Text

Licensing Requirements Manual (LRM) Quick Index
	ML20160A078
Person / Time
Site:	Beaver Valley
Issue date:	05/20/2020
From:	; Energy Harbor Nuclear Corp
To:	; Office of Nuclear Reactor Regulation
Shared Package
ML20160A057	List: L-20-051, Technical Specification Bases, Revision 37, Reactor Coolant System (RCS) (Part 2 of 2); ML20160A058; ML20160A059; ML20160A060; ML20160A062; ML20160A063; ML20160A064; ML20160A065; ML20160A066; ML20160A067; ML20160A068; ML20160A069; ML20160A070; ML20160A071; ML20160A072; ML20160A073; ML20160A074; ML20160A075; ML20160A076; ML20160A077; ML20160A078; ML20160A079;
References
	L-20-051
	Download: ML20160A078 (262)
	v • d • e

Unit 1 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 SG Pressure/Temperature 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 Auxiliary River Water System (ARWS) 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. Bttry Bank Maint Requirements 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 3.9 REFUELING OPERATIONS 3.9.1-1 3.1.2 Boration Flow Paths - Operating 3.1.2-1 3.9.1 Crane Travel - Spent Fuel Strg. Pool Bldg. 3.9.1-1 3.1.3 Charging Pump - Shutdown 3.1.3-1 3.9.2 Manipulator Crane 3.9.2-1 3.1.4 Charging Pumps - Operating 3.1.4-1 3.9.3 Decay Time 3.9.3-1 3.1.5 Boric Acid Transfer Pumps - Shutdown 3.1.5-1 3.9.4 Cnmt. Purge and Exhst. Isolation System 3.9.4-1 3.1.6 Boric Acid Transfer Pumps - Operating 3.1.6-1 3.1.7 Borated Water Sources - Shutdown 3.1.7-1 5.0 ADMINISTRATIVE CONTROLS 5.1-1 3.1.8 Borated Water Sources - Operating 3.1.8-1 5.1 Core Operating Limits Report 5.1-1 3.1.9 Rod Position Indication System - Shutdown 3.1.9.1 5.2 Pressure and Temperature Limits Report 5.2-i 3.1.10 Boron Dilution 3.1.10-1 5.3 Procedure Review and Approval 5.3-1 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 3.3.3 Meteorological Monitoring Instrmtation B 3.3.3-1 3.3.5 Quadrant Power Tilt Ratio (QPTR) Monitor Alarm B 3.3.4 AFD Monitor Alarm B 3.3.4-1 3.3.5-1 B 3.3.5 QPTR Monitor Alarm B 3.3.5-1 3.3.6 Seismic Monitoring Instrumentation 3.3.6-1 B 3.3.6 Seismic Monitoring Instrumentation B 3.3.6-1 3.3.7 Movable Incore Detectors 3.3.7-1 B 3.3.7 Movable Incore Detectors B 3.3.7-1 3.3.8 Leading Edge Flow Meter 3.3.8-1 B 3.3.8 Leading Edge Flow Meter B 3.3.8-1 3.3.9 Turbine Overspeed Protection 3.3.9-1 B 3.3.9 Turbine Overspeed Protection B 3.3.9-1 3.3.10 RTS, ESFAS, and Loss of Power Trip Setpoints B 3.3.11 Fuel Strg. Pool Area Rad. Monitor B 3.3.11-1 3.3.10-1 B 3.3.12 Explosive Gas Mntrg. Instrmtion B 3.3.12-1 3.3.11 Fuel Storage Pool Area Radiation Monitor B 3.3.13 Containment Hydrogen Analyzers B 3.3.13-1 3.3.11-1 B 3.3.14 Cntrl Rm Isolation Rad. Monitors B 3.3.14-1 3.3.12 Explosive Gas Monitoring Instrumentation B 3.3.15 Containment Area Radiation Alarm B 3.3.15-1 3.3.12-1 B 3.3.16 Accident Monitoring Instrumentation B 3.3.16-1 3.3.13 Containment Hydrogen Analyzers 3.3.13-1 B 3.3.17 Cnmt Prge & Exhst Isltn Rad. Mntrs B 3.3.17-1 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 3.3.17 Containment Purge & Exhaust Isolation Radiation B 3.4.4 DELETED Monitors 3.3.17-1 B 3.4.5 Reactor Coolant System Vents B 3.4.5-1 B 3.4.6 Presszr Sfty Vlv Lift Invlvg Lquid Disch B 3.4.6-1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1-1 B 3.6.1 Containment Isolation Valves B 3.6.1-1 3.4.1 Loop Isolation Valves - Shutdown 3.4.1-1 B 3.6.2 Containment Sump B 3.6.2-1 3.4.2 Chemistry 3.4.2-1 B 3.7.1 SG Pressure/Temperature Limitation B 3.7.1-1 3.4.3 Pressurizer 3.4.3-1 B 3.7.2 Flood Protection B 3.7.2-1 3.4.4 DELETED B 3.7.3 Sealed Source Contamination B 3.7.3-1 3.4.5 RCS Vents 3.4.5-1 B 3.7.4 Snubbers B 3.7.4-1 3.4.6 Pressurizer Safety Valve Lift Involving Liquid B 3.7.5 Auxiliary River Water System B 3.7.5-1 Water Discharge 3.4.6-1 B 3.7.6 Explosive Gas Mixture B 3.7.6-1 3.4.7 RCS Pressure Isolation Valves 3.4.7-1 B 3.7.7 SLCRS B 3.7.7-1 B 3.8.1 125V DC Battery Bnks Maint Rqmts B 3.8.1-1 3.6 CONTAINMENT 3.6.1-1 B 3.8.2 Emer. DG 2000 Hour Rating Limit B 3.8.2-1 3.6.1 Containment Isolation Valves 3.6.1-1 B 3.9.1 Crane Trvl - Spnt Fuel Stg Pool Bldg B 3.9.1-1 3.6.2 Containment Sump 3.6.2-1 B 3.9.2 Manipulator Crane B 3.9.2-1 B 3.9.3 Decay Time B 3.9.3-1 B 3.9.4 Cnmt Purge & Exhst Isolation Sys B 3.9.4-1 Revision 1

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 105 20-015 3.3.1-2 2/26/20 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

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 103 18-090 5.2-11 4/3/19 (continued) 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 5.2-28 104 19-076, 19-095, 5.1-1 10/22/19 and 19-106 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-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 99 17-096 5.1-11 10/25/17 (continued) 5.1-12 5.1-13 5.1-14 5.1-15 5.1-16 100 18-016 3.7.4-2 4/13/18 101 18-020 5.1-1 4/26/18 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 5.1-16 102 18-096 3.7.4-2 9/27/18 18-095 3.7.7-3 18-121 B 3.7.4-1 103 18-090 5.2-i 4/3/19 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

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 97 17-069 5.2-24 7/19/17 (continued) 5.2-25 5.2-26 5.2-27 5.2-28 98 17-097 5.2-i 9/7/17 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 99 17-096 5.1-1 10/25/17 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

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 94 16-114 5.1-1 10/6/16 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 95 15-201 3.3.6-3 11/7/16 3.3.6-4 96 16-151 3.3.6-3 2/9/17 3.3.6-4 97 17-069 5.2-i 7/19/17 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

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 87 14-152 3.9.1-1 1/23/15 5.3-1 5.4-2 B 3.9.1-1 88 15-034 3.3.6-4 4/17/15 15-062 3.7.4-2 B 3.7.4-1 89 14-226 3.7.4-11 5/7/15 3.7.4-12 B 3.7.4-11 B 3.7.4-12 B 3.7.4-14 15-031 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 90 15-203 3.3.7-1 12/3/15 3.3.7-2 5.1-2 5.1-3 5.1-4 91 16-013 3.3.7-1 1/28/16 5.1-2 5.1-3 92 16-038 3.3.8-2 4/26/16 93 16-049 3.9.2-2 6/10/16

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 83 13-203 B 3.7.2-1 12/6/13 84 14-070 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 85 14-053 3.1.8-1 7/24/14 86 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

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 79 12-133 3.7.4-5 3/15/13 B 3.7.4-5 12-263 B 3.3.8-2 80 13-039 5.2-i 5/24/13 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 81 13-124 3.7.2-1 9/25/13 B 3.7.2-1 82 13-168 5.1-1 10/17/13 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-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 71 10-068 B 3.3.16-1 12/15/10 (continued) B 3.3.17-1 B 3.4.4-1 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 72 11-001 3.4.2-2 3/31/11 11-004 3.7.5-1 B 3.7.5-1 73 11-079 3.3.6-3 5/4/11 3.3.6-4 74 11-101 3.3.9-2 7/1/11 75 11-155 B 3.9.3-1 11/18/11 76 12-031 & 12-043 5.2-4 3/16/12 12-031 5.2-6 77 12-011 3.4.3-1 3/30/12 3.4.3-2 3.4.3-3 B 3.4.3-1 78 12-028 5.1-1 4/26/12 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

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 71 10-068 3.3.13-1 12/15/10 (continued) 3.3.14-1 3.3.14-2 3.3.15-1 3.3.16-1 3.3.17-1 3.4.2-1 3.4.4-1 3.4.5-1 3.4.5-2 3.4.5-3 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 3.7.7-3 3.9.1-1 3.9.2-1 3.9.2-2 3.9.4-1 8-i 8-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 3.0-9 B 3.1.1-1 B 3.1.1-2 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

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 69 10-130 5.1-1 10/16/10 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 70 10-155 5.1-7 10/22/10 71 10-068 TOC page i 12/15/10 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 3.3.3-1 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 3.3.9-1 3.3.11-1

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 63 07-106 3.1.3-1 3/20/08 3.1.5-1 3.1.6-1 07-192 3.1.3-2 08-009 B 3.7.1-1 64 08-044 3.3.2-3 4/4/08 08-025 3.4.5-1 B 3.4.5-1 65 08-090 B 3.3.8-1 9/4/08 66 07-119 3.3.14-1 10/9/08 3.3.14-2 3.3.14-3 67 08-036 3.3.10-3 4/27/09 08-157 3.4.5-1 3.4.5-2 09-004 3.8.1-1 09-022 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 68 09-179 5.1-2 1/7/10 5.1-11 5.1-12 5.1-13

BVPS-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date 60 07-121 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 61 07-145 & 07-146 3.3.2-3 10/15/2007 07-146 3.3.10-4 3.3.10-5 3.3.10-6 62 07-165 5.1-1 10/20/2007 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-1 LICENSING REQUIREMENTS MANUAL REVISION STATUS Revision Number LRM Request Number Pages Issued Implementation Date All previous Revision All previous LRM All LRM pages in Prior to 6/23/2007 Numbers Request Numbers old format 56 1-098 All LRM pages in 6/23/2007 Improved Technical Specification format 07-045 3.0-1 57 07-086 5.1-11 8/23/2007 5.1-12 5.1-13 58 07-096 3.3.14-2 9/18/2007 1-092 3.7.4-1 3.7.4-2 B 3.7.4-1 B 3.7.4-2 07-111 5.2-3 5.2-5 5.2-6 5.2-7 5.2-8 5.2-10 5.2-11 5.2-12 5.2-13 5.2-18 5.2-19 5.2-22 59 07-139 5.1-1 10/5/2007 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

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 3.3 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 lncore 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 3.3.17 Containment Purge & Exhaust Isolation Radiation Monitors .......................... 3.3.17-1 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 1 LRM Revision 71

LICENSING REQUIREMENTS MANUAL TABLE OF CONTENTS Page No.

3.4 REACTOR COOLANT SYSTEM (RCS) (continued) 3.4.5 RCS Vents ...................................................................................................... 3.4.5-1 3.4.6 Pressurizer Safety Valve Lift Involving Liquid 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 Auxiliary River Water System (ARWS) ........................................................... 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 Bank Maintenance Requirements .................................... 3.8.1-1 3.8.2 Emergency Diesel Generator (EDG) 2000 Hour Rating Limit ........................ 3.8.2-1 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 3.9.4 Containment Purge and Exhaust Isolation System ........................................ 3.9.4-1 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 1 ii LRM Revision 71

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 15A 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 15A.

A. Information Not Incorporated by Reference from the UFSAR

Section 3.3.9, Turbine Overspeed Protection Beaver Valley Unit 1 1.0 - 1 LRM Revision 56

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 1 1.0 - 2 LRM Revision 56

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.

Beaver Valley Unit 1 1.1 - 1 LRM Revision 71

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 1 1.2 - 1 LRM Revision 56

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 1 1.3 - 1 LRM Revision 56

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 1 1.4 - 1 LRM Revision 56

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.

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 FENOC 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.

Beaver Valley Unit 1 3.0-1 LRM Revision 71

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.

Beaver Valley Unit 1 3.0 - 2 LRM Revision 56

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.

Beaver Valley Unit 1 3.0-3 LRM Revision 71

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 2.07 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 AL TERATIONS 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.

Beaver Valley Unit 1 3.1.1 - 1 LRM Revision 71

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.

Beaver Valley Unit 1 3.1.1 - 2 LRM Revision 71

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 :s; 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 25°F, 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 8.1 Apply LR 3.0.3. Immediately associated Completion Time of Condition A not met.

Beaver Valley Unit 1 3.1.2 - 1 LRM Revision 71

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.

Beaver Valley Unit 1 3.1.2 - 2 LRM Revision 71

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~ 2.07 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 AL TERATIONS 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.

Beaver Valley Unit 1 3.1.3 - 1 LRM Revision 71

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.

Beaver Valley Unit 1 3.1.3 - 2 LRM Revision 71

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 25°F, 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 8.1 Apply LR 3.0.3. Immediately associated Completion Time of Condition A not met.

Beaver Valley Unit 1 3.1.4 - 1 LRM Revision 71

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.

Beaver Valley Unit 1 3.1.4 - 2 LRM Revision 71

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. AL TERATIONS 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 lnservice recirculation flow, the pump develops a discharge Testing Program pressure of greater than or equal to 107 psig.

Beaver Valley Unit 1 3.1.5 - 1 LRM Revision 71

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 8.1 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 lnservice recirculation flow, the pump develops a discharge Testing Program pressure greater than or equal to 107 psig.

Beaver Valley Unit 1 3.1.6 - 1 LRM Revision 71

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 5000 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 175,000 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 AL TERATIONS 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 1 3.1.7 - 1 LRM Revision 71

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 1 3.1.7 - 2 LRM Revision 71

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 11,336 gallons,

b. Between 7000 and 7700 ppm of boron, and

c. A minimum solution temperature of 65 0 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 1 3.1.8 - 1 LRM Revision 85

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.

Beaver Valley Unit 1 3.1.8 - 2 LRM Revision 71

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 The group demand position indicators shall be FUNCTIONAL and capable of determining within +/- 2 steps the demand position for each shutdown or control rod not fully inserted.

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

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

Nonfunctional.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.1.9.1 Required group demand position indicator(s) shall be Once per 31 days determined to be FUNCTIONAL by movement of the associated control rod at least 1O steps in any one direction.

Beaver Valley Unit 1 3.1.9 - 1 LRM Revision 71

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.

- NOTE -

The addition of borated water to the RCS does not constitute a reduction in RCS boron concentration provided the boron concentration of the borated water being added is greater than the minimum required to satisfy the applicable SHUTDOWN MARGIN requirements in the Technical Specifications.

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 1 3.1.10 - 1 LRM Revision 56

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.

Beaver Valley Unit 1 3.3.1 - 1 LRM Revision 56

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

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 0.75 second

b. Two loops 0.75 second

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

12. Undervoltage-RCPs 1.2 seconds

13. Underfrequency-RCPs 0.6 second

14. Steam Generator Water Level - Low Low 2.0 seconds

15. Turbine Trip

a. Auto Stop Oil Pressure NOT APPLICABLE

b. Turbine Stop Valve NOT APPLICABLE

16. Safety Injection Input from ESFAS NOT APPLICABLE

17. Reactor Trip System Interlocks NOT APPLICABLE

18. Reactor Trip Breakers (RTBs) NOT APPLICABLE

19. RTB Undervoltage and Shunt Trip Mechanisms NOT APPLICABLE

20. Automatic Trip Logic NOT APPLICABLE Beaver Valley Unit 1 3.3.1 - 2 LRM Revision 105

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 TABLE NOTATION (1) Neutron detectors are exempt from response time testing. Response time shall be measured from detector output or input of first electronic component in channel.

(2) Refer to Table 3.3.1-1.a for required response times.

Beaver Valley Unit 1 3.3.1 - 3 LRM Revision 56

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

Combined 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 assumed in the safety analysis for 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 1 3.3.1 - 4 LRM Revision 56

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 1 3.3.2 - 1 LRM Revision 56

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 Rx Plant River 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) :s; 3.0

c. Feedwater Isolation

1) Feedwater Regulating Valves :s; 10.0(6)

2) Feedwater Bypass Valves :s; 30.0(6)

3) Feedwater Isolation Valves :s; 10.0(6)

d. Containment Isolation-Phase "A" :s; 22.0(8)/33.0(7)

e. Auxiliary Feedwater Pumps :s; 60.0

f. Rx Plant River Water System :s; 77.0(8)/110.0(7)

Beaver Valley Unit 1 3.3.2 - 2 LRM Revision 56

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(10)/27.0(3)/27.0(4)

b. Reactor Trip (from SI) 3.0

c. Feedwater Isolation

1) Feedwater Regulating Valves 10.0(6)

2) Feedwater Bypass Valves 30.0(6)

3) Feedwater Isolation Valves 10.0(6)

d. Containment Isolation-Phase "A" 22.0(8)

e. Auxiliary Feedwater Pumps 60.0

f. Rx Plant River Water System 77.0(8)/110.0(7)

4. Steam Line Pressure-Low

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

b. Reactor Trip (from SI) 3.0

c. Feedwater Isolation

1) Feedwater Regulating Valves 10.0(6)

2) Feedwater Bypass Valves 30.0(6)

3) Feedwater Isolation Valves 10.0(6)

d. Containment Isolation-Phase "A" 22.0(8)/33.0(7)

e. Auxiliary Feedwater Pumps 60.0

f. Rx Plant River Water System 77.0(8)/110.0(7)

g. Steam Line Isolation 8.0(11)

5. Containment Pressure-High High

a. Containment Quench Spray 43.9(9)

b. Containment Isolation-Phase "B" Not Applicable

c. Control Room Ventilation Isolation (on CIB) 22.0(8)/77.0(7)

d. Recirculation Spray Not Applicable Beaver Valley Unit 1 3.3.2 - 3 LRM Revision 64

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

6. Steam Generator Water Level-High High

a. Turbine Trip-Reactor Trip Not Applicable

b. Feedwater Isolation

1) Feedwater Regulating Valves 10.0(6)

2) Feedwater Bypass Valves 30.0(6)

3) Feedwater Isolation Valves 10.0(6)

7. Containment Pressure-Intermediate High High

a. Steam Line Isolation :s; 8.0(11)

8. Steamline Pressure Rate-High Negative

a. Steamline Isolation :s; 8.0(11)

9. Loss of Power (TS 3.3.5)

a. 4.16kv Emergency Bus Undervoltage :s; 1.3 (Loss of Voltage)

b. 4.16kv and 480v Emergency Bus Undervoltage :s; 95 (Degraded voltage)

10. Steam Generator Water Level-Low Low

a. Motor-driven Auxiliary :s; 60.0 Feedwater Pumps(2)

b. Turbine-driven Auxiliary :s; 60.0 Feedwater Pump(1)

11. Undervoltage RCP

a. Turbine-driven Auxiliary :s; 60.0 Feedwater Pump

12. Trip of Main Feedwater Pumps

a. Motor-driven Auxiliary :s; 60.0 Feedwater Pumps Beaver Valley Unit 1 3.3.2 - 4 LRM Revision 56

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 any Steam Generator (2) on 2/3 in 2/3 Steam Generators (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 isolation includes signal response and valve closure time. Valve isolation times shall be limited such that when added to the actuation circuitry time the total response time does not exceed the applicable limit specified for Feedwater Isolation on Table 3.3.2-1.

(7) Diesel generator starting and sequence loading delays included.

(8) Diesel generator starting and sequence loading delays not included.

(9) Diesel generator starting and sequence loading delays included. This response time also includes pump total start time (pump acceleration, begin to deliver flow, etc.) and time to fill the spray piping with water. The maximum allowable isolation valve stroke time is included in the Quench Spray analysis of record. NOTE that the containment Quench Spray isolation valve [MOV-1QS-101A,B] stroke time is specified in LRM Table 3.6.1-1 "Containment Penetrations."

(10) 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.

(11) The MSIV isolation time shall be limited to 5 seconds.

Beaver Valley Unit 1 3.3.2 - 5 LRM Revision 56

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 8.1 Prepare and present a 30 days meteorological monitoring report to the onsite safety channels Nonfunctional for review committee for their more than 7 days. review outlining the cause of the malfunction and the plans for restoring the channel(s) to FUNCTIONAL status.

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 1 3.3.3 - 1 LRM Revision 71

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' +/- 50 1

b. Nominal Elev. 150' +/- 50 1

c. Nominal Elev. 35' +/- 50 1

3. AIR TEMPERATURE T

a. T Elev. 500' - 35' +/- 0.1 0 C 1

b. T Elev. 150' - 35' +/- 0.1 0 C 1

Starting speed of anemometer shall be < 1 mph.

Beaver Valley Unit 1 3.3.3 - 2 LRM Revision 56

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 Once per 30 minutes thereafter Beaver Valley Unit 1 3.3.4 - 1 LRM Revision 71

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 1 3.3.5 - 1 LRM Revision 71

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 8.1 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 1 3.3.6 - 1 LRM Revision 71

Licensing Requirements Manual Seismic Monitoring Instrumentation 3.3.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Seismic event ::?: 0.01 g. 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 1 3.3.6-2 LRM Revision 71

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(a) INSTRUMENTS

1. Triaxial Force Balance Accelerometers

a. Containment Foundation (BV-XT-1ER-105A) +/-1g 1(b)

b. Charging Floor - Containment Structure +/-1g 1(b)

(BV-XT-1ER-105B)

c. Auxiliary Building (BV-XT-1ER-105C) +/-1g 1(b)

d. N.W. Corner of Control Room +/-1g 1(b)

(BV-XT-1ER-105D)

2. Peak Recording Accelerometers

a. Top of Recirculation Spray Cooler +/-1g 1 (BV-PRA-1ER-103-1)

b. Recirculation Spray Pump +/-1g 1 (BV-PRA-1ER-103-2)

c. RHR Heat Exchanger (BV-PRA-1ER-103-3) +/-1g 1

d. Primary Plant CCW H.X. (BV-PRA-1ER-103-4) +/-1g 1

3. High Dynamic Accelerograph

a. Top Floor of Auxiliary Building 0 - 1.2 g 1 (BV-XR-1ER-102)

4. Response Spectrum Analyzer

a. Control Room (BV-1ER-RSA-1) N/A 1 (a) Measurement range tolerance is +/- 5% of upper range value (b) With reactor control room indication Beaver Valley Unit 1 3.3.6 - 3 LRM Revision 96

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 Force Balance Accelerometers

a. Containment Foundation M R SA (BV-XT-1ER-105A)

b. Charging Floor - Containment Structure M R SA (BV-XT-1ER-105B)

c. Auxiliary Building (BV-XT-1ER-105C) M R SA

d. N.W. Corner of Control Room M R SA (BV-XT-1ER-105D)

2. Peak Recording Accelerometers

a. Top of Recirculation Spray Cooler N/A R N/A (BV-PRA-1ER-103-1)

b. Recirculation Spray Pump N/A R N/A (BV-PRA-1ER-103-2)

c. RHR Heat Exchanger N/A R N/A (BV-PRA-1ER-103-3)

d. Primary Plant CCW H.X. N/A R N/A (BV-PRA-1ER-103-4)

3. High Dynamic Accelerograph

a. Top Floor of Auxiliary Building M R SA (BV-XR-1ER-102)

4. Response Spectrum Analyzer

a. Control Room (BV-1ER-RSA-1) N/A N/A R M = 31 days R = 18 months SA = 184 days Beaver Valley Unit 1 3.3.6 - 4 LRM Revision 96

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 detector 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 FNH 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 FNH 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 1 3.3.7 - 1 LRM Revision 91

Licensing Requirements Manual Movable lncore 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 F~H and Fo(Z).

Beaver Valley Unit 1 3.3.7-2 LRM Revision 90

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 8.1 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 8.2 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 8.3 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 1 3.3.8 - 1 LRM Revision 71

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 1 3.3.8 - 2 LRM Revision 92

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 8.1 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 8.2 Isolate the turbine from the 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months steam supply.

OR 8.3 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 1 3.3.9 - 1 LRM Revision 71

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 1 3.3.9-2 LRM Revision 74

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 40 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 1 3.3.9 - 3 LRM Revision 56

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 1 3.3.10 - 1 LRM Revision 56

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% of 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% of RATED THERMAL POWER

5. Source Range, Neutron Flux 105 counts per second

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

7. Overpower T See Technical Specification Table Notation 2 on Table 3.3.1-1

8. Pressurizer

a. Pressure-Low 1945 psig

b. Pressure-High 2385 psig

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

10. Reactor Coolant Flow-Low 90.2% 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 19.6% of narrow range instrument span (b)

(a) The Unit 1 Setpoint Methodology used to establish the Reactor Trip System Setpoints is defined in WCAP-11419.

(b) The predefined as-found acceptance criteria band, and the as-left setpoint tolerance band is +/- 0.5% span.

Beaver Valley Unit 1 3.3.10 - 2 LRM Revision 56

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(c) TRIP SETPOINT(a)

15. Turbine Trip

a. Auto stop oil pressure 47.6 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% RATED THERMAL POWER

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

e. Power Range Neutron Flux, P-10 10% 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 1 Setpoint Methodology used to establish the Reactor Trip System Setpoints is defined in WCAP-11419.

(c) With the exception of Functional Unit number 15.b.

Beaver Valley Unit 1 3.3.10 - 3 LRM Revision 67

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 N.A.

c. Containment Pressure - High 5.0 psig(b)

d. Pressurizer Pressure - Low 1845 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 N.A.

Actuation Relays

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

b. Recirculation Spray

1. Automatic Actuation Logic and N.A.

Actuation Relays

2. Refueling Water Storage Tank 27 feet 7.5 inches(e)

(RWST) 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 1 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System Setpoints is defined in WCAP-11419.

(b) The predefined as-found acceptance band, and the as-left setpoint tolerance is +/- 0.33 psig.

(c) Time constants utilized in the lead-lag controllers for Steam Line Pressure-Low are

't 1 ~ 50 seconds and 2 5 seconds. CHANNEL CALIBRATION shall ensure that these time constants are adjusted to these values.

(e) The predefined as-found acceptance band, and the as-left setpoint tolerance is +/- 3.5 inches.

Beaver Valley Unit 1 3.3.10 - 4 LRM Revision 61

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

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. N.A. for Unit 1

b. Automatic Actuation Logic and Actuation N.A.

Relays

c. Containment Pressure-Intermediate 7.0 psig(b)

High High

d. Steamline 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 89.7% 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 1 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System Setpoints is defined in WCAP-11419.

(b) The predefined as-found acceptance band, and the as-left setpoint tolerance is +/- 0.33 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 the as-left setpoint tolerance band is

+/- 0.5% span.

Beaver Valley Unit 1 3.3.10 - 5 LRM Revision 61

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 19.6% of narrow range instrument span (d)

c. Safety Injection (Start All Auxiliary See Function 1 above for all Safety Injection Feedwater Pumps) 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 - 14 feet 1/2 inch(e)

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

8. ESF INTERLOCKS

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

b. Pressurizer Pressure, P-11 2000 psig

c. Low-Low Tavg, P-12 5410 F (a) The Unit 1 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System Setpoints is defined in WCAP-11419.

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

+/- 0.5% span.

(e) The predefined as-found acceptance band, and the as-left setpoint tolerance is +/- 3.5 inches.

Beaver Valley Unit 1 3.3.10 - 6 LRM Revision 61

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 < 0.9 second time delay (includes auxiliary relay times)

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

3. 4160V Emergency Bus Separation 3897.9 V with a 90 +/- 5 second time delay

4. 480V Emergency Bus Separation 449.8 V with a 90 +/- 5 second time delay (a) The Unit 1 Setpoint Methodology used to establish the Engineered Safety Feature Actuation System Setpoints is defined in WCAP-11419.

Beaver Valley Unit 1 3.3.10 - 7 LRM Revision 56

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 (RM-207) shall be FUNCTIONAL with:

a. Setpoint of::;; 15 mR/hr above background, and

b. Measurement range of 10 104 mR/hr.

APPLICABILITY: With fuel in the storage pool or building.

ACTION 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 8.1 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 1 3.3.11 - 1 LRM Revision 71

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 Waste Gas Decay Tanks Oxygen Monitor (O 2 - AS-GW-110-1,2) 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 1 3.3.12 - 1 LRM Revision 56

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 1 3.3.12 - 2 LRM Revision 56

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 8.1 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 1 3.3.13-1 LRM Revision 71

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 (RM-RM-218 A & B) shall be FUNCTIONAL with:

a. Setpoint of::;; 0.47 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 radiation 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months monitor Nonfunctional.

B. One radiation monitor 8.1 Verify the corresponding 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Nonfunctional. Unit 2 control room radiation monitor (same AND train) is FUNCTIONAL.

Once per 31 days thereafter C. Required Action and C. 1 Restore the Nonfunctional 7 days Associated Completion Unit 1 or required Unit 2 Time of Condition B not radiation monitor to met. FUNCTIONAL status.

OR C.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.

Beaver Valley Unit 1 3.3.14-1 LRM Revision 71

Licensing Requirements Manual Control Room Isolation Radiation Monitors 3.3.14 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two Unit 1 radiation D. 1 Verify both the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months monitors Nonfunctional. corresponding Unit 2 control room radiation AND monitors are FUNCTIONAL. Once per 31 days thereafter E. Required Action and E.1 Restore the Nonfunctional 7 days Associated Completion Unit 1 or Unit 2 monitor(s)

Time of Condition D not to FUNCTIONAL status.

met with one Unit 2 control room radiation monitor OR Nonfunctional.

E.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.

F. Required Action and F.1 Isolate the combined Immediately Associated Completion control room by closing all Time of Condition D not series normal air intake met with two Unit 2 control and exhaust isolation room radiation monitors dampers for both Unit 1 Nonfunctional. and Unit 2.

Beaver Valley Unit 1 3.3.14 - 2 LRM Revision 71

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 -------------------------------------------------------------------------

- NOTE -

Control Room intake and exhaust isolation dampers are not actuated.

Perform a CHANNEL OPERATIONAL TEST. 92 days LRS 3.3.14.3 Perform a CHANNEL CALIBRATION. 18 months Beaver Valley Unit 1 3.3.14 - 3 LRM Revision 66

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 (RM-RM-219A &

B) shall be FUNCTIONAL with:

a. Setpoints of::;; 1.5 x 104 R/hr above background, and

b. Measurement range of 1 - 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 8.1 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 1 3.3.15-1 LRM Revision 71

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 1 3.3.15 - 2 LRM Revision 56

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

- NOTE -

Not applicable to Function 1.

A One or more Functions A.1 Restore the Nonfunctional 30 days with one required channel channel(s) to FUNCTIONAL Nonfunctional. status.

B. One or more Functions 8.1 Restore at least one 7 days with two required channel to FUNCTIONAL channels Nonfunctional. status.

OR One Function 1 channel Nonfunctional.

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

Beaver Valley Unit 1 3.3.16-1 LRM Revision 71

Licensing Requirements Manual Accident Monitoring Instrumentation 3.3.16 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.16.1 Perform a CHANNEL CHECK. 31 days LRS 3.3.16.2 Perform a CHANNEL CALIBRATION. 18 months Beaver Valley Unit 1 3.3.16 - 2 LRM Revision 56

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 Acoustical Detector Position Indicator 2 per valve (1)

(1) One Detector Active, Second Detector Passive Beaver Valley Unit 1 3.3.16 - 3 LRM Revision 56

Licensing Requirements Manual Containment Purge & Exhaust Isolation Radiation Monitors 3.3.17 3.3 INSTRUMENTATION 3.3.17 Containment Purge & Exhaust Isolation Radiation Monitors LR 3.3.17 Two Containment Purge & Exhaust Isolation Radiation Monitors (RM-VS-104 A & B) shall be FUNCTIONAL with:

a. Setpoint of::;; 1.6 x 103 cpm above background, and

b. Measurement range of 10 - 106 cpm.

APPLICABILITY: During movement of recently irradiated fuel assemblies within the containment, During movement of fuel assemblies over recently irradiated fuel assemblies within the containment.

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 or more monitors 8.1 Close the containment Immediately Nonfunctional. purge and exhaust penetrations.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.3.17.1 Perform a CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months LRS 3.3.17 .2 Perform a CHANNEL OPERATIONAL TEST. 31 days LRS 3.3.17.3 Perform a CHANNEL CALIBRATION. 18 months Beaver Valley Unit 1 3.3.17-1 LRM Revision 71

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 isolation valve operators.

Beaver Valley Unit 1 3.4.1 - 1 LRM Revision 56

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 8.1 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 1 3.4.2 - 1 LRM Revision 71

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 MODE4 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 1 3.4.2 - 2 LRM Revision 72

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 0 F.

Beaver Valley Unit 1 3.4.2 - 3 LRM Revision 56

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 differential temperature of 320°F, and

d. A maximum auxiliary spray water differential temperature of 320°F.

APPLICABILITY: At all times.

ACTIONS

- NOTE -

Separate condition entry is allowed for each pressurizer temperature limit.

CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer heatup-rate A.1 limit exceeded, - NOTE -

Required Action A.1 is only applicable to pressurizer heatup rate and cooldown rate limit(s).

Restore rate to within the 30 minutes limit(s).

OR AND Beaver Valley Unit 1 3.4.3 - 1 LRM Revision 77

Licensing Requirements Manual Pressurizer 3.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME Pressurizer cooldown-rate A.2 limit exceeded, - NOTE -

Required Action A.2 is only applicable to pressurizer normal and auxiliary spray water differential temperature limit(s).

Restore differential 30 minutes temperature to within the limit(s).

OR AND Pressurizer normal spray A.3 Perform an engineering 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months water differential evaluation to determine the temperature limit effects of the out-of-limit exceeded, condition on the structural integrity of the pressurizer.

OR AND Pressurizer auxiliary spray A.4 Determine that the 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months water differential pressurizer remains temperature limit exceeded acceptable for continued by more than 60°F. operation.

B. Pressurizer auxiliary spray B.1 Restore differential 30 minutes water differential temperature to within the temperature limit exceeded limit(s).

by less than or equal to 60°F.

AND B.2 Notify Design Engineering 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months to include the event in Cycle Counting.

C. Required Action and C. 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 C.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 1 3.4.3 - 2 LRM Revision 77

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 1 3.4.3 - 3 LRM Revision 77

Licensing Requirements Manual 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 DELETED Beaver Valley Unit 1 3.4.4 - 1 LRM Revision 71

Licensing Requirements Manual RCS Vents 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Vents LR 3.4.5 All power operated RCS vent valves shall be FUNCTIONAL and closed for each vent path from the following locations:

a. Reactor Vessel Head

b. Pressurizer Steam Space

- 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.

3. A FUNCTIONAL RCS vent valve may be opened in MODES 1 and 2 under administrative control provided the redundant in series valves are maintained closed.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A A.1

- NOTE - - NOTE -

Separate Condition entry is Power operation may allowed for each location. continue and entry into MODES 1-4 is not restricted until the next One or more locations with scheduled outage, at which one vent path time all RCS vent valves Nonfunctional. shall be FUNCTIONAL prior to entry into MODE 1.

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

Beaver Valley Unit 1 3.4.5 - 1 LRM Revision 71

Licensing Requirements Manual RCS Head Vents 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. All vent paths from one of B.1 Maintain the Nonfunctional Immediately the above locations valves closed with power Nonfunctional. removed or with the manual isolation valves closed.

AND B.2.1 Restore at least one of the 30 days Nonfunctional vent paths to FUNCTIONAL status.

OR B.2.2 Apply LR 3.0.3. 30 days C. Three vent paths from the C. 1 Maintain the Nonfunctional Immediately above locations valves closed with power Nonfunctional. removed or with the manual isolation valves closed.

AND C.2.1 Restore at least one of the 21 days Nonfunctional vent paths to FUNCTIONAL status.

OR C.2.2 Apply LR 3.0.3. 21 days D. All vent paths from both of D. 1 Maintain the Nonfunctional Immediately the above locations valves closed with power Nonfunctional. removed or close the manual isolation valves.

AND D.2.1 Restore at least one vent 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months path from one of the above locations to FUNCTIONAL status.

OR D.2.2 Apply LR 3.0.3. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Beaver Valley Unit 1 3.4.5 - 2 LRM Revision 71

Licensing Requirements Manual RCS Head Vents 3.4.5 LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.4.5.1 Each RCS vent path shall be demonstrated 18 months FUNCTIONAL by:

a. Verifying all manual isolation valves in each vent path are 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 vent path to the Pressurizer Relief Tank.

Beaver Valley Unit 1 3.4.5 - 3 LRM Revision 71

Licensing Requirements Manual Pressurizer Safety Valve Lift Involving Liquid Water Discharge 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 Pressurizer Safety Valve Lift Involving Liquid Water Discharge LR 3.4.6 The OPERABILITY of pressurizer safety valve(s) shall be evaluated after having discharged liquid water from a water solid pressurizer to mitigate an overpressure event.

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) having discharged liquid water AND from a water solid pressurizer to mitigate an A.2 Be in MODE 4 with any 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months overpressure event. 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 1 3.4.6 - 1 LRM Revision 71

Licensing Requirements Manual Pressurizer Safety Valve Lift Involving Liquid 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 1 3.4.6 - 2 LRM Revision 56

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 1 3.4.7 - 1 LRM Revision 56

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 1, Cold leg, LHSI SI-23 (1)(2)

SI-12 (1)(2)

Loop 2, Cold leg, LHSI SI-24 (1)(2)

SI-11 (1)(2)

Loop 3, Cold leg, LHSI SI-25 (1)(2)

SI-10 (1)(2)

Loop 1, Hot leg, LHSI SI-15 (1)

Loop 2, Hot leg, LHSI SI-16 (1)

Loop 3, Hot leg, LHSI SI-17 (1)

Common, Hot leg, LHSI SI-13 SI-14 Loop 1, Cold leg, SIACC SI-48 (1)

SI-51 (1)

Loop 2, Cold leg, SIACC SI-49 (1)

SI-52 (1)(2)

Loop 3, Cold leg, SIACC SI-50 (1)

SI-53 (1)(2)

Loop 1, Hot leg, RHS MOV-RH-700 (1)

MOV-RH-701 (1)

Loop 2, Cold leg, RHS MOV-RH-720A (1)

Loop 3, Cold leg, RHS MOV-RH-720B (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 1 3.4.7 - 2 LRM Revision 56

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 1 3.6.1 - 1 LRM Revision 56

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

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 1 CCR to RHS Hx 1A & RHS Pump (1)MOV-1CC-112A2 N/A 1CCR-247 N/A 1A Seal Cooler RV-1CC-261 N/A 2 CCR from RHS Hx 1B & RHS (1)MOV-1CC-112B3 N/A 1CCR-252 N/A Pump 1B Seal Cooler RV-1CC-262 N/A 3 Does not exist 4 CCR from RHS Hx 1A & RHS (1)MOV-1CC-112A3 N/A 1CCR-251 N/A Pump 1A Seal Cooler RV-1CC-264 N/A 5 CCR to RHS Hx 1B & RHS Pump (1)MOV-1CC-112B2 N/A 1CCR-248 N/A 1B Seal Cooler RV-1CC-263 N/A 6 Spare 7 High Head SI to Hot Legs (2)(8)1SI-83 N/A (2)(8)MOV-1SI-869A N/A 8 CCR from RCP 1B & 1C Thermal (B)TV-1CC-107D1 < 60 (B)TV-1CC-107D2 < 60 Barriers RV-1CC-265 N/A 9 CCR from Shroud Coolers (B)TV-1CC-111D1 < 60 (B)TV-1CC-111D2 < 60 RV-1CC-266 N/A 10 Spare 11 Air Recirc. Cooling Water-Out (B)TV-1CC-110D < 60 (B)TV-1CC-110F2 < 60 RV-1CC-267 N/A (B)TV-1CC-110F1 < 60 12 Spare Beaver Valley Unit 1 3.6.1 - 2 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 2 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 13 Deluge System to CNMT Hose Reels 1FP-827 N/A (A)TV-1FP-107 15 14 Air Recirc. Cooling Water-In (B)TV-1CC-110E3 < 60 (B)TV-1CC-110E2 < 60 RV-1CC-268 N/A 15 Coolant System Charging (2)(8)1CH-31 N/A (2)(8)MOV-1CH-289 15 16 CCR to Shroud Coolers (B)TV-1CC-111A2 < 60 (B)TV-1CC-111A1 < 60 RV-1CC-269 N/A 17 CCR to RCP 1B (B)TV-1CC-103B1 < 60 (B)TV-1CC-103B < 60 RV-1CC-270 N/A 18 CCR to RCP 1C (B)TV-1CC-103C1 < 60 (B)TV-1CC-103C < 60 RV-1CC-271 N/A 19 RCP's Seal Water Return (A)MOV-1CH-378 < 60 (A)MOV-1CH-381 < 60 1CH-369 N/A 20 SI Accum. Makeup 1SI-42 N/A 1SI-41 N/A 21 Spare 22 Spare 23 Spare 24 RHS to RWST 1RH-14 N/A 1RH-15 N/A 1RH-16 N/A Beaver Valley Unit 1 3.6.1 - 3 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 3 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 25 CCR from RCP 1B & 1C Motors (B)TV-1CC-105D1 < 60 (B)TV-1CC-105D2 < 60 RV-1CC-272 N/A 26 CCR from RCP 1A Thermal Barrier (B)TV-1CC-107E1 < 60 (B)TV-1CC-107E2 < 60 RV-1CC-273 N/A 27 CCR from RCP 1A Motor (B)TV-1CC-105E1 < 60 (B)TV-1CC-105E2 < 60 RV-1CC-274 N/A 28 RCS Letdown (A)TV-1CH-200A < 60 (A)TV-1CH-204 < 60 (A)TV-1CH-200B < 60 (A)TV-1CH-200C < 60 (1)MOV-1CH-142 N/A RV-1CH-203 N/A 29 Primary Drain Transfer Pump #1 (A)TV-1DG-108A < 60 (A)TV-1DG-108B < 60 Discharge RV-1DG-102 N/A 30 Spare 31 Deluge System to Cable Penetration 1FP-804 N/A (A)TV-1FP-105 15 Area 32 Deluge System to RHR Area 1FP-800 N/A (A)TV-1FP-106 15 33 High Head SI to Hot Legs (2)(8)1SI-84 N/A (2)(8)MOV-1SI-869B N/A 34 Spare Beaver Valley Unit 1 3.6.1 - 4 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 4 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 35 Seal Injection Water RCP 1A (2)(8)1CH-181 N/A (2)(8)MOV-1CH-308A N/A 36 Seal Injection Water RCP 1B (2)(8)1CH-182 N/A (2)(8)MOV-1CH-308B N/A 37 Seal Injection Water RCP 1C (2)(8)1CH-183 N/A (2)(8)MOV-1CH-308C N/A 38 Containment Sump Pump Discharge (A)TV-1DA-100A < 60 (A)TV-1DA-100B < 60 RV-1DA-101 N/A 39 Steam Generator 1A Blowdown Closed System N/A (2)(A)TV-1BD-100A < 60 40 Steam Generator 1B Blowdown Closed System N/A (2)(A)TV-1BD-100B < 60 41 Steam Generator 1C Blowdown Closed System N/A (2)(A)TV-1BD-100C < 60 42 Compressed Air to Containment 1SA-15 N/A 1SA-14 N/A 43 Air Activity Monitor Return to (A)TV-1CV-102-1 < 60 (A)TV-1CV-102 < 60 Containment 44 Containment to Air Activity Monitor (A)TV-1CV-101A < 60 (A)TV-1CV-101B < 60 45 Primary Grade Water to PRT 1RC-72 N/A (A)TV-1RC-519 < 60 46 Charging Fill Header (2)(8)1CH-170 N/A (2)(1)(8)FCV-1CH-160 N/A 47 Instrument Air 1IA-91 N/A 1IA-90 N/A (B)TV-1IA-400 < 60 Beaver Valley Unit 1 3.6.1 - 5 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 5 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 48 Primary Vent Header (A)TV-1DG-109A2 < 60 (A)TV-1DG-109A1 < 60 49 Nitrogen Supply to PRT 1RC-68 N/A (A)TV-1RC-101 < 60 50 Spare 51 Spare 52 Spare 53 Nitrogen Supply to SI Accumulators (A)TV-1SI-101-2 5 (A)TV-1SI-101-1 5 54 Spare 55-1 SI Accumulator Sample (A)TV-1SS-109A1 < 60 (A)TV-1SS-109A2 < 60 RV-1SS-605 N/A 55-2 CNMT Leakage Monitoring Open Taps (12)1CV-60 and N/A Associated Cap 55-3 Spare 55-4 PRT Gas Sample (A)TV-1SS-111A1 < 60 (A)TV-1SS-111A2 < 60 56-1 Pressurizer Liquid Sample (A)TV-1SS-100A1 < 60 (A)TV-1SS-100A2 < 60 RV-1SS-608 N/A 56-2 RCS Cold Leg Sample (A)TV-1SS-102A1 < 60 (A)TV-1SS-102A2 < 60 RV-1SS-606 N/A Beaver Valley Unit 1 3.6.1 - 6 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 6 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 56-3 RCS Hot Leg Samples (A)TV-1SS-105A1 < 60 (A)TV-1SS-105A2 < 60 RV-1SS-609 N/A 56-4 STM GEN 1A Blowdown Sample Closed System N/A (2)(A)TV-1SS-117A < 60 57-1 CNMT Leakage Monitoring Open Taps (12)1CV-58 and N/A Associated Cap 57-2 CNMT Leakage Monitoring Open Taps (12)1CV-57 and N/A Associated Cap 57-3 Spare 57-4 Spare 58 CCR to RCP 1A (B)TV-1CC-103A1 < 60 (B)TV-1CC-103A < 60 RV-1CC-275 N/A 59 Spare 60 Low Head SI to Hot Legs (2)(8)1SI-13 N/A (2)(8)MOV-1SI-890A N/A 61 Low Head SI to Cold Legs (2)(8)1SI-10 N/A (2)(8)MOV-1SI-890C N/A (2)(8)1SI-11 N/A (2)(8)1SI-12 N/A 62 Low Head SI to Hot Legs (2)(8)1SI-14 N/A (2)(8)MOV-1SI-890B N/A 63 QSP Discharge 360 Header 1QS-4 N/A (B)MOV-1QS-101B 75(4) 0 64 QSP Discharge 360 Header 1QS-3 N/A (B)MOV-1QS-101A 75(4) 0 Beaver Valley Unit 1 3.6.1 - 7 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 7 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 65 Fuel Transfer Tube (7)Flange N/A (6)1FH-1 N/A 66 Outside RSP 2A Suction from CNMT (B)(2)MOV-1RS-155A 75(4) 67 Outside RSP 2B Suction from CNMT (B)(2)MOV-1RS-155B 75(4) 68 Low Head SI Pump 1A Suction from (9)(2)(8)MOV-1SI-860A N/A CNMT Sump 69 Low Head SI Pump 1B Suction from (9)(2)(8)MOV-1SI-860B N/A CNMT Sump 70 Outside RSP 2B Discharge 1RS-101 N/A (B)(2)MOV-1RS-156B 75(4) 71 Outside RSP 2A Discharge 1RS-100 N/A (B)(2)MOV-1RS-156A 75(4) 72 Spare 73 Main Steam Loop 1A Bypass Closed System N/A (14)(2)MOV-1MS-101A N/A Main Steam Loop 1A Closed System N/A (2)TV-1MS-101A 5(10)

Main Steam Line Drain Closed System N/A (2)TV-1MS-111A 10 Main Steam to Aux. Feed Pump Closed System N/A (2)MOV-1MS-105 N/A Main Steam Atmospheric Dump Closed System N/A (6)PCV-1MS-101A N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-101A N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-102A N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-103A N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-104A N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-105A N/A Main Steam Residual Heat Closed System N/A (6)HCV-MS-104 N/A Release Beaver Valley Unit 1 3.6.1 - 8 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 8 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 74 Main Steam Loop 1B Bypass Closed System N/A (14)(2)MOV-1MS-101B N/A Main Steam Loop 1B Closed System N/A (2)TV-1MS-101B 5(10)

Main Steam Line Drain Closed System N/A (2)TV-1MS-111B 10 Main Steam to Aux. Feed Pump Closed System N/A (2)MOV-1MS-105 N/A Main Steam Atmospheric Dump Closed System N/A (6)PCV-1MS-101B N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-101B N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-102B N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-103B N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-104B N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-105B N/A Main Steam Residual Heat Closed System N/A (6)HCV-MS-104 N/A Release 75 Main Steam Loop 1C Bypass Closed System N/A (14)(2)MOV-1MS-101C N/A Main Steam Loop 1C Closed System N/A (2)TV-1MS-101C 5(10)

Main Steam Line Drain Closed System N/A (2)TV-1MS-111C 10 Main Steam to Aux. Feed Pump Closed System N/A (2)MOV-1MS-105 N/A Main Steam Atmospheric Dump Closed System N/A (6)PCV-1MS-101C N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-101C N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-102C N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-103C N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-104C N/A Main Steam Safety Valve Closed System N/A (6)SV-MS-105C N/A Main Steam Residual Heat Closed System N/A (6)HCV-MS-104 N/A Release 76 FW Loop 1A Closed System N/A (2)HYV-1FW-100A 10(15)

Auxiliary Feedwater Loop 1A Closed System N/A (2)FW-42 N/A Beaver Valley Unit 1 3.6.1 - 9 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 9 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 77 FW Loop 1B Closed System N/A (2)HYV-1FW-100B 10(15)

Auxiliary Feedwater Loop 1B Closed System N/A (2)FW-43 N/A 78 FW Loop 1C Closed System N/A (2)HYV-1FW-100C 10(15)

Auxiliary Feedwater Loop 1C Closed System N/A (2)FW-44 N/A 79 RW to 1A RSP Hx Closed System N/A (2)MOV-1RW-104A N/A 80 RW to 1C RSP Hx Closed System N/A (2)MOV-1RW-104C N/A 81 RW to 1B RSP Hx Closed System N/A (2)MOV-1RW-104B N/A 82 RW to 1D RSP Hx Closed System N/A (2)MOV-1RW-104D N/A 83 RW from 1A RSP Hx Closed System N/A (2)MOV-1RW-105A N/A (2)1RW-615 N/A (2)RV-1RW-101A N/A 84 RW from 1C RSP Hx Closed System N/A (2)MOV-1RW-105C N/A (2)1RW-627 N/A (2)RV-1RW-101C N/A 85 RW from 1B RSP Hx Closed System N/A (2)MOV-1RW-105B N/A (2)1RW-621 N/A (2)RV-1RW-101B N/A 86 RW from 1D RSP Hx Closed System N/A (2)MOV-1RW-105D N/A (2)1RW-633 N/A (2)RV-1RW-101D N/A Beaver Valley Unit 1 3.6.1 - 10 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 10 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 87 H2 Discharge to CNMT N/A 1HY-111 N/A 1HY-197 N/A 88 H2 Discharge to CNMT N/A 1HY-110 N/A 1HY-196 N/A 89 Main Condenser Ejector Vent 1AS-278 N/A (B)TV-1SV-100A < 60 90 CNMT Purge Exhaust (11)VS-D-5-3B (5)8 (11)VS-D-5-3A (5)8 91 CNMT Purge Supply (11)VS-D-5-5B (5)11 (11)VS-D-5-5A (5)8 (11)VS-D-5-6 N/A 92 CNMT Vacuum Pump 1B & H2 (A)TV-1CV-150C <5 Recomb. Suction (A)TV-1CV-150D <5 1HY-102 N/A 1HY-104 N/A 93 CNMT Vacuum Pump 1A & H2 (A)TV-1CV-150A <5 Recomb. Suction (A)TV-1CV-150B <5 1HY-101 N/A 1HY-103 N/A 94 CNMT Vacuum Ejector Suction (11)HCV-1CV-151 N/A (11)HCV-1CV-151-1 N/A 95 RVLIS (3 lines) (2)(13) N/A 95-64 H2 Analyzer - CNMT Dome SOV-1HY-102B1 N/A SOV-1HY-102B2 N/A Beaver Valley Unit 1 3.6.1 - 11 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 11 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 95-69 H2 Analyzer - PRZR Cubicle SOV-1HY-103B1 N/A SOV-1HY-103B2 N/A 95-72 H2 Analyzer Discharge SOV-1HY-104B1 N/A SOV-1HY-104B2 N/A 96 High Head SI to Cold Legs (2)(8)1SI-95 N/A (2)(8)MOV-1SI-836 N/A 97-1 RHR Inlet Sample (A)TV-1SS-104A1 < 60 (A)TV-1SS-104A2 < 60 RV-1SS-610 N/A 97-2 RHR Outlet Sample (A)TV-1SS-103A1 < 60 (A)TV-1SS-103A2 < 60 RV-1SS-607 N/A 97-3 CNMT Leakage Monitoring Open Taps (12)1CV-59 and N/A Associated Cap 97-4 Steam Generator 1C Blowdown Closed System N/A (2)(A)TV-1SS-117C < 60 Sample 98-1 Spare 98-2 Spare 98-3 Spare 98-4 Spare 99 Spare 100 Spare Beaver Valley Unit 1 3.6.1 - 12 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 12 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 101 Spare 102 Spare 103 Purification Pump Discharge to 1PC-38 N/A 1PC-37 N/A Refueling Cavity 104 Refueling Cavity to Purification Pump 1PC-9 N/A 1PC-10 N/A Suction 105-1 Steam Generator 1B Blowdown Closed System N/A (2)(A)TV-1SS-117B < 60 Sample 105-2 PRZR Vapor Sample (A)TV-1SS-112A1 < 60 (A)TV-1SS-112A2 < 60 RV-1SS-611 N/A 105-3 Spare 105-4 Spare 106 SI Accumulator Test Line (A)MOV-1SI-842 < 60 (A)TV-1SI-889 < 60 107 Spare 108 Spare 109 RVLIS (3 lines) (2)(13) N/A Beaver Valley Unit 1 3.6.1 - 13 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 13 of 15)

CONTAINMENT PENETRATIONS MAXIMUM MAXIMUM PENT. STROKE TIME STROKE TIME No. IDENTIFICATION DESCRIPTION INSIDE VALVE (SEC) OUTSIDE VALVE (SEC) 109-44 Inlet Flow Sample - CNMT Dome SOV-1HY-102A1 N/A SOV-1HY-102A2 N/A 109-49 Inlet Flow Sample - PRZR Cubicle SOV-1HY-103A1 N/A SOV-1HY-103A2 N/A 109-52 Flow Sample Discharge SOV-1HY-104A1 N/A SOV-1HY-104A2 N/A 110-1 PRZR Dead Weight Calibrator N/A 1RC-277 N/A 1RC-278 N/A 110-2 Spare 110-3 Spare 110-4 Spare 111 Spare (7)Flange N/A (7)Flange N/A 112 Spare (7)Flange N/A (7)Flange N/A 113 BIT to Cold Legs (2)(8)1SI-94 N/A (2)(8)MOV-1SI-867C (4)15 (2)(8)MOV-1SI-867D (4)15 Beaver Valley Unit 1 3.6.1 - 14 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves 3.6.1 TABLE 3.6.1-1 (Page 14 of 15)

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

Primary Containment Airlock PH-P-1 Equalization Valve (1)(3)1VS-169 N/A Equalization Valve (1)(3)1VS-170 N/A Equalization Valve (1)(3)1VS-167 N/A Equalization Valve (1)(3)1VS-168 N/A Emergency Containment Airlock PH-P-2 Equalization Valve (1)(7)1VS-184 N/A Equalization Valve (1)(7)1VS-183 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) Tested individually by Type C Test. Leakage rates added to Air Lock Type B Test.

(4) Maximum opening time.

(5) When required by LR 3.9.4.

Beaver Valley Unit 1 3.6.1 - 15 LRM Revision 56

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

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 Technical Specifications 3.6.1 and 3.6.3.

Listed for information only.

(7) Tested under Type "B" testing.

(8) Subject to testing as per Technical Specification Amendment 65.

(9) Auto open on Safety Injection recirculation signal.

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

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

(12) Valve and associated cap replaced isolation function provided by TV-1LM-100A1 and TV-1LM-100A2.

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

(14) Only one main steam bypass valve is permitted to be open at a time in Modes 1, 2, and 3.

(15) 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.

Beaver Valley Unit 1 3.6.1 - 16 LRM Revision 56

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 1 3.6.2 - 1 LRM Revision 56

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 0 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 1 3.7.1 - 1 LRM Revision 56

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 695 Mean Sea Level. :s; 700 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 1 3.7.2 - 1 LRM Revision 81

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 1 3.7.3 - 1 LRM Revision 56

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 1 3.7.3 - 2 LRM Revision 56

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.

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 1 3.7.4 - 1 LRM Revision 71

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 1 3.7.4 - 2 LRM Revision 102

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 Between TV-CC-103B1 & TV-CC-CC-HSS-001A 6" CCR Supply line to RC-P-1B 105B/CCR-290 Yes 12 Between TV-CC-103B1 & TV-CC-CC-HSS-001B 6" CCR Supply line to RC-P-1B 105B/CCR-290 Yes 12 CC-HSS-021A 4" CCR Supply line to RCP motor Between TV-CC-105A & RC-P-1A Yes 12 CC-HSS-021B 4" CCR Supply line to RCP motor Between TV-CC-105A & RC-P-1A Yes 12 CC-HSS-401 Suction to CCR pump 1C Between CCR-309 & CCR-3 Yes 72 CC-HSS-402 Suction to CCR pump 1B Between CCR-309 & CCR-1 Yes 72 CC-HSS-403 Suction to CCR pump 1A Between CCR-309 & CCR-2 Yes 72 CC-HSS-404 CCR Discharge header Between CCR pumps & CCR Hx's Yes 12 CC-HSS-405 CCR Supply line to Non-regen. Hx Between TV-CC-130 & CH-E-2 Yes 12 CC-HSS-406A 18" CCR Supply header to RHR Between MOV-CC-112A2 & RH-E-1A Yes 72 CC-HSS-406B 18" CCR Supply header to RHR Between MOV-CC-112A2 & RH-E-1A Yes 72 CC-HSS-407A 18" CCR Supply header to RHR Between MOV-CC-112B2 & RH-E-1B Yes 72 CC-HSS-407B 18" CCR Supply header to RHR Between MOV-CC-112B2 & RH-E-1B Yes 72 CC-HSS-408 18" CCR Supply header to RHR Between MOV-CC-112B2 & RH-E-1B Yes 72 CC-PSSP-300A 24" CCR Supply header to RHR Between CCR-18 & CCR-247 Yes 12 CC-PSSP-300B 24" CCR Supply header to RHR Between CCR-18 & CCR-247 Yes 12 CC-PSSP-301 24" CCR Supply header to RHR Between CCR-18 & CCR-247/248 Yes 12 FC-HSS-201 Fuel Pool pump discharge to Hx Between PC-110 & FC-E-1A Yes 72 Beaver Valley Unit 1 3.7.4 - 3 LRM Revision 60

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 FC-HSS-5A Fuel Pool pump discharge to Hx Between PC-111 & FC-E-1B Yes 72 PS-243-VS-1 Charging line to Loop 1 Valve support to MOV-RC-556A Yes 72 PS-244-VS-1 Charging line to Loop 2 Valve support to MOV-RC-556B Yes 72 PS-245-VS-1 Charging line to Loop 3 Valve support to MOV-RC-556C Yes 72 QS-HSS-202 From QS-P-1B to Cnmt spray headers Between MOV-QS-103B & MOV-QS-101B No QS-HSS-205A From QS-P-1A to Cnmt spray headers Between MOV-QS-103A & MOV-QS-101A No QS-HSS-205B From QS-P-1A to Cnmt spray headers Between MOV-QS-103A & MOV-QS-101A No RC-HC-10B Upper S/G Restraint S/G RC-E-1B No RC-HC-10C Upper S/G Restraint S/G RC-E-1C No RC-HC-11A Upper S/G Restraint S/G RC-E-1A No RC-HC-12C Upper S/G Restraint S/G RC-E-1C No RC-HC-9A Upper S/G Restraint S/G RC-E-1A No RC-HC-9B Upper S/G Restraint S/G RC-E-1B No RC-HSS-1 4" PZR Spray line Between Loop3 cold leg & PCV-RC-455B. Yes 12 RC-HSS-101 8" Bypass line for Loop1 Valve support to MOV-RC-585 No RC-HSS-102 8" Bypass line for Loop1 Valve support to MOV-RC-585 No RC-HSS-103 8" Bypass line for Loop2 Valve support to MOV-RC-586 No RC-HSS-104 8" Bypass line for Loop2 Valve support to MOV-RC-586 No RC-HSS-105 8" Bypass line for Loop3 Valve support to MOV-RC-587 No Beaver Valley Unit 1 3.7.4 - 4 LRM Revision 60

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 RC-HSS-106 8" Bypass line for Loop3 Valve support to MOV-RC-587 No RC-HSS-119 12" Line from PZR to PRT Upstream of PRT in PRT Cub. No RC-HSS-126 PZR Code Safety Valve discharge line Downstream of RV-RC-551 C No RC-HSS-127 PZR Relief line from PORV Downstream of PCV-RC-455D No RC-HSS-130 8" Bypass line for Loop3 Support for vent RC-241 No RC-HSS-131 8" Bypass line for Loop3 Support for vent RC-241 No RC-HSS-2 4" PZR Spray line Between Loop3 cold leg & PCV-RC-455B. Yes 12 RC-HSS-23 4" PZR Spray line Between PCV-RC-455A/B & PZR Yes 12 RC-HSS-3 4" PZR Spray line Between Loop3 cold leg & PCV-RC-455B. Yes 12 RC-HSS-302 PZR Relief line to PORV Between MOV-RC-536 & PCV-RC-456 No RC-HSS-303A PZR Relief line from PORV Downstream of PCV-RC-456 No RC-HSS-303B PZR Relief line from PORV Downstream of PCV-RC-456 No RC-HSS-4 4" PZR Spray line Between Loop3 cold leg & PCV-RC-455B. Yes 12 RC-HSS-41A PZR Relief line to PORV Between PZR & MOV-RC-537 No RC-HSS-42A-A PZR Relief line to PORV Between PZR & MOV-RC-536 No RC-HSS-42A-B PZR Relief line to PORV Between PZR & MOV-RC-536 No RC-HSS-44A PZR Relief line from PORV Downstream of PCV-RC-456 No RC-PSSP-115 12" Line from PZR to PRT Downstream of PZR in PZR Cub. No RC-PSSP-116 12" Line from PZR to PRT Downstream of PZR in PZR Cub. No Beaver Valley Unit 1 3.7.4 - 5 LRM Revision 79

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 RC-PSSP-122A PZR Relief line to PORV Between PZR & MOV-RC-537 No RC-PSSP-122B PZR Relief line to PORV Between PZR & MOV-RC-537 No RC-PSSP-128 12" Line from PZR to PRT Upstream of PRT in PRT Cub. No RC-PSSP-129 12" Line from PZR to PRT Upstream of PRT in PRT Cub. No RC-PSSP-20 12" Line from PZR to PRT Upstream of PRT in PRT Cub. No RC-PSSP-24A PZR Code Safety Valve discharge line Downstream of RV-RC-551A No RC-PSSP-24B PZR Code Safety Valve discharge line Downstream of RV-RC-551A No RC-PSSP-25A PZR Code Safety Valve discharge line Downstream of RV-RC-551B No RC-PSSP-25B PZR Code Safety Valve discharge line Downstream of RV-RC-551B No RC-PSSP-301 PZR Relief line to PORV Between MOV-RC-535 & PCV-RC-455C No Between MOV-RH-758 & MOV-RH-RH-HSS-101 Downstream of RHR Hx's 720A/B Yes 12 Between MOV-RH-758 & MOV-RH-RH-HSS-102 Downstream of RHR Hx's 720A/B Yes 12 RH-HSS-105 Downstream of MOV-RH-701 Between MOV-RH-701 & RHR Pumps No RH-HSS-106 Upstream of MOV-RH-700 Between Loop1 Hot Leg & MOV-RH-700 No RH-HSS-107 Downstream of MOV-RH-701 Between MOV-RH-701 & RHR Pumps No RH-HSS-108 Downstream of MOV-RH-701 Between MOV-RH-701 & RHR Pumps No RH-HSS-109 Upstream of MOV-RH-700 Between Loop1 Hot Leg & MOV-RH-700 No Beaver Valley Unit 1 3.7.4 - 6 LRM Revision 60

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 RH-HSS-110 Upstream of MOV-RH-700 Between Loop1 Hot Leg & MOV-RH-700 No RH-HSS-111 Downstream of MOV-RH-701 Between MOV-RH-701 & RHR Pumps No RH-HSS-112 Upstream of MOV-RH-700 Between Loop1 Hot Leg & MOV-RH-700 No RH-HSS-113 Suction line to RHR Pump 1A Between MOV-RH-701 & RH-P-1A No RH-HSS-114 Suction line to RHR Pump 1B Between MOV-RH-701 & RH-P-1B No RH-HSS-121 At MOV-RH-720A Upstream of MOV-RH-720A Yes 72 RH-HSS-122 At MOV-RH-720A Upstream of MOV-RH-720A Yes 72 RH-HSS-123 At MOV-RH-720A Downstream of MOV-RH-720A Yes 72 RH-HSS-124 At MOV-RH-720A Downstream of MOV-RH-720A Yes 72 RH-HSS-203 6" line to QS-TK-1 Between containment penetration & RH-15 Yes 12 RH-HSS-204A 6" line to QS-TK-1 Between containment penetration & RH-15 Yes 12 RH-HSS-204B 6" line to QS-TK-1 Between containment penetration & RH-15 Yes 12 RH-HSS-402 6" line to QS-TK-1 Between RH-14 & containment penetration Yes 12 RH-HSS-403 6" line to QS-TK-1 Between RH-14 & containment penetration Yes 12 RS-HSS-201 10" Supply line to RS Hx 1A Between RS-P-1A & RS-E-1A No RS-HSS-202 10" Supply line to RS Hx 1A Between RS-P-1A & RS-E-1A No RS-HSS-209A 10" Supply line to RS Hx 1D Between RS-P-2B & MOV-RS-156B No RS-HSS-210A 10" Supply line to RS Hx 1C Between RS-P-2A & MOV-RS-156A No RS-HSS-219 From RS Hx 1D to Cnmt spray header Between RS-E-1D & Cnmt spray header No Beaver Valley Unit 1 3.7.4 - 7 LRM Revision 60

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 RS-HSS-220 From RS Hx 1D to Cnmt spray header Between RS-E-1D & Cnmt spray header No RS-HSS-221 From RS Hx 1D to Cnmt spray header Between RS-E-1D & Cnmt spray header No RS-HSS-229 10" Supply line to RS Hx 1B Between RS-P-1B & RS-E-1B No RS-HSS-234 4" Cross connect for RS-P-1A & 1B Between RS-102 & RS-103 No RS-HSS-237 10" Supply line to RS Hx 1A Between RS-P-1A & RS-E-1A No RS-HSS-238 10" Supply line to RS Hx 1A Between RS-P-1A & RS-E-1A No SHP-HSS-201 32" MS line from Stm Gen 1A Between RC-E-1A & Cnmt Pen #73 No SHP-HSS-202 32" MS line from Stm Gen 1A Between RC-E-1A & Cnmt Pen #73 No SHP-HSS-203 32" MS line from Stm Gen 1A Between RC-E-1A & Cnmt Pen #73 No SHP-HSS-204 32" MS line from Stm Gen 1A Between RC-E-1A & Cnmt Pen #73 No SHP-HSS-205 32" MS line from Stm Gen 1A Between RC-E-1A & Cnmt Pen #73 No SHP-HSS-206 32" MS line from Stm Gen 1A Between RC-E-1A & Cnmt Pen #73 No SHP-HSS-207 32" MS line from Stm Gen 1B Between RC-E-1B & Cnmt Pen #74 No SHP-HSS-208 32" MS line from Stm Gen 1B Between RC-E-1B & Cnmt Pen #74 No SHP-HSS-209 32" MS line from Stm Gen 1C Between RC-E-1C & Cnmt Pen #75 No SHP-HSS-210 32" MS line from Stm Gen 1C Between RC-E-1C & Cnmt Pen #75 No SHP-HSS-211 32" MS line from Stm Gen 1C Between RC-E-1C & Cnmt Pen #75 No SHP-HSS-212 32" MS line from Stm Gen 1C Between RC-E-1C & Cnmt Pen #75 No SHP-HSS-213 32" MS line from Stm Gen 1C Between RC-E-1C & Cnmt Pen #75 No Beaver Valley Unit 1 3.7.4 - 8 LRM Revision 60

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 SHP-HSS-214 32" MS line from Stm Gen 1C Between RC-E-1C & Cnmt Pen #75 No SHP-HSS-214A 32" MS line from Stm Gen 1C Between RC-E-1C & Cnmt Pen #75 No SI-HSS-114A SI-TK-1C discharge Between SI-50 & SI-53 No SI-HSS-114B SI-TK-1C discharge Between SI-50 & SI-53 No SI-HSS-212A Low Head SI to Cold Legs Between MOV-SI-864A/B & MOV-SI-890C No SI-HSS-212B Low Head SI to Cold Legs Between MOV-SI-864A/B & MOV-SI-890C No SI-HSS-409 Low Head SI to Loop2 cold leg Between MOV-SI-890C & SI-11 Yes 12 SI-HSS-410 Low Head SI to Loop1 cold leg Between MOV-SI-890C & SI-12 Yes 12 SI-HSS-411 Low Head SI to Loop1 cold leg Between MOV-SI-890C & SI-12 Yes 12 SI-HSS-412 Low Head SI to Loop1 cold leg Between SI-12 & SI-23 Yes 72 SI-HSS-413 Low Head SI to Loop1 cold leg Between SI-12 & SI-23 Yes 72 SI-HSS-414 Low Head SI to Loop1 cold leg Between SI-12 & SI-23 Yes 72 SI-HSS-415 Low Head SI to Loop1 cold leg Between SI-12 & SI-23 Yes 72 SI-HSS-416 Low Head SI to Loop2 cold leg Between SI-11 & SI-24 Yes 72 SI-HSS-417 Low Head SI to Loop2 cold leg Between SI-11 & SI-24 Yes 72 SI-HSS-418 Low Head SI to Loop2 cold leg Between SI-11 & SI-24 Yes 72 SI-HSS-419 Low Head SI to Loop2 cold leg Between SI-11 & SI-24 Yes 72 SI-HSS-420 Low Head SI to Loop3 cold leg Between SI-10 & SI-25 Yes 12 Beaver Valley Unit 1 3.7.4 - 9 LRM Revision 60

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 SI-HSS-421 Low Head SI to Loop3 cold leg Between SI-10 & SI-25 Yes 12 SI-HSS-422 Low Head SI to Loop3 cold leg Between SI-10 & SI-25 Yes 12 SI-HSS-423 Low Head SI to Loop3 cold leg Between SI-10 & SI-25 Yes 12 SI-HSS-511 From SI-P-1B to Charging Pumps Between MOV-SI-863B & CH-19, 20, 21 Yes 72 SI-HSS-512 From SI-P-1B to Charging Pumps Between MOV-SI-863B & CH-19, 20, 21 Yes 72 SI-HSS-512A From SI-P-1B to Charging Pumps Between MOV-SI-863B & CH-19, 20, 21 Yes 72 SI-HSS-514 From SI-P-1B to Charging Pumps Between MOV-SI-863B & CH-19, 20, 21 Yes 72 SI-HSS-515 From SI-P-1B to Charging Pumps Between MOV-SI-863B & CH-19, 20, 21 Yes 72 SI-HSS-516A From SI-P-1B to Charging Pumps Between MOV-SI-863B & CH-19, 20, 21 Yes 72 SI-HSS-516B From SI-P-1B to Charging Pumps Between MOV-SI-863B & CH-19, 20, 21 Yes 72 SI-HSS-517 From SI-P-1A to Charging Pumps Between MOV-SI-863A & CH-146/147/148 Yes 72 SI-HSS-518 From SI-P-1A to Charging Pumps Between MOV-SI-863A & CH-146/147/148 Yes 72 SI-HSS-519 From SI-P-1A to Charging Pumps Between MOV-SI-863A & CH-146/147/148 Yes 72 SI-HSS-520 From SI-P-1A to Charging Pumps Between MOV-SI-863A & CH-146/147/148 Yes 72 SI-HSS-521 From SI-P-1A to Charging Pumps Between MOV-SI-863A & CH-146/147/148 Yes 72 SI-HSS-522 From SI-P-1A to Charging Pumps Between MOV-SI-863A & CH-146/147/148 Yes 12 SI-HSS-523A From SI-P-1B to Charging Pumps Between MOV-SI-863B & CH-19, 20, 21 Yes 12 SI-HSS-523B From SI-P-1B to Charging Pumps Between MOV-SI-863B & CH-19, 20, 21 Yes 12 SI-PSSP-002 From RS pump to Charging pumps Between RS-P-2B & RS-159 No Beaver Valley Unit 1 3.7.4 - 10 LRM Revision 60

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 SI-PSSP-003 From RS pump to Charging pumps Between RS-P-2B & RS-159 No SI-PSSP-009 From RS pump to Charging pumps Between RS-P-2A & RS-157 No SI-PSSP-010 From RS pump to Charging pumps Between RS-P-2A & RS-157 No SI-PSSP-033A From SI-P-1B to Charging Pumps Between SI-7 & MOV-SI-863B No SI-PSSP-036A From SI-P-1A to Charging Pumps Between SI-6 & MOV-SI-863A No SI-PSSP-060D Low Head SI Pump discharge line Between SI-P-1A & SI-6 No SI-PSSP-067C Low Head SI Pump discharge line Between SI-P-1B & SI-7 No SI-PSSP-337 Low Head SI to Loop1 cold leg Between MOV-SI-890C & SI-12 Yes 12 VS-357-1 Drain line from Loop 1 Valve support to MOV-RC-557A Yes 72 VS-358-1 Drain line from Loop 2 Valve support to MOV-RC-557B Yes 72 VS-359-1 Drain line from Loop 3 Valve support to MOV-RC-557C Yes 72 WFPD-HSS-201 16" FW supply line to Stm Gen 1A Between Penetration X-76 & RC-E-1A No WFPD-HSS-202 16" FW supply line to Stm Gen 1A Between Penetration X-76 & RC-E-1A No WFPD-HSS-203 16" FW supply line to Stm Gen 1A Between Penetration X-76 & RC-E-1A No WFPD-HSS-204 16" FW supply line to Stm Gen 1A Between Penetration X-76 & RC-E-1A No WFPD-HSS-205 16" FW supply line to Stm Gen 1A Between Penetration X-76 & RC-E-1A No WFPD-HSS-206 16" FW supply line to Stm Gen 1A Between Penetration X-76 & RC-E-1A No WFPD-HSS-207 16" FW supply line to Stm Gen 1B Between Penetration X-77 & RC-E-1B No Beaver Valley Unit 1 3.7.4 - 11 LRM Revision 89

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 WFPD-HSS-208 16" FW supply line to Stm Gen 1B Between Penetration X-77 & RC-E-1B No WFPD-HSS-208A 16" FW supply line to Stm Gen 1B Between Penetration X-77 & RC-E-1B No WFPD-HSS-209 16" FW supply line to Stm Gen 1C Between Penetration X-78 & RC-E-1C No WFPD-HSS-210 16" FW supply line to Stm Gen 1C Between Penetration X-78 & RC-E-1C No WFPD-HSS-211 16" FW supply line to Stm Gen 1C Between Penetration X-78 & RC-E-1C No WFPD-HSS-212 16" FW supply line to Stm Gen 1C Between Penetration X-78 & RC-E-1C No WFPD-HSS-212A 16" FW supply line to Stm Gen 1C Between Penetration X-78 & RC-E-1C No WFPD-HSS-228 16" FW supply line to Stm Gen 1A Between FW-25 & FW-156A No WFPD-HSS-229 16" FW supply line to Stm Gen 1B Between FW-26 & FW-156B No WFPD-HSS-230 16" FW supply line to Stm Gen 1C Between FW-27 & FW-156C No WFPD-HSS-231 16" FW supply line to Stm Gen 1C Between FW-27 & FW-156C No WFPD-HSS-232 16" FW supply line to Stm Gen 1B Between FW-26 & FW-156B No WFPD-HSS-233 16" FW supply line to Stm Gen 1A Between FW-25 & FW-156A No WGCB-H-47A S/G Blowdown from S/G 1A Between TV-BD-101A2 & BD-1 No WGCB-PSSP-101 S/G Blowdown from S/G 1C Between TV-BD-101C2 & BD-3 No WGCB-PSSP-200A S/G Blowdown from S/G 1B Valve support to TV-BD-101B2 No WGCB-PSSP-200B S/G Blowdown from S/G 1B Valve support to TV-BD-101B2 No WGCB-PSSP-200C S/G Blowdown from S/G 1B Valve support to TV-BD-101B1 No WGCB-PSSP-200D S/G Blowdown from S/G 1B Valve support to TV-BD-101B1 No Beaver Valley Unit 1 3.7.4 - 12 LRM Revision 89

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 WGCB-PSSP-46E S/G Blowdown from S/G 1A Valve support to TV-BD-101A1 No WGCB-PSSP-46F S/G Blowdown from S/G 1A Valve support to TV-BD-101A1 No WGCB-PSSP-46G S/G Blowdown from S/G 1A Valve support to TV-BD-101A2 No WGCB-PSSP-46H S/G Blowdown from S/G 1A Valve support to TV-BD-101A2 No WGCB-PSSP-55E S/G Blowdown from S/G 1C Valve support to TV-BD-101C1 No WGCB-PSSP-55F S/G Blowdown from S/G 1C Valve support to TV-BD-101C1 No WGCB-PSSP-55G S/G Blowdown from S/G 1C Valve support to TV-BD-101C2 No WGCB-PSSP-55H S/G Blowdown from S/G 1C Valve support to TV-BD-101C2 No WR-HSS-300 "B" RW supply header to RS Hx's Between RW-109 & MOV-RW-104B/D Yes 12 WR-HSS-301 "B" RW supply header to RS Hx's Between MOV-RW-103C/D & RW-109 Yes 12 WR-HSS-302 "B" RW supply header to RS Hx's Between MOV-RW-103C/D & RW-109 Yes 12 WR-HSS-303A "B" RW supply header to RS Hx's Between MOV-RW-103C/D & RW-109 Yes 12 WR-HSS-303B "B" RW supply header to RS Hx's Between MOV-RW-103C/D & RW-109 Yes 12 WR-HSS-304A 30" RW return line in Safegds 722' el Next to REJ-RW-26R1 Yes 12 WR-HSS-304B 30" RW return line in Safegds 722' el Next to REJ-RW-26R1 Yes 12 WR-HSS-306 24" RW return line from RS Hx's Between Hx's & RW-197/198 Yes 12 WR-HSS-307 24" RW return line from RS Hx's Just upstream of RW-197/198 Yes 12 WR-HSS-308 "A" RW supply header to RS Hx Between RW-108 & MOV-RW-104A/C Yes 12 Beaver Valley Unit 1 3.7.4 - 13 LRM Revision 60

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 WR-HSS-309 "A" RW supply header to RS Hx Between RW-108 & MOV-RW-104A/C Yes 12 WR-HSS-310 "B" RW supply header (PAB) Between RW-107 & MOV-RW-103C/D Yes 12 WR-HSS-311 "B" RW supply header to CCR Hx's Between MOV-RW-114B & RW-184/187 Yes 12 WR-HSS-312 "B" RW supply header to CCR Hx's Between MOV-RW-114B & RW-184/187 Yes 12 WR-HSS-313 "A" RW supply header to CCR Hx's Between MOV-RW-114A & MOV-RW-106A Yes 12 WR-HSS-314 30" RW discharge header from CCR Hx's Between RW-190 & RW-645 Yes 12 WR-HSS-316 24" RW return line from RS Hx's Just downstream of RW-197/198 Yes 12 Beaver Valley Unit 1 3.7.4 - 14 LRM Revision 60

Licensing Requirements Manual Auxiliary River Water System (ARWS) 3.7.5

3. 7 PLANT SYSTEMS 3.7.5 Auxiliary River Water System (ARWS)

LR 3.7.5 At least one of the two auxiliary river water subsystems shall be FUNCTIONAL.

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

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

B. Required Action and 8.1 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 ARWS pump develops at least 92 days 60 psig discharge pressure, while pumping through its test flow line.

LRS 3.7.5.2 Start the required ARWS pump, shut down one Reactor 18 months on a Plant River Water System Pump, and verify that the STAGGERED ARWS subsystem provides at least 8000 gpm cooling TEST BASIS water to that portion of the Reactor Plant River 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 1 3.7.5 - 1 LRM Revision 72

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% by volume.

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 1 3.7.6 - 1 LRM Revision 56

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 1 3.7.6 - 2 LRM Revision 56

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. Required Action and 8.1 Apply LR 3.0.3. Immediately associated Completion Time not met.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.7.7.1 Initiate, from the control room, flow through the HEPA 15.5 days on a filter and charcoal adsorber train and verify that the train STAGGERED operates for at least 15 minutes. TEST BASIS Beaver Valley Unit 1 3.7.7 - 1 LRM Revision 71

Licensing Requirements Manual Supplemental Leak Collection and Release System (SLCRS) 3.7.7 LICENSING REQUIREMENT SURVEILLANCES continued SURVEILLANCE FREQUENCY LRS 3.7.7.2 Each SLCRS exhaust air filter train shall be 18 months or demonstrated FUNCTIONAL: after every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of

a. By verifying that the charcoal adsorbers remove system operation

~ 99% of a halogenated hydrocarbon refrigerant test gas when they are tested in-place in accordance with ANSI N510-1975 while operating the ventilation system at a flow rate of 36,000 cfm +/- 10%. After each complete or

b. By verifying that the HEPA filter banks remove partial

~ 99% of the DOP when they are tested in-place in replacement of a accordance with ANSI N510-1975 while operating HEPA filter or the ventilation system at a flow rate of 36,000 cfm charcoal adsorber

+/- 10%. bank

c. By subjecting the carbon contained in at least one test canister or at least two carbon samples removed from one of the charcoal adsorbers to a After any laboratory carbon sample analysis and verifying a structural removal efficiency of~ 90% for radioactive methyl maintenance on iodide at an air flow velocity of 0.9 ft/sec with an inlet the HEPA filter or methyl iodide concentration of 1. 75 mg/m 3 , ~ 95% charcoal adsorber relative humidity, and 30°C; other test conditions housings including test parameter tolerances shall be in accordance with ASTM D3803-1989. The carbon samples not obtained from test canisters shall be prepared by either: Following painting, fire or

1) Emptying one entire bed from a removed chemical release adsorber tray, mixing the adsorbent thoroughly, in any ventilation and obtaining samples at least two inches in zone diameter and with a length equal to the communicating thickness of the bed, or with the system

2) Emptying a longitudinal sample from an adsorber tray, mixing the adsorbent thoroughly, and obtaining samples at least two inches in diameter and with a length equal to the thickness of the bed,

d. By verifying a system flow rate of 36,000 cfm +/- 10%

during system operation.

Beaver Valley Unit 1 3.7.7 - 2 LRM Revision 71

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 demonstrated FUNCTIONAL:

a. By verifying that the pressure drop across the 18 months combined HEPA filters and charcoal adsorber banks is < 6 inches Water Gauge while operating the ventilation system at a flow rate of 36,000 cfm

+/- 10%.

b. By verifying that the SLCRS flow is diverted through 18 months on a the filter train on a Containment Isolation - STAGGERED Phase "A" signal. TEST BASIS 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 1 3.7.7 - 3 LRM Revision 102

Licensing Requirements Manual 125V D.C. Battery Bank Maintenance Requirements 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 125V D.C. Battery Bank Maintenance Requirements LR 3.8.1 The 125V D.C. battery banks (1-1, 1-2, 1-3, & 1-4) 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 1 3.8.1 - 1 LRM Revision 67

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 2,850 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 1 3.8.2 - 1 LRM Revision 56

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 except when single failure proof crane (1CR-15) and single failure proof rigging are being utilized for load movement.

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 -------------------------------------------------------------------------

- NOTE -

Not required to be met when utilizing single failure proof crane (1CR-15) and single failure proof rigging for load movement.

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 1 3.9.1 - 1 LRM Revision 87

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 ::;;; 2850 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 1 3.9.2 - 1 LRM Revision 71

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 crane automatic load cut off when the crane load exceeds has been idle for 2850 pounds. 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 1 3.9.2 - 2 LRM Revision 93

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 1 3.9.3 - 1 LRM Revision 56

Licensing Requirements Manual Containment Purge and Exhaust Isolation System 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Containment Purge and Exhaust Isolation System LR 3.9.4 The Containment Purge and Exhaust isolation system shall be FUNCTIONAL.

APPLICABILITY: During movement of recently irradiated fuel assemblies within the containment, During movement of fuel assemblies over recently irradiated fuel assemblies within the containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A Containment Purge and A.1 Close each of the purge Immediately Exhaust isolation system and exhaust penetrations Nonfunctional. providing direct access from the containment atmosphere to the outside atmosphere.

LICENSING REQUIREMENT SURVEILLANCES SURVEILLANCE FREQUENCY LRS 3.9.4.1 The Containment Purge and Exhaust isolation system 7 days shall be demonstrated FUNCTIONAL by verifying that containment Purge and Exhaust isolation occurs on manual initiation and on a high-high radiation signal from each of the containment radiation monitoring instrumentation channels and the isolation time of each system isolation valve is within limits.

Beaver Valley Unit 1 3.9.4 - 1 LRM Revision 71

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 - 4.4 x 10-4 k/k/0 F at RATED THERMAL POWER.

c. 300 ppm Surveillance Limit: (- 37 pcm/0 F)

d. The revised predicted near-EOL 300 ppm MTC shall be calculated using Figure 5.1-5 and the following algorithm from Reference 11 :

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/0 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/ 0 F / AFD

- - Predictive Correction is -3 pcm/ 0 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 27-1 Beaver Valley Unit 1 5.1 - 1 LRM Revision 105

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: (- 42.5 pcm/0 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 (F Q(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 (Z) = FQM (Z)

1.0815$

FQW (Z) = FQC (Z)

W(Z)

(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, an 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 27-1 Beaver Valley Unit 1 5.1 - 2 LRM Revision 105

Licensing Requirements Manual Core Operating Limits Report 5.1 5.1 Core Operating Limits Report The W(Z) values are provided in Table 5.1-1 and 5.1-2. The W(Z) values in Table 5.1-1 were generated assuming that they will be used for full power surveillance. The W(Z) values in Table 5.1-2 were generated assuming that they will be used for a part power surveillance during initial cycle startup following the refueling outage. When a part power surveillance is performed, the W(Z) values should be multiplied by the factor 1/P, when P > 0.5. When P is 0.5, the W(Z) values should be multiplied by the factor 1/(0.5), or 2.0. This is consistent with the adjustment in the FQ(Z) limit at part power conditions.

The FQ(Z) penalty function, applied when the analytic F Q(Z) function increases from one monthly measurement to the next, is provided in Table 5.1-3.

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

FNH < CF H * (1 + PF H (1-P))$

Where: CF H = Value listed in Table 5.1-4 PF H = 0.3 THERMAL POWER P = RATED THERMAL POWER 5.1.8 LCO 3.2.3 Axial Flux Difference (AFD)

The AFD acceptable operation limits are provided in Figure 5.1-4.

5.1.9 LCO 3.3.1 Reactor Trip System Instrumentation - Overtemperature and Overpower T Parameter Values from Table Notations 1 and 2

a. Overtemperature T Setpoint Parameter Values:

Parameter Value Overtemperature ~T reactor trip setpoint K1 ~ 1.242 Overtemperature ~T reactor trip setpoint Tavg K2 ~ 0.0183/ 0 F coefficient Overtemperature T reactor trip setpoint pressure K3 ~ 0.001/psia coefficient Tavg at RATED THERMAL POWER T' ~ 577.90 F(1)

$ 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, an additional uncertainty of (0.01)*(3-T/12.5) is added to the standard uncertainty on FN H of 1.04, where T is the total number of measured thimbles. At least three measured thimbles per core quadrant are also required.

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

COLR Cycle 27-1 Beaver Valley Unit 1 5.1 - 3 LRM Revision 105

Licensing Requirements Manual Core Operating Limits Report 5.1 5.1 Core Operating Limits Report Nominal pressurizer pressure P' 2250 psia Measured reactor vessel average temperature lead/lag 1 30 secs time constants 2 4 secs Measured reactor vessel T lag time constant 't 4 ~ 6 secs Measured reactor vessel average temperature lag 't 5 ~ 2 secs time 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%, f( 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 (q t - 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 (q t - qb) exceeds +15%, the T trip setpoint shall be automatically reduced by 1.47% of its value at RATED THERMAL POWER.

b. Overpower T Setpoint Parameter Values:

Parameter Value Overpower T reactor trip setpoint K4 ~ 1.085 Overpower T reactor trip setpoint Tavg K5 0.02/0 F for increasing rate/lag coefficient average temperature K5 = 0/0 F for decreasing average temperature Overpower T reactor trip setpoint Tavg K6 0.0021/ 0 F for T > T" heatup coefficient K6 = 0/0 F for T ~ T" Tavg at RATED THERMAL POWER T" ~ 577.9 0 F(2)

Measured reactor vessel average 't 3 ~ 10 secs temperature rate/lag time constant Measured reactor vessel T lag time 't 4 ~ 6 secs constant Measured reactor vessel average 't 5 ~ 2 secs temperature lag time constant (2) T represents the cycle-specific Full Power Tavg value used in core design.

COLR Cycle 27-1 Beaver Valley Unit 1 5.1 - 4 LRM Revision 105

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 581.50 F(1)

Pressurizer Pressure Pressure 2218 psia(2)

Reactor Coolant System Total Flow Rate Flow Value listed in Table 5.1-4(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 T avg value is determined by adding the appropriate allowances for rod control operation and verification via control board indication (3.60 F) to the cycle specific full power T avg 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 27-1 Beaver Valley Unit 1 5.1 - 5 LRM Revision 105

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 LEFM TM System," Revision 0, May 2000.

10. WCAP-16009-P-A, "Realistic Large Break LOCA Evaluation Methodology Using Automated Statistical Treatment of Uncertainty Method (ASTRUM),"

Revision 0, January 2005.

11. WCAP-137 49-P-A, "Safety Evaluation Supporting the Conditional Exemption of the Most Negative EOL Moderator Temperature Coefficient Measurement," March 1997 (Westinghouse Proprietary).

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

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

14. WCAP-12610-P-A & CENPD-404-P-A, Addendum 1-A, "Optimized ZIRLO' ," July 2006.

COLR Cycle 27-1 Beaver Valley Unit 1 5.1 - 6 LRM Revision 105

Licensing Requirements Manual Core Operating Limits Report 5.1 670 660 2435 PSIA UNACCEPTABLE OPERATION 650 2250 PSIA 640 630 Tavg(DegF) 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 27-1 Beaver Valley Unit 1 5.1 - 7 LRM Revision 105

Licensing Requirements Manual Core Operating Limits Report 5.1

'~ -

54.53, 225 200

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CONTROL ROD INSERTION LIMITS COLR Cycle 27-1 Beaver Valley Unit 1 5.1 - 8 LRM Revision 105

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 j

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 27-1 Beaver Valley Unit 1 5.1 - 9 LRM Revision 105

Licensing Requirements Manual Core Operating Limits Report 5.1 120 110 i( 8 I 100) i ; ( +8 I 10 0) i 100 f

H 90 I

UNACCEPTABLE OPERATION I J

\

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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 27-1 Beaver Valley Unit 1 5.1 - 10 LRM Revision 105

Licensing Requirements Manual Core Operating Limits Report 5.1

- 30 . 00 CYCLE BURNUE' MTC (MWD/MTU) (pcm/ ° F) 14000 -30.961 18000 -32.214 0

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- 33 . 00 1 4000 1 5000 1 6000 17000 1 8000 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 27-1 Beaver Valley Unit 1 5.1 - 11 LRM Revision 105

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

FQ Surveillance W(Z) Function versus Burnup at 100% RTP Exclusion Axial Elevation 150 3000 8000 12000 16000 Zone Point (feet) MWD/MTU MWD/MTU MWD/MTU MWD/MTU MWD/MTU

1 12.08 1.0000 1.0000 1.0000 1.0000 1.0000

2 11.88 1.0000 1.0000 1.0000 1.0000 1.0000

3 11.68 1.0000 1.0000 1.0000 1.0000 1.0000

4 11.47 1.0000 1.0000 1.0000 1.0000 1.0000

5 11.27 1.0000 1.0000 1.0000 1.0000 1.0000

6 11.07 1.0000 1.0000 1.0000 1.0000 1.0000

7 10.87 1.0000 1.0000 1.0000 1.0000 1.0000 8 10.67 1.1550 1.1976 1.2469 1.2126 1.1954 9 10.47 1.1500 1.1963 1.2385 1.2102 1.1908 10 10.27 1.1533 1.1930 1.2287 1.2060 1.1859 11 10.07 1.1437 1.1883 1.2200 1.2003 1.1807 12 9.86 1.1451 1.1842 1.2195 1.1982 1.1752 13 9.66 1.1500 1.1809 1.2185 1.1980 1.1694 14 9.46 1.1470 1.1715 1.2115 1.1957 1.1662 15 9.26 1.1412 1.1681 1.2106 1.1921 1.1721 16 9.06 1.1401 1.1635 1.2080 1.1884 1.1790 17 8.86 1.1415 1.1560 1.2030 1.1868 1.1832 18 8.66 1.1505 1.1558 1.2035 1.1877 1.1867 19 8.46 1.1574 1.1620 1.2062 1.1937 1.1894 20 8.25 1.1628 1.1655 1.2068 1.1986 1.1925 21 8.05 1.1668 1.1676 1.2053 1.2012 1.1947 22 7.85 1.1695 1.1685 1.2027 1.2023 1.1995 23 7.65 1.1698 1.1672 1.1979 1.2014 1.2031 24 7.45 1.1690 1.1648 1.1920 1.1992 1.2054 25 7.25 1.1664 1.1605 1.1837 1.1943 1.2045 26 7.05 1.1632 1.1556 1.1742 1.1877 1.2016 27 6.84 1.1590 1.1498 1.1644 1.1807 1.1976 28 6.64 1.1531 1.1424 1.1532 1.1724 1.1926 29 6.44 1.1466 1.1343 1.1443 1.1629 1.1861 30 6.24 1.1396 1.1256 1.1370 1.1522 1.1780 31 6.04 1.1315 1.1161 1.1286 1.1406 1.1688 32 5.84 1.1225 1.1053 1.1194 1.1294 1.1587 Note: Top and Bottom 10% Excluded COLR Cycle 27-1 Beaver Valley Unit 1 5.1 - 12 LRM Revision 105

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

FQ Surveillance W(Z) Function versus Burnup at 100% RTP Exclusion Axial Elevation 150 3000 8000 12000 16000 Zone Point (feet) MWD/MTU MWD/MTU MWD/MTU MWD/MTU MWD/MTU 33 5.64 1.1131 1.1002 1.1098 1.1217 1.1474 34 5.44 1.1109 1.0988 1.1021 1.1135 1.1364 35 5.23 1.1118 1.0996 1.0984 1.1098 1.1327 36 5.03 1.1114 1.1011 1.0974 1.1057 1.1292 37 4.83 1.1120 1.1023 1.0956 1.1029 1.1254 38 4.63 1.1157 1.1032 1.0938 1.0999 1.1208 39 4.43 1.1195 1.1039 1.0916 1.0965 1.1155 40 4.23 1.1227 1.1042 1.0894 1.0930 1.1101 41 4.03 1.1256 1.1042 1.0870 1.0895 1.1043 42 3.83 1.1295 1.1041 1.0842 1.0846 1.1008 43 3.62 1.1339 1.1037 1.0811 1.0838 1.0984 44 3.42 1.1376 1.1055 1.0781 1.0856 1.0958 45 3.22 1.1408 1.1104 1.0753 1.0873 1.0923 46 3.02 1.1442 1.1220 1.0749 1.0885 1.0945 47 2.82 1.1506 1.1417 1.0792 1.0938 1.1037 48 2.62 1.1665 1.1643 1.0918 1.1058 1.1172 49 2.42 1.1875 1.1873 1.1081 1.1201 1.1326 50 2.21 1.2079 1.2107 1.1251 1.1345 1.1481 51 2.01 1.2285 1.2342 1.1418 1.1482 1.1624 52 1.81 1.2488 1.2574 1.1581 1.1614 1.1759 53 1.61 1.2676 1.2790 1.1734 1.1739 1.1889 54 1.41 1.2844 1.2986 1.1874 1.1854 1.2009

55 1.21 1.0000 1.0000 1.0000 1.0000 1.0000

56 1.01 1.0000 1.0000 1.0000 1.0000 1.0000

57 0.81 1.0000 1.0000 1.0000 1.0000 1.0000

58 0.60 1.0000 1.0000 1.0000 1.0000 1.0000

59 0.40 1.0000 1.0000 1.0000 1.0000 1.0000

60 0.20 1.0000 1.0000 1.0000 1.0000 1.0000

61 0.00 1.0000 1.0000 1.0000 1.0000 1.0000 Note: Top and Bottom 10% Excluded COLR Cycle 27-1 Beaver Valley Unit 1 5.1 - 13 LRM Revision 105

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

FQ Surveillance W(Z) Function versus Burnup at 75% RTP Exclusion Axial Elevation Zone Point (feet) 75% RTP

1 12.08 1.0000

2 11.88 1.0000

3 11.68 1.0000

4 11.47 1.0000

5 11.27 1.0000

6 11.07 1.0000

7 10.87 1.0000 8 10.67 1.2616 9 10.47 1.2465 10 10.27 1.2173 11 10.07 1.1881 12 9.86 1.1706 13 9.66 1.1635 14 9.46 1.1473 15 9.26 1.1237 16 9.06 1.1064 17 8.86 1.1019 18 8.66 1.1013 19 8.46 1.1016 20 8.25 1.1024 21 8.05 1.1014 22 7.85 1.1006 23 7.65 1.0982 24 7.45 1.0949 25 7.25 1.0925 26 7.05 1.0892 27 6.84 1.0860 28 6.64 1.0799 29 6.44 1.0758 30 6.24 1.0699 31 6.04 1.0640 32 5.84 1.0567 Note: Top and Bottom 10% Excluded COLR Cycle 27-1 Beaver Valley Unit 1 5.1 - 14 LRM Revision 105

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

FQ Surveillance W(Z) Function versus Burnup at 75% RTP Exclusion Axial Elevation 75% RTP Zone Point (feet) 33 5.64 1.0508 34 5.44 1.0510 35 5.23 1.0555 36 5.03 1.0569 37 4.83 1.0609 38 4.63 1.0673 39 4.43 1.0744 40 4.23 1.0798 41 4.03 1.0853 42 3.83 1.0943 43 3.62 1.1018 44 3.42 1.1093 45 3.22 1.1163 46 3.02 1.1236 47 2.82 1.1338 48 2.62 1.1529 49 2.42 1.1772 50 2.21 1.2008 51 2.01 1.2269 52 1.81 1.2504 53 1.61 1.2743 54 1.41 1.2940

55 1.21 1.0000

56 1.01 1.0000

57 0.81 1.0000

58 0.60 1.0000

59 0.40 1.0000

60 0.20 1.0000

61 0.00 1.0000 Note: Top and Bottom 10% Excluded COLR Cycle 27-1 Beaver Valley Unit 1 5.1 - 15 LRM Revision 105

Licensing Requirements Manual Core Operating Limits Report 5.1 Table 5.1-3 FQ(Z) Penalty Factor versus Burnup Cycle Burnup (MWD/MTU) FQ(Z) Penalty Factor

>0 1.0200 Note: The Penalty Factor, to be applied to FQ(Z) in accordance with Technical Specification Surveillance Requirement (SR) 3.2.1.2, is the maximum factor by which F Q(Z) is expected 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.

Table 5.1-4 FA.H Limit versus Minimum Measured Flow Minimum Measured Flow (MMF)

FA.H Limit (gpm)

MMF ;?: 279,731 1.62 279,731 > MMF ;?: 278,348 1.61 278,348 > MMF ;?: 277,499 1.60 COLR Cycle 27-1 Beaver Valley Unit 1 5.1 - 16 LRM Revision 105

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Pressure and Temperature Limits Report BVPS-1 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 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 N/A 5.2-3 5.2.1.3 3.5.2 N/A N/A 5.2-3 BVPS-1 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 10 Beaver Valley Unit 1 5.2 - i LRM Revision 103

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 1 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 Liquid Water Discharge.

5.2.1 Operating Limits The PTLR limits for Beaver Valley Power Station (BVPS) Unit 1 have been prepared in accordance with the requirements of Technical Specification 5.6.4, using the methodology contained in Reference 1.

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

The RCS temperature rate-of-change limits are defined as:

a. A maximum heatup of 100°F in any one hour period (Reference 2).

b. A maximum cooldown of 100°F in any one hour period (Reference 2), and

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. This rate-of-change limit ensures that thermal gradient stress resulting from temperature change is not induced in the reactor vessel during inservice hydrostatic testing operations above system design pressure.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 1 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report 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 Figure 5.2-2 and Table 5.2-2. These limits are defined in Reference 2.

Consistent with the methodology described in Reference 1, the RCS P/T limits for heatup and cooldown shown in Figures 5.2-1 and 5.2-2 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 (Reference 5). 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.

Pressure-temperature limit curves shown in Figure 5.2-3 were 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, and 5.2-3.

Figures 5.2-1 and 5.2-2 and Tables 5.2-1 and 5.2-2 are based upon analysis of all applicable surveillance capsules per Reference 2. Reference 2 provides an updated surveillance capsule credibility evaluation, updated Position 2.1 chemistry factor values, and an updated fluence evaluation. Therefore, the development of the P/T limit curves (Reference 2) utilized 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 2, the limiting material for the current BVPS-1 P/T limits continues to be the lower shell plate B6903-1 at 50 EFPY.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 2 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report Using the fluence analysis provided in Section 2 of Reference 2, the neutron fluence value for lower shell plate B6903-1 at 50 EFPY is determined to be 5.89 x 1019 n/cm2 (E > 1.0 MeV). Using this updated fluence value along with the updated Position 2.1 chemistry factor value (Table 5.2-4) for this material, the limiting 1/4T and 3/4T adjusted reference temperature (ART) values are 244.0°F and 208.8°F, respectively, at 50 EFPY. Note that for conservatism, P/T limit curves were developed using 1/4T and 3/4T ART values of 244.5°F and 209.5°F, respectively (Reference 2).

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 and enable temperature in accordance with Table 5.2-3. The lift setting provided does not impose any reactor coolant pump restrictions.

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 WCAP-14040-A, Revision 4 (Reference 1). The PORV lift setting (Reference 10) shown in Table 5.2-3 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. Based on this method, the arming temperature (Reference 10) is 3470 F with uncertainty for 50 EFPY.

The calculated enable temperature is based on either a RCS temperature of less than 2000 F or materials concerns (reactor vessel metal temperature less than RTNDT + 500 F), whichever is greater. The calculated enable temperature (Reference 10) is 345oF with uncertainty for 50 EFPY.

As the arming temperature is higher and, therefore, more conservative than the calculated enable temperature, the OPPS enable temperature, as shown in Table 5.2-3, is set to equal the arming temperature.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 3 LRM Revision 103

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

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 keylock switches (one in each train) into their "automatic" position. Once OPPS is activated (armed/enabled) reactor coolant system pressure transmitters will signal a rise in system pressure above the 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.

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 4.5-3 of the UFSAR. Also, the results of these analyses shall be used to update Figures 5.2-1 and 5.2-2, 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 3 and 4) 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, RT NDT, 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 8 is an NRC commitment made by FENOC to use only the calculated vessel fluence values when performing future capsule surveillance evaluations for BVPS Unit 1. This commitment is a condition of license Amendment 256 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.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 4 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report 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 5.2-4 shows the calculation of the surveillance material chemistry factors using surveillance capsule data.

Table 5.2-4a shows the Calculation of Chemistry Factors based on St. Lucie Unit 1, Millstone Unit 2, and Fort Calhoun Surveillance Capsule Data.

Table 5.2-4b shows the St. Lucie Unit 1, Millstone Unit 2, and Fort Calhoun Surveillance Weld Data.

Table 5.2-5, taken from Reference 2, provides the reactor vessel beltline material property table.

Table 5.2-6, taken from Reference 2, shows the reactor vessel extended beltline material properties.

Table 5.2-7, taken from Reference 2, provides a summary of the Adjusted Reference Temperature (ARTs) for 50 EFPY.

Table 5.2-8, taken from Reference 2, shows the calculation of ARTs for 50 EFPY.

Table 5.2-9, taken from Reference 2, provides RT PTS values for the beltline materials at 50 EFPY.

Table 5.2-10, taken from Reference 2, provides RT PTS values for the extended beltline materials at 50 EFPY.

Table 5.2-11, provides Reactor Vessel Toughness Data (Unirradiated)

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 5 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 5.2 Pressure and Temperature Limits Report 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. WCAP-18102-NP, Revision 1 , "Beaver Valley Unit 1 Heatup and Cooldown Limit Curves for Normal Operation," B.E. Mays, et al., February 2018.

3. WCAP-17896-NP, Revision 0 , "Analysis of Capsule X from the FirstEnergy Nuclear Operating Company Beaver Valley Unit 1 Reactor Vessel Radiation Surveillance Program," E.J. Long and E.T. Hayes, September 2014.

4. WCAP- 8457, "Duquesne Light Company, Beaver V alley Unit No. 1 Reactor Vessel Radiation Surveillance Program," J. A Davidson, October 1974.

5. 10 CFR Part 50, Appendix G, "Fracture Toughness Requirements," Federal Register, Volume 60, No. 243, December 19, 1995.

6. 10 CFR 50.61, "Fracture Toughness Requirements for Protection Against Pressurized Thermal Shock Events," Federal Register, Volume 60, No.

243, December 19, 1995. (PTS Rule)

7. Regulatory Guide 1.99, Revision 2, "Radiation Embrittlement of Reactor Vessel Materials," U.S. Nuclear Regulatory Commission, May 1988.

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

9. WCAP-15571, Supplement 1, Revision 2, "Analysis of Capsule Y from Beaver Valley Unit 1 Reactor Vessel Radiation Surveillance Program,"

A. E. Freed, September 2011.

10. LTR-SCS-16-58 Rev. 0, LTOPS Setpoint Evaluation for 50 EFPY for Beaver Valley Unit 1, June 2017.

11. NUREG-0800, BTP 5-2 and 5- 3, "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants," March 2007.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 6 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: Lower Shell Plate B6903-1 using Regulatory Guide 1.99 Position 1.1 data LIMITING ART VALUES AT 50 EFPY: 1/4T, 244.5 0 F (Axial Flaw) 3/4T, 209.5 0 F (Axial Flaw) 2500 i II Operlim Version:5.4 Run:19454 Operlim.xlsm Version: 5.4 I I 2250 J ,_ I- , '

~

j

[Leak Test Limit

/I Ii' l 2000 'j I

' I Unacceptable Acceptable Operation Operation 1750 I

I I

IHeatup Rate 1500 60 Deg. F/Hr

- ~ Critical Limit I I 60 Deg. F/Hr I I rt 1250 I Heatup

- 1100 Rate Deg. F/Hr - Critical Limit 100 Deg. F/Hr I j

r7V1 1000 IA 750 I ___....I I Criticality Limit based on l

500 inservice hydrostatic test I-I temperature (301ºF) for the l

service period up to 50 EFPY

~

Boltup Temperature 250 0

0 50 100 150 200 250 300 350 400 450 500 550 Moderator Temperature (Deg. F)

Figure 5.2-1 (Page 1 of 1)

Reactor Coolant System Heatup Limitations Applicable for 50 EFPY (LCO 3.4.3)

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 7 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 MATERIAL PROPERTY BASIS LIMITING MATERIAL: Lower Shell Plate B6903-1 using Regulatory Guide 1.99 Position 1.1 data LIMITING ART VALUES AT 50 EFPY: 1/4T, 244.5 0 F (Axial Flaw) 3/4T, 209.50 F (Axial Flaw) 2500 Operlim Version:5.4 Run:19454 Operlim.xlsm Version: 5.4 2250 2000 Unacceptable Acceptable Operation Operation 1750 1500 1250 1000 750 Cooldown Rates

ºF/Hr Steady-State 500

-20

-40

-60

-100 250 0

0 50 100 150 200 250 300 350 400 450 500 550 Moderator Temperature (Deg. F)

Figure 5.2-2 (Page 1 of 1)

Reactor Coolant System Cooldown Limitations Applicable for 50 EFPY (LCO 3.4.3)

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 8 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 2500 2000

- /

/

0 1500 en

~

w cc:

~

en

~

en ~

w 8: 1000 i.---

~

500 I

0 I

50 60 70 80 90 100 110 120 TEMPERA TURE {°F)

Figure 5.2-3 (Page 1 of 1)

Isolated Loop Pressure - Temperature Limit Curve (LCO 3.4.3)

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 9 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-1 (Page 1 of 2)

Heatup Curve Data Points for 50 EFPY (LCO 3.4.3) 60°F/hr 100°F/hr 60°F/hr Heatup 100°F/hr Heatup Criticality Criticality T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) 60 0 301 0 60 0 301 0 60 602 301 1190 60 552 301 947 65 602 305 1241 65 552 305 990 70 602 310 1303 70 552 310 1042 75 602 315 1358 75 552 315 1099 80 602 320 1417 80 552 320 1162 85 602 325 1483 85 552 325 1232 90 602 330 1555 90 552 330 1310 95 602 335 1636 95 552 335 1395 100 602 340 1724 100 552 340 1488 105 602 345 1821 105 552 345 1592 110 603 350 1929 110 552 350 1706 115 604 355 2048 115 552 355 1832 120 606 360 2179 120 552 360 1971 125 609 365 2324 125 552 365 2124 130 612 370 2483 130 552 370 2292 135 616 135 552 375 2464 140 621 140 553 145 627 145 555 150 633 150 557 155 640 155 561 160 648 160 565 165 657 165 570 170 667 170 575 175 678 175 582 180 691 180 590 185 704 185 598 190 719 190 608 195 736 195 619 200 755 200 631 205 775 205 645 210 798 210 660 215 823 215 677 220 851 220 696 225 882 225 717 PTLR Revision 10 Beaver Valley Unit 1 5.2 - 10 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-1 (Page 2 of 2)

Heatup Curve Data Points for 50 EFPY (LCO 3.4.3) 60°F/hr 100°F/hr 60°F/hr Heatup 100°F/hr Heatup Criticality Criticality T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) 230 915 230 741 235 953 235 766 240 994 240 795 245 1040 245 827 250 1085 250 861 255 1132 255 900 260 1184 260 943 265 1241 265 990 270 1303 270 1042 275 1358 275 1099 280 1417 280 1162 285 1483 285 1232 290 1555 290 1310 295 1636 295 1395 300 1724 300 1488 305 1821 305 1592 310 1929 310 1706 315 2048 315 1832 320 2179 320 1971 325 2324 325 2124 330 2483 330 2292 335 2464 Leak Test Limit T (°F) P (psig) 283 2000 301 2485 PTLR Revision 10 Beaver Valley Unit 1 5.2 - 11 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-2 (Page 1 of 2)

Cooldown Curve Data Points for 50 EFPY (LCO 3.4.3)

Steady State 200 F/hr 400 F/hr 600 F/hr 1000 F/hr T P T P T P T P T P (0 F) (psig) (0 F) (psig) (0 F) (psig) (0 F) (psig) (0 F) (psig) 60 0 60 0 60 0 60 0 60 0 60 621 60 607 60 563 60 518 60 426 65 621 65 608 65 564 65 519 65 426 70 621 70 609 70 565 70 520 70 427 75 621 75 610 75 566 75 521 75 428 80 621 80 611 80 567 80 522 80 429 85 621 85 613 85 569 85 523 85 431 90 621 90 614 90 570 90 525 90 432 95 621 95 616 95 572 95 527 95 434 100 621 100 618 100 574 100 529 100 436 105 621 105 621 105 576 105 531 105 439 110 621 110 621 110 579 110 534 110 442 115 621 115 621 115 582 115 537 115 445 120 621 120 621 120 585 120 541 120 449 125 621 125 621 125 589 125 545 125 453 130 621 130 621 130 593 130 549 130 458 130 680 130 637 135 598 135 554 135 464 135 684 135 641 140 603 140 559 140 470 140 689 140 646 145 609 145 566 145 477 145 694 145 652 150 615 150 572 150 485 150 700 150 658 155 623 155 580 155 494 155 706 155 665 160 630 160 588 160 504 160 713 160 672 165 639 165 598 165 515 165 721 165 680 170 649 170 609 170 527 170 729 170 689 175 660 175 620 175 541 175 739 175 700 180 672 180 633 180 556 180 749 180 711 185 685 185 648 185 573 185 761 185 723 190 700 190 664 190 593 190 774 190 737 195 717 195 682 195 614 195 788 195 752 200 735 200 702 200 637 200 803 200 769 205 755 205 724 205 664 205 821 205 788 210 778 210 748 210 693 210 840 210 808 215 802 215 775 215 725 215 861 215 831 220 830 220 805 220 761 220 884 220 856 225 860 225 838 225 801 225 910 225 884 230 894 230 875 230 846 230 938 230 915 235 931 235 916 235 895 235 970 235 949 240 973 240 961 240 949 240 1004 240 987 245 1018 245 1011 245 1010 245 1043 245 1029 250 1069 250 1067 250 1067 250 1085 250 1075 255 1125 255 1125 255 1125 PTLR Revision 10 Beaver Valley Unit 1 5.2 - 12 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-2 (Page 2 of 2)

Cooldown Curve Data Points for 50 EFPY (LCO 3.4.3)

Steady State 200 F/hr 400 F/hr 600 F/hr 1000 F/hr T P T P T P T P T P

( F) 0 (psig) ( F) 0 (psig) ( F) 0 (psig) ( F) 0 (psig) ( F) 0 (psig) 255 1132 255 1127 260 1183 260 1183 260 1183 260 1184 260 1183 265 1241 265 1241 265 1241 265 1241 265 1241 270 1305 270 1305 270 1305 270 1305 270 1305 275 1375 275 1375 275 1375 275 1375 275 1375 280 1452 280 1452 280 1452 280 1452 280 1452 285 1537 285 1537 285 1537 285 1537 285 1537 290 1632 290 1632 290 1632 290 1632 290 1632 295 1736 295 1736 295 1736 295 1736 295 1736 300 1851 300 1851 300 1851 300 1851 300 1851 305 1979 305 1979 305 1979 305 1979 305 1979 310 2120 310 2120 310 2120 310 2120 310 2120 315 2275 315 2275 315 2275 315 2275 315 2275 320 2448 320 2448 320 2448 320 2448 320 2448 PTLR Revision 10 Beaver Valley Unit 1 5.2 - 13 LRM Revision 103

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 347 F PORV Setpoint 397 psig PTLR Revision 10 Beaver Valley Unit 1 5.2 - 14 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-4 (Page 1 of 1)

Calculation of Chemistry Factors Using Surveillance Capsule Data Material Capsule Capsule f(a) FF(b) L\RTNDT(c) FF *L\RTNDT FF2 Lower Shell V 0.297 0.6677 127.9 85.40 0.446 Plate U 0.618 0.8652 118.3 102.35 0.749 B6903-1(d)

W 0.952 0.9862 147.7 145.66 0.973 (Longitudinal)

Y 2.10 1.2018 141.7 170.30 1.444 X 4.99 1.4020 175.8 246.46 1.965 Lower Shell V 0.297 0.6677 138.0 92.14 0.446 Plate U 0.618 0.8652 132.1 114.29 0.749 B6903-1(d)

W 0.952 0.9862 180.2 177.72 0.973 (Transverse)

Y 2.10 1.2018 166.9 200.58 1.444 X 4.99 1.4020 179.0 250.95 1.965 SUM: 1585.86 11.154 CF = L (FF

L\RTNDT) L (FF2) = (1585.86) (11.154) = 142.20 F(e) 169.4 V 0.297 0.6677 113.10 0.446 (159.8) 174.8 Beaver Valley U 0.618 0.8652 151.23 0.749 (164.9)

Unit 1 Surveillance 197.5 W 0.952 0.9862 194.76 0.973 Weld Metal(d) (186.3)

(Heat # 305424) 189.2 Y 2.10 1.2018 227.40 1.444 (178.5) 252.1 X 4.99 1.4020 353.39 1.965 (237.8)

SUM: 1039.87 5.577 2 (e)

CF = L (FF

L\RTNDT) +L(FF ) = (1039.87) (5.577) = 186.5 F 0

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 4-1 of Reference 2.

(b) FF = fluence factor = f (0.28 - 0.1

log f).

(c) RTNDT values are the measured 30 ft-lb shift values. The Beaver Valley Unit 1 RTNDT values for the surveillance weld data are adjusted by a ratio of 1.06. Pre-adjusted values are listed in parentheses, and were taken from Table 4-1 of Reference 2.

NOTE: Per Regulatory Guide 1.99, Revision 2 (Reference 7), section 2.1 "Radiation Embrittlement of Reactor Vessel Materials," the vessel weld chemistry factor is divided by the surveillance weld chemistry factor to obtain a ratio factor to multiply the RTNDT values by to obtain adjusted RTNDT values. In Table 5-2 of Reference 2, the ratio is determined to be 1.06 or (191.7/181.6).

(d) The plate and weld surveillance data is deemed non-credible per Appendix D of Reference 2.

(e) Position 2.1 chemistry factor values are summarized in Table 5-4 of Reference 2.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-4a (Page 1 of 2)

Calculation of Chemistry Factors(a)

(Based on St. Lucie Unit 1, Millstone Unit 2, and Fort Calhoun Surveillance Capsule Data)

Material Capsule Capsule f(b) FF(c) I>RTNDT(d) FF

RTNDT I> FF2 82.6 97o 0.5174 0.8160 67.44 0.666 (72.34)

Weld Metal 81.1 Heat # 90136(e) 104o 0.7885 0.9333 75.68 0.871 (67.4)

(St. Lucie Unit 1) 83.8 284o 1.243 1.0606 88.85 1.125 (68.0)

Weld Metal 67.5 97° 0.324 0.6902 (65.93) 46.61 0.476 Heat # 90136(e)

(Millstone Unit 2) 57.0 104° 0.949 0.9853 (52.12) 56.18 0.971 61.4 83° 1.74 1.1523 (56.09) 70.74 1.328 SUM: 405.50 5.437 CF = (FF

RTNDT)

M I> + M (FF2) = (405.50) + (5.437) = 74.6 F(g) 0 W-225 0.488 0.800 197.30 157.83 0.640 (210)

Weld Metal Heat # 305414(f) W-265 0.847 0.953 218.30 208.13 0.909 (Fort Calhoun (225)

Unit 1)

W-275 1.54 1.119 215.90 241.68 1.253 (219)

SUM: 607.64 2.802 CF = (FF

RTNDT)

M I> + M (FF2) = (607.64) (2.802) = 216.9 F(g)

+ 0 Notes for Table 5.2-4a are on the following page.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-4a (Page 2 of 2)

Calculation of Chemistry Factors (a)

(Based on St. Lucie Unit 1, Millstone Unit 2, and Fort Calhoun Surveillance Capsule Data)

Notes:

(a) Use of St. Lucie and Fort Calhoun Surveillance Capsule Data approved by NRC letter dated February 20, 2002, "BEAVER VALLEY POWER STATION, UNIT 1 ISSUANCE OF AMENDMENT RE: AMENDED PRESSURE-TEMPERATURE LIMITS (TAC NO.

MB2301)." As a result of the unclear identification of the Millstone Unit 2 surveillance weld heat number, the Millstone Unit 2 data was not originally incorporated into Beaver Valley Unit 1 chemistry factor calculations. Since the Millstone Unit 2 surveillance weld contains specimens made of Heat # 90136, the use of this data is appropriate. See Appendix D of Reference 2 for more details.

(b) f = calculated surveillance capsule fluence values (x 10 19 n/cm2, E > 1.0 MeV). The surveillance capsule fluence results for St. Lucie Unit 1 and Millstone Unit 2 are contained in Table 4-2 of Reference 2. The surveillance capsule fluence results for Fort Calhoun Unit 1 are contained in Table D-5 of Reference 3.

(0.28 - 0.1

log f)

(c) FF = fluence factor = f .

(d) RTNDT values are the measured 30 ft-lb. shift values. RTNDT values for the surveillance weld data are adjusted first by the difference in operating temperature then using the ratio procedure to account for differences in the surveillance weld chemistry and the beltline weld chemistry. Pre-adjusted values are listed in parentheses, and were taken from Tables 4-2 of Reference 2 and Table A-5 of Reference 9. The temperature adjustments for each capsule were calculated from the data in Table 5.2-4b and the average plant irradiation temperature for BV-1. The St. Lucie Unit 1 RTNDT values for the weld data are adjusted by a ratio of 1.17. The Millstone Unit 2 and Fort Calhoun RTNDT values were not adjusted since the ratio was less than 1.00; therefore, a conservative value of 1.00 was used.

(e) The St. Lucie Unit 1 and Millstone Unit 2 surveillance data is deemed credible per Appendix D of Reference 2; however, a full margin term should be utilized for conservatism when this data is applied as a result of the unclear identification of the Millstone Unit 2 weld specimen heat numbers. See Appendix D of Reference 2 for more details.

(f) The Fort Calhoun Unit 1 surveillance data is deemed non-credible per Appendix D of Reference 3.

(g) Position 2.1 chemistry factor values are summarized in Table 5-4 of Reference 2.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-4b (Page 1 of 1)

St. Lucie Unit 1, Millstone Unit 2, and Fort Calhoun Surveillance Weld Data (a)(b)

Irradiated Capsule f(d)

Cu Ni L\RTNDT(e)

Material Capsule Temperature(c) (x1019 n/cm2, (wt. %) (wt. %) (oF)

(oF) E > 1.0 MeV)

Weld Metal 97o 0.23 0.07 541 0.5174 72.34 Heat # 90136 o 104 0.23 0.07 544.6 0.7885 67.4 (St. Lucie Unit 1) 284o 0.23 0.07 546.3 1.243 68.0 Weld Metal 97° 0.30 0.06 544.3 0.324 65.93 Heat # 90136 104° 0.30 0.06 547.6 0.949 52.12 (Millstone Unit 2) 83° 0.30 0.06 548.0 1.74 56.09 Weld Metal W-225 0.35 0.60 530 0.488 210 Heat W-265 0.35 0.60 536 0.847 225

305414 (Fort Calhoun W-275 0.35 0.60 539.6 1.54 219 Unit 1)

Notes:

(a) Use of St. Lucie and Fort Calhoun Surveillance Capsule Data approved by NRC letter dated February 20, 2002, "BEAVER VALLEY POWER STATION, UNIT 1 -

ISSUANCE OF AMENDMENT RE: AMENDED PRESSURE-TEMPERATURE LIMITS (TAC NO. MB2301)." As a result of the unclear identification of the Millstone Unit 2 surveillance weld heat number, the Millstone Unit 2 data was not originally incorporated into Beaver Valley Unit 1 chemistry factor calculations. Since the Millstone Unit 2 surveillance weld contains specimens made of Heat # 90136, the use of this data is appropriate. See Appendix D of Reference 2 for more details.

(b) Data contained in this table was obtained from Reference 2, unless otherwise noted.

(c) Irradiated temperatures are the average inlet temperatures over the specific cycles corresponding to the operating time experienced by each of the respective capsules.

(d) f = calculated surveillance capsule fluence values.

(e) RTNDT values are the measured 30 ft-lb shift values from Table 4-2 of Reference 2 and Table D-5 of Reference 3.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-5 (Page 1 of 1)

Reactor Vessel Beltline Material Properties Position 1.1 Initial Cu Ni Material Description Chemistry RTNDT(a)

(wt. %) (wt. %)

Factor ( 0 F)

(0 F)

Intermediate Shell Plate B6607-1 0.14 0.62 100.5 26.8 Intermediate Shell Plate B6607-2 0.14 0.62 100.5 53.6 Lower Shell Plate B6903-1 0.21 0.54 147.2 13.1 Lower Shell Plate B7203-2 0.14 0.57 98.7 0.4 Intermediate to Lower Shell Weld 0.27 0.07 124.3 -56 Seam (Heat # 90136)11-714 Intermediate Longitudinal Shell Weld 0.28 0.63 191.7 -56 Seams (Heat # 305424)19-714 A&B Lower Longitudinal Weld Seams 0.34 0.61 210.5 -56 (Heat # 305414)20-714 A&B Surveillance Weld (Heat # 305424) 0.26 0.61 181.6 ---

Note:

(a) The initial RTNDT values for the plates are based on measured data while the weld values are generic.

PTLR Revision 10 Beaver Valley Unit 1 5.2 19 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-6 (Page 1 of 2)

Reactor Vessel Extended Beltline Material Properties(a)

Initial Material Description Material Heat Number Wt % Wt %

RTNDT(c)

ID (Lot Number) Cu Ni

( 0 F)

Upper Shell Forging B6604 123V339VA1 0.12(b) 0.68 40 305414 0.34 0.61 -56 (Gen)

(3951 & 3958)

Upper to Intermediate AOFJ 0.03 0.93 10 (Gen)10-714 Shell Girth Weld FOIJ 0.03 0.94 10 (Gen)

EODJ 0.02 1.04 10 (Gen)

HOCJ 0.02 0.93 10 (Gen)

B6608-1 95443-1 0.10 0.82 48.5 Inlet Nozzles B6608-2 95460-1 0.10 0.82 -15.2 B6608-3 95712-1 0.08 0.79 11.4 EODJ 0.02 1.04 10 (Gen)

FOIJ 0.03 0.94 10 (Gen) 1-717B HOCJ 0.02 0.93 10 (Gen)

Inlet Nozzle Welds 1-717D DBIJ 0.02 0.97 10 (Gen) 1-717F EOEJ 0.01 1.03 10 (Gen)

ICJJ 0.03 0.99 10 (Gen)

JACJ 0.04 0.97 10 (Gen)

B6605-1 95415-1 0.13(d) 0.77 -26.2 Outlet Nozzles B6605-2 95415-2 0.13(d) 0.77 3.3 B6605-3 95444-1 0.09 0.79 10.1 ICJJ 0.03 0.99 10 (Gen)

IOBJ 0.02 0.97 10 (Gen) 1-717A JACJ 0.04 0.97 10 (Gen)

Outlet Nozzle Welds 1-717C HOCJ 0.02 0.93 10 (Gen) 1-717E EODJ 0.02 1.04 10 (Gen)

FOIJ 0.03 0.94 10 (Gen)

Notes for Table 5.2-6 are on the following page.

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Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-6 (Page 2 of 2)

Reactor Vessel Extended Beltline Material Properties (a)

Notes:

(a) Data obtained from Table 3-2 of Reference 2.

(b) The Cu wt % was not available from the CMTR so in accordance with Regulatory Guide 1.99, Revision 2, a standard deviation analysis (average + standard deviation) was done to determine the value based on Westinghouse 508 Class 2 Shell Forgings (55 data points).

(c) The initial RTNDT value for the upper shell forging, inlet nozzle forgings, and outlet nozzle forgings are based on measured values. The generic initial RT NDT values for the weld materials were determined in accordance with NUREG-0800 [Reference 11] and 10 CFR 50.61 [Reference 6].

(d) The Cu wt % was not available from the CMTR, so in accordance with Regulatory Guide 1.99, Revision 2, a standard deviation analysis (average + standard deviation) was done to determine the value based on Westinghouse 508 Class 2 Nozzle Forgings (178 data points).

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 21 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-7 (Page 1 of 1)

Summary of Adjusted Reference Temperatures (ARTs) for 50 EFPY(e) 50 EFPY Material Description 1/4T ART(a) 3/4T ART(a)

(ºF) (ºF)

Intermediate Shell Plate B6607-1 195.2 171.2 Intermediate Shell Plate B6607-2 222.0 198.0 Lower Shell Plate B7203-2 166.4 142.8 Lower Shell Plate B6903-1 244.0(f) 208.8(f)

- Using S/C Data(b) 237.3 203.3 Intermediate Shell Longitudinal Weld 19-714A/B 182.4 133.5

- Using S/C Data(b) 177.7 130.2 Intermediate to Lower Shell Circ. Weld 11-714 175.7 146.0

- Using S/C Data (c) 109.3 91.4 Lower Shell Longitudinal Weld 20-714A/B 199.9 146.2

- Using S/C Data(d) 205.6 150.3 Upper Shell Forging B6604 139.4 119.2 Upper Shell to Intermediate Shell Girth Weld 10-714 172.9 122.5 (Heat # 305414)

-Using S/C Data(d) 177.9 125.9 Upper Shell to Intermediate Shell Girth Weld 10-714 88.4 44.0 (Heat #'s AOFJ and FOIJ)

Upper Shell to Intermediate Shell Girth Weld 10-714 44.0 44.0 (Heat #'s EODJ and HOCJ)

Inlet and Outlet Nozzle Welds (All Heat #'s) 44.0 44.0 Notes:

(a) ART = I + RTNDT + M.

(b) Based on Beaver Valley Unit 1 surveillance data. (Data not credible. ART calculated with a full .)

(c) Based on St. Lucie Unit 1 and Millstone Unit 2 surveillance data. (Data credible.

ART calculated with a full per Appendix D of Reference 2.)

(d) Based on Fort Calhoun Unit 1 surveillance data. (Data not credible. ART calculated with a full .)

(e) Data obtained from Tables 7-2 and 7-3 of Reference 2. Nozzle ART values are excluded from this table, as these values are calculated using surface fluence values. See Reference 2 for nozzle ART values.

(f) For the purposes of P/T limit curve development, a 1/4T ART value of 244.5°F and a 3/4T ART value of 209.5°F were used for conservatism.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 22 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-8 (Page 1 of 1)

Calculation of Adjusted Reference Temperatures (ARTs) for 50 EFPY(c)

Parameter VALUES Operating Time 50 EFPY Material Plate B6903-1 Plate B6903-1 Location Lower Shell Lower Shell Plate Plate 1/4T ART(ºF) 3/4T ART(ºF)

Chemistry Factor, CF (ºF) 147.2 147.2 Fluence (f), n/cm2 (E>1.0 Mev) 3.672 x 1019 1.427 x 1019 Fluence Factor, FF 1.3374 1.0987

~RTNDT = CF x FF(ºF) 196.9(b) 161.7(b)

Initial RTNDT, I(ºF)(a) 13.1 13.1 Margin, M(ºF) 34(b) 34(b)

(d)

IL ART = I+(CF*FF)+M, ºF per RG 1.99, Revision 2 J 244.0 1 208.8(d) g Notes:

(a) Initial RTNDT values are measured values for plate material.

(b) Based on Regulatory Guide 1.99, Revision 2 Position 1.1.

(Surveillance data not credible. ART calculated with a full .)

(c) Data obtained from Tables 7-2 and 7-3 of Reference 2.

(d) For the purposes of P/T limit curve development, a 1/4T ART value of 244.5°F and a 3/4T ART value of 209.5°F were used for conservatism.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 23 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-9 (Page 1 of 2)

RTPTS Calculation for Beltline Region Materials at Life Extension (50 EFPY) (a)

Surface Fluence Chemistry Initial Material Heat <IRTPTS(d) 0 U 0 <] Margin(e) RTPTS(f)

Material Description Fluence Factor, Factor RTNDT(c)

ID Number ( F) 0

( F) 0

( F) 0 (x1019 n/cm2) FF(b) (°F) (°F)

Intermediate Shell Plate B6607-1 C4381-1 5.88 1.4330 100.5 26.8 144.0 0 17 34 204.8 Intermediate Shell Plate B6607-2 C4381-2 5.88 1.4330 100.5 53.6 144.0 0 17 34 231.6 Lower Shell Plate B6903-1 C6317-1 5.89 1.4333 147.2 13.1 211.0 0 17 34 258.1 i => "in C: C) -credible surveillance data(g)

C:

0 C: 5.89 1.4333 142.2 13.1 203.8 0 17 (g) 34 250.9 Lower Shell Plate B7203-2 C6293-2 5.89 1.4333 98.7 0.4 141.5 0 17 34 175.9 Intermediate to Lower 11-714 90136 5.88 1.4330 124.3 -56 178.1 17 28 65.5 187.6 Shell Girth Weld (h) i => "in C: C) 0

~ ~ .0 Q) ::::,

u, ~ "ci>

cu C:

0 Q)"O cu cu

+-'

5.88 1.4330 74.6 -56 106.9 17 28(h) 65.5 116.4 Intermediate Shell 19-714 305424 1.13 1.0341 191.7 -56 198.2 17 28 65.5 207.8 Longitudinal Weld A&B i => "in C: C:-credible surveillance data(g)

C:

0 C: 1.13 1.0341 186.5 -56 192.9 17 28 (g) 65.5 202.4 Lower Shell Longitudinal 20-714 305414 1.14 1.0366 210.5 -56 218.2 17 28 65.5 227.7 Weld A&B i =>"ingi -credible surveillance data(i)

C:

0 C: 1.14 1.0366 216.9 -56 224.8 17 28 (i) 65.5 234.4 Notes:

(a) Data obtained from Table E-1 of Reference 2.

(b) FF = fluence factor = f (0.28 - 0.10 log (f)).

(c) Initial RTNDT values are measured values with the exception of the vessel welds.

(d) RTPTS = CF

FF.

2 2 1/2 (e) M = 2 *( U + ) .

(f) RTPTS = Initial RTNDT + RTPTS + Margin.

<I PTLR Revision 10 Beaver Valley Unit 1 5.2 - 24 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-9 (Page 2 of 2)

RTPTS Calculation for Beltline Region Materials at Life Extension (50 EFPY) (a)

Notes continued:

(g) The BVPS-1 surveillance weld metal is the same weld heat as the BVPS-1 intermediate shell longitudinal welds (Heat #305424). The BVPS-1 surveillance weld data is non-credible; therefore, the higher 01:,. term of 28°F was utilized for BVPS-1 weld heat 305424.

The BVPS-1 surveillance plate material is representative of the BVPS-1 lower shell plate B6903-1. The surveillance plate material is non- credible; therefore, the higher 01:,. term of 17°F was utilized for BVPS-1 plate B6903-1. These credibility evaluation conclusions are contained in Appendix D of Reference 2.

(h) The St. Lucie Unit 1 and Millstone Unit 2 surveillance weld metal is the same weld heat as the BVPS-1 intermediate to lower shell girth weld (Heat #90136). The St. Lucie Unit 1 surveillance weld data is credible; however, the full Ot:,. term of 28°F was utilized for BVPS-1 weld Heat #90136 for conservatism. Additional details and the credibility evaluation conclusions are contained in Appendix D of Reference 2.

(i) The Fort Calhoun surveillance weld metal is the same weld heat as the BVPS-1 lower shell longitudinal welds (Heat #305414). The Fort Calhoun surveillance weld data is non-credible; therefore, the higher 01:,. term of 28°F was utilized for BVPS-1 weld Heat #305414.

This credibility evaluation conclusion is contained in Appendix D of Reference 3 and confirmed in Reference 2.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 25 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-10 (Page 1 of 2)

RTPTS Calculation for Extended Beltline Region Materials at Life Extension (50 EFPY) (a)

Surface Fluence Chemistry Initial Material Material Heat Number RTPTS(d)

<I 0 U 0 <] Margin(e) RTPTS(f)

Fluence Factor, Factor RTNDT(c)

Description ID (Lot Number) ( F) 0

( F) 0

( F) 0 (x1019 n/cm2) FF(b) (°F) (°F)

Upper Shell B6604 123V339VA1 0.718 0.9071 84.2 40 76.4 0 17 34 150.4 Forging Upper to 305414 Intermediate 10-714 0.718 0.9071 210.5 -56 190.9 17 28 65.5 200.5 (3951 & 3958)

Shell Girth Weld i "in

J C:C: -credible surveillance data(g)

C:0 C: 0.718 0.9071 216.9 -56 196.7 17 28 (g) 65.5 206.3 AOFJ 0.718 0.9071 41.0 10 37.2 17 18.6 50.4 97.6 Upper to FOIJ 0.718 0.9071 41.0 10 37.2 17 18.6 50.4 97.6 Intermediate 10-714 EODJ 0.718 0.9071 27.0 10 24.5 17 12.2 41.9 76.4 Shell Girth Weld HOCJ 0.718 0.9071 27.0 10 24.5 17 12.2 41.9 76.4 B6608-1 95443-1 0.0210 0.1773 67.0 48.5 11.9 0 5.9 11.9 72.3 Inlet Nozzles B6608-2 95460-1 0.0210 0.1773 67.0 -15.2 11.9 0 5.9 11.9 8.6 B6608-3 95712-1 0.0210 0.1773 51.0 11.4 9.0 0 4.5 9.0 29.5 EODJ 0.0210 0.1773 27.0 10 4.8 17 2.4 34.3 49.1 FOIJ 0.0210 0.1773 41.0 10 7.3 17 3.6 34.8 52.0 1-717 B HOCJ 0.0210 0.1773 27.0 10 4.8 17 2.4 34.3 49.1 Inlet Nozzle 1-717 D DBIJ 0.0210 0.1773 27.0 10 4.8 17 2.4 34.3 49.1 Welds 1-717 F EOEJ 0.0210 0.1773 20.0 10 3.5 17 1.8 34.2 47.7 ICJJ 0.0210 0.1773 41.0 10 7.3 17 3.6 34.8 52.0 JACJ 0.0210 0.1773 54.0 10 9.6 17 4.8 35.3 54.9 B6605-1 95415-1 0.0161 0.1501 95.3 -26.2 14.3 0 7.2 14.3 2.4 Outlet Nozzles B6605-2 95415-2 0.0161 0.1501 95.3 3.3 14.3 0 7.2 14.3 31.9 B6605-3 95444-1 0.0161 0.1501 58.0 10.1 8.7 0 4.4 8.7 27.5 ICJJ 0.0161 0.1501 41.0 10 6.2 17 3.1 34.6 50.7 IOBJ 0.0161 0.1501 27.0 10 4.1 17 2.0 34.2 48.3 1-717 A Outlet Nozzle JACJ 0.0161 0.1501 54.0 10 8.1 17 4.1 35.0 53.1 1-717 C Welds 1-717 E HOCJ 0.0161 0.1501 27.0 10 4.1 17 2.0 34.2 48.3 EODJ 0.0161 0.1501 27.0 10 4.1 17 2.0 34.2 48.3 FOIJ 0.0161 0.1501 41.0 10 6.2 17 3.1 34.6 50.7 Notes:

(a) Data obtained from Table E-1 of Reference 2.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 26 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-10 (Page 2 of 2)

RTPTS Calculation for Extended Beltline Region Materials at Life Extension (50 EFPY) (a)

Notes continued:

(b) FF = fluence factor = f (0.28 - 0.10 log (f)).

(c) Initial RTNDT value for the upper shell forging, inlet nozzle forgings, and outlet nozzles are based on measured values. All other values are generic.

(d) RTPTS = CF

FF.

(e) M = 2 * (O'U2 + 2 1/2

) . However, 01::,. need not exceed 0.5

RTNDT.

(f) RTPTS = Initial RTNDT + RTPTS + Margin.

(g) The Fort Calhoun surveillance weld metal is the same weld heat as the BVPS-1 upper to intermediate shell girth weld (Heat #305414). The Fort Calhoun surveillance weld data is non-credible; therefore, the higher 01:i term of 28°F was utilized for BVPS-1 weld Heat

305414. This credibility evaluation conclusion is contained in Appendix D of Reference 3 and confirmed in Reference 2.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 27 LRM Revision 103

Licensing Requirements Manual Pressure and Temperature Limits Report 5.2 Table 5.2-11 (Page 1 of 1)

Reactor Vessel Toughness Data (Unirradiated)

UPPER SHELF ENERGY (FT-LB)

Cu Ni P TNDT RTNDT COMPONENT HEAT NO. CODE NO. MATERIAL TYPE

(%) (%) (%) (0 F) (0 F) MWD NMWD Closure Head C6213-1B B6610 A533B CL. 1 .15 --- .010 -40 0* 121 ---

Dome Closure Head A5518-2 B6611 A533B CL. 1 .14 --- .015 -20 -20* 131 ---

Seg.

Closure Head ZV3758 --- A508 CL. 2 .08 --- .007 60* 60* >100 ---

Flange Vessel Flange ZV-3661 FV-2961 A508 CL. 2 .12 --- .010 -54.7** 10** 166 ---

Inlet Nozzle 9-5443-1 B6608-1 A508 CL. 2 .10 .82 .008 35.8** 48.5** 82.5 ---

Inlet Nozzle 9-5460-1 B6608-2 A508 CL. 2 .10 .82 .010 -18.3** -15.2** 94 ---

Inlet Nozzle 9-5712-1 B6608-3 A508 CL. 2 .08 .79 .007 -2.5** 11.4** 97 ---

Outlet Nozzle 9-5415-1 B6605-1 A508 CL. 2 .13 .77 .008 -26.2** -26.2** 93 ---

Outlet Nozzle 9-5415-2 B6605-2 A508 CL. 2 .13 .77 .007 3.0** 3.3** 112.5 ---

Outlet Nozzle 9-5444-1 B6605-3 A508 CL. 2 .09 .79 .007 10.1** 10.1** 103 ---

Upper Shell 123V339VA1 --- A508 CL. 2 .12 .68 .010 40 40* 155 101 Inter Shell C4381-2 B6607-2 A533B CL. 1 .14 .62 .015 -10 53.6 123 83 Inter Shell C4381-1 B6607-1 A533B CL. 1 .14 .62 .015 -10 26.8 128.5 94 Lower Shell C6317-1 B6903-1 A533B CL. 1 .21 .54 .010 -50 13.1 134 83 Lower Shell C6293-2 B7203-2 A533B CL. 1 .14 .57 .015 -20 0.4 129.5 85 Trans Ring 123V223 --- A508 CL. 2 --- --- --- 30 30* 143 ---

Bottom Hd Seg C4423-3 B6618 A533B CL. 1 .13 --- .008 -30 -29* 124 ---

Bottom Hd Dome C4482-1 B6619 A533B CL. 1 .13 --- .015 -50 -33* 125.5 ---

Inter to Lower 90136 --- --- .27 .07 --- --- -56 --- > 100 Shell Weld Inter Shell Long. 305424 --- --- .28 .63 --- --- -56 --- > 100 Weld Lower Shell 305414 --- --- .34 .61 --- --- -56 --- > 100 Long. Weld Weld HAZ --- --- --- -40 -40 --- 136.5

Estimated Per NRC Standard Review Plan Branch Technical Position MTEB 5-2

- Estimated Per BWRVIP-173-A, Alternate Approach 2 MWD Major Working Direction NMWD Normal to Major Working Direction Note: For evaluation of Inservice Reactor Vessel Irradiation damage assessments, the best estimate chemistry values reported in the latest response to Generic Letter 92-01 or equivalent document are applicable.

PTLR Revision 10 Beaver Valley Unit 1 5.2 - 28 LRM Revision 103

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 and/or 10 CFR 72.48 evaluation. If a procedure or revision thereto requires a 10 CFR 50.59 and/or 10 CFR 72.48 evaluation, the Responsible Discipline Manager or his designee shall ensure that the procedure, with the associated 10 CFR 50.59 and/or 10 CFR 72.48 evaluation, is forwarded to the Plant Operations Review Committee for review. Pursuant to 10 CFR 50.59 and 10 CFR 72.48, NRC approval of items involving license amendments 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 FENOC QAPM, Regulatory Guide 1.33 conformance description.

Beaver Valley Unit 1 5.3 - 1 LRM Revision 87

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.

Beaver Valley Unit 1 5.4 - 1 LRM Revision 56

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 and 10 CFR 72.48.

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.

Beaver Valley Unit 1 5.4 - 2 LRM Revision 87

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 3.3 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 lncore Detectors ........................................................................... B 3.3.7-1 B 3.3.8 Leading Edge Flow Meter ........................................................................... B 3.3.8-1 B 3.3.9 Turbine Overspeed Protection .................................................................... B 3.3.9-1 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 3.3.17 Containment Purge and Exhaust Isolation Radiation Monitors ................... B 3.3.17-1 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 Vents ................................................................... B 3.4.5-1 B 3.4.6 Pressurizer Safety Valve Lift Involving Liquid 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 Auxiliary River Water System (ARWS) ........................................................ 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 1 B-i LRM Revision 71

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 3.9 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 B 3.9.4 Containment Purge and Exhaust Isolation System ..................................... B 3.9.4-1 Beaver Valley Unit 1 B-ii LRM Revision 71

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.

Beaver Valley Unit 1 B 3.0 -1 LRM Revision 71

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.

Beaver Valley Unit 1 B 3.0-2 LRM Revision 71

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 FENOC Corrective Action Program.

Entry into LR 3.0.3 may result in the Unit being outside of its design/licensing bases and therefore potentially reportable per 10 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.

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:

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Licensing Requirements Manual LR Applicability B 3.0 BASES LR 3.0.4 (continued)

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 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 200°F, a minimum of two separate and redundant boron injection systems are provided to ensure single functional capability in the event an assumed failure renders one of the systems 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, a low head safety injection pump may be used in lieu of the FUNCTIONAL charging pump with a minimum RCS vent of 2.07 square inches open to the pressurizer relief tank (PRT) or containment atmosphere. 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. The requirement for an RCS vent ensures that the RCS pressure will not exceed the shutoff head of the low head safety injection pumps.

MOV-1Sl-890C is the low head safety injection pump discharge isolation valve to the RCS coldlegs, the valve 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 this valve is 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 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 less than or equal to 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 1.0%

~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 11,336 gallons of 7000 ppm borated water from the boric acid storage tanks.

With the RCS temperature below 200°F, one injection system 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 5000 gallons of 7000 ppm borated water from the boric acid storage tanks or 175,000 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 1 group demand 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 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."

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.

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Licensing Requirements Manual Movable lncore Detectors B 3.3.7 B 3.3 INSTRUMENTATION B 3.3. 7 Movable lncore 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 F0 (Z) or F~H , a full incore flux map is used. Quarter-core flux maps, as defined in WCAP-8648, June 1976, may be used in recalibration 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 in-plant process computer (IPC). If the IPC is unavailable, a manual calculation that accounts for steam generator blowdown is acceptable, and may be performed in lieu of using the IPC.

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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 manufacturer's 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. 1 Updated Final Safety Analysis Report.

The LRS Note allows for entry into the applicability of LR 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 valves 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 testing has been satisfactorily completed to the extent possible and the valves are not otherwise believed to be incapable of performing their function.

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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, "TMl-2 Lessons Learned Task Force Status Report and Short-Term Recommendations."

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Licensing Requirements Manual Containment Purge and Exhaust Isolation Radiation Monitors B 3.3.17 B 3.3 INSTRUMENTATION B 3.3.17 Containment Purge and Exhaust Isolation Radiation Monitors BASES BACKGROUND The Unit 1 Containment Purge and Exhaust Isolation Radiation Monitors provide a backup function to automatically isolate the containment purge and exhaust system penetration flow paths on high radiation to limit the release of radioactive material from the containment to the environment.

The requirements of this LR are applicable during movement of recently irradiated fuel (i.e., fuel that has occupied part of a critical reactor core within the previous 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months ).

The primary means of limiting the release of radioactive material from the Unit 1 containment exhaust to the environment is filtration of the containment exhaust by the Supplemental Leak Collection and Release System (SLCRS). The OPERABILITY requirements for the SLCRS to filter containment exhaust are specified in the Unit 1 Technical Specifications. The FUNCTIONALITY of these radiation monitors ensure that the radiation level in the Purge and Exhaust system is continually measured (during movement of recently irradiated fuel assemblies and during movement of fuel assemblies over recently irradiated fuel assemblies) and that the backup function to SLCRS filtration (i.e., the automatic isolation function of the radiation monitors) is initiated when the radiation level exceeds the setpoint.

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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 spray water differential temperature 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.

The heatup and cooldown rate limits of LR 3.4.3.a and LR 3.4.3.b are specified in UFSAR Table 4.1-10.

The maximum pressurizer spray differential temperature limits of LR 3.4.3.c, LR 3.4.3.d and the Condition B Required Actions are defined by the analysis performed in WCAP-15351.

The analysis of WCAP-15351 includes initiation of normal spray, where the stagnant water prior to establishing flow would be at containment ambient conditions. Once flow is established, the analysis considers a maximum normal spray differential temperature of 320°F as determined from the cold leg to the pressurizer steam space.

The analysis of WCAP-15351 includes several cases of auxiliary spray flow such as drawing flow from the RWST and flow during initial plant heatup. These cases qualify a limited number of occurrences for a differential temperature of up to 380°F. If a differential temperature of 320°F is exceeded, as determined from the charging side outlet of the regenerative heat exchanger to the pressurizer steam space, the event must be tracked in the cycle counting program.

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Licensing Requirements Manual B 3.4.4 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.4 DELETED Beaver Valley Unit 1 B 3.4.4 - 1 LRM Revision 71

Licensing Requirements Manual Reactor Coolant System Vents B 3.4.5 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.5 Reactor Coolant System 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 and the pressurizer steam space, ensures the capability exists to perform this function.

The valve redundancy of the reactor coolant system 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 I1.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 14 accident analyses, but may be used for alternate shutdown capability.

The administrative control specified in LR Note 3 consists of maintaining positive control of the RCS vent valve control switch key(s) associated with the series vent valves required to be maintained closed along with heightened operator awareness of the FUNCTIONAL RCS vent valve being in the open position.

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Licensing Requirements Manual Pressurizer Safety Valve Lift Involving Liquid Discharge B 3.4.6 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.6 Pressurizer Safety Valve Lift Involving Liquid 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 used for the MOVs in Penetrations 1, 2, 4 & 5 in the original BV-1 Technical Specifications and for several other Containment Isolation Valve (CIV) MOVs 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 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 the original Technical Specification or Amendment 1 correspondence. It has been inferred since 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. 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 original or Amendment No. 1 to the BV-1 Technical Specifications.

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. 185 to the BV-1 Technical Specifications added criteria to Technical Specifications 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 Beaver Valley Unit 1 B 3.6.1 - 1 LRM Revision 56

Licensing Requirements Manual Containment Isolation Valves B 3.6.1 BASES BACKGROUND (continued)

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. 261 to the BV-1 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 700 F and 200 psig are based on steam generator average impact values taken at 10 0 F and are sufficient to prevent brittle fracture.

The applicability is limited to whenever the temperature of the primary or secondary coolant of the associated steam generator is s 70 0 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 lnservice 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 1980's, snubber surveillance requirements were identified in three documents: Section XI of the ASME Boiler and Pressure Vessel (B&PV) Code, a plant's Technical Specifications and Part 4 of the ASME Operation and Maintenance (OM) Code. The three documents were similar in purpose and concept - demonstrate and ensure snubber functional integrity through periodic visual examination, sample testing and service life monitoring. However, they varied enough in details 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 lnservice 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 plant's 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 system's 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.

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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 CC-HSS-001A No Single train to B RPC CC-HSS-001B No Single train to B RPC CC-HSS-021A No Single train to A RPC CC-HSS-021B No Single train to A RPC CC-HSS-401 No Redundant trains CC-HSS-402 No Redundant trains CC-HSS-403 No Redundant trains CC-HSS-404 No Common pipe from CC pumps to CC Hx CC-HSS-405 No Single train CC-HSS-406A No Redundant train to A Hx CC-HSS-406B No Redundant train to A Hx CC-HSS-407A No Redundant train to B Hx CC-HSS-407B No Redundant train to B Hx CC-HSS-408 No Redundant train to B Hx CC-PSSP-300A No Common piping to RH Hx's CC-PSSP-300B No Common piping to RH Hx's CC-PSSP-301 No Common piping to RH Hx's FC-HSS-201 No Redundant train to A Hx Beaver Valley Unit 1 B 3.7.4 - 3 LRM Revision 60

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 FC-HSS-5A No Redundant train to B Hx PS-243-VS-1 No Redundant trains of charging system PS-244-VS-1 No Redundant trains of charging system PS-245-VS-1 No Redundant trains of charging system QS-HSS-202 Yes QS Pump Start waterhammer QS-HSS-205A Yes QS Pump Start waterhammer QS-HSS-205B Yes QS Pump Start waterhammer RC-HC-10B Yes Line break waterhammer RC-HC-10C Yes Line break waterhammer RC-HC-11A Yes Line break waterhammer RC-HC-12C Yes Line break waterhammer RC-HC-9A Yes Line break waterhammer RC-HC-9B Yes Line break waterhammer RC-HSS-1 No Single train Pressurizer spray RC-HSS-101 Yes Line break waterhammer RC-HSS-102 Yes Line break waterhammer RC-HSS-103 Yes Line break waterhammer RC-HSS-104 Yes Line break waterhammer RC-HSS-105 Yes Line break waterhammer Beaver Valley Unit 1 B 3.7.4 - 4 LRM Revision 60

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 RC-HSS-106 Yes Line break waterhammer RC-HSS-119 Yes PORV and Safety Valve discharge RC-HSS-126 Yes PORV and Safety Valve discharge RC-HSS-127 Yes PORV and Safety Valve discharge RC-HSS-130 Yes Line break waterhammer RC-HSS-131 Yes Line break waterhammer RC-HSS-2 No Single train Pressurizer spray RC-HSS-23 No Single train Pressurizer spray RC-HSS-3 No Single train Pressurizer spray RC-HSS-302 Yes PORV and Safety Valve discharge RC-HSS-303A Yes PORV and Safety Valve discharge RC-HSS-303B Yes PORV and Safety Valve discharge RC-HSS-4 No Single train Pressurizer spray RC-HSS-41A Yes PORV and Safety Valve discharge RC-HSS-42A-A Yes PORV and Safety Valve discharge RC-HSS-42A-B Yes PORV and Safety Valve discharge RC-HSS-44A Yes PORV and Safety Valve discharge RC-PSSP-115 Yes PORV and Safety Valve discharge RC-PSSP-116 Yes PORV and Safety Valve discharge Beaver Valley Unit 1 B 3.7.4 - 5 LRM Revision 79

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 RC-PSSP-122A Yes PORV and Safety Valve discharge RC-PSSP-122B Yes PORV and Safety Valve discharge RC-PSSP-128 Yes PORV and Safety Valve discharge RC-PSSP-129 Yes PORV and Safety Valve discharge RC-PSSP-20 Yes PORV and Safety Valve discharge RC-PSSP-24A Yes PORV and Safety Valve discharge RC-PSSP-24B Yes PORV and Safety Valve discharge RC-PSSP-25A Yes PORV and Safety Valve discharge RC-PSSP-25B Yes PORV and Safety Valve discharge RC-PSSP-301 Yes PORV and Safety Valve discharge RH-HSS-101 No Common RH return piping RH-HSS-102 No Common RH return piping RH-HSS-105 Yes Line break waterhammer RH-HSS-106 Yes Line break waterhammer RH-HSS-107 Yes Line break waterhammer RH-HSS-108 Yes Line break waterhammer RH-HSS-109 Yes Line break waterhammer Beaver Valley Unit 1 B 3.7.4 - 6 LRM Revision 60

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 RH-HSS-110 Yes Line break waterhammer RH-HSS-111 Yes Line break waterhammer RH-HSS-112 Yes Line break waterhammer RH-HSS-113 Yes Line break waterhammer RH-HSS-114 Yes Line break waterhammer RH-HSS-121 No Redundant train RH-720B RH-HSS-122 No Redundant train RH-720B RH-HSS-123 No Redundant train RH-720B RH-HSS-124 No Redundant train RH-720B RH-HSS-203 No Single train from RH to RWST RH-HSS-204A No Single train from RH to RWST RH-HSS-204B No Single train from RH to RWST RH-HSS-402 No Single train from RH to RWST RH-HSS-403 No Single train from RH to RWST RS-HSS-201 Yes RS Pump start waterhammer RS-HSS-202 Yes RS Pump start waterhammer RS-HSS-209A Yes RS Pump start waterhammer RS-HSS-210A Yes RS Pump start waterhammer RS-HSS-219 Yes RS Pump start waterhammer Beaver Valley Unit 1 B 3.7.4 - 7 LRM Revision 60

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 RS-HSS-220 Yes RS Pump start waterhammer RS-HSS-221 Yes RS Pump start waterhammer RS-HSS-229 Yes RS Pump start waterhammer RS-HSS-234 Yes RS Pump start waterhammer RS-HSS-237 Yes RS Pump start waterhammer RS-HSS-238 Yes RS Pump start waterhammer SHP-HSS-201 Yes Main Steam Line break SHP-HSS-202 Yes Main Steam Line break SHP-HSS-203 Yes Main Steam Line break SHP-HSS-204 Yes Main Steam Line break SHP-HSS-205 Yes Main Steam Line break SHP-HSS-206 Yes Main Steam Line break SHP-HSS-207 Yes Main Steam Line break SHP-HSS-208 Yes Main Steam Line break SHP-HSS-209 Yes Main Steam Line break SHP-HSS-210 Yes Main Steam Line break SHP-HSS-211 Yes Main Steam Line break SHP-HSS-212 Yes Main Steam Line break SHP-HSS-213 Yes Main Steam Line break Beaver Valley Unit 1 B 3.7.4 - 8 LRM Revision 60

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 SHP-HSS-214 Yes Main Steam Line break SHP-HSS-214A Yes Main Steam Line break SI-HSS-114A Yes Line break waterhammer SI-HSS-114B Yes Line break waterhammer SI-HSS-212A Yes SI Pump start waterhammer SI-HSS-212B Yes SI Pump start waterhammer SI-HSS-409 No Common portion of SI trains SI-HSS-410 No Common portion of SI trains SI-HSS-411 No Common portion of SI trains SI-HSS-412 No Single train portion of SI SI-HSS-413 No Single train portion of SI SI-HSS-414 No Single train portion of SI SI-HSS-415 No Single train portion of SI SI-HSS-416 No Single train portion of SI SI-HSS-417 No Single train portion of SI SI-HSS-418 No Single train portion of SI SI-HSS-419 No Single train portion of SI SI-HSS-420 No Common portion of SI trains Beaver Valley Unit 1 B 3.7.4 - 9 LRM Revision 60

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 SI-HSS-421 No Common portion of SI trains SI-HSS-422 No Common portion of SI trains SI-HSS-423 No Common portion of SI trains SI-HSS-511 No Redundant flow paths LH to HH pumps SI-HSS-512 No Redundant flow paths LH to HH pumps SI-HSS-512A No Redundant flow paths LH to HH pumps SI-HSS-514 No Redundant flow paths LH to HH pumps SI-HSS-515 No Redundant flow paths LH to HH pumps SI-HSS-516A No Redundant flow paths LH to HH pumps SI-HSS-516B No Redundant flow paths LH to HH pumps SI-HSS-517 No Redundant flow paths LH to HH pumps SI-HSS-518 No Redundant flow paths LH to HH pumps SI-HSS-519 No Redundant flow paths LH to HH pumps SI-HSS-520 No Redundant flow paths LH to HH pumps SI-HSS-521 No Redundant flow paths LH to HH pumps SI-HSS-522 No Common pipe for HH suction headers SI-HSS-523A No Common pipe for HH suction headers SI-HSS-523B No Common pipe for HH suction headers RS Pump start SI-PSSP-002 Yes waterhammer Beaver Valley Unit 1 B 3.7.4 - 10 LRM Revision 60

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 SI-PSSP-003 Yes RS Pump start waterhammer SI-PSSP-009 Yes RS Pump start waterhammer SI-PSSP-010 Yes RS Pump start waterhammer SI-PSSP-033A Yes SI Pump start waterhammer SI-PSSP-036A Yes SI Pump start waterhammer SI-PSSP-060D Yes SI Pump start waterhammer SI-PSSP-067C Yes SI Pump start waterhammer SI-PSSP-337 No Common portion of SI trains VS-357-1 No Redundant trains of drain system VS-358-1 No Redundant trains of drain system VS-359-1 No Redundant trains of drain system WFPD-HSS-201 Yes Feedwater waterhammer events (1)

WFPD-HSS-202 Yes Feedwater waterhammer events (1)

WFPD-HSS-203 Yes Feedwater waterhammer events (1)

WFPD-HSS-204 Yes Feedwater waterhammer events (1)

WFPD-HSS-205 Yes Feedwater waterhammer events (1)

WFPD-HSS-206 Yes Feedwater waterhammer events (1)

WFPD-HSS-207 Yes Feedwater waterhammer events (1)

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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 WFPD-HSS-208 Yes Feedwater waterhammer events (1)

WFPD-HSS-208A Yes Feedwater waterhammer events (1)

WFPD-HSS-209 Yes Feedwater waterhammer events (1)

WFPD-HSS-210 Yes Feedwater waterhammer events (1)

WFPD-HSS-211 Yes Feedwater waterhammer events (1)

WFPD-HSS-212 Yes Feedwater waterhammer events (1)

WFPD-HSS-212A Yes Feedwater waterhammer events (1)

WFPD-HSS-228 Yes Feedwater waterhammer events (1)

WFPD-HSS-229 Yes Feedwater waterhammer events (1)

WFPD-HSS-230 Yes Feedwater waterhammer events (1)

WFPD-HSS-231 Yes Feedwater waterhammer events (1)

WFPD-HSS-232 Yes Feedwater waterhammer events (1)

WFPD-HSS-233 Yes Feedwater waterhammer events (1)

WGCB-H-47A Yes S/G blowdown waterhammer WGCB-PSSP-101 Yes S/G blowdown waterhammer WGCB-PSSP-200A Yes S/G blowdown waterhammer WGCB-PSSP-200B Yes S/G blowdown waterhammer WGCB-PSSP-200C Yes S/G blowdown waterhammer WGCB-PSSP-200D Yes S/G blowdown waterhammer Beaver Valley Unit 1 B 3.7.4 - 12 LRM Revision 89

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 WGCB-PSSP-46E Yes S/G blowdown waterhammer WGCB-PSSP-46F Yes S/G blowdown waterhammer WGCB-PSSP-46G Yes S/G blowdown waterhammer WGCB-PSSP-46H Yes S/G blowdown waterhammer WGCB-PSSP-55E Yes S/G blowdown waterhammer WGCB-PSSP-55F Yes S/G blowdown waterhammer WGCB-PSSP-55G Yes S/G blowdown waterhammer WGCB-PSSP-55H Yes S/G blowdown waterhammer WR-HSS-300 No Common pipe to/from RSS Hx's WR-HSS-301 No Common pipe to/from RSS Hx's WR-HSS-302 No Common pipe to/from RSS Hx's WR-HSS-303A No Common supply pipe to CC Hx's WR-HSS-303B No Common supply pipe to CC Hx's WR-HSS-304A No Common return pipe from CC Hx's WR-HSS-304B No Common return pipe from CC Hx's WR-HSS-306 No Common pipe to/from RSS Hx's WR-HSS-307 No Common pipe to/from RSS Hx's WR-HSS-308 No Common pipe to/from RSS Hx's Beaver Valley Unit 1 B 3.7.4 - 13 LRM Revision 60

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 WR-HSS-309 No Common pipe to/from RSS Hx's WR-HSS-310 No Common supply pipe to CC Hx's WR-HSS-311 No Common supply pipe to CC Hx's WR-HSS-312 No Common supply pipe to CC Hx's WR-HSS-313 No Common supply pipe to CC Hx's WR-HSS-314 No Common return pipe from CC Hx's WR-HSS-316 No Common pipe to/from RSS Hx's (1) Events include: feedwater line break, pump trip, valve closure, and check valve slam.

Beaver Valley Unit 1 B 3.7.4 - 14 LRM Revision 89

Licensing Requirements Manual Auxiliary River Water System (ARWS)

B 3.7.5 B 3. 7 PLANT SYSTEMS B 3. 7.5 Auxiliary River Water System (ARWS)

BASES BACKGROUND The FUNCTIONALITY of the ARWS 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 River Water System supply pumps Nonfunctional. The scenario of a postulated gasoline barge impact with the intake structure and coincident explosion disabling the Reactor Plant River Water System (RPRWS) is a low probability event. Nonetheless, the ARWS provides defense in-depth in assuring shutdown cooling capability. The requirement to operate the ARWS is not coincident with a postulated Design Basis Accident, but only for the postulated gasoline barge impact event.

Although the ARWS is a manually operated 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 ARWS pump can be manually started on the emergency bus during loss of offsite power after the diesel loading sequence is complete. If there is a delay in starting the ARWS, 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 RPRWS 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 RPRWS being disabled as a result of the postulated site scenario coincident with one of the ARWS subsystems being FUNCTIONAL.

The STAGGERED TEST BASIS for LRS 3. 7 .5.2 ensures that each ARWS pump is periodically full flow tested.

Beaver Valley Unit 1 B 3.7.5 - 1 LRM Revision 72

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 1 B 3.7.6 - 1 LRM Revision 56

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 Main Steam Valve Room and Emergency Air Lock. No credit for SLCRS operation was taken in the OBA 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.

Beaver Valley Unit 1 B 3.7.7 - 1 LRM Revision 71

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 1 B 3.8.1 - 1 LRM Revision 56

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 1 B 3.8.2 - 1 LRM Revision 56

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 14 of the BVPS Unit 1 UFSAR will be ruptured. This assumption is consistent with the activity release assumed in the accident analyses.

Single Failure Proof Crane 1CR-15 travels from the Decontamination Building into the Fuel Building over the cask pit. It cannot physically travel over the spent fuel racks in the storage pool. The yoke assembly and associated rigging used for movement of dry cask components with 1CR-15 are single failure proof. Drops of heavy loads for lifts by crane 1CR-15 over the cask pit are not postulated due to 1CR-15 being a single failure proof crane and use of single failure proof rigging.

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 1 B 3.9.1 - 1 LRM Revision 87

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 1 B 3.9.2 -1 LRM Revision 71

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 1 B 3.9.3 -1 LRM Revision 75

Licensing Requirements Manual Containment Purge and Exhaust Isolation System B 3.9.4 B 3.9 REFUELING OPERATIONS B 3.9.4 Containment Purge and Exhaust Isolation System BASES BACKGROUND The Unit 1 Containment Purge and Exhaust Isolation System provides a backup function to limit the leakage of radioactive material from within containment to the environment. The primary means of limiting the leakage of radioactive material from containment is filtration by the Supplemental Leak Collection and Release System (SLCRS). The Unit 1 Technical Specifications contain the appropriate requirements for SLCRS.

The LR is applicable during movement of recently irradiated fuel assemblies and during movement of fuel assemblies over recently irradiated fuel assemblies because there is a potential for the limiting fuel handling accident (FHA) to occur. Therefore, the requirements of this Specification may be required to limit leakage of radioactive material within the containment to the environment. A FHA which does not involve recently irradiated fuel (i.e., fuel that has occupied part of a critical reactor core within the previous 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months ) will result in radiation exposures that are within the guideline values specified in 10 CFR 50.67 without any reliance on the requirements of this Specification to limit leakage to the environment. The 100 hour0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months limit is based on the current radiological analysis for a FHA which assumes a decay time of 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months . LR 3.9.3 prohibits irradiated fuel movement unless 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months of decay has occurred. Therefore, this LR will not be applicable unless the decay time in LR 3.9.3 and the time assumed in the radiological analysis for a FHA are reduced to below 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months .

Beaver Valley Unit 1 B 3.9.4 - 1 LRM Revision 56

ML20160A078

Text

3.6.3. APPLICABILITY

Reference:

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