP451X RWST 14" supply line to LHSI Pump 21A Between RWST & 2SIS*1 Yes 12 RWST 14" supply line to CHS/HHSI 2SIS-PSSP480 Pumps Between RWST & 2SIS*27 Yes 12 2SIS-PSSP492 RWST 14" supply line to LHSI Pump 21B Between RWST & 2SIS*2 Yes 12 Between 2SIS*MOV863B &

2SIS-PSSP785 8" LHSI supply line to CHS/HHSI Pumps 2CHS*20/*MOV8131B Yes 72 Between 2SWS*MOV103B &

2SWS-PSSP752 24"SWS supply hdr B to RSS Hx's SWS*104/*MOV104B&D Yes 12 Between 2SWS*MOV103A &

2SWS-PSSP753 24"SWS supply hdr A to RSS Hx's SWS*104/*MOV104A&C Yes 12 Between 2SWS*MOV103A &

2SWS-PSSP754Y 24"SWS supply hdr A to RSS Hx's SWS*104/*MOV104A&C Yes 12 2SWS-PSSP766A 16" SWS discharge line from RSS Hx 21D Between 2SWS*MOV105D & the River No Between 2RSS*E21D &

2SWS-PSSP768Y 16" SWS discharge line from RSS Hx 21D 2SWS*MOV105D No 2SWS-PSSP769A 16" SWS discharge line from RSS Hx 21C Between 2SWS*MOV105C & the River No Beaver Valley Unit 2 3.7.4 - 13 LRM Revision 54

Licensing Requirements Manual Snubbers 3.7.4 TABLE 3.7.4-1 (Page 12 of 12)

SNUBBERS AND ASSOCIATED COMPLETION TIMES (HOURS)

LCO 3.0.8 Completion Functional Location Plant Location System Boundaries Applies Time Between 2RSS*E21C &

2SWS-PSSP770A 16" SWS discharge line from RSS Hx 21C 2SWS*MOV105C No Between 2RSS*E21C &

2SWS-PSSP770B 16" SWS discharge line from RSS Hx 21C 2SWS*MOV105C No Between 2RSS*E21C &

2SWS-PSSP771Y 16" SWS discharge line from RSS Hx 21C 2SWS*MOV105C No 2SWS-PSSP772A 16" SWS discharge line from RSS Hx 21A Between 2SWS*MOV105A & the River No 2SWS-PSSP772B 16" SWS discharge line from RSS Hx 21A Between 2SWS*MOV105A & the River No Between 2RSS*E21A &

2SWS-PSSP773A 16" SWS discharge line from RSS Hx 21A 2SWS*MOV105A No Between 2RSS*E21A &

2SWS-PSSP773B 16" SWS discharge line from RSS Hx 21A 2SWS*MOV105A No Between 2RSS*E21A &

2SWS-PSSP774Y 16" SWS discharge line from RSS Hx 21A 2SWS*MOV105A No Between 2RSS*E21B &

2SWS-PSSP830Y 16" SWS discharge line from RSS Hx 21B 2SWS*MOV105B No 2SWS-PSSP832A 16" SWS discharge line from RSS Hx 21B Between 2SWS*MOV105B & the River No 2SWS-PSSP832B 16" SWS discharge line from RSS Hx 21B Between 2SWS*MOV105B & the River No Beaver Valley Unit 2 3.7.4 - 14 LRM Revision 54

Licensing Requirements Manual Standby Service Water System (SWE) 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Standby Service Water System (SWE)

LR 3.7.5 At least one of the two standby service water subsystems shall be FUNCTIONAL.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required SWE subsystem A.1 Restore at least one 7 days Nonfunctional. subsystem to FUNCTIONAL status.

B. Required Action and B.1 Apply LR 3.0.3. Immediately associated Completion Time not met.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.7.5.1 Verify that the required SWE pump develops at least 92 days 109 psid differential pressure, while pumping through its test flow line.

LRS 3.7.5.2 Start the required SWE pump, shut down one Service 18 months on a Water System Pump, and verify that the SWE STAGGERED subsystem provides at least 8584 gpm cooling water to TEST BASIS that portion of the Service Water System under test for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Beaver Valley Unit 2 3.7.5 - 1 LRM Revision 69

Licensing Requirements Manual Explosive Gas Mixture 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Explosive Gas Mixture LR 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

> 4% 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.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Concentration of oxygen in A.1 Suspend all additions of Immediately the waste gas holdup waste gases to the system > 2% by volume gaseous waste decay tank.

but 4% by volume.

AND A.2 Reduce the concentration 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months of oxygen to 2%.

B. Concentration of oxygen in B.1 Suspend all additions of Immediately the waste gas holdup waste gases to the affected system > 4% by volume tank.

and the hydrogen concentration > 4% by AND volume.

B.2 Reduce the concentration Immediately of oxygen to 4% by volume.

Beaver Valley Unit 2 3.7.6 - 1 LRM Revision 52

Licensing Requirements Manual Explosive Gas Mixture 3.7.6 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.7.6.1 The concentrations of oxygen in the waste gas holdup In accordance system shall be determined to be within the above limits with LR 3.3.12 by 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.

Beaver Valley Unit 2 3.7.6 - 2 LRM Revision 52

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 3.7.7 Two SLCRS exhaust air filter trains shall be FUNCTIONAL.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SLCRS exhaust air A.1 Restore the Nonfunctional 7 days filter train Nonfunctional. train to FUNCTIONAL status.

B. Two SLCRS exhaust filter B.1 Verify by administrative 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months trains Nonfunctional due to means that both PAB the branch flow path from emergency exhaust fans the charging pump cubicles are FUNCTIONAL.

and component cooling water pump area being AND isolated.

B.2 Monitor air temperature of Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months charging pump cubicles and component cooling water pump area.

AND B.3 Place at least one PAB 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months from discovery emergency exhaust fan in of air temperature service if cubicle/pump exceeding limit area air temperatures exceed 100oF.

AND B.4 Restore one required 7 days Nonfunctional SLCRS exhaust filter train to FUNCTIONAL status.

C. Required Action and C.1 Apply LR 3.0.3. Immediately associated Completion Time not met.

Beaver Valley Unit 2 3.7.7 - 1 LRM Revision 83

Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS) 3.7.7 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.7.7.1 Initiate, from the control room, flow through the "standby" 31 days HEPA filter and charcoal adsorber train and verify that the train operates for at least 15 minutes with the heater controls operational.

LRS 3.7.7.2 Each SLCRS exhaust air filter train shall be 18 months demonstrated FUNCTIONAL:

AND

a. By verifying that the charcoal adsorbers remove 99.95% of a halogenated hydrocarbon refrigerant After each test gas when they are tested in-place in accordance complete or with ANSI N510-1980 while operating the ventilation partial system at a flow rate of 57,000 cfm +/- 10%. replacement of a HEPA filter or

b. By verifying that the HEPA filter banks remove charcoal 99.95% of the DOP when they are tested in-place adsorber bank in accordance with ANSI N510-1980 while operating the ventilation system at a flow rate of 57,000 cfm AND

+/- 10%.

After any

c. Within 31 days after removal, subjecting the carbon structural contained in at least one test canister or at least two maintenance on carbon samples removed from one of the charcoal the HEPA filter adsorbers to a laboratory carbon sample analysis or charcoal and verifying a removal efficiency of 99% for adsorber radioactive methyl iodide at an air flow velocity of 0.7 housings ft/sec with an inlet methyl iodide concentration of 1.75 mg/m3, 70% relative humidity, and 30°C; other AND test conditions including test parameter tolerances shall be in accordance with ASTM D3803-1989. The Following carbon samples not obtained from test canisters shall painting, fire or be taken with a slotted tube sampler in accordance chemical release with ANSI N509-1980. in any ventilation zone

d. By verifying a system flow rate of 57,000 cfm +/- 10% communicating during system operation. with the system Beaver Valley Unit 2 3.7.7 - 2 LRM Revision 83

Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS) 3.7.7 LICENSING REQUIREMENT SURVEILLANCES (continued)

SURVEILLANCE FREQUENCY LRS 3.7.7.3 Each SLCRS exhaust air filter train shall be 18 months demonstrated FUNCTIONAL:

a. By verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 6.8 inches Water Gauge while operating the ventilation system at a flow rate of 57,000 cfm

+/- 10%.

b. By verifying that the exhaust from the contiguous area is diverted through the SLCRS filter train on a Containment Isolation - Phase "A" signal in less than 5 minutes.

LRS 3.7.7.4 Verify that the air flow distribution to each HEPA filter After initial and charcoal adsorber is within +/- 20% of the averaged installation flow per unit.

AND After any maintenance affecting the flow distribution Beaver Valley Unit 2 3.7.7 - 3 LRM Revision 87

Licensing Requirements Manual 125V D.C. Battery Banks Maintenance Requirements 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 125V D.C. Battery Banks Maintenance Requirements LR 3.8.1 The 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.

APPLICABILITY: When the battery bank(s) are required to be OPERABLE in accordance with the Technical Specifications.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LR not met. A.1 Apply LR 3.0.3. Immediately LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.8.1.1 Verify no visible corrosion at either terminals or Once per 92 days connectors, or the connection resistance of these items are within design specifications. AND Within 7 days after a battery discharge with battery terminal voltage below 110V, or battery overcharge with battery terminal voltage above 150V LRS 3.8.1.2 Verify the following: 18 months

a. The cells, cell plates, and battery racks show no visual indication of physical damage or abnormal deterioration,

b. The cell-to-cell and terminal connections are clean, tight, and coated with anti-corrosion material, and

c. The resistance of cell-to-cell and terminal connections are within design specifications.

Beaver Valley Unit 2 3.8.1 - 1 LRM Revision 63

Licensing Requirements Manual EDG 2000 Hour Rating Limit 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 Emergency Diesel Generator (EDG) 2000 Hour Rating Limit LR 3.8.2 The auto-connected loads to each EDG shall not exceed the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating limit of 4,535 kw.

APPLICABILITY: When the EDG is required to be OPERABLE in accordance with the Technical Specifications.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LR not met. A.1 Apply LR 3.0.3. Immediately LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.8.2.1 Verify that the auto-connected loads to each EDG do 18 months during not exceed the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating. shutdown Beaver Valley Unit 2 3.8.2 - 1 LRM Revision 52

Licensing Requirements Manual Main Fuel Oil Storage Tank Maintenance Requirements 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Main Fuel Oil Storage Tank Maintenance Requirements LR 3.8.3 Main Fuel Oil Storage Tanks shall be maintained in accordance with LRS 3.8.3.1.

APPLICABILITY: When the associated Emergency Diesel Generator is required OPERABLE in accordance with Technical Specifications.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LR not met. A.1 Apply LR 3.0.3. Immediately LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.8.3.1 Drain each main fuel oil storage tank, remove the 10 years accumulated sediment, and clean the tank using a sodium hypochlorite solution or other appropriate cleaning solution.

Beaver Valley Unit 2 3.8.3 - 1 LRM Revision 52

Licensing Requirements Manual Crane Travel - Spent Fuel Storage Pool Building 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Crane Travel - Spent Fuel Storage Pool Building LR 3.9.1 Loads 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.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LR not met. A.1 Place the crane load in a Immediately safe condition.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.9.1.1 Crane interlocks and physical stops which prevent 30 days prior to crane travel with loads in excess of 2450 pounds over crane use fuel assemblies shall be demonstrated FUNCTIONAL. whenever the crane has been idle for more than 30 days Beaver Valley Unit 2 3.9.1 - 1 LRM Revision 67

Licensing Requirements Manual Manipulator Crane 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Manipulator Crane LR 3.9.2 The manipulator crane and auxiliary hoist shall be used for movement of 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, and

2. 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 in excess of 600 pounds.

APPLICABILITY: During movement of control rods or fuel assemblies within the reactor pressure vessel.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements for crane A.1 Suspend use of any Immediately and/or hoist Nonfunctional manipulator FUNCTIONALITY not met. crane and/or auxiliary hoist from operations involving the movement of control rods and fuel assemblies within the reactor pressure vessel.

Beaver Valley Unit 2 3.9.2 - 1 LRM Revision 67

Licensing Requirements Manual Manipulator Crane 3.9.2 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.9.2.1 Each manipulator crane used for movement of fuel Within 30 days assemblies within the reactor pressure vessel shall be prior to demonstrated FUNCTIONAL by performing a load test manipulator crane of at least 3250 pounds and demonstrating an use when the automatic load cut off when the crane load exceeds crane has been 2700 pounds. idle for more than 30 days LRS 3.9.2.2 Each auxiliary hoist and associated load indicator used Within 30 days for movement of control rods within the reactor pressure prior to auxiliary vessel shall be demonstrated FUNCTIONAL by hoist use when performing a load test of at least 700 pounds. the hoist has been idle for more than 30 days Beaver Valley Unit 2 3.9.2 - 2 LRM Revision 89

Licensing Requirements Manual Decay Time 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Decay Time LR 3.9.3 The reactor shall be subcritical for at least 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months .

APPLICABILITY: During movement of irradiated fuel assemblies in the reactor pressure vessel.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor subcritical for less A.1 Suspend all operations Immediately than 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months . involving movement of irradiated fuel assemblies in the reactor pressure vessel.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.9.3.1 The reactor shall be determined to have been Prior to subcritical for at least 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months by verification of the movement of date and time of subcriticality. irradiated fuel assemblies in the reactor pressure vessel Beaver Valley Unit 2 3.9.3 - 1 LRM Revision 52

Licensing Requirements Manual Core Operating Limits Report 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 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.

5.1.1 SL 2.1.1 Reactor Core Safety Limits See Figure 5.1-1.

5.1.2 SHUTDOWN MARGIN (SDM)

a. In MODES 1, 2, 3, and 4, SHUTDOWN MARGIN shall be 1.77% k/k.(1)

b. Prior to manually blocking the Low Pressurizer Pressure Safety Injection Signal, the Reactor Coolant System shall be borated to the MODE 5 boron concentration and shall remain this boron concentration at all times when this signal is blocked.

c. In MODE 5, SHUTDOWN MARGIN shall be 1.0% k/k.

5.1.3 LCO 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 10-4 k/k/F at RATED THERMAL POWER.

c. 300 ppm Surveillance Limit: (- 35 pcm/F)

d. The revised predicted near-EOL 300 ppm MTC shall be calculated using Figure 5.1-5 and the following algorithm from Reference 10 :

Revised Predicted MTC = Predicted MTC* + AFD Correction** + Predictive Correction***

where,

Predicted MTC is calculated from Figure 5.1-5 at the burnup corresponding to the measurement of 300 ppm at RTP conditions,

- AFD Correction is the more negative value of :

{0 pcm/F or (AFD

AFD Sensitivity)}

where: AFD is the measured AFD minus the predicted AFD from an incore flux map taken at or near the burnup corresponding to 300 ppm.

and AFD Sensitivity = 0.10 pcm/F / AFD

- - Predictive Correction is -3 pcm/F.

(1) The MODE 1 and MODE 2 with keff 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).

COLR Cycle 23 Beaver Valley Unit 2 5.1 - 1 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 5.1 Core Operating Limits Report If the revised predicted MTC is less negative than the SR 3.1.3.2 limit (COLR 5.1.3.c) and all of the benchmark data contained in the surveillance procedure are met, then an MTC measurement in accordance with SR 3.1.3.2 is not required.

e. 60 ppm Surveillance Limit: (- 40.5 pcm/F) 5.1.4 LCO 3.1.5 Shutdown Bank Insertion Limits The Shutdown Banks shall be withdrawn to at least 225 steps.(2) 5.1.5 LCO 3.1.6 Control Bank Insertion Limits

a. 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 in Figure 5.1-2.(2)

c. Sequence Limits - The sequence of withdrawal shall be A, B, C and D bank, in that order.

d. 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 at least to a position equal to the all-rods-out position minus 128 steps.

5.1.6 LCO 3.2.1 Heat Flux Hot Channel Factor (FQ(Z))

The Heat Flux Hot Channel Factor - FQ (Z) limit is defined by:

CFQ FQ (Z)

K(Z) for P > 0.5 P

CFQ FQ (Z)

K(Z) for P 0.5 0.5 THERMAL POWER Where: CFQ = 2.40 P = RATED THERMAL POWER K(Z) = the function obtained from Figure 5.1-3.

FQC ZFQM Z*1.0815$

TZCOLR COLR FQW ZFXY ZM Surv * *AXY Z*R j 1.0815$ for P > 0.5 P

TZCOLR COLR FQW ZFXY ZM Surv * *AXY Z*R j 1.0815$ for P 0.5 0.5 (2) As indicated by the group demand counter

$ An additional uncertainty is to be applied if the number of measured thimbles for the moveable incore detector system is less than 75% of the total number of thimbles. If there are less than 75% of the total number of thimbles and at least 50% of the total number of thimbles measured, and additional uncertainty of (0.01)*(3-T/12.5) is added to the measurement uncertainty, 1.05, where T is the total number of measured thimbles. This adjusted measurement uncertainty is then multiplied by 1.03 to obtain the total uncertainty to be applied. At least three measured thimbles per core quadrant are also required.

COLR Cycle 23 Beaver Valley Unit 2 5.1 - 2 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 5.1 Core Operating Limits Report FXY ZMSurv is the measured planar radial peaking factor and is equal to the value M

of FQ Z/P M Z, where P M Z is the measured core average axial power shape.

The T(Z) values in Tables 5.1-1 and 5.1-2 were generated assuming that they will be used for a full power surveillance, applicable to RAOC Operating Space (ROS)

1 and #2, respectively. The Rj values in Table 5.1-3 and 5.1-4 were generated to account for the increase in FQ between surveillances, applicable to ROS #1 and

2, respectively. The AXY Z factors adjust the surveillance to the reference conditions assumed in generating the T(Z) factors. AXY Z may be assumed to equal 1.0 or may be determined for specific surveillance conditions using the approved methods listed in TS 5.6.3.

Either ROS1 or ROS2 may be implemented at any time during operation.

If ROS1 is implemented and entering LCO 3.2.1 Condition B for FQW Z not within limits, EITHER take Action B.1.1 and implement ROS2, OR take Action B.2.1 by using Table 5.1-5 to determine required THERMAL POWER and AFD limits based on Required FQW Z margin improvement.

If ROS2 is implemented and entering LCO 3.2.1 Condition B for FQW Z not within limits, take Action B.2.1 by using Table 5.1-5 to determine required THERMAL POWER and AFD limits based on Required FQW Z margin improvement.

5.1.7 LCO 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor ( FNH )

N FH CF * (1 PF (1 P)) $

H H Where: CF = 1.62 H

PF = 0.3 H

THERMAL POWER P = RATED THERMAL POWER 5.1.8 LCO 3.2.3 Axial Flux Difference (AFD)

The AFD acceptable operation limits for both ROS1 and ROS2 are provided in Figure 5.1-4.

$ An additional uncertainty is to be applied if the number of measured thimbles for the moveable incore detector system is less than 75% of the total number of thimbles. If there are less than 75% of the total number of thimbles and at least 50% of the total number of thimbles measured, and additional uncertainty of (0.01)*(3-T/12.5) is added to the standard uncertainty on FNH of 1.04, where T is the total number of measured thimbles. At least three measured thimbles per core quadrant are also required.

COLR Cycle 23 Beaver Valley Unit 2 5.1 - 3 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 5.1 Core Operating Limits Report 5.1.9 LCO 3.3.1 Reactor Trip System Instrumentation - Overtemperature and Overpower T Parameter Values from Table Notations 3 and 4

a. Overtemperature T Setpoint Parameter Values:

Parameter Value Overtemperature T reactor trip setpoint K1 1.239 Overtemperature T reactor trip setpoint Tavg K2 0.0183/F coefficient Overtemperature T reactor trip setpoint pressure K3 0.001/psia coefficient Tavg at RATED THERMAL POWER T' 574.2F(1)

Nominal pressurizer pressure P' 2250 psia Measured reactor vessel T lead/lag time constants 1 = 0 sec*

(* The response time is toggled off to meet the analysis 2 = 0 sec*

value of zero.)

Measured reactor vessel T lag time constant 3 6 secs Measured reactor vessel average temperature lead/lag 4 30 secs time constants 5 4 secs Measured reactor vessel average temperature lag time 6 2 secs constant f (I) is a function of the indicated difference between top and bottom detectors of the power-range nuclear ion chambers, with gains to be selected based on measured instrument response during plant startup tests such that:

(i) For qt - qb between -37% and +15%, f1(I) = 0, where qt and qb are percent RATED THERMAL POWER in the top and bottom halves of the core respectively, and qt + qb is total THERMAL POWER in percent of RATED THERMAL POWER.

(ii) For each percent that the magnitude of (qt - qb) exceeds -37%, the T trip setpoint shall be automatically reduced by 2.52% of its value at RATED THERMAL POWER.

(iii) For each percent that the magnitude of (qt - qb) exceeds +15%, the T trip setpoint shall be automatically reduced by 1.47% of its value at RATED THERMAL POWER.

(1) T' represents the cycle-specific Full Power Tavg value used in core design.

COLR Cycle 23 Beaver Valley Unit 2 5.1 - 4 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 5.1 Core Operating Limits Report

b. Overpower T Setpoint Parameter Values:

Parameter Value Overpower T reactor trip setpoint K4 1.094 Overpower T reactor trip setpoint Tavg K5 0.02/F for increasing rate/lag coefficient average temperature K5 = 0/F for decreasing average temperature Overpower T 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" 574.2F(1)

Measured reactor vessel T lead/lag 1 = 0 sec*

time constants 2 = 0 sec*

(* The response time is toggled off to meet the analysis value of zero.)

Measured reactor vessel T lag time 3 6 secs constant Measured reactor vessel average 6 2 secs temperature lag time constant Measured reactor vessel average 7 10 secs temperature rate/lag time constant (1) T represents the cycle-specific Full Power Tavg value used in core design.

COLR Cycle 23 Beaver Valley Unit 2 5.1 - 5 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 5.1 Core Operating Limits Report 5.1.10 LCO 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits Parameter Indicated Value Reactor Coolant System Tavg Tavg 577.8F(1)

Pressurizer Pressure Pressure 2214 psia(2)

Reactor Coolant System Total Flow Rate Flow 267,483 gpm(3) 5.1.11 LCO 3.9.1 Boron Concentration (MODE 6)

The boron concentration of the Reactor Coolant System, the refueling canal, and the refueling cavity shall be maintained 2400 ppm. This value includes a 50 ppm conservative allowance for uncertainties.

(1) The Reactor Coolant System (RCS) indicated Tavg value is determined by adding the appropriate allowances for rod control operation and verification via control board indication (3.6F) to the cycle specific full power Tavg used in the core design.

(2) The pressurizer pressure value includes allowances for pressurizer pressure control operation and verification via control board indication.

(3) The RCS total flow rate includes allowances for normalization 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.

COLR Cycle 23 Beaver Valley Unit 2 5.1 - 6 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 5.1 Core Operating Limits Report 5.1.12 References

1. WCAP-9272-P-A, "WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY," July 1985 (Westinghouse Proprietary).

2. WCAP-8745-P-A, "Design Bases for the Thermal Overpower T and Thermal Overtemperature T 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-10216-P-A, Revision 1A, "Relaxation of Constant Axial Offset Control-FQ Surveillance Technical Specification," February 1994.

5. WCAP-14565-P-A, "VIPRE-01 Modeling and Qualification for Pressurized Water Reactor Non-LOCA Thermal-Hydraulic Safety Analysis,"

October 1999.

6. WCAP-12610-P-A, "VANTAGE+ Fuel Assembly Reference Core Report,"

April 1995 (Westinghouse Proprietary).

7. WCAP-15025-P-A, "Modified WRB-2 Correlation, WRB-2M, for Predicting Critical Heat Flux in 17x17 Rod Bundles with Modified LPD Mixing Vane Grids," April 1999.

8. Caldon, Inc. Engineering Report-80P, "Improving Thermal Power Accuracy and Plant Safety While Increasing Operating Power Level Using the LEFMTM System," Revision 0, March 1997.

9. Caldon, Inc. Engineering Report-160P, "Supplement to Topical Report ER-80P: Basis for a Power Uprate With the LEFMTM System," Revision 0, May 2000.

10. WCAP-13749-P-A, Safety Evaluation Supporting the Conditional Exemption of the Most Negative EOL Moderator Temperature Coefficient Measurement, March 1997 (Westinghouse Proprietary).

11. WCAP-16045-P-A, Qualification of the Two-Dimensional Transport Code PARAGON, August 2004.

12. WCAP-16045-P-A, Addendum 1-A, Qualification of the NEXUS Nuclear Data Methodology, August 2007.

13. WCAP-12610-P-A & CENPD-404-P-A, Addendum 1-A Optimized ZIRLOTM, July 2006.

14. WCAP-17661-P-A, Revision 1, Improved RAOC and CAOC FQ Surveillance Technical Specifications, February 2019.

. COLR Cycle 23 Beaver Valley Unit 2 5.1 - 7 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 670 660 2435 PSIA UNACCEPTABLE OPERATION 650 2250 PSIA 640 630 Tavg (Deg F) 2000 PSIA 620 1920 PSIA 610 600 ACCEPTABLE OPERATION 590 580 0 0.2 0.4 0.6 0.8 1 1.2 1.4 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)

COLR Cycle 23 Beaver Valley Unit 2 5.1 - 8 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 225 (54.53, 225) 200 BANK C (100, 187)

ROD BANK POSITION (Steps Withdrawn) 175 150 125 (0, 114) BANK D 100 75 50 25 (8, 0) 0 0 10 20 30 40 50 60 70 80 90 100 PERCENT OF RATED THERMAL POWER Figure 5.1-2 (Page 1 of 1)

CONTROL ROD INSERTION LIMITS AS A FUNCTION OF RATED POWER LEVEL COLR Cycle 23 Beaver Valley Unit 2 5.1 - 9 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 1.2 0.0, 1.00 6.0, 1.00 1.0 12.0, 0.925 0.8 K(Z) 0.6 0.4 0.2 0.0 0 2 4 6 8 10 12 Core Height (feet)

Figure 5.1-3 (Page 1 of 1)

FQT NORMALIZED OPERATING ENVELOPE, K(Z)

COLR Cycle 23 Beaver Valley Unit 2 5.1 - 10 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 ROS1 ROS2 RA1 RA2 120 110 100 90 UNACCEPTABLE UNACCEPTABLE

% of Rated Thermal Power OPERATION OPERATION 80 ACCEPTABLE 70 OPERATION 60 50 40 30 20 10 0

-60 -50 -40 -30 -20 -10 0 10 20 30 40 50 60 Axial Flux Difference (Delta I) %

ROS1 ROS2

(-26%, 50%) (-9%, 100%) (-25%, 50%) (-8%, 100%)

(9%, 100%) (23%, 50%) (8%, 100%) (22%, 50%)

RA1 RA2

(-25%, 50%) (-9.7%, 95%) (-25%, 50%) (-11.4%, 90%)

(9.4 %, 95%) (22%, 50%) (10.8%, 90%) (22%, 50%)

Figure 5.1-4 (Page 1 of 1)

AXIAL FLUX DIFFERENCE LIMITS AS A FUNCTION OF PERCENT OF RATED THERMAL POWER FOR RAOC COLR Cycle 23 Beaver Valley Unit 2 5.1 - 11 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 29.00 CYCLE BURNUP MTC (MWD/MTU) (pcm/°F) 14000 -30.004 18000 -31.236 MODERATOR TEMPERATURE COEFFICIENT (pcm/°F) 30.00 31.00 32.00 14000 15000 16000 17000 18000 CYCLE BURNUP (MWD/MTU)

Figure 5.1-5 (Page 1 of 1)

HOT FULL POWER PREDICTED MODERATOR TEMPERATURE COEFFICIENT AS A FUNCTION OF CYCLE BURNUP WHEN 300 PPM IS ACHIEVED COLR Cycle 23 Beaver Valley Unit 2 5.1 - 12 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 Table 5.1-1 (Page 1 of 1)

FQ Surveillance T(Z) Function versus Burnup at 100% RTP for ROS1 Axial Elevation 150 1000 2000 3000 4000 6000 8000 10000 12000 14000 16000 Point (feet) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) 1* 12.0720 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 2* 11.8708 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 3* 11.6696 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 4* 11.4684 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 5* 11.2672 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 6* 11.0660 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 7* 10.8648 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 8 10.6636 1.1212 1.0970 1.0994 1.0966 1.1140 1.1429 1.1618 1.1790 1.1987 1.2050 1.2231 9 10.4624 1.2089 1.1910 1.1932 1.1914 1.2100 1.2378 1.2537 1.2670 1.2820 1.2840 1.2962 10 10.2612 1.2344 1.2210 1.2231 1.2226 1.2410 1.2671 1.2799 1.2900 1.3005 1.3030 1.3076 11 10.0600 1.1946 1.1900 1.1887 1.1899 1.2070 1.2319 1.2427 1.2510 1.2591 1.2630 1.2632 12 9.8588 1.2149 1.2130 1.2076 1.2111 1.2230 1.2449 1.2525 1.2600 1.2692 1.2660 1.2604 13 9.6576 1.2914 1.2910 1.2829 1.2858 1.2960 1.3074 1.3211 1.3170 1.3265 1.3230 1.3063 14 9.4564 1.3017 1.3030 1.2964 1.2998 1.3080 1.3168 1.3339 1.3230 1.3279 1.3280 1.3142 15 9.2552 1.2549 1.2590 1.2521 1.2613 1.2620 1.2684 1.2870 1.2750 1.2768 1.2810 1.2719 16 9.0540 1.2304 1.2360 1.2416 1.2486 1.2440 1.2572 1.2651 1.2470 1.2467 1.2580 1.2534 17 8.8528 1.2941 1.3000 1.3164 1.3193 1.3220 1.3257 1.3227 1.2930 1.2949 1.3040 1.3008 18 8.6516 1.3443 1.3510 1.3710 1.3720 1.3770 1.3754 1.3647 1.3260 1.3284 1.3340 1.3332 19 8.4504 1.3247 1.3330 1.3546 1.3561 1.3600 1.3573 1.3421 1.3070 1.3079 1.3140 1.3158 20 8.2492 1.2783 1.2890 1.3111 1.3131 1.3170 1.3138 1.2934 1.2630 1.2632 1.2730 1.2772 21 8.0480 1.3337 1.3450 1.3685 1.3694 1.3720 1.3643 1.3387 1.3070 1.3041 1.3140 1.3182 22 7.8468 1.3812 1.3940 1.4176 1.4175 1.4180 1.4067 1.3742 1.3410 1.3361 1.3470 1.3504 23 7.6456 1.3523 1.3660 1.3899 1.3899 1.3900 1.3777 1.3427 1.3110 1.3074 1.3200 1.3254 24 7.4444 1.2880 1.3030 1.3261 1.3268 1.3270 1.3152 1.2801 1.2510 1.2506 1.2650 1.2735 25 7.2432 1.3035 1.3190 1.3422 1.3424 1.3410 1.3272 1.2878 1.2580 1.2577 1.2730 1.2814 26 7.0420 1.3622 1.3790 1.4006 1.3997 1.3960 1.3781 1.3321 1.3030 1.2982 1.3120 1.3203 27 6.8408 1.3651 1.3830 1.4026 1.4014 1.3970 1.3770 1.3282 1.3040 1.2958 1.3090 1.3183 28 6.6396 1.2984 1.3160 1.3348 1.3345 1.3300 1.3123 1.2654 1.2490 1.2401 1.2530 1.2654 29 6.4384 1.2724 1.2910 1.3074 1.3075 1.3030 1.2849 1.2417 1.2270 1.2158 1.2280 1.2414 30 6.2372 1.3254 1.3440 1.3585 1.3572 1.3510 1.3290 1.2878 1.2690 1.2521 1.2610 1.2735 31 6.0360 1.3224 1.3410 1.3537 1.3547 1.3450 1.3227 1.2869 1.2660 1.2457 1.2520 1.2651 32 5.8348 1.2575 1.2760 1.2897 1.2918 1.2800 1.2581 1.2316 1.2110 1.1924 1.1970 1.2106 33 5.6336 1.2082 1.2260 1.2408 1.2436 1.2360 1.2104 1.1863 1.1690 1.1485 1.1530 1.1670 34 5.4324 1.2600 1.2790 1.2969 1.2938 1.2850 1.2609 1.2297 1.2040 1.1906 1.1910 1.1964 35 5.2312 1.2943 1.3130 1.3319 1.3297 1.3170 1.2935 1.2621 1.2290 1.2183 1.2170 1.2201 36 5.0300 1.2836 1.3030 1.3218 1.3205 1.3090 1.2861 1.2562 1.2230 1.2128 1.2110 1.2124 37 4.8288 1.2738 1.2910 1.3123 1.3121 1.3010 1.2795 1.2516 1.2190 1.2087 1.2060 1.2073 38 4.6276 1.2745 1.2930 1.3130 1.3136 1.3040 1.2823 1.2562 1.2240 1.2132 1.2080 1.2097 39 4.4264 1.2841 1.3020 1.3222 1.3237 1.3150 1.2940 1.2691 1.2360 1.2253 1.2200 1.2185 40 4.2252 1.2672 1.2840 1.3043 1.3070 1.3000 1.2822 1.2591 1.2290 1.2173 1.2110 1.2087 41 4.0240 1.2058 1.2220 1.2414 1.2459 1.2410 1.2290 1.2103 1.1870 1.1751 1.1700 1.1678 42 3.8228 1.2011 1.2160 1.2350 1.2410 1.2400 1.2299 1.2126 1.1950 1.1793 1.1740 1.1693 43 3.6216 1.2485 1.2620 1.2829 1.2914 1.2920 1.2813 1.2625 1.2480 1.2292 1.2200 1.2113 44 3.4204 1.2520 1.2640 1.2889 1.2988 1.3000 1.2916 1.2774 1.2660 1.2464 1.2340 1.2231 45 3.2192 1.2308 1.2410 1.2671 1.2781 1.2810 1.2776 1.2702 1.2620 1.2434 1.2310 1.2211 46 3.0180 1.2273 1.2360 1.2613 1.2690 1.2740 1.2698 1.2684 1.2620 1.2443 1.2330 1.2250 47 2.8168 1.2404 1.2520 1.2735 1.2712 1.2840 1.2799 1.2842 1.2820 1.2658 1.2530 1.2499 48 2.6156 1.2616 1.2720 1.2944 1.2843 1.3020 1.3038 1.3044 1.3120 1.2970 1.2840 1.2836 49 2.4144 1.2455 1.2540 1.2767 1.2662 1.2820 1.2905 1.2916 1.3080 1.2959 1.2860 1.2881 50 2.2132 1.1957 1.2020 1.2236 1.2128 1.2270 1.2427 1.2490 1.2720 1.2648 1.2660 1.2716 51 2.0120 1.2212 1.2240 1.2440 1.2311 1.2430 1.2645 1.2746 1.3020 1.2980 1.2980 1.3052 52 1.8108 1.2720 1.2700 1.2880 1.2719 1.2810 1.3066 1.3194 1.3510 1.3498 1.3530 1.3619 53 1.6096 1.2647 1.2580 1.2724 1.2538 1.2600 1.2897 1.3067 1.3430 1.3488 1.3580 1.3704 54 1.4084 1.2282 1.2170 1.2272 1.2066 1.2100 1.2425 1.2637 1.3040 1.3176 1.3330 1.3510 55* 1.2072 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 56* 1.0060 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 57* 0.8048 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 58* 0.6036 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 59* 0.4024 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 60* 0.2012 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 61* 0.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000

Top and Bottom 10% Excluded COLR Cycle 23 Beaver Valley Unit 2 5.1 - 13 LRM Revision 98

Licensing Requirements Manual Core Operating Limits Report 5.1 Table 5.1-2 (Page 1 of 1)

FQ Surveillance T(Z) Function versus Burnup at 100% RTP for ROS2 Axial Elevation 150 1000 2000 3000 4000 6000 8000 10000 12000 14000 16000 Point (feet) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) (MWD/MTU) 1* 12.0720 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 2* 11.8708 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 3* 11.6696 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 4* 11.4684 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 5* 11.2672 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 6* 11.0660 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 7* 10.8648 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 8 10.6636 1.1212 1.0920 1.0742 1.0658 1.0820 1.1086 1.1324 1.1450 1.1680 1.2050 1.2027 9 10.4624 1.2081 1.1820 1.1650 1.1605 1.1790 1.2049 1.2264 1.2310 1.2514 1.2830 1.2719 10 10.2612 1.2296 1.2080 1.1943 1.1983 1.2130 1.2372 1.2559 1.2560 1.2723 1.2970 1.2835 11 10.0600 1.1865 1.1710 1.1699 1.1730 1.1830 1.2060 1.2227 1.2230 1.2344 1.2540 1.2441 12 9.8588 1.1981 1.1940 1.1993 1.1998 1.2100 1.2218 1.2351 1.2400 1.2399 1.2530 1.2456 13 9.6576 1.2742 1.2740 1.2800 1.2799 1.2890 1.2852 1.2938 1.3010 1.2964 1.2950 1.2966 14 9.4564 1.2891 1.2910 1.2936 1.2941 1.3030 1.2936 1.3001 1.3060 1.2991 1.2990 1.2979 15 9.2552 1.2404 1.2440 1.2520 1.2536 1.2620 1.2526 1.2569 1.2570 1.2504 1.2570 1.2518 16 9.0540 1.2181 1.2230 1.2318 1.2339 1.2410 1.2322 1.2338 1.2280 1.2233 1.2390 1.2292 17 8.8528 1.2836 1.2940 1.2969 1.2985 1.3040 1.2909 1.2877 1.2800 1.2721 1.2900 1.2801 18 8.6516 1.3362 1.3520 1.3483 1.3493 1.3540 1.3313 1.3241 1.3210 1.3072 1.3220 1.3225 19 8.4504 1.3180 1.3330 1.3325 1.3337 1.3380 1.3092 1.3004 1.3040 1.2880 1.3020 1.3069 20 8.2492 1.2731 1.2890 1.2898 1.2916 1.2950 1.2612 1.2525 1.2610 1.2453 1.2610 1.2718 21 8.0480 1.3295 1.3450 1.3468 1.3475 1.3500 1.3092 1.2990 1.3050 1.2870 1.3010 1.3122 22 7.8468 1.3781 1.3940 1.3957 1.3954 1.3960 1.3486 1.3353 1.3390 1.3200 1.3330 1.3456 23 7.6456 1.3503 1.3660 1.3693 1.3692 1.3690 1.3198 1.3063 1.3090 1.2931 1.3070 1.3219 24 7.4444 1.2870 1.3030 1.3074 1.3080 1.3080 1.2587 1.2466 1.2500 1.2383 1.2530 1.2712 25 7.2432 1.3033 1.3190 1.3247 1.3247 1.3230 1.2706 1.2547 1.2570 1.2470 1.2600 1.2802 26 7.0420 1.3621 1.3790 1.3846 1.3835 1.3800 1.3255 1.3007 1.2970 1.2888 1.3000 1.3202 27 6.8408 1.3649 1.3820 1.3890 1.3876 1.3830 1.3319 1.3053 1.2940 1.2880 1.2980 1.3183 28 6.6396 1.2983 1.3160 1.3242 1.3238 1.3200 1.2766 1.2523 1.2410 1.2343 1.2440 1.2654 29 6.4384 1.2723 1.2910 1.2996 1.2994 1.2950 1.2574 1.2334 1.2210 1.2118 1.2210 1.2414 30 6.2372 1.3253 1.3440 1.3528 1.3536 1.3450 1.3090 1.2813 1.2640 1.2497 1.2550 1.2735 31 6.0360 1.3224 1.3410 1.3532 1.3545 1.3430 1.3110 1.2827 1.2620 1.2453 1.2490 1.2651 32 5.8348 1.2575 1.2760 1.2897 1.2918 1.2790 1.2553 1.2297 1.2100 1.1924 1.1950 1.2105 33 5.6336 1.2082 1.2260 1.2401 1.2436 1.2360 1.2103 1.1862 1.1690 1.1512 1.1530 1.1662 34 5.4324 1.2600 1.2790 1.2915 1.2914 1.2840 1.2600 1.2262 1.2040 1.1864 1.1870 1.1884 35 5.2312 1.2943 1.3130 1.3265 1.3239 1.3140 1.2914 1.2532 1.2280 1.2124 1.2120 1.2127 36 5.0300 1.2836 1.3030 1.3159 1.3146 1.3030 1.2828 1.2456 1.2200 1.2065 1.2050 1.2060 37 4.8288 1.2738 1.2910 1.3045 1.3057 1.2930 1.2751 1.2401 1.2150 1.2016 1.1980 1.2001 38 4.6276 1.2745 1.2930 1.3062 1.3069 1.2950 1.2769 1.2437 1.2180 1.2050 1.2000 1.2013 39 4.4264 1.2841 1.3020 1.3150 1.3164 1.3050 1.2870 1.2555 1.2300 1.2160 1.2080 1.2089 40 4.2252 1.2672 1.2840 1.2968 1.2995 1.2900 1.2728 1.2449 1.2200 1.2071 1.1980 1.1982 41 4.0240 1.2058 1.2220 1.2339 1.2384 1.2320 1.2177 1.1960 1.1750 1.1644 1.1550 1.1568 42 3.8228 1.2011 1.2160 1.2274 1.2331 1.2290 1.2156 1.1974 1.1800 1.1677 1.1570 1.1575 43 3.6216 1.2485 1.2620 1.2727 1.2788 1.2770 1.2609 1.2474 1.2320 1.2139 1.2020 1.1977 44 3.4204 1.2523 1.2650 1.2738 1.2823 1.2830 1.2691 1.2620 1.2480 1.2285 1.2180 1.2090 45 3.2192 1.2286 1.2400 1.2493 1.2596 1.2620 1.2554 1.2545 1.2430 1.2248 1.2140 1.2023 46 3.0180 1.2222 1.2310 1.2436 1.2536 1.2550 1.2485 1.2532 1.2420 1.2255 1.2230 1.2060 47 2.8168 1.2294 1.2390 1.2551 1.2651 1.2670 1.2596 1.2666 1.2620 1.2430 1.2530 1.2296 48 2.6156 1.2444 1.2580 1.2743 1.2845 1.2870 1.2832 1.2904 1.2890 1.2710 1.2840 1.2593 49 2.4144 1.2281 1.2420 1.2557 1.2661 1.2690 1.2696 1.2788 1.2830 1.2697 1.2860 1.2613 50 2.2132 1.1797 1.1910 1.2025 1.2128 1.2170 1.2222 1.2345 1.2450 1.2386 1.2660 1.2429 51 2.0120 1.2047 1.2130 1.2217 1.2311 1.2350 1.2432 1.2570 1.2730 1.2706 1.2970 1.2736 52 1.8108 1.2546 1.2590 1.2641 1.2718 1.2750 1.2842 1.2985 1.3180 1.3203 1.3510 1.3284 53 1.6096 1.2475 1.2470 1.2482 1.2538 1.2560 1.2672 1.2833 1.3090 1.3176 1.3540 1.3374 54 1.4084 1.2118 1.2060 1.2033 1.2065 1.2080 1.2206 1.2390 1.2700 1.2858 1.3280 1.3190 55* 1.2072 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 56* 1.0060 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 57* 0.8048 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 58* 0.6036 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 59* 0.4024 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 60* 0.2012 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 61* 0.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000

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Licensing Requirements Manual Core Operating Limits Report 5.1 Table 5.1-3 (Page 1 of 1)

FQ Surveillance Rj Factor versus Burnup at 100% RTP for ROS1 Cycle Cycle Rj Cycle Rj Penalty Rj Penalty Burnup Burnup Penalty Burnup Multiplier Multiplier (MWD/MTU) (MWD/MTU) Multiplier (MWD/MTU) 150 1.048 6800 1.000 13451 1.000 346 1.045 6996 1.000 13646 1.000 541 1.042 7192 1.000 13842 1.000 737 1.037 7387 1.000 14038 1.000 932 1.033 7583 1.004 14233 1.000 1128 1.027 7778 1.007 14429 1.000 1324 1.022 7974 1.011 14624 1.000 1519 1.014 8170 1.014 14820 1.000 1715 1.010 8365 1.017 15016 1.000 1910 1.008 8561 1.016 15211 1.000 2106 1.007 8756 1.017 15407 1.000 2302 1.007 8952 1.014 15602 1.000 2497 1.008 9148 1.007 15798 1.000 2693 1.011 9343 1.005 15994 1.000 2888 1.011 9539 1.003 16189 1.000 3084 1.010 9734 1.002 16385 1.000 3280 1.009 9930 1.001 16580 1.000 3475 1.008 10126 1.000 16776 1.000 3671 1.006 10321 1.000 16972 1.000 3866 1.004 10517 1.000 17167 1.000 4062 1.003 10712 1.000 17363 1.000 4258 1.002 10908 1.000 17558 1.000 4453 1.001 11104 1.000 17754 1.000 4649 1.000 11299 1.000 17950 1.000 4844 1.000 11495 1.000 18145 1.000 5040 1.000 11690 1.000 5236 1.000 11886 1.000 5431 1.000 12082 1.000 5627 1.000 12277 1.000 5822 1.000 12473 1.000 6018 1.000 12668 1.000 6214 1.000 12864 1.000 6409 1.000 13060 1.000 6605 1.000 13255 1.000 Note: The Burnup Dependent Transient FQ Margin Decrease Factor Rj, to be applied to FQ(Z) in accordance with Technical Specification Surveillance Requirement (SR) 3.2.1.2, is the amount by which FQ(Z) is calculated to increase over a 39 Effective Full 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. Values may be interpolated to the surveillance cycle burnup.

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Licensing Requirements Manual Core Operating Limits Report 5.1 Table 5.1-4 (Page 1 of 1)

FQ Surveillance Rj Factor versus Burnup at 100% RTP for ROS2 Cycle Cycle Rj Cycle Rj Rj Penalty Burnup Burnup Penalty Burnup Penalty Multiplier (MWD/MTU) (MWD/MTU) Multiplier (MWD/MTU) Multiplier 150 1.037 6800 1.007 13451 1.000 346 1.031 6996 1.009 13646 1.000 541 1.024 7192 1.008 13842 1.000 737 1.019 7387 1.008 14038 1.000 932 1.014 7583 1.012 14233 1.000 1128 1.011 7778 1.012 14429 1.000 1324 1.008 7974 1.011 14624 1.000 1519 1.008 8170 1.013 14820 1.000 1715 1.007 8365 1.013 15016 1.000 1910 1.007 8561 1.012 15211 1.000 2106 1.009 8756 1.010 15407 1.000 2302 1.009 8952 1.009 15602 1.000 2497 1.009 9148 1.005 15798 1.000 2693 1.009 9343 1.003 15994 1.000 2888 1.008 9539 1.002 16189 1.000 3084 1.007 9734 1.001 16385 1.000 3280 1.006 9930 1.000 16580 1.000 3475 1.004 10126 1.000 16776 1.000 3671 1.001 10321 1.000 16972 1.000 3866 1.000 10517 1.000 17167 1.000 4062 1.000 10712 1.000 17363 1.000 4258 1.000 10908 1.000 17558 1.000 4453 1.000 11104 1.001 17754 1.000 4649 1.000 11299 1.003 17950 1.000 4844 1.000 11495 1.012 18145 1.000 5040 1.000 11690 1.013 5236 1.000 11886 1.014 5431 1.000 12082 1.014 5627 1.000 12277 1.014 5822 1.000 12473 1.013 6018 1.000 12668 1.012 6214 1.001 12864 1.011 6409 1.003 13060 1.002 6605 1.005 13255 1.001 Note: The Burnup Dependent Transient FQ Margin Decrease Factor Rj, to be applied to FQ(Z) in accordance with Technical Specification Surveillance Requirement (SR) 3.2.1.2, is the amount by which FQ(Z) is calculated to increase over a 39 Effective Full 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. Values may be interpolated to the surveillance cycle burnup.

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Licensing Requirements Manual Core Operating Limits Report 5.1 Table 5.1-5 (Page 1 of 1)

Required Thermal Power Limits and AFD Reductions Required Action B.2.1 AFD Power Percent Space Reduction Reduction Margin ROS1 RA1 1.00% 5% 3.14%

RA2 1.00% 10% 4.04%

< 50% RTP ROS2 RA1 0.00% 5% 0.00%

RA2 0.00% 10% 0.98%

< 50% RTP COLR Cycle 23 Beaver Valley Unit 2 5.1 - 17 LRM Revision 98

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Pressure and Temperature Limits Report BVPS-2 Technical Specification to PTLR Cross-Reference Technical PTLR Specification Section Figure Table 3.4.3 5.2.1.1 5.2-1 N/A 5.2-2 5.2-3 5.2-4 5.2-5 5.2-6 3.4.6 N/A N/A 5.2-3 3.4.7 N/A N/A 5.2-3 3.4.10 N/A N/A 5.2-3 3.4.12 5.2.1.2 5.2-8 5.2-3 5.2.1.3 3.5.2 N/A N/A 5.2-3 BVPS-2 Licensing Requirement to PTLR Cross-Reference Licensing PTLR Requirement Section Figure Table LR 3.1.2 N/A N/A 5.2-3 LR 3.1.4 N/A N/A 5.2-3 LR 3.4.6 N/A N/A 5.2-3 PTLR Revision 7 Beaver Valley Unit 2 5.2 - i LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report 5.2 Reactor Coolant System (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,

2. LCO 3.4.6 RCS Loops - MODE 4,

3. LCO 3.4.7 RCS Loops - MODE 5, Loops Filled,

4. LCO 3.4.10 Pressurizer Safety Valves,

5. LCO 3.4.12 Overpressure Protection System (OPPS),

6. LCO 3.5.2 ECCS - Operating,

7. LR 3.1.2 Boration Flow Paths - Operating,

8. LR 3.1.4 Charging Pump - Operating, and

9. LR 3.4.6 Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge 5.2.1 Operating Limits The PTLR limits for Beaver Valley Power Station (BVPS) Unit 2 were developed using a methodology specified in the Technical Specifications. The methodology listed 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 XI, Division 1, and b) Use of methodology of the 1996 version of ASME Section XI, Appendix G, Fracture Toughness Criteria for Protection Against Failure.

5.2.1.1 RCS Pressure and Temperature (P/T) Limits (LCO 3.4.3)

The RCS temperature rate-of-change limits defined in Reference 14 are:

a. A maximum heatup of 60°F in any one hour period.

b. A maximum cooldown of 100°F in any one hour period, and PTLR Revision 7 Beaver Valley Unit 2 5.2 - 1 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report

c. 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 P/T 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 margins for instrument error. The criticality limit curve specifies pressure-temperature limits for core operation to provide additional margin during actual power production as specified in 10 CFR 50, Appendix G. The heatup and cooldown curves also include the effect of the reactor vessel flange.

The P/T limits for core operation (except for low power physics testing) are that the reactor vessel must be at a temperature equal to or higher than the minimum temperature required for the inservice hydrostatic test, and at least 40°F higher than 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. The limiting component is the steam generator channel head to tubesheet region.

This figure provides the ASME III, Appendix G limiting curve which 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 expected operating range for an isolated loop and Code Case 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 resulting P/T combination 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 current BVPS-2 P/T limits continues to be the intermediate shell plate B9004-1 at 30 EFPY.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report 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 value at 30 EFPY is 3.03 x 1019 n/cm2 (E > 1.0 MeV). This value was calculated by interpolating the fluence at the 0° azimuthal position for BVPS-2 from the end of Cycle 15 to the fluence value at the future projection out to 32 EFPY. The fluence of 3.39 x 1019 n/cm2 (E > 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 1019 n/cm2 (E > 1.0 MeV).

5.2.1.2 Overpressure Protection System (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 limits in 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.

5.2.1.3 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 XI, 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 237oF.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report The calculated enable temperature is based on either a RCS temperature of less than 200F or materials concerns (reactor vessel metal temperature less than RTNDT + 50F), 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 conservative than 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 requires the 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 restrictions contained 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 14 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 to 30 EFPY. As a result, Tables 5.2-3 and 5.2-4 and Figure 5.2-8 remain valid for Capsule X up to 30 EFPY.

From a plant operations viewpoint the terms armed and enabled are synonymous 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 in the control room and open the OPPS PORVs.

5.2.1.4 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 tension applied to any stud, and with the RCS vented to atmosphere.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report 5.2.2 Reactor Vessel Material Surveillance Program The 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 results of 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 acceptance standards utilize the reference nil-ductility temperature, RTNDT, which is determined in accordance with ASME,Section III, NB-2331. The empirical relationship between RTNDT and the fracture toughness of the reactor vessel steel is developed in accordance with Appendix G, Protection Against Non-Ductile Failure, to Section XI 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 the calculated vessel fluence values when performing future capsule surveillance evaluations for BVPS Unit 2. This commitment is a condition of License Amendment 138 and will remain in effect until the NRC staff approves an alternate methodology to perform these evaluations. Best-estimate values generated using the FERRET Code may be provided for information only.

5.2.3 Supplemental Data Tables The following tables provide supplemental information on reactor vessel material properties and are provided to be consistent with Generic Letter 96-03. Some of the 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.

Table 5.2-6, taken from Table 2-1 of Reference 14, provides the reactor vessel beltline material property table.

Table 5.2-7, taken from Table 4-2 of Reference 13, provides the reactor vessel extended beltline material property table.

Table 5.2-8, taken from Tables 4-7 and 4-8 of Reference 14, provides a summary of the Adjusted Reference Temperature (ARTs) for 30 EFPY.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report Table 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 RTPTS values for the Beltline Region Materials at 54 EFPY.

Table 5.2-11, taken from Table 6-4 of Reference 13, provides RTPTS 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.

5.2.4 References

1. WCAP-14040-A, Revision 4, Methodology Used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves, J. D. Andrachek, et al., May 2004.

2. (Deleted)

3. (Deleted)

4. WCAP-9615, Revision 1, Duquesne Light Company, Beaver Valley Unit No. 2 Reactor Vessel Radiation Surveillance Program, P. A. Peter, June 1995.

5. WCAP-15676, Evaluation of Pressurized Thermal Shock for Beaver Valley Unit 2, J. H. Ledger, August 2001.

6. 10 CFR Part 50, Appendix G, Fracture Toughness Requirements, Federal Register, Volume 60, No. 243, December 19, 1995.

7. 10 CFR 50.61, Fracture Toughness Requirements for Protection Against Pressurized Thermal Shock Events, May 15, 1991. (PTS Rule)

8. Regulatory Guide 1.99, Rev. 2, Radiation Embrittlement of Reactor Vessel Materials, U.S. Nuclear Regulatory Commission, May 1988.

9. FENOC Calculation No. 10080-SP-2RCS-006, Revision 4, Addendum 1, BV-2 LTOPS Setpoint Evaluation Capsule W for 22 EFPY.

10. FirstEnergy Nuclear Operating Company letter L-01-157, "Supplement to License Amendment Requests Nos. 295 and 167," dated December 21, 2001.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report

11. (Deleted)

12. WCAP-16527, Revision 0, "Analysis of Capsule X from FirstEnergy Nuclear Operating Company Beaver Valley Unit 2 Reactor Vessel Radiation Surveillance Program," B. N. Burgos, J. Conermann, S. L. Anderson, March 2006.

13. WCAP-16527, Supplement 1, Revision 1, "Analysis of Capsule X from FirstEnergy Nuclear Operating Company Beaver Valley Unit 2 Reactor Vessel Radiation Surveillance Program," A. E. Freed, September 2011.

14. WCAP-16528, Revision 1, "Beaver Valley Unit 2 Heatup and Cooldown Limit Curves for Normal Operation," June 2008.

15. Westinghouse Letter FENOC-07-92, dated June 8, 2007, LTOPS Setpoint Evaluation for Beaver Valley Unit 2 Capsule X at 22 and 30 EFPY.

16. Westinghouse Letter MCOE-LTR-13-19, Revision 0, dated March 6, 2013, Acceptable Initial RTNDT Values for the Beaver Valley Unit 2 Reactor Vessel Inlet Nozzle Materials.

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 7 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: INTERMEDIATE SHELL PLATE B9004-1 1/4T, 143oF LIMITING ART VALUES AT 30 EFPY:

3/4T, 132oF CURVES APPLICABLE FOR HEATUP RATES UP TO 60oF/HR FOR THE SERVICE PERIOD UP TO 30 EFPY.

2500 Leak Test Limit 2250 2000 Unacceptable Operation Acceptable Operation 1750 INDICATED PRESSURE (PSIG)

Heatup rate 1500 to 60°F / Hr.

Criticality Limit for 60°F/Hr 1250 1000 750 Criticality Limit based on inservice 500 hydrostatic test temperatue (199°F) for Boltup the service period up to 30 EFPY Temperature 250 0

0 50 100 150 200 250 300 350 400 450 500 INDICATED TEMPERATURE (°F)

Figure 5.2-1 (Page 1 of 1)

Reactor Coolant System Heatup Limitations Applicable for the First 30 EFPY (LCO 3.4.3)

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 8 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: INTERMEDIATE SHELL PLATE B9004-1 1/4T, 143oF LIMITING ART VALUES AT 30 EFPY:

3/4T, 132oF CURVE APPLICABLE FOR COOLDOWN RATES UP TO 0oF/HR FOR THE SERVICE PERIOD UP TO 30 EFPY.

2500 2250 2000 Unacceptable Operation Acceptable Operation 1750 INDICATED PRESSURE (PSIG) 1500 Cooldown Rate 0°F/Hr 1250 1000 750 500 Boltup Temperature 250 0

0 50 100 150 200 250 300 350 400 450 500 INDICATED TEMPERATURE (°F)

Figure 5.2-2 (Page 1 of 1)

Reactor Coolant System Cooldown (steady state - 0oF/Hr.)

Limitations Applicable for the First 30 EFPY (LCO 3.4.3)

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 9 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: INTERMEDIATE SHELL PLATE B9004-1 1/4T, 143oF LIMITING ART VALUES AT 30 EFPY:

3/4T, 132oF CURVE APPLICABLE FOR COOLDOWN RATES UP TO 20°F/HR FOR THE SERVICE PERIOD UP TO 30 EFPY.

2500 2250 2000 Unacceptable Operation Acceptable Operation 1750 INDICATED PRESSURE (PSIG) 1500 Cooldown Rate 20°F/Hr 1250 1000 750 500 Boltup Temperature 250 0

0 50 100 150 200 250 300 350 400 450 500 INDICATED 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)

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 10 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: INTERMEDIATE SHELL PLATE B9004-1 1/4T, 143oF LIMITING ART VALUES AT 30 EFPY:

3/4T, 132oF CURVE APPLICABLE FOR COOLDOWN RATES UP TO 40°F/HR FOR THE SERVICE PERIOD UP TO 30 EFPY.

2500 2250 2000 Unacceptable Operation Acceptable Operation 1750 INDICATED PRESSURE (PSIG) 1500 Cooldown Rate 40°F/Hr 1250 1000 750 500 Boltup Temperature 250 0

0 50 100 150 200 250 300 350 400 450 500 INDICATED TEMPERATURE (°F)

Figure 5.2-4 (Page 1 of 1)

Reactor Coolant System Cooldown (up to 40oF/Hr.)

Limitations Applicable for the First 30 EFPY (LCO 3.4.3)

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 11 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: INTERMEDIATE SHELL PLATE B9004-1 1/4T, 143oF LIMITING ART VALUES AT 30 EFPY:

3/4T, 132oF CURVE APPLICABLE FOR COOLDOWN RATES UP TO 60°F/HR FOR THE SERVICE PERIOD UP TO 30 EFPY.

2500 2250 2000 Unacceptable Operation Acceptable Operation 1750 INDICATED PRESSURE (PSIG) 1500 Cooldown Rate 60°F/Hr 1250 1000 750 500 Boltup Temperature 250 0

0 50 100 150 200 250 300 350 400 450 500 INDICATED TEMPERATURE (°F)

Figure 5.2-5 (Page 1 of 1)

Reactor Coolant System Cooldown (up to 60oF/Hr.)

Limitations Applicable for the First 30 EFPY (LCO 3.4.3)

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 12 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: INTERMEDIATE SHELL PLATE B9004-1 1/4T, 143oF LIMITING ART VALUES AT 30 EFPY:

3/4T, 132oF CURVE APPLICABLE FOR COOLDOWN RATES UP TO 100°F/HR FOR THE SERVICE PERIOD UP TO 30 EFPY.

2500 2250 2000 Unacceptable Operation Acceptable Operation 1750 INDICATED PRESSURE (PSIG) 1500 Cooldown Rate 100°F/Hr 1250 1000 750 500 Boltup Temperature 250 0

0 50 100 150 200 250 300 350 400 450 500 INDICATED TEMPERATURE (°F)

Figure 5.2-6 (Page 1 of 1)

Reactor Coolant System Cooldown (up to 100oF/Hr.)

Limitations Applicable for the First 30 EFPY (LCO 3.4.3)

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 13 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Figure 5.2-7 (Page 1 of 1)

Isolated Loop Pressure - Temperature Limit Curve (LCO 3.4.3)

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 14 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 See Table 5.2-4 for RCP restrictions.

Figure 5.2-8 (Page 1 of 1)

Maximum Allowable Nominal PORV Setpoint for the Overpressure Protection System (LCO 3.4.12)

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 15 LRM Revision 79

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) 60F/HR HEATUP 60F/HR CRITICALITY LEAK TEST LIMIT Temp. Press. Temp. Press. Temp. Press.

(F) (psig) (F) (psig) (F) (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 95 621 199 621 100 621 199 621 105 621 199 777 110 621 199 793 115 621 199 813 120 621 199 835 120 621 199 861 120 777 199 889 125 793 199 921 130 813 199 957 135 835 200 996 140 861 205 1040 145 889 210 1089 150 921 215 1143 155 957 220 1203 160 996 225 1269 165 1040 230 1342 170 1089 235 1423 175 1143 240 1512 180 1203 245 1611 185 1269 250 1719 190 1342 255 1840 195 1423 260 1972 200 1512 265 2118 205 1611 270 2280 210 1719 275 2458 215 1840 220 1972 225 2118 230 2280 235 2458 PTLR Revision 7 Beaver Valley Unit 2 5.2 - 16 LRM 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) 0F/HR 20F/HR 40F/HR 60F/HR 100F/HR Temp. Press. Press. Press. Press. Press.

(F) (psig) (psig) (psig) (psig) (psig) 60 0 0 0 0 0 60 621 621 621 602 525 65 621 621 621 612 536 70 621 621 621 621 548 75 621 621 621 621 562 80 621 621 621 621 578 85 621 621 621 621 595 90 621 621 621 621 614 95 621 621 621 621 621 100 621 621 621 621 621 105 621 621 621 621 621 110 621 621 621 621 621 115 621 621 621 621 621 120 621 621 621 621 621 120 621 621 621 621 621 120 892 867 844 822 783 125 918 896 875 855 823 130 947 927 909 893 867 135 980 962 947 934 917 140 1016 1001 989 980 971 145 1055 1044 1036 1031 1031 150 1099 1092 1087 1087 1087 155 1147 1144 1144 1144 1144 160 1201 1201 1201 1201 1201 165 1260 1260 1260 1260 1260 170 1325 1325 1325 1325 1325 175 1397 1397 1397 1397 1397 180 1477 1477 1477 1477 1477 185 1565 1565 1565 1565 1565 190 1662 1662 1662 1662 1662 195 1770 1770 1770 1770 1770 200 1888 1888 1888 1888 1888 205 2020 2020 2020 2020 2020 210 2165 2165 2165 2165 2165 215 2325 2325 2325 2325 2325 PTLR Revision 7 Beaver Valley Unit 2 5.2 - 17 LRM Revision 79

Licensing Requirements Manual Pressure 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 240F PORV Setpoint Figure 5.2-8 PTLR Revision 7 Beaver Valley Unit 2 5.2 - 18 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-4 (Page 1 of 1)

Reactor Coolant Pump Restrictions TRCS Running RCPs 137oF 0-2 137oF 3 PTLR Revision 7 Beaver Valley Unit 2 5.2 - 19 LRM Revision 79

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 Material Capsule Capsule f(a) FF(b) RTNDT(c) FF*RTNDT FF2 U 0.615 0.864 24.0 20.73 0.746 Intermediate Shell Plate V 2.64 1.260 56.0 70.54 1.587 B9004-2(d) W 3.61 1.334 71.0 94.68 1.778 (Longitudinal)

X 5.63 1.425 98.0 139.65 2.031 U 0.615 0.864 17.7 15.29 0.746 Intermediate Shell Plate V 2.64 1.260 46.1 58.07 1.587 B9004-2(d) W 3.61 1.334 63.4 84.55 1.778 (Transverse)

X 5.63 1.425 104.1 148.34 2.031 SUM: 631.87 12.284 2

CF = (FF

RTNDT) (FF ) = (631.87) (12.284) = 51.4F Beaver Valley U 0.615 0.864 4.1 3.54 0.746 Unit 2 V 2.64 1.260 25.7 32.37 1.587 Surveillance Weld Metal(e) W 3.61 1.334 6.0 8.00 1.778 (Heat #83642) X 5.63 1.425 22.9 32.63 2.031 SUM: 76.55 6.142 2

CF = (FF

RTNDT) (FF ) = (76.55) (6.142)= 12.5F Notes:

(a) f = calculated surveillance capsule neutron fluence (x 1019 n/cm2, E > 1.0 MeV). The surveillance capsule fluence results are contained in Table 8-1 of Reference 13.

(b) FF = fluence factor = f (0.28 - 0.1

log f).

(c) RTNDT values are the measured 30 ft-lb shift values. The BVPS-2 RTNDT values for the surveillance weld data were not adjusted since the ratio was 0.91; therefore, a conservative value of 1.00 was used.

(d) The surveillance plate data is deemed non-credible, per Appendix A of Reference 13.

(e) The surveillance weld data is deemed credible, per Appendix A of Reference 13.

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 20 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-6 (Page 1 of 1)

Reactor Vessel Beltline Material Properties Cu Ni Initial RTNDT Material (wt%) (wt%) (F)(a)

Closure Head Flange B9002-1 0.06(b) 0.74 -10 Vessel Flange B9001-1 0.06(b) 0.73 0 Intermediate Shell Plate B9004-1 0.065 0.55 60 Intermediate Shell Plate B9004-2 0.06 0.57 40 Lower Shell Plate B9005-1 0.08 0.58 28 Lower Shell Plate B9005-2 0.07 0.57 33 Intermediate to Lower Shell Weld 101-171 (Heat 83642) 0.046 0.086 -30 Intermediate Longitudinal Weld 101-124 A & B (Heat 83642) 0.046 0.086 -30 Lower Longitudinal Weld 101-142 A & B (Heat 83642) 0.046 0.086 -30 Plate Surveillance Material B9004-2 0.06 0.57 40 Surveillance Weld (Heat 83642) 0.065 0.065 -30(c)

Notes:

(a) The initial RTNDT values for all of the beltline materials are based on measured data.

(b) According to the BVPS-2 reactor vessel CMTRs and MISC-PENG-ER-021, the material for the closure head flange (B9002-1) and vessel flange (B9001-1) forgings are ASTM A508 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 A508 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 (B9002-1) and the vessel flange (B9001-1) was 0.06%.

(c) The initial RTNDT value is determined in accordance with the requirements of Subparagraph NB-2331 of Section III of the ASME B&PV Code, as specified by Paragraph II - D of 10 CFR Part 50, Appendix G. These fracture toughness requirements are also summarized in Branch Technical Position MTEB Section II.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 TNDT value of

-30°F defined on page 3-14 of WCAP-9615, the initial RTNDT value is concluded to be equal to TNDT (i.e., -30.0°F).

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 21 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-7 (Page 1 of 1)

Reactor Vessel Extended Beltline Material Properties (a)

Initial Material Material Wt % Wt%

Heat Number RTNDT Description ID Cu Ni

(°F)(b)

B9003-1 A9406-1 0.13 0.60 50 Upper Shell B9003-2 B4431-2 0.12 0.60 60 B9003-3 A9406-2 0.13 0.60 50 51912 (3490) 0.156 0.059 -50 51912 (3536) 0.156 0.059 -70 101-122A Upper Shell EAIB 0.02 0.98 10 (Gen) 101-122B Longitudinal Welds IAGA 0.03 0.98 -30 101-122C BOHB 0.05 1.00 10 (Gen)

BAOED 0.02 1.00 -50 4P5174 (1122) 0.09 1.00 -50 Upper Shell to 51922 (3489) 0.05 1.00 -56 (Gen)

Intermediate Shell 103-121 AAGC 0.03 0.98 -70 Girth Weld KOIB 0.03 0.97 -60 B9011-1 2V2436-01-002 0.11 0.85 60(c)

Inlet Nozzles B9011-2 2V2437-02-001 0.13 0.88 60(c) (Gen)

B9011-3 2V2445-02-003 0.13 0.84 70(c) 4P5174 (1122) 0.09 1.00 -50 LOHB 0.03 1.03 -60 HABJC 0.02 1.02 -70 BABBD 0.02 1.04 -70 105-121A FABGC 0.03 1.02 -80 Inlet Nozzle Welds 105-121B EOBC 0.02 0.96 -60 105-121C FAAFC 0.07 1.04 -60 CCJC 0.02 0.99 -60 FAGB 0.02 1.06 -30 BAOED 0.02 1.00 -50 B9012-1 AV8080-2E9558 0.13 0.72 -10 Outlet Nozzles B9012-2 AV8120-2E9560 0.13 0.74 -10 B9012-3 AV8097-2E9559 0.13 0.70 -10 BABBD 0.02 1.04 -70 FAAFC 0.07 1.04 -60 107-121A HAAEC 0.03 1.03 -80 Outlet Nozzle Welds 107-121B HABJC 0.02 1.02 -70 107-121C HAGB 0.02 1.04 -40 GACJC 0.03 1.00 -80 JAHB 0.03 0.97 -40 Notes:

(a) Materials information taken from Reference 13 (b) Based on Reference 13, the generic Initial RTNDT values were determined in accordance with NUREG-0800 and the 10 CFR 50.61.

(c) As described in Reference 16, the reactor vessel initial RTNDT values for the inlet nozzles are conservatively assigned values. The actual initial RTNDT values for the reactor vessel inlet nozzles are located in BVPS-2 UFSAR Table 5.3-1.

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 22 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-8 (Page 1 of 1)

Summary of Adjusted Reference Temperature (ARTs) for 30 EFPY(a)

Method Used To Material Description 30 EFPY ART Calculate the CF(b) 1/4T ART (°F) 3/4T ART (°F)

Intermediate Shell Plate B9004-1 Position 1.1 143 132 Position 1.1 119 109 Intermediate Shell Plate B9004-2 Position 2.1 119 106 Lower Shell Plate B9005-1 Position 1.1 123 110 Lower Shell Plate B9005-2 Position 1.1 120 109 Position 1.1 53 35 Vessel Beltline Welds(c)

Position 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 7 Beaver Valley Unit 2 5.2 - 23 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-9 (Page 1 of 1)

Calculation of Adjusted Reference Temperatures (ARTs) for 30 EFPY(a)

PARAMETER VALUES Operating Time 30 EFPY Material - Intermediate Shell Plate B9004-1 B9004-1 Location 1/4T 3/4T Chemistry Factor, CF (°F) 40.5 40.5 Fluence, (f), (1019 n/cm2)(b) 2.113 0.8215 Fluence Factor, FF 1.203 0.9448 RTNDT = CF x FF(°F) 48.74 38.27 Intitial RTNDT, I(°F) 60 60 Margin, 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) Fluence (f), is based upon fsurf (1019 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 7 Beaver Valley Unit 2 5.2 - 24 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-10 (Page 1 of 1)

RTPTS Calculation for Beltline Region Materials at Life Extension (54 EFPY)(a)

Surface Neutron Fluence Chemistry Initial Material Description Material Heat RTPTS(d) U Margin(e) RTPTS(f)

Fluence Factor, Factor RTNDT(c)

ID Number (F) (F) (F) (F) (F)

(x1019 n/cm2) FF(b) (°F) (°F)

Intermediate Shell B9004-1 --- 5.18 1.4092 40.5 60 57.1 0 17 34 151.1 Plate Intermediate Shell B9004-2 --- 5.18 1.4092 37 40 52.1 0 17 34 126.1 Plate Using non-credible surveillance data(g) 5.18 1.4092 51.4 40 72.4 0 17 34 146.4 Lower Shell Plate B9005-1 --- 5.21 1.4104 51 28 71.9 0 17 34 133.9 Lower Shell Plate B9005-2 --- 5.21 1.4104 44 33 62.1 0 17 34 129.1 Intermediate to Lower 101-171 83642 5.18 1.4092 34.4 -30 48.5 0 24.2 48.5 67.0 Shell Girth Weld Using credible surveillance data(g) 5.18 1.4092 12.5 -30 17.6 0 8.8 17.6 5.2 Intermediate Shell 101-124 83642 1.76 1.1554 34.4 -30 39.7 0 19.9 39.7 49.5 Longitudinal Welds A&B Using credible surveillance data(g) 1.76 1.1554 12.5 -30 14.4 0 7.2 14.4 -1.1 Lower Shell 101-142 83642 1.77 1.1569 34.4 -30 39.8 0 19.9 39.8 49.6 Longitudinal Welds A&B Using credible surveillance data(g) 1.77 1.1569 12.5 -30 14.5 0 7.2 14.5 -1.1 Notes:

(a) Data obtained from Table 6-3 of Reference 13.

(b) FF = fluence factor = f (0.28 - 0.1 log (f)).

(c) Initial RTNDT values are measured values.

(d) RTPTS = CF

FF.

(e) M = 2 *(U2 + 2)1/2.

(f) RTPTS = Initial RTNDT + RTPTS + Margin.

(g) The BVPS-2 surveillance weld metal is the same weld heat as the BVPS-2 beltline welds (heat 83642). The BVPS-2 surveillance weld data is credible; therefore, the reduced term of 14°F was utilized for BVPS-2 weld heat 83642. The BVPS-2 surveillance plate material is representative of the BVPS-2 intermediate shell plate B9004-2. The surveillance plate material is non-credible; therefore, the higher term of 17°F was utilized for BVPS-2 plate B9004-2. The credibility evaluation conclusions are contained in Appendix A of Reference 13.

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 25 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-11 (Page 1 of 3)

RTPTS Calculation for Extended Beltline Region Materials at Life Extension (54 EFPY)(a)

Surface Neutron Fluence Chemistry Initial Material Description Heat Number RTPTS(e) U Margin(f) RTPTS(g)

Material ID Fluence Factor, Factor RTNDT(c)

(Lot Number) (F) (F) (F) (F) (F)

(x1019 FF(b) (°F) (°F) n/cm2)

B9003-1 A9406-1 0.515 0.8147 91.0 50 74.1 0 17 34 158.1 Upper Shell Plates B9003-2 B4431-2 0.515 0.8147 83.0 60 67.6 0 17 34 161.6 B9003-3 A9406-2 0.515 0.8147 91.0 50 74.1 0 17 34 158.1 51912 (3490) 0.515 0.8147 73.71 -50 60.1 0 28 56 66.1 51912 (3536) 0.515 0.8147 73.71 -70 60.1 0 28 56 46.1 101-122A Upper Shell EAIB 0.515 0.8147 27.0 10(d) 22.0 17 11.0 40.5 72.5 101-122B Longitudinal Welds IAGA 0.515 0.8147 41.0 -30 33.4 0 16.7 33.4 36.8 101-122C BOHB 0.515 0.8147 68.0 10(d) 55.4 17 27.7 65.0 130.4 BAOED 0.515 0.8147 27.0 -50 22.0 0 11.0 22.0 -6.0 4P5174 0.515 0.8147 122.0 -50 99.4 0 28 56.0 105.4 Upper to Intermediate 51922 0.515 0.8147 68.0 -56(d) 55.4 17 27.7 65.0 64.4 103-121 Shell Girth Weld AAGC 0.515 0.8147 41.0 -70 33.4 0 16.7 33.4 -3.2 KOIB 0.515 0.8147 41.0 -60 33.4 0 16.7 33.4 6.8 B9011-1 2V2436-01-002 0.0298 0.2188 77.0 60(h) 16.8 0 8.4 16.8 93.7 Inlet Nozzles B9011-2 2V2437-02-001 0.0298 0.2188 96.0 60(d)(h) 21.0 17 10.5 40.0 121.0 B9011-3 2V2445-02-003 0.0298 0.2188 96.0 70(h) 21.0 0 10.5 21.0 112.0 PTLR Revision 7 Beaver Valley Unit 2 5.2 - 26 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-11 (Page 2 of 3)

RTPTS Calculation for Extended Beltline Region Materials at Life Extension (54 EFPY)(a)

Surface Neutron Fluence Chemistry Initial Material Heat Number RTPTS(e) U Margin(f) RTPTS(g)

Description Material ID Fluence Factor, Factor RTNDT(c)

(Lot Number) (F) (F) (F) (F) (F)

(x1019 FF(b) (°F) (°F) n/cm2) 4P5174 0.0298 0.2188 122.0 -50 26.7 0 13.3 26.7 3.4 LOHB 0.0298 0.2188 41.0 -60 9.0 0 4.5 9.0 -42.1 HABJC 0.0298 0.2188 27.0 -70 5.9 0 3.0 5.9 -58.2 BABBD 0.0298 0.2188 27.0 -70 5.9 0 3.0 5.9 -58.2 105-121A Inlet Nozzle FABGC 0.0298 0.2188 41.0 -80 9.0 0 4.5 9.0 -62.1 105-121B Welds EOBC 0.0298 0.2188 27.0 -60 5.9 0 3.0 5.9 -48.2 105-121C FAAFC 0.0298 0.2188 95.0 -60 20.8 0 10.4 20.8 -18.4 CCJC 0.0298 0.2188 27.0 -60 5.9 0 3.0 5.9 -48.2 FAGB 0.0298 0.2188 27.0 -30 5.9 0 3.0 5.9 -18.2 BAOED 0.0298 0.2188 27.0 -50 5.9 0 3.0 5.9 -38.2 B9012-1 AV8080-2E9558 0.0151 0.1440 94.0 -10 13.5 0 6.8 13.5 17.1 Outlet Nozzles B9012-2 AV8120-2E9560 0.0151 0.1440 94.5 -10 13.6 0 6.8 13.6 17.2 B9012-3 AV8097-2E9559 0.0151 0.1440 93.5 -10 13.5 0 6.7 13.5 16.9 BABBD 0.0151 0.1440 27.0 -70 3.9 0 1.9 3.9 -62.2 FAAFC 0.0151 0.1440 95.0 -60 13.7 0 6.8 13.7 -32.6 107-121A Outlet Nozzle HAAEC 0.0151 0.1440 41.0 -80 5.9 0 3.0 5.9 -68.2 107-121B Welds HABJC 0.0151 0.1440 27.0 -70 3.9 0 1.9 3.9 -62.2 107-121C HAGB 0.0151 0.1440 27.0 -40 3.9 0 1.9 3.9 -32.2 GACJC 0.0151 0.1440 41.0 -80 5.9 0 3.0 5.9 -68.2 JAHB 0.0151 0.1440 41.0 -40 5.9 0 3.0 5.9 -28.2 PTLR Revision 7 Beaver Valley Unit 2 5.2 - 27 LRM Revision 79

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-11 (Page 3 of 3)

RTPTS Calculation for Extended Beltline Region Materials at Life Extension (54 EFPY)(a)

Notes:

(a) Data obtained from Table 6-4 of Reference 13.

(b) FF = fluence factor = f (0.28 - 0.1 log (f)).

(c) Initial RTNDT values are measured values, unless otherwise noted.

(d) Initial RTNDT values are generic.

(e) RTPTS = CF

FF.

(f) M = 2 *(U2 + 2)1/2.

(g) RTPTS = Initial RTNDT + RTPTS + Margin.

(h) As described in Reference 16, the reactor vessel initial RTNDT values for the inlet nozzles are conservatively assigned values. The actual initial RTNDT values for the reactor vessel inlet nozzles are located in BVPS-2 UFSAR Table 5.3-1.

PTLR Revision 7 Beaver Valley Unit 2 5.2 - 28 LRM Revision 79

Licensing Requirements Manual Procedure Review and Approval 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Procedure Review and Approval 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 Independent Qualified Reviewer (IQR), 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 approval of 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. If a procedure or revision thereto requires a 10 CFR 50.59 evaluation, the Responsible Discipline Manager or his designee shall ensure that the procedure, with the associated 10 CFR 50.59 evaluation, is forwarded to the Plant Operations Review Committee for review. Pursuant to 10 CFR 50.59, NRC approval of items involving unreviewed safety questions shall be obtained prior to approval of the procedure or revision thereto for implementation. Final procedure approval shall be by the Responsible Discipline Manager or his designee, as specified in administrative procedures.

IQRs shall meet the applicable qualifications as delineated in plant procedures.

Temporary changes to procedures will be approved as described in the QAPM, Regulatory Guide 1.33 conformance description.

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Licensing Requirements Manual Record Retention 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Record Retention The 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.

2. Records and logs of principal maintenance activities, inspections, repair and replacement of principal items of equipment related to nuclear safety.

3. All reportable events of the type described in 10 CFR 50.73.

4. 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.

8. 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.

2. Records of new irradiated fuel inventory, fuel transfers and assembly burnup histories.

3. Records of facility radiation and contamination surveys.

4. Records of radiation exposure for all individuals entering radiation control areas.

5. Records of gaseous and liquid radioactive material released to the environs.

6. Records of transient or operational cycles for those facility components designed for a limited number of transients or cycles.

7. Records of training and qualification for current numbers of the plant staff.

8. Records of in-service inspections performed pursuant to the Technical Specifications.

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Licensing Requirements Manual Record Retention 5.4 5.4 Record Retention

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 the date at which the service life commences and associated installation and maintenance 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.

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LICENSING REQUIREMENTS MANUAL BASES TABLE OF CONTENTS Page No.

B 3.0 LICENSING REQUIREMENT (LR) APPLICABILITY ........................................ B 3.0-1 B 3.0 LICENSING REQUIREMENT SURVEILLANCE (LRS) APPLICABILITY ......... B 3.0-5 B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.1 - B 3.1.8 Boration Systems ............................................................................. B 3.1.1-1 B 3.1.9 Rod Position Indication - Shutdown ............................................................ B 3.1.9-1 B 3.1.10 Boron Dilution.............................................................................................. B 3.1.10-1 B 3.1.11 Rod Position Indication System - Shutdown Test Exception....................... B 3.1.11-1 B 3.3 INSTRUMENTATION B 3.3.3 Meteorological Monitoring Instrumentation ................................................. B 3.3.3-1 B 3.3.4 Axial Flux Difference (AFD) Monitor Alarm ................................................. B 3.3.4-1 B 3.3.5 Quadrant Power Tilt Ratio (QPTR) Monitor Alarm ...................................... B 3.3.5-1 B 3.3.6 Seismic Monitoring Instrumentation ............................................................ B 3.3.6-1 B 3.3.7 Movable Incore 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 3.3.9-1 B 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 3.3.13-1 B 3.3.14 Control Room Isolation 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 Instrumentation ........................................................... B 3.3.16-1 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.1 Loop Isolation Valves - Shutdown ............................................................... B 3.4.1-1 B 3.4.2 Chemistry .................................................................................................... B 3.4.2-1 B 3.4.3 Pressurizer .................................................................................................. B 3.4.3-1 B 3.4.4 DELETED.................................................................................................... B 3.4.4-1 B 3.4.5 Reactor Coolant System Head Vents.......................................................... B 3.4.5-1 B 3.4.6 Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge....... B 3.4.6-1 B 3.6 CONTAINMENT B 3.6.1 Containment Isolation Valves...................................................................... B 3.6.1-1 B 3.6.2 Containment Sump...................................................................................... B 3.6.2-1 B 3.7 PLANT SYSTEMS B 3.7.1 Steam Generator 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 3.7.3-1 B 3.7.4 Snubbers ..................................................................................................... B 3.7.4-1 B 3.7.5 Standby Service Water System (SWE) ....................................................... B 3.7.5-1 B 3.7.6 Explosive Gas Mixture................................................................................. B 3.7.6-1 B 3.7.7 Supplemental Leak Collection and Release System (SLCRS) ................... B 3.7.7-1 Beaver Valley Unit 2 B-i LRM Revision 67

LICENSING REQUIREMENTS MANUAL BASES TABLE OF CONTENTS Page No.

B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.1 125V D.C. Battery Banks Maintenance Requirements ............................... B 3.8.1-1 B 3.8.2 Emergency DG 2000 Hour Rating Limit ...................................................... B 3.8.2-1 B 3.8.3 Main Fuel Oil Storage Tank Maintenance Requirements............................ B 3.8.3-1 B 3.9 REFUELING OPERATIONS B 3.9.1 Crane Travel - Spent Fuel Storage Pool Building ....................................... B 3.9.1-1 B 3.9.2 Manipulator Crane....................................................................................... B 3.9.2-1 B 3.9.3 Decay Time ................................................................................................. B 3.9.3-1 Beaver Valley Unit 2 B-ii LRM Revision 67

Licensing Requirements Manual LR Applicability B 3.0 B 3.0 LICENSING REQUIREMENT (LR) APPLICABILITY BASES LRs LR 3.0.1 through LR 3.0.3 establish the general requirements applicable to all LRs and apply at all times, unless otherwise stated.

LR 3.0.1 LR 3.0.1 establishes the Applicability statement within each individual LR as the requirement for when the LR is required to be met (i.e., when the unit is in the MODES or other specified conditions of the Applicability statement 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 each Required Action for an ACTIONS Condition is applicable from the point in time that an ACTIONS Condition is entered. The Required Actions establish those remedial measures that must be taken within specified Completion Times when the requirements of an LR are not met. This Specification establishes that:

a. Completion of the Required Actions within the specified Completion Times constitutes compliance with a Specification and

b. Completion of the Required Actions is not required when an LCO is met within the specified Completion Time, unless otherwise specified.

There are two basic types of Required Actions. The first type of Required Action specifies a time limit in which the LR must be met. This time limit is the Completion Time to restore an inoperable/Nonfunctional system or component to OPERABLE/FUNCTIONAL status or to restore variables to within specified limits. If this type of Required Action is not completed within the specified Completion Time, entry into LR 3.0.3 may be required, or a shutdown may be required to place the unit in a MODE or condition in which the LR is not applicable. (Whether stated as a Required 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 permit continued 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 is no longer applicable, unless otherwise stated in the individual LR.

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Licensing Requirements Manual LR Applicability B 3.0 BASES LR 3.0.2 (continued)

The nature of some Required Actions in some Conditions necessitates that, once the Condition is entered, the Required Actions must be completed 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 when a system or component is removed from service intentionally. The reasons 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 that does not compromise safety. Intentional entry into ACTIONS should not be made for operational convenience. Additionally, if intentional entry into ACTIONS 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 may result in LR 3.0.3 being entered. Individual LRs may specify a time limit for performing an LRS when equipment is removed from service or bypassed for testing. In this case, the Completion Times of the Required Actions are applicable when this time limit expires, if the equipment remains 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 other specified 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 3.0.3 LR 3.0.3 establishes the actions that must be implemented when an LR is not met and:

a. The ACTIONS require that LR 3.0.3 be entered;

b. An associated Required Action and Completion Time is not met and no other Condition applies; or

c. The condition of the unit is not specifically addressed by the associated 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.

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Licensing Requirements Manual LR Applicability B 3.0 BASES 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 prescribed limits as defined by the LR and its ACTIONS. It is not intended to be used as an operational convenience that permits routine voluntary removal of redundant systems or components from service in lieu of other alternatives that would not result in redundant systems or components being inoperable/Nonfunctional.

Upon entering LR 3.0.3, Action must be initiated to immediately communicate the situation to the Shift Manager and document the condition in accordance with the 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 CFR 50.72 and/or 50.73. The safety significance of the condition is required to be evaluated per NOP-OP-1009 Operability Determinations and Functionality Assessments (consistent with the guidance of NRC Regulatory Issue Summary 2005-20 (Revision 1), and as required by Appendix B of 10 CFR 50) and appropriate corrective actions are required to be initiated, within the time frame determined by the Shift Manager that shall not exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months from the time of entry into LR 3.0.3. The time frame for completion of the corrective actions shall be commensurate with the 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 exited if any of the following occurs:

a. The LR is now met,

b. The LR is no longer applicable,

c. A Condition exists for which the Required Actions have now been performed, or

d. ACTIONS exist that do not have expired Completion Times. These Completion 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.

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Licensing Requirements Manual LR Applicability B 3.0 BASES LR 3.0.4 LR 3.0.4 establishes the allowance for restoring equipment to service under administrative controls when it has been removed from service or declared 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 not comply with the applicable ACTIONS) to allow the performance of required testing to demonstrate either:

a. The OPERABILITY/FUNCTIONALITY of the equipment being returned to service; or

b. The OPERABILITY/FUNCTIONALITY of other equipment.

The administrative controls ensure the time the equipment is returned to service in conflict with the requirements of the ACTIONS is limited to the time absolutely necessary to perform the required testing to demonstrate OPERABILITY/FUNCTIONALITY. If the OPERABILITY/

FUNCTIONALITY of the affected equipment can not be demonstrated, the administrative controls will also ensure the equipment/plant 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 on another channel in the other trip system. A similar example of demonstrating the OPERABILITY/FUNCTIONALITY of other equipment is taking an inoperable/Nonfunctional channel or trip system out of the tripped condition to permit the logic to function and indicate the appropriate response during the performance of a surveillance requirement on another channel in the same trip system.

LR 3.0.5 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 containing Instrumentation 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 governed by Technical Specifications.

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Licensing Requirements Manual LR Applicability B 3.0 BASES LR 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 otherwise could not be performed if required to comply with the requirements of the LR. Unless otherwise specified, all the other LR requirements remain unchanged. This will ensure all appropriate requirements of the MODE or other specified condition not directly associated with or required to be changed to perform the special test or operation will remain in effect.

The Applicability 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 Test Exception LR or under the other applicable LR requirements. If it is desired to perform the special operation under the provisions of the Test Exception LR, the requirements of the Test Exception LR shall be followed.

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Licensing Requirements Manual LRS Applicability B 3.0 B 3.0 LICENSING REQUIREMENT SURVEILLANCE (LRS) APPLICABILITY BASES LRSs LRS 3.0.1 through LRS 3.0.3 establish the general requirements applicable to all Specifications and apply at all times, unless otherwise 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 otherwise 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 specified condition 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.g., 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 are OPERABLE/FUNCTIONAL when:

a. The systems or components are known to be inoperable/Nonfunctional, although still meeting the LRSs; or

b. 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 other specified 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 an allowable exception to the requirements of an LR.

Unplanned events may satisfy the requirements (including applicable acceptance criteria) for a given LRS. In this case, the unplanned event may be credited as fulfilling the performance of the LRS. This allowance includes those LRSs whose performance is normally precluded in a given MODE or other specified condition.

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Licensing Requirements Manual LRS Applicability B 3.0 BASES LRS 3.0.1 (continued)

Surveillances, including surveillances invoked by Required Actions, do not have to be performed on inoperable/Nonfunctional equipment because 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 in the 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 satisfactorily completed to the extent possible and the equipment is not otherwise believed to be incapable of performing its function. This will allow operation 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 turbine maintenance during refueling that requires testing at steam pressures of greater than 600 psig. If other appropriate testing is satisfactorily completed, the AFW System can be considered OPERABLE. This allows startup 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 Completion Time that requires the periodic performance of the Required Action on a "once per . . ." interval.

LRS 3.0.2 permits a 25% extension of the interval specified in the Frequency. This extension facilitates Surveillance scheduling and considers plant operating conditions that may not be suitable for conducting the Surveillance (e.g., transient conditions or other ongoing Surveillance or maintenance activities).

The 25% extension does not significantly degrade the reliability that results from performing the Surveillance at its specified Frequency. This is based on the recognition that the most probable result of any particular Surveillance being performed is the verification of conformance with the LRS. The exceptions to LRS 3.0.2 are those Surveillances for which the 25% extension of the interval specified in the Frequency does not apply.

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Licensing Requirements Manual LRS Applicability B 3.0 BASES LRS 3.0.2 (continued)

These exceptions are stated in the individual LRs or LRS. The requirements 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 25% extension also does not apply to the initial portion of a periodic Completion Time that requires performance on a "once per ..." basis. The 25% extension applies to each performance after the initial performance. The initial performance of the Required Action, whether it is a particular Surveillance or some other remedial action, is considered a single action with a single Completion Time. One reason for not allowing the 25% extension to this Completion Time is that such an action usually verifies that no loss of function has occurred by checking the status of redundant or diverse components or accomplishes the function of the inoperable/Nonfunctional equipment in an alternative manner.

The provisions of LRS 3.0.2 are not intended to be used repeatedly merely as an operational convenience to extend Surveillance intervals (other than those consistent with refueling intervals) or periodic Completion Time intervals beyond those specified.

LRS 3.0.3 LRS 3.0.3 establishes the flexibility to defer declaring affected equipment inoperable/Nonfunctional or an affected variable outside the specified limits when a surveillance has not been completed within the specified Frequency. A delay period of up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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 specified Frequency was not met.

This delay period provides adequate time to complete surveillances that have been missed. This delay period permits the completion of a surveillance before complying with Required Actions or other remedial measures 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 perform the surveillance, the safety significance of the delay in completing the required surveillance, and the recognition that the most probable result of any particular surveillance being performed is the verification of conformance with the requirements.

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Licensing Requirements Manual LRS Applicability B 3.0 BASES LRS 3.0.3 (continued)

When a surveillance with a Frequency based not on time intervals, but upon specified unit conditions, operating situations, or requirements of regulations (e.g., prior to being placed into use, or in accordance with 10 CFR 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 interval specified, the missed surveillance should be performed at the first reasonable opportunity.

LRS 3.0.3 provides a time limit for, and allowances for the performance of, 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 be an 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 to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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 surveillance as well as any plant configuration changes required or shutting the plant down to perform the surveillance) and impact on any analysis assumptions, in addition to unit conditions, planning, availability of personnel, and the time required to perform the surveillance. This risk impact should be managed through the program in place to implement 10 CFR 50.65(a)(4) and its implementation guidance, NRC Regulatory Guide 1.182, Assessing and Managing Risk Before Maintenance Activities at Nuclear Power Plants. This Regulatory Guide addresses consideration of temporary and aggregate risk impacts, determination of risk management action thresholds, and risk management action up to and including plant shutdown. The missed surveillance should be treated as an emergent condition as discussed in the Regulatory Guide. The risk evaluation may use quantitative, qualitative, or blended methods. The degree 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. If 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 missed surveillances will be placed in the Corrective Action Program.

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Licensing Requirements Manual LRS Applicability B 3.0 BASES LRS 3.0.3 (continued)

If a surveillance is not completed within the allowed delay period, then the equipment 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. If 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 of the 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.

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Licensing Requirements Manual Boration Systems B 3.1.1 - B 3.1.8 B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.1 - B 3.1.8 Boration Systems BASES 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 functional capability in the event an assumed failure renders one of the flow paths Nonfunctional. Allowable out-of-service periods ensure that minor component 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 Injection pump may be used in lieu of the FUNCTIONAL charging pump with a minimum open RCS vent of 3.14 square inches. This will provide latitude for maintenance and ISI examinations on the charging system for repair or corrective action and will ensure that boration and makeup are available when the charging pumps are out-of-service. An open vent insures that RCS pressure will not exceed the shutoff head of the Low Head Safety Injection pumps.

2SIS-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 required since 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 to verify all charging pumps except the required OPERABLE pump to be inoperable when less than or equal to the enable temperature set forth in the 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 head of the Low Head Safety Injection pumps is below the setpoint of the overpressure protection system.

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Licensing Requirements Manual Boration Systems B 3.1.1 - B 3.1.8 BASES BACKGROUND (continued)

The boration capability of the boric acid storage system is sufficient to provide a SHUTDOWN MARGIN from all operating conditions of 1.77%

k/k after xenon decay and cooldown to 200°F. The maximum boration capability requirements occur at BOL from full power peak xenon conditions and requires 13,390 gallons of 7000 ppm borated water from the boric acid storage tanks.

With the RCS temperature below 350°F, one boron injection flow path is acceptable without single failure consideration on the basis of the stable reactivity condition of the reactor and the additional restrictions prohibiting CORE ALTERATIONS and positive reactivity change in the event the single injection system becomes Nonfunctional.

The boration capability required below 200°F is sufficient to provide a SHUTDOWN MARGIN of 1% k/k after xenon decay and cooldown from 200°F to 140°F. This condition requires either 2315 gallons of 7000 ppm borated water from the boric acid storage tanks or 10,196 gallons of 2400 ppm borated water from the refueling water storage tank.

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Licensing Requirements Manual Rod Position Indication - Shutdown B 3.1.9 B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.9 Rod Position Indication - Shutdown BASES 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 Indication in Modes 1 and 2 are specified in the Technical Specifications. In the shutdown MODES addressed 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.

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Licensing Requirements Manual Boron Dilution B 3.1.10 B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.10 Boron Dilution BASES 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. A flow rate of at least 3000 GPM will circulate an equivalent Reactor Coolant 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.

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Licensing Requirements Manual Rod Position Indication System - Shutdown Test Exception B 3.1.11 B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.11 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 are derived from the induced voltage in the position indicator coils as the rod is dropped. This induced voltage is small compared to the normal voltage and, therefore, cannot be observed if the Position Indication Systems remain FUNCTIONAL.

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Licensing Requirements Manual Meteorological Monitoring Instrumentation B 3.3.3 B 3.3 INSTRUMENTATION B 3.3.3 Meteorological Monitoring Instrumentation BASES BACKGROUND The FUNCTIONALITY of the meteorological instrumentation ensures that sufficient meteorological data is available for estimating potential radiation doses to the public as a result of routine or accidental release of radioactive materials to the atmosphere. This capability is required to evaluate the need for initiating protective measures to protect the health and safety of the public and is consistent with the recommendations of Regulatory Guide 1.23, "Onsite Meteorological Programs."

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Licensing Requirements Manual AFD Monitor Alarm B 3.3.4 B 3.3 INSTRUMENTATION B 3.3.4 Axial Flux Difference (AFD) Monitor Alarm BASES BACKGROUND Surveillance of the AFD verifies that the AFD, as indicated by the Nuclear Instrumentation System (NIS) excore channels, is within its limits. During operation above 50% RATED THERMAL POWER, when the AFD 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 operation outside of the limits.

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Licensing Requirements Manual QPTR Monitor Alarm B 3.3.5 B 3.3 INSTRUMENTATION B 3.3.5 Quadrant Power Tilt Ratio (QPTR) Monitor Alarm BASES BACKGROUND Surveillance of the QPTR verifies that the QPTR, as indicated by the Nuclear Instrumentation System (NIS) excore channels, is within its limits.

During operation above 50% 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 occur quickly (e.g., a dropped rod), there are other indications of abnormality that prompt a verification of core power tilt.

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Licensing Requirements Manual Seismic Monitoring Instrumentation B 3.3.6 B 3.3 INSTRUMENTATION B 3.3.6 Seismic Monitoring Instrumentation BASES 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, "Instrumentation for Earthquakes." Applicable guidance for performance of CHANNEL CHECK, CHANNEL OPERATIONAL TEST and CHANNEL CALIBRATION is provided in ANSI/ANS-2.2-1978.

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.

The channel calibrations for the items listed in Table 3.3.6-2, Section 1 and the associated channel operational test in Section 3 will not be performed in April 2020 (2R21) due to the pandemic. See 10 CFR 50.59 evaluation 20-00442 for justification.

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Licensing Requirements Manual Movable Incore Detectors B 3.3.7 B 3.3 INSTRUMENTATION B 3.3.7 Movable Incore Detectors BASES BACKGROUND The 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 115, dated September 7, 2000.

For the purpose of measuring FQ(Z) or FN H, a full incore flux map is used.

Quarter-core flux maps, as defined in WCAP-8648, June 1976, may be used in re-calibration of the excore neutron flux detection system, and full incore flux maps or symmetric incore thimbles may be used for monitoring the Quadrant Power Tilt Ratio when one Power Range Channel is inoperable.

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Licensing Requirements Manual Leading Edge Flow Meter B 3.3.8 B 3.3 INSTRUMENTATION B 3.3.8 Leading Edge Flow Meter BASES BACKGROUND The Leading Edge Flow Meter (LEFM) is the preferred method of obtaining 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 better than +/-0.6% RTP at full power. This is more accurate than the venturi-based flow instrumentation. However, the accuracy of the LEFM is only valid while the instrument is performing as designed. The on-line verification and self-diagnostic features of the LEFM provides the ability to assure that the instrument is performing as designed.

The Applicability Statement applies when performing calorimetric power measurements during MODE 1 operations at steady-state conditions above 98.6% of RTP. The Operating License limits the maximum steady state power to 100% of RTP when calorimetric heat balance measurements are made daily using the LEFM.

If 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 Instrumentation System (NIS) indication until the next required performance of the daily power calorimetric surveillance is due.

If the LEFM remains Nonfunctional at the time that the next required calorimetric heat balance measurement is due, plant operation may continue at 98.6% 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 hours2.893519e-4 days 0.00694 hours 4.133598e-5 weeks 9.5125e-6 months compared to after 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is considered negligible (or after 31 hours3.587963e-4 days 0.00861 hours 5.125661e-5 weeks 1.17955e-5 months compared to after 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months if Technical 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). If the PCS is unavailable, a manual calculation that accounts for steam generator blowdown is acceptable, and may be performed in lieu of using the PCS.

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Licensing Requirements Manual Leading Edge Flow Meter B 3.3.8 BASES BACKGROUND (continued)

This surveillance is performed every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when power is above 50%.

The NIS excore power range channel indications are renormalized if they are not found to be within 2% of the calorimetric measurement. This 2% requirement for renormalization is distinct from the allowance for calorimetric uncertainty, and these allowances are handled as independent contributions to determine the maximum power assumed in 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 be monitored continuously, it is not required to be consulted again until the required daily calorimetric comparisons of NIS indication are performed.

The surveillance requirement to perform planned maintenance and inspections every 18 months is based upon the manufacturers recommendations, and is consistent with the surveillance intervals specified for similar electronic apparatus.

Additional guidance for determining steady-state THERMAL POWER is taken from NEI POSITION STATEMENT, Guidance to Licensees on Complying with the Licensed Power Limit, dated June 12, 2008

[ML081750537], endorsed by the NRC in Regulatory Issue Summary 2007-21, Revision 1, Adherence to Licensed Power Limits, dated February 9, 2009 [ML082690105], and is described in the BVPS Operating Manual.

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Licensing Requirements Manual Turbine Overspeed Protection B 3.3.9 B 3.3 INSTRUMENTATION B 3.3.9 Turbine Overspeed Protection BASES BACKGROUND This LR is provided to ensure that the turbine overspeed protection instrumentation and the turbine speed control valves are FUNCTIONAL and will protect the turbine from excessive overspeed. Protection from turbine excessive overspeed is required since excessive overspeed of the turbine could generate potentially damaging missiles which could impact and damage safety related components, equipment or structures.

Surveillance test intervals for the turbine speed control valves are assumed in a turbine overspeed calculation discussed in the Beaver Valley Power Station Unit No. 2 Updated Final Safety Analysis Report.

The inspection intervals were also an assumption in the baseline turbine missile generation probability used in the same calculation.

The LRS note allows for entry into the applicability of LR 3.3.9 without LRS 3.3.9.1, 3.3.9.2, 3.3.9.3, and 3.3.9.4 being performed for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 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. The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months delay 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 been satisfactorily completed to the extent possible and the valves are not otherwise believed to be incapable of performing their function.

The governor, throttle, reheat stop and intercept valve inspections are performed on a sampling basis, such that each throttle and governor valve shall be inspected at an interval of no more than eight (8) refueling outages (12 years); while each reheat stop and intercept valve shall be inspected at an interval of no more than twelve (12) refueling outages (18 years).

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Licensing Requirements Manual Fuel Storage Pool Area Radiation Monitor B 3.3.11 B 3.3 INSTRUMENTATION B 3.3.11 Fuel Storage Pool Area Radiation Monitor BASES BACKGROUND The Fuel Storage Pool Area Radiation Monitor functions to assure personnel safety around the fuel storage pool. The FUNCTIONALITY of this 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 70.24, 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.

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Licensing Requirements Manual Explosive Gas Monitoring Instrumentation B 3.3.12 B 3.3 INSTRUMENTATION B 3.3.12 Explosive Gas Monitoring Instrumentation BASES BACKGROUND This 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 64 of Appendix A to 10 CFR Part 50.

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Licensing Requirements Manual Containment Hydrogen Analyzers B 3.3.13 B 3.3 INSTRUMENTATION B 3.3.13 Containment Hydrogen Analyzers BASES 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 longer defines a design-basis LOCA hydrogen release and eliminated the requirements 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-basis accident and were removed from the Technical Specifications by License Amendments 259 (Unit 1) and 142 (Unit 2). However, the hydrogen analyzers are required to diagnose the course of a BDBA and implement severe accident management strategies for hydrogen control.

Maintaining requirements within the LRM for a hydrogen monitoring system capable of diagnosing BDBAs (as described in BVPS Letter to the NRC L-04-012, dated January 28, 2004) is an NRC commitment.

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Licensing Requirements Manual Control Room Isolation Radiation Monitors B 3.3.14 B 3.3 INSTRUMENTATION B 3.3.14 Control Room Isolation Radiation Monitors BASES BACKGROUND The Control Room Isolation 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. The OPERABILITY requirements for the containment phase B isolation signal are specified in the technical specifications. The FUNCTIONALITY of these radiation monitors ensure that the radiation level in the control room is continually measured (in MODES 1, 2, 3, and 4) and that the automatic function of the monitors is initiated when the radiation level exceeds the monitor setpoint.

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Licensing Requirements Manual Containment Area Radiation Alarm B 3.3.15 B 3.3 INSTRUMENTATION B 3.3.15 Containment Area Radiation Alarm BASES BACKGROUND This LR only addresses the alarm function of the containment area radiation monitors. The indication provided by these monitors is addressed in the Post Accident Monitoring Instrumentation Technical Specification. The Containment Area Radiation Alarm provides a warning of high radiation in the containment. The FUNCTIONALITY of these radiation monitors ensures that the radiation level in the containment is continually measured (in MODES 1, 2, 3, and 4) and that the alarm is initiated when the radiation level exceeds the monitor setpoint.

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Licensing Requirements Manual Accident Monitoring Instrumentation B 3.3.16 B 3.3 INSTRUMENTATION B 3.3.16 Accident Monitoring Instrumentation BASES BACKGROUND The OPERABILITY/FUNCTIONALITY of the accident monitoring instrumentation ensures that sufficient information is available on selected plant parameters to monitor and assess these variables during and following an accident. This capability is consistent with the recommendations of Regulatory Guide 1.97, "Instrumentation for Light-Water-Cooled Nuclear Plants to Assess Plant Conditions During and Following an Accident," December 1975 and NUREG-0578, "TMI-2 Lessons Learned Task Force Status Report and Short-Term Recommendations."

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Licensing Requirements Manual Loop Isolation Valves - Shutdown B 3.4.1 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.1 Loop Isolation Valves - Shutdown BASES BACKGROUND LR 3.4.1 ensures that power is removed from isolated loop isolation valve operators 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 hot and 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 testing in MODES 5 and 6 and the loop will not be considered isolated when either the hot leg or cold leg loop isolation valve remains open.

If 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 the valve from being operated. Although operating procedures make the occurrence of this event unlikely, the prudent action is to remove power from the loop isolation valve operators. The completion time of 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to remove power from the loop isolation valve operators is sufficient considering the complexity of the task.

LRS 3.4.1.1 is performed at least once per 7 days to ensure that the RCS loop 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.

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Licensing Requirements Manual Chemistry B 3.4.2 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.2 Chemistry BASES BACKGROUND The 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 of the Reactor Coolant System over the life of the plant. The associated effects 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 time intervals without having a significant effect on the structural integrity of the Reactor Coolant System. The time interval permitting continued operation 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 to take corrective action.

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Licensing Requirements Manual Pressurizer B 3.4.3 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.3 Pressurizer BASES BACKGROUND The limitations imposed on the pressurizer heatup and cooldown rates and auxiliary spray water temperature differential are provided to assure that the pressurizer is operated within the design criteria assumed for the fatigue analysis performed in accordance with the ASME Code requirements.

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Licensing Requirements Manual B 3.4.4 B 3.4 REACTOR COOLANT SYSTEM (RCS)

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Licensing Requirements Manual Reactor Coolant System Head Vents B 3.4.5 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.5 Reactor Coolant System Head Vents BASES BACKGROUND Reactor Coolant System Vents are provided to exhaust noncondensible gases and/or steam from the primary system that could inhibit natural circulation core cooling. The FUNCTIONALITY of at least one reactor coolant 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 control system does not prevent isolation of the vent path.

The function, capabilities, and testing requirements of the Reactor Coolant System vent systems are consistent with the requirements of Item II.B.1 of NUREG-0737, "Clarification of TMI Action Plan Requirements," November 1980. These specifications, including timeframes for the action statements, were previously included in plant technical 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 credited in the Chapter 15 accident analyses, but are a safety related means for providing letdown to achieve cold shutdown and for alternate shutdown capability.

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Licensing Requirements Manual Pressurizer Safety Valve Lift Involving Loop Seal or Water Discharge B 3.4.6 B 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 valve operation involving liquid discharge. This requirement is to ensure a safety 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 a prudent precaution that provides additional assurance, beyond the inservice testing and inspection requirements, that the valves are evaluated for operability after a liquid discharge.

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Licensing Requirements Manual Containment Isolation Valves B 3.6.1 B 3.6 CONTAINMENT B 3.6.1 Containment Isolation Valves BASES BACKGROUND There are two types of 'administrative controls' applicable to the Containment Isolation Valves listed in Table 3.6.1-1 of this Licensing Requirements Manual (LRM). The administrative controls which apply when any locked or sealed closed Containment Isolation Valves are opened 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 Isolation 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 the original BVPS Unit 1 Technical Specifications and in Amendment No. 1 of the 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 to be opened on an intermittent basis to perform essential operating functions" in Modes 1-4. The term 'administrative controls' was not explicitly defined or described in either BVPS Unit 1 original Technical Specifications nor Amendment 1 correspondence. It 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 'administrative controls' were not described/defined and the documented basis discussed their essential operating functions. When BVPS Unit 2 was initially licensed, the Unit 2 Technical Specifications were modeled after the Unit 1 Technical Specifications. Note (1) used for valves in Penetrations 28, 46, 55C, 57C, 87, 88, 92, 93, 97B, 105B in the original BVPS Unit 2 Technical Specifications followed this same justification as used for CIVs using Note (1) in the BVPS Unit 1 Technical Specifications.

Subsequently the Unit 2 containment air lock valves had Note (1) added since their operation basis was described in the UFSAR (similar to the Unit 1 containment air lock valves). A review/revision of Table 3.6.1-1 was 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 the Beaver Valley Unit 2 B 3.6.1 - 1 LRM Revision 52

Licensing Requirements Manual Containment Isolation Valves B 3.6.1 BASES BACKGROUND (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 CIVs which are operated pursuant to other defined administrative controls such as for normally locked or sealed closed CIVs.]

Amendment No. 66 to the BV-2 Technical Specifications added criteria to Technical Specification 3/4.6.1.1 and 3/4.6.3.1 allowing a locked or sealed closed CIV to be opened without declaring the CIV inoperable, in accordance with Generic Letter 91-08. Locked or sealed closed CIVs may only be opened, without entering the LCO, if the administrative controls defined in Technical Specification Bases 3.6.3 is followed, in accordance with Technical Specification 3.6.3. [The explicitly defined

'administrative controls' which allow opening of locked or sealed closed CIVs are not the same 'administrative controls' for opening CIVs per Note (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.

CIVs 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.

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Licensing Requirements Manual Containment Sump B 3.6.2 B 3.6 CONTAINMENT B 3.6.2 Containment Sump BASES BACKGROUND The purpose of this LR is to assure good housekeeping practice is applied 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)) are removed from the containment building. The presence of debris in the containment sump following a LOCA could interfere with the operation of the Emergency Core Cooling System pumps needed to mitigate the LOCA. The requirements of this LR include the performance of a visual inspection following containment entries for maintenance or inspection.

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Licensing Requirements Manual Steam Generator Pressure/Temperature Limitation B 3.7.1 B 3.7 PLANT SYSTEMS B 3.7.1 Steam Generator Pressure/Temperature Limitation BASES 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 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 heat release valve and associated isolation valve, or removal of a steam generator manway or safety valve.

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Licensing Requirements Manual Flood Protection B 3.7.2 B 3.7 PLANT SYSTEMS B 3.7.2 Flood Protection BASES 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). The Montgomery 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). The Montgomery Lock and Dam tailwater level may also be obtained by contacting the US Army Corps of Engineers or the Montgomery Lock and Dam. Telephone numbers may be obtained from the Emergency Notification Call List in the Emergency Preparedness implementing procedures.

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Licensing Requirements Manual Sealed Source Contamination B 3.7.3 B 3.7 PLANT SYSTEMS B 3.7.3 Sealed Source Contamination BASES BACKGROUND The 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.

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Licensing Requirements Manual Snubbers B 3.7.4 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 systems is 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 2004 Edition up to and including the 2006 Addenda, Subsection ISTD, Preservice and Inservice Examination and Testing of Dynamic Restraints (Snubbers) in Light-Water Reactor Power Plants.

In August 2014, the NRC approved the use of ASME OM Code Case OMN-13, Rev. 0 (2004 Edition), in Regulatory Guide 1.192, Rev. 1.

OMN-13 allows for a maximum visual inspection interval of 10 years, if certain conditions are met.

During the 1980s, snubber surveillance requirements were identified in three documents: Section XI of the ASME Boiler and Pressure Vessel (B&PV) Code, a plants 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 to cause 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 three documents 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 Inservice Examination and Testing of Dynamic Restraints (Snubbers) in Light-Water Reactor Nuclear Power Plants. In 1999, the NRC endorsed the use of ISTD requirements in lieu of the snubber surveillance requirements identified in Section XI or a plants Technical Specifications or licensee controlled documents

[10 CFR 50.55a(b)(3)(v)].

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Licensing Requirements Manual Snubbers B 3.7.4 BASES BACKGROUND (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 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . 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 systems Completion Time applies.

LCO 3.0.8 is not applicable to snubbers whose function is to arrest a water 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 perform an immediate, event driven assessment when a snubber is Nonfunctional.

Beaver Valley Unit 2 B 3.7.4 - 2 LRM Revision 67

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 1 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2BDG-PSSP868 No A loop SG blowdown 2BDG-PSSP876 No A loop SG blowdown 2BDG-PSSP927 No B loop SG blowdown 2BDG-PSSP945 No C loop SG blowdown 2BDG-PSSP947 No A loop SG blowdown 2BRS-PSSP091Y Yes Waterhammer load is zero Redundant train of degasifer piping 2CCP-PSSP301 No Common CCP pumps discharge piping 2CCP-PSSP317A No Common CCP pumps discharge piping 2CCP-PSSP317B No Common CCP pumps discharge piping 2CHS-PSSP006 No Single train charging piping 2CHS-PSSP015X No Single train charging piping 2CHS-PSSP016X No C loop fill piping 2CHS-PSSP017X No A loop fill piping 2CHS-PSSP024 No Single Train to A RCP 2CHS-PSSP025 No Single Train to A RCP 2CHS-PSSP025X Yes Relief Valve discharge Beaver Valley Unit 2 B 3.7.4 - 3 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 2 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis Waterhammer load is virtually Common charging pump discharge 2CHS-PSSP252Y Yes zero header 2CHS-PSSP308A Yes Waterhammer load is zero Common RCP leakoff piping 2CHS-PSSP308B Yes Waterhammer load is zero Common RCP leakoff piping 2CHS-PSSP660X No B loop fill piping 2CHS-PSSP673X No Single train letdown piping 2CHS-PSSP685C Yes AOV closure 2DGS-PSSP879 No Redundant train of loop drain (C loop) 2EDG-PSSP029A No Single train to # 1 Diesel 2EDG-PSSP029B No Single train to # 1 Diesel 2EDG-PSSP030Y No Single train to # 1 Diesel 2EDG-PSSP033Y No Single train to # 2 Diesel 2EDG-PSSP042A No Single train to # 2 Diesel 2EDG-PSSP042B No Single train to # 2 Diesel 2FWE-PSSP009 No Redundant trains of FEW (C loop) 2FWE-PSSP010 No Redundant trains of FEW (C loop) 2FWE-PSSP354A Yes Relief Valve discharge 2FWE-PSSP354B Yes Relief Valve discharge 2FWS-PSSP001 Yes FWS Pump Trip / FCV closure 2FWS-PSSP002A Yes FWS Pump Trip / FCV closure Beaver Valley Unit 2 B 3.7.4 - 4 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 3 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2FWS-PSSP002B Yes FWS Pump Trip / FCV closure 2FWS-PSSP003A Yes FWS Pump Trip / FCV closure 2FWS-PSSP003B Yes FWS Pump Trip / FCV closure 2FWS-PSSP005 Yes FWS Pump Trip / FCV closure 2FWS-PSSP006 Yes FWS Pump Trip / FCV closure 2FWS-PSSP012 Yes FWS Pump Trip / FCV closure 2FWS-PSSP016 Yes FWS Pump Trip / FCV closure 2FWS-PSSP036 Yes FWS Pump Trip / FCV closure 2FWS-PSSP039 Yes FWS Pump Trip / FCV closure 2FWS-PSSP060 Yes FWS Pump Trip / FCV closure 2MSS-PSSP001 Yes Turbine trip 2MSS-PSSP002A Yes Turbine trip 2MSS-PSSP002B Yes Turbine trip 2MSS-PSSP003A Yes Turbine trip 2MSS-PSSP003B Yes Turbine trip 2MSS-PSSP005 Yes Turbine trip 2MSS-PSSP006 Yes Turbine trip 2MSS-PSSP007 Yes Turbine trip 2MSS-PSSP008A Yes Turbine trip 2MSS-PSSP008B Yes Turbine trip Beaver Valley Unit 2 B 3.7.4 - 5 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 4 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2MSS-PSSP009 Yes Turbine trip 2MSS-PSSP011A Yes Turbine trip 2MSS-PSSP011B Yes Turbine trip 2MSS-PSSP012 Yes Turbine trip 2MSS-PSSP103 Yes Safety Valve blowdown 2MSS-PSSP107 Yes Safety Valve blowdown 2MSS-PSSP108A Yes Safety Valve blowdown 2MSS-PSSP108B Yes Safety Valve blowdown 2MSS-PSSP110 Yes Safety Valve blowdown 2MSS-PSSP111A Yes Safety Valve blowdown 2MSS-PSSP111B Yes Safety Valve blowdown 2MSS-PSSP112A Yes Safety Valve blowdown 2MSS-PSSP112B Yes Safety Valve blowdown 2MSS-PSSP124 Yes Safety Valve blowdown 2MSS-PSSP128A Yes Safety Valve blowdown 2MSS-PSSP128B Yes Safety Valve blowdown 2MSS-PSSP130 Yes Safety Valve blowdown 2MSS-PSSP131A Yes Safety Valve blowdown 2MSS-PSSP131B Yes Safety Valve blowdown Beaver Valley Unit 2 B 3.7.4 - 6 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 5 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2MSS-PSSP132A Yes Safety Valve blowdown 2MSS-PSSP132B Yes Safety Valve blowdown 2MSS-PSSP144 Yes Safety Valve blowdown 2MSS-PSSP147A Yes Safety Valve blowdown 2MSS-PSSP147B Yes Safety Valve blowdown 2MSS-PSSP149 Yes Safety Valve blowdown 2MSS-PSSP150A Yes Safety Valve blowdown 2MSS-PSSP150B Yes Safety Valve blowdown 2MSS-PSSP151A Yes Safety Valve blowdown 2MSS-PSSP151B Yes Safety Valve blowdown 2MSS-PSSP164 Yes Safety Valve blowdown 2MSS-PSSP165 Yes Safety Valve blowdown 2MSS-PSSP168 Yes Safety Valve blowdown 2MSS-PSSP456 Yes Turbine trip 2MSS-PSSP476 Yes Turbine trip 2QSS-PSSP101Y Yes Quench Spray Pump start 2QSS-PSSP129Y Yes Quench Spray Pump start 2QSS-PSSP131Y Yes Quench Spray Pump start Beaver Valley Unit 2 B 3.7.4 - 7 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 6 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2QSS-PSSP138Y Yes Quench Spray Pump start 2QSS-PSSP154X No Single train to RWST cooling pumps 2QSS-PSSP217X No Single train to RWST cooling pumps 2RCS-PSSP001X No Single train of Pressurizer spray 2RCS-PSSP006A Yes PSARV Discharge 2RCS-PSSP007X Yes PSARV Discharge 2RCS-PSSP009A Yes PSARV Discharge 2RCS-PSSP009B Yes PSARV Discharge 2RCS-PSSP010A Yes PSARV Discharge 2RCS-PSSP010B Yes PSARV Discharge 2RCS-PSSP011X Yes PSARV Discharge 2RCS-PSSP012A Yes PSARV Discharge 2RCS-PSSP012B Yes PSARV Discharge 2RCS-PSSP014A Yes PSARV Discharge 2RCS-PSSP014B Yes PSARV Discharge 2RCS-PSSP015X Yes PSARV Discharge 2RCS-PSSP016X Yes PSARV Discharge 2RCS-PSSP017X Yes PSARV Discharge 2RCS-PSSP018X Yes PSARV Discharge Beaver Valley Unit 2 B 3.7.4 - 8 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 7 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2RCS-PSSP019X Yes PSARV Discharge 2RCS-PSSP020X Yes PSARV Discharge 2RCS-PSSP021X Yes PSARV Discharge 2RCS-PSSP022 No Redundant train of loop drain (A loop) 2RCS-PSSP022X Yes PSARV Discharge 2RCS-PSSP022Y Yes PSARV Discharge 2RCS-PSSP023X Yes PSARV Discharge 2RCS-PSSP026 No Redundant train of loop drain (B loop) 2RCS-PSSP026A Yes PSARV Discharge 2RCS-PSSP026B Yes PSARV Discharge 2RCS-PSSP028 No Redundant train of loop drain (A loop) 2RCS-PSSP029X Yes PSARV Discharge 2RCS-PSSP030 No Redundant train of loop drain (B loop) 2RCS-PSSP030X Yes PSARV Discharge 2RCS-PSSP031X Yes PSARV Discharge 2RCS-PSSP035 No Redundant train of loop drain (C loop) 2RCS-PSSP035X Yes PSARV Discharge 2RCS-PSSP653 No Redundant train of loop drain (B loop) 2RCS-PSSP882 Yes PSARV Discharge Beaver Valley Unit 2 B 3.7.4 - 9 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 8 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2RCS-PSSP883A Yes PSARV Discharge 2RCS-PSSP883B Yes PSARV Discharge 2RCS-PSSP884A Yes PSARV Discharge 2RCS-PSSP884B Yes PSARV Discharge 2RCS-PSSP885 Yes PSARV Discharge 2RCS-PSSP887A Yes PSARV Discharge 2RCS-PSSP887B Yes PSARV Discharge 2RCS-PSSP890 Yes PSARV Discharge 2RCS-PSSP891A Yes PSARV Discharge 2RCS-PSSP891B Yes PSARV Discharge 2RCS-PSSP892A Yes PSARV Discharge 2RCS-PSSP892B Yes PSARV Discharge 2RCS-PSSP893 Yes PSARV Discharge 2RCS-PSSP894 Yes PSARV Discharge 2RCS-PSSP896 Yes PSARV Discharge 2RCS-PSSP897 Yes PSARV Discharge 2RCS-PSSP898 Yes PSARV Discharge 2RCS-PSSP906 Yes Relief Valve discharge 2RCS-SN21A10 Yes MS / FW line break Beaver Valley Unit 2 B 3.7.4 - 10 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 9 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2RCS-SN21A12 Yes MS / FW line break 2RCS-SN21B10 Yes MS / FW line break 2RCS-SN21B12 Yes MS / FW line break 2RCS-SN21C10 Yes MS / FW line break 2RCS-SN21C12 Yes MS / FW line break 2RHS-PSSP003 No Redundant train of RHR (B train) 2RHS-PSSP005 Yes Relief Valve discharge 2RHS-PSSP007 No Redundant train of RHR (A train) 2RHS-PSSP008A No Redundant train of RHR (A train) 2RHS-PSSP008B No Redundant train of RHR (A train) 2RHS-PSSP013X Yes Relief Valve discharge 2RHS-PSSP521X Yes MS / FW line break 2RHS-PSSP522X Yes MS / FW line break 2RSS-PSSP124A Yes RSS Pump start 2RSS-PSSP124B Yes RSS Pump start 2RSS-PSSP129A Yes RSS Pump start 2RSS-PSSP129B Yes RSS Pump start Beaver Valley Unit 2 B 3.7.4 - 11 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 10 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2RSS-PSSP134A Yes RSS Pump start 2RSS-PSSP134B Yes RSS Pump start 2RSS-PSSP139A Yes RSS Pump start 2RSS-PSSP139B Yes RSS Pump start 2RSS-PSSP465X Yes Low Head Pump start 2RSS-PSSP572A Yes Waterhammer load is zero A train RSS pump to penetration 2RSS-PSSP572B Yes Waterhammer load is zero A train RSS pump to penetration 2RSS-PSSP577 No D train RSS pump return line 2RSS-PSSP579A Yes Waterhammer load is zero B train RSS pump to penetration 2RSS-PSSP579B Yes Waterhammer load is zero B train RSS pump to penetration 2SIS-PSSP006A No Common LH SI piping 2SIS-PSSP006B No Common LH SI piping 2SIS-PSSP014A No Redundant train of SI 2SIS-PSSP014B No Redundant train of SI 2SIS-PSSP208X No Redundant train of SI 2SIS-PSSP209A No Redundant train of SI 2SIS-PSSP209B No Redundant train of SI 2SIS-PSSP301Y No Common LH SI piping Beaver Valley Unit 2 B 3.7.4 - 12 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 11 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis 2SIS-PSSP358Y Yes Low Head Pump start 2SIS-PSSP366Y Yes Low Head Pump start 2SIS-PSSP449A Yes Low Head Pump start 2SIS-PSSP449B Yes Low Head Pump start 2SIS-PSSP450X Yes Low Head Pump start 2SIS-PSSP451X No Common LH SI piping 2SIS-PSSP480 No Common LH SI piping 2SIS-PSSP492 No Common LH SI piping 2SIS-PSSP785 No Redundant train of SI 2SWS-PSSP752 No Common piping to RSS Hx's 2SWS-PSSP753 No Common piping to RSS Hx's 2SWS-PSSP754Y No Common piping to RSS Hx's Fill of empty RSS Heat 2SWS-PSSP766A No Exchangers Fill of empty RSS Heat 2SWS-PSSP768Y No Exchangers Fill of empty RSS Heat 2SWS-PSSP769A No Exchangers Beaver Valley Unit 2 B 3.7.4 - 13 LRM Revision 54

Licensing Requirements Manual Snubbers B 3.7.4 BASES TABLE B 3.7.4-1 (Page 12 of 12)

BASIS FOR SNUBBERS COMPLETION TIME Functional Location Waterhammer Type of Waterhammer Completion Time Basis Fill of empty RSS Heat 2SWS-PSSP770A No Exchangers Fill of empty RSS Heat 2SWS-PSSP770B No Exchangers Fill of empty RSS Heat 2SWS-PSSP771Y No Exchangers Fill of empty RSS Heat 2SWS-PSSP772A No Exchangers Fill of empty RSS Heat 2SWS-PSSP772B No Exchangers Fill of empty RSS Heat 2SWS-PSSP773A No Exchangers Fill of empty RSS Heat 2SWS-PSSP773B No Exchangers Fill of empty RSS Heat 2SWS-PSSP774Y No Exchangers Fill of empty RSS Heat 2SWS-PSSP830Y No Exchangers Fill of empty RSS Heat 2SWS-PSSP832A No Exchangers Fill of empty RSS Heat 2SWS-PSSP832B No Exchangers Beaver Valley Unit 2 B 3.7.4 - 14 LRM Revision 54

Licensing Requirements Manual Standby Service Water System (SWE)

B 3.7.5 B 3.7 PLANT SYSTEMS B 3.7.5 Standby Service Water System (SWE)

BASES BACKGROUND The FUNCTIONALITY of the SWE ensures that sufficient cooling capacity is available to bring the reactor to a cold shutdown condition in the event that 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 explosion disabling 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 meet single active failure criteria, the system is designed with redundant pumps and 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 bus during loss of offsite power after the diesel loading sequence is complete.

With no loss of power signal present, the SWE is automatically started upon 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. If there is a delay in starting the SWE, the auxiliary feedwater system is available to remove reactor core decay heat for a short term period.

The requirements for subsystem FUNCTIONALITY are similar to those of the SWS except that one subsystem is required to be FUNCTIONAL in the MODES noted. The LR reflects the low risk of the postulated event compared to more stringent requirements associated with safety related systems. 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 2 B 3.7.5 - 1 LRM Revision 69

Licensing Requirements Manual Explosive Gas Mixture B 3.7.6 B 3.7 PLANT SYSTEMS B 3.7.6 Explosive Gas Mixture BASES BACKGROUND This 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.

Isolation of the affected tank for purposes of purging and/or discharge permits the flammable gas concentrations of the tank to be reduced below the lower explosive limit in a hydrogen rich system. Maintaining the 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 Design Criterion 60 of Appendix A to 10 CFR Part 50.

Beaver Valley Unit 2 B 3.7.6 - 1 LRM Revision 52

Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS)

B 3.7.7 B 3.7 PLANT SYSTEMS B 3.7.7 Supplemental Leak Collection and Release System (SLCRS)

BASES BACKGROUND The 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 SLCRS except for the Emergency Air Lock.

No credit for SLCRS operation was taken in the DBA LOCA analysis for collection and filtration of Reactor Containment building leakage and ESF leakage effluents even though an unquantifiable amount of contiguous area penetration leakage and ESF leakage effluents would in fact be collected and filtered. Therefore, defeating the capability to have SLCRS filter the contiguous areas (normally unfiltered) does not result in either train of SLCRS being NONFUNCTIONAL. With no SLCRS exhaust flow from either the unfiltered or filtered flow paths, heat removal from these contiguous areas would either be provided by the local area safety related air conditioning units or would not be required.

The SLCRS does, however, perform a heat removal support function for various safety related equipment (e.g. High Head Safety Injection/Charging pumps and Component Cooling Water pumps).

In the event that the SLCRS ventilation branch path from the HHSI/Charging Pump cubicles and Component Cooling Water pumps area is isolated, the Auxiliary Building Emergency Ventilation Fans must be available to provide the heat removal function.

SLCRS is also credited with heat removal of the Engineered Safety Feature (ESF) Pump Motors (e.g., Recirculation Spray and Motor Driven Auxiliary Feedwater) in the event of a DBA, if either of the Safeguards ACUs are unavailable.

Beaver Valley Unit 2 B 3.7.7 - 1 LRM Revision 92

Licensing Requirements Manual 125V D.C. Battery Banks Maintenance Requirements B 3.8.1 B 3.8 ELECTRICAL POWER SYSTEMS B 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 the Technical 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 - 1 LRM Revision 52

Licensing Requirements Manual Emergency DG 2000 Hour Rating Limit B 3.8.2 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.2 Emergency DG 2000 Hour Rating Limit BASES BACKGROUND The provisions of this LR require a periodical verification that the Emergency Diesel Generator (EDG) 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating limit continues to be met. The verification required by this LR supplements the other EDG requirements in the Technical Specification.

Beaver Valley Unit 2 B 3.8.2 - 1 LRM Revision 52

Licensing Requirements Manual Main Fuel Oil Storage Tank Maintenance Requirements B 3.8.3 B 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 the EDG Technical Specification requirements and provides additional assurance the EDG fuel oil supply is maintained with an acceptable level of 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 Building B 3.9.1 B 3.9 REFUELING OPERATIONS B 3.9.1 Crane Travel - Spent Fuel Storage Pool Building BASES BACKGROUND The restriction on movement of loads in excess of the normal weight of a fuel assembly and control rod assembly and associated handling tool over other fuel assemblies ensures that no more than the contents of those fuel assembly rods assumed in the fuel handling accident described in Chapter 15 of the BVPS Unit 2 UFSAR will be ruptured. This assumption is consistent with the activity release assumed in the accident analyses.

The frequency of LRS 3.9.1.1 FUNCTIONALITY demonstration is based on the inspection frequency specified in ANSI B30.2-1976, paragraph 2-2.1.4.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 B 3.9.1 - 1 LRM Revision 67

Licensing Requirements Manual Manipulator Crane B 3.9.2 B 3.9 REFUELING OPERATIONS B 3.9.2 Manipulator Crane BASES BACKGROUND The 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 vessel are protected from excessive lifting force in the event they are inadvertently engaged during lifting operations.

Beaver Valley Unit 2 B 3.9.2 - 1 LRM Revision 67

Licensing Requirements Manual Decay Time B 3.9.3 B 3.9 REFUELING OPERATIONS B 3.9.3 Decay Time BASES BACKGROUND The minimum requirement for reactor subcriticality prior to movement of irradiated fuel assemblies in the reactor vessel ensures that sufficient time 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 calculation assumptions 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 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months . This requirement is based on cooling water inlet temperature to the fuel storage pool heat exchanger as described in a BVPS letter to the NRC (L-01-113), dated October 29, 2001. After 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months , 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 - 1 LRM Revision 70

ML22144A134

Text

3.6.3. APPLICABILITY

Reference:

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