Text

Technical Requirements Manual
	ML21008A422
Person / Time
Site:	Braidwood
Issue date:	12/17/2020
From:	; Exelon Generation Co LLC
To:	; Office of Nuclear Reactor Regulation, Office of Nuclear Material Safety and Safeguards
Shared Package
ML21008A383	List: ML21008A380; ML21008A386; ML21008A387; ML21008A388; ML21008A389; ML21008A392; ML21008A394; ML21008A397; ML21008A399; ML21008A401; ML21008A402; ML21008A403; ML21008A404; ML21008A405; ML21008A406; ML21008A408; ML21008A409; ML21008A410; ML21008A411; ML21008A413; ML21008A414; ML21008A416; ML21008A417; ML21008A418; ML21008A420; ML21008A421; ML21008A422; ML21008A426; ML21137A191; ML21137A207; ML21137A221; ML21137A238; ML21137A246; ML21137A251; ML21137A253; RS-20-153, Amendment 29 to Fire Protection Report, Chapter 3, Guidelines of BTP Cmeb 9.5-1;
References
	RS-20-153
	Download: ML21008A422 (492)
	v • d • e

Braidwood Station Technical Requirements Manual (TRM)

Braidwood Station, Units 1 and 2 Renewed Facility Operating License Nos. NPF-72 and NPF-77 NRC Docket Nos. STN 50-456, STN 50-457 and 72-73

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL 1.0 USE AND APPLICATION 1.1-1 .......................................Revision 1 1.1-2 .......................................Revision 69 1.1-3 .......................................Revision 100 1.1-4 .......................................Revision 84 1.1-5 .......................................Revision 75 1.1-6 .......................................Revision 75 1.1-7 .......................................Revision 93 1.2-1 .......................................Revision 1 1.2-2 .......................................Revision 1 1.2-3 .......................................Revision 1 1.3-1 .......................................Revision 98 1.3-2 .......................................Revision 98 1.3-3 .......................................Revision 1 1.3-4 .......................................Revision 1 1.3-5 .......................................Revision 1 1.3-6 .......................................Revision 1 1.3-7 .......................................Revision 1 1.3-8 .......................................Revision 1 1.3-9 .......................................Revision 1 1.3-10 ......................................Revision 1 1.3-11 ......................................Revision 1 1.3-12 ......................................Revision 1 1.3-13 ......................................Revision 1 1.3-14 ......................................Revision 1 1.4-1 .......................................Revision 1 1.4-2 .......................................Revision 38 1.4-3 .......................................Revision 1 1.4-4 .......................................Revision 1 1.4-5 .......................................Revision 1 1.4-6 .......................................Revision 1 1.4-7 .......................................Revision 1 1.5-1 .......................................Revision 1 1.6-1 .......................................Revision 13 2.0.a RTS INSTRUMENTATION TRIP SETPOINTS 2.0.a-1 .....................................Revision 52 2.0.a-2 .....................................Revision 52 2.0.a-3 .....................................Revision 52 2.0.b ESFAS INSTRUMENTATION TRIP SETPOINTS 2.0.b-1 .....................................Revision 52 2.0.b-2 .....................................Revision 52 2.0.b-3 .....................................Revision 92 2.0.b-4 .....................................Revision 95 2.0.c BDPS INSTRUMENTATION TRIP SETPOINT 2.0.c-1 .....................................Revision 52 BRAIDWOOD UNITS 1 & 2 i Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL 2.1.a MISCELLANEOUS TEST REQUIREMENTS 2.1.a-1 .....................................Revision 101 2.1.a-2 .....................................Revision 106 2.1.a-3 .....................................Revision 106 2.1.a-4 .....................................Revision 1 2.1.a-5 .....................................Revision 28 2.1.a-6 .....................................Revision 28 2.1.a-7 .....................................Revision 62 2.1.a-8 .....................................Revision 62 2.1.a-9 .....................................Revision 62 2.1-a-10 ....................................Revision 62 3.0 TRM LIMITING CONDITION FOR OPERATION (TLCO) AND SURVEILLANCE REQUIREMENT (TSR) APPLICABILITY 3.0-1 .......................................Revision 1 3.0-2 .......................................Revision 98 3.0-3 .......................................Revision 1 3.0-4 .......................................Revision 98 3.0-5 .......................................Revision 37 3.1 REACTIVITY CONTROL SYSTEMS 3.1.a-1 .....................................Revision 6 3.1.a-2 .....................................Revision 1 3.1.b-1 .....................................Revision 1 3.1.b-2 .....................................Revision 1 3.1.b-3 .....................................Revision 90 3.1.c-1 .....................................Revision 100 3.1.d-1 .....................................Revision 100 3.1.e-1 .....................................Revision 6 3.1.e-2 .....................................Revision 1 3.1.e-3 .....................................Revision 88 3.1.f-1 .....................................Revision 1 3.1.f-2 .....................................Revision 1 3.1.g-1 .....................................Revision 11 3.1.g-2 .....................................Revision 11 3.1.h-1 .....................................Revision 1 3.1.h-2 .....................................Revision 1 3.1.i-1 .....................................Revision 18 3.1.i-2 .....................................Revision 1 3.1.j-1 .....................................Revision 1 3.1.j-2 .....................................Revision 1 3.1.k-1 .....................................Revision 14 3.1.k-2 .....................................Revision 11 3.1.k-3 .....................................Revision 11 3.2 POWER DISTRIBUTION LIMITS None BRAIDWOOD UNITS 1 & 2 ii Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL 3.3 INSTRUMENTATION 3.3.a-1 .....................................Revision 29 3.3.a-2 .....................................Revision 12 3.3.b-1 .....................................Revision 1 3.3.b-2 .....................................Revision 99 3.3.b-3 .....................................Revision 99 3.3.b-4 .....................................Revision 99 3.3.c-1 .....................................Revision 1 3.3.c-2 .....................................Revision 1 3.3.c-3 .....................................Revision 1 3.3.d-1 .....................................Revision 1 3.3.d-2 .....................................Revision 1 3.3.d-3 .....................................Revision 1 3.3.e-1 .....................................Revision 1 3.3.e-2 .....................................Revision 1 3.3.e-3 .....................................Revision 1 3.3.e-4 .....................................Revision 46 3.3.f-1 .....................................Revision 1 3.3.f-2 .....................................Revision 1 3.3.f-3 .....................................Revision 49 3.3.g-1 .....................................Revision 57 3.3.g-2 .....................................Revision 57 3.3.g-3 .....................................Revision 97 3.3.g-4 .....................................Revision 8 3.3.g-5 .....................................Revision 70 3.3.g-6 .....................................Revision 57 3.3.h-1 .....................................Revision 16 3.3.h-2 .....................................Revision 102 3.3.h-3 .....................................Revision 16 3.3.h-4 .....................................Revision 16 3.3.h-5 .....................................Revision 16 3.3.i-1 .....................................Revision 37 3.3.i-2 .....................................Revision 1 3.3.i-3 .....................................Revision 1 3.3.i-4 .....................................Revision 1 3.3.j-1 .....................................Revision 38 3.3.j-2 .....................................Revision 38 3.3.k-1 .....................................Revision 84 3.3.k-2 .....................................Revision 91 3.3.o-1 .....................................Revision 1 3.3.o-2 .....................................Revision 1 3.3.o-3 .....................................Revision 1 3.3.o-4 .....................................Revision 1 3.3.p-1 .....................................Revision 1 3.3.p-2 .....................................Revision 1 3.3.p-3 .....................................Revision 1 3.3.p-4 .....................................Revision 87 3.3.y-1 .....................................Revision 78 BRAIDWOOD UNITS 1 & 2 iii Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL 3.3.y-2 .....................................Revision 78 3.3.y-3 .....................................Revision 78 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.b-1 .....................................Revision 1 3.4.b-2 .....................................Revision 1 3.4.b-3 .....................................Revision 40 3.4.b-4 .....................................Revision 1 3.4.c-1 .....................................Revision 1 3.4.c-2 .....................................Revision 1 3.4.e-1 .....................................Revision 34 3.4.e-2 .....................................Revision 37 3.4.e-3 .....................................Revision 34 3.4.f-1 .....................................Revision 82 3.4.f-2 .....................................Revision 82 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.a-1 .....................................Revision 1 3.5.a-2 .....................................Revision 1 3.6 CONTAINMENT SYSTEMS None 3.7 PLANT SYSTEMS 3.7.a-1 .....................................Revision 1 3.7.a-2 .....................................Revision 1 3.7.b-1 .....................................Revision 81 3.7.b-2 .....................................Revision 104 3.7.b-3 .....................................Revision 104 3.7.b-4 .....................................Revision 104 3.7.b-5 .....................................Revision 104 3.7.c-1 .....................................Revision 1 3.7.c-2 .....................................Revision 1 3.7.c-3 .....................................Revision 1 3.7.d-1 .....................................Revision 1 3.7.d-2 .....................................Revision 1 3.7.d-3 .....................................Revision 24 3.7.g-1 .....................................Revision 100 3.7.g-2 .....................................Revision 100 3.7.i-1 .....................................Revision 77 3.7.i-2 .....................................Revision 1 3.7.j-1 .....................................Revision 1 3.7.k-1 .....................................Revision 21 BRAIDWOOD UNITS 1 & 2 iv Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL 3.8 ELECTRICAL POWER SYSTEMS 3.8.a-1 .....................................Revision 37 3.8.a-2 .....................................Revision 1 3.8.a-3 .....................................Revision 1 3.8.a-4 .....................................Revision 1 3.8.a-5 .....................................Revision 1 3.8.a-6 .....................................Revision 1 3.8.a-7 .....................................Revision 46 3.8.a-8 .....................................Revision 46 3.8.a-9 .....................................Revision 46 3.8.a-10 ....................................Revision 46 3.8.a-11 ....................................Revision 46 3.8.a-12 ....................................Revision 46 3.8.a-13 ....................................Revision 46 3.8.a-14 ....................................Revision 46 3.8.a-15 ....................................Revision 46 3.8.a-16 ....................................Revision 46 3.8.a-17 ....................................Revision 46 3.8.a-18 ....................................Revision 46 3.8.a-19 ....................................Revision 46 3.8.a-20 ....................................Revision 46 3.8.b-1 .....................................Revision 1 3.8.b-2 .....................................Revision 97 3.8.b-3 .....................................Revision 88 3.8.b-4 .....................................Revision 1 3.8.b-5 .....................................Revision 76 3.8.b-6 .....................................Revision 88 3.8.b-7 .....................................Revision 1 3.8.b-8 .....................................Revision 85 3.8.c-1 .....................................Revision 26 3.8.c-2 .....................................Revision 26 3.8.c-3 .....................................Revision 63 3.8.c-4 .....................................Revision 63 3.8.c-5 .....................................Revision 26 3.9 REFUELING OPERATIONS 3.9.a-1 .....................................Revision 89 3.9.a-2 .....................................Revision 89 3.9.a-3 .....................................Revision 89 3.9.a-4 .....................................Revision 89 3.9.a-5 .....................................Revision 89 3.9.a-6 .....................................Revision 89 3.9.a-7 .....................................Revision 89 3.9.a-8 .....................................Revision 89 3.9.a-9 .....................................Revision 89 3.9.a-10 ....................................Revision 89 3.9.a-11 ....................................Revision 89 3.9.b-1 .....................................Revision 1 3.9.c-1 .....................................Revision 17 BRAIDWOOD UNITS 1 & 2 v Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL 3.9.c-2 .....................................Revision 17 3.9.d-1 .....................................Revision 75 3.9.d-2 .....................................Revision 75 3.9.e-1 .....................................Revision 1 4.0 DESIGN FEATURES None 5.0 ADMINISTRATIVE CONTROLS 5.1-1 .......................................Revision 1 5.2-1 .......................................Revision 1 5.2-2 .......................................Revision 1 5.2-3 .......................................Revision 1 5.3-1 .......................................Revision 1 5.3-2 .......................................Revision 1 5.3-3 .......................................Revision 1 APPENDICES Appendix A ODCM AND RADIOLOGICAL CONTROLS REPORTS AND PROGRAM 1 of 5 ......................................Revision 33 2 of 5 ......................................Revision 33 3 of 5 ......................................Revision 33 4 of 5 ......................................Revision 33 5 of 5 ......................................Revision 33 Appendix B PRIMARY COOLANT SOURCES OUTSIDE CONTAINMENT 1 of 4 ......................................Revision 58 2 of 4 ......................................Revision 58 3 of 4 ......................................Revision 58 4 of 4 ......................................Revision 58 Appendix C Not used Appendix D RADIOACTIVE EFFLUENT CONTROLS PROGRAM 1 of 5 ......................................Revision 33 2 of 5 ......................................Revision 33 3 of 5 ......................................Revision 33 4 of 5 ......................................Revision 33 5 of 5 ......................................Revision 33 Appendix E TRANSIENT MONITORING PROGRAM 1 of 6 ......................................Revision 1 2 of 6 ......................................Revision 1 3 of 6 ......................................Revision 1 4 of 6 ......................................Revision 1 5 of 6 ......................................Revision 1 6 of 6 ......................................Revision 1 BRAIDWOOD UNITS 1 & 2 vi Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL Appendix F PRE-STRESSED CONCRETE CONTAINMENT TENDON SURVEILLANCE PROGRAM 1 of 5 ......................................Revision 61 2 of 5 ......................................Revision 61 3 of 5 ......................................Revision 61 4 of 5 ......................................Revision 61 5 of 5 ......................................Revision 61 Appendix G REACTOR COOLANT PUMP FLYWHEEL INSPECTION PROGRAM 1 of 5 ......................................Revision 71 2 of 5 ......................................Revision 71 3 of 5 ......................................Revision 71 4 of 5 ......................................Revision 71 5 of 5 ......................................Revision 71 Appendix H Not used Appendix I STEAM GENERATOR PROGRAM 1 of 9 ......................................Revision 101 2 of 9 ......................................Revision 101 3 of 9 ......................................Revision 101 4 of 9 ......................................Revision 101 5 of 9 ......................................Revision 101 6 of 9 ......................................Revision 101 7 of 9 ......................................Revision 101 8 of 9 ......................................Revision 101 9 of 9 ......................................Revision 101 Appendix J SECONDARY WATER CHEMISTRY 1 of 5 ......................................Revision 1 2 of 5 ......................................Revision 1 3 of 5 ......................................Revision 1 4 of 5 ......................................Revision 1 5 of 5 ......................................Revision 1 BRAIDWOOD UNITS 1 & 2 vii Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL Appendix K VENTILATION FILTER TESTING PROGRAM 1 of 15 .....................................Revision 65 2 of 15 .....................................Revision 65 3 of 15 .....................................Revision 65 4 of 15 .....................................Revision 65 5 of 15 .....................................Revision 65 6 of 15 .....................................Revision 65 7 of 15 .....................................Revision 65 8 of 15 .....................................Revision 65 9 of 15 .....................................Revision 65 10 of 15 ....................................Revision 65 11 of 15 ....................................Revision 65 12 of 15 ....................................Revision 65 13 of 15 ....................................Revision 65 14 of 15 ....................................Revision 65 15 of 15 ....................................Revision 65 Appendix L EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM 1 of 7 ......................................Revision 44 2 of 7 ......................................Revision 44 3 of 7 ......................................Revision 44 4 of 7 ......................................Revision 44 5 of 7 ......................................Revision 44 6 of 7 ......................................Revision 44 7 of 7 ......................................Revision 44 Appendix M DIESEL FUEL OIL TESTING PROGRAM 1 of 9 ......................................Revision 103 2 of 9 ......................................Revision 103 3 of 9 ......................................Revision 103 4 of 9 ......................................Revision 103 5 of 9 ......................................Revision 103 6 of 9 ......................................Revision 103 7 of 9 ......................................Revision 103 8 of 9 ......................................Revision 103 9 of 9 ......................................Revision 103 Appendix N TECHNICAL SPECIFICATION BASES CONTROL PROGRAM 1 of 13 .....................................Revision 64 2 of 13 .....................................Revision 64 3 of 13 .....................................Revision 64 4 of 13 .....................................Revision 64 5 of 13 .....................................Revision 64 6 of 13 .....................................Revision 64 7 of 13 .....................................Revision 64 8 of 13 .....................................Revision 64 9 of 13 .....................................Revision 64 10 of 13 ....................................Revision 64 BRAIDWOOD UNITS 1 & 2 viii Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL Appendix N 11 of 13 ....................................Revision 64 (continued) 12 of 13 ....................................Revision 64 13 of 13 ....................................Revision 64 Appendix O SAFETY FUNCTION DETERMINATION PROGRAM 1 of 43 .....................................Revision 106 2 of 43 .....................................Revision 106 3 of 43 .....................................Revision 106 4 of 43 .....................................Revision 106 5 of 43 .....................................Revision 106 6 of 43 .....................................Revision 106 7 of 43 .....................................Revision 106 8 of 43 .....................................Revision 106 9 of 43 .....................................Revision 106 10 of 43 ....................................Revision 106 11 of 43 ....................................Revision 106 12 of 43 ....................................Revision 106 13 of 43 ....................................Revision 106 14 of 43 ....................................Revision 106 15 of 43 ....................................Revision 106 16 of 43 ....................................Revision 106 17 of 43 ....................................Revision 106 18 of 43 ....................................Revision 106 19 of 43 ....................................Revision 106 20 of 43 ....................................Revision 106 21 of 43 ....................................Revision 106 22 of 43 ....................................Revision 106 23 of 43 ....................................Revision 106 24 of 43 ....................................Revision 106 25 of 43 ....................................Revision 106 26 of 43 ....................................Revision 106 27 of 43 ....................................Revision 106 28 of 43 ....................................Revision 106 29 of 43 ....................................Revision 106 30 of 43 ....................................Revision 106 31 of 43 ....................................Revision 106 32 of 43 ....................................Revision 106 33 of 43 ....................................Revision 106 34 of 43 ....................................Revision 106 35 of 43 ....................................Revision 106 36 of 43 ....................................Revision 106 37 of 43 ....................................Revision 106 38 of 43 ....................................Revision 106 39 of 43 ....................................Revision 106 40 of 43 ....................................Revision 106 41 of 43 ....................................Revision 106 42 of 43 ....................................Revision 106 43 of 43 ....................................Revision 106 BRAIDWOOD UNITS 1 & 2 ix Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL Appendix P CONTAINMENT LEAKAGE RATE TESTING PROGRAM 1 of 6 ......................................Revision 105 2 of 6 ......................................Revision 105 3 of 6 ......................................Revision 105 4 of 6 ......................................Revision 105 5 of 6 ......................................Revision 105 6 of 6 ......................................Revision 105 Appendix Q Not Used Appendix R Not Used Appendix S TECHNICAL REQUIREMENTS MANUAL CONTROL PROGRAM 1 of 12 .....................................Revision 64 2 of 12 .....................................Revision 64 3 of 12 .....................................Revision 64 4 of 12 .....................................Revision 64 5 of 12 .....................................Revision 64 6 of 12 .....................................Revision 64 7 of 12 .....................................Revision 64 8 of 12 .....................................Revision 64 9 of 12 .....................................Revision 64 10 of 12 ....................................Revision 64 11 of 12 ....................................Revision 64 12 of 12 ....................................Revision 64 Appendix T CONFIGURATION RISK MANAGEMENT PROGRAM 1 of 4 ......................................Revision 9 2 of 4 ......................................Revision 9 3 of 4 ......................................Revision 9 4 of 4 ......................................Revision 9 Appendix U BATTERY MONITORING AND MAINTENANCE PROGRAM 1 of 4 ......................................Revision 26 2 of 4 ......................................Revision 26 3 of 4 ......................................Revision 26 4 of 4 ......................................Revision 26 B 3.8.c-1 ...................................Revision 26 B 3.8.c-2 ...................................Revision 26 B 3.8.c-3 ...................................Revision 26 B 3.8.c-4 ...................................Revision 26 B 3.8.c-5 ...................................Revision 26 B 3.8.c-6 ...................................Revision 26 B 3.8.c-7 ...................................Revision 26 B 3.8.c-8 ...................................Revision 26 B 3.8.c-9 ...................................Revision 26 BRAIDWOOD UNITS 1 & 2 x Revision 106

AFFECTED PAGE LIST - TECHNICAL REQUIREMENTS MANUAL Appendix V 1 of 7 ......................................Revision 56 2 of 7 ......................................Revision 56 3 of 7 ......................................Revision 56 4 of 7 ......................................Revision 56 5 of 7 ......................................Revision 56 6 of 7 ......................................Revision 56 7 of 7 ......................................Revision 56 Appendix W 1 of 4 ......................................Revision 74 2 of 4 ......................................Revision 74 3 of 4 ......................................Revision 74 4 of 4 ......................................Revision 74 BRAIDWOOD UNITS 1 & 2 xi Revision 106

TABLE OF CONTENTS - TECHNICAL REQUIREMENTS MANUAL 1.0 USE AND APPLICATION........................................ 1.0-1 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 1.5 TLCO and TSR Implementation............................ 1.5-1 1.6 TRM Revisions.......................................... 1.6-1 2.0.a RTS Instrumentation Trip Setpoints................... 2.0.a-1 2.0.b ESFAS Instrumentation Trip Setpoints................. 2.0.b-1 2.1.a Miscellaneous Test Requirements...................... 2.1.a-1 3.0 TLCO Applicability......................................... 3.0-1 3.0 TSR Applicability.......................................... 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS........................... 3.1.a-1 3.1.a Boration Flow Path - Shutdown ................... 3.1.a-1 3.1.b Boration Flow Paths - Operating ................. 3.1.b-1 3.1.c Charging Pump - Shutdown ........................ 3.1.c-1 3.1.d Charging Pumps - Operating ...................... 3.1.d-1 3.1.e Borated Water Source - Shutdown ................. 3.1.e-1 3.1.f Borated Water Sources - Operating ............... 3.1.f-1 3.1.g Position Indication System - Shutdown ........... 3.1.g-1 3.1.h SDM - MODE 1 and MODE 2 with keff ! 1.0 ........... 3.1.h-1 3.1.i SDM - MODE 5 .................................... 3.1.i-1 3.1.j Shutdown and Control Rods ....................... 3.1.j-1 3.1.k Position Indication System - Shutdown (Special Test Exception).............................. 3.1.k-1 3.2 Not Used BRAIDWOOD UNITS 1 & 2 i Revision 1 Technical Requirements Manual

TABLE OF CONTENTS - TECHNICAL REQUIREMENTS MANUAL 3.3 INSTRUMENTATION......................................3.3.a-1 3.3.a Movable Incore Detectors ........................3.3.a-1 3.3.b Seismic Monitoring Instrumentation ..............3.3.b-1 3.3.c Meteorological Monitoring Instrumentation .......3.3.c-1 3.3.d Loose-Part Detection System .....................3.3.d-1 3.3.e Explosive Gas Monitoring Instrumentation ........3.3.e-1 3.3.f High Energy Line Break Isolation Sensors ........3.3.f-1 3.3.g Turbine Overspeed Protection ....................3.3.g-1 3.3.h PDMS Instrumentation ............................3.3.h-1 3.3.i PAM Instrumentation .............................3.3.i-1 3.3.j Hydrogen Monitors ...............................3.3.j-1 3.3.k Feedwater Flow ..................................3.3.k-1 3.3.l Not Used 3.3.m Not Used 3.3.n Not Used 3.3.o FHB Ventilation System Actuation Instrumentation..............................3.3.o-1 3.3.p Radiation Monitoring Instrumentation ............3.3.p-1 3.3.q Not Used 3.3.r Not Used 3.3.s Not Used 3.3.t Not Used 3.3.u Not Used 3.3.v Not Used 3.3.w Not Used 3.3.x Not Used 3.3.y Engineereed Safety Feature Actuation System (ESFAS)

Instrumentation..............................3.3.y-1 3.4 REACTOR COOLANT SYSTEM (RCS).........................3.4.b-1 3.4.a Not Used 3.4.b RCS Chemistry ...................................3.4.b-1 3.4.c Pressurizer Temperature Limits ..................3.4.c-1 3.4.d Not Used 3.4.e Reactor Vessel Head Vents .......................3.4.e-1 3.4.f Structural Integrity ............................3.4.f-1 BRAIDWOOD UNITS 1 & 2 ii Revision 101 Technical Requirements Manual

TABLE OF CONTENTS - TECHNICAL REQUIREMENTS MANUAL 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)................3.5.a-1 3.5.a ECCS Subsystems - Tavg 200#F and Pressurizer Level 5%...................................3.5.a-1 3.6 Not Used 3.7 PLANT SYSTEMS........................................3.7.a-1 3.7.a Steam Generator Pressure/Temperature Limitations..................................3.7.a-1 3.7.b Snubbers ........................................3.7.b-1 3.7.c Sealed Source Contamination .....................3.7.c-1 3.7.d Area Temperature Monitoring .....................3.7.d-1 3.7.e Not Used 3.7.f Not Used 3.7.g Auxiliary Feedwater (AF) Flow Control Valves ....3.7.g-1 3.7.h Not Used 3.7.i FHB Ventilation Systems .........................3.7.i-1 3.7.j Spent Fuel Pool Water Level .....................3.7.j-1 3.7.k Spent Fuel Pool Boron Concentration .............3.7.k-1 3.8 ELECTRICAL POWER SYSTEMS.............................3.8.a-1 3.8.a Containment Penetration Conductor Overcurrent Protective Devices...........................3.8.a-1 3.8.b Motor Operated Valves Thermal Overload Protection Devices......................................3.8.b-1 3.8.c Battery Monitoring and Maintenance ..............3.8.c-1 3.9 REFUELING OPERATIONS.................................3.9.a-1 3.9.a Decay Time ......................................3.9.a-1 3.9.b Communications ..................................3.9.b-1 3.9.c Refueling Machine/Auxiliary Hoist ...............3.9.c-1 3.9.d Crane Travel - Spent Fuel Pool ..................3.9.d-1 3.9.e Refueling Cavity Water Level ....................3.9.e-1 4.0 Not Used BRAIDWOOD UNITS 1 & 2 iii Revision 100 Technical Requirements Manual

TABLE OF CONTENTS - TECHNICAL REQUIREMENTS MANUAL 5.0 ADMINISTRATIVE CONTROLS.................................. 5.1-1 5.1 Safety Limit Violation............................... 5.1-1 5.2 Procedures and Programs.............................. 5.2-1 5.2.a Process Control Program ......................... 5.2-1 5.2.b In-Plant Radiation Monitoring ................... 5.2-2 5.2.c Radiological Environmental Monitoring Program ... 5.2-2 5.2.d Radiation Protection Program .................... 5.2-3 5.2.e Offsite Dose Calculation Manual ................. 5.2-3 5.3 Reporting Requirements............................... 5.3-1 5.3.a Startup Report .................................. 5.3-1 5.3.b Annual Specific Activity Report ................. 5.3-2 5.3.c Special Reports ................................. 5.3-2 BRAIDWOOD UNITS 1 & 2 iv Revision 1 Technical Requirements Manual

TABLE OF CONTENTS - TECHNICAL REQUIREMENTS MANUAL TABLES TABLE T1.1-1 MODES ...........................................1.1-7 TABLE T2.0.a-1 Reactor Trip System Instrumentation Trip Setpoints....................................2.0.a-1 TABLE T2.0.b-1 Engineered Safety Feature Actuation System Instrumentation Trip Setpoints...............2.0.b-1 TABLE T2.0.c-1 Boron Dilution Protection System Instrumentation Trip Setpoint................................2.0.c-1 TABLE T3.3.b-1 Seismic Monitoring Instrumentation ..............3.3.b-4 TABLE T3.3.c-1 Meteorological Monitoring Instrumentation .......3.3.c-3 TABLE T3.3.d-1 Loose-Part Detection Instrumentation ............3.3.d-3 TABLE T3.3.e-1 Explosive Gas Monitoring Instrumentation ........3.3.e-4 TABLE T3.3.f-1 High Energy Line Break Instrumentation ..........3.3.f-3 TABLE T3.3.g-1 Turbine Overspeed Protection ....................3.3.g-5 TABLE T3.3.g-2 Extraction Steam Non-Return Check Valves and the Associated MOV or Manual Isolation Valve........................................3.3.g-6 TABLE T3.3.i-1 Post Accident Monitoring Instrumentation ........3.3.i-4 TABLE T3.3.o-1 FHB Ventilation System Actuation Instrumentation..............................3.3.o-4 TABLE T3.3.p-1 Radiation Monitoring Instrumentation for Plant Operations.............................3.3.p-4 TABLE T3.3.y-1 Engineered Safety Feature Actuation System Instrumentation..............................3.3.y-3 TABLE T3.4.b-1 RCS Chemistry Limits ............................3.4.b-4 TABLE T3.7.b-1 Snubber Inservice Inspection Program Elements ...3.7.b-4 TABLE T3.7.d-1 Area Temperature Monitoring .....................3.7.d-3 TABLE T3.8.a-1 Containment Penetration Conductor Overcurrent Protective Devices (Unit 1)..................3.8.a-7 TABLE T3.8.a-2 Containment Penetration Conductor Overcurrent Protective Devices (Unit 2)..................3.8.a-14 TABLE T3.8.b-1 Motor-Operated Valves Thermal Overload Protective Devices (Unit 1).............................3.8.b-3 TABLE T3.8.b-2 Motor-Operated Valves Thermal Overload Protective Devices (Unit 2).............................3.8.b-6 BRAIDWOOD UNITS 1 & 2 v Revision 88 Technical Requirements Manual

TABLE OF CONTENTS - TECHNICAL REQUIREMENTS MANUAL FIGURES FIGURE 3.9.a-1 41 MBTU/hr SFP Heat Load Margin .................3.9.a-3 FIGURE 3.9.a-2 42 MBTU/hr SFP Heat Load Margin .................3.9.a-4 FIGURE 3.9.a-3 43 MBTU/hr SFP Heat Load Margin .................3.9.a-5 FIGURE 3.9.a-4 44 MBTU/hr SFP Heat Load Margin .................3.9.a-6 FIGURE 3.9.a-5 44 MBTU/hr SFP Heat Load Margin .................3.9.a-7 FIGURE 3.9.a-6 45 MBTU/hr SFP Heat Load Margin .................3.9.a-8 FIGURE 3.9.a-7 46 MBTU/hr SFP Heat Load Margin .................3.9.a-9 FIGURE 3.9.a-8 47 MBTU/hr SFP Heat Load Margin .................3.9.a-10 FIGURE 3.9.a-9 48 MBTU/hr SFP Heat Load Margin .................3.9.a-11 BRAIDWOOD UNITS 1 & 2 vi Revision 89 Technical Requirements Manual

TABLE OF CONTENTS - TECHNICAL REQUIREMENTS MANUAL APPENDICES Appendix A: ODCM AND RADIOLOGICAL CONTROLS REPORTS AND PROGRAM Appendix B: PRIMARY COOLANT SOURCES OUTSIDE CONTAINMENT Appendix C: Not Used Appendix D: RADIOACTIVE EFFLUENT CONTROLS PROGRAM Appendix E: TRANSIENT MONITORING PROGRAM Appendix F: PRE-STRESSED CONCRETE CONTAINMENT TENDON SURVEILLANCE PROGRAM Appendix G: REACTOR COOLANT PUMP FLYWHEEL INSPECTION PROGRAM Appendix H: Not used Appendix I: STEAM GENERATOR PROGRAM Appendix J: SECONDARY WATER CHEMISTRY PROGRAM Appendix K: VENTILATION FILTER TESTING PROGRAM Appendix L: EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM Appendix M: DIESEL FUEL OIL TESTING PROGRAM Appendix N: ITS BASES CONTROL PROGRAM Appendix O: SAFETY FUNCTION DETERMINATION PROGRAM Appendix P: CONTAINMENT LEAKAGE RATE TESTING PROGRAM Appendix Q: Not used Appendix R: Not used Appendix S: TECHNICAL REQUIREMENTS MANUAL CONTROL PROGRAM Appendix T: CONFIGURATION RISK MANAGEMENT PROGRAM Appendix U: BATTERY MONITORING AND MAINTENANCE PROGRAM Appendix V: CONTROL ROOM ENVELOPE HABITABILITY PROGRAM Appendix W: SURVEILLANCE FREQUENCY CONTROL PROGRAM BRAIDWOOD UNITS 1 & 2 vii Revision 96 Technical Requirements Manual

TRM Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions

NOTE-------------------------------------

The defined terms of this section appear in capitalized type and are applicable throughout this Technical Requirements Manual.

Term Definition ACTIONS ACTIONS shall be that part of a Requirement that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel so that it responds within the required range and accuracy to known inputs. The CHANNEL CALIBRATION shall encompass the entire channel, including the required sensor, alarm, interlock, display, and trip functions.

Calibration of instrument channels with Resistance Temperature Detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping calibrations or total channel steps so that the entire channel is calibrated.

CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

BRAIDWOOD UNITS 1 & 2 1.1 1 Revision 1 Technical Requirements Manual

TRM Definitions 1.1 1.1 Definitions CHANNEL OPERATIONAL A COT shall be the injection of a simulated or TEST (COT) actual signal into the channel as close to the sensor as practicable to verify the OPERABILITY of required alarm, interlock, display, and trip functions. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints so that the setpoints are within the required range and accuracy.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS The COLR is the unit specific document that REPORT (COLR) provides cycle specific parameter limits for the current reload cycle. These cycle specific parameter limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Unit operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT I-131 DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcurie per gram) that alone would produce the same dose when inhaled as the combined activities of iodine isotopes I-131, I-132, I-133, I-134, and I-135 actually present. The determination of DOSE EQUIVALENT I-131 shall be performed using the Committed Effective Dose Equivalent (CEDE) dose conversion factors from Table 2.1 of EPA Federal Guidance Report No. 11, 1988, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion."

BRAIDWOOD UNITS 1 & 2 1.1 2 Revision 69 Technical Requirements Manual

TRM Definitions 1.1 1.1 Definitions INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f).

MEMBER(S) OF THE PUBLIC MEMBER(S) OF THE PUBLIC shall include all persons who are not occupationally associated with the plant. This category does not include employees of the licensee, its contractors or vendors and persons who enter the site to service equipment or to make deliveries. This category does include persons who use portions of the site for recreational, occupational, or other purposes not associated with the plant.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table T1.1-1 with fuel in the reactor vessel.

OFFSITE DOSE CALCULATION The ODCM shall contain the methodology and MANUAL (ODCM) parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring Alarm/Trip Setpoints, and in the conduct of the Environmental Radiological Monitoring Program. The ODCM shall also contain (1) the Radioactive Effluent Controls and Radiological Environmental Monitoring Programs and (2) descriptions of the information that should be included in the Annual Radiological Environmental Operating and Radioactive Effluent Release Reports.

OPERABLE - OPERABILITY A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

BRAIDWOOD UNITS 1 & 2 1.1 3 Revision 100 Technical Requirements Manual

TRM Definitions 1.1 1.1 Definitions PROCESS CONTROL PROGRAM The PCP shall contain the current formulas, (PCP) sampling, analyses, tests, and determinations to be made to ensure that processing and packaging of solid radioactive wastes based on demonstrated processing of actual or simulated wet solid wastes will be accomplished in such a way as to assure compliance with 10 CFR Parts 20, 61, and 71, State regulations, burial ground requirements, and other requirements governing the disposal of solid radioactive waste.

PURGE - PURGING PURGE or PURGING shall be any controlled process of discharging air or gas from a confinement to maintain temperature, pressure, humidity, concentration or other operating condition, in such a manner that replacement air or gas is required to purify the confinement.

QUADRANT POWER TILT QPTR shall be the ratio of the maximum upper RATIO (QPTR) excore detector calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.

RATED THERMAL POWER (RTP) RTP shall be a total reactor core heat transfer rate to the reactor coolant of 3645 MWt.

SHUTDOWN MARGIN (SDM) SDM shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:

a. All Rod Cluster Control Assemblies (RCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SDM; and

b. In MODES 1 and 2, the fuel and moderator temperatures are changed to the hot zero power temperature.

BRAIDWOOD UNITS 1 & 2 1.1 4 Revision 84 Technical Requirements Manual

TRM Definitions 1.1 1.1 Definitions SINGLE-FAILURE PROOF Cranes meeting requirements of ASME NOG-1-2004, LOAD HANDLING SYSTEM NUREG-0554 and NUREG-0612, as applicable.

Special Lifting Devices meeting requirements of NUREG-0612, Section 5.1.6(1)(a).

Lifting devices that are not specially designed that meet the requirements of NUREG-0612, Section 5.1.6(1)(b).

Interfacing lift points such as lifting lugs or cask trunions meeting requirements of NUREG-0612, Section 5.1.6(3).

SITE BOUNDARY The SITE BOUNDARY shall be that line beyond which the land is neither owned, nor leased, nor otherwise controlled by the licensee.

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

TRIP ACTUATING DEVICE A TADOT shall consist of operating the trip OPERATIONAL TEST actuating device and verifying the OPERABILITY (TADOT) of required alarm, interlock, display, and trip functions. The TADOT shall include adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy.

UNRESTRICTED AREA An UNRESTRICTED AREA shall be any area at or beyond the SITE BOUNDARY access to which is not controlled by the licensee for purposes of protection of individuals from exposure to radiation and radioactive materials, or any area within the SITE BOUNDARY used for residential quarters or for industrial, commercial, institutional, and/or recreational purposes.

BRAIDWOOD UNITS 1 & 2 1.1 5 Revision 75 Technical Requirements Manual

TRM Definitions 1.1 1.1 Definitions VENTILATION EXHAUST A VENTILATION EXHAUST TREATMENT SYSTEM shall TREATMENT SYSTEM be any system designed and installed to reduce gaseous radioiodine or radioactive material in particulate form in effluents by passing ventilation or vent exhaust gases through charcoal adsorbers and/or HEPA filters for the purpose of removing iodines or particulates from the gaseous exhaust stream prior to the release to the environment. Such a system is not considered to have any effect on noble gas effluents.

Engineered Safety Features Atmospheric Cleanup Systems are not considered to be VENTILATION EXHAUST TREATMENT SYSTEM components.

WASTE GAS HOLDUP A WASTE GAS HOLDUP SYSTEM shall be any system SYSTEM designed and installed to reduce radioactive gaseous effluents by collecting Reactor Coolant System off-gases from the Reactor Coolant System and providing for delay or holdup for the purpose of reducing the total radioactivity prior to release to the environment.

BRAIDWOOD UNITS 1 & 2 1.1 6 Revision 75 Technical Requirements Manual

TRM Definitions 1.1 Table T1.1-1 (page 1 of 1)

MODES

% RATED AVERAGE REACTIVITY THERMAL REACTOR COOLANT MODE TITLE CONDITION POWER(a) TEMPERATURE (keff) (!F) 1 Power Operation 0.99 >5 NA 2 Startup 0.99 # 5 NA 3 Hot Standby < 0.99 NA 350 4 Hot Shutdown(b) < 0.99 NA 350 > Tavg > 200 5 Cold Shutdown(b) < 0.99 NA # 200 6 Refueling(c) NA NA NA (a) Excluding decay heat.

(b) All required reactor vessel head closure bolts fully tensioned.

(c) One or more required reactor vessel head closure bolts less than fully tensioned.

BRAIDWOOD UNITS 1 & 2 1.1 7 Revision 93 Technical Requirements Manual

TRM Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

Logical connectors are used in the Technical Requirements Manual (TRM) to discriminate between, and yet connect, discrete Conditions, Required Actions, Completion Times, Surveillances, and Frequencies. The only logical connectors that appear in the TRM are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (i.e., left justified with the number of the Required Action). The successive levels of logic are identified by additional digits of the Required Action number and by successive indentations of the logical connectors.

When logical connectors are used to state a Condition, Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical connectors.

BRAIDWOOD UNITS 1 & 2 1.2 1 Revision 1 Technical Requirements Manual

TRM Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued)

EXAMPLE 1.2-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. TLCO not A.1 Verify . . .

met.

AND A.2 Restore . . .

In this example the logical connector AND is used to indicate that when in Condition A, both Required Actions A.1 and A.2 must be completed.

BRAIDWOOD UNITS 1 & 2 1.2 2 Revision 1 Technical Requirements Manual

TRM Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued)

EXAMPLE 1.2-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. TLCO not A.1 Trip . . .

met.

OR A.2.1 Verify . . .

AND A.2.2.1 Reduce . . .

OR A.2.2.2 Perform . . .

OR A.3 Align . . .

This example represents a more complicated use of logical connectors. Required Actions A.1, A.2, and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement.

Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND. Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

BRAIDWOOD UNITS 1 & 2 1.2 3 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Technical Requirements Manual Limiting Conditions for Operation (TLCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with a TLCO state Conditions that typically describe the ways in which the requirements of the TLCO can fail to be met.

Specified with each stated Condition are Required Action(s) and Completion Time(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the TLCO. Unless otherwise specified, the Completion Time begins when a senior licensed operator on the operating shift crew with responsibility for plant operations makes the determination that an LCO is not met and an ACTIONS Condition is entered. The "otherwise specified" exceptions are varied, such as a Required Action Note or Surveillance Requirement Note that provides an alternative time to perform specific tasks, such as testing, without starting the Completion Time. While utilizing the Note, should a Condition be applicable for any reason not addressed by the Note, the Completion Time begins. Should the time allowance in the Note be exceeded, the Completion Time begins at that point. The exceptions may also be incorporated into the Completion Time. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the TLCO Applicability.

If situations are discovered that require entry into more than one Condition at a time within a single TLCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition, unless otherwise specified.

BRAIDWOOD UNITS 1 & 2 1.3 1 Revision 98 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued)

Once a Condition has been entered, subsequent trains, subsystems, components, or variables expressed in the Condition, discovered to be inoperable or not within limits, will not result in separate entry into the Condition, unless specifically stated. The Required Actions of the Condition continue to apply to each additional failure, with Completion Times based on initial entry into the Condition, unless otherwise specified.

However, when a subsequent train, subsystem, component, or variable expressed in the Condition is discovered to be inoperable or not within limits, the Completion Time(s) may be extended. To apply this Completion Time extension, two criteria must first be met. The subsequent inoperability:

a. Must exist concurrent with the first inoperability; and

b. Must remain inoperable or not within limits after the first inoperability is resolved.

The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:

a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; or

b. The stated Completion Time as measured from discovery of the subsequent inoperability.

The above Completion Time extension does not apply to those TLCOs that have exceptions that allow completely separate re-entry into the Condition (for each train, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual TLCOs.

BRAIDWOOD UNITS 1 & 2 1.3 2 Revision 98 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued)

The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e., "once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery . . ." Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended.

EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.

BRAIDWOOD UNITS 1 & 2 1.3 3 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

The Required Actions of Condition B are to be in MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND in MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months ) is allowed for reaching MODE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months , the time allowed for reaching MODE 5 is the next 33 hours3.819444e-4 days 0.00917 hours 5.456349e-5 weeks 1.25565e-5 months because the total time allowed for reaching MODE 5 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

If Condition B is entered while in MODE 3, the time allowed for reaching MODE 5 is the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

BRAIDWOOD UNITS 1 & 2 1.3 4 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump to 7 days inoperable. OPERABLE status.

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

When a pump is declared inoperable, Condition A is entered.

If the pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition B is entered, Condition A and B are exited, and therefore, the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump. TLCO 3.0.c is entered, since the ACTIONS do not include a Condition for more than one inoperable pump. The Completion Time clock for Condition A does not stop after TLCO 3.0.c is entered, but continues to be tracked from the time Condition A was initially entered.

While in TLCO 3.0.c, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, TLCO 3.0.c may be exited and operation continued in accordance with Condition A.

BRAIDWOOD UNITS 1 & 2 1.3 5 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

While in TLCO 3.0.c, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired, TLCO 3.0.c may be exited and operation continued in accordance with Condition B. The Completion Time for Condition B is tracked from the time the Condition A Completion Time expired.

On restoring one of the pumps to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for

> 7 days.

BRAIDWOOD UNITS 1 & 2 1.3 6 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore 7 days Function X Function X train train to OPERABLE AND inoperable. status.

10 days from discovery of failure to meet the TLCO B. One B.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y Function Y train train to OPERABLE AND inoperable. status.

10 days from discovery of failure to meet the TLCO C. One C.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function X Function X train train to OPERABLE inoperable. status.

AND OR One C.2 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y Function Y train train to OPERABLE inoperable. status.

BRAIDWOOD UNITS 1 & 2 1.3 7 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

When one Function X train and one Function Y train are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each train starting from the time each train was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second train was declared inoperable (i.e., the time the situation described in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time, Conditions B and C are exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected train was declared inoperable (i.e.,

initial entry into Condition A).

The Completion Times of Conditions A and B are modified by a logical connector with a separate 10 day Completion Time measured from the time it was discovered the TLCO was not met. In this example, without the separate Completion Time, it would be possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the TLCO. The separate Completion Time modified by the phrase "from discovery of failure to meet the TLCO" is designed to prevent indefinite continued operation while not meeting the TLCO. This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock". In this instance, the Completion Time "time zero" is specified as commencing at the time the TLCO was initially not met, instead of at the time the associated Condition was entered.

BRAIDWOOD UNITS 1 & 2 1.3 8 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve(s) 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves to OPERABLE inoperable. status.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months met.

A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis.

Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.

Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months provided this does not result in any subsequent valve being inoperable for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

If the Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (plus the extension) expires while one or more valves are still inoperable, Condition B is entered.

BRAIDWOOD UNITS 1 & 2 1.3 9 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-5 ACTIONS

NOTE----------------------------

Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months met.

The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table.

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve.

BRAIDWOOD UNITS 1 & 2 1.3 10 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve.

If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve.

Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply.

EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform Once per inoperable. TSR 3.x.x.x. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months OR A.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to

! 50% RTP.

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

BRAIDWOOD UNITS 1 & 2 1.3 11 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

Entry into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 has a "once per" Completion Time, which qualifies for the 25% extension, per TSR 3.0.b, to each performance after the initial performance. The initial 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval. If Required Action A.1 is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by TSR 3.0.b),

Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is not met, Condition B is entered.

If after entry into Condition B, Required Action A.1 or A.2 is met, Condition B is exited and operation may then continue in Condition A.

BRAIDWOOD UNITS 1 & 2 1.3 12 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Verify affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months subsystem subsystem inoperable. isolated. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Restore subsystem 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE status.

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

Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered and each "Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter" interval begins upon performance of Required Action A.1.

BRAIDWOOD UNITS 1 & 2 1.3 13 Revision 1 Technical Requirements Manual

TRM Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or any subsequent 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval from the previous performance (plus the extension allowed by TSR 3.0.b), Condition B is entered.

The Completion Time clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition B is entered, Condition B is exited and operation may continue in accordance with Condition A, provided the Completion Time for Required Action A.2 has not expired.

IMMEDIATE When "Immediately" is used as a Completion Time, the COMPLETION TIME Required Action should be pursued without delay and in a controlled manner.

BRAIDWOOD UNITS 1 & 2 1.3 14 Revision 1 Technical Requirements Manual

TRM Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Technical Requirements Manual Surveillance Requirement (TSR) has a specified Frequency in which the Surveillance must be met in order to meet the associated Limiting Condition for Operation (TLCO). An understanding of the correct application of the specified Frequency is necessary for compliance with the TSR.

The "specified Frequency" is referred to throughout this section and Section 3.0, Surveillance Requirement (TSR)

Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each TSR as well as certain Notes in the Surveillance column that modify performance requirements.

Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated TLCO is within its Applicability, represent potential TSR 3.0.d conflicts. To avoid these conflicts, the TSR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With a TSR satisfied, TSR 3.0.d imposes no restriction.

Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are "otherwise stated" conditions allowed by TSR 3.0.a. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both. Example 1.4-5 discusses these special situations.

BRAIDWOOD UNITS 1 & 2 1.4 1 Revision 1 Technical Requirements Manual

TRM Frequency 1.4 1.4 Frequency DESCRIPTION (continued)

The use of "met" or "performed" in these instances conveys specific meaning. A surveillance is "met" only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed," constitutes a Surveillance not "met." "Performance" refers only to the requirement to specifically determine the ability to meet the acceptance criteria. TSR 3.0.d restrictions would not apply if both the following conditions are satisfied:

a. The Surveillance is not required to be performed; and

b. The Surveillance is not required to be met or, even if required to be met, is not known to be failed.

EXAMPLES The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the TLCO (TLCO not shown) is MODES 1, 2, and 3. The examples do not reflect the potential application of TLCO 3.0.d.2.

BRAIDWOOD UNITS 1 & 2 1.4 2 Revision 38 Technical Requirements Manual

TRM Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of TSR most often encountered in the Technical Requirements Manual (TRM). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time.

Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the stated Frequency is allowed by TSR 3.0.b for operational flexibility. The measurement of this interval continues at all times, even when the TSR is not required to be met per TSR 3.0.a (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the TLCO). If the interval specified by TSR 3.0.b is exceeded while the unit is in a MODE or other specified condition in the Applicability of the TLCO, and the performance of the Surveillance is not otherwise modified (refer to Example 1.4-3), then TSR 3.0.c becomes applicable.

If the interval as specified by TSR 3.0.b is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the TLCO for which performance of the TSR is required, the Surveillance must be performed within the Frequency requirements of TSR 3.0.b prior to entry into the MODE or other specified condition. Failure to do so would result in a violation of TSR 3.0.d.

BRAIDWOOD UNITS 1 & 2 1.4 3 Revision 1 Technical Requirements Manual

TRM Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level < 25% RTP to 25% RTP, the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND"). This type of Frequency does not qualify for the extension allowed by TSR 3.0.b.

"Thereafter" indicates future performances must be established per TSR 3.0.b, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to < 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP.

BRAIDWOOD UNITS 1 & 2 1.4 4 Revision 1 Technical Requirements Manual

TRM Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE-----------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 25% RTP.

Perform channel adjustment. 7 days The interval continues, whether or not the unit operation is

< 25% RTP between performances.

As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is < 25% RTP, this Note allows 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after power reaches 25% RTP to perform the Surveillance. The Surveillance is still considered to be performed within the "specified Frequency." Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by TSR 3.0.b) interval, but operation was < 25% RTP, it would not constitute a failure of the TSR or failure to meet the TLCO. Also, no violation of TSR 3.0.d occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power 25% RTP.

Once the unit reaches 25% RTP, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of TSR 3.0.c would apply.

BRAIDWOOD UNITS 1 & 2 1.4 5 Revision 1 Technical Requirements Manual

TRM Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE-----------------

Only required to be performed in MODE 1.

Perform complete cycle of the valve. 7 days The interval continues, whether or not the unit operation is in MODE 1, 2, or 3 (the assumed Applicability of the associated TLCO) between performances.

As the Note modifies the required performance of the Surveillance, the note is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is not in MODE 1, this Note allows entry into and operation in MODES 2 and 3 to perform the Surveillance. The Surveillance is still considered to be performed within the "specified Frequency" if completed prior to MODE 1. Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by TSR 3.0.b) interval, but operation was not in MODE 1, it would not constitute a failure of the TSR or failure to meet the TLCO. Also, no violation of TSR 3.0.d occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not result in entry into MODE 1.

Once the unit reaches MODE 1, the requirement for the Surveillance to be performed within its specified Frequency applies and would require that the Surveillance had been performed. If the Surveillance were not performed prior to MODE 1, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of TSR 3.0.c would apply.

BRAIDWOOD UNITS 1 & 2 1.4 6 Revision 1 Technical Requirements Manual

TRM Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE-----------------

Only required to be met in MODE 1.

Verify leakage rates are within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-5 specifies that the requirements of this Surveillance do not have to be met until the unit is in MODE 1. The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance.

Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by TSR 3.0.b),

but the unit was not in MODE 1, there would be no failure of the TSR nor failure to meet the TLCO. Therefore, no violation of TSR 3.0.d occurs when changing MODES, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change was not made into MODE 1. Prior to entering MODE 1 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), TSR 3.0.d would require satisfying the TSR.

BRAIDWOOD UNITS 1 & 2 1.4 7 Revision 1 Technical Requirements Manual

TRM TLCO and TSR Implementation 1.5 1.0 USE AND APPLICATION 1.5 TLCO and TSR Implementation The Technical Requirements Manual (TRM) provides those limitations upon plant operations which are part of the licensing basis for the station but do not meet the criteria for continued inclusion in the Technical Specifications.

It also provides information which supplements the Technical Specifications such as specific plant setpoints for Technical Specification equipment. Nothing in the TRM shall supersede any Technical Specification requirement.

TLCOs and TSRs are implemented the same as Technical Specifications (see TRM 3.0). However, TLCOs and TSRs are treated as plant procedures and are not part of the Technical Specifications. Therefore the following exceptions apply:

a. Violations of the Action or Surveillance requirements in a TLCO are not reportable as conditions prohibited by, or deviations from, the Technical Specifications per 10 CFR 50.72 or 10 CFR 50.73, unless specifically required by the TRM.

b. Power reduction or plant shutdowns required to comply with the Actions of a TLCO or as a result of the application of TLCO 3.0.c are not reportable per 10 CFR 50.72 or 10 CFR 50.73.

c. Violations of TLCO or TSR requirements, except as provided for in TLCO 3.0 of this manual, shall be treated the same as plant procedure violations.

BRAIDWOOD UNITS 1 & 2 1.5 1 Revision 1 Technical Requirements Manual

TRM Technical Requirements Manual Revisions 1.6 1.0 USE AND APPLICATION 1.6 Technical Requirements Manual Revisions Changes to this manual shall be made under the following provisions:

a. Changes to the TRM shall be made under appropriate administrative controls and reviews.

b. Licensees may make changes to TRM without prior NRC approval provided the change does not require prior NRC approval pursuant to 10 CFR 50.59.

c. The TRM revision process shall contain provisions to ensure that the TRM is maintained consistent with the UFSAR.

d. Proposed changes that require NRC approval pursuant to 10 CFR 50.59 shall be reviewed and approved by the NRC prior to implementation. Changes to the TRM implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e) as modified by approved exemptions.

BRAIDWOOD UNITS 1 & 2 1.6 1 Revision 13 Technical Requirements Manual

TRM RTS Instrumentation Trip Setpoints 2.0.a Table T2.0.a-1 (page 1 of 3)

Reactor Trip System Instrumentation Trip Setpoints APPLICABLE MODES OR OTHER SPECIFIED NOMINAL TRIP FUNCTION CONDITIONS SETPOINT

1. Manual Reactor Trip 1,2, NA 3(a), 4(a), 5(a)

2. Power Range Neutron Flux

a. High 1,2 109% RTP(h)

b. Low 1(b),2 25% RTP

3. Power Range Neutron Flux Rate - High 1,2 5% RTP with time Positive Rate constant 2 sec

4. Intermediate Range Neutron Flux 1(b), 2(c) 25% RTP

5. Source Range Neutron Flux 2(d) 1.0 E5 cps 3 , 4 , 5 (a) (a) (a) 1.0 E5 cps

6. Overtemperature T 1,2 See LCO 3.3.1

7. Overpower T 1,2 See LCO 3.3.1 (continued)

(a) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(b) Below the P-10 (Power Range Neutron Flux) interlock.

(c) Above the P-6 (Source Range Block Permissive) interlock.

(d) Below the P-6 (Source Range Block Permissive) interlock.

(h) Trip setpoint may be set more conservative than Nominal Trip Setpoint as necessary in response to plant conditions.

BRAIDWOOD UNITS 1 & 2 2.0.a 1 Revision 52 Technical Requirements Manual

TRM RTS Instrumentation Trip Setpoints 2.0.a Table T2.0.a-1 (page 2 of 3)

Reactor Trip System Instrumentation Trip Setpoints APPLICABLE MODES OR OTHER SPECIFIED NOMINAL TRIP FUNCTION CONDITIONS SETPOINT

8. Pressurizer Pressure

a. Low 1(e) 1885 psig

b. High 1,2 2385 psig

9. Pressurizer Water Level - High 1(e) 92% of instrument span

10. Reactor Coolant Flow - Low (per loop) 1(e) 90% of loop minimum measured flow

11. Reactor Coolant Pump (RCP) Breaker 1(e) NA Position (per train)

12. Undervoltage RCPs (per train) 1(e) 5268 V

13. Underfrequency RCPs (per train) 1(e) 57.0 Hz

14. Steam Generator (SG) Water Level-Low Low (per SG)

a. Unit 1 1,2 18.0% of narrow range instrument span

b. Unit 2 1,2 36.3% of narrow range instrument span

15. Turbine Trip

a. Emergency Trip Header Pressure 1(f) 1000 psig (per train)

b. Turbine Throttle Valve Closure 1(f) 1% open (per train)

(continued)

(e) Above the P-7 (Low Power Reactor Trips Block) interlock.

(f) Above the P-8 (Power Range Neutron Flux) interlock.

BRAIDWOOD UNITS 1 & 2 2.0.a 2 Revision 52 Technical Requirements Manual

TRM RTS Instrumentation Trip Setpoints 2.0.a Table T2.0.a-1 (page 3 of 3)

Reactor Trip System Instrumentation Trip Setpoints APPLICABLE MODES OR OTHER SPECIFIED NOMINAL TRIP FUNCTION CONDITIONS SETPOINT

16. Safety Injection (SI) Input from 1,2 NA Engineered Safety Feature Actuation System (ESFAS)

17. Reactor Trip System Interlocks

a. Source Range Block Permissive, 2(d) 1E-10 amp P-6

b. Low Power Reactor Trips Block, P-7 (1) P-10 Input 1 NA (2) P-13 Input 1 NA

c. Power Range Neutron Flux, P-8 1 30% RTP

d. Power Range Neutron Flux, P-10 1,2 10% RTP

e. Turbine Impulse Pressure, P-13 1 10% turbine power

18. Reactor Trip Breakers (RTBs)(g) 1,2 NA 3 , 4 , 5 (a) (a) (a) NA

19. Reactor Trip Breaker Undervoltage 1,2 NA and Shunt Trip Mechanisms 3(a), 4(a), 5(a) NA

20. Automatic Trip Logic 1,2 NA 3(a), 4(a), 5(a) NA (a) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(d) Below the P-6 (Source Range Block Permissive) interlock.

(g) Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.

BRAIDWOOD UNITS 1 & 2 2.0.a 3 Revision 52 Technical Requirements Manual

TRM ESFAS Instrumentation Trip Setpoints 2.0.b Table T2.0.b-1 (page 1 of 4)

Engineered Safety Feature Actuation System Instrumentation Trip Setpoints APPLICABLE MODES OR OTHER SPECIFIED NOMINAL TRIP FUNCTION CONDITIONS SETPOINT

1. Safety Injection

a. Manual Initiation 1,2,3,4 NA

b. Automatic Actuation Logic and 1,2,3,4 NA Actuation Relays

c. Containment Pressure-High 1 1,2,3 3.4 psig

d. Pressurizer Pressure-Low 1,2,3(a) 1829 psig

e. Steam Line Pressure-Low 1,2,3(a) 640 psig(b)

2. Containment Spray

a. Manual Initiation 1,2,3,4 NA

b. Automatic Actuation Logic and 1,2,3,4 NA Actuation Relays

c. Containment Pressure High-3 1,2,3 20.0 psig (continued)

(a) Above the P-11 (Pressurizer Pressure) interlock.

(b) Time constants used in the lead/lag controller are t1 ! 50 seconds and t2 5 seconds.

BRAIDWOOD UNITS 1 & 2 2.0.b 1 Revision 52 Technical Requirements Manual

TRM ESFAS Instrumentation Trip Setpoints 2.0.b Table T2.0.b-1 (page 2 of 4)

Engineered Safety Feature Actuation System Instrumentation Trip Setpoints APPLICABLE MODES OR OTHER SPECIFIED NOMINAL TRIP FUNCTION CONDITIONS SETPOINT

3. Containment Isolation

a. Phase A Isolation (1) Manual Initiation 1,2,3,4 NA (2) Automatic Actuation Logic 1,2,3,4 NA and Actuation Relays (3) Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

b. Phase B Isolation (1) Manual Initiation 1,2,3,4 NA (2) Automatic Actuation Logic 1,2,3,4 NA and Actuation Relays (3) Containment Pressure 1,2,3 20.0 psig High-3

4. Steam Line Isolation

a. Manual Initiation 1,2(c),3(c) NA

b. Automatic Actuation Logic and 1,2(g),3(g) NA Actuation Relays

c. Containment Pressure-High 2 1,2(g),3(g) 8.2 psig

d. Steam Line Pressure (1) Low 1,2(g),3(a)(f)(g) 640 psig(b)

(2) Negative Rate-High 3(d)(g) 100.0 psi(e)

(continued)

(a) Above the P-11 (Pressurizer Pressure) interlock.

(b) Time constants used in the lead/lag controller are t1 ! 50 seconds and t2 5 seconds.

(c) Except when all Main Steam Isolation Valves (MSIVs) are closed.

(d) Below the P-11 (Pressurizer Pressure) interlock with Function 4.d.1 blocked.

(e) Time constant utilized in the rate/lag controller is ! 50 seconds.

(f) Below the P-11 (Pressurizer Pressure) interlock with Function 4.d.2 not enabled.

(g) Except when all Main Steam Isolation Valves (MSIVs) and MSIV bypass valves are closed.

BRAIDWOOD UNITS 1 & 2 2.0.b 2 Revision 52 Technical Requirements Manual

TRM ESFAS Instrumentation Trip Setpoints 2.0.b Table T2.0.b-1 (page 3 of 4)

Engineered Safety Feature Actuation System Instrumentation Trip Setpoints APPLICABLE MODES OR OTHER SPECIFIED NOMINAL TRIP FUNCTION CONDITIONS SETPOINT

5. Turbine Trip and Feedwater Isolation

a. Automatic Actuation Logic and 1,2(h),3(h) NA Actuation Relays

b. Steam Generator (SG) Water Level-High High (P-14)

1) Unit 1 1,2(h),3(h) 88.0% of narrow range instrument span

2) Unit 2 1,2(h),3(h) 80.8% of narrow range instrument span

c. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

6. Auxiliary Feedwater

a. Automatic Actuation Logic and 1,2,3 NA Actuation Relays

b. SG Water Level-Low Low

1) Unit 1 1,2,3 18.0% of narrow range instrument span

2) Unit 2 1,2,3 36.3% of narrow range instrument span

c. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

d. Loss of Offsite Power 1,2,3 2870 V (Undervoltage on Bus 141(241))

e. Undervoltage Reactor Coolant 1,2 5268 V Pump (per train)

f. Auxiliary Feedwater Pump Suction Transfer on Suction Pressure-Low Pressure Transmitter 1,2,3 18.1 psia Pressure Switch 20.5 psia (continued)

(h) Except when all Feedwater Isolation Valves are closed or isolated by a closed manual valve.

BRAIDWOOD UNITS 1 & 2 2.0.b 3 Revision 92 Technical Requirements Manual

TRM ESFAS Instrumentation Trip Setpoints 2.0.b Table T2.0.b-1 (page 4 of 4)

Engineered Safety Feature Actuation System Instrumentation Trip Setpoints APPLICABLE MODES OR OTHER SPECIFIED NOMINAL TRIP FUNCTION CONDITIONS SETPOINT

7. Switchover to Containment Sump

a. Automatic Actuation Logic and 1,2,3,4 NA Actuation Relays

b. Refueling Water Storage Tank 1,2,3,4 46.7% of instrument (RWST) Level-Low Low span Coincident with Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

8. ESFAS Interlocks

a. Reactor Trip, P-4 1,2,3 NA

b. Pressurizer Pressure, P-11 1,2,3 1930 psig

c. Tavg - Low Low, P-12 1,2,3 550#F

9. Loss of Power

a. Loss of Voltage 1,2,3,4,5(i),6(i) 2870 V with time delay of 1.8 sec

b. Degraded Voltage 1,2,3,4,5(i),6(i) 3987 V with a time delay of 310 sec

c. Low Degraded Voltage 1,2,3,4,5(i),6(i) 3244.15 V with a time delay of 3.0 sec (i) When associated DG is required to be OPERABLE by LCO 3.8.2, "AC Sources-Shutdown."

BRAIDWOOD UNITS 1 & 2 2.0.b 4 Revision 95 Technical Requirements Manual

TRM BDPS Instrumentation Trip Setpoint 2.0.c Table T2.0.c-1 (page 1 of 1)

Boron Dilution Protection System Instrumentation Trip Setpoint APPLICABLE MODES OR OTHER SPECIFIED NOMINAL TRIP FUNCTION CONDITIONS SETPOINT Boron Dilution Alert Channels Volume Control Tank Level High 3,4,5 70.0%

BRAIDWOOD UNIT 1 2.0.c 1 Revision 52 Technical Requirements Manual

TRM Miscellaneous Test Requirements 2 .1. a 2.1.a MISCELLANEOUS TEST REQUIREMENTS

NOTES- ----------------------------------

1. Each of the following Surveillances shall be completed within its specified frequency.

2. Failure to meet the surveillance requirement require immediate actions to determine OPERABILITY of the associated equipment. LCOs potentially impacted are identified in the TSR with().

APPLICABILITY: Defined in the TSR SURVEILLANCE REQUIREMENTS SU RV EI LLANCE FREQUENCY TSR 2.4.a.l -------------------NOTES-------------------

1. Only applicable in MODE 1.

2. TSR 3.0.d is not applicable.

Perform CHANNEL CALIBRATION on Reactor 18 months Coolant System total flow rate indicators.

(LCD 3.4.1)

TSR 2.4.b.l -------------------NOTE--------------------

Required to be met in MODES 1, 2, and 3.

Perform CHANNEL CALIBRATION on pressurizer 18 months PORV actuation instrumentation.

C LCD 3. 4. 11 )

(continued)

BRAIDWOOD - UNITS 1 &2 2.1.a - 1 Revision 101 Technical Requirements Manual

TRM Miscellaneous Test Requirements

2. l.a SURVEILLANCE REQUIREMENTS (continued)

SU RV EI LLANCE FREQUENCY TSR 2.5.a.l -------- - ----------NOTE--------------------

Required to be met in MODES 1, 2; and MODE 3 with the RCS pressure > 1000 psig.

Perform CHANNEL CALIBRATION on accumulator 18 months water level channels.

CLCO 3. 5 .1)

TSR 2.5.a.2 -------------------NOTE--------------------

Required to be met in MODES 1, 2; and MODE 3 with the RCS pressure > 1000 psig.

Perform CHANNEL CALIBRATION on accumulator 18 months pressure channels.

CLCO 3. 5 .1)

TSR 2.5.b.l -------------------NOTE--------------------

Required to be met in MODES 1, 2, 3, and 4.

Verify, through a visual inspection of all Prior to accessible areas of the containment, loose entering MODE 4 debris which could be transported to the containment sump during LOCA conditions has been removed.

CLCO 3.6.8)

(continued)

BRAIDWOOD - UNITS 1 &2 2.1.a - 2 Revision 106 Technical Requirements Manual

TRM Miscellaneous Test Requirements

2. l.a SURVEILLANCE REQUIREMENTS (continued)

SU RV EI LLANCE FREQUENCY TSR 2.5.b.2 -------------------NOTES-------------------

1. Required to be met in MODES 1, 2, 3, and 4.

2. Only required to be performed once TSR 2.5.b.l has been completed.

3. TSR 3.0.d is not applicable.

Verify, through a visual inspection of the Fo 11 owing each areas affected within containment, loose containment debris which could be transported to the entry containment sump during LOCA conditions has been removed.

(LCO 3.6.8)

(continued)

BRAIDWOOD - UNITS 1 &2 2.1.a - 3 Revision 106 Technical Requirements Manual

TRM Miscellaneous Test Requirements

2. l.a SURVEILLANCE REQUIREMENTS (continued)

SU RV EI LLANCE FREQUENCY TSR 2.5.c.l -------------------NOTES------------------ -

1. Only applicable to the following ECCS throttle valves:

a. High Head SI System -

SI8810A,B,C,D

b. SI System - SI8822A,B,C,D and SI8816A, B, C, D

2. Required to be met in MODES 1, 2, 3; and MODE 4 when the associated ECCS subsystems are required to be OPERABLE.

3. Only required to be performed for affected valves following valve stroking operation or maintenance on the valve.

Verify the correct position of each Once within position stop for the ECCS throttle valves. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (LCO 3.5.2)

(continued)

BRAIDWOOD - UNITS 1 &2 2.1.a-4 Revision 1 Technical Requirements Manual

TRM Miscellaneous Test Requirements

2. l.a SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 2.5.c.2 -------------------NOTES-------------------

1. A flow balance test that introduces flow to the loops shall not be performed in MODE 1, 2, 3, or 4.

2. Only required to be performed following alterations to the CV pump and/or piping system that alter the ECCS flow characteristics.

3. Required to be met in MODES 1, 2, 3; and MODE 4 when the associated ECCS subsystems are required to be OPERABLE.

Verify through analytical means or a flow Prior to balance test that the CV pump performance associated curve and/or the following CV ECCS cold leg subsystems being injection flow characteristics are met with declared a single pump running: OPERABLE

a. The sum of the injection line flow rates, excluding the highest flow rate, is~ 330 gpm; and

b. The total pump flow rate is ~ 550 gpm, including a simulated seal injection flow of~ 80 gpm.

(continued)

BRAIDWOOD - UNITS 1 &2 2.1.a - 5 Revision 28 Technical Requirements Manual

TRM Miscellaneous Test Requirements

2. l.a SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY (continued) -- --------- ----- ---NOTE -- --- --------- ----- -

Only applicable in MODES 1, 2, 3, 4, and 5.

Verify the CV pump performance curve and/or CV ECCS cold leg injection flow characteristics are acceptable by a technical evaluation that concludes the evaluation results are:

1. within the acceptance criteria of the accident analyses of record; and

2. acceptable for continued equipment operation.

Demonstrate by a flow balance test that the flow rates specified in a. and b. above are within limits prior to the associated subsystems being declared OPERABLE following the next refueling.

CLCO 3.5.2)

(continued) I BRAIDWOOD - UNITS 1 &2 2.1.a-6 Revision 28 Technical Requirements Manual

TRM Miscellaneous Test Requirements 2.1. a SURVEILLANCE REQUIREMENTS (continued)

SU RV EI LLANCE FREQUENCY TSR 2.5.c.3 -------------------NOTES-------------------

1. A flow balance test that introduces flow to the loops shall not be performed in MODE 1, 2, 3, or 4.

2. Only required to be performed following alterations to the SI pump and/or piping system that alter the ECCS flow characteristics.

3. Required to be met in MODES 1, 2, 3; and MODE 4 when the associated ECCS subsystems are required to be OPERABLE.

Verify through analytical means or a flow Prior to balance test that the SI pump performance associated curve and/or the following SI ECCS cold leg subsystems being injection flow characteristics are met with declared a single pump running: OPERABLE

a. The sum of the injection line flow rates, excluding the highest flow rate, is~ 439 gpm; and

b. The total pump flow rate is~ 655 gpm.

OR (continued) I BRAIDWOOD - UNITS 1 &2 2.1.a - 7 Revision 62 Technical Requirements Manual

T~

Miscellaneous Test Requirements 2.1.a SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY (continued)

Verify the SI pump performance curve and/or SI ECCS cold leg injection flow characteristics are acceptable by a technical evaluation that concludes the evaluation results are:

1. within the acceptance criteria of the accident analyses of record; and

2. acceptable for continued equipment operation (e.g., pump NPSH, pump runout, etc.).

Flow rates specified in a. and b. above shall be returned to within limits prior to the associated subsystems being declared OPERABLE if in a refueling outage or no later than the end of the next refueling if in MODES 1, 2, 3, 4, or 5.

(LCD 3.5.2)

(continued)

BRAIDWOOD - UNITS 1 &2 2.1.a - 8 Revision 62 Technical Requirements Manual

TRM Miscellaneous Test Requirements 2.1.a SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 2.5.c.4 -------------------NOTES-------------------

1. Only required to be performed following alterations to the RHR pump and/or piping system that alter the ECCS flow characteristics.

2. Required to be met in MODES 1, 2, 3; and MODE 4 when the associated ECCS subsystems are required to be OPERABLE.

Verify the RHR pump performance curve Prior to and/or RHR ECCS cold leg injection flow associated ECCS characteristics are consistent with the subsystems assumptions used in the safety analyses. required to be OPERABLE CLCO 3.5.2/LCO 3.5.3)

TSR 2.6.a.l Deleted.

(continued)

BRAIDWOOD - UNITS 1 &2 2.1.a - 9 Revision 62 Technical Requirements Manual

TRM Miscellaneous Test Requirements

2. l.a SURVEILLANCE REQUIREMENTS (continued)

SU RV EI LLANCE FREQUENCY TSR 2.7.a.l ------------ -------NOTES-------------------

1. This surveillance shall not be performed in MODE 1, 2, or 3.

2. Required to be met in MODES 1, 2, and 3.

Perform an inspection of the 18 months B Train Auxiliary Feedwater Pump diesel engine in accordance with manufacturer's recorrmendation for this class of service.

(LCO 3.7.5)

TSR 2.7.a.2 ---- ---- -----------NOTE------- -------------

Required to be met in MODES 1, 2, 3, and 4.

Perform a hydrographic survey to verify the 18 months Essential Service Cooling Pond CESCP) slopes exhibit no excess degradation.

(LCO 3.7.9)

BRAIDWOOD - UNITS 1 &2 2.l.a-10 Revision 62 Technical Requirements Manual

TRM TLCO Applicability 3.0 3.0 TECHNICAL REQUIREMENTS MANUAL (TRM) LIMITING CONDITION FOR OPERATION (TLCO) APPLICABILITY TLCO 3.0.a TLCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in TLCO 3.0.b and TLCO 3.0.f.

TLCO 3.0.b Upon discovery of a failure to meet a TLCO, the Required Actions of the associated Conditions shall be met, except as provided in TLCO 3.0.e.

If the TLCO 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.

TLCO 3.0.c When a TLCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to:

1. Implement appropriate compensatory actions as needed,

2. Verify that the plant is not in an unanalyzed condition or that a required safety function is not compromised by the inoperabilities, and

3. Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , obtain Station Duty Officer approval of the compensatory actions and plan for exiting TLCO 3.0.c.

Exceptions to this TLCO are stated in the individual TLCOs.

Where corrective measures are completed that permit operation in accordance with the TLCO or ACTIONS, completion of the actions required by TLCO 3.0.c is not required.

TLCO 3.0.c is only applicable in MODES 1, 2, 3, and 4.

BRAIDWOOD UNITS 1 & 2 3.0 1 Revision 1 Technical Requirements Manual

TRM TLCO Applicability 3.0 3.0 TECHNICAL REQUIREMENTS MANUAL (TRM) LIMITING CONDITION FOR OPERATION (TLCO) APPLICABILITY TLCO 3.0.d When a TLCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

1. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time;

2. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate (exceptions to this Specification are stated in the individual Specifications); or

3. When an allowance is stated in the individual value, parameter, or other TLCO This TLCO shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

TLCO 3.0.e Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to TLCO 3.0.b for the system returned to service under administrative control to perform the required testing to demonstrate OPERABILITY.

BRAIDWOOD UNITS 1 & 2 3.0 2 Revision 98 Technical Requirements Manual

TRM TLCO Applicability 3.0 3.0 TECHNICAL REQUIREMENTS MANUAL (TRM) LIMITING CONDITION FOR OPERATION (TLCO) APPLICABILITY TLCO 3.0.f Exception TLCOs allow specified TRM requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TRM requirements remain unchanged. Compliance with Exception TLCOs is optional. When an Exception TLCO is desired to be met but is not met, the ACTIONS of the Exception TLCO shall be met. When an Exception TLCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable TLCOs.

TLCO 3.0.g TLCOs, including associated ACTIONs, shall apply to each unit individually, unless otherwise indicated. Whenever the TLCO refers to a system or component that is shared by both units, the ACTIONs will apply to both units simultaneously.

BRAIDWOOD UNITS 1 & 2 3.0 3 Revision 1 Technical Requirements Manual

TRM TSR Applicability 3.0 3.0 TECHNICAL REQUIREMENTS MANUAL (TRM) SURVEILLANCE REQUIREMENT (TSR)

APPLICABILITY TSR 3.0.a TSRs shall be met during the MODES or other specified conditions in the Applicability for individual TLCOs, unless otherwise stated in the TSR. Failure to meet a TSR, whether such failure is experienced during the performance of the TSR or between performances of the TSR, shall be failure to meet the TLCO. Failure to perform a TSR within the specified Frequency shall be failure to meet the TLCO except as provided in TSR 3.0.c. TSRs do not have to be performed on inoperable equipment or variables outside specified limits.

TSR 3.0.b The specified Frequency for each TSR is met if the TSR 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 TSR are stated in the individual TSRs.

TSR 3.0.c If it is discovered that a TSR was not performed within its specified Frequency, then compliance with the requirement to declare the TLCO 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 Frequency, whichever is greater. This delay period is permitted to allow performance of the TSR. The delay period is only applicable when there is a reasonable expectation the surveillance will be met when performed. A risk evaluation shall be performed for any TSR 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 TSR is not performed within the delay period, the TLCO must immediately be declared not met, and the applicable Condition(s) must be entered.

When the TSR is performed within the delay period and the TSR is not met, the TLCO must immediately be declared not met, and the applicable Condition(s) must be entered.

BRAIDWOOD UNITS 1 & 2 3.0 4 Revision 98 Technical Requirements Manual

TRM TSR Applicability 3.0 3.0 TECHNICAL REQUIREMENTS MANUAL (TRM) SURVEILLANCE REQUIREMENT (TSR)

APPLICABILITY TSR 3.0.d Entry into a MODE or other specified condition in the Applicability of a TLCO shall only be made when the TLCO's TSRs have been met within their specified Frequency, except as provided by TSR 3.0.c. When a TLCO is not met due to TSRs not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with TLCO 3.0.d.

This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

TSR 3.0.e TSRs shall apply to each unit individually, unless otherwise indicated.

BRAIDWOOD UNITS 1 & 2 3.0 5 Revision 37 Technical Requirements Manual

TRM Boration Flow Path - Shutdown 3.1.a 3.1 REACTIVITY CONTROL SYSTEMS 3.1.a Boration Flow Path - Shutdown TLCO 3.1.a One of the following boron injection flow paths via the Chemical & Volume Control (CV) System shall be OPERABLE and capable of being powered from an OPERABLE emergency power source:

1. A flow path via a boric acid transfer pump from the Boric Acid Storage System, which is OPERABLE as specified in TLCO 3.1.e for MODE 5 or as specified in TLCO 3.1.f for MODE 4; or

2. A flow path from the Refueling Water Storage Tank (RWST) which is OPERABLE as specified in TLCO 3.1.e for MODE 5 or as specified in LCO 3.5.4 for MODE 4.

APPLICABILITY: MODES 4 and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required flow path A.1 ---------NOTE--------

inoperable. Not applicable if positive reactivity OR addition is the direct result of a Required flow path not RCS cooldown required capable of being by Technical powered from an Specifications.

OPERABLE emergency ---------------------

power source.

Suspend positive Immediately reactivity additions.

BRAIDWOOD UNITS 1 & 2 3.1.a 1 Revision 6 Technical Requirements Manual

TRM Boration Flow Path - Shutdown 3.1.a SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.a.1 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.1.a.1.

Verify Boric Acid Storage System solution 7 days temperature is 65°F.

TSR 3.1.a.2 Verify each manual, power operated, or 31 days automatic valve in the required flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.

BRAIDWOOD UNITS 1 & 2 3.1.a 2 Revision 1 Technical Requirements Manual

TRM Boration Flow Paths - Operating 3.1.b 3.1 REACTIVITY CONTROL SYSTEMS 3.1.b Boration Flow Paths - Operating TLCO 3.1.b One boron injection flow path via the Chemical & Volume (CV)

Control System from the Refueling Water Storage Tank (RWST) shall be OPERABLE, and either:

1. One additional OPERABLE flow path from the RWST, or

2. An OPERABLE flow path via a boric acid transfer pump from the Boric Acid Storage System.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required flow path A.1 Restore required flow 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. path to OPERABLE status.

(continued)

BRAIDWOOD UNITS 1 & 2 3.1.b 1 Revision 1 Technical Requirements Manual

TRM Boration Flow Paths - Operating 3.1.b ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A AND not met.

B.2 Borate to the 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SHUTDOWN MARGIN specified in the COLR at 200!F.

AND B.3.1 Restore required flow 174 hours0.00201 days 0.0483 hours 2.876984e-4 weeks 6.6207e-5 months path to OPERABLE status.

OR B.3.2 Be in MODE 4. 180 hours0.00208 days 0.05 hours 2.97619e-4 weeks 6.849e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.b.1 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.1.b.2.

Verify Boric Acid Storage System solution 7 days temperature is 65!F.

(continued)

BRAIDWOOD UNITS 1 & 2 3.1.b 2 Revision 1 Technical Requirements Manual

TRM Boration Flow Paths - Operating 3.1.b SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.1.b.2 Verify each manual, power operated, or 31 days automatic valve in the required flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.

TSR 3.1.b.3 -------------------NOTE--------------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

Verify each automatic valve in the required 36 months flow path actuates to its correct position on an actual or simulated safety injection actuation signal.

TSR 3.1.b.4 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.1.b.2.

Verify required flow path from the Boric 18 months Acid Storage System delivers 30 gpm to the RCS.

BRAIDWOOD UNITS 1 & 2 3.1.b 3 Revision 90 Technical Requirements Manual

TRM Charging Pump - Shutdown 3.1.c 3.1 REACTIVITY CONTROL SYSTEMS 3.1.c Charging Pump - Shutdown TLCO 3.1.c One centrifugal charging pump in the boron injection flow path required by TLCO 3.1.a shall be OPERABLE and capable of being powered from an OPERABLE emergency power source.

APPLICABILITY: MODES 4 and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required charging pump A.1 ---------NOTE--------

inoperable. Not applicable if positive reactivity OR addition is the direct result of a Required charging pump RCS cooldown required not capable of being by Technical powered from an Specifications.

OPERABLE emergency ---------------------

power source.

Suspend positive Immediately reactivity additions.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.c.1 Verify the required centrifugal charging In accordance pump's developed head at the test flow with the point is greater than or equal to the INSERVICE required developed head. TESTING PROGRAM BRAIDWOOD UNITS 1 & 2 3.1.c 1 Revision 100 Technical Requirements Manual

TRM Charging Pumps - Operating 3.1.d 3.1 REACTIVITY CONTROL SYSTEMS 3.1.d Charging Pumps - Operating TLCO 3.1.d Two centrifugal charging pumps shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One charging pump A.1 Restore charging pump 7 days inoperable. to OPERABLE status.

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

B.2 Borate to the 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SHUTDOWN MARGIN specified in the COLR at 200!F.

AND B.3 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.d.1 Verify each centrifugal charging pump's In accordance developed head at the test flow point is with the greater than or equal to the required INSERVICE developed head. TESTING PROGRAM BRAIDWOOD UNITS 1 & 2 3.1.d 1 Revision 100 Technical Requirements Manual

TRM Borated Water Source - Shutdown 3.1.e 3.1 REACTIVITY CONTROL SYSTEMS 3.1.e Borated Water Source - Shutdown TLCO 3.1.e One of the following borated water sources shall be OPERABLE:

1. A Boric Acid Storage System, or

2. The Refueling Water Storage Tank (RWST).

APPLICABILITY: MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required borated water A.1 Suspend positive Immediately source inoperable. reactivity additions.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.e.1 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.1.e.2 and the outside air temperature < 35!F.

Verify RWST solution temperature 35!F. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

BRAIDWOOD UNITS 1 & 2 3.1.e 1 Revision 6 Technical Requirements Manual

TRM Borated Water Source - Shutdown 3.1.e SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.1.e.2 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.1.e.2.

Verify RWST boron concentration 2300 ppm 7 days and # 2500 ppm.

TSR 3.1.e.3 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.1.e.2.

Verify RWST borated water level is 9.0%. 7 days TSR 3.1.e.4 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.1.e.1.

Verify Boric Acid Storage System solution 7 days temperature is 65!F.

TSR 3.1.e.5 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.1.e.1.

Verify Boric Acid Storage System boron 7 days concentration is 7000 ppm.

(continued)

BRAIDWOOD UNITS 1 & 2 3.1.e 2 Revision 1 Technical Requirements Manual

TRM Borated Water Source - Shutdown 3.1.e SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.1.e.6 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.1.e.1.

Verify Boric Acid Storage System borated 7 days water level is 12.0%.

BRAIDWOOD UNITS 1 & 2 3.1.e 3 Revision 88 Technical Requirements Manual

TRM Borated Water Sources - Operating 3.1.f 3.1 REACTIVITY CONTROL SYSTEMS 3.1.f Borated Water Sources - Operating TLCO 3.1.f The Boric Acid Storage System shall be OPERABLE when required as a borated water source by TLCO 3.1.b for MODES 1, 2, and 3 or TLCO 3.1.a for MODE 4.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required Boric Acid A.1 Restore the Boric 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Storage System Acid Storage System inoperable in MODE 1, to OPERABLE status.

2, or 3.

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

B.2 Borate to the 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SHUTDOWN MARGIN specified in the COLR at 200°F.

AND B.3.1 Restore the required 174 hours0.00201 days 0.0483 hours 2.876984e-4 weeks 6.6207e-5 months Boric Acid Storage System to OPERABLE status.

OR B.3.2 Be in MODE 4. 180 hours0.00208 days 0.05 hours 2.97619e-4 weeks 6.849e-5 months (continued)

BRAIDWOOD UNITS 1 & 2 3.1.f 1 Revision 1 Technical Requirements Manual

TRM Borated Water Sources - Operating 3.1.f ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Boric Acid C.1 Restore the required 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Storage System Boric Acid Storage inoperable in MODE 4. System to OPERABLE status.

OR C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.f.1 Verify Boric Acid Storage System solution 7 days temperature is 65°F.

TSR 3.1.f.2 Verify Boric Acid Storage System boron 7 days concentration is 7000 ppm.

TSR 3.1.f.3 Verify Boric Acid Storage System borated 7 days water level is 40%.

BRAIDWOOD UNITS 1 & 2 3.1.f 2 Revision 1 Technical Requirements Manual

TRM Position Indication System - Shutdown 3.1.g 3.1 REACTIVITY CONTROL SYSTEMS 3.1.g Position Indication System - Shutdown TLCO 3.1.g One Digital Rod Position Indication (DRPI), excluding bank demand position indication, shall be OPERABLE and capable of determining the control rod position within 12 steps for each shutdown or control rod not fully inserted.

APPLICABILITY: MODES 3, 4, and 5 with the Rod Control System capable of rod withdrawal.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more shutdown A.1 Restore required 15 minutes or control rods with OPERABLE DRPI.

required DRPI inoperable.

B. Required Action and B.1 Initiate action to Immediately associated Completion fully insert all Time of Condition A rods.

not met.

OR B.2 Initiate boration to Immediately restore RCS boron concentration to within the limits specified in the COLR.

OR B.3 Open Reactor Trip Immediately Breakers (RTBs) and Reactor Trip Bypass Breakers (RTBBs).

BRAIDWOOD UNITS 1 & 2 3.1.g 1 Revision 11 Technical Requirements Manual

TRM Position Indication System - Shutdown 3.1.g SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.g.1 Verify each DRPI agrees within 12 steps of 18 months the group demand position for the full indicated range of rod travel.

BRAIDWOOD UNITS 1 & 2 3.1.g 2 Revision 11 Technical Requirements Manual

TRM SDM - MODE 1 and MODE 2 with keff 1.0 3.1.h 3.1 REACTIVITY CONTROL SYSTEM 3.1.h Shutdown Margin (SDM) - MODE 1 and MODE 2 with keff 1.0 TLCO 3.1.h SDM shall be within the limits specified in the COLR.

APPLICABILITY: MODE 1, and MODE 2 with keff 1.0.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate and continue 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months boration.

AND A.2 Restore required SDM 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to within limits specified in the COLR.

BRAIDWOOD UNITS 1 & 2 3.1.h 1 Revision 1 Technical Requirements Manual

TRM SDM - MODE 1 and MODE 2 with keff 1.0 3.1.h SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.h.1 Verify SDM is within limit with control Prior to banks at the maximum insertion limit operation above specified in LCO 3.1.6 and considering the 5% RATED following factors: THERMAL POWER after each fuel

a. Reactor Coolant System boron loading concentration,

b. Control rod position,

c. Reactor Coolant System average temperature,

d. Fuel burnup based on gross thermal energy generation,

e. Xenon concentration, and

f. Samarium concentration.

BRAIDWOOD UNITS 1 & 2 3.1.h 2 Revision 1 Technical Requirements Manual

TRM SDM - MODE 5 3.1.i 3.1 REACTIVITY CONTROL SYSTEMS 3.1.i Shutdown Margin (SDM) - MODE 5 TLCO 3.1.i SDM shall be within the limits specified in the COLR.

APPLICABILITY: MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Declare both Boron Immediately Dilution Protection System subsystems inoperable and enter Condition C of LCO 3.3.9, "Boron Dilution Protection System (BDPS)," for "Two Boron Dilution Alert channels inoperable or no reactor coolant pump in operation or one or more RCS loop isolation valve(s) not open."

AND A.2 Enter Condition A of Immediately LCO 3.1.1, "Shutdown Margin (SDM)," for SDM not within limit.

BRAIDWOOD UNITS 1 & 2 3.1.i 1 Revision 18 Technical Requirements Manual

TRM SDM - MODE 5 3.1.i SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY NONE BRAIDWOOD UNITS 1 & 2 3.1.i 2 Revision 1 Technical Requirements Manual

TRM Shutdown and Control Rods 3.1.j 3.1 REACTIVITY CONTROL SYSTEM 3.1.j Shutdown and Control Rods TLCO 3.1.j All shutdown and control rods not fully inserted shall be OPERABLE.

APPLICABILITY: MODES 3, 4, and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rods A.1 Verify SDM is within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. the limits specified in the COLR. AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter B. Required Action and B.1 Initiate and continue 15 minutes associated Completion boration to restore Time of Condition A the required SDM to not met. within limits specified in the OR COLR.

SDM not within the limits specified in the COLR for Required Action A.1.

BRAIDWOOD UNITS 1 & 2 3.1.j 1 Revision 1 Technical Requirements Manual

TRM Shutdown and Control Rods 3.1.j SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY NONE BRAIDWOOD UNITS 1 & 2 3.1.j 2 Revision 1 Technical Requirements Manual

TRM Position Indication System - Shutdown (Special Test Exception) 3.1.k 3.1 REACTIVITY CONTROL SYSTEMS 3.1.k Position Indication System - Shutdown (Special Test Exception)

TLCO 3.1.k The requirements of TLCO 3.1.g may be suspended provided either:

1. Only one shutdown or control bank is withdrawn from the fully inserted position at a time, or

2. The Reactor Coolant System (RCS) boron concentration is within the limits specified in the COLR for maintaining keff 0.987 with all shutdown and control rods fully withdrawn.

APPLICABILITY: MODES 3, 4, and 5 during performance of rod drop time measurements and during the surveillance of Digital Rod Position Indication (DRPI) for OPERABILITY.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE-------- A.1 Restore required 15 minutes Only applicable when OPERABLE DRPI.

invoking TLCO 3.1.k.1.

More than one bank of rods withdrawn.

OR

NOTE--------

Only applicable when invoking TLCO 3.1.k.2.

RCS boron concentration not within limit.

(continued)

BRAIDWOOD UNITS 1 & 2 3.1.k 1 Revision 14 Technical Requirements Manual

TRM Position Indication System - Shutdown (Special Test Exception) 3.1.k ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Actions and B.1 Initiate action to Immediately associated Completion fully insert all Times of Condition A rods.

not met.

OR B.2 Initiate boration to Immediately restore RCS boron concentration to within the limits specified in the COLR.

OR B.3 Open Reactor Trip Immediately Breakers (RTBs) and Reactor Trip Bypass Breakers (RTBBs).

BRAIDWOOD UNITS 1 & 2 3.1.k 2 Revision 11 Technical Requirements Manual

TRM Position Indication System - Shutdown (Special Test Exception) 3.1.k SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.k.1 -------------------NOTE--------------------

Only required to be performed when invoking TLCO 3.1.k.1.

Verify each DRPI agrees within 12 steps of Once within the group demand position when the rods are 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior stationary and within 24 steps of the group to the start of demand position during rod motion. rod drop time measurements AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter TSR 3.1.k.2 -------------------NOTE--------------------

Only required to be performed when invoking TLCO 3.1.k.2.

Verify the RCS boron concentration is Once within 2 within the limits specified in the COLR for hours prior to maintaining keff 0.987 with all shutdown the start of and control rods fully withdrawn. either rod drop time measurements or the surveillance of DRPI for OPERABILITY AND 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months thereafter BRAIDWOOD UNITS 1 & 2 3.1.k 3 Revision 11 Technical Requirements Manual

TRM Movable Incore Detectors 3.3.a 3.3 INSTRUMENTATION 3.3.a Movable Incore Detectors TLCO 3.3.a The Movable Incore Detection System shall be OPERABLE with:

1. 75% of the detector thimbles,

2. 2 detector thimbles per core quadrant, and

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

NOTES --------------------------

Only 50% of the detector thimbles are required for:

1. Power Distribution Monitoring System (PDMS) calibrations after the initial PDMS calibration following each refueling.

2. Monitoring normalized symmetric power distribution, i.e., Quadrant Power Tilt Ratio (QPTR) via an incore flux map, provided there are 2 detector thimbles per core quadrant and at least 2 of the detector thimbles per core quadrant have a symmetric thimble in at least one other quadrant.

APPLICABILITY: When the Movable Incore Detection System is used for:

1. Recalibration of the Excore Neutron Flux Detection System,

2. Calibration of the PDMS,

3. Monitoring normalized symmetric power distribution, or

4. Measurement of FNH ,FQC(Z), and FQW(Z).

BRAIDWOOD UNITS 1 & 2 3.3.a 1 Revision 29 Technical Requirements Manual

TRM Movable Incore Detectors 3.3.a ACTIONS

NOTE-------------------------------------

TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Movable Incore A.1 Suspend use of the Immediately Detection System Movable Incore inoperable. Detection System data for applicable recalibration, measurement, or monitoring.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.a.1 Normalize each detector output when 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months required for:

a. Recalibration of the Excore Neutron Flux Detection System,

b. Calibration of the PDMS,

c. Monitoring normalized symmetric power distribution, or Measurement of FNH , FQ(Z), and FQ(Z).

C W d.

BRAIDWOOD UNITS 1 & 2 3.3.a 2 Revision 12 Technical Requirements Manual

TRM Seismic Monitoring Instrumentation 3.3.b 3.3 INSTRUMENTATION 3.3.b Seismic Monitoring Instrumentation TLCO 3.3.b The seismic monitoring instrumentation in Table T3.3.b-1 shall be OPERABLE.

APPLICABILITY: At all times.

ACTIONS

NOTES -----------------------------------

1. Separate Condition entry is allowed for each instrument.

2. TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more seismic A.1 Restore required 30 days monitoring instruments instrument to inoperable. OPERABLE status.

B. Required Action and B.1 Prepare and submit a 10 days associated Completion report to the Plant Time of Condition A Operating Review not met. Committee outlining the cause of the malfunction and the plans for restoring the instrument to OPERABLE status.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.b 1 Revision 1 Technical Requirements Manual

TRM Seismic Monitoring Instrumentation 3.3.b ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. ---------NOTES-------- C.1 Process data to be 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

1. Required Actions used in decision to C.1, C.2, C.4 and shut down the plant C.5 shall be completed whenever AND Condition C is entered. C.2 Conduct plant 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months walkdown inspections

2. Not applicable to to be used in triaxial peak decision to shut down accelerographs. the plant AND Containment Foundation accelerometer or Free C.3 Restore actuated 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Field accelerometer instrument(s) to actuated during a OPERABLE status.

confirmed seismic event. AND C.4 Perform TSR 3.3.b.3 5 days for each actuated instrument.

AND C.5 Prepare and submit a 10 days report to the Plant Operating Review Committee describing the magnitude, frequency spectrum, and resultant effect upon facility features important to safety.

BRAIDWOOD UNITS 1 & 2 3.3.b 2 Revision 99 Technical Requirements Manual

TRM Seismic Monitoring Instrumentation 3.3.b SURVEILLANCE REQUIREMENTS

NOTES ------------------------------------

1. Refer to Table T3.3.b-1 to determine which TSRs apply for each instrument.

2. Surveillances are defined in Regulatory Guide 1.12, Nuclear Power Plant Instrumentation for Earthquakes, Revision 2.

SURVEILLANCE FREQUENCY TSR 3.3.b.1 -------------------NOTE--------------------

Channel Check is verification of functional status.

Perform Channel Check. 31 days TSR 3.3.b.2 -------------------NOTE--------------------

Channel Functional Test is the determination that the sensor responds to known inputs.

Perform Channel Functional Test. 184 days TSR 3.3.b.3 -------------------NOTE--------------------

Channel Calibration is the determination that the sensor responds within a specific range and accuracy to known inputs.

Perform Channel Calibration. 18 months TSR 3.3.b.4 Install fresh magnetic recording plates in 18 months the triaxial peak accelerographs.

BRAIDWOOD UNITS 1 & 2 3.3.b 3 Revision 99 Technical Requirements Manual

TRM Seismic Monitoring Instrumentation 3.3.b Table T3.3.b-1 (page 1 of 1)

Seismic Monitoring Instrumentation REQUIRED SURVEILLANCE INSTRUMENTS AND SENSOR LOCATIONS(a) MEASUREMENT RANGE INSTRUMENTS REQUIREMENTS

1. Network Control Center (NCC)

Auxiliary Electrical Equipment Room, OPA02J

a. Internal Trigger(b) 0.001 g - 0.02 g 1(c) TSR 3.3.b.2

2. Triaxial Acceleration Sensors

a. Containment Foundation/10W - 377 ft -2 g to +2 g 1 TSR 3.3.b.1 TSR 3.3.b.2 TSR 3.3.b.3

b. Containment/10W - 502 ft -2 g to +2 g 1 TSR 3.3.b.1 TSR 3.3.b.2 TSR 3.3.b.3

c. Containment/10X - 426 ft -2 g to +2 g 1 TSR 3.3.b.1 TSR 3.3.b.2 TSR 3.3.b.3

d. Free Field/38 + 01S, 34 + 15E -4 g to +4 g 1 TSR 3.3.b.1 TSR 3.3.b.2 TSR 3.3.b.3

e. Auxiliary Building/18N - 426 ft -4 g to +4 g 1 TSR 3.3.b.1 TSR 3.3.b.2 TSR 3.3.b.3

f. Auxiliary Building/18L - 335 ft -4 g to +4 g 1 TSR 3.3.b.1 TSR 3.3.b.2 TSR 3.3.b.3

3. Triaxial Peak Accelerographs

a. Containment/Reactor Equipment Accumulators -2 g to +2 g 1 TSR 3.3.b.4

b. Containment/Reactor Piping -2 g to +2 g 1 TSR 3.3.b.4

c. Auxiliary Building/Category I Piping -2 g to +2 g 1 TSR 3.3.b.4 (a) All seismic sensors and instruments are located in Unit 1 (b) Adjustable setpoint (c) With control room annunciation BRAIDWOOD UNITS 1 & 2 3.3.b 4 Revision 99 Technical Requirements Manual

TRM Meteorological Monitoring Instrumentation 3.3.c 3.3 INSTRUMENTATION 3.3.c Meteorological Monitoring Instrumentation TLCO 3.3.c The meteorological monitoring instrumentation channels in Table T3.3.c-1 shall be OPERABLE.

APPLICABILITY: At all times.

ACTIONS

NOTES ------------------------------------

1. Separate Condition entry is allowed for each channel.

2. TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore channel to 7 days meteorological OPERABLE status.

monitoring instrument channels inoperable.

B. Required Action and B.1 Prepare and submit a 10 days associated Completion report to the Plant Time of Condition A Operating Review not met. Committee outlining the cause of the malfunction and the plans for restoring the channel to OPERABLE status.

BRAIDWOOD UNITS 1 & 2 3.3.c 1 Revision 1 Technical Requirements Manual

TRM Meteorological Monitoring Instrumentation 3.3.c SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.c.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months TSR 3.3.c.2 Perform CHANNEL CALIBRATION. 184 days BRAIDWOOD UNITS 1 & 2 3.3.c 2 Revision 1 Technical Requirements Manual

TRM Meteorological Monitoring Instrumentation 3.3.c Table T3.3.c-1 (page 1 of 1)

Meteorological Monitoring Instrumentation REQUIRED SURVEILLANCE INSTRUMENT AND LOCATION CHANNELS REQUIREMENTS

1. Wind Speed

a. Nominal Elevation 34 ft 1 TSR 3.3.c.1 TSR 3.3.c.2

b. Nominal Elevation 203 ft 1 TSR 3.3.c.1 TSR 3.3.c.2

2. Wind Direction

a. Nominal Elevation 34 ft 1 TSR 3.3.c.1 TSR 3.3.c.2

b. Nominal Elevation 203 ft 1 TSR 3.3.c.1 TSR 3.3.c.2

3. Air Temperature - T (Nominal Elevation 30 ft/199 ft) 1 TSR 3.3.c.1 TSR 3.3.c.2 BRAIDWOOD UNITS 1 & 2 3.3.c 3 Revision 1 Technical Requirements Manual

TRM Loose-Part Detection System 3.3.d 3.3 INSTRUMENTATION 3.3.d Loose-Part Detection System TLCO 3.3.d The Loose-Part Detection instrumentation in Table T3.3.d-1 shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

NOTES -----------------------------------

1. Separate Condition entry is allowed for each instrument.

2. TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required 30 days Loose-Part Detection instrument to System instruments OPERABLE status.

inoperable.

B. Required Action and B.1 Prepare and submit a 10 days associated Completion report to the Plant Time of Condition A Operating Review not met. Committee outlining the cause of the malfunction and the plans for restoring the instrument to OPERABLE status.

BRAIDWOOD UNITS 1 & 2 3.3.d 1 Revision 1 Technical Requirements Manual

TRM Loose-Part Detection System 3.3.d SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.d.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months TSR 3.3.d.2 -------------------NOTE--------------------

Verification of setpoint not required.

Perform CHANNEL OPERATIONAL TEST. 31 days TSR 3.3.d.3 Perform CHANNEL CALIBRATION. 18 months BRAIDWOOD UNITS 1 & 2 3.3.d 2 Revision 1 Technical Requirements Manual

TRM Loose-Part Detection System 3.3.d Table T3.3.d-1 (page 1 of 1)

Loose-Part Detection Instrumentation

NOTE------------------------------------------------------------

The Loose-Part Detection Instrumentation is considered OPERABLE if one of the two sensor channels for each instrument in Table T3.3.d-1 and the associated amplifier are OPERABLE.

REQUIRED SURVEILLANCE INSTRUMENT AND LOCATION CHANNELS REQUIREMENTS

1. Reactor Head 1 TSR 3.3.d.1 TSR 3.3.d.2

a. _VE-LM001 (270°) TSR 3.3.d.3 OR

b. _VE-LM002 (0°)

2. Reactor Bottom 1 TSR 3.3.d.1 TSR 3.3.d.2

a. _VE-LM003 (G-9) TSR 3.3.d.3 OR

b. _VE-LM004 (H-13)

3. "A" Steam Generator Channel Head 1 TSR 3.3.d.1 TSR 3.3.d.2

a. _VE-LM005 (Hot Side) TSR 3.3.d.3 OR

b. _VE-LM006 (Cold Side)

4. "B" Steam Generator Channel Head 1 TSR 3.3.d.1 TSR 3.3.d.2

a. _VE-LM007 (Hot Side) TSR 3.3.d.3 OR

b. _VE-LM008 (Cold Side)

5. "C" Steam Generator Channel Head 1 TSR 3.3.d.1 TSR 3.3.d.2

a. _VE-LM009 (Hot Side) TSR 3.3.d.3 OR

b. _VE-LM010 (Cold Side)

6. "D" Steam Generator Channel Head 1 TSR 3.3.d.1 TSR 3.3.d.2

a. _VE-LM011 (Hot Side) TSR 3.3.d.3 OR

b. _VE-LM012 (Cold Side)

BRAIDWOOD UNITS 1 & 2 3.3.d 3 Revision 1 Technical Requirements Manual

TRM Explosive Gas Monitoring Instrumentation 3.3.e 3.3 INSTRUMENTATION 3.3.e Explosive Gas Monitoring Instrumentation TLCO 3.3.e The explosive gas monitoring instrumentation channels in Table T3.3.e-1 shall be OPERABLE with their Alarm/Trip setpoints set to ensure that the limits of the Explosive Gas and Storage Tank Radioactivity Monitoring Program are not exceeded.

APPLICABILITY: According to Table T3.3.e-1.

ACTIONS

NOTES ------------------------------------

1. Separate Condition entry is allowed for each channel.

2. TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1.1 Suspend affected Immediately channels inoperable. system operation.

OR (continued)

BRAIDWOOD UNITS 1 & 2 3.3.e 1 Revision 1 Technical Requirements Manual

TRM Explosive Gas Monitoring Instrumentation 3.3.e ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.1.2.1 ---------NOTE--------

Only applicable during degassing operation.

Take and analyze grab Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months samples.

AND A.1.2.2 ---------NOTE--------

Only applicable during non-degassing operations.

Take and analyze grab Once per samples. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND A.2.1 Restore channel to 30 days OPERABLE status.

OR A.2.2 Prepare and submit a 60 days report to the Plant Operating Review Committee explaining the reason for not correcting the inoperability in a timely manner.

BRAIDWOOD UNITS 1 & 2 3.3.e 2 Revision 1 Technical Requirements Manual

TRM Explosive Gas Monitoring Instrumentation 3.3.e SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.e.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months TSR 3.3.e.2 Perform CHANNEL OPERATIONAL TEST. 31 days TSR 3.3.e.3 -------------------NOTES-------------------

1. For the Hydrogen Analyzer, the CHANNEL CALIBRATION shall include the use of standard gas samples containing hydrogen and nitrogen.

2. For the Oxygen Analyzer and the Waste Gas Compressor Discharge Oxygen Analyzer, the CHANNEL CALIBRATION shall include the use of standard gas samples containing oxygen and nitrogen.

Perform CHANNEL CALIBRATION. 92 days BRAIDWOOD UNITS 1 & 2 3.3.e 3 Revision 1 Technical Requirements Manual

TRM Explosive Gas Monitoring Instrumentation 3.3.e Table T3.3.e-1 (page 1 of 1)

Explosive Gas Monitoring Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE INSTRUMENT CONDITIONS CHANNELS REQUIREMENTS

1. Hydrogen Analyzer (0AT-GW8000) (a) 1 TSR 3.3.e.1 TSR 3.3.e.2 TSR 3.3.e.3

2. Oxygen Analyzer (0AIT-GW8003) (a) 1 TSR 3.3.e.1 TSR 3.3.e.2 TSR 3.3.e.3

3. Waste Gas Compressor Discharge Oxygen (b) 1 TSR 3.3.e.1 Analyzer (0AIT-GW004) TSR 3.3.e.2 TSR 3.3.e.3 (a) During WASTE GAS HOLDUP SYSTEM operation.

(b) During Waste Gas Compressor operation.

BRAIDWOOD UNITS 1 & 2 3.3.e 4 Revision 46 Technical Requirements Manual

TRM HELB Isolation Sensors 3.3.f 3.3 INSTRUMENTATION 3.3.f High Energy Line Break (HELB) Isolation Sensors TLCO 3.3.f The HELB instrumentation channels shown in Table T3.3.f-1 shall be OPERABLE.

APPLICABILITY: According to Table T3.3.f-1.

ACTIONS

NOTES------------------------------------

1. Separate Condition entry is allowed for each channel.

2. TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore the required 7 days auxiliary steam channel to OPERABLE isolation status.

instrumentation channels inoperable. OR A.2 Suspend the supply of 7 days auxiliary steam to the Auxiliary Building.

OR A.3 Establish a 7 days continuous watch in the affected area.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.f 1 Revision 1 Technical Requirements Manual

TRM HELB Isolation Sensors 3.3.f ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more required B.1 Restore the required 7 days steam generator channel to OPERABLE blowdown line status.

isolation instrumentation OR channels inoperable.

B.2 Limit the total steam 7 days generator blowdown flow rate to 60 gpm on the affected unit.

OR B.3 Establish a 7 days continuous watch in the affected area.

SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

TSR 3.3.f.1 and TSR 3.3.f.2 apply to each HELB instrument in Table T3.3.f-1.

SURVEILLANCE FREQUENCY TSR 3.3.f.1 Perform CHANNEL OPERATIONAL TEST. 18 months TSR 3.3.f.2 Perform CHANNEL CALIBRATION. 18 months BRAIDWOOD UNITS 1 & 2 3.3.f 2 Revision 1 Technical Requirements Manual

TRM HELB Isolation Sensors 3.3.f Table T3.3.f-1 (page 1 of 1)

High Energy Line Break Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED INSTRUMENT AND LOCATION CONDITIONS CHANNELS

1. Auxiliary Steam Isolation

a. 0TS-AS031A (a) 1 0TS-AS032A

b. 0TS-AS031B (a) 1 0TS-AS032B

c. 0TS-AS031C (b) 1 0TS-AS032C

d. 0TS-AS031D (b) 1 0TS-AS032D

e. 0TS-AS031E (b) 1 0TS-AS032E

f. 0TS-AS031F (b) 1 0TS-AS032F

2. Steam Generator Blowdown Line Isolation

a. TS-SD045A 1,2,3,4 1 TS-SD045B

b. TS-SD046A 1,2,3,4 1 TS-SD046B

c. TS-SD045C 1,2,3,4 1 TS-SD045D

d. TS-SD046C 1,2,3,4 1 TS-SD046D (a) When auxiliary steam is supplied from any source to the Auxiliary Building, except when the Recycle Evaporator Auxiliary Steam blank-off flange is installed in line 0AS96A-10.

(b) When auxiliary steam is supplied from any source to the Auxiliary Building, except when the Radwaste Evaporator Auxiliary Steam blank-off flange is installed in line 0AS03F-16.

BRAIDWOOD UNITS 1 & 2 3.3.f 3 Revision 49 Technical Requirements Manual

TRM Turbine Overspeed Protection 3.3.g 3.3 INSTRUMENTATION 3.3.g Turbine Overspeed Protection TLCO 3.3.g At least one Turbine Overspeed Protection System, as shown in Table T3.3.g-1, shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One throttle valve or A.1 Restore the valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months one governor valve per OPERABLE status.

high pressure turbine steam line inoperable.

B. One reheat stop valve B.1 Restore the valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or one reheat OPERABLE status.

intercept valve per low pressure turbine steam line inoperable.

C. Required Action and C.1 Close at least one 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion valve in the affected Time of Condition A or steam line.

B not met.

OR C.2 Isolate the turbine 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months from the steam supply.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.g 1 Revision 57 Technical Requirements Manual

TRM Turbine Overspeed Protection 3.3.g ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Turbine Overspeed D.1 ---------NOTE--------

Protection System For additional inoperable for reasons guidance, reference other than Condition A Tables T3.3.g-1 and or B. T3.3.g-2.

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

SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

TSR 3.0.d is not applicable.

SURVEILLANCE FREQUENCY TSR 3.3.g.1 Cycle each of the 12 extraction steam Once within nonreturn check valves from the closed 7 days prior to position. entering MODE 3 from MODE 4.

TSR 3.3.g.2 -------------------NOTE--------------------

Only required to be performed during turbine operation.

Verify, by direct observation, freedom of 31 days movement of each of the 12 extraction steam nonreturn check valve weight arms.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.g 2 Revision 57 Technical Requirements Manual

TRM Turbine Overspeed Protection 3.3.g SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.3.g.3 -------------------NOTE--------------------

Only required to be performed during turbine operation.

Verify, by direct observation, closure of 92 days each of the following valves from the running position.

a. Six turbine reheat stop valves; and

b. Six turbine reheat intercept valves.

TSR 3.3.g.4 -------------------NOTE--------------------

Only required to be performed during turbine operation.

Verify, by direct observation, closure of 184 days each of the following valves from the running position.

a. Four high pressure turbine throttle valves; and

b. Four high pressure turbine governor valves.

TSR 3.3.g.5 Perform CHANNEL CALIBRATION. 18 months (continued)

BRAIDWOOD UNITS 1 & 2 3.3.g 3 Revision 97 Technical Requirements Manual

TRM Turbine Overspeed Protection 3.3.g SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.3.g.6 Disassemble at least one of each type of 40 months the following valves and perform a visual and surface inspection of valve seats, disks, and stems to verify no unacceptable flaws or corrosion:

a. Four high pressure turbine throttle valves,

b. Four high pressure turbine governor valves,

c. Six turbine reheat stop valves,

d. Six turbine reheat intercept valves; and

e. Twelve extraction steam nonreturn check valves.

BRAIDWOOD UNITS 1 & 2 3.3.g 4 Revision 8 Technical Requirements Manual

TRM Turbine Overspeed Protection 3.3.g TABLE T3.3.g-1 (page 1 of 1)

Turbine Overspeed Protection

NOTE -------------------------------------------------------------

TLCO 3.3.g requires at least one Turbine Overspeed Protection System to be OPERABLE. This TLCO is satisfied by the operability of one overspeed trip network along with the turbine throttle, governor, reheat stop, reheat intercept, and nonreturn check valves.

OVERSPEED TRIP OVERSPEED TRIP OVERSPEED TRIP NETWORK #1 NETWORK #2 NETWORK #3 Speed Probes(1/2SE-TS013_) Speed Probes (1/2SE-TS011_) Speed Probes (1/2SE-TS014_)

Turbine Emergency Trip Cabinet DEH Control Cabinet 1/2PA22J DEH Control Cabinet 1/2PA22J 1/2PA38J High Pressure Trip Manifold High Pressure Trip Manifold OST-2 Solenoids 1/2FSV-EH5022A, B, C and Solenoids 1/2FSV-EH5021A, B, C and (b) (c)

D D Turbine Overspeed Trip System Panel 1/2TG09J High Pressure Trip Manifold Solenoids 1/2FSV-EH5021A, B, C and D (a) and 1/2FSV-EH5022A, B, C and D (a) The high pressure trip manifold solenoid portion of Overspeed Trip Network #1 is OPERABLE provided any one of the following combinations of solenoids are OPERABLE: 1/2FSV-EH5021A and 1/2FSV-EH5021B; 1/2FSV-EH5021A and 1/2FSV-EH5021D; 1/2FSV-EH5021B and 1/2FSV-EH5021C; 1/2FSV-EH5021C and 1/2FSV-EH5021D; 1/2FSV-EH5022A and 1/2FSV-EH5022B; 1/2FSV-EH5022A and 1/2FSV-EH5022D; 1/2FSV-EH5022B and 1/2FSV-EH5022C; or 1/2FSV-EH5022C and 1/2FSV-EH5022D.

(b) The high pressure trip manifold solenoid portion of Overspeed Trip Network #2 is OPERABLE provided any one of the following combinations of solenoids are OPERABLE: 1/2FSV-EH5022A and 1/2FSV-EH5022B; 1/2FSV-EH5022A and 1/2FSV-EH5022D; 1/2FSV-EH5022B and 1/2FSV-EH5022C; or 1/2FSV-EH5022C and 1/2FSV-EH5022D.

(c) The high pressure trip manifold solenoid portion of Overspeed Trip Network #3 is OPERABLE provided any one of the following combinations of solenoids are OPERABLE: 1/2FSV-EH5021A and 1/2FSV-EH5021B; 1/2FSV-EH5021A and 1/2FSV-EH5021D; 1/2FSV-EH5021B and 1/2FSV-EH5021C; or 1/2FSV-EH5021C and 1/2FSV-EH5021D.

Entry into TLCO 3.3.g, CONDITIONS A or B is only required when a problem exists with one of the specified valves prohibiting it from closing. The inability of the valve to close requires it to be declared inoperable.

Entry into TLCO 3.3.g, CONDITION D requires isolation of the turbine from the steam supply within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for the Turbine Overspeed Protection System being inoperable for reasons other than those identified in CONDITIONS A and B.

Examples could include:

1. NO OVERSPEED TRIP NETWORK The main turbine has three separate electrical overspeed trip networks. Overspeed Trip Network #1 is comprised of speed probes 1/2SE-TS013_, 1/2PA38J, OST-2, 1/2TG09J and High Pressure Trip Manifold Solenoids 1/2FSV-EH5021A, B, C and D and 1/2FSV-EH5022A, B, C and D. Overspeed Trip Network #2 is comprised of speed probes 1/2SE-TS011_, 1/2PA22J and High Pressure Trip Manifold Solenoids 1/2FSV-EH5022A, B, C and D.

Overspeed Trip Network #3 is comprised of speed probes 1/2SE-TS014_, 1/2PA22J and High Pressure Trip Manifold Solenoids 1/2FSV-EH5021A, B, C and D. With no overspeed trip network, the turbine must be isolated from the steam supply.

2. FAILURE ON A NONRETURN CHECK VALVE Failure of a nonreturn check valve to move freely would require the valve to be declared inoperable and entry in to CONDITION D. Isolation of the steam flow path is accomplished by closing the MOV and/or manual isolation valve. Closing the MOV and/or manual isolation valve prohibits the reflux of extraction steam from the isolated steam line and satisfies Required Action of CONDITION D. Reference Table T3.3.g-2 for determining the correct valve (MOV or manual) to isolate the flow path.

BRAIDWOOD UNITS 1 & 2 3.3.g 5 Revision 70 Technical Requirements Manual

TRM Turbine Overspeed Protection 3.3.g TABLE T3.3.g-2 (page 1 of 1)

Extraction Steam Nonreturn Check Valves and the Associated MOV or Manual Isolation Valve HEATER FAILED EXTRACTION STEAM MOTOR-OPERATED MANUAL ISOLATION NONRETURN CHECK VALVE ISOLATION VALVE VALVES

_2A _ES011A _ES010A NA

_2B _ES011B _ES010B NA

_2C _ES011C _ES010C NA

_3A _ES015A _ES013A NA

_3B _ES015B _ES013B NA

_3C _ES015C _ES013C NA

_4A _ES017A _ES016A NA

_4B _ES017B _ES016B NA

_4C _ES017C _ES016C NA

_5A _ES008 _ES007 _ES009A

_5B _ES008 _ES007 _ES009B

_6A _ES002 _ES001 _ES003A

_6B _ES002 _ES001 _ES003B

_7A _ES005 _ES004 _ES006A

_7B _ES005 _ES004 _ES006B BRAIDWOOD UNITS 1 & 2 3.3.g 6 Revision 57 Technical Requirements Manual

TRM PDMS 3.3.h 3.3 INSTRUMENTATION 3.3.h Power Distribution Monitoring System (PDMS)

TLCO 3.3.h The PDMS shall be OPERABLE with required PDMS instrumentation in Table T3.3.h-1 OPERABLE.

APPLICABILITY: MODE 1 with THERMAL POWER > 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1 Restore required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Separate Condition channel to OPERABLE entry is allowed for status.

each Function.

One or more Functions with one or more required channels inoperable.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.h 1 Revision 16 Technical Requirements Manual

TRM PDMS 3.3.h ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. PDMS inoperable for B.1 Apply LCO 3.1.4, "Rod Immediately reasons other than Group Alignment Condition A. Limits," as applicable, with PDMS OR inoperable.

AND Required Action and associated Completion B.2 Apply LCO 3.2.1, Immediately Time of Condition A "Heat Flux Hot not met. Channel Factor (FQ(Z))," as applicable, with PDMS inoperable.

AND B.3 Apply LCO 3.2.2, Immediately "Nuclear Enthalpy Rise Hot Channel Factor (F!NH)," as applicable, with PDMS inoperable.

AND B.4 Apply LCO 3.2.4, Immediately "Quadrant Power Tilt Ratio (QPTR)," as applicable, with PDMS inoperable.

BRAIDWOOD UNITS 1 & 2 3.3.h 2 Revision 102 Technical Requirements Manual

TRM PDMS 3.3.h SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.h.1 Perform CHANNEL CHECK for each required 7 days instrumentation channel.

TSR 3.3.h.2 -------------------NOTE--------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for each 18 months required instrumentation channel.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.h 3 Revision 16 Technical Requirements Manual

TRM PDMS 3.3.h SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.3.h.3 Perform PDMS calibration. Prior to declaring PDMS OPERABLE after each refueling AND

NOTE------

Not required to be performed until 31 Effective Full Power Days (EFPD) after the Core Exit Thermocouple (CETC) chess knight move pattern not satisfied 31 EFPD thereafter with the CETC chess knight move pattern not satisfied AND 180 EFPD thereafter with the CETC chess knight move pattern satisfied BRAIDWOOD UNITS 1 & 2 3.3.h 4 Revision 16 Technical Requirements Manual

TRM PDMS 3.3.h Table T3.3.h-1 (Page 1 of 1)

Power Distribution Monitoring System Instrumentation REQUIRED FUNCTION CHANNELS

1. Power Range Neutron Flux Monitors 3

2. Reactor Coolant System (RCS) Cold Leg 2 Temperature

3. Reactor Power 1(a)

4. Control Bank Position (per bank) 1(b)

5. Core Exit Temperature 17 with 2 per core quadrant (a) Either calorimetric power, the average power of the power range neutron flux monitors, or the average power of the !T channels.

(b) Either the Demand Position Indication System or the Digital Rod Position Indication (DRPI) System.

BRAIDWOOD UNITS 1 & 2 3.3.h 5 Revision 16 Technical Requirements Manual

TRM PAM Instrumentation 3.3.i 3.3 INSTRUMENTATION 3.3.i Post Accident Monitoring (PAM) Instrumentation TLCO 3.3.i The PAM instrumentation for each Function shown in Table T3.3.i-1 shall be OPERABLE.

APPLICABILITY: According to Table T3.3.i-1.

ACTIONS

NOTES ------------------------------------

1. Separate Condition entry is allowed for each Function.

2. TLCO 3.0.d.3 is applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Enter the Condition Immediately with one or more referenced in required channel Table T3.3.i-1 for inoperable. the channel.

B. As required by B.1 Restore required 30 days Required Action A.1 channel to OPERABLE and referenced in status.

Table T3.3.i-1.

C. As required by C.1 Restore one required 7 days Required Action A.1 channel to OPERABLE and referenced in status.

Table T3.3.i-1.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.i 1 Revision 37 Technical Requirements Manual

TRM PAM Instrumentation 3.3.i ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. ---------NOTE--------- D.1 Initiate alternate 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Required Action D.2.2 method of monitoring shall be completed the appropriate whenever Required parameters.

Action D.2.1 is not met. AND D.2.1 Restore one required 7 days As required by channel to OPERABLE Required Action A.1 status.

and referenced in Table T3.3.i-1. OR D.2.2 Submit a report to 14 days the Plant Operating Review Committee outlining the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

E. One or more Functions E.1 Restore one required 7 days with two required channel to OPERABLE channels inoperable. status.

F. Required Action and F.1 Enter TLCO 3.0.c. Immediately associated Completion Time of Condition B, C, D or E not met.

BRAIDWOOD UNITS 1 & 2 3.3.i 2 Revision 1 Technical Requirements Manual

TRM PAM Instrumentation 3.3.i SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.i.1 Perform CHANNEL CHECK. 31 days TSR 3.3.i.2 Perform CHANNEL CALIBRATION. 18 months BRAIDWOOD UNITS 1 & 2 3.3.i 3 Revision 1 Technical Requirements Manual

TRM PAM Instrumentation 3.3.i Table T3.3.i-1 (page 1 of 1)

Post Accident Monitoring Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

1. Auxiliary Feedwater Flow Rate 1,2,3 2 B TSR 3.3.i.1 (per SG) TSR 3.3.i.2

2. PORV Position Indicator(a) 1,2,3 1 C TSR 3.3.i.1 (open/closed) (per valve)

3. PORV Block Valve Position 1,2,3 1 C TSR 3.3.i.1 Indicator(b) (open/closed) (per valve)

4. Safety Valve Position Indicator 1,2,3 1 C TSR 3.3.i.1 (open/closed) (per valve)

5. Containment Floor Drain Sump 1,2,3 2 B TSR 3.3.i.1 Water Level (Narrow Range) TSR 3.3.i.2

6. Auxiliary Building Vent Stack 1,2,3 1 D TSR 3.3.i.1 (Wide Range Noble Gas) (per TSR 3.3.i.2 stack)

7. Reactor Coolant Subcooling 1,2,3 2 B None Margin Monitor(c)

(a) Not applicable if the associated block valve is in the closed position.

(b) Not applicable if the block valve is verified in the closed position and power is removed.

(c) Use monitoring channels (10 highest average core exit temperatures) in conjunction with RCS pressure to determine the subcooling margin.

BRAIDWOOD UNITS 1 & 2 3.3.i 4 Revision 1 Technical Requirements Manual

TRM Hydrogen Monitor 3.3.j 3.3 INSTRUMENTATION 3.3.j Hydrogen Monitor TLCO 3.3.j One containment hydrogen monitor channel shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

NOTE------------------------------------

TLCO 3.0.d.3 is applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTES-------- A.1 Place the hydrogen Immediately

1. The monitor must monitor in the be in standby mode standby mode.

to meet the requirement in OR NUREG-0737, Item II.F.1.6. A.2 Declare the hydrogen Immediately monitor inoperable.

2. Not applicable if hydrogen monitor is in operation.

Required hydrogen monitor not in the standby mode.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.j 1 Revision 38 Technical Requirements Manual

TRM Hydrogen Monitor 3.3.j ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required hydrogen B.1 Confirm readiness for Immediately monitor channel utilizing alternate inoperable. method of monitoring.

AND B.2 Restore required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months hydrogen monitor channel to OPERABLE status.

C. Required Action and C.1 Submit a report to 14 days associated Completion the Plant Operating Time of Condition B Review Committee not met. outlining the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the hydrogen monitor channel to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.j.1 Verify hydrogen monitor is in standby mode. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months TSR 3.3.j.2 Perform CHANNEL CHECK. 31 days TSR 3.3.j.3 Perform CHANNEL OPERATIONAL TEST. 92 days TSR 3.3.j.4 Perform CHANNEL CALIBRATION. 18 months BRAIDWOOD UNITS 1 & 2 3.3.j 2 Revision 38 Technical Requirements Manual

TRM Feedwater Flow 3.3.k 3.3 INSTRUMENTATION 3.3.k Feedwater Flow TLCO 3.3.k The Leading Edge Flow Meter system shall be OPERABLE.

APPLICABILITY: MODE 1, with THERMAL POWER > 98.3% RTP.

ACTIONS

NOTE------------------------------------

TLCO 3.0.d.2 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. LEFM system A.1 Restore LEFM system 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. to OPERABLE status.

B. REQUIRED ACTION and B.1 Reduce power to Immediately associated COMPLETION < 98.3% RTP.

TIME of CONDITION A not met.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.k 1 Revision 84 Technical Requirements Manual

TRM Feedwater Flow 3.3.k SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.k.1 Perform CHANNEL CHECK. Prior to exceeding 98.3%

RTP AND Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter TSR 3.3.k.2 Perform CHANNEL CALIBRATION. Once per 24 months BRAIDWOOD UNITS 1 & 2 3.3.k 2 Revision 91 Technical Requirements Manual

TRM FHB Ventilation System Actuation Instrumentation 3.3.o 3.3 INSTRUMENTATION 3.3.o Fuel Handling Building Exhaust Filter Plenum (FHB) Ventilation System Actuation Instrumentation TLCO 3.3.o The FHB Ventilation System actuation instrumentation in Table T3.3.o-1 shall be OPERABLE.

APPLICABILITY: According to Table T3.3.o-1.

ACTIONS

NOTE-------------------------------------

TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Restore channel to 7 days inoperable. OPERABLE status.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.o 1 Revision 1 Technical Requirements Manual

TRM FHB Ventilation System Actuation Instrumentation 3.3.o ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1.1 Place in emergency Immediately associated Completion mode one FHB Time for Condition A Ventilation System not met. train capable of being powered by an OR OPERABLE emergency power source.

Two channels inoperable. AND B.1.2 Take actions to Immediately provide an appropriate portable continuous monitor with the same alarm setpoint in the fuel pool area.

OR B.2 Suspend crane Immediately operations with loads, including new fuel assemblies, over or within the spent fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.o.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

BRAIDWOOD UNITS 1 & 2 3.3.o 2 Revision 1 Technical Requirements Manual

TRM FHB Ventilation System Actuation Instrumentation 3.3.o SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.3.o.2 Perform CHANNEL OPERATIONAL TEST. 92 days TSR 3.3.o.3 Perform CHANNEL CALIBRATION. 18 months BRAIDWOOD UNITS 1 & 2 3.3.o 3 Revision 1 Technical Requirements Manual

TRM FHB Ventilation System Actuation Instrumentation 3.3.o TABLE T3.3.o-1 (page 1 of 1)

FHB Ventilation System Actuation Instrumentation APPLICABLE MODES OR OTHER SPECIFIED ALARM/TRIP REQUIRED SURVEILLANCE FUNCTIONAL UNIT CONDITIONS SETPOINT CHANNELS REQUIREMENTS Fuel Building Isolation (a) 5 mR/h 2 TSR 3.3.o.1 Radioactivity-High and Criticality TSR 3.3.o.2 (0RE-AR055/56) TSR 3.3.o.3 (a) During crane operations with loads, including new fuel assemblies, over or within the spent fuel storage pool.

BRAIDWOOD UNITS 1 & 2 3.3.o 4 Revision 1 Technical Requirements Manual

TRM Radiation Monitoring Instrumentation 3.3.p 3.3 INSTRUMENTATION 3.3.p Radiation Monitoring Instrumentation TLCO 3.3.p The Radiation Monitoring instrumentation Alarm/Trip Setpoints for each Function in Table T3.3.p-1 shall be OPERABLE.

APPLICABILITY: According to Table T3.3.p-1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Adjust the Setpoint 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months with one or more to within limit.

required channels Alarm/Trip Setpoint(s) not within limits specified in Table T3.3.p-1.

(continued)

BRAIDWOOD UNITS 1 & 2 3.3.p 1 Revision 1 Technical Requirements Manual

TRM Radiation Monitoring Instrumentation 3.3.p ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare the channel Immediately associated Completion inoperable and enter Time of Condition A applicable Condition not met. and Required Actions of LCO 3.3.6, "Containment Ventilation Isolation Instrumentation,"

LCO 3.3.7, "VC Filtration System Actuation Instrumentation,"

LCO 3.3.8, "FHB Ventilation System Actuation Instrumentation,"

TLCO 3.3.o, "FHB Ventilation System Actuation Instrumentation," and TLCO 3.7.i, "FHB Ventilation Systems,"

for one or more radiation monitors inoperable, as applicable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.p.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months TSR 3.3.p.2 Perform CHANNEL OPERATIONAL TEST. 92 days (continued)

BRAIDWOOD UNITS 1 & 2 3.3.p 2 Revision 1 Technical Requirements Manual

TRM Radiation Monitoring Instrumentation 3.3.p SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.3.p.3 Perform CHANNEL CALIBRATION. 18 months BRAIDWOOD UNITS 1 & 2 3.3.p 3 Revision 1 Technical Requirements Manual

TRM Radiation Monitoring Instrumentation 3.3.p TABLE T3.3.p-1 (page 1 of 1)

Radiation Monitoring Instrumentation for Plant Operations APPLICABLE MODES CHANNELS OR OTHER SPECIFIED ALARM/TRIP REQUIRED TO SURVEILLANCE FUNCTIONAL UNIT CONDITIONS SETPOINT CHANNELS TRIP/ALARM REQUIREMENTS

1. Fuel Building Isolation (a) ! 5 mR/hr 2 1 TSR 3.3.p.1 Radioactivity-High and TSR 3.3.p.2 Criticality TSR 3.3.p.3 (0RE-AR055/56)

2. Containment Isolation Containment Radioactivity-High a) U-1 All (b) 2 1 TSR 3.3.p.1 (1RE-AR011/12) TSR 3.3.p.2 TSR 3.3.p.3 b) U-2 All (b) 2 1 TSR 3.3.p.1 (2RE-AR011/12) TSR 3.3.p.2 TSR 3.3.p.3

3. Main Control Room Isolation-Outside Air Intake-Gaseous Radioactivity-High a) Train A All ! 2 mR/hr 2 1 TSR 3.3.p.1 (0RE-PR031B/32B) TSR 3.3.p.2 TSR 3.3.p.3 b) Train B All ! 2 mR/hr 2 1 TSR 3.3.p.1 (0RE-PR033B/34B) TSR 3.3.p.2 TSR 3.3.p.3 (a) During crane operations with loads, including new fuel assemblies, over or within the spent fuel storage pool.

(b) Trip Setpoint shall be established at G 2 x background in the Containment Building at RTP.

BRAIDWOOD UNITS 1 & 2 3.3.p 4 Revision 87 Technical Requirements Manual

TRM ESFAS Instrumentation 3.3.y 3.3 INSTRUMENTATION 3.3.y Engineered Safety Feature Actuation System (ESFAS) Instrumentation TLCO 3.3.y The ESFAS Instrumentation in Table T3.3.y-1 shall be OPERABLE.

APPLICABILITY: According to Table T3.3.y-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Enter the Condition Immediately channel(s) inoperable. referenced in Table T3.3.y-1 for the channel.

B. One Auxiliary B.1 Restore channel to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Feedwater - Manual OPERABLE status.

Initiation channel inoperable.

C. Required Action and C.1 Enter TLCO 3.0.c. Immediately associated Completion Time of Condition B not met.

OR Two Auxiliary Feedwater - Manual Initiation channels inoperable.

BRAIDWOOD UNITS 1 & 2 3.3.y 1 Revision 78 Technical Requirements Manual

TRM ESFAS Instrumentation 3.3.y SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.y.1 Perform TRIP ACTUATING DEVICE OPERATIONAL 18 months TEST.

BRAIDWOOD UNITS 1 & 2 3.3.y 2 Revision 78 Technical Requirements Manual

TRM ESFAS Instrumentation 3.3.y Table T3.3.y-1 (page 1 of 1)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CONDITIONS CHANNELS REQUIREMENTS Auxiliary Feedwater - Manual 1,2,3 B, C 2 TSR 3.3.y.1 Initiation BRAIDWOOD UNITS 1 & 2 3.3.y 3 Revision 78 Technical Requirements Manual

TRM RCS Chemistry 3.4.b 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.b RCS Chemistry TLCO 3.4.b RCS Chemistry shall be maintained within the limits of Table T3.4.b-1.

APPLICABILITY: According to Table T3.4.b-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more chemistry A.1 Restore parameter to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months parameters in excess within its of its Steady-State Steady-State Limit.

Limit but within its Transient Limit.

B. Dissolved Oxygen B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months concentration in excess of its AND Steady-State Limit for

> 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . B.2 Be in MODE 4 with 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Tavg 250°F.

OR Dissolved Oxygen concentration in excess of its Transient Limit.

(continued)

BRAIDWOOD - UNITS 1 & 2 3.4.b - 1 Revision 1 Technical Requirements Manual

TRM RCS Chemistry 3.4.b ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Chloride or Fluoride C.1 Initiate action to Immediately concentration in reduce pressurizer excess of its pressure 500 psig.

Steady-State Limit for

> 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . AND OR C.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND Chloride or Fluoride concentration in C.3 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months excess of its Transient Limit. AND C.4 Perform an Prior to engineering increasing evaluation to pressurizer determine the effects pressure above of the out-of-limit 500 psig condition on the structural integrity OR of the RCS and to determine that the Prior to RCS remains proceeding to acceptable for MODE 4 from continued operation. MODE 5 BRAIDWOOD - UNITS 1 & 2 3.4.b - 2 Revision 1 Technical Requirements Manual

TRM RCS Chemistry 3.4.b SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

TSR 3.4.b.1 applies to each RCS Chemistry parameter in Table T3.4.b-1.

SURVEILLANCE FREQUENCY TSR 3.4.b.1 ------------------NOTES--------------------

1. Not required to be performed for Dissolved Oxygen if RCS Tavg 250°F.

2. Not required to be performed for Dissolved Oxygen in Mode 1 if Dissolved Hydrogen concentration is > 15 cc/kg and is sampled at the same frequency as Dissolved Oxygen.

Verify RCS chemistry parameters within In accordance limits specified in Table T3.4.b-1. with EPRI PWR Primary Water Chemistry Guidelines BRAIDWOOD - UNITS 1 & 2 3.4.b - 3 Revision 40 Technical Requirements Manual

TRM RCS Chemistry 3.4.b Table T3.4.b-1 RCS Chemistry Limits APPLICABLE MODES OR OTHER STEADY SPECIFIED STATE TRANSIENT PARAMETER CONDITIONS LIMIT LIMIT

1. Dissolved Oxygen MODES 1,2,3, and 100 ppb 1000 ppb MODE 4 with Tavg > 250°F

2. Chloride At All Times 150 ppb 1500 ppb

3. Fluoride At All Times 150 ppb 1500 ppb BRAIDWOOD UNITS 1 & 2 3.4.b 4 Revision 1 Technical Requirements Manual

TRM Pressurizer Temperature Limits 3.4.c 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.c Pressurizer Temperature Limits TLCO 3.4.c The pressurizer temperature shall be limited to:

1. 100°F heatup in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period;

2. 200°F cooldown in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period; and

3. 320°F spray water temperature differential.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1 Restore pressurizer 30 minutes Required Actions A.2 temperature to within and A.3 shall be limits.

completed whenever this Condition is AND entered.

A.2 Perform an 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months engineering Pressurizer evaluation to temperature not within determine the effects limits. of the out-of-limit condition on the structural integrity of the pressurizer.

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

(continued)

BRAIDWOOD UNITS 1 & 2 3.4.c 1 Revision 1 Technical Requirements Manual

TRM Pressurizer Temperature Limits 3.4.c ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Actions and B.1 ---------NOTE--------

associated Completion Required Action B.1 Times of Condition A is only applicable not met. when in MODES 1 and 2.

Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND B.2 Reduce pressurizer 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months pressure to

< 500 psig.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.4.c.1 -------------------NOTE--------------------

Only required to be performed during system heatup and cooldown.

Verify pressurizer heatup or cooldown rates 30 minutes are within limits.

TSR 3.4.c.2 -------------------NOTE--------------------

Only required to be performed during auxiliary spray operation.

Verify auxiliary spray water temperature 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months differential is within limit.

BRAIDWOOD UNITS 1 & 2 3.4.c 2 Revision 1 Technical Requirements Manual

TRM Reactor Vessel Head Vents 3.4.e 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.e Reactor Vessel Head Vents TLCO 3.4.e Two reactor vessel head vent paths, each consisting of two valves in series powered from emergency buses, shall be OPERABLE and closed.

NOTE ---------------------------

The reactor vessel head vent valves may be cycled for the purposes of re-seating to eliminate identified seat leakage, correcting indication problems, or Inservice Inspection in MODES 3 and 4 provided:

1. Only one valve in each train is cycled at a time; and

2. The same train redundant valve is verified closed and de-energized.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One reactor vessel A.1 Initiate action to Immediately head vent path maintain the inoperable. inoperable vent path closed.

AND A.2 Initiate action to Immediately remove power from the valve actuators of the valves in the inoperable vent path.

(continued)

BRAIDWOOD UNITS 1 & 2 3.4.e 1 Revision 34 Technical Requirements Manual

TRM Reactor Vessel Head Vents 3.4.e ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. ---------NOTE--------- B.1 Initiate action to Immediately TLCO 3.0.d.3 is maintain the applicable in MODES 1 inoperable vent paths and 2 provided closed.

Required Actions B.1 and B.2 are complete. AND B.2 Initiate action to Immediately Both reactor vessel remove power from the head vent paths valve actuators of inoperable. the valves in the inoperable vent paths.

AND B.3 Restore one vent path 30 days to OPERABLE status.

C. Required Actions and C.1 Enter TLCO 3.0.c. Immediately associated Completion Times of Condition B not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.4.e.1 Verify all manual isolation valves in each 18 months vent path are locked in the open position.

(continued)

BRAIDWOOD UNITS 1 & 2 3.4.e 2 Revision 37 Technical Requirements Manual

TRM Reactor Vessel Head Vents 3.4.e SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.4.e.2 -------------------NOTE--------------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4 except as allowed by TLCO Note.

18 months Perform a complete cycle of each valve in the vent path from the control room.

TSR 3.4.e.3 ------------------ NOTE--------------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

Verify flow through the reactor vessel head 18 months vent paths during venting operation.

BRAIDWOOD UNITS 1 & 2 3.4.e 3 Revision 34 Technical Requirements Manual

TRM Structural Integrity 3.4.f 3.4 Reactor Coolant System (RCS) 3.4.f Structural Integrity TLCO 3.4.f The structural integrity of all ASME Code Class 1, 2, and 3 plant components shall be maintained in accordance with the Inservice Inspection and Testing Programs.

APPLICABILITY: MODES 1, 2, 3, 4, 5, and 6.

ACTIONS

NOTES -----------------------------------

1. Separate Condition entry is allowed for each component.

2. TLCO 3.0.d.3 is applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1 Restore the Prior to Only applicable to structural integrity increasing the ASME Code Class 1 and of the affected RCS temperature 2 components. component to within to ! 200F

its limits.

Structural integrity OR of one or more ASME component(s) not in A.2 Isolate the affected Prior to conformance. component. increasing the RCS temperature to ! 200F (continued)

BRAIDWOOD UNITS 1 & 2 3.4.f 1 Revision 82 Technical Requirements Manual

TRM Structural Integrity 3.4.f ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. ---------NOTE--------- B.1 Restore the Immediately Only applicable to structural integrity ASME Code Class 3 of the affected components. component to within

its limits.

Structural integrity OR of one or more ASME component(s) not in B.2 Isolate the affected Immediately conformance. component.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.4.f.1 Perform an inspection of each RCP flywheel. In accordance with the RCP Flywheel Inspection Program.

TSR 3.4.f.2 Verify the structural integrity of ASME In accordance Code Class 1, 2, and 3 components. with the Inservice Inspection and Testing Programs.

BRAIDWOOD UNITS 1 & 2 3.4.f 2 Revision 82 Technical Requirements Manual

TRM ECCS Subsystems - Tavg 200°F and Pressurizer Level 5%

3.5.a 3.5 EMERGENCY CORE COOLING SYSTEM (ECCS) 3.5.a ECCS Subsystems - Tavg 200°F and Pressurizer Level 5%

TLCO 3.5.a One of the following means of decay heat removal shall be available:

1. One Safety Injection (SI) pump and flow path, or

2. A flow path to permit gravity feed from the RWST to the Reactor Coolant System (RCS) with the reactor vessel head removed.

APPLICABILITY: MODES 5 and 6 with pressurizer level 5%.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. No means of decay heat A.1 Initiate action to Immediately removal available. restore an available means of decay heat removal.

OR A.2 Initiate action to Immediately establish pressurizer level > 5%.

BRAIDWOOD UNITS 1 & 2 3.5.a 1 Revision 1 Technical Requirements Manual

TRM ECCS Subsystems - Tavg 200°F and Pressurizer Level 5%

3.5.a SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.5.a.1 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.5.a.1.

Verify the required SI pump motor circuit 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months breaker is racked in.

TSR 3.5.a.2 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.5.a.1.

Verify an OPERABLE flow path available from 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the RWST to the RCS.

TSR 3.5.a.3 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.5.a.2.

Verify the reactor vessel head is removed. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months TSR 3.5.a.4 -------------------NOTE--------------------

Only required to be performed when complying with TLCO 3.5.a.2.

Verify an OPERABLE flow path available to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months permit gravity feed from the RWST to the RCS.

BRAIDWOOD UNITS 1 & 2 3.5.a 2 Revision 1 Technical Requirements Manual

TRM Steam Generator Pressure/Temperature Limitations 3.7.a 3.7 PLANT SYSTEMS 3.7.a Steam Generator Pressure/Temperature Limitations TLCO 3.7.a Reactor and Secondary coolant pressure shall be 200 psig.

APPLICABILITY: When either Reactor or Secondary coolant temperature in the steam generator is 70°F.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each side (Primary or Secondary) of each steam generator.

CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1 Reduce the steam 30 minutes Required Actions A.2 generator pressure of and A.3 shall be the applicable side completed whenever to 200 psig.

this Condition is entered. AND A.2 Perform an Prior to Reactor coolant engineering increasing pressure > 200 psig. evaluation to temperature to determine the effect > 200°F OR of the overpressurization on Secondary coolant the structural pressure > 200 psig. integrity of the steam generator.

AND A.3 Determine that the Prior to steam generator increasing remains acceptable temperature to for continued > 200°F operation.

BRAIDWOOD UNITS 1 & 2 3.7.a 1 Revision 1 Technical Requirements Manual

TRM Steam Generator Pressure/Temperature Limitations 3.7.a SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.a.1 -------------------NOTE--------------------

Only required to be performed when the temperature of either Reactor or Secondary coolant 70°F.

Verify pressure in each side of the steam 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months generator is 200 psig.

BRAIDWOOD UNITS 1 & 2 3.7.a 2 Revision 1 Technical Requirements Manual

T~

Snubbers

3. 7.b 3.7 PLANT SYSTEMS 3.7.b Snubbers TLCO 3.7.b All required snubbers shall be OPERABLE.

NOTES--- ------------------------

1. Not applicable to snubbers installed on nonsafety related systems unless their failure, or failure of the associated system(s), would adversely affect any safety related system.

2. Required snubber(s) are those installed in a system, subsystem, or train required to be OPERABLE.

3. Verification of Steam Generator snubber fluid levels shall be through local examination of reservoirs and snubbers, not based on remote panel lighting indication.

APPLICABILITY: MODES 1, 2, 3, 4, and MODES 5, and 6 for snubbers located on systems required OPERABLE in those MODES.

BRAIDWOOD - UNITS 1 &2 3.7.b - 1 Revision 81 Technical Requirements Manual

TRM Snubbers 3.7.b ACTIONS

-- --- ------- -- --- - ----- ------ ---- ---NOTE - ------ -- -- ------ -- -- ---------- -- -- -

Separate Condition entry is allowed for each snubber.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1.1 Initiate an Immediatel y snubber(s) associated OPERABILITY with a TRM system Determination on the inoperable. attached component.

AND A. l. 2 Perform Engineering 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months evaluation on the attached component OR A.2 Declare the attached Immediately system inoperable and enter appropriate TRM action.

B. One or more required B.l Evaluate entry into Immediatel y snubber(s) associated Technical with a Technical Specification LCD Specification 3.0.9.

Structure, system or component inoperable. AND B.2 Evaluate the risk Immediately associated with the inoperable snubber and ability to properly manage the risk.

AND B.3 Evaluate Auxiliary Immediately Feedwater OPERABILITY and/or alternate core cooling capability AND BRAIDWOOD - UNITS 1 &2 3.7.b - 2 Revision 104 Technical Requirements Manual

TRM Snubbers 3.7.b CONDITION REQUIRED ACTION COMPLETION TIME B.4 Evaluate non-seismic Irrmediately capability associated with the inoperable snubber.

AND B.5.1 Perform an 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months engineering evaluation on attached component to determine potential system degradation.

OR B.5.2 Declare the affected Immediately plant system(s) inoperable.

BRAIDWOOD - UNITS 1 &2 3.7.b - 3 Revision 104 Technical Requirements Manual

TRM Snubbers 3.7.b SURVEILLANCE REQUIREMENTS

NOTE---------------------------------------

The provisions of TSR 3.0.b are applicable for all inspection intervals up to and including 48 months.

SURVEILLANCE FREQUENCY TSR 3.7.b.l Perform required inservice examinations and In accordance testing of snubbers in accordance with the with the Inservice Inspection Program. Inservice Inspection Program BRAIDWOOD - UNITS 1 &2 3.7.b - 4 Revision 104 Technical Requirements Manual

T~

Snubbers 3.7.b Table T3.7.b-l (page 1 of 1)

Snubber Inservice Inspection Program Elements A. Transient Event Inspection An inspection shall be performed of all snubbers attached to sections of systems that have experienced unexpected, potentially damaging transients as determined from a review of operational data and a visual inspection of the systems within 6 months following such an event. In addition to satisfying the visual inspection acceptance criteria, freedom of motion of mechanical snubbers shall be verified using at least one of the following: (1) manually induced snubber movement; or (2) evaluation of in-place snubber piston setting; or (3) stroking the mechanical snubber through its full range of travel.

B. Locations with Two Snubbers Configurations that utilize two snubbers at the same location shall be considered as one required snubber.

BRAIDWOOD - UNITS 1 &2 3.7.b - 5 Revision 104 Technical Requirements Manual

TRM Sealed Source Contamination 3.7.c 3.7 PLANT SYSTEMS 3.7.c Sealed Source Contamination TLCO 3.7.c Each sealed source containing radioactive material either in excess of 100 Ci of beta and/or gamma emitting material or 5 Ci of alpha emitting material shall be free of 0.005 Ci of removable contamination.

APPLICABILITY: At all times.

ACTIONS

NOTES ------------------------------------

1. Separate Condition entry is allowed for each source.

2. TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1 Withdraw the sealed Immediately Required Actions A.2 source from use.

and A.3 shall be completed whenever AND Condition A is entered. A.2.1 Decontaminate and Prior to use or

repair the sealed transfer to source. another licensee One or more sealed sources with removable OR contamination not within limits. A.2.2 Dispose of the sealed Immediately source in accordance with Commission Regulations.

AND A.3 Submit report to the 12 months Plant Operating Review Committee.

BRAIDWOOD UNITS 1 & 2 3.7.c 1 Revision 1 Technical Requirements Manual

TRM Sealed Source Contamination 3.7.c SURVEILLANCE REQUIREMENTS

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 Agreement State.

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

3. Startup sources and fission detectors previously subjected to core flux are exempted from the TSRs. Startup sources do not include "secondary startup sources" which do not contain radioactive material.

4. 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.

SURVEILLANCE FREQUENCY TSR 3.7.c.1 -------------------NOTE--------------------

Only required to be performed on sources in use.

Perform leakage testing for all sealed 6 months sources containing radioactive materials with a half-life > 30 days (excluding Hydrogen 3) and in any form other than gas.

(continued)

BRAIDWOOD UNITS 1 & 2 3.7.c 2 Revision 1 Technical Requirements Manual

TRM Sealed Source Contamination 3.7.c SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.7.c.2 -------------------NOTES-------------------

1. Only required to be performed on stored sources not in use.

2. Only required to be performed if not tested within the previous 6 months.

Perform leakage testing for each sealed Prior to use or source and fission detector. transfer to another licensee TSR 3.7.c.3 -------------------NOTE--------------------

Only required to be performed on stored sources not in use.

Perform leakage testing on sealed sources Prior to use or and fission detectors transferred without a transfer to certificate indicating the last test date. another licensee TSR 3.7.c.4 -------------------NOTE--------------------

Only required to be performed on sealed startup sources and fission detectors not previously subjected to core flux.

Perform leakage testing for each sealed Once within 31 startup source and fission detector. days prior to being subjected to core flux or installed in the core or following repair or maintenance to sources BRAIDWOOD UNITS 1 & 2 3.7.c 3 Revision 1 Technical Requirements Manual

TRM Area Temperature Monitoring 3.7.d 3.7 PLANT SYSTEMS 3.7.d Area Temperature Monitoring TLCO 3.7.d The temperature limit of each area in Table T3.7.d-1 shall not be exceeded for > 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , or by > 30° F.

APPLICABILITY: Whenever the equipment in the affected area is required to be OPERABLE.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each area.

CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1.1 Restore area 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Required Actions A.2 temperature to within and A.3 shall be limit.

completed whenever Condition A is OR entered.

A.1.2 Declare the equipment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months in the affected area One or more area inoperable.

temperatures exceeding the temperature limit AND by > 30°F.

A.2 Submit a report to 30 days the Plant Operating Review Committee outlining the cumulative time and the amount by which the temperature in the affected area exceeded the limit.

AND (continued)

BRAIDWOOD UNITS 1 & 2 3.7.d 1 Revision 1 Technical Requirements Manual

TRM Area Temperature Monitoring 3.7.d ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Perform an analysis 30 days to demonstrate the continued OPERABILITY of the affected equipment.

B. One or more area B.1 Submit a report to 30 days temperatures exceeding the Plant Operating the temperature limit Review Committee for > 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . outlining the cumulative time and the amount by which the temperature in the affected area exceeded the limit.

AND B.2 Perform an analysis 30 days to demonstrate the continued OPERABILITY of the affected equipment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.d.1 Verify each area temperature is within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limits in accordance with Table T3.7.d-1.

BRAIDWOOD UNITS 1 & 2 3.7.d 2 Revision 1 Technical Requirements Manual

TRM Area Temperature Monitoring 3.7.d Table T3.7.d-1 (page 1 of 1)

Area Temperature Monitoring TEMPERATURE LIMIT AREA (°F)

1. Miscellaneous Electrical Equipment and Battery Rooms 108

2. ESF Switchgear Rooms 108

3. Division 12 (Division 22) Cable Spreading Room 108

4. Upper Cable Spreading Rooms 90

5. Diesel Generator Rooms 132

6. Diesel Oil Storage Rooms 132

7. Auxiliary Building Vent Exhaust Filter Cubicle 105

8. Centrifugal Charging Pump Rooms 122

9. Containment Spray Pump Rooms 130

10. RHR Pump Rooms 130

11. Safety Injection Pump Rooms 130

12. Control Room 90

13. Lower Cable Spreading Rooms 108 BRAIDWOOD UNITS 1 & 2 3.7.d 3 Revision 24 Technical Requirements Manual

TRM Auxiliary Feedwater (AF) Flow Control Valves 3.7.g 3.7 PLANT SYSTEMS 3.7.g Auxiliary Feedwater (AF) Flow Control Valves TLCO 3.7.g The AF Flow Control Valves shall be OPERABLE.

APPLICABILITY: Modes 1, 2 and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1 Restore AF Flow 30 days Separate Condition Control Valve Air entry is allowed for accumulator(s) to each accumulator. OPERABLE status.

One or more AF Flow Control Valve Air Accumulator(s) inoperable.

B. One or more AF Flow B.1 Restore AF Flow 30 days Control Valve(s) not Control Valve(s) to capable of closing on OPERABLE status.

demand from the main control room.

C. ---------NOTE--------- C.1 Restore AF Flow 30 days Not applicable to Control Valve(s) to Unit 2. OPERABLE status.

One or more AF Flow Control Valve(s) not capable of throttling flow as assumed in the safety analysis for the Steam Generator Tube Rupture Margin to Overfill event.

(continued)

BRAIDWOOD UNITS 1 & 2 3.7.g 1 Revision 100 Technical Requirements Manual

TRM Auxiliary Feedwater (AF) Flow Control Valves 3.7.g ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Actions and D.1 Enter TLCO 3.0.c Immediately associated Completion Times of Conditions A, B or C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.g.1 Perform leakage test for each AF Flow In accordance Control Valve Air Accumulator. with the INSERVICE TESTING PROGRAM BRAIDWOOD UNITS 1 & 2 3.7.g 2 Revision 100 Technical Requirements Manual

TRM Fuel Handling Building Ventilation Systems 3.7.i 3.7 PLANT SYSTEMS 3.7.i Fuel Handling Building (FHB) Ventilation Systems TLCO 3.7.i Two FHB Ventilation System trains shall be OPERABLE.

NOTE----------------------------

The TLCO requirements do not apply when the main hoist/load block travels over the spent fuel pool without a load due to the design of the load block.

APPLICABILITY: During crane operation with loads, including new fuel assemblies, over or within the spent fuel storage pool.

ACTIONS

NOTE-------------------------------------

TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One FHB Ventilation A.1 Restore FHB 7 days System train Ventilation System inoperable. train to OPERABLE status.

B. Required Action and B.1 Place in emergency Immediately associated Completion mode one OPERABLE FHB Time of Condition A Ventilation System not met. train capable of being powered by an OPERABLE emergency power source.

OR B.2 Suspend crane Immediately operation with loads, including new fuel assemblies, over or within the spent fuel storage pool.

(continued)

BRAIDWOOD UNITS 1 & 2 3.7.i 1 Revision 77 Technical Requirements Manual

TRM Fuel Handling Building Ventilation Systems 3.7.i ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Two FHB Ventilation C.1 Suspend crane Immediately System trains operation with loads, inoperable. including new fuel assemblies, over or within the spent fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.i.1 For FHB Ventilation Systems required to be In accordance OPERABLE, the following SRs are applicable: with applicable SRs SR 3.7.13.1 SR 3.7.13.4 SR 3.7.13.2 SR 3.7.13.5 BRAIDWOOD UNITS 1 & 2 3.7.i 2 Revision 1 Technical Requirements Manual

TRM Spent Fuel Pool Water Level 3.7.j 3.7 PLANT SYSTEMS 3.7.j Spent Fuel Pool Water Level TLCO 3.7.j The spent fuel pool water level shall be 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY: During movement of loads, including new fuel assemblies, over or within the spent fuel pool.

ACTIONS

NOTE-------------------------------------

TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel pool water A.1 Suspend movement of Immediately level not within loads, including new limit. fuel assemblies, over or within the spent fuel pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.j.1 Verify spent fuel pool water level is 7 days 23 ft above the top of the irradiated fuel assemblies seated in the storage racks.

BRAIDWOOD UNITS 1 & 2 3.7.j 1 Revision 1 Technical Requirements Manual

TRM Spent Fuel Pool Boron Concentration 3.7.k 3.7 PLANT SYSTEMS 3.7.k Spent Fuel Pool Boron Concentration TLCO 3.7.k The spent fuel pool boron concentration shall be 2000 ppm.

APPLICABILITY: Whenever fuel assemblies are stored in the spent fuel pool.

ACTIONS

NOTE-------------------------------------

TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel pool boron A.1 Suspend movement of Immediately concentration not loads, including new within limit. fuel assemblies, over or within the spent fuel pool.

AND A.2 Initiate action to Immediately restore spent fuel pool boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.k.1 Verify the spent fuel pool boron 7 days concentration is within limit.

BRAIDWOOD UNITS 1 & 2 3.7.k 1 Revision 21 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a 3.8 ELECTRICAL POWER SYSTEMS 3.8.a Containment Penetration Conductor Overcurrent Protective Devices TLCO 3.8.a The containment penetration conductor overcurrent protective devices in Table T3.8.a-1 for Unit 1 (Table T3.8.a-2 for Unit 2) shall be OPERABLE.

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

ACTIONS

NOTES -----------------------------------

1. Separate Condition entry is allowed for each device.

2. TLCO 3.0.d.3 is applicable to overcurrent devices in circuits which have the circuit breakers tripped, inoperable circuit breakers racked out or removed.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore the 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months containment protective device to penetration conductor OPERABLE status.

overcurrent protective devices inoperable. OR (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 1 Revision 37 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Verify the circuit is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months de-energized with the associated circuit AND breaker tripped.

7 days thereafter AND A.2.2 Determine operability Immediately status of the following affected system or initial component. performance of Required Action A.2.1 OR A.3.1 Verify the circuit is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months de-energized with the associated circuit AND breaker racked out or removed. 7 days thereafter AND A.3.2 Determine operability Immediately status of the following affected system or initial component. performance of Required Action A.3.1 B. Required Actions and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Times of Condition A AND not met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months BRAIDWOOD UNITS 1 & 2 3.8.a 2 Revision 1 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.8.a.1 -------------------NOTES-------------------

1. A representative sample shall consist of 10% of the circuit breakers selected, on a rotating basis, from 6.9 kV and 4.16 kV circuit breakers.

2. For each circuit breaker found inoperable during these functional tests, an additional representative sample of 10% of all circuit breakers of the inoperable type shall be functionally tested until no more failures are found or all circuit breakers of the inoperable type have been functionally tested.

Perform CHANNEL CALIBRATION on the 18 months associated protective relays of the sampled circuit breakers.

(continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 3 Revision 1 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.8.a.2 -------------------NOTES-------------------

1. A representative sample shall consist of 10% of the circuit breakers selected, on a rotating basis, from 6.9 kV and 4.16 kV circuit breakers.

2. For each circuit breaker found inoperable during these functional tests, an additional representative sample of 10% of all circuit breakers of the inoperable type shall be functionally tested until no more failures are found or all circuit breakers of the inoperable type have been functionally tested.

Perform an integrated system functional 18 months test on a representative sample of each circuit breaker type, which includes simulated automatic actuation of the system to demonstrate that the overall penetration design remains within operable limits.

(continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 4 Revision 1 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.8.a.3 -------------------NOTES-------------------

1. A representative sample shall consist of 10% of the circuit breakers selected, on a rotating basis, from each type of 480 V circuit breakers.

2. Testing of these circuit breakers shall consist of injecting a current in excess of the breakers nominal setpoint and measuring the response time. The measured response time will be compared to the manufacturers data to ensure that it is a value specified by the manufacturer.

3. Circuit breakers found inoperable during functional tests shall be restored to OPERABLE or replaced with OPERABLE circuit breakers prior to resuming operation.

4. For each circuit breaker found inoperable during these functional tests, an additional representative sample of 10% of all circuit breakers of the inoperable type shall be functionally tested until no more failures are found or all circuit breakers of the inoperable type have been functionally tested.

Functionally test a representative sample 18 months of each 480 V circuit breaker type.

(continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 5 Revision 1 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.8.a.4 -------------------NOTES-------------------

1. A representative sample shall consist of 10% of the fuses selected, on a rotating basis, from each type of fuse.

2. Testing of these fuses shall consist of a nondestructive resistance measurement test which demonstrates that the fuse meets the manufacturer's design criteria.

3. Fuses found inoperable during functional tests shall be replaced with OPERABLE fuses prior to resuming operation.

4. For each fuse found inoperable during these functional tests, an additional representative sample of 10% of all fuses of the inoperable type shall be functionally tested until no more failures are found or all fuses of the inoperable type have been functionally tested.

Functionally test a representative sample 18 months of each fuse type.

TSR 3.8.a.5 -------------------NOTE--------------------

Only applicable to 6.9 kV and 4.16 kV circuit breakers.

Perform an inspection and preventative 60 months maintenance for each breaker in accordance with the manufacturer's recommendation.

BRAIDWOOD UNITS 1 & 2 3.8.a 6 Revision 1 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-1 (page 1 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 1)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

1. 6.9 kV Switchgear 1RC01PA - RCP A Bus 157 Cub 1 Primary Bus 157 Normal (UAT) Feed ACB 1571 Backup Bus 157 Emergency (SAT) Feed ACB 1572 Backup 1RC01PB - RCP B Bus 156 Cub 2 Primary Bus 156 Normal (UAT) Feed ACB 1561 Backup Bus 156 Emergency (SAT) Feed ACB 1562 Backup 1RC01PC - RCP C Bus 158 Cub 5 Primary Bus 158 Normal (SAT) Feed ACB 1582 Backup Bus 158 Emergency (UAT) Feed ACB 1581 Backup 1RC01PD - RCP D Bus 159 Cub 5 Primary Bus 159 Normal (SAT) Feed ACB 1592 Backup Bus 159 Emergency (UAT) Feed ACB 1591 Backup

2. 480 V Pressurizer Heater Switchgear 1RY03EA - Pressurizer Heater Backup Group A, Compt. A1A-A6A, B1A Primary Compt. A1B-A6B, B1B Backup 1RY03EB - Pressurizer Heater Backup Group B, Compt. B1A-B6A, A1A Primary Compt. B1B-B6B, A1B Backup 1RY03EC - Pressurizer Heater Backup Group C, Compt. A1A-A6A Primary Compt. A1B-A6B Backup 1RY03ED - Pressurizer Heater Backup Group D, Compt. B1A-B6A Primary Compt. B1B-B6B Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 7 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-1 (page 2 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 1)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

3. 480 V A.C. Switchgear Circuit Breakers 1VP01CA - RCFC Fan 1A 1A Low Speed Feed Breaker Switchgear 131X Cub 4C Primary 1A Hi Speed Feed Breaker Switchgear 131X Cub 5C Primary Bus 131X Normal Feed 141 Switchgear Cub 19 ACB 1415X Backup 1VP01CC - RCFC Fan 1C 1C Low Speed Feed Breaker Switchgear 131X Cub 2C Primary 1C Hi Speed Feed Breaker Switchgear 131X Cub 3C Primary Bus 131X Normal Feed 141 Switchgear Cub 19 ACB 1415X Backup 1VP01CB - RCFC Fan 1B 1B Low Speed Feed Breaker Switchgear 132X Cub 4C Primary 1B Hi Speed Feed Breaker Switchgear 132X Cub 5C Primary Bus 132X Normal Feed 142 Switchgear Cub 14 ACB 1425X Backup 1VP01CD - RCFC Fan 1D 1D Low Speed Feed Breaker Switchgear 132X Cub 2C Primary 1D Hi Speed Feed Breaker Switchgear 132X Cub 3C Primary Bus 132X Normal Feed 142 Switchgear Cub 14 ACB 1425X Backup 1EW39E - Containment Stinger Bus Rectifier Containment Stinger Bus 134Y Cub 2C Primary Fuses in Bus 134Y Cub 2C Backup 1AP200EA/ED Containment Outage Pwr Distr Panels - Unit 1 Circuit Breaker in Bus 233X Cub 2C Primary Fuses in Bus 233X Cub 2C Backup 1AP200EB/EC Containment Outage Pwr Distr Panels - Unit 1 Circuit Breakers in Bus 234X Cub 5D Primary Fuses in Bus 234X Cub 5D Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 8 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-1 (page 3 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 1)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

4. 480 V Molded Case Circuit Breakers (MCCB) MCC 133X4 1RC01PA-A - Cub B1 Front Primary Cub B1 Rear Backup 1RC01PA-B - Cub B2 Front Primary Cub B2 Rear Backup 1HC22G - Cub B3 Front Primary Cub B3 Rear Backup 1FH03G - Cub B4 Front Primary Cub B4 Rear Backup 1VP05CA - Cub C1 Front Primary Cub C1 Rear Backup 1RF03P - Cub C2 Front Primary Cub C2 Rear Backup 1RC01PD-A - Cub D1 Front Primary Cub D1 Rear Backup 1RC01PD-B - Cub D2 Front Primary Cub D2 Rear Backup 1RF02PB - Cub D4 Front Primary Cub D4 Rear Backup 1RF01P - Cub D5 Front Primary Cub D5 Rear Backup 1RE01PA - Cub D6 Front Primary Cub D6 Rear Backup 1VP02CA - Cub E1 Front Primary Cub E1 Rear Backup 1VP04CA - Cub E2 Front Primary Cub E2 Rear Backup 1VP04CC - Cub F1 Front Primary Cub F1 Rear Backup 1EW11EA,B,C - Cub F3 Front Primary Cub F3 Rear Backup 1IC02EA - Cub F5 Front Primary Cub F5 Rear Backup 1IC02EB - Cub G1 Front Primary Cub G1 Rear Backup 1IC02EC - Cub G2 Front Primary Cub G2 Rear Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 9 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-1 (page 4 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 1)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

5. 480 V Molded Case Circuit Breakers (MCCB) MCC 134X5 1IC02EF - Cub A1 Front Primary Cub A1 Rear Backup 1IC02EE - Cub A2 Front Primary Cub A2 Rear Backup 1IC02ED - Cub A3 Front Primary Cub A3 Rear Backup 1FH02J - Cub G1 Front Primary Cub G1 Rear Backup 1FH03J - Cub G2 Front Primary Cub G2 Rear Backup 1RC01PB-B - Cub B1 Front Primary Cub B1 Rear Backup 1RE01PB - Cub B3 Front Primary Cub B3 Rear Backup 1RC01PC-A - Cub C1 Front Primary Cub C1 Rear Backup 1RC01PC-B - Cub C2 Front Primary Cub C2 Rear Backup 1VP05CB - Cub J1 Front Primary Cub J1 Rear Backup 1RC01PB-A - Cub C3 Front Primary Cub C3 Rear Backup 1HC65G-A - Cub D3 Front Primary Cub D3 Rear Backup 1VP02CB - Cub F1 Front Primary Cub F1 Rear Backup 1RC01R-A - Cub F2-A Primary Cub F2-B Backup 1RF02PA - Cub G3 Front Primary Cub G3 Rear Backup 1EW12EA,B,C - Cub F3-A Primary Cub F3-B Backup 1VP04CB - Cub F4 Front Primary Cub F4 Rear Backup 1VP04CD - Cub F5 Front Primary Cub F5 Rear Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 10 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-1 (page 5 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 1)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

6. 480 V Molded Case Circuit Breakers (MCCB) MCC 132X2A 1SI8808C - Cub A2 Primary MCC 132X2 Cub B2 Backup 1SI8808B - Cub A3 Primary MCC 132X2 Cub B2 Backup

7. 480 V Molded Case Circuit Breakers (MCCB) MCC 132X2 1RH8702B - Cub B1 Front Primary Cub B1 Rear Backup 1RH8701B - Cub B3 Front Primary Cub B3 Rear Backup 1CV8112 - Cub B4 Front Primary Cub B4 Rear Backup 1OG079 - Cub C1 Front Primary Cub C1 Rear Backup 1WO056A - Cub C2 Front Primary Cub C2 Rear Backup 1OG080- Cub C3 Front Primary Cub C3 Rear Backup 1RY8000B - Cub C4 Front Primary Cub C4 Rear Backup 1RC8003C - Cub D5 Front Primary Cub D5 Rear Backup 1RC8003B - Cub D4 Front Primary Cub D4 Rear Backup 1RC8002A - Cub G1 Front Primary Cub G1 Rear Backup 1RC8002B - Cub G2 Front Primary Cub G2 Rear Backup 1RC8002C - Cub G3 Front Primary Cub G3 Rear Backup 1RC8002D - Cub G4 Front Primary Cub G4 Rear Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 11 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-1 (page 6 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 1)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

8. 480 V Molded Case Circuit Breakers (MCCB) MCC 131X2A 1SI8808D - Cub A2 Primary MCC 131X2 Cub B2 Backup 1SI8808A - Cub A3 Primary MCC 131X2 Cub B2 Backup

9. 480 V Molded Case Circuit Breakers (MCCB) MCC 131X2 1RC8001A - Cub G1 Front Primary Cub G1 Rear Backup 1RC8001B - Cub G2 Front Primary Cub G2 Rear Backup 1RC8001C - Cub G3 Front Primary Cub G3 Rear Backup 1RC8001D - Cub G4 Front Primary Cub G4 Rear Backup 1RH8701A - Cub B1 Front Primary Cub B1 Rear Backup 1RH8702A - Cub B4 Front Primary Cub B4 Rear Backup 1LL42J - Cub C1 Front Primary Cub C1 Rear Backup 1VQ001A - Cub C3 Front Primary Cub C3 Rear Backup 1VQ002A - Cub F1 Front Primary Cub F1 Rear Backup 1RC8003D - Cub C4 Front Primary Cub C4 Rear Backup 1RC8003A - Cub C5 Front Primary Cub C5 Rear Backup 1OG057A - Cub D1 Front Primary Cub D1 Rear Backup 1CC9416 - Cub D3 Front Primary Cub D3 Rear Backup 1CC9438 - Cub D4 Front Primary Cub D4 Rear Backup 1OG081 - Cub E2 Front Primary Cub E2 Rear Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 12 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-1 (page 7 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 1)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

10. 480 V Molded Case Circuit Breakers (MCCB) MCC 133X6 1HC01G - Cub B2 Primary Cub B1 Backup 1LL04E - Cub C2 Primary Cub C1 Backup 1VP03CA - Cub A3 Front Primary Cub A3 Rear Backup 1VP03CD - Cub C4 Front Primary Cub C4 Rear Backup

11. 480 V Molded Case Circuit Breakers (MCCB) MCC 134X7 1LL05E - Cub B2 Primary Cub B1 Backup 1VP03CB - Cub A3 Front Primary Cub A3 Rear Backup 1VP03CC - Cub B4 Front Primary Cub B4 Rear Backup

12. 480 V Molded Case Circuit Breakers (MCCB) MCC 131X2B 1WO056B - Cub A4 Front Primary Cub A4 Rear Backup 1RY8000A - Cub A5 Front Primary Cub A5 Rear Backup

13. 260 VAC RCD Power (53 rods, 5 panels)

Stationary Gripper Coils fuse (all panels) Primary Stationary Gripper Coils fuse (all panels) Backup Lift Coils fuse (all panels) Primary Lift Coils fuse (all panels) Backup Movable Gripper Coils fuse (all panels) Primary Movable Gripper Coils fuse (all panels) Backup BRAIDWOOD UNITS 1 & 2 3.8.a 13 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-2 (page 1 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 2)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

1. 6.9 kV Switchgear 2RC01PA - RCP A Bus 257 Cub 7 Primary Bus 257 Normal (UAT) Feed ACB 2571 Backup Bus 257 Emergency (SAT) Feed ACB 2572 Backup 2RC01PB - RCP B Bus 256 Cub 5 Primary Bus 256 Normal (UAT) Feed ACB 2561 Backup Bus 256 Emergency (SAT) Feed ACB 2562 Backup 2RC01PC - RCP C Bus 258 Cub 3 Primary Bus 258 Normal (SAT) Feed ACB 2582 Backup Bus 258 Emergency (UAT) Feed ACB 2581 Backup 2RC01PD - RCP D Bus 259 Cub 3 Primary Bus 259 Normal (SAT) Feed ACB 2592 Backup Bus 259 Emergency (UAT) Feed ACB 2591 Backup

2. 480 V Pressurizer Heater Switchgear 2RY03EA - Pressurizer Heater Backup Group A, Compt. B1A-B6A, A1A Primary Compt. B1B-B6B, A1B Backup 2RY03EB - Pressurizer Heater Backup Group B, Compt. A1A-A6A, B1A Primary Compt. A1B-A6B, B1B Backup 2RY03EC - Pressurizer Heater Backup Group C, Compt. B1A-B6A Primary Compt. B1B-B6B Backup 2RY03ED - Pressurizer Heater Backup Group D, Compt. A1A-A6A Primary Compt. A1B-A6B Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 14 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-2 (page 2 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 2)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

3. 480 V A.C. Switchgear Circuit Breakers 2VP01CA - RCFC Fan 2A 2A Low Speed Feed Breaker Switchgear 231X Cub 4C Primary 2A Hi Speed Feed Breaker Switchgear 231X Cub 5C Primary Bus 231X Normal Feed 241 Switchgear Cub 4 ACB 2415X Backup 2VP01CC - RCFC Fan 2C 2C Low Speed Feed Breaker Switchgear 231X Cub 2C Primary 2C Hi Speed Feed Breaker Switchgear 231X Cub 3C Primary Bus 231X Normal Feed 241 Switchgear Cub 4 ACB 2415X Backup 2VP01CB - RCFC Fan 2B 2B Low Speed Feed Breaker Switchgear 232X Cub 4C Primary 2B Hi Speed Feed Breaker Switchgear 232X Cub 5C Primary Bus 232X Normal Feed 242 Switchgear Cub 8 ACB 2425X Backup 2VP01CD - RCFC Fan 2D 2D Low Speed Feed Breaker Switchgear 232X Cub 2C Primary 2D Hi Speed Feed Breaker Switchgear 232X Cub 3C Primary Bus 232X Normal Feed 242 Switchgear Cub 8 ACB 2425X Backup 2EW39E - Containment Stinger Bus Rectifier Containment Stinger Bus 234Y Cub 2C Primary Fuses in Bus 234Y Cub 2C Backup 2AP200EA/ED Containment Outage Pwr Distr Panels - Unit 2 Circuit Breaker in Bus 133X Cub 2C Primary Fuses in Bus 133X Cub 2C Backup 2AP200EB/EC Containment Outage Pwr Distr Panels - Unit 2 Circuit Breaker in Bus 134X Cub 5D Primary Fuses in Bus 134X Cub 5D Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 15 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-2 (page 3 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 2)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

4. 480 V Molded Case Circuit Breakers (MCCB) MCC 233X4 2RC01PA-A - Cub B1 Front Primary Cub B1 Rear Backup 2RC01PA-B - Cub B2 Front Primary Cub B2 Rear Backup 2HC22G - Cub B3 Front Primary Cub B3 Rear Backup 2FH03G - Cub B4 Front Primary Cub B4 Rear Backup 2VP05CA - Cub C1 Front Primary Cub C1 Rear Backup 2RF03P - Cub C2 Front Primary Cub C2 Rear Backup 2RC01PD-A - Cub D1 Front Primary Cub D1 Rear Backup 2RC01PD-B - Cub D2 Front Primary Cub D2 Rear Backup 2RF02PB - Cub D4 Front Primary Cub D4 Rear Backup 2RF01P - Cub D5 Front Primary Cub D5 Rear Backup 2RE01PA - Cub D6 Front Primary Cub D6 Rear Backup 2VP02CA - Cub E1 Front Primary Cub E1 Rear Backup 2VP04CA - Cub E2 Front Primary Cub E2 Rear Backup 2VP04CC - Cub F1 Front Primary Cub F1 Rear Backup 2EW11EA,B,C - Cub F3 Front Primary Cub F3 Rear Backup 2IC02EA - Cub F5 Front Primary Cub F5 Rear Backup 2IC02EB - Cub G1 Front Primary Cub G1 Rear Backup 2IC02EC - Cub G2 Front Primary Cub G2 Rear Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 16 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-2 (page 4 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 2)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

5. 480 V Molded Case Circuit Breakers (MCCB) MCC 234X5 2IC02EF - Cub A1 Front Primary Cub A1 Rear Backup 2IC02EE - Cub A2 Front Primary Cub A2 Rear Backup 2IC02ED - Cub A3 Front Primary Cub A3 Rear Backup 2FH02J - Cub G1 Front Primary Cub G1 Rear Backup 2FH03J - Cub G2 Front Primary Cub G2 Rear Backup 2RC01PB-B - Cub B1 Front Primary Cub B1 Rear Backup 2RE01PB - Cub B3 Front Primary Cub B3 Rear Backup 2RC01PC-A - Cub C1 Front Primary Cub C1 Rear Backup 2RC01PC-B - Cub C2 Front Primary Cub C2 Rear Backup 2VP05CB - Cub J1 Front Primary Cub J1 Rear Backup 2RC01PB-A - Cub C3 Front Primary Cub C3 Rear Backup 2HC65G-A - Cub D3 Front Primary Cub D3 Rear Backup 2VP02CB - Cub F1 Front Primary Cub F1 Rear Backup 2RC01R-A - Cub F2-A Primary Cub F2-B Backup 2RF02PA - Cub G3 Front Primary Cub G3 Rear Backup 2EW12EA,B,C - Cub F3-A Primary Cub F3-B Backup 2VP04CB - Cub F4 Front Primary Cub F4 Rear Backup 2VP04CD - Cub F5 Front Primary Cub F5 Rear Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 17 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-2 (page 5 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 2)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

6. 480 V Molded Case Circuit Breakers (MCCB) MCC 232X2A 2SI8808C - Cub A2 Primary MCC 232X2 Cub B2 Backup 2SI8808B - Cub A3 Primary MCC 232X2 Cub B2 Backup

7. 480 V Molded Case Circuit Breakers (MCCB) MCC 232X2 2RH8702B - Cub B1 Front Primary Cub B1 Rear Backup 2RH8701B - Cub B3 Front Primary Cub B3 Rear Backup 2CV8112 - Cub B4 Front Primary Cub B4 Rear Backup 2OG079 - Cub C1 Front Primary Cub C1 Rear Backup 2WO056A - Cub C2 Front Primary Cub C2 Rear Backup 2OG080 - Cub C3 Front Primary Cub C3 Rear Backup 2RY8000B - Cub C4 Front Primary Cub C4 Rear Backup 2RC8003C - Cub D5 Front Primary Cub D5 Rear Backup 2RC8003B - Cub D4 Front Primary Cub D4 Rear Backup 2RC8002A - Cub G1 Front Primary Cub G1 Rear Backup 2RC8002B - Cub G2 Front Primary Cub G2 Rear Backup 2RC8002C - Cub G3 Front Primary Cub G3 Rear Backup 2RC8002D - Cub G4 Front Primary Cub G4 Rear Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 18 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-2 (page 6 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 2)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

8. 480 V Molded Case Circuit Breakers (MCCB) MCC 231X2A 2SI8808D - Cub A2 Primary MCC 231X2 Cub B2 Backup 2SI8808A - Cub A3 Primary MCC 231X2 Cub B2 Backup

9. 480 V Molded Case Circuit Breakers (MCCB) MCC 231X2 2RC8001A - Cub G1 Front Primary Cub G1 Rear Backup 2RC8001B - Cub G2 Front Primary Cub G2 Rear Backup 2RC8001C - Cub G3 Front Primary Cub G3 Rear Backup 2RC8001D - Cub G4 Front Primary Cub G4 Rear Backup 2RH8701A - Cub B1 Front Primary Cub B1 Rear Backup 2RH8702A - Cub B4 Front Primary Cub B4 Rear Backup 2LL42J - Cub C1 Front Primary Cub C1 Rear Backup 2VQ001A - Cub C3 Front Primary Cub C3 Rear Backup 2VQ002A - Cub F1 Front Primary Cub F1 Rear Backup 2RC8003D - Cub C4 Front Primary Cub C4 Rear Backup 2RC8003A - Cub C5 Front Primary Cub C5 Rear Backup 2OG057A - Cub D1 Front Primary Cub D1 Rear Backup 2CC9416 - Cub D3 Front Primary Cub D3 Rear Backup 2CC9438 - Cub D4 Front Primary Cub D4 Rear Backup 2OG081 - Cub E2 Front Primary Cub E2 Rear Backup (continued)

BRAIDWOOD UNITS 1 & 2 3.8.a 19 Revision 46 Technical Requirements Manual

TRM Containment Penetration Conductor Overcurrent Protective Devices 3.8.a Table T3.8.a-2 (page 7 of 7)

Containment Penetration Conductor Overcurrent Protective Devices (Unit 2)

PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE

10. 480 V Molded Case Circuit Breakers (MCCB) MCC 233X6 2HC01G - Cub B2 Primary Cub B1 Backup 2LL04E - Cub C2 Primary Cub C1 Backup 2VP03CA - Cub A3 Front Primary Cub A3 Rear Backup 2VP03CD - Cub C4 Front Primary Cub C4 Rear Backup

11. 480 V Molded Case Circuit Breakers (MCCB) MCC 234X7 2LL05E - Cub B2 Primary Cub B1 Backup 2VP03CB - Cub A3 Front Primary Cub A3 Rear Backup 2VP03CC - Cub B4 Front Primary Cub B4 Rear Backup

12. 480 V Molded Case Circuit Breakers (MCCB) MCC 231X2B 2WO056B - Cub A4 Front Primary Cub A4 Rear Backup 2RY8000A - Cub A5 Front Primary Cub A5 Rear Backup

13. 260 VAC RCD Power (53 rods, 5 panels)

Primary Stationary Gripper Coils fuse (all panels) Backup Stationary Gripper Coils fuse (all panels)

Primary Lift Coils fuse (all panels) Backup Lift Coils fuse (all panels)

Primary Movable Gripper Coils fuse (all panels) Backup Movable Gripper Coils fuse (all panels)

BRAIDWOOD UNITS 1 & 2 3.8.a 20 Revision 46 Technical Requirements Manual

TRM Motor Operated Valves Thermal Overload Protection Devices 3.8.b 3.8 ELECTRICAL POWER SYSTEMS 3.8.b Motor Operated Valves Thermal Overload Protection Devices TLCO 3.8.b The thermal overload protection devices integral with the motor starter of each valve listed in Table T3.8.b-1 for Unit 1 (Table T3.8.b-2 for Unit 2) shall be OPERABLE.

APPLICABILITY: Whenever the motor operated valve is required to be OPERABLE.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each thermal overload protection device.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more thermal A.1 Declare the affected Immediately overload protection valve inoperable.

devices inoperable.

AND A.2 Enter the applicable Immediately Conditions and Required Actions for the affected valve.

BRAIDWOOD UNITS 1 & 2 3.8.b 1 Revision 1 Technical Requirements Manual

TRM Motor Operated Valves Thermal Overload Protection Devices 3.8.b SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

TSR 3.8.b.1 applies to each thermal overload protection device in Table T3.8.b-1 (Table T3.8.b-2).

SURVEILLANCE FREQUENCY TSR 3.8.b.1 -------------------NOTE-------------------

Each thermal overload is calibrated and each valve is cycled through at least one complete cycle of full travel with the motor operator when the thermal overload is OPERABLE.

Perform CHANNEL CALIBRATION. 6 years BRAIDWOOD UNITS 1 & 2 3.8.b 2 Revision 97 Technical Requirements Manual

TRM Motor Operated Valves Thermal Overload Protection Devices 3.8.b Table T3.8.b-1 (page 1 of 3)

Thermal Overload Protection Devices - Unit 1 VALVE NUMBER FUNCTION 1OG057A OA H2 Recombiner Discharge Isolation Valve 1OG079 H2 Recombiner Discharge Containment Isolation Valve 1OG080 H2 Recombiner Suction Containment Isolation Valve 1OG081 H2 Recombiner Suction Containment Isolation Valve 1OG082 OA H2 Recombiner Discharge Containment Isolation Valve 1OG083 OA H2 Recombiner Discharge Containment Isolation Valve 1OG084 OA H2 Recombiner Containment Outlet Isolation Valve 1OG085 H2 Recombiner Containment Outlet Isolation Valve 1AF006A 1A AF Pump SX Suction Isolation Valve 1AF006B 1B AF Pump SX Suction Downstream Isolation Valve 1AF013A AF Motor Driven Pump Discharge Header Downstream Isolation Valve 1AF013B AF Motor Driven Pump Discharge Header Downstream Isolation Valve 1AF013C AF Motor Driven Pump Discharge Header Downstream Isolation Valve 1AF013D AF Motor Driven Pump Discharge Header Downstream Isolation Valve 1AF013E AF Diesel Driven Pump Discharge Header Downstream Isolation Valve 1AF013F AF Diesel Driven Pump Discharge Header Downstream Isolation Valve 1AF013G AF Diesel Driven Pump Discharge Header Downstream Isolation Valve 1AF013H AF Diesel Driven Pump Discharge Header Downstream Isolation Valve 1AF017A 1A AF Pump SX Suction Upstream Isolation Valve 1AF017B 1B AF Pump SX Suction Upstream Isolation Valve 1CC201A 1A SX to CC Makeup Isolation Valve 1CC201B 1B SX to CC Makeup Isolation Valve 1CC202A 1A SX to CC Makeup Isolation Valve 1CC202B 1B SX to CC Makeup Isolation Valve 1CC685 RCP Thermal Barrier Outlet Header Containment Isolation Valve 1CC9412A CC to RHR HX 1A Isolation Valve 1CC9412B CC to RHR HX 1B Isolation Valve 1CC9413A RCPs CC Supply Downstream Containment Isolation Valve 1CC9413B RCPs CC Supply Upstream Containment Isolation Valve 1CC9414 CC Water from RCPs Isolation Valve 1CC9415 Service Loop Isolation Valve 1CC9416 CC Water from RCPs Isolation Valve 1CC9438 CC Water from RCPs Thermal Barrier Isolation Valve 1CC9473A Discharge Header X-tie Isolation Valve 1CC9473B Discharge Header X-tie Isolation Valve 1CS001A 1A CS Pump Suction from RWST 1CS001B 1B CS Pump Suction from RWST 1CS007A 1A CS Pump Discharge Line Downstream Isolation Valve 1CS007B 1B CS Pump Discharge Line Downstream Isolation Valve 1CS009A 1A CS Pump Suction from 1A Recirc Sump 1CS009B 1B CS Pump Suction from 1B Recirc Sump 1CS019A CS Eductor 1A Suction Conn Isolation Valve 1CS019B CS Eductor 1B Suction Conn Isolation Valve (continued)

BRAIDWOOD UNITS 1 & 2 3.8.b 3 Revision 88 Technical Requirements Manual

TRM Motor Operated Valves Thermal Overload Protection Devices 3.8.b Table T3.8.b-1 (page 2 of 3)

Thermal Overload Protection Devices - Unit 1 VALVE NUMBER FUNCTION 1CV112B MOV VCT Outlet Upstream Isolation VCT Valve 1CV112C MOV VCT Outlet Downstream Isolation VCT Valve 1CV112D MOV RWST to Charging Pump Suction Header 1CV112E MOV RWST to Charging Pump Suction Header 1CV8100 MOV RCP Seal Leakoff Header Isolation 1CV8104 MOV Emergency Boration Valve 1CV8105 MOV Charging Pumps Discharge Header Isolation Valve 1CV8106 MOV Charging Pumps Discharge Header Isolation Valve 1CV8110 MOV A & B Charging Pump Recirc Downstream Isolation 1CV8111 MOV A & B Charging Pump Recirc Upstream Isolation 1CV8112 RCP Seal Water Return Isolation Valve 1CV8355A MOV RCP 1A Seal Injection Inlet to Containment Isolation 1CV8355B MOV RCP 1B Seal Injection Inlet Isolation 1CV8355C MOV RCP 1C Seal Injection Isolation 1CV8355D MOV RCP 1D Seal Injection Isolation 1CV8804A MOV RHR System X-Tie Valve to Charging Pump Suction Header A/B 1RH610 1A RHR Pump Recirc Line Isolation Valve 1RH611 1B RHR Pump Recirc Line Isolation Valve 1RH8701A RC Loop 1A to RHR Pump Isolation Valve 1RH8702A RC Loop 1C to RHR Pump Isolation Valve 1RH8701B RC Loop 1A to RHR Pump Isolation Valve 1RH8702B RC Loop 1C to RHR Pump Isolation Valve 1RH8716A RHR HX 1RH02AA Downstream Isolation Valve 1RH8716B RHR HX 1RH02AB Downstream Isolation Valve 1RY8000A Pressurizer Relief Isolation Valve 1A 1RY8000B Pressurizer Relief Isolation Valve 1B 1SI8801A SI Charging Pump Discharge Isolation Valve 1SI8801B SI Charging Pump Discharge Isolation Valve 1SI8802A 1A SI Pump Discharge Line Downstream Containment Isolation Valve 1SI8802B 1B SI Pump Discharge Line Downstream Isolation Valve 1SI8804B 1B SI Pump Suction X-tie from RHR HX 1SI8806 SI Pumps Upstream Suction Isolation Valve 1SI8807A SI to Charging Pump Suction X-tie Isolation Valve 1SI8807B SI to Charging Pump Suction X-tie Isolation Valve 1SI8808A Accumulator 1A Discharge Isolation Valve 1SI8808B Accumulator 1B Discharge Isolation Valve 1SI8808C Accumulator 1C Discharge Isolation Valve 1SI8808D Accumulator 1D Discharge Isolation Valve 1SI8809A SI RHR HX 1A Discharge Line Downstream Isolation Valve 1SI8809B SI RHR HX 1B Discharge Line Downstream Isolation Valve 1SI8811A SI Containment Sump A Outlet Isolation Valve 1SI8811B SI Containment Sump B Outlet Isolation Valve 1SI8812A SI RWST to RH Pump 1A Outlet Isolation Valve 1SI8812B SI RWST to RH Pump 1B Outlet Isolation Valve 1SI8813 SI Pumps 1A-1B Recirc Line Downstream Isolation Valve 1SI8814 SI Pump 1A Recirc Line Isolation Valve 1SI8835 SI Pumps X-tie Discharge Isolation Valve 1SI8840 SI RHR HX Discharge Line Upstream Containment Penetration Isolation Valve 1SI8821A 1A SI Pump Discharge Line X-tie Isolation Valve 1SI8821B 1B SI Pump Discharge Line X-tie Isolation Valve 1SI8920 1B SI Pump Recirc Line Isolation Valve 1SI8923A 1A SI Pump Suction Isolation Valve 1SI8923B 1B SI Pump Suction Isolation Valve 1SI8924 1A SI Pump Suction X-tie Downstream Isolation Valve (continued)

BRAIDWOOD UNITS 1 & 2 3.8.b 4 Revision 1 Technical Requirements Manual

TRM Motor Operated Valves Thermal Overload Protection Devices 3.8.b Table T3.8.b-1 (page 3 of 3)

Thermal Overload Protection Devices - Unit 1 VALVE NUMBER FUNCTION 1SX016B RCFC B&D SX Supply MOV 1SX016A RCFC A&C SX Supply MOV 1SX027A RCFC A&C SX Return MOV 1SX027B RCFC B&D SX Return MOV 0SX007 CC HX Outlet Valve 0SX063A SX to Control Room Refrig Condenser OA 0SX063B SX to Control Room Refrig Condenser OB 0SX146 CC HX "O" Outlet Valve 0SX147 CC HX "O" Outlet Valve 1SX001A 1A SX Pump Suction Valve MOV 1SX001B 1B SX Pump Suction Valve MOV 1SX004 Unit 1 SX Supply to Unit 1 CCW HX MOV 1SX005 1B SX Pump Supply to CCW HX "O" MOV 1SX007 CC HX Outlet Valve 1SX010 Unit 1 Train A Return Valve AB 1SX011 Train A Train B Unit 1 Return X-tie Valve AB 1SX033 1A SX Pump Discharge X-tie MOV 1SX034 1B SX Pump Discharge X-tie MOV 1SX136 Unit 1 Train B Return Valve AB 1SX150A SX Strainer 1A Backwash to Waste Treatment Building MOV 1SX150B SX Strainer 1B Backwash to Waste Treatment Building MOV 1W0006A Chilled Water Coils 1A & 1C Supply Isolation Valve 1W0006B Chilled Water Coils 1B & 1D Supply Isolation Valve 1W0020A Chilled Water Coils 1A & 1C Return Isolation Valve 1W0020B Chilled Water Coils 1B & 1D Return Isolation Valve 1W0056A Chilled Water Containment Isolation Valve 1W0056B Chilled Water Containment Isolation Valve BRAIDWOOD UNITS 1 & 2 3.8.b 5 Revision 76 Technical Requirements Manual

TRM Motor Operated Valves Thermal Overload Protection Devices 3.8.b Table T3.8.b-2 (page 1 of 3)

Thermal Overload Protection Devices - Unit 2 VALVE NUMBER FUNCTION 2OG057A OB H2 Recombiner Discharge Isolation Valve 2OG079 H2 Recombiner Discharge Containment Isolation Valve 2OG080 H2 Recombiner Suction Containment Isolation Valve 2OG081 H2 Recombiner Suction Containment Isolation Valve 2OG082 OB H2 Recombiner Discharge Containment Isolation Valve 2OG083 OB H2 Recombiner Discharge Containment Isolation Valve 2OG084 OB H2 Recombiner Containment Outlet Isolation Valve 2OG085 H2 Recombiner Containment Outlet Isolation Valve 2AF006A 2A AF Pump SX Suction Isolation Valve 2AF006B 2B AF Pump SX Suction Downstream Isolation Valve 2AF013A AF Motor Driven Pump Discharge Header Downstream Isolation Valve 2AF013B AF Motor Driven Pump Discharge Header Downstream Isolation Valve 2AF013C AF Motor Driven Pump Discharge Header Downstream Isolation Valve 2AF013D AF Motor Driven Pump Discharge Header Downstream Isolation Valve 2AF013E AF Diesel Driven Pump Discharge Header Downstream Isolation Valve 2AF013F AF Diesel Driven Pump Discharge Header Downstream Isolation Valve 2AF013G AF Diesel Driven Pump Discharge Header Downstream Isolation Valve 2AF013H AF Diesel Driven Pump Discharge Header Downstream Isolation Valve 2AF017A 2A AF Pump SX Suction Upstream Isolation Valve 2AF017B 2B AF Pump SX Suction Upstream Isolation Valve 2CC201A 2A SX to CC Makeup Isolation Valve 2CC201B 2B SX to CC Makeup Isolation Valve 2CC202A 2A SX to CC Makeup Isolation Valve 2CC202B 2B SX to CC Makeup Isolation Valve 2CC685 RCP Thermal Barrier Outlet Header Containment Isolation Valve 2CC9412A CC to RHR HX 2A Isolation Valve 2CC9412B CC to RHR HX 2B Isolation Valve 2CC9413A RCP CC Supply Downstream Containment Isolation 2CC9413B RCPs CC Supply Upstream Containment Isolation 2CC9414 CC Water from RCPs Isolation Valve 2CC9415 Service Loop Isolation Valve 2CC9416 CC Water from RCPs Isolation Valve 2CC9438 CC Water from RCPs Thermal Barrier Isolation Valve 2CC9473A Discharge Header X-tie Isolation Valve 2CC9473B Discharge Header X-tie Isolation Valve 2CS001A 2A CS Pump Suction from RWST 2CS001B 2B CS Pump Suction from RWST 2CS007A 2A CS Pump Discharge Line Downstream Isolation Valve 2CS007B 2B CS Pump Discharge Line Downstream Isolation Valve 2CS009A 2A CS Pump Suction from 2A Recirc Sump 2CS009B 2B CS Pump Suction from 2B Recirc Sump 2CS019A CS Eductor 2A Suction Conn Isolation Valve 2CS019B CS Eductor 2B Suction Conn Isolation Valve (continued)

BRAIDWOOD UNITS 1 & 2 3.8.b 6 Revision 88 Technical Requirements Manual

TRM Motor Operated Valves Thermal Overload Protection Devices 3.8.b Table T3.8.b-2 (page 2 of 3)

Thermal Overload Protection Devices - Unit 2 VALVE NUMBER FUNCTION 2CV112B MOV VCT Outlet Upstream Isolation VCT Valve 2CV112C MOV VCT Outlet Downstream Isolation VCT Valve 2CV112D MOV RWST to Charging Pump Suction Header 2CV112E MOV RWST to Charging Pump Suction Header 2CV8100 MOV RCP Seal Leakoff Header Isolation 2CV8104 MOV Emergency Boration Valve 2CV8105 MOV Charging Pumps Discharge Header Isolation Valve 2CV8106 MOV Charging Pumps Discharge Header Isolation Valve 2CV8110 MOV A & B Charging Pump Recirc Downstream Isolation 2CV8111 MOV A & B Charging Pump Recirc Upstream Isolation 2CV8112 RCP Seal Water Return Isolation Valve 2CV8355A MOV RCP 2A Seal Injection Inlet to Containment Isolation 2CV8355B MOV RCP 2B Seal Injection Inlet Isolation 2CV8355C MOV RCP 2C Seal Injection Isolation 2CV8355D MOV RCP 2D Seal Injection Isolation 2CV8804A MOV RHR System X-Tie Valve to Charging Pump Suction Header A/B 2RH610 2A RHR Pump Recirc Line Isolation Valve 2RH611 2B RHR Pump Recirc Line Isolation Valve 2RH8701A RC Loop 2A to RHR Pump Isolation Valve 2RH8702A RC Loop 2C to RHR Pump Isolation Valve 2RH8701B RC Loop 2A to RHR Pump Isolation Valve 2RH8702B RC Loop 2C to RHR Pump Isolation Valve 2RH8716A RHR HX 2RH02AA Downstream Isolation Valve 2RH8716B RHR HX 2RH02AB Downstream Isolation Valve 2RY8000A Pressurizer Relief Isolation Valve 2A 2RY8000B Pressurizer Relief Isolation Valve 2B 2SI8801A SI Charging Pump Discharge Isolation Valve 2SI8801B SI Charging Pump Discharge Isolation Valve 2SI8802A 2A SI Pump Discharge Line Downstream Containment Isolation Valve 2SI8802B 2B SI Pump Discharge Line Downstream Isolation Valve 2SI8804B 2B SI Pump Suction X-tie from RHR HX 2SI8806 SI Pumps Upstream Suction Isolation Valve 2SI8807A SI to Charging Pump Suction X-tie Isolation Valve 2SI8807B SI to Charging Pump Suction X-tie Isolation Valve 2SI8808A Accumulator 2A Discharge Isolation Valve 2SI8808B Accumulator 2B Discharge Isolation Valve 2SI8808C Accumulator 2C Discharge Isolation Valve 2SI8808D Accumulator 2D Discharge Isolation Valve 2SI8809A SI RHR HX 2A Discharge Line Downstream Isolation Valve 2SI8809B SI RHR HX 2B Discharge Line Downstream Isolation Valve 2SI8811A SI Containment Sump A Outlet Isolation Valve 2SI8811B SI Containment Sump B Outlet Isolation Valve 2SI8812A SI RWST to RHR Pump 2A Outlet Isolation Valve 2SI8812B SI RWST to RHR Pump 2B Outlet Isolation Valve 2SI8813 SI Pumps 2A-2B Recirc Line Downstream Isolation Valve 2SI8814 SI Pump 2A Recirc Line Isolation Valve 2SI8835 SI Pumps X-tie Discharge Isolation Valve 2SI8840 SI RHR HX Discharge Line Upstream Containment Penetration Isolation Valve 2SI8821A 2A SI Pump Discharge Line X-tie Isolation Valve 2SI8821B 2B SI Pump Discharge Line X-tie Isolation Valve 2SI8920 2B SI Pump Recirc Line Isolation Valve 2SI8923A 2A SI Pump Suction Isolation Valve 2SI8923B 2B SI Pump Suction Isolation Valve 2SI8924 2A SI Pump Suction X-tie Downstream Isolation Valve (continued)

BRAIDWOOD UNITS 1 & 2 3.8.b 7 Revision 1 Technical Requirements Manual

TRM Motor Operated Valves Thermal Overload Protection Devices 3.8.b Table T3.8.b-2 (page 3 of 3)

Thermal Overload Protection Devices - Unit 2 VALVE NUMBER FUNCTION 2SX016B RCFC B&D SX Supply MOV 2SX016A RCFC A&C SX Supply MOV 2SX027A RCFC A&C SX Return MOV 2SX027B RCFC B&D SX Return MOV 0SX007 CC HX Outlet Valve 0SX063A SX to Control Room Refrig Condenser 0A 0SX063B SX to Control Room Refrig Condenser 0B 0SX146 CC HX "0" Outlet Valve 0SX147 CC HX "0" Outlet Valve 2SX001A 2A SX Pump Suction Valve MOV 2SX001B 2B SX Pump Suction Valve MOV 2SX004 Unit 2 SX Supply to Unit 2 CCW HX MOV 2SX005 2B SX Pump Supply to CCW HX "O" MOV 2SX007 CC HX Outlet Valve 2SX010 Unit 2 Train A Return Valve AB 2SX011 Train A Train B Unit 2 Return X-tie Valve AB 2SX033 2A SX Pump Discharge X-tie MOV 2SX034 2B SX Pump Discharge X-tie MOV 2SX136 Unit 2 Train B Return Valve AB 2SX150A SX Strainer 2A Backwash to Waste Treatment Building MOV 2SX150B SX Strainer 2B Backwash to Waste Treatment Building MOV 2W0006A Chilled Water Coils 2A & 2C Supply Isolation Valve 2W0006B Chilled Water Coils 2B & 2D Supply Isolation Valve 2W0020A Chilled Water Coils 2A & 2C Return Isolation Valve 2W0020B Chilled Water Coils 2B & 2D Return Isolation Valve 2W0056A Chilled Water Containment Isolation Valve 2W0056B Chilled Water Containment Isolation Valve BRAIDWOOD UNITS 1 & 2 3.8.b 8 Revision 85 Technical Requirements Manual

TRM Battery Monitoring and Maintenance 3.8.c 3.8 ELECTRICAL POWER SYSTEMS 3.8.c Battery Monitoring and Maintenance TLCO 3.8.c Battery cell parameters for Division 11(21) and Division 12(22) batteries shall be within limits of Table T3.8.c-1.

APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One battery with one A.1 Verify pilot cell 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or more battery cell electrolyte level and parameters not within float voltage meet Category A or B Table T3.8.c-1 limits. Category C limits.

AND A.2 Verify battery cell 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months parameters meet Table T3.8.c-1 Category C AND limits.

Once per 7 days thereafter AND A.3 Restore battery cell 31 days parameters to Category A and B limits of Table T3.8.c-1.

(continued)

BRAIDWOOD UNITS 1 & 2 3.8.c 1 Revision 26 Technical Requirements Manual

TRM Battery Monitoring and Maintenance 3.8.c ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. ---------NOTE--------- B.1 Conduct an equalizing 31 days Required Actions B.1 charge of the and B.2 must be affected battery completed after LCO cell(s).

3.8.6, "Battery Parameters," Required AND Action C.3 is completed. B.2 Verify successful 31 days

completion of appropriate testing One battery with one for the affected or more cells with cell(s).

electrolyte level less than the minimum established design limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.8.c.1 Verify battery cell parameters meet Table 7 days T3.8.c-1 Category A limits.

(continued)

BRAIDWOOD UNITS 1 & 2 3.8.c 2 Revision 26 Technical Requirements Manual

TRM Battery Monitoring and Maintenance 3.8.c SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.8.c.2 Verify battery cell parameters meet Table 92 days T3.8.c-1 Category B limits.

AND Once within 7 days after a battery discharge

< 110 V AND Once within 7 days after a battery overcharge

> 145 V TSR 3.8.c.3 Verify no visible corrosion at battery 92 days terminals and connectors.

OR Verify battery connection resistance is d 150 micro-ohms for inter-cell connections, d 150 micro-ohms for inter-rack connections, d 150 micro-ohms for inter-tier connections, and d 150 micro-ohms for terminal connections.

AND Verify total battery connection resistance is < 3245 micro-ohms.

TSR 3.8.c.4 Verify battery cells, cell plates, and 18 months racks show no visual indication of physical damage or abnormal deterioration that could degrade battery performance.

(continued)

BRAIDWOOD UNITS 1 & 2 3.8.c 3 Revision 63 Technical Requirements Manual

TRM Battery Monitoring and Maintenance 3.8.c SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.8.c.5 Remove visible terminal corrosion, verify 18 months battery cell to cell and terminal connections are clean and tight, and are coated with anti-corrosion material.

TSR 3.8.c.6 Verify battery connection resistance is 18 months d 150 micro-ohms for inter-cell connections, d 150 micro-ohms for inter-rack connections, d 150 micro-ohms for inter-tier connections, and d 150 micro-ohms for terminal connections.

AND Verify total battery connection resistance is < 3245 micro-ohms.

BRAIDWOOD UNITS 1 & 2 3.8.c 4 Revision 63 Technical Requirements Manual

TRM Battery Monitoring and Maintenance 3.8.c Table T3.8.c-1 (page 1 of 1)

Battery Cell Parameters Requirements CATEGORY A: CATEGORY B: CATEGORY C:

LIMITS FOR EACH LIMITS FOR EACH CONNECTED ALLOWABLE LIMITS FOR EACH PARAMETER DESIGNATED PILOT CELL CELL CONNECTED CELL Electrolyte Level t Minimum level t Minimum level Above top of plates, and indication mark, and d 1/4 indication mark, and d 1/4 not overflowing inch above maximum level inch above maximum level indication mark(a) indication mark(a)

Float Voltage t 2.13 V t 2.13 V(b) > 2.07 V Specific Gravity(c)(d) t 1.200 t 1.195 Not more than 0.020 below average of all connected AND cells Average of all connected AND cells > 1.205 Average of all connected cells t 1.195 (a) It is acceptable for the electrolyte level to temporarily increase above the specified maximum during equalizing charges provided it is not overflowing.

(b) Corrected for average electrolyte temperature.

(c) Corrected for electrolyte temperature.

(d) A battery charging current of < 3 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 7 days. When charging current is used to satisfy specific gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance.

BRAIDWOOD - UNITS 1 & 2 3.8.c-5 Revision 26 Technical Requirements Manual

TRM Decay Time 3.9.a 3.9 REFUELING OPERATIONS 3.9.a Decay Time TLCO 3.9.a The reactor shall be subcritical for ! 113 hours0.00131 days 0.0314 hours 1.868386e-4 weeks 4.29965e-5 months OR The reactor shall be subcritical for 0 65 hours7.523148e-4 days 0.0181 hours 1.074735e-4 weeks 2.47325e-5 months AND the core offload shall be within the limits of the appropriate figure (Figure 3.9.a-1 through 3.9.a-9, as applicable).

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor subcritical A.1 Suspend movement of Immediately for 65 hours7.523148e-4 days 0.0181 hours 1.074735e-4 weeks 2.47325e-5 months . irradiated fuel in the reactor vessel.

OR Reactor subcritical for < 113 hours0.00131 days 0.0314 hours 1.868386e-4 weeks 4.29965e-5 months AND the core offload not within the limits of the appropriate figure (Figure 3.9.a-1 through 3.9.a-9, as applicable).

BRAIDWOOD UNITS 1 & 2 3.9.a 1 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.9.a.1 -------------------NOTE--------------------

Not required to be performed once Acceptable Region II in Figure 3.9.a-1 through 3.9.a-9 is entered.

Verify the reactor subcritical ! 113 hours0.00131 days 0.0314 hours 1.868386e-4 weeks 4.29965e-5 months Prior to by confirming the date and time of initial subcriticality. movement of irradiated fuel OR in the reactor vessel each Verify the reactor subcritical 0 65 hours7.523148e-4 days 0.0181 hours 1.074735e-4 weeks 2.47325e-5 months outage by confirming the date and time of subcriticality AND verify the core offload remains within the limits of the appropriate figure (Figure 3.9.a-1 through 3.9.a-9, as applicable) determined by TSR 3.9.a.2 during movement of irradiated fuel.

TSR 3.9.a.2 -------------------NOTE--------------------

Only required to be performed if cycle-specific Spent Fuel Pool (SFP) Heat Load Margin figures are used in TSR 3.9.a.1.

Determine the SFP Heat Load Margin for the Prior to specific cycle for use in TSR 3.9.a.1. initial Round the margin down to the next MBTU/hr movement of value to determine the applicable SFP Heat irradiated fuel Load Margin Figure (Figure 3.9.a-1 through in the reactor 3.9.a-9). vessel each outage.

BRAIDWOOD UNITS 1 & 2 3.9.a 2 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a 41 MBTU/hr SFP Heat Load Margin ICDT 200 180 Total Number of Assys Offloaded 160 140 Unacceptable Region 120 100 80 Acceptable Region I 60 Acceptable Region II 40 20 0

40 50 60 70 80 90 100 110 120 130 140 Time After Shutdown (Hrs)

Figure 3.9.a-1, 41 MBTU/hr SFP Heat Load Margin BRAIDWOOD UNITS 1 & 2 3.9.a 3 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a 42 MBTU/hr SFP Heat Load Margin 200 IJ_I

,, 180

,,,.. :.- ...... - I

,,m Q)

...... :.- ...... - - ..... I Unacceptable j 160 Region ,,,.. ......

~-

I 0 '--

=

0 tn 140 120 I

/ --

I j

I

~

tn ,)

~

100 Acceptable Region I I 0

Q) 80 I J

Acceptable --

.c 60 ,I Region II --

E z

l 40 I'

....-m 0 20

,j I- I 0

40 50 60 70 80 90 100 110 120 130 140 Time After Shutdown (Hrs)

Figure 3.9.a-2, "42 MBTU/hr SFP Heat Load Margin" BRAIDWOOD - UNITS 1 &2 3.9.a - 4 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a 43 MBTU/hr SFP Heat Load Margin 200 I 1_ 1_

,,co Cl>

180

.....,__ - '- i.- ..... - ....-

~ i-I' r

)

0 160 Unacceptable

,j

- i.- ..... -- ~

,)

=

0 rn

~

140 120 Region I

j I

rn rn )

<( 100 I'

'I- Acceptable 0

80 Region I Ii.

Cl>

.c

,I E 60 I Acceptable -~

s Region II z 40 )

-co

+I J I

0 20 I- ~

0 r 40 50 60 70 80 90 100 110 120 130 Time After Shutdown (Hrs)

Figure 3.9.a-3, "43 MBTU/hr SFP Heat Load Margin" BRAIDWOOD - UNITS 1 &2 3.9.a - 5 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a 44 MBTU/hr SFP Heat Load Margin 200 1_ 1

-- I '

I

,, 180 --

..- r-,

,,cu Q)

._ )

0 160

)

I~ - I I

E 140 Unacceptable Region I 0 j 120 ' I

~

x

)

<( 100 I 0 80 Acceptable )

Lo.

Q)

Region I v

.c 60 ~

I E J

s I Acceptable z 40 Region II

.....cu 20 J

,I 0

I-I 0

40 50 60 70 80 90 100 110 120 Time After Shutdown (Hrs)

Figure 3.9.a-4, "44 MBTU/hr SFP Heat Load Margin" BRAIDWOOD - UNITS 1 &2 3.9.a - 6 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a 45 MBTU/hr SFP Heat Load Margin 200 1_ 1_

"O 180 ~

-- I

v' Q)

"O 160 ~

E

"'0 )

r

,J 0 140 Unacceptable Region

,I I

>i 120 I

)

<C 100 I

'lo-0 l

I..

80 Acceptable I

,I Q)

.0 Region I E ,

s 60 I/

z ) Acceptable

-....,, 40 I Region II

~

"' 20 'f I

J 0 r 40 50 60 70 80 90 100 110 120 Time After Shutdown (Hrs)

Figure 3.9.a-5, "45 MBTU/hr SFP Heat Load Margin" BRAIDWOOD - UNITS 1 &2 3.9.a - 7 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a 46 MBTU/hr SFP Heat Load Margin 200 I I_

/

-0 CJ) 180 - 1"

-0 ca 160 ~-- /

E 0

I I/ ,J 140 I /'

0 tn

>a 120 Unacceptable Region " /

)

tn tn

<( 100 /

'+- i' 0

....CJ) 80 Acceptable Region I

/

J

.!l E 60 x

s /

z 40 I

) Acceptable Region II

....0ca 20 /

I- I 0 r 40 50 60 70 80 90 100 110 Time After Shutdown (Hrs)

Figure 3.9.a-6, "46 MBTU/hr SFP Heat Load Margin" BRAIDWOOD - UNITS 1 &2 3.9.a - 8 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a 47 MBTU/hr SFP Heat Load Margin 200 I I ]I ' _ I

~-

'O 180 _i-- / '

Q)

~-

'O 160 I ns 0 I/ ' I tt: 140 I ,,/

0 ,,y J

/

~ 120 Unacceptable

,I

<C 100 Region Acceptable /

0 Region I j Q) 80 I

,g E 60 ~

/

s J Acceptable z /

40 Region II

....ns0 ,'

j I- 20 /

0 40 50 60 70 80 90 100 110 Time After Shutdown (Hrs)

Figure 3.9.a-7, "47 MBTU/hr SFP Heat Load Margin" BRAIDWOOD - UNITS 1 &2 3.9.a - 9 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a 48 MBTU/hr SFP Heat Load Margin 200 I I_

I 180

-- /

"C Q)

"C cu 160 J'I"

~

- /

.1' 0 / /

e 140 / J, 0 ,,/ /

t/) /

~

t/)

120 v t/) Unacceptable

<( 100 /

....0 Region Acceptable i' s... 80 Region I v Q) /

.c J/

E 60 /

J Acceptable z 40 / Region II cu

,,,._ /

/

~ 20 )~

0 r 40 50 60 70 80 90 100 Time After Shutdown (Hrs)

Figure 3.9.a-8, "48 MBTU/hr SFP Heat Load Margin" BRAIDWOOD - UNITS 1 &2 3.9.a - 10 Revision 89 Technical Requirements Manual

TRM Decay Time 3.9.a 49 MBTU/hrSFP Heat Load Margin 200

"'C 180 Cl>

"'C n:s 160 0

5: 140 0

tn

~

tn 120

(

....0 100

....Cl> 80

.c E 60

J z

-...n:s 40

{:. 20 0

40 50 60 70 80 90 100 Time After Shutdown (Hrs)

Figure 3.9.a-9, "49 MBTU/hr SFP Heat Load Margin" BRAIDWOOD - UNITS 1 &2 3.9.a - 11 Revision 89 Technical Requirements Manual

TRM Communications 3.9.b 3.9 REFUELING OPERATIONS 3.9.b Communications TLCO 3.9.b Direct communications shall be maintained between the control room and personnel at the containment refueling station.

APPLICABILITY: During CORE ALTERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Direct communications A.1 Suspend CORE Immediately not maintained. ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.9.b.1 Demonstrate direct communications between Once within the control room and personnel at the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months prior to containment refueling station. the start of CORE ALTERATIONS AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter BRAIDWOOD - UNITS 1 & 2 3.9.b 1 Revision 1 Technical Requirements Manual

TRM Refueling Equipment 3.9.c 3.9 REFUELING OPERATIONS 3.9.c Refueling Equipment TLCO 3.9.c The following refueling equipment shall be OPERABLE:

1. The refueling machine used for movement of fuel assemblies, and

2. The auxiliary hoist or reactor cavity maintenance crane used for latching and unlatching drive rods.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling machine A.1 Suspend use of the Immediately inoperable. inoperable refueling machine from operations involving the movement of fuel assemblies within the reactor vessel.

B. Required auxiliary B.1 Suspend use of the Immediately hoist inoperable. inoperable required auxiliary hoist or OR inoperable required reactor cavity Required reactor maintenance crane cavity maintenance from operations crane inoperable. involving the movement of drive rods within the reactor vessel.

BRAIDWOOD UNITS 1 & 2 3.9.c 1 Revision 17 Technical Requirements Manual

TRM Refueling Equipment 3.9.c SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.9.c.1 Verify refueling machine operability by: Once within 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months prior

a. Performing a load test of to the start of 3563 pounds; and movement of fuel assemblies

b. Demonstrating an automatic load cutoff within the when the crane load > 2850 pounds. reactor vessel TSR 3.9.c.2 Verify required auxiliary hoist or required Once within reactor cavity maintenance crane and 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months prior associated load indicator operability by to the start of performing a load test 2500 pounds. movement of drive rods within the reactor vessel BRAIDWOOD UNITS 1 & 2 3.9.c 2 Revision 17 Technical Requirements Manual

TRM Crane Travel Spent Fuel Pool 3.9.d 3.9 REFUELING OPERATIONS 3.9.d Crane Travel Spent Fuel Pool TLCO 3.9.d Loads shall be limited to d 2000 pounds when traveling over fuel assemblies in the spent fuel pool.

NOTES---------------------------

1. Based on the design of the load block, the main hoist/load block is allowed to travel over the spent fuel pool.

2. Loads > 2000 pounds may be carried over the cask loading area provided they are carried by a SINGLE-FAILURE PROOF LOAD HANDLING SYSTEM.

3. Deviations from defined safe load paths for heavy loads require Plant Operations Review Committee approval.

APPLICABILITY: With fuel assemblies in the spent fuel pool.

ACTIONS

NOTE-------------------------------------

TLCO 3.0.c is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Load not within limit. A.1 Place the crane load Immediately in a safe condition.

BRAIDWOOD UNITS 1 & 2 3.9.d 1 Revision 75 Technical Requirements Manual

TRM Crane Travel Spent Fuel Pool 3.9.d SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.9.d.1 Verify crane interlocks prevent crane Once within travel with loads > 2000 pounds over fuel 7 days prior to assemblies in the spent fuel pool, with the crane use exception of the cask loading area.

AND Once per 7 days thereafter during crane operation BRAIDWOOD UNITS 1 & 2 3.9.d 2 Revision 75 Technical Requirements Manual

TRM Refueling Cavity Water Level 3.9.e 3.9 REFUELING OPERATIONS 3.9.e Refueling Cavity Water Level TLCO 3.9.e Refueling cavity water level shall be maintained 23 ft above the top of the reactor vessel flange.

APPLICABILITY: During movement of new fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water A.1 Suspend movement of Immediately level not within new fuel assemblies limit. within containment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.9.e.1 Verify refueling cavity water level is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 23 ft above the top of reactor vessel flange.

BRAIDWOOD UNITS 1 & 2 3.9.e 1 Revision 1 Technical Requirements Manual

TRM Safety Limit Violation 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Safety Limit Violation 5.1 The following actions shall be taken in the event a Safety Limit (Technical Specification 2.1.1 or 2.1.2) is violated:

a. The NRC Operations Center shall be notified by telephone as soon as possible and in all cases within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ,

b. The Site Vice President and the Offsite Review and Investigative Function shall be notified within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

c. A Safety Limit Violation Report shall be prepared. The report shall be reviewed by the Onsite Review and Investigative Function. This report shall describe: (1) applicable circumstances preceding the violation, (2) effects of the violation upon facility components, systems or structures, and (3) corrective action to prevent recurrence,

d. The Safety Limit Violation Report shall be submitted to the Commission, the Offsite Review and Investigative Function and the Site Vice President within 14 days of the violation, and

e. Critical operation of the Unit shall not be resumed until authorized by the Commission.

BRAIDWOOD UNITS 1 & 2 5.1 1 Revision 1 Technical Requirements Manual

TRM Procedures and Programs 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Procedures and Programs 5.2.a Process Control Program (PCP)

Written procedures shall be established, implemented, and maintained covering the activities of the PCP implementation.

The PCP shall contain the current formulas, sampling, analyses, tests, and determinations to be made to ensure that processing and packaging of solid radioactive wastes based on demonstrated processing of actual or simulated wet solid wastes will be accomplished in such a way as to assure compliance with 10 CFR Parts 20, 61, and 71, State regulations, burial ground requirements, and other requirements governing the disposal of solid radioactive waste.

Changes to the PCP:

1. Shall be documented and records of reviews performed shall be retained for the duration of the unit Operating License.

This documentation shall contain:

a. Sufficient information to support the change together with the appropriate analyses or evaluations justifying the change(s) and,

b. A determination that the change will maintain the overall conformance of the solidified waste product to existing requirements of Federal, State, and other applicable regulations.

2. Shall become effective after review and acceptance by the Onsite Review and Investigative Function (Onsite Review) and the approval of the Station Manager.

BRAIDWOOD UNITS 1 & 2 5.2 1 Revision 1 Technical Requirements Manual

TRM Procedures and Programs 5.2 5.2 Procedures and Programs 5.2.b In-Plant Radiation Monitoring A program shall be established, implemented and maintained which will ensure the capability to accurately determine the airborne iodine concentration in vital areas under accident conditions.

This program shall include the following:

1. Training of personnel,

2. Procedures for monitoring, and

3. Provisions for maintenance of sampling and analysis equipment.

5.2.c Radiological Environmental Monitoring Program A program shall be established, implemented and maintained which will monitor the radiation and radionuclides in the environs of the plant. The program shall provide (1) representative measurements of radioactivity in the highest potential exposure pathways, and (2) verification of the accuracy of the effluent monitoring program and modeling of environmental exposure pathways. The program shall (1) be contained in the Offsite Dose Calculation Manual (ODCM), (2) conform to the guidance of Appendix I to 10 CFR Part 50, and (3) include the following:

1. Monitoring, sampling, analysis, and reporting of radiation and radionuclides in the environment in accordance with the methodology and parameters in the ODCM,

2. A Land Use Census to ensure that changes in the use of areas at and beyond the SITE BOUNDARY are identified and that modifications to the monitoring program are made if required by the results of this census, and

3. Participation in an Interlaboratory Comparison Program to ensure that independent checks on the precision and accuracy of the measurements of radioactive materials in environmental sample matrices are performed as part of the Quality Assurance Program for environmental monitoring.

BRAIDWOOD UNITS 1 & 2 5.2 2 Revision 1 Technical Requirements Manual

TRM Procedures and Programs 5.2 5.2 Procedures and Programs 5.2.d Radiation Protection Program Procedures for personnel radiation protection shall be prepared consistent with the requirements of 10 CFR Part 20 and shall be approved, maintained and adhered to for all operations involving personnel radiation exposure.

5.2.e Offsite Dose Calculation Manual (ODCM)

The requirement for an ODCM program is contained in Technical Specification 5.5.1.

Changes to the ODCM shall become effective after review and acceptance by the Onsite Review and Investigative Function and the approval of the Station Manager on the date specified by the Onsite Review and Investigative Function.

BRAIDWOOD UNITS 1 & 2 5.2 3 Revision 1 Technical Requirements Manual

TRM Reporting Requirements 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.3.a Startup Report

1. A summary report of plant startup and power escalation testing shall be submitted to the Commission following:

(1) receipt of an Operating License, (2) amendment to the license involving a planned increase in power level, (3) installation of fuel that has a different design or has been manufactured by a different fuel supplier, and (4) modifications that may have significantly altered the nuclear, thermal, or hydraulic performance of the plant.

2. The Startup Report shall address each of the tests identified in the Updated Final Safety Analysis Report (UFSAR) and shall include a description of the measured values of the operating conditions or characteristics obtained during the test program and a comparison of these values with design predictions and specifications. Any corrective actions that were required to obtain satisfactory operation shall also be described. Any additional specific details required in license conditions based on other commitments shall be included in this report.

3. Startup Reports shall be submitted within: (1) 90 days following completion of the Startup Test Program, (2) 90 days following resumption or commencement of commercial power operation, or (3) 9 months following initial criticality, whichever is earliest. If the Startup Report does not cover all three events (i.e., initial criticality, completion of Startup Test Program, and resumption or commencement of commercial operation) supplementary reports shall be submitted at least every 3 months until all three events have been completed.

BRAIDWOOD UNITS 1 & 2 5.3 1 Revision 1 Technical Requirements Manual

TRM Reporting Requirements 5.3 5.3 Reporting Requirements 5.3.b Annual Specific Activity Report An Annual Report covering the activity of the facility for the previous calendar year shall be submitted to the Commission prior to March 1 of each year.

The results of specific activity analysis in which the primary coolant exceeded the limits of Specification 3.4.16. The following information shall be included: (1) Reactor power history starting 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months prior to the first sample in which the limit was exceeded; (2) Results of the last isotopic analysis for radioiodine performed prior to exceeding the limit, results of analysis while limit was exceeded and results of one analysis after radioiodine activity was reduced to less than limit. Each result should include date and time of sampling and the radioiodine concentrations; (3) Clean-up system flow history starting 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months prior to the first sample in which the limit was exceeded; (4) Graph of the I-131 concentration and one other radioiodine isotope concentration in microcuries per gram as a function of time for the duration of the specific activity above the steady-state level; and (5) The time duration when the specific activity of the primary coolant exceeded the radioiodine limit.

5.3.c Special Reports

1. In the event the unit is in MODE 1 or 2 with Keff 1 and with the Moderator Temperature Coefficient (MTC) more positive than the beginning of life limit specified in the COLR, a Special Report shall be prepared and submitted to the Commission within 10 days. The Special Report shall describe the value of the measured MTC, the interim control rod withdrawal limits, and the predicted average core burnup necessary for restoring the positive MTC to within its limit for the all rods withdrawn condition.

2. In the event an inoperable Main Control Room Radiation Outside Air Intake Monitor (ORE-PR031B/32B or ORE-PR033B/34B) is not restored to OPERABLE within 30 days, a Special Report shall be prepared and submitted to the Commission within the following 30 days. The Special Report shall describe the cause of the inoperability and the plans for restoration.

BRAIDWOOD UNITS 1 & 2 5.3 2 Revision 1 Technical Requirements Manual

TRM Reporting Requirements 5.3 5.3 Reporting Requirements 5.3.c Special Reports (continued)

3. In the event the unit is in MODE 4, 5, or 6 with the reactor head on and either the PORVs, RHR suction relief valves, or the RCS vents are used to mitigate an RCS pressure transient, a Special Report shall be prepared and submitted to the Commission within 30 days. The Special Report shall describe the circumstances initiating the transient, the effect of the PORVs, RHR suction relief valves, or RCS vents on the transient, and any corrective action necessary to prevent recurrence.

4. In the event the unit is in MODE 1, 2, 3, or 4 and the ECCS is actuated and injects water into the RCS, a Special Report shall be prepared and submitted to the Commission within 90 days. The Special Report shall describe the circumstances of the actuation and the total accumulated actuation cycles to date. The current value of the usage factor for each affected Safety Injection nozzle shall be provided in this Special Report whenever its value exceeds 0.70.

(NOTE: If a Licensee Event Report (LER) has been provided to the NRC documenting the event and that report includes all of the requirements of the Special Report, no additional actions are required.)

BRAIDWOOD UNITS 1 & 2 5.3 3 Revision 1 Technical Requirements Manual

TRM ODCM and Radiological Controls Reports and Program Appendix A ODCM AND RADIOLOGICAL CONTROLS REPORTS AND PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTIONS TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 5 Revision 33 Technical Requirements Manual

TRM ODCM and Radiological Controls Reports and Program Appendix A 1.1 PURPOSE This Program provides guidance for the implementation of Technical Specification (TS) 5.5.1, "Offsite Dose Calculation Manual (ODCM)", 5.6.2, "Annual Radiological Environmental Operating Report", and 5.6.3, "Radioactive Effluent Release Report."

The ODCM contains the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and the conduct of the Radiological Environmental Monitoring Program. In addition, the ODCM contains the radioactive effluent controls, radiological environmental monitoring activities, and descriptions of the information that is included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release Reports.

1.2 REFERENCES

1. Technical Specifications:

a. 5.5.1, "Offsite Dose Calculation Manual (ODCM)"

b. 5.6.2, "Annual Radiological Environmental Operating Report"

c. 5.6.3, "Radioactive Effluent Release Report"

2. US NRC 10CFR20.1302

3. US NRC 40CFR190

4. US NRC 10CFR50, Appendix I 1.3 DEFINITIONS AND/OR ACRONYMS Offsite Dose Calculation Manual - ODCM 1.4 PROGRAM DESCRIPTION The purpose of this Program is to ensure that methodologies, parameters, effluent controls, radiological monitoring, and reporting requirements are properly implemented by the ODCM or other approved plant procedures.

BRAIDWOOD UNITS 1 & 2 2 of 5 Revision 33 Technical Requirements Manual

TRM ODCM and Radiological Controls Reports and Program Appendix A 1.5 PROGRAM IMPLEMENTATION

1. The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the Radiological Environmental Monitoring Program.

2. The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release Reports required in Reference 1.

The Chemistry Department shall have responsibility for the implementation, performance, completion and reporting of this Program.

1.6 ACCEPTANCE CRITERIA Acceptance criteria is contained in the ODCM, plant implementing or surveillance procedures.

1.7 LCOARS/COMPENSATORY MEASURES No LCOARs will be entered as a result of exceeding any acceptance criteria. Any corrective measures are contained in the ODCM or plant procedures. In addition, an Issue Report (IR) may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

1.8 REPORTING REQUIREMENTS

1. Annual Radiological Environmental Operating Report covering the operation of the facility during the previous calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the ODCM, and Reference 4.

BRAIDWOOD UNITS 1 & 2 3 of 5 Revision 33 Technical Requirements Manual

TRM ODCM and Radiological Controls Reports and Program Appendix A

2. The Radioactive Effluent Release Report covering the operation of the facility during the previous year shall be submitted prior to May 1 of each year in accordance with 10CFR50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the facility. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in conformance with 10CFR50.36a and Reference 4.

A single submittal may be made for the facility. The submittal should combine sections common to both units.

The Chemistry Department is responsible for preparing and submitting the subject reports.

1.9 CHANGE CONTROL Changes to the ODCM shall be documented and records of reviews performed shall be retained. As a minimum, the documentation shall contain:

1. sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s); and

2. a determination that the change(s) maintain the levels of radioactive effluent control required by References 2, 3, 4, and 10CFR50.36a and do not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations.

Changes to the ODCM are effective upon approval of the Plant Manager or designee.

Changes to the ODCM shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made.

Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.

BRAIDWOOD UNITS 1 & 2 4 of 5 Revision 33 Technical Requirements Manual

TRM ODCM and Radiological Controls Reports and Program Appendix A Changes to this Program, other than editorial changes, shall include a 10CFR50.59 Review and a Station Qualified Review (SQR).

The SQR composition shall include Regulatory Assurance Department in all cases. As a part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager. Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and was determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 5 of 5 Revision 33 Technical Requirements Manual

TRM Primary Coolant Sources Outside Containment Program Appendix B PRIMARY COOLANT SOURCES OUTSIDE CONTAINMENT BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 4 Revision 58 Technical Requirements Manual

TRM Primary Coolant Sources Outside Containment Program Appendix B 1.1 PURPOSE The purpose of this Program is to verify leakage tests are performed on each system or portion of systems outside containment that could potentially contain highly radioactive fluids or gases, pursuant to Technical Specification (TS) 5.5.2, "Primary Coolant Sources Outside Containment". This Program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to level as low as practicable.

1.2 References

1. Technical Specifications 5.5.2, "Primary Coolant Sources Outside Containment"

2. UFSAR Appendix E.77 (UFSAR), "Primary Coolant Sources Outside Containment (III.D.1.1)"

3. NUREG 0737.III.D.1.1, "Integrity of Systems Outside Containment Likely to Contain Radioactive Material for Pressurized-Water Reactors and Boiling-Water Reactors"

4. NRC Generic Letter 88-05, "Boric Acid Corrosion of Carbon Steel Reactor Pressure Boundary Components in PWR Plants" 1.3 DEFINITIONS AND ACRONYMS

1. INDICATION - The response from the application of a visual examination (VT-2).

2. VT-2 (Visual Examination) - An inspection of an ASME/NUREG System component at normal system operating pressure.

1.4 PROGRAM DESCRIPTION This Program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include the recirculation portions of the Containment Spray, Safety Injection, Chemical and Volume Control, and Residual Heat Removal.

BRAIDWOOD UNITS 1 & 2 2 of 4 Revision 58 Technical Requirements Manual

TRM Primary Coolant Sources Outside Containment Program Appendix B 1.5 PROGRAM IMPLEMENTATION This Program determines, through the associated implementing procedures, that leakage sources outside containment will be accounted for to insure the total amount will not exceed the UFSAR acceptable limits for Braidwood Station. The bases for this Program were established per References 2 and 3 that provide for the following:

1. Monitor the leak testing of piping so that the appropriate lines are examined at least once per 18 months on each System or portions of Systems;

2. Direct leak test examinations such that systems are tested at approximate operating pressure or higher;

3. Align systems such that all piping tested is properly pressurized;

4. Identify lines that contain gases that require pressure decay and/or metered makeup testing;

5. Quantify results of leakage examinations;

6. Initiate corrective action; and

7. Preventive maintenance in accordance with approved plant procedures consistent with the Braidwood Maintenance Rule.

The Engineering Programs Group shall have responsibility for the completion of this Program.

1.6 ACCEPTANCE CRITERIA

1. All examinations required by this Program are completed at least once per 18 months. The provisions of SR 3.0.2 are applicable.

2. Cumulative leakage shall be within the acceptable range specified per UFSAR Table 15.6-13.

BRAIDWOOD UNITS 1 & 2 3 of 4 Revision 58 Technical Requirements Manual

TRM Primary Coolant Sources Outside Containment Program Appendix B 1.7 LCOARS/COMPENSATORY MEASURES Any examinations exceeding acceptance criteria shall be immediately conveyed to the Shift Manager. The Shift Manager shall determine the OPERABILITY status and implement a LCOAR if applicable. In addition, an Issue Report may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

1.8 REPORTING REQUIREMENTS Any examinations exceeding acceptance criteria will be coordinated/reported in accordance with the requirements of the Maintenance Rule Program.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10CFR50.59 Review and a Station Qualified Review (SQR).

The SQR composition shall include the Regulatory Assurance Department in all cases. As a part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager. Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 4 of 4 Revision 58 Technical Requirements Manual

TRM Radioactive Effluent Controls Program Appendix D RADIOACTIVE EFFLUENT CONTROLS PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITION AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 5 Revision 33 Technical Requirements Manual

TRM Radioactive Effluent Controls Program Appendix D 1.1 PURPOSE This Program is in compliance with Technical Specification (TS) 5.5.4, "Radioactive Effluent Controls Program." This Program provides controls for radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable. The Program shall be contained in the Offsite Dose Calculation Manual (ODCM) which is implemented by plant procedures which also include remedial actions taken whenever the acceptance criteria is exceeded.

1.2 REFERENCES

1. Technical Specifications 5.5.4, "Radioactive Effluent Controls Program"

2. Offsite Dose Calculation Manual (ODCM)

3. US NRC 10CFR20, Appendix B, Table 2, Column 2

4. US NRC 10CFR20.1302

5. US NRC 10CFR50, Appendix I

6. US NRC 40CFR190 1.3 DEFINITIONS AND/OR ACRONYMS Offsite Dose Calculation Manual - ODCM 1.4 PROGRAM DESCRIPTION This Program ensures that appropriate plant procedures, along with the ODCM are implemented for radioactive effluent controls. These controls are to be maintained in accordance with the guidance provided by referenced NRC requirements. This Program provides the general guidance for surveillance testing, monitoring, setpoint determination, exposure limits, and reporting requirements.

BRAIDWOOD UNITS 1 & 2 2 of 5 Revision 33 Technical Requirements Manual

TRM Radioactive Effluent Controls Program Appendix D 1.5 PROGRAM IMPLEMENTATION This Program shall be implemented by plant procedures or the ODCM which will include at least the following:

1. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in Reference 2;

2. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to 10 times the concentrations stated in Reference 3;

3. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with Reference 4 and with the methodology and parameters per Reference 2;

4. Limitations on the quarterly and annual doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to Reference 5;

5. Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in Reference 2, Section 12 at least every 31 days;

6. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to Reference 5;

7. Limitations on the dose rate resulting from radioactive material released in gaseous effluents to areas beyond the site boundary conforming to the acceptance criteria.

BRAIDWOOD UNITS 1 & 2 3 of 5 Revision 33 Technical Requirements Manual

TRM Radioactive Effluent Controls Program Appendix D

8. Limitations on the quarterly and annual air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to Reference 5.

9. Limitations on the quarterly and annual doses to a member of the public from Iodine-131, Iodine-133, Tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to Reference 5; and

10. Limitations on the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to Reference 6.

The Chemistry Department shall have responsibility for the implementation, performance, completion, and reporting of this Program.

1.6 ACCEPTANCE CRITERIA All acceptance criteria pertaining to this Program is located in the ODCM, implementing, or surveillance procedures.

1.7 LCOARS/COMPENSATORY MEASURES An Issue Report (IR) may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program..

1.8 REPORTING REQUIREMENTS Any reporting requirements are listed in the ODCM and implementing procedures.

BRAIDWOOD UNITS 1 & 2 4 of 5 Revision 33 Technical Requirements Manual

TRM Radioactive Effluent Controls Program Appendix D 1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10CFR50.59 Review and a Station Qualified Review (SQR).

The SQR composition shall include Regulatory Assurance Department in all cases. As a part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager. Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and was determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 5 of 5 Revision 33 Technical Requirements Manual

TRM Transient Monitoring Program Appendix E TRANSIENT MONITORING PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 6 Revision 1 Technical Requirements Manual

TRM Transient Monitoring Program Appendix E 1.1 PURPOSE The purpose of this Program is to provide guidance for tracking the number of cycles of specific transients and to ensure operation within the Braidwood Plant Design Basis is in accordance with Technical Specifications (TS) 5.5.5, "Component Cyclic or Transient Limit."

The minimum requirements for cyclic or transient tracking are those transients listed in Attachment 1 of this Program. These items, in addition to various other monitored parameters or transients, will be tracked periodically in accordance with appropriate Plant Procedures.

Components affected by the transients monitored are typically ASME Section III Code Class 1 vessels. The design of such components includes cyclic/fatigue assumptions which must be tracked to ensure that the unit is operating within its design basis. Piping and components designed to ANSI B31.1, Power piping does not generally require fatigue monitoring as those considerations are inherent to the safety margins applied by that Code.

1.2 REFERENCES

1. TS Specification 5.5.5, "Component Cyclic or Transient Limit"

2. Updated Final Safety Analysis Report, (UFSAR), Section 3.9 and 5.2

3. 10CFR50, Appendix A

4. "WCAP-12235, General Guidelines for Nuclear Power Plant Transient and Fatigue Monitoring", March, 1989 1.3 DEFINITION AND/OR ACRONYMS Not applicable.

BRAIDWOOD UNITS 1 & 2 2 of 6 Revision 1 Technical Requirements Manual

TRM Transient Monitoring Program Appendix E 1.4 PROGRAM DESCRIPTION This Program ensures that appropriate plant procedures are implemented to monitor transients that may have an affect on ASME Section III Code Class 1 vessels/components as specified in Reference 2.

Attachment 1 provides component cyclic or transient limits as well as design cycle or transient parameters for specific plant components. Monitoring of additional equipment/parameters not listed in Attachment 1 may be performed as a good practice on an as needed basis, and are not considered within the scope of this Program though they may be tracked using appropriate Plant Procedures, Implementing procedures shall have adequate measures to identify cumulative cyclic/transient conditions requiring further analysis prior to the design basis limits being reached.

In the event any of the limits are approached or exceeded, required actions or reporting requirements are specified in this Program or appropriate Plant Procedures.

1.5 PROGRAM IMPLEMENTATION Specific plant procedures have been developed and implemented in order to perform the following:

1. Provide a tracking program for the relevant transient cycles/trips for those ASME Section III Code Class 1 components specified in Reference 2.

2. Periodically monitor components identified in Attachment 1 for code compliance relative to parameters such as, transient limits and usage factors.

System Engineering Department shall have responsibility for the implementation, performance, completion, and reporting of this Program.

1.6 ACCEPTANCE CRITERIA

1. Attachment 1 provides cyclic or transient limit acceptance criteria for each component within the scope of this Program.

BRAIDWOOD UNITS 1 & 2 3 of 6 Revision 1 Technical Requirements Manual

TRM Transient Monitoring Program Appendix E

2. Should the design basis limits be approached or exceeded, an evaluation and recommended operating restrictions (if any) will be provided by Site Engineering - Mechanical. Any recommendations to modify design limits shall be accompanied by a safety evaluation.

1.7 LCOARS/COMPENSATORY MEASURES In the event that a component has reached its administrative cyclic or transient limit, the Shift Manager shall be notified immediately. The Shift Manager shall determine OPERABILITY status and implement a LCOAR if applicable. In addition, a Problem Identification Form (PIF) may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

1.8 REPORTING REQUIREMENTS

1. A special report will be generated whenever cyclic or transient limits are being approached or exceeded. This report shall be generated and distributed, as a minimum to the following:

PORC (Plant Operations Review Committee)

Site V.P. - Braidwood Plant Manager Operations Manager Engineering Manager

2. Any violations of the cyclic or transient limits shall be reported to the NRC in accordance with 10CFR50.71 and 10CFR50.72.

BRAIDWOOD UNITS 1 & 2 4 of 6 Revision 1 Technical Requirements Manual

TRM Transient Monitoring Program Appendix E 1.9 CHANGE CONTROL Changes to this Program, other than editorial, shall include a 10CFR50.59 evaluation and an Independent Technical Review (ITR).

The ITR composition shall include Regulatory Assurance Department in all cases. As a part of the ITR, for a change to this Program, concurrence from Byron Station and Braidwood Plant Operations Review Committee (PORC) approval is required. The concurrence shall be that Byron Station is implementing the same change or that the change has been reviewed and determined not to be applicable to Byron Station.

BRAIDWOOD UNITS 1 & 2 5 of 6 Revision 1 Technical Requirements Manual

TRM Transient Monitoring Program Appendix E ATTACHMENT 1 COMPONENT CYCLIC OR TRANSIENT LIMITS CYCLIC OR DESIGN CYCLE COMPONENT TRANSIENT LIMIT OR TRANSIENT Reactor Coolant 200 heatup cycles at Heatup cycle - Tavg from System 100°F/h and 200 cool- 200°F to 550°F.

down cycles at < 100 °F/h. Cooldown cycle - Tavg from 550°F to 200°F.

200 pressurizer cooldown Pressurizer cooldown cycles at 200°F/h. cycle temperature from 650°F to 100°F.

80 loss of load cycles, 15% of RATED THERMAL without immediate Turbine POWER to 0% of RATED or Reactor Trip. THERMAL POWER.

40 cycles of loss-of-offsite Loss-of-Offsite A.C.

A.C. electrical power. electrical ESF Electrical System.

80 cycles of loss of flow Loss of only one in one reactor coolant loop. reactor coolant pump.

400 Reactor trip cycles. 100% to 0% of RATED THERMAL POWER.

10 auxiliary spray actuation Spray water temperature cycles. differential > 320°F.

200 leak tests. Pressurized to 2485 psig.

10 hydrostatic pressure Pressurized to 3107 tests. psig.

Secondary Coolant 1 large steam line break. Break in a > 6 inch System steam line.

10 hydrostatic pressure Pressurized to 1481 tests. psig.

BRAIDWOOD UNITS 1 & 2 6 of 6 Revision 1 Technical Requirements Manual

TRM Pre-stressed Concrete Containment Tendon Surveillance Program Appendix F PRE-STRESSED CONCRETE CONTAINMENT TENDON SURVEILLANCE PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOAR/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 5 Revision 61 Technical Requirements Manual

TRM Pre-stressed Concrete Containment Tendon Surveillance Program Appendix F 1.1 PURPOSE This Program provides controls for monitoring any tendon degradation in the pre-stressed concrete containments and is pursuant to Technical Specifications (TS) 5.5.6 and 5.6.8.

1.2 REFERENCES

1. Technical Specifications:

a. 5.5.6, Pre-Stressed Concrete Containment Tendon Surveillance Program

b. 5.6.8, Tendon Surveillance Report

2. USFAR Section 3.8.1.7.3.2, Inservice Tendon Surveillance Program

3. U.S. NRC 10 CFR 50.55a

4. U.S. NRC Regulatory Guide 1.35.1, Determining Pre-Stressing Forces For Inspection of Pre-Stressed Concrete Containments, dated July 1990

5. ASME Boiler and Pressure Vessel Code,Section XI, Sub Section IWL

6. Drawings:

a. S884: Containment Building Tendon Location Plans and Sections

b. Inland Ryerson Company Drawings 781 / 782 through 781 / 782-23

c. Braidwood Station In Service Inspection Drawings for Containment Tendons

7. Braidwood SER Section 3.8.1

8. Braidwood Maintenance Rule 10 CFR 50.65 BRAIDWOOD UNITS 1 & 2 2 of 5 Revision 61 Technical Requirements Manual

TRM Pre-stressed Concrete Containment Tendon Surveillance Program Appendix F 1.3 DEFINITIONS AND/OR ACRONYMS

1. TENDON - The bundle of wire assemblies and anchorages that maintain pre-stressed forces within the containment structure.

2. ANCHORAGE - The components at each end of the wire bundle that are used to maintain the required pre-stressed forces and distribute the forces within the tendon.

3. LIFT OFF FORCE - The force required to lift the containment tendon anchorage from the shim stack or structure.

4. SHEATHING FILLER GREASE - The corrosion protection medium that encases the tendon and anchorage.

1.4 PROGRAM DESCRIPTION The Pre-Stressed Concrete Containment Tendon Surveillance Program provides a standardized methodology to ensure that aging and degradation issues are identified early and monitored through the following activities:

1. Measuring, recording, and evaluating the lift off force for tendons included in the test sample population;

2. Ensuring the containment vessel, tendon anchorages, and tendon wires do not exhibit signs of abnormal degradation;

3. Ensuring the tendon wires continue to maintain the required integrity through physical testing; and

4. Ensuring the sheathing filler grease continues to protect the tendon components from corrosion by identification of free water and chemical analysis of the sheathing filler grease.

BRAIDWOOD UNITS 1 & 2 3 of 5 Revision 61 Technical Requirements Manual

TRM Pre-stressed Concrete Containment Tendon Surveillance Program Appendix F 1.5 PROGRAM IMPLEMENTATION Inspection schedules, examination and testing methods, personnel qualification requirements, and reporting requirements shall be established, implemented, and maintained in accordance with Section XI, Subsection IWL of the ASME Boiler and Pressure Vessel Code and applicable addenda as required by 10 CFR 50.55(a) except where alternative, exemption or relief has been authorized by the NRC. The Engineering Programs Group shall have the responsibility for all aspects of the Program.

The detection of degradation of the containment structure or trending shall be coordinated with the requirements of the Maintenance Rule.

1.6 ACCEPTANCE CRITERIA Acceptance criteria for the Braidwood Pre-Stressed Concrete Containment Tendon Surveillance Program is contained in appropriate Plant Procedures as described in the Braidwood Containment Inservice Inspection (CISI) Program Plan.

1.7 LCOARS / COMPENSATORY MEASURES In the event the acceptance criteria is exceeded, immediately notify the Shift Manager. In addition, the issue shall be entered into the Corrective Action Program to provide proper tracking and resolution of noted problems associated with the implementation of this Program. Engineering shall determine if the condition that exceeded the acceptance criteria renders the containment inoperable. In the event the containment is found to be inoperable, the Shift Manager shall be immediately notified and the Shift Manager shall implement the applicable LCOAR.

1.8 REPORTING REQUIREMENTS

1. Items which do not meet the acceptance criteria shall be evaluated by Engineering and an Engineering Evaluation Report shall be prepared. The Engineering Evaluation Report(s) shall be maintained at the site and are subject to review by the regulatory and enforcement authorities.

a. The Engineering Evaluation Report shall be in accordance with the ASME Code Section XI, IWL Subsection.

BRAIDWOOD UNITS 1 & 2 4 of 5 Revision 61 Technical Requirements Manual

TRM Pre-stressed Concrete Containment Tendon Surveillance Program Appendix F

2. The following conditions shall also be reported in the ISI Summary Report required by ASME Section XI, IWA6000 when:

a. The elongation corresponding to a specific load

( adjusted for effective wires or strands )

during re-tensioning of the tendons differs by more than 10 percent from that recorded during the last measurement;

b. The Sheathing Filler Grease Analysis contains chemically combined water exceeding 10 percent by weight;

c. The presence of free water is identified in the sheathing filler grease;

d. The absolute difference between the amount of sheathing filler grease removed during inspection and testing and the amount replaced thereafter exceeds 10 percent of the tendon duct volume; or

e. Grease leakage is detected during general visual examination of the containment surface.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10 CFR 50.59 Review and a Station Qualified Review (SQR). The SQR composition shall include the Regulatory Assurance Department in all cases. As part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager. Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and was determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 5 of 5 Revision 61 Technical Requirements Manual

TRM Reactor Coolant Pump Flywheel Inspection Program Appendix G REACTOR COOLANT PUMP FLYWHEEL INSPECTION PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 5 Revision 71 Technical Requirements Manual

TRM Reactor Coolant Pump Flywheel Inspection Program Appendix G 1.1 PURPOSE The purpose of this Program is to verify the structural integrity of each Reactor Coolant Pump Flywheel pursuant to Technical Specification (TS) 5.5.7, "Reactor Coolant Pump Flywheel Inspection Program." This Program provides for the inspection of each reactor coolant pump flywheel in general conformance with Reference 5 as modified by References 12 and 13.

1.2 REFERENCES

1. Technical Specification 5.5.7, "Reactor Coolant Pump Flywheel Inspection Program"

2. UFSAR:

a. Section 5.4.1.5.2

b. Appendix A

3. 10CFR50 Appendix A and B

4. NUREG-0800, Section 5.4.1.1, "Pump Flywheel Integrity"

5. Regulatory Guide 1.14, "Reactor Coolant Pump Flywheel Integrity"

6. Braidwood Station Units 1 and 2 Inservice Inspection Program Plan

7. Westinghouse WCAP-8163, "Topical Report on Reactor Coolant Pump Integrity in LOCA"

8. Westinghouse Vendor Manual F-198, "Reactor Coolant Pump" BRAIDWOOD UNITS 1 & 2 2 of 5 Revision 71 Technical Requirements Manual

TRM Reactor Coolant Pump Flywheel Inspection Program Appendix G

9. Braidwood SER Sections:

a. 2.2.4

b. 3.5.1.2

c. 5.4.1

10. Braidwood Station Maintenance Rule Program

11. Westinghouse WCAP-14535A, "Topical Report on Reactor Coolant Pump Flywheel Inspection Elimination"

12. Mahesh Chawla to O.D. Kingsley, "Issuance of Amendments -

Byron Station, Units 1 and 2 and Braidwood Station, Units 1 and 2 - Request for Technical Specifications Change -

Revision to the Reactor Coolant Pump Flywheel Inspection Program," dated September 21, 2001.

13. Marshall David to M.J. Pacilio, "Braidwood Station, Units 1 and 2, and Byron Station, Unit Nos. 1 and 2 - Issuance of Amendments RE: Extension of Inspection Interval for Reactor Coolant Flywheels (TAC Nos. ME3640, ME3641, ME3642, and ME3643), dated September 16, 2010.

1.3 DEFINITIONS AND/OR ACRONYMS

1. UT - Ultrasonic Testing

2. SURFACE EXAMINATION - Examination method using liquid penetrant (PT) or magnetic particle (MT) techniques.

3. INDICATION - The response from the application of a nondestructive examination (NDE).

4. RELEVANT INDICATION OR FLAW - An imperfection or unintentional discontinuity that is detectable by NDE.

5. DEFECT - A flaw of such size, shape, orientation, location, or properties as to be rejectable.

1.4 PROGRAM DESCRIPTIONS One of the following examinations shall be performed on each reactor coolant pump flywheel at the specified frequency:

BRAIDWOOD UNITS 1 & 2 3 of 5 Revision 71 Technical Requirements Manual

TRM Reactor Coolant Pump Flywheel Inspection Program Appendix G

1. A qualified in-place UT examination over the volume from the inner bore of the flywheel to the circle of half the outer radius or

2. A surface examination (MT or PT) of the bore and keyway area whenever the flywheels are removed for maintenance purposes.

Since the exposed surfaces, other than the bore and keyway areas, of the flywheels are coated with corrosion preventative primer paint, a surface examination of these surfaces is not practicable.

3. For reactor coolant pump motor serial numbers 4S88P961 and 1S88P961, in lieu of Regulatory Position c.4.b(1) and c.4.b(2), a qualified in-place UT examination over the volume from the inner bore of the flywheel to the circle of one-half the outer radius or a surface examination (MT and/or PT) of exposed surfaces of the removed flywheel may be conducted at approximately 10 year intervals coinciding with the Inservice Inspection schedule as required by ASME Section XI.

For all other reactor coolant pump motors, in lieu of Regulatory Position c.4.b(1) and c.4.b(2), a qualified in-place UT examination over the volume from the inner bore of the flywheel to the circle of one-half the outer radius or a surface examination (MT and/or PT) of exposed surfaces of the removed flywheel may be conducted at an interval not to exceed 20 years.

1.5 PROGRAM IMPLEMENTATION Inspection schedules, personnel, equipment and material certifications, applicable examination methods, and examination reports shall be initiated and maintained in accordance with Braidwood Unit 1 and 2 Inservice Inspection Program Plan and associated procedures.

The Engineering Programs Group shall have responsibility for the implementation, performance, completion, and reporting of this Program.

1.6 ACCEPTANCE CRITERIA

1. All relevant indications shall be recorded on the appropriate examination form.

BRAIDWOOD UNITS 1 & 2 4 of 5 Revision 71 Technical Requirements Manual

TRM Reactor Coolant Pump Flywheel Inspection Program Appendix G

2. Final disposition of flaws shall be based on engineering analysis.

1.7 LCOARS/COMPENSATORY MEASURES In the event indication(s) exceed allowable length, the Shift Manager shall be notified immediately. The Shift Manager shall determine OPERABILITY status and implement a LCOAR if applicable.

In addition, an Issue Report (IR) may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

1.8 REPORTING REQUIREMENTS

1. If the examination and evaluation indicate an increase in flaw size or growth rate greater than predicted for the service life of the flywheel, the results of the examination and evaluation should be submitted to the NRC for evaluation.

2. The detection of flaws that exceed the acceptance criteria standards shall be coordinated with the requirements of the Maintenance Rule Program.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10 CFR 50.59 Review and a Station Qualified Review (SQR).

The SQR composition shall include Regulatory Assurance Department in all cases. As a part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager. Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and was determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 5 of 5 Revision 71 Technical Requirements Manual

TRM Appendix H Revision 96 deleted this Appendix BRAIDWOOD UNITS 1 & 2 1 of 1 Revision 96 Technical Requirements Manual

TRM Steam Generator Program Appendix I STEAM GENERATOR PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 9 Revision 101 Technical Requirements Manual

TRM Steam Generator Program Appendix I 1.1 PURPOSE This Program verifies the tube integrity of the Steam Generators (SGs) by performing inspections and tube plugging in accordance with Technical Specification (TS) 3.4.19, Steam Generator (SG)

Tube Integrity, and the Steam Generator Program. The Steam Generator Program is defined by TS 5.5.9, NEI 97-06 and its associated EPRI Steam Generator Management Program Guidelines.

TS 5.6.9, Steam Generator (SG) Tube Inspection Reports, provides the SG reporting requirements.

1.2 REFERENCES

1. Technical Specifications:

a. 5.5.9, "Steam Generator (SG) Program"

b. 5.6.9, "Steam Generator (SG) Tube Inspection Reports"

c. 3.4.13, "RCS Operational LEAKAGE"

d. 3.4.19, Steam Generator (SG) Tube Integrity

2. Updated Final Safety Analysis Report Sections:

a. 5.4.2, "Steam Generators"

b. 15.1.5, "Steam System Piping Failure"

c. 15.6.3, "Steam Generator Tube Rupture"

3. Exelon Generation Company, LLC, Quality Assurance Topical Report

4. ASME Boiler and Pressure Vessel Code:

a.Section V, Nondestructive Examination, latest approved Edition and Addenda

b.Section XI, Rules for Inservice Inspection of Nuclear Power Plant Components, latest approved Edition and Addenda

5. American Society for Nondestructive Testing (ASNT):

"Standard for Qualification and Certification of Nondestructive Testing Personnel, CP-189, 1995 Edition" BRAIDWOOD UNITS 1 & 2 2 of 9 Revision 101 Technical Requirements Manual

TRM Steam Generator Program Appendix I

6. General Design Criteria (GDC) of Appendix A to 10CFR50:

a. GDC-14

b. GDC-15

c. GDC-30

d. GDC-31

e. GDC-32

7. Nuclear Energy Institute (NEI) Technical Specification Task Force (TSTF) Standard Technical Specification Change Traveler:

a. TSTF-449, Revision 4

b. TSTF-510, Revision 2

8. Draft Regulatory Guide 1.121, "Bases for Plugging Degraded PWR Steam Generator Tubes"

9. Maintenance Rule Performance Criteria RC-2, Remove Heat from Reactor to Steam Generators Including Steam Generator Integrity

10. NEI 97-06 Steam Generator Program Guidelines

11. EPRI PWR Steam Generator Examination Guidelines

12. EPRI Primary to Secondary Leak Guidelines

13. EPRI Steam Generator Integrity Guidelines

14. EPRI Steam Generator In Situ Pressure Test Guidelines

15. EPRI Steam Generator Secondary Water Chemistry Guidelines

16. EPRI Steam Generator Primary Water Chemistry Guidelines 1.3 DEFINITIONS AND/OR ACRONYMS

1. IMPERFECTION - An exception to the dimensions, finish or contour of a tube from that required by fabrication drawings or specifications. Eddy current testing indications !20% of the nominal wall thickness, if detectable, may be considered as imperfections.

BRAIDWOOD UNITS 1 & 2 3 of 9 Revision 101 Technical Requirements Manual

TRM Steam Generator Program Appendix I

2. DEGRADATION - A service induced cracking, wastage, wear or general corrosion occurring on either inside or outside of a tube.

3. DEGRADED TUBE - A tube containing imperfections 20% of the nominal tube wall thickness caused by degradation.

4. DEFECT - An imperfection of such severity that it exceeds the plugging limit. A tube containing a defect is defective.

5. PLUGGING LIMIT- The imperfection depth at or beyond which the tube shall be removed from service by plugging. The plugging limit imperfection depth for the tubing is equal to 40% of the nominal wall thickness.

For Unit 2 only, this definition does not apply to service-induced flaws identified in the portion of the tube below 14.01 inches from the top of the tubesheet. Service-induced flaws found in the portion of the tube below 14.01 inches from the top of the tubesheet do not require plugging.

For Unit 2 only, service-induced flaws identified in the portion of the tube from the top of the tubesheet to 14.01 inches below the top of the tubesheet shall be plugged upon detection.

6. Deleted.

BRAIDWOOD UNITS 1 & 2 4 of 9 Revision 101 Technical Requirements Manual

TRM Steam Generator Program Appendix I

7. DEGRADATION ASSESSMENT - An assessment of degradation performed prior to an upcoming outage to determine the type and location of flaws to which the tubes may be susceptible and to determine which inspection methods need to be employed and at what locations. The assessment includes appropriate inspection plans, inspection methods and inspection intervals for the applicable degradation mechanisms identified.

8. CONDITION MONITORING - An evaluation of the as found condition of the tubing during a SG inspection outage with respect to the performance criteria for structural integrity and accident induced leakage prior to the plugging of tubes.

9. OPERATIONAL ASSESSMENT - An evaluation that projects the condition of the tubes from the as-left condition exiting a SG inspection outage to the next SG inspection with respect to the performance criteria for structural integrity and accident induced leakage following plugging of tubes.

1.4 PROGRAM DESCRIPTION This Program verifies the tube integrity of the SGs through periodic eddy current inspections. The Bases for this Program and TS Section were established by NEI TSTF-449 & TSTF-510 (References 7.a & 7.b) and NEI 97-06 (Reference 10) and its referenced EPRI Guidelines (References 11 through 16). The SG Program provides a means to detect and plug degradation of SG tubes in order to maintain the steam generator performance criteria for tube structural integrity, accident induced leakage, and operational leakage as delineated in TS 5.5.9 and NEI 97-06.

1.5 PROGRAM IMPLEMENTATION A SG Program has been established and implemented to ensure that SG tube integrity is maintained. The SG Program is implemented through Exelon SG Program administrative and surveillance procedures to ensure compliance with the requirements of TS 3.4.19, TS 5.5.9, NEI 97-06 and its associated EPRI Guidelines.

The SG Program includes the following provisions:

BRAIDWOOD UNITS 1 & 2 5 of 9 Revision 101 Technical Requirements Manual

TRM Steam Generator Program Appendix I

1. Condition monitoring assessments are performed during each SG inspection to evaluate the as-found condition of the tubes with respect to the SG performance criteria for structural integrity and accident induced leakage as determined from the inservice inspection results.

2. SG integrity is maintained by meeting the performance criteria for tube structural integrity, accident induced leakage and operational leakage. The SG Program procedures implement the performance criteria that are delineated in TS 5.5.9.b and NEI 97-06. Meeting the SG performance criteria provides reasonable assurance of maintaining tube integrity at normal and accident conditions.

3. Tubes found by inservice inspection that contain flaws that are equal to or greater than 40% of the nominal tube wall thickness are plugged. For Unit 2 only, service-induced flaws identified in the portion of the tube from the top of the tubesheet to 14.01 inches below the top of the tubesheet are plugged upon detection. For Unit 2 only, service-induced flaws found in the portion of the tube below 14.01 inches from the top of the tubesheet do not require plugging.

4. Periodic SG tube inspections are performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging criteria. For Unit 2 only, the portion of the tube below 14.01 inches from the top of tubesheet is excluded. The tube-to-tubesheet weld is not part of the tube. The inspection scope, inspection methods and inspection intervals are determined by a degradation assessment that is performed in accordance with TS 5.5.9.d and NEI 97-06 to ensure that SG integrity is maintained until the next SG inspection.

BRAIDWOOD UNITS 1 & 2 6 of 9 Revision 101 Technical Requirements Manual

TRM Steam Generator Program Appendix I

5. Operational primary-to-secondary leakage monitoring is performed in accordance with TS 3.4.13, NEI 97-06 and EPRI Primary to Secondary Leak Guidelines (Reference 12).

6. There are no approved tube repair methods for the Units 1 and 2 SGs.

The Engineering Programs Department is the owner of the SG Program. The site Chemistry and Operations Departments are responsible for monitoring and responding to operational primary to secondary leakage. The site Chemistry Department is responsible for implementing the primary water and secondary water chemistry programs as described in References 15 and 16.

1.6 ACCEPTANCE CRITERIA

1. A tube with an imperfection depth greater than or equal to 40% of the nominal tube wall thickness shall be plugged.

For Unit 2 only, service-induced flaws found in the portion of the tube below 14.01 inches from the top of the tubesheet do not require plugging.

For Unit 2 only, service induced flaws identified in the portion of the tube from the top of the tubesheet to 14.01 inches below the top of the tubesheet shall be plugged upon detection.

2. Deleted.

3. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage and operational leakage as delineated in TS 5.5.9.b.

4. For Unit 1, the maximum equivalent plugging level is 5% per SG.

5. For Unit 2, the maximum equivalent plugging level is 5% per SG.

BRAIDWOOD UNITS 1 & 2 7 of 9 Revision 101 Technical Requirements Manual

TRM Steam Generator Program Appendix I 1.7 LCOARS/COMPENSATORY MEASURES

1. If a SG performance criterion is exceeded, reports shall be submitted to the NRC as required by 10 CFR 50.72 and 50.73, including a Corrective Action Program investigation identifying the performance criterion exceeded and an Operational Assessment establishing the basis for the next operating cycle.

2. The Shift Manager shall be notified immediately for any of the conditions identified below. The Shift Manager shall determine OPERABILITY status and implement a LCOAR as applicable. In addition, an Issue Report (IR) may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

a. Primary-to-secondary leakage not within limit.

b. One or more SG tubes satisfying the tube plugging criteria and not plugged in accordance with the SG Program.

c. A SG performance criterion is exceeded.

d. SG Tube integrity is not maintained.

1.8 REPORTING REQUIREMENTS

1. Following each inservice inspection of SG tubes performed in accordance with TS 5.5.9, a report of inspection results shall be submitted to the NRC within 180 days after initial entry into MODE 4 in accordance with TS 5.6.9.

2. An inservice summary report shall be submitted to the NRC and IEMA within 90 days of the completion of each refueling outage when SG inspections are performed, as required by ASME Section XI IWA-6000.

3. The Steam Generator Surveillance Program effectiveness is monitored by Maintenance Rule Criteria RC-2.

The Engineering Programs Department is responsible for preparing and submitting the above reports.

BRAIDWOOD UNITS 1 & 2 8 of 9 Revision 101 Technical Requirements Manual

TRM Steam Generator Program Appendix I 1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10CFR50.59 Review and a Station Qualified Review (SQR).

The SQR composition shall include Regulatory Assurance Department in all cases. As a part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager. Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and was determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 9 of 9 Revision 101 Technical Requirements Manual

TRM Secondary Water Chemistry Program Appendix J SECONDARY WATER CHEMISTRY PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 5 Revision 1 Technical Requirements Manual

TRM Secondary Water Chemistry Program Appendix J 1.1 PURPOSE In accordance with Technical Specification (TS) 5.5.10, "Secondary Water Chemistry Program." This Program provides controls for monitoring secondary water chemistry in order to inhibit steam generator tube degradation.

1.2 REFERENCES

1. Technical Specification 5.5.10, "Secondary Water Chemistry Program"

2. UFSAR Section 5.4.2.1.3, and 10.3.3

3. Electric Power Research Institute, PWR Secondary Water Chemistry Guidelines

4. Westinghouse Guidelines for Secondary Water Chemistry, February, 1985 1.3 DEFINITIONS AND/OR ACRONYMS

1. SECONDARY SYSTEM CHEMISTRY PARAMETERS - Chemical impurities in the secondary system have the potential to create conditions harmful to steam generator materials. Carefully controlling steam generator chemistry parameters minimizes material degradation.

Parameters that cause rapid corrosion cannot be exceeded for more than brief periods at power. Power reductions or shutdown is required within set times of exceeding limits on these critical parameters.

2. Pressurized Water Reactor - PWR 3, Electric Power Research Institute - EPRI

4. Institute of Nuclear Power Operations - INPO BRAIDWOOD UNITS 1 & 2 2 of 5 Revision 1 Technical Requirements Manual

TRM Secondary Water Chemistry Program Appendix J 1.4 PROGRAM DESCRIPTION The Secondary Chemistry Monitoring Program states chemical parameters which can indicate corrosive conditions and provides concentration limits for each parameter. These secondary chemistry guidelines were derived from Reference 3. Station procedures outline who is responsible for what actions and describes how other documents interact with this Program.

This Program provides controls for monitoring secondary water chemistry to inhibit Steam Generator tube degradation. The Program includes:

1. identification of a sampling schedule for critical variables and control points for these variables;

2. identification of the procedures used to measure the values of the critical variables;

3. identification of process sampling points which shall include monitoring the discharge of the condensate pumps for evidence of condenser inleakage;

4. procedures for the recording and management of data;

5. procedures defining corrective actions for all out of specification chemistry conditions; and

6. procedures identifying the authority responsible for the interpretation of the data and the sequence and timing of corrective actions.

1.5 PROGRAM IMPLEMENTATION The requirements of the Program apply at all times.

1. The sampling schedule for the critical variables and control points for these variables is located in appropriate station procedures. The department responsible for this action is the Chemistry Department.

2. A means to measure the values of the critical variables will be located in appropriate station procedures. The Chemistry Department is responsible for revising and implementing these procedures.

BRAIDWOOD UNITS 1 & 2 3 of 5 Revision 1 Technical Requirements Manual

TRM Secondary Water Chemistry Program Appendix J

3. Process sampling points are identified in appropriate station procedures and include the condensate pump discharge for evidence of a condenser leak. The Chemistry Department maintains a sample point book which contains additional sampling points. The Chemistry Department is responsible for this action.

4. The recording and management of the data is controlled by appropriate station procedures and is the responsibility of the Chemistry Department.

5. The definitions for corrective actions for all out of specification chemistry conditions are in appropriate station procedures and are the responsibility of the Chemistry Department with support from the Operations and Radiation Protection Departments.

6. The Chemistry Department shall be responsible for the interpretation of the data and the sequence and timing of corrective actions. This shall be performed with required support from the Operating, Radiation Protection, and System Engineering Departments.

1.6 ACCEPTANCE CRITERIA This Program is based on Reference 3 and acceptance criteria are incorporated into appropriate station procedures.

1.7 LCOARS/COMPENSATORY MEASURES The compensatory measures for exceeding secondary water chemistry parameters can be identified in appropriate station procedures.

In addition, a Problem Identification Form (PIF) may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

BRAIDWOOD UNITS 1 & 2 4 of 5 Revision 1 Technical Requirements Manual

TRM Secondary Water Chemistry Program Appendix J 1.8 REPORTING REQUIREMENTS To assure corporate and station steam generator chemistry objectives are met, an ongoing review of secondary water chemistry will be conducted by the Chemistry Department. The Chemistry Supervisor and/or their designee is responsible for a monthly review of key program parameters, chosen by the Chemistry Supervisor and /or their designee. The Program's effectiveness will be measured against recognized industry standards, such as INPO standards (or other comparable standards).

The Chemistry Department is additionally responsible for reporting and reviewing programmatic failures through an approved station problem identification process.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall require a 10CFR50.59 evaluation and an Independent Technical Review (ITR). The ITR composition shall include Regulatory Assurance in all cases. As a part of the ITR, for a change to this Program, concurrence from Byron and Braidwood Plant Operations Review Committee (PORC) approval is required. The concurrence shall be that Byron is implementing the same change or that the change has been reviewed and determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 5 of 5 Revision 1 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K VENTILATION FILTER TESTING PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA

1. 7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 &2 1 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K 1.1 PURPOSE The purpose of this Program is to provide guidelines for performing surveillance testing of Technical Specification (TS) 5.5.11, "Ventilation Filter Testing Program (VFTP)" HVAC System Filters at Braidwood Station.

1.2 REFERENCES

1. Technical Specification Section 5.5.11, "Ventilation Filter Testing Program (VFTP)"

2. USNRC Regulatory Guide 1.52, Rev. 2, March 1978

3. ANSI N510 1980

4. ASTM D 3803-1989, "Standard Test Method for Nuclear Grade Activated Carbon"

5. UFSAR Appendix A 1.3 DEFINITIONS AND/OR ACRONYMS

1. Ventilation Filter Testing Program - VFTP

2. High Efficiency Particulate Air - HEPA 1.4 PROGRAM DESCRIPTION This Program implements the following required testing of Engineered Safety Feature (ESF) ventilation filter systems at the frequencies specified in accordance with References 2 and 3.

1. Demonstrate for each of the ESF filter systems that an in-place test of the High Efficiency Particulate Air (HEPA) filters shows a penetration when tested in accordance with References 2 and 3 at the system flow rate, specified in Table 1, Part 1.

2. Demonstrate for each of the ESF filter systems that an in place test of the charcoal absorber shows a bypass leakage within limits when tested in accordance with References 2 and 3 at the system flow rated specified in Table l, Part 2.

BRAIDWOOD UNITS 1 &2 2 of 15 Revision 65 Technical Requirements Manual

T~

Ventilation Filter Testing Program Appendix K

3. Demonstrate for each of the ESF filter systems that a laboratory test of a sample of the charcoal absorber, when obtained as described in Reference 2, shows the methyl iodide penetration less than the value specified in Table 1, Part 3, when tested in accordance with References 2, 3 and 4 at a temperature of 30°C and Relative Humidity (RH) specified in Table 1, Part 3.

4. Demonstrate for each of the ESF filter systems that the pressure drop across the combined HEPA filters and the charcoal adsorbers is < 6 inches of water gauge when tested in accordance with References 2 and 3 at the system flow rate, specified in Table 1, Part 4.

5. Demonstrate for each of the ESF filter systems that a bypass leakage test of the 1) combined HEPA filters and damper or

2) combined charcoal filter and damper leakage shows a total bypass leakage within acceptable limits at the system flow rate specified in Table 1, Part 5.

6. Demonstrate that the heaters for each of the ESF filter systems dissipate the value specified in Table 1, Part 6, when tested in accordance with References 3 and 5.

1.5 PROGRAM IMPLEMENTATION Technical Section Filter Testing. Inspection and Repair

1. Control Room Ventilation (VC) System:

a. At least once per 18 months (+ 25% tolerance) or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housing, or (2) following painting, fire or chemical release in any ventilation zone communicating with the Emergency Makeup System filter plenum shall meet the following requirements:

1. Verify that each HEPA and charcoal bank satisfies the inplace penetration testing acceptance criteria of less than 0.05% and less than 1.0%, respectively; and that the system flow rate is ~ 5400 cfm and ~ 6600 cfm for the Emergency Makeup System using test procedure guidance in accordance with References 2 and 3; BRAIDWOOD UNITS 1 &2 3 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K

2. Verify, within 31 days (+ 25% tolerance) after removal, that a laboratory analysis of a representative carbon sample from the Emergency Makeup System obtained in accordance with Reference 2 meets the laboratory testing criteria for a methyl iodide penetration of less than 2.0% when tested according to Reference 4 at a temperature of 30 °C and a RH of 70%; and

3. Verify a system flow rate of~ 5400 cfm and

~ 6600cfm for the Emergency Makeup System and

~ 44,550 cfm and ~ 54,450 cfm for the Recirculation System when tested in accordance with Reference 3.

b. After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months (+ 25% tolerance) of Emergency Makeup System operation, verify, within 31 days (+ 25%

tolerance) after removal, that a laboratory analysis of a representative carbon sample from the Emergency Makeup System obtained in accordance with Reference 2, meets the laboratory testing criteria for a methyl iodide penetration of less than 2.0% when tested according to Reference 4 at a temperature of 30°C and a RH of 70%.

c. At least once per 18 months (+ 25% tolerance) by:

1. verifying the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 6.0 inches Water Gauge while operating the Emergency Makeup System at a flow rate of~ 5400 cfm and ~ 6600 cfm when tested in accordance with References 2 and 3.

2. verifying that the heaters dissipate~ 24.5 kW and ~ 29.9 kW when tested in accordance with Reference 3 and the exceptions noted in Reference 5.

BRAIDWOOD UNITS 1 &2 4 of 15 Revision 65 Technical Requirements Manual

T~

Ventilation Filter Testing Program Appendix K

d. After each complete or partial replacement of a HEPA filter bank in the Emergency Makeup System, verify that the affected HEPA filter bank satisfies the inplace penetration testing acceptance criteria of less than 0.05% in accordance with Reference 3 while operating the Emergency Makeup System at a flow rate of ~ 5400 cfm and ~ 6600 cfm.

e. After each complete or partial replacement of a charcoal adsorber bank in the Emergency Makeup System, verify that the affected charcoal adsorber bank satisfies the inplace penetration testing acceptance criteria of less than 1% in accordance with Reference 3 while operating the system at a flow rate of~ 5400 cfm and ~ 6600 cfm.

f. At least once per 18 months (+ 25% tolerance) or (1) after any structural maintenance on the charcoal adsorber housings, or (2) following painting, fire or chemical release in any ventilation zone communicating with the recirculation charcoal adsorber by:

BRAIDWOOD UNITS 1 &2 5 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K

1. verifying that the recirculation charcoal adsorber plenum satisfies the inplace penetration testing acceptance criteria of less than 2% total bypass, using the test procedure guidance in accordance with References 2 and 3, while the system flow rate is ~ 44,550 cfm and

~ 54,450 cfm for the recirculation charcoal adsorber;

2. verifying, within 31 days (+ 25% tolerance) after removal, that a laboratory analysis of a representative carbon sample from the recirculation charcoal adsorber obtained in accordance with Reference 2 meets the laboratory testing criteria for a methyl iodide penetration of less than 4% when tested according to Reference 4 at a temperature of 30 °C and a RH of 70%; and

3. verifying a system flow rate of~ 44,550 cfm and

~ 54,450 cfm for the Recirculation Charcoal Adsorber when tested in accordance with Reference 3.

g. After each complete or partial replacement of a charcoal adsorber bank in the Recirculation Charcoal Absorber System by verifying that the charcoal adsorber bank satisfies the inplace penetration testing acceptance criteria of less than 0.1% in accordance with Reference 3 while operating at a system flow rate of~ 44,550 cfm and ~ 54,450 cfm.

h. After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months (+ 25% tolerance) of Recirculation Charcoal Adsorber System operation by verifying, within 31 days (+ 25% tolerance) after removal, that a laboratory analysis of a representative carbon sample obtained in accordance with Reference 2, meets the laboratory testing criteria for a methyl iodide penetration of less than 4% when tested according to Reference 4 at a temperature of 30°C and a RH of 70%.

BRAIDWOOD UNITS 1 & 2 6 of 15 Revision 65 Technical Requirements Manual

T~

Ventilation Filter Testing Program Appendix K

2. Non-Accessible Area Exhaust Filter Plenum Ventilation System:

a. At least once per 18 months (+ 25% tolerance) or Cl) after any structural maintenance on the HEPA filter or charcoal adsorber housing, or (2) following painting, fire or chemical release in any ventilation zone communicating with the exhaust filter plenum by:

1. verifying that each HEPA and charcoal bank satisfies the inplace penetration and bypass leakage testing acceptance criteria of less than 1%, using the test procedure guidance in accordance with References 2 and 3, while the flow rate is ~ 60,210 cfm and $ 73,590 cfm for the train;

2. verifying, within 31 days C+ 25%

tolerance) after removal, that a laboratory analysis of a representative carbon sample from each bank of adsorbers of the train obtained in accordance with Reference 2 meets the laboratory testing criteria for a methyl iodide penetration of less than 4.5% (and administratively controlled to less than 3% to accommodate total bypass leakage margin) when tested according to Reference 4 at a temperature of 30 °C and a RH of 70%; and

3. verifying a system flow rate of ~ 60,210 cfm and $ 73,590 cfm through the train through the exhaust filter plenum when tested in accordance with Reference 3.

4. verifying that with 2 of 3 trains operatin at a flow rate of~ 60,210 cfm and

$ 73,590 cfm for each train and exhausting through the HEPA filters and charcoal adsorbers, with 2 main VA supply and 2 main VA exhaust fans operating, the total charcoal bypass flow of the system including damper bypass leakage at an additional 0.5 inches water gauge differential pressure above actual differential pressure for all three train Ctwo on-line and one in standby) is less than or equal to 4%.

BRAIDWOOD UNITS 1 &2 7 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K

5. verifying that with 2 of 3 trains operatin at a flow rate of ~ 60,210 cfm and

~ 73,590 cfm for each train and exhausting through the HEPA filters and charcoal adsorbers, with 2 main VA supply and 2 main VA exhaust fans operating, the total HEPA bypass flow of the system including damper bypass leakage at an additional 0.5 inches wter gauge differential pressure above actual differential pressure for all three train (two on-line and one in standby) is less than or equal to 1%.

6. verifying, with a system flow of~ 60,210 cfm and ~ 73,590 cfm through the train and exhaust filter plenum, that the flow rate in each filter bank is ~ 20,070 cfm and

~ 24,530 cfm.

b. After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months (+25% tolerance) of charcoal adsorber operation by verifying, within 31 days (+ 25%

tolerance) after removal, that a laboratory analysis of a representative carbon sample obtained from each bank of adsorbers of the train in accordance with Reference 2, meets the laboratory testing criteria for a methyl iodide penetration of less than an average of 4.5% (and administratively controlled to less than 3%

to accorrmodate total bypass leakage margin) when I

tested according to Reference 4 at a temperature of 30°C and a RH 70%.

c. At least once per 18 months (+25% tolerance) by verifying for each filter bank of the train that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 6.0 inches Water Gauge while operating the exhaust filter plenum at a flow rate of~ 60,210 cfm and ~ 73,590 cfm when tested in accordance with References 2 and 3.

d. After each complete or partial replacement of a HEPA filter bank by verifying that the exhaust filter plenum satisfies the inplace penetration testing acceptance criteria of less than 1% in accordance with Reference 3 while operating at a flow rate of~ 60,210 cfm and ~ 73,590 cfm through the train.

BRAIDWOOD UNITS 1 &2 8 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K

e. After each complete or partial replacement of a charcoal adsorber bank by verifying that the exhaust filter plenum satisfies the inplace penetration testing acceptance criteria of less than 1% in accordance with Reference 3 while operating at a system flow rate of~ 60,210 cfm and ~ 73,590 cfm through the train.

3. Fuel Handling Building Exhaust Filter Plenums:

a. At least once per 18 months (+ 25% tolerance) or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housing, or (2) following painting, fire or chemical release in any ventilation zone communicating with the system by:

1. verifying that the Fuel Handling Building Exhaust Filter Plenum satisfies the inplace penetration testing acceptance criteria of less than 1% when using the test procedure guidance in accordance with References 2 and 3 while the system flow rate is~ 18,900 cfm and~ 23,100 cfm;

2. verifying, within 31 days (+ 25%

tolerance) after removal, that a laboratory analysis of a representative carbon sample obtained in accordance with Reference 2 meets the laboratory testing criteria for a methyl iodide penetration of less than 10% when tested according to Reference 4 at a temperature of 30 °C and a RH of 95%;

3. verifying a flow rate of~ 18,900 cfm and

~ 23,100 cfm through the Fuel Handling Building Exhaust Filter Plenum during operation when tested in accordance with Reference 3; and BRAIDWOOD UNITS 1 &2 9 of 15 Revision 65 Technical Requirements Manual

T~

Ventilation Filter Testing Program Appendix K

4. verifying that with the system operating at a flow rate of~ 18,900 cfm and $

23,100 cfm and exhausting through the HEPA filters and charcoal adsorbers, with 2 main VA supply and 2 main VA exhaust fans operating, the total HEPA bypass flow of the system including damper bypass leakage at an additional 0.5 inches water gauge differential pressure above actual differential pressure is less than or equa to 1% and the total charcoal bypass flow o the system including damper bypass leakage is less than or equal to 1%.

b. After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months (+25% tolerance) of charcoal adsorber operation by verifying, within 31 days (+ 25%

tolerance) after removal, that a laboratory analysis of a representative carbon sample obtained in accordance with Reference 2, meets the laboratory testing criteria for a methyl iodide penetration of less than 10% when tested according to Reference 4 at a temperature of 30°C and a RH of 95%.

c. At least once per 18 months (+25% tolerance) by verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 6.0 inches Water Gauge while operating the exhaust filter plenum at a flow rate of ~ 18,900 cfm and $

23,100 cfm when tested in accordance with References 2 and 3.

d. After each complete or partial replacement of a HEPA filter bank by verifying that the Fuel Handling Building Exhaust Filter Plenum satisfies the inplace penetration testing acceptance criteria of less than 1% in accordance with Reference 3 while operating at a system flow rate of~ 18,900 cfm and $ 23,100 cfm; and

e. After each complete or partial replacement of a charcoal adsorber bank by verifying that the Fuel Handling Building Exhaust Filter Plenum satisfies the inplace penetration testing acceptance criteria of less than 1% in accordance with Reference 3 while operating at a system flow rate of~ 18,900 cfm and$

23,100 cfm.

BRAIDWOOD UNITS 1 &2 10 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K 1.6 ACCEPTANCE CRITERIA Acceptance criteria is listed in Table 1.

1.7 LCOARS/COMPENSATORY MEASURES In the event any of the acceptance criteria is not met, the Shift Manager will irrrnediately be notified. The Shift Manger shall determine OPERABILITY status and implement a LCOAR as applicable.

In addition, an Issue Report may be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

1.8 REPORTING REQUIREMENTS Not applicable.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall require a 10 CFR 50.59 Review and a Station Qualified Review CSQR). The SOR composition shall include Regulatory Assurance Department in all cases. As a part of the SOR, Byron and Braidwood Plant Operations Review Corrrnittee CPORC) approval is required as determined by the Regulatory Assurance Manager. Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and was determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 &2 11 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K TABLE 1 VENTILATION FILTER TESTING PROGRAM CVFTP)

Part 1 ESF Ventilation Flow Rate Penetration System Control Room ~ 5400 cfm and <0.05%

Ventilation CVC) ~ 6600 cfm Filtration System (makeup)

Nonaccessable Area ~ 60,210 cfm and < 1%

Exhaust Filter ~ 73,590 cfm per Plenum Ventilation train, and System (after ~ 20,070 cfm and structural ~ 24,530 cfm per maintenance of the bank HEPA filter housings)

Nonaccessible Area ~ 60,210 cfm and < 1%

Exhaust Filter ~ 73,590 cfm per Plenum Ventilation train System (for reasons other than structural maintenance of the EPA filter housings)

Fuel Handling ~ 18,900 cfm and < 1%

Building Exhaust ~ 23,100 cfm Filter Plenum CFHB)

Ventilation System BRAIDWOOD UNITS 1 &2 12 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K Part 2 ESF Ventilation S~stem Flow Rate B~pass VC Filtration System ; : : 5400 cfm and < 1%

(makeup) ~ 6600 cfm VC Filtration System ; : : 44,550 cfm < 0.1%

(recirculation, charcoal and bed after complete or ~ 54,450 cfm partial replacement)

Nonaccessible Area ; : : 60,210 cfm < 1%

Exhaust Filter Plenum and Ventilation System (after ~ 73,590 cfm structural maintenance of per train, and the charcoal adsorber ; : : 20,070 cfm housings) and

~ 24,530 cfm per bank Nonaccessible Area ; : : 60,210 cfm < 1%

Exhaust Filter Plenum and Ventilation System (for ~ 73,590 cfm reasons other than per train structural maintenance of the charcoal adsorber housings)

FHB Ventilation System ; : : 18,900 cfm < 1%

and

~ 23,100 cfm per train BRAIDWOOD UNITS 1 &2 13 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K Part 3 ESF Ventilation S~stem Penetration RH VC Filtration System 2.0% 70%

(makeup)

VC Filtration System 4% 70%

(recirculation)

Nonaccessible Area Exhaust 4.5% 70%

Filter Plenum Ventilation System FHB Ventilation System 10% 95%

Part 4 EFS Ventilation S~stem Fl ow Rate VC Filtration System ~ 5400 cfm and (makeup) ~ 6600 cfm Nonaccessible Area ~ 60,210 cfm and Exhaust Filter Plenum ~ 73,590 cfm per train Ventilation System FHB Ventilation System ~ 18,900 cfm and

~ 23,100 cfm BRAIDWOOD UNITS 1 &2 14 of 15 Revision 65 Technical Requirements Manual

TRM Ventilation Filter Testing Program Appendix K Part 5 ESF Ventilation System Flow Rate Bypass Nonaccessible Area ~ 60, 210 cfm and ~ 1% (HEPA)

Exhaust Filter Plenum ~ 73,590 cfm per

~ 4% (Charcoal)

Ventilation System on-line train FHB Ventilation System ~ 18,900 cfm and ~ 1%

~ 23,100 cfm VC Filteration System ~ 44,550 cfm < 2%

(recirculation for and reasons other than ~ 54,450 complete or partial charcoal bed replacement)

Part 6 ESF Ventilation System Wattage VC Filtration System ~ 24.5 kW and ~ 29.9 kW BRAIDWOOD UNITS 1 &2 15 of 15 Revision 65 Technical Requirements Manual

TRM Explosive Gas & Storage Tank Radioactivity Monitoring Program Appendix L EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 7 Revision 44 Technical Requirements Manual

TRM Explosive Gas & Storage Tank Radioactivity Monitoring Program Appendix L 1.1. PURPOSE In accordance with Technical Specification (TS) Specification 5.5.12, "Explosive Gas and Storage Tank Radioactive Monitoring Program". This Program provides controls for:

1. potentially explosive gas mixtures contained in the Waste Gas System;

2. the quantity of radioactivity contained in gas decay tanks; and

3. the quantity of radioactivity contained in unprotected outdoor liquid radwaste storage tanks.

The requirements of this Program dictate the contents of the implementing procedures.

1.2 REFERENCES

1. TS Specification 5.5.12, "Explosive Gas and Storage Tank Radioactivity Monitoring Program"

2. UFSAR Section 11.3.2.6

3. ODCM

4. Standard Review Plan 11.3, Branch Technical Position (BTP)

ETSB 11-5, "Postulated Radioactive Release due to Waste Gas System Leak or Failure," in NUREG-0800, July 1981

5. 10CFR20, Appendix B, Table 2, Column 2

6. General Design Criterion 60 of Appendix A to 10CFR50 BRAIDWOOD UNITS 1 & 2 2 of 7 Revision 44 Technical Requirements Manual

TRM Explosive Gas & Storage Tank Radioactivity Monitoring Program Appendix L 1.3 DEFINITIONS AND/OR ACRONYMS A WASTE GAS HOLDUP SYSTEM - Any system designed and installed to reduce radioactive gaseous effluents by collecting Reactor Coolant System off-gases from the Reactor Coolant System and providing for delay or holdup for the purpose of reducing the total radioactivity prior to release to the environment.

PRIMARY COOLANT DEGASSING OPERATION - When preparing the plant for MODE 5 prior to MODE 6, the Reactor Coolant is degassed to reduce the hydrogen concentrations. At the start of the degassing operation, the Volume Control Tank (VCT) gas space contains hydrogen and traces of fission gases. The operation involves opening the VCT vent, raising VCT water level to force gasses out of the tank, and closing the VCT vent.

MEMBER(S) OF THE PUBLIC - Include all persons who are not occupationally associated with the plant. This category does not include employees of the licensee, its contractors or vendors and persons who enter the site to service equipment or to make deliveries. This category does include persons who use portions of the site for recreational, occupational, or other purposes not associated with the plant.

The SITE BOUNDARY - Be that line beyond which the land is neither owned, nor leased, nor otherwise controlled by the licensee.

IMMEDIATELY - That the Required Actions should be pursued without delay and in a controlled manner.

1.4 PROGRAM DESCRIPTION This Program ensures that the concentration of potentially explosive gas mixtures contained in the WASTE GAS HOLDUP SYSTEM is maintained below the flammability limits for hydrogen and oxygen.

Sample instruments with alarms are provided to alert operators to take compensatory measures to prevent the hydrogen and oxygen concentrations from reaching flammability limits. 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 Reference 6.

BRAIDWOOD UNITS 1 & 2 3 of 7 Revision 44 Technical Requirements Manual

TRM Explosive Gas & Storage Tank Radioactivity Monitoring Program Appendix L Restricting the quantity of radioactivity contained in each gas decay tank provides assurance that in the event of an uncontrolled release of the tank's contents, the resulting whole body exposure to a MEMBER OF THE PUBLIC at the nearest SITE BOUNDARY will not exceed 0.5 rem. This is consistent with Reference 4.

The quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tank's contents and that do not have tank overflows and surrounding area drains connected to the liquid radwaste treatment system is an amount that would result in concentrations less than the limits of Reference 5, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tank's contents.

The Radiation Protection Department shall be the Program owner with required support from the Operating, Chemistry, and System Engineering Departments.

1.5 PROGRAM IMPLEMENTATION The requirements of this Program apply at all times.

1. The concentration of hydrogen and oxygen in the WASTE GAS HOLDUP SYSTEM shall be determined to be within the acceptance criteria by continuously monitoring the waste gases in the WASTE GAS HOLDUP SYSTEM with the hydrogen and oxygen monitors required by TRM LCO 3.3.e.

2. The quantity of radioactivity contained in each gas decay tank shall be determined, in accordance with the guidance provided in Reference 4, to be within the acceptance criteria at least once per 7 days when radioactive materials are being added to the tank, and at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months during PRIMARY COOLANT DEGASSING OPERATION.

3. The quantity of radioactive material contained in the Primary Water Storage Tank and any Outside Temporary Tanks shall be determined to be within the acceptance criteria by analyzing a representative sample of the tank's contents at least once per 7 days when radioactive materials are being added to the tank.

BRAIDWOOD UNITS 1 & 2 4 of 7 Revision 44 Technical Requirements Manual

TRM Explosive Gas & Storage Tank Radioactivity Monitoring Program Appendix L If the supply and discharge piping to the Primary Water Storage Tanks are crosstied with flow for a sufficient duration, one sample of the Primary Water Makeup System may be used to represent the contents of each tank.

1.6 ACCEPTANCE CRITERIA

1. Explosive Gas Mixtures The concentration of oxygen in the WASTE GAS HOLDUP SYSTEM shall be 2% by volume whenever the hydrogen concentration is > 4% by volume.

2. Radioactivity Contained in Gas Decay Tanks The quantity of radioactivity contained in each gas decay tank shall be limited to 5 E+04 Curies of noble gases (considered as Xe-133 equivalent).

3. Radioactivity Contained in Unprotected Outdoor Liquid Radwaste Storage Tanks.

The quantity of radioactive material, excluding tritium and dissolved or entrained noble gases, shall be limited to the following:

a. Primary Water Storage Tank 2000 Curies when sampling 0A and 0B Primary Water Storage Tanks individually OR Primary Water Storage Tank 1000 Curies when obtaining one sample representing both tanks with 0A and 0B Primary Water Storage Tanks crosstied

b. Outside Temporary Tank 10 Curies 1.7 LCOARS/COMPENSATORY MEASURES

1. Explosive Gas Mixtures

a. With the concentration of oxygen in the WASTE GAS HOLDUP SYSTEM > 2% by volume but 4% by volume, when hydrogen is > 4% by volume, restore the oxygen concentration to 2% within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

BRAIDWOOD UNITS 1 & 2 5 of 7 Revision 44 Technical Requirements Manual

TRM Explosive Gas & Storage Tank Radioactivity Monitoring Program Appendix L

b. With the concentration of oxygen in the WASTE GAS HOLDUP SYSTEM > 4% by volume and the hydrogen concentration > 4% by volume, IMMEDIATELY suspend all additions of waste gases to the system and reduce the concentration of oxygen to 4% by volume, then restore the oxygen concentration to 2% within the following 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

The department responsible for the above actions is the Operating Department.

2. Radioactivity Contained in Gas Decay Tanks With the quantity of radioactive material in any gas decay tank exceeding the acceptance criteria:

a. IMMEDIATELY suspend all additions of radioactive material to the tank, and within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , reduce the tank contents to within the limit; and

b. describe the events leading to this condition in the next Radioactive Effluent Release Report.

The department responsible for action a is the Operating Department, action b is the responsibility of the Radiation Protection Department.

3. Radioactivity Contained in Unprotected Outdoor Liquid Radwaste Storage Tanks With the quantity of radioactive material in the Primary Water Storage Tank or any Outside Temporary Tank exceeding the acceptance criteria:

a. IMMEDIATELY suspend all additions of radioactive material to the tank;

b. within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months reduce the tank contents to within the acceptance criteria; and

c. describe the events leading to this condition in the next Radioactive Effluent Release Report The Operations Department is responsible for actions a and b, and the Radiation Protection Department is responsible for action c.

BRAIDWOOD UNITS 1 & 2 6 of 7 Revision 44 Technical Requirements Manual

TRM Explosive Gas & Storage Tank Radioactivity Monitoring Program Appendix L The Shift Manager shall determine OPERABILITY status and implement a LCOAR as applicable. A Problem Identification Form (PIF) may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

1.8 REPORTING REQUIREMENTS This Program shall be reviewed every two years for technical accuracy and revision. The review shall be done by the Radiation Protection Department with input from the Operating, Chemistry, and System Engineering Departments.

Program failures shall be reported through an approved station problem identification process. The Operations Department will be responsible for ensuring that Program failures have been reported.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10CFR50.59 evaluation and an Independent Technical Review (ITR). The ITR composition shall include Regulatory Assurance Department in all cases. As a part of the ITR, for a change to this Program, concurrence from Byron and Braidwood Plant Operations Review Committee (PORC) approval is required. The concurrence shall be that Byron is implementing the same change or that the change has been reviewed and determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 7 of 7 Revision 44 Technical Requirements Manual

TRM Diesel Fuel Oil Testing Program Appendix M DIESEL FUEL OIL TESTING PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 9 Revision 103 Technical Requirements Manual

TRM Diesel Fuel Oil Testing Program Appendix M 1.1 PURPOSE The purpose of this Program is to provide guidance for implementation of Diesel Fuel Oil Testing at the Braidwood Station as required by Technical Specification (TS) 5.5.13. This Program, through approved Exelon Nuclear, Braidwood Station, or Vendor procedures, ensures that delivered, new and stored diesel fuel oil meet the appropriate standards.

1.2 REFERENCES

1. Technical Specification 5.5.13, "Diesel Fuel Oil Testing Program"

2. ASTM Standards

a. D5452-98, "Particulate Contamination in Aviation Fuels by Laboratory Filtration,"

b. D1552-95, "Standard Test Method for Sulfur in Petroleum Products (High Temperature Method)"

c. D975-98b, "Standard Specifications for Diesel Fuel Oils"

d. D2622-98, "Standard Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-Ray Fluorescent Spectrometry"

e. D4176-93, "Standard Test Method for Free Water and Particulate Contamination in Distillate Fuels (Visual Inspection Procedures)"

f. D4057-95, "Standard Practice for Manual Sampling of Petroleum and Petroleum Products"

g. D1298-99, "Standard Practice for Density, Relative density (Specific Gravity), or API Gravity of Crude Petroleum and Liquid Petroleum Products by Hydrometer Method"

h. D4294-98, "Standard Test Method for Sulfur in Petroleum Products by Energy-Dispersive X-Ray Fluorescence Spectroscopy"

i. D2709-96e, "Test Method for Water and Sediment in Distillate Fuels by Centrifuge"

j. D1500-98, "Standard Test Method for ASTM Color of Petroleum Products (ASTM Color Scale)"

3. Commitments

a. CM-1, Action Tracking Item 1367498-18-36, License Renewal Fuel Oil Chemistry Aging Management Program (1.5.5, 1.5.6, and Attachment A)

BRAIDWOOD UNITS 1 & 2 2 of 9 Revision 103 Technical Requirements Manual

TRM Diesel Fuel Oil Testing Program Appendix M 1.3 DEFINITIONS AND/OR ACRONYMS

1. DELIVERED DIESEL FUEL - Any diesel fuel being delivered to Braidwood Station which is intended to be used by INSTALLED PLANT EQUIPMENT. Fuel is typically delivered by truck and is either blended at approximately 25% #1 grade and 75% #2 grade, or purchased such that the resultant fuel has an approximate 25% #1 to 75% #2 ratio (i.e. one truck load #1 to three truck loads #2). This blend can be used year-around, but is intended to prevent winter gelling concerns.

Braidwood Station may also specify straight #2 fuel if desired, with optional anti-gel additives utilized for winter considerations. Delivered diesel fuel oil receives a cursory analysis of properties to give confidence that the truck indeed contains diesel fuel oil prior to adding it to any OUTDOOR BULK DIESEL FUEL OIL TANK. If fuel is being delivered using the one truck load #1 to three truck loads #2 method to achieve the blend, it is recognized that the straight #1 fuel parameters may not meet the blend's specification. In this case, the fuel is still accepted since it is known that it will eventually be blended with #2 and the resultant further analyzed before use as described in the definition of "UNCERTIFIED" DIESEL FUEL OIL.

2. "UNCERTIFIED" DIESEL FUEL OIL - Any diesel fuel oil that has not been tested and found to meet the applicable acceptance criteria for grade #2 diesel fuel oil and is to be added, or already is in, the INSTALLED PLANT EQUIPMENT's TANKS or the OUTDOOR BULK DIESEL FUEL OIL TANKS. Fuel in the INSTALLED PLANT EQUIPMENT's TANKS or the OUTDOOR BULK DIESEL OIL TANKS can become "UNCERTIFIED" when samples are not found to meet fuel specification (following analysis of an optional confirmatory sample) or by adding DELIVERED or "UNCERTIFIED" FUEL to the tanks. In the event fuel is "UNCERTIFIED",

actions are taken to either bring the fuel back into specifications and/or prevent the fuel from being used until it is deemed "CERTIFIED".

3. "CERTIFIED" DIESEL FUEL OIL - Diesel fuel oil in any station diesel fuel oil tank which has previously been sampled, analyzed, and found to meet the applicable acceptance criteria for grade #2 diesel fuel oil. This fuel can be stored in either the OUTDOOR BULK DIESEL FUEL OIL TANKS or tanks associated with the INSTALLED PLANT EQUIPMENT. This fuel is periodically sampled and analyzed. See Attachment A for test and test frequency.

BRAIDWOOD UNITS 1 & 2 3 of 9 Revision 103 Technical Requirements Manual

TRM Diesel Fuel Oil Testing Program Appendix M

4. NEW FUEL OIL - Diesel fuel oil that has been sampled and tested in accordance with the requirements of TS 5.5.13 for NEW FUEL OIL. TS 5.5.13 requires specific tests of fuel oil prior to addition to storage tanks, e.g., 1) an API gravity or an absolute specific gravity, 2) a flash point and kinematic viscosity, and 3) a clear and bright appearance with proper color or a water and sediment content. Additional tests are required to verify other properties of NEW FUEL OIL within 30 days following sampling and addition to storage tanks.

For the Emergency Diesel Generators (EDGs), the OUTDOOR BULK DIESEL FUEL OIL TANKS (one 50,000 gal. and one 125,000 gal.) are normally the source of "NEW" FUEL OIL

5. STORED FUEL OIL - Diesel fuel oil that has been sampled and tested in accordance with the requirements of TS 5.5.13 for STORED FUEL OIL. Fuel oil degradation during long term storage shows up as an increase in particulate, due mostly to oxidation. Consequently, TS 5.5.13 requires STORED FUEL OIL to be tested for total particulate concentration every 31 days.

For the EDGs, the inside storage tanks (each Unit 1 EDG is provided with two 25,000 gal. inside storage tanks and each Unit 2 EDG is provided with one 50,000 gal. inside storage tank) are the source of the required "STORED" FUEL OIL.

6. INSTALLED PLANT EQUIPMENT - EDGs, Diesel-driven fire pump, Security diesel generator, Diesel-driven Auxiliary Feedwater pump, Auxiliary boilers (note: Auxiliary boilers burn "CERTIFIED" or "UNCERTIFIED" fuel directly from the OUTDOOR BULK DIESEL FUEL OIL TANKS).

7. OUTDOOR BULK DIESEL FUEL OIL TANKS - Typically called 125K and 50K tanks (OD003T and OD012T respectively). These tanks receive the delivered fuel and store it "UNCERTIFIED" until being "CERTIFIED" through analysis. Once "CERTIFIED" the fuel stored in these tanks is normally used to fill the tanks of the INSTALLED PLANT EQUIPMENT.

BRAIDWOOD UNITS 1 & 2 4 of 9 Revision 103 Technical Requirements Manual

TRM Diesel Fuel Oil Testing Program Appendix M 1.4 PROGRAM DESCRIPTION The Diesel Fuel Oil Testing Program provides guidance for testing DELIVERED, NEW, and STORED DIESEL FUEL OIL. This Program includes sampling and testing requirements as outlined in Attachment A which also may be contained in appropriate procedures, as well as acceptance criteria in accordance with the applicable standards.

This Program also describes preventative maintenance activities that are performed to ensure good fuel quality and tank condition for certain INSTALLED PLANT EQUIPMENT TANKS.

1.5 PROGRAM IMPLEMENTATION This Diesel Fuel Oil Testing Program implements required sampling and analysis of DELIVERED, NEW, and STORED DIESEL FUEL OIL. The Program includes sampling and testing requirements as outlined in Attachment A which also may be contained in appropriate procedures, as well as acceptance criteria, in accordance with applicable standards. This Program also describes preventative maintenance activities that are performed to ensure good fuel quality and tank condition for certain INSTALLED PLANT EQUIPMENT'S TANKS. This Program establishes the following:

1. Other properties of NEW FUEL OIL are within limits within 30 days following sampling in accordance with ASTM D4057-95 and addition to storage tanks;

2. Total particulate concentration of the fuel oil is ! 10 mg/l when tested every 31 days in accordance with ASTM D5452-98.

3. Acceptability (certification) of "UNCERTIFIED" fuel oil and continued certification on a periodic basis in the fuel oil storage tanks by determining that the fuel oil:

a. meets ASTM D975-98b specifications;

b. meets ASTM D5452-98 specification for particulate contamination;

c. meets Illinois EPA sulfur requirements and may be tested in accordance with ASTM D1552-95, ASTM D2622-98, or ASTM D4294-98;

d. a flash point and kinematic viscosity is within limits:

BRAIDWOOD UNITS 1 & 2 5 of 9 Revision 103 Technical Requirements Manual

TRM Diesel Fuel Oil Testing Program Appendix M

e. API specific gravity or an absolute specific gravity within limits when tested in accoradance with ASTM D1298-99;

f. water and sediment when tested in accordance with ASTM D2709-96e is within limits; and

g. a clear and bright appearance with when tested in accordance with ASTM D4176-93, and proper color when tested in accordance with ASTM D1500-98.

Actual testing for each individual tank may vary. The minimum testing schedule is shown in Attachment A. Actual fuel analysis performed is determined within specific Exelon Nuclear, Braidwood Station, or approved Vendor procedures.

4. 10 year OUTDOOR BULK DIESEL FUEL OIL TANK (0DO03T - 125K gallon tank and 0DO12T - 50K gallon tank) cleaning using a Sodium hypochlorite (household bleach) solution or evaluated equivalent; and

5. 10 year EDG tank cleaning using a Sodium Hypochlorite (household bleach) solution or evaluated equivalent (Unit 1 has four 25,000 gallon (1DO01TA/B/C/D) and Unit 2 has two 50,000 gallon (2DO01TA/B) tanks) (CM-1); and

6. Periodic check for and removal of accumulated water from the EDG day tanks (CM-1).

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program frequencies.

The Braidwood Operating Department, Chemistry Departments, and Vendors are responsible for the implementation, performance, completion, and reporting of this Program.

1.6 ACCEPTANCE CRITERIA Acceptance criteria for the fuel used in the INSTALLED PLANT EQUIPMENT at Braidwood is specified in the applicable Exelon Nuclear, Braidwood Station, and Vendor procedures implemented by this Program.

BRAIDWOOD UNITS 1 & 2 6 of 9 Revision 103 Technical Requirements Manual

TRM Diesel Fuel Oil Testing Program Appendix M 1.7 LCOARS/COMPENSATORY MEASURES In the event the diesel fuel oil does not meet the acceptance criteria, the Shift Manager or designee shall be immediately notified. The Shift Manager or designee shall determine OPERABILITY status and implement a LCOAR(s) as applicable.

Typically, fuel stored in the 125K and 50K OUTDOOR BULK DIESEL FUEL OIL TANKS which does not meet acceptance criteria is declared "UNCERTIFIED" since there is not any LOCAR(s) associated with these tanks. Actions are taken to prevent "UNCERTIFIED" fuel from being used. A confirmatory sample should be analyzed in the event a sample is found to not meet the acceptance criteria. In addition, an Issue Report (IR) may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

1.8 REPORTING REQUIREMENTS Analysis results are reported to Braidwood by Vendor.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10 CFR 50.59 Review and a Station Qualified Review (SQR).

The SQR composition shall include Regulatory Assurance Department in all cases. As a part of the SQR, concurrence from Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager. Byron and Braidwood shall implement the same change unless the change has been reviewed and determined not to be applicable to Braidwood.

BRAIDWOOD UNITS 1 & 2 7 of 9 Revision 103 Technical Requirements Manual

TRM Diesel Fuel Oil Testing Program Appendix M ATTACHMENT A Diesel Fuel Oil Testing Matrix Outdoor Bulk Diesel EDG Tanks: EDG Tanks: _B AF Pump Diesel Diesel-Driven Fire Security Diesel Fuel Oil Tanks: 1DO01TA/B/C/D (25K gal.) 1DO02TA/B (500 gal.) Day Tanks: Pump Diesel Fuel Generator Day 0DO03T (125K gal.) 2DO01TA/B (50K gal.) 2DO02TA/B (500 gal.) 1DO10T (500 gal.) Oil Tank: Tank:

0DO012T (50K gal.) 2DO10T (500 gal.) 0DO05T (650 gal.) 0DO06T (500 gal.)

Frequency Monthly Monthly Monthly Monthly(5) Monthly(5) Monthly Parameter:

Flash Point XX(2)

Cloud Point XX(3)

Water & Sediment XX(1)(2) X(6) X(6) X(6) X(6) X Ramsbottom Carbon XX(3)

Residue Ash XX(3)

Kinematic XX(2) X X X X X Viscosity Copper Strip XX(3)

Corrosion Cetane Index XX(3)

Sulfur XX(3)

API Gravity XX(2) X X X X X Distillation XX(3)

Temperature Bacteria X X(6) X(6) X(6) X(6)

Clear & Bright XX(1)(2) X X X X X Color XX(1)(2) X X X X X Heat Value X Total Particulate XX(4) XX(6) X(6) X(6) X(6) X Contamination Removal of accumulated XX XX XX(6) X(6) X(6) water XX = Technical Specification required testing performed X = Testing performed BRAIDWOOD UNITS 1 & 2 8 of 9 Revision 103 Technical Requirements Manual

TRM Diesel Fuel Oil Testing Program Appendix M NOTES:

(1) Water & Sediment OR Clear & Bright with Color is required.

(2) Technical Specifications require verifying within limits within 30 days prior to adding new fuel oil to storage tanks.

(3) Technical Specifications require verifying within 30 days following sampling and addition to storage tanks.

(4) Required since the Outdoor Bulk Diesel Fuel Oil Tanks are considered the source of stored fuel for the _B AF Pump Diesel Day Tanks.

(5) Testing performed on a monthly basis, however, results are only required to be verified on a quarterly basis.

(6) Testing required per the License Renewal Fuel Oil Chemistry Aging Management Program (CM-1)

BRAIDWOOD UNITS 1 & 2 9 of 9 Revision 103 Technical Requirements Manual

TRM TS Bases Control Program Appendix N TECHNICAL SPECIFICATIONS BASES CONTROL PROGRAM TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA

1. 7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 &2 1 of 13 Revision 64 Technical Requirements Manual

TRM TS Bases Control Program Appendix N 1.1 PURPOSE The purpose of this Program is to provide guidance for identifying, processing, and implementing changes to the Technical Specifications (TS) Bases. This Program implements and satisfies the requirements of TS 5.5.14, "Technical Specifications (TS)

Bases Control Program."

This Program is applicable to the preparation, review, implementation, and distribution of changes to the TS Bases. This Program also provides guidance for preparing TS Bases Change Packages for distribution.

1.2 REFERENCES

1. TS 5.5.14, "Technical Specifications (TS) Bases Control Program"

2. 10 CFR 50.4, "Written Corrmunications"

3. 10 CFR 50.59, "Changes, Tests and Experiments"

4. 10 CFR 50.71, "Maintenance of Records, Making of Reports"

5. 10 CFR 50.90, "Application for Amendment of License or Construction Permit" 1.3 DEFINITIONS AND/OR ACRONYMS

1. 10 CFR 50.59 REVIEW - A written regulatory evaluation which provides the basis for the determination that a change does, or does not, require NRC approval pursuant to 10 CFR 50.59.

The scope of the evaluation should be corrmensurate with the potential safety significance of the change, but must address the relevant safety concerns included in the Safety Analysis Report and other owner controlled documents. The depth of the evaluation must be sufficient to determine whether or not NRC approval is required prior to implementation. Depending upon the significance of the change, the evaluation may be brief; however, a simple statement of conclusion is not sufficient.

BRAIDWOOD UNITS 1 &2 2 of 13 Revision 64 Technical Requirements Manual

TRM TS Bases Control Program Appendix N

2. EDITORIAL CHANGE - Editorial changes include correction of punctuation, insignificant word or title changes, style or format changes, typographical errors, or correction of reference errors that do not change the intent, outcome, results, functions, processes, responsibilities, or performance requirements of the item being changed. Changes in numerical values shall not be considered as editorial changes. Editorial changes do not constitute a change to the TRM and therefore do not require further 10 CFR 50.59 Reviews. If the full scope of this proposed change is encompassed by one or more of the below, then the change is considered editorial.

Rewording or format changes that do not result in changing actions to be accomplished.

Deletion of cycle-specific information that is no longer applicable.

Addition of clarifying information, such as:

Spelling, grarrmar, or punctuation changes Changes to references Name or title references 1.4 PROGRAM DESCRIPTION

1. A Licensee may make changes to the TS Bases without prior NRC approval provided the changes do not require either of the following:

a. A change in the TS as currently incorporated in the 1i cense; or

b. A change to the Updated Final Safety Analysis Report (UFSAR) or TS Bases that requires NRC approval pursuant to 10 CFR 50.59.

2. Changes that meet the above criteria (i.e., 1.4.1.a or 1.4.1.b) shall be submitted to the NRC pursuant to 10 CFR 50.90 and reviewed and approved by the NRC prior to implementation.

3. The TS Bases shall be maintained consistent with the UFSAR.

BRAIDWOOD UNITS 1 &2 3 of 13 Revision 64 Technical Requirements Manual

TRM TS Bases Control Program Appendix N

4. If a change to the TS Bases is not consistent with the UFSAR, then the cognizant Engineer shall prepare and submit a UFSAR Change Package when the TS Bases Change Request is submitted to Regulatory Assurance (RA) for processing.

5. Changes to the TS Bases that do not require prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e), as modified by approved exemptions.

6. TS Bases changes associated with a TS Amendment shall be implemented consistent with the implementation requirements of the TS Amendment.

7. Cantera Licensing (CL) is responsible for the control and distribution of the TS Bases. In order to prevent distribution errors (i.e., omissions or duplications), CL shall maintain the master TS Bases distribution list.

1.5 PROGRAM IMPLEMENTATION

1. TS Bases Change Requestor identifies the need for a revision to the TS Bases and notifies the RA Licensing Engineer (i.e., hereafter referred to as RA LE). A TS Bases change can be initiated through any Stations' RA. TS Bases Change Requestor notifies their counterparts on the need for a change.

2. RA LE notifies their counterparts of identified need for revision to the TS Bases.

3. RA LE obtains concurrence from CL on the need for a change.

BRAIDWOOD UNITS 1 &2 4 of 13 Revision 64 Technical Requirements Manual

TRM TS Bases Control Program Appendix N

4. RA LE drafts TS Bases changes considering format, rules of usage, and technical adequacy.

5. CL Engineer (i.e., hereafter referred to as CLE) reviews the agreed upon TS Bases wording changes for consistency with format, rules of usage, and technical adequacy and provides final concurrence.

6. After concurrence of the TS Bases wording changes is obtained, CLE makes an electronic version available in a working directory for use in the preparation of the 10 CFR 50.59 REVIEW and Station Qualified Review CSQR) process. The CLE shall ensure that the master electronic TS Bases files are revised per step 14 below upon receiving SOR approval. The Revision number in the footer should be a sequential number (i.e., l, 2, etc.).

NOTE *

If the TS Bases changes are applicable to more than one *

Station, the following steps should be performed *

concurrently for each Station. *

7. TS Bases Change Requestor provides a 10 CFR 50.59 REVIEW for the TS Bases changes in accordance with appropriate plant procedures. An exception to this requirement applies when the changes are being requested in order to reflect an approved NRC Safety Evaluation CSE) associated with a site specific Operating License or TS change. The NRC SE is sufficient to support the changes provided it has been determined that the changes are consistent with and entirely bounded by the NRC SE. A 10 CFR 50.59 REVIEW shall be performed for TS Bases changes that reflect generic industry approval by an NRC SE to determine site specific applicability. A 10 CFR 50.59 REVIEW is not required for an EDITORIAL CHANGE.

8. TS Bases Change Requestor completes Attachment A, "Technical Specifications Bases Change Request Form," as follows:

BRAIDWOOD UNITS 1 &2 5 of 13 Revision 64 Technical Requirements Manual

TRM TS Bases Control Program Appendix N

a. Identifies the affected sections, and includes a copy of the proposed TS Bases changes;

b. Briefly surrmarizes the changes including the LCO, Action, or Surveillance Requirement to which the changes apply;

c. Briefly surrmarizes the reason for the changes and attaches all supporting documentation;

d. Identifies any schedule requirements and proposed implementation date that apply (i.e., describe any time limitations that might apply which would require expedited processing). If the changes are outage related, then checks "yes" and lists the applicable outage identifier;

e. Identifies any known implementation requirements such as procedure changes, UFSAR changes, Passport changes, Reportability Manual revisions, pre-implementation training requirements, etc.;

f. If a 10 CFR 50.59 REVIEW was prepared to support the TS Bases changes, the Requestor then checks the appropriate box, lists the associated 10 CFR 50.59 REVIEW Number, and attaches the original;

g. If the changes to the TS Bases are the result of an approved NRC SE associated with a site specific Operating License or TS change and the scope of the changes determined to be consistent with and entirely bounded by the NRC SE, then the Requestor checks the appropriate box and attaches a copy;

h. If the changes to the TS Bases are EDITORIAL CHANGES, the the Requestor checks the appropriate box and no 10 CFR 50.59 REVIEW is required;

i. Signs and dates as Requestor and identifies the originating department;

j. Obtains approval to proceed from Department Supervisor (or designee); and

k. Returns Attachment A to the RA LE.

BRAIDWOOD UNITS 1 &2 6 of 13 Revision 64 Technical Requirements Manual

T~

TS Bases Control Program Appendix N

9. RA LE reviews the TS Bases Change Request Form, including supporting documentation, and documents the review by signing Attachment A. The review verifies that the following information or documentation is included:

a. Completed 10 CFR 50.59 REVIEW. If the changes are related to an approved NRC SE associated with a site specific Operating License or TS change and determined to be entirely bounded by the NRC SE, then only a copy of the SE is required to be attached and no 10 CFR 50.59 REVIEW is required. A 10 CFR 50.59 REVIEW is not required for an EDITORIAL CHANGE;

b. Identification of known documents requiring revisions; and

c. Completed UFSAR Change Request with supporting documentation, in accordance with appropriate plant procedures, if applicable.

10. If the TS Bases change is not an EDITORIAL CHANGE, the RA LE/TS Bases Change Requester obtains SOR approval of the TS Bases changes by performing the following:

a. RA LE prepares the TS Bases Change SOR package. The SOR package shall include Attachment A (including completed 10 CFR 50.59 REVIEW or NRC SE) and the revised TS Bases pages. Attachment A is provided for the purpose of reviewing and finalizing the implementation requirements and ensuring the necessary actions have been initiated. RA LE shall assign Action Tracking CAT) items, as necessary, to track implementation requirements;

b. TS Bases Change Requester submits the TS Bases Change SOR package to the SOR Committee members for a preliminary review. The SOR composition shall include RA and Operating Departments in all cases; and

c. TS Bases Change Requester resolves preliminary review comments and finalizes the TS Bases Change SOR package.

11. The RAM shall determine the need for Plant Operations Review Committee CPORC) approval. The need for PORC approval shall be documented on Attachment A.

BRAIDWOOD UNITS 1 &2 7 of 13 Revision 64 Technical Requirements Manual

TRM TS Bases Control Program Appendix N

12. RA LE/TS Bases Change Requester obtains PORC approval, if necessary.

13. RA LE notifies CLE of approval of the TS Bases changes by forwarding a copy of the approved SQR/PORC Change package to CLE.

14. After approval of the TS Bases changes by SQR/PORC, CLE ensures that the controlled master electronic files are updated.

15. RS/RA completes Attachment B, "Technical Specifications Bases Change Instruction Form," as follows:

a. CLE indicates the effective date of the TS Bases changes consistent with the SQR/PORC approval or TS amendment required implementation date. If the TS Bases change is a result of a TS Amendment, the update shall be implemented coincident with implementation requirements of the TS Amendment. Otherwise, the update must be implemented by the date indicated on Attachment B;

b. CLE lists each page to be removed and inserted, including the Affected Page List; and

c. RA LE provides the updated master file directory for updating Electronic Document Management System (EDMS), if applicable.

16. CLE creates a TS Bases Change Package. The TS Bases Change Package shall consist of:

a. TS Bases Change Instruction Form (Attachment B);

b. Revised Affected Page List; and

c. Revised TS Bases pages.

One CLE shall assemble and approve the TS Bases Change Package for distribution and a second CLE shall perform a peer check to verify completeness of the TS Bases Change Package.

BRAIDWOOD UNITS 1 &2 8 of 13 Revision 64 Technical Requirements Manual

T~

TS Bases Control Program Appendix N

17. After the RA LE notifies the CLE that SQR/PORC approval of the TS Bases changes has been obtained and that all AT items assigned to track implementation requirements have been completed, CLE forwards the TS Bases Change Package to the RA LE as notification of the need to update the onsite TS Bases controlled copies and EDMS, if applicable. CLE also forwards the TS Bases Change Package to CL Records Management as notification of the need to update the offsite CCL) TS Bases controlled copies and to transmit updates to the offsite (non-CL) TS Bases controlled copies.

18. RA LE forwards the TS Bases Change Package to Station Records Management as notification of the need to update the onsite TS Bases controlled copies and EDMS, if applicable.

19. Upon completion of updating the onsite TS Bases controlled copies and EDMS (if applicable), Station Records Management Supervisor signs and dates Attachment B and returns Attachment B to the appropriate CLE.

20. Upon completion of updating the offsite CCL) TS Bases controlled copies and transmitting updates to the offsite (non-CL) TS Bases controlled copies, CL Records Management signs and dates Attachment B and returns Attachment B to the appropriate CLE.

21. RA LE ensures that the documentation required to be maintained as a quality record is provided to Station Records Management for the purpose of record retention.

BRAIDWOOD UNITS 1 &2 9 of 13 Revision 64 Technical Requirements Manual

T~

TS Bases Control Program Appendix N 1.6 ACCEPTANCE CRITERIA Not applicable.

1.7 LCOARS/COMPENSATORY MEASURES An Issue Report may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

The RAM will be responsible for ensuring that Program failures have been resolved.

1.8 REPORTING REQUIREMENTS

NOTE *

TS Bases changes requiring prior NRC approval shall be *

submitted in accordance with Reference 5.

TS Bases changes not requiring prior NRC approval, as described in Section 1.4 of this Program, shall be submitted to the NRC in accordance with 10 CFR 50.7l(e).

1.9 CHANGE CONTROL Changes to this Program, other than EDITORIAL CHANGES, shall include a 10 CFR 50.59 REVIEW and a SOR. The SOR composition shall include RA Department in all cases. For a change to this Program, PORC approval from all Stations is required. The concurrence shall be that the other Stations are implementing the same changes or that the changes have been reviewed and determined not to be applicable to the other Stations.

BRAIDWOOD UNITS 1 &2 10 of 13 Revision 64 Technical Requirements Manual

TRM TS Bases Control Program Appendix N ATTACHMENT A TECHNICAL SPECIFICATIONS BASES CHANGE REQUEST FORM

1. Change Request #: Affected Bases Section(s): __________

2. Description of changes:

3. Reason for changes (attach all supporting documentation):

4. Schedule Requirements:

Outage Related (check one) 0 No 0 Yes, Outage# _ _ __

Other (explain)

5. Implementation Requirements (attach additional pages, as necessary):

Identify the impact of the changes on the following:

Affected N/A 0 0 UFSAR _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

00 00 TS_~-----~------------

Technical Requirerrents Manual _ _ _ _ _ _ _ _ _ _ __

0 0 NRC Safety Evaluation - - - - - - - - - - - - - -

0 0 Fire Protection R e p o r t - - - - - - - - - - - - - -

0 0 0 0 NRC Conmitrrents Vendor Docurrenta-ti~on _ _ _ _ _ _ _ _ _ _ _ _ _ __

0 0 Special Pennits/Licenses _ _ _ _ _ _ _ _ _ _ _ __

0 0 0 0 Procedures Envi rornrent~al,.....,,...Qu-al,..,.i"""fi-ca...,.t.,....io_n _ _ _ _ _ _ _ _ _ _ __

0 0 Design Basis Docl.llrentation - - - - - - - - - - - - -

0 0 Engineering C a l c u l a t i o n s - - - - - - - - - - - - -

0 0 Drawings/Prints - - - - - - - - - - - - - - - -

0 0 PRA Infonnation - - - - - - - - - - - - - - - -

0 0 Programs~~-~--------------

0 0 Reportability Manual - - - - - - - - - - - - - -

0 0 QA Topical Report - - - - - - - - - - - - - - -

0 D Passport._ _,....,,...,.---=-~,---=--~~---------

0 0 Pre-Irrplerrentation Training R e q u i r e d - - - - - - - - -

0 0 Maintenance Rule 0 0 Dffsite Dose Calc~ul~at~i-on_M_a-nu-a~l- - - - - - - - - - -

0 0 Other _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

6. Check one:

0 10 CFR 50.59 REVIEW Attached, 10 CFR 50.59 REVIEW#: _ _ _ _ _ _ _ __

0 NRC SE Attached, Changes consistent with and entirely bounded by NRC SE 0 EDITORIAL CHANGE, No 10 CFR 50.59 REVIEW required

7. Requestor: I /=---=----=-=-------

(Signature) (Date) (Department)

8. Requesting Supervisor Approval: --------~! __________

(Signature) (Date)

9. PORC Approval Required: 0 Yes 0 No

10. Licensing Engineer Review: ~~--~---~! _ _ _ _ _ _ _ _ __

(Signature) (Date)

BRAIDWOOD UNITS 1 &2 11 of 13 Revision 64 Technical Requirements Manual

TRM TS Bases Control Program Appendix N ATTACHMENT B TECHNICAL SPECIFICATIONS BASES CHANGE INSTRUCTION FORM FOR ONSITE/OFFSITE DISTRIBUTION AND FOR UPDATING EDMS Braidwood/Byron/Dresden/LaSalle/QC (circle one) TS Bases Revision#~~

NOTE: This change is effective as of and shall be implemented by CSQR/PORC or Amendment Implementation Date)

(Date)

Approved for distribution: ~~~~~~~~~~~~~/---~~~-

(CLE Signature) (Date)

Verified: -,---=-~~~~~~~~~~~1-----,..~~-

(CLE Signature) (Date) l~OVE ti on REMOVE Page INSERT Section INSERT Page UPDATE EDMS Section UPDATE EDMS Page Affected All Affected Page All N/A N/A Paqe List Li st BRAIDWOOD UNITS 1 &2 12 of 13 Revision 64 Technical Requirements Manual

TRM TS Bases Control Program Appendix N ATTACHMENT B TECHNICAL SPECIFICATIONS BASES CHANGE INSTRUCTION FORM FOR ONSITE/OFFSITE DISTRIBUTION AND FOR UPDATING EDMS Braidwood/Byron/Dresden/LaSalle/QC (circle one) TS Bases Revision# _ _

Station Records Management:

Onsite Distribution Completed: ,...,,.---,--~-,...----~---..,.-!....,..,,...__,_ _ _ __

(Station Records Mgmt. Supr.) (Date)

EDMS Update Completed: ...,..,,....,-,.-,.---=--....,--.,-,---,---=---,....-'I---=-,---,------

(Stat ion Records Mgmt. Supr.) (Date)

- Return this sheet to: Cantera Licensing Braidwood/Byron/Dresden/LaSalle/QC (circle one) CLE CANTE RA CL Records Management:

Offsite (CL) Distribution Completed:

(CL Records Mgmt.)

Offsite (non-CU Distribution Transmitted: _ _ _ _ _ _ _ _ _~/_ _ _ _ _ __

(CL Records Mgmt.) (Date)

- Return this sheet to Braidwood/Byron/Dresden/LaSalle/QC (circle one) CL Offsite (non-CL) Controlled Copy Holders:

Offsite (non-CL) Distribution Completed: ---------~! _______

(Signature) (Date)

- Return this sheet to: EXELON GENERATION COMPANY, LLC LICENSING AND REGULATORY AFFAIRS DEPARTMENT 4300 WINFIELD ROAD WARRENVILLE, IL 60555 BRAIDWOOD UNITS 1 &2 13 of 13 Revision 64 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.1 PURPOSE The purpose of the SFDP is to ensure that the proper Actions are taken upon failure to concurrently meet two or more Technical Specifications (TS) Limiting Conditions for Operation (LCOs) such that multiple inoperabilities of Systems, Structures, or Components (SSCs) do not result in an undetected LOSS OF SAFETY FUNCTION (LOSF).

1.2 REFERENCES

1. Technical Specification LCO 3.0.6

2. TS Specification 5.5.15, "Safety Function Determination Program (SFDP)"

3. Maintenance Rule Scoping Manual 1.3 DEFINITIONS AND/OR ACRONYMS

1. ACTIONS - In the LCO Actions section, it describes the Required Actions to be taken under designated Conditions within specified COMPLETION TIMES.

2. LOSS OF SAFETY FUNCTION (LOSF) - A LOSF exists when, assuming no concurrent single failure and assuming no concurrent loss of offsite power or loss of emergency diesel generator(s), a safety function assumed in the accident analysis cannot be performed.

3. COMPLETION TIME - In the LCO Actions section, it states the amount of time allowed to complete a Required Action.

4. COMPLETION TIME EXTENSION - The additional amount of time a SUPPORTED SYSTEM may be inoperable due to its associated SUPPORT SYSTEM being inoperable. NOTE - the inoperability of the SUPPORTED SYSTEM must only be directly attributed to its associated SUPPORT SYSTEM being inoperable and the SUPPORT SYSTEM Required Actions not specifically requiring entry into the SUPPORTED SYSTEMS Required Actions and associated COMPLETION TIMES.

5. CONDITION - In the LCO Actions section, it describes the ways in which the requirements of an LCO can fail to be met.

BRAIDWOOD UNITS 1 & 2 2 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.3. 6. OPERABLE/OPERABILITY - A system, subsystem, train, component, or device shall be OPERABLE when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

7. SAFETY FUNCTION - An accident mitigation feature required by NRC regulation, plant design or Technical Specifications normally composed of two trains of SUPPORTED and SUPPORT equipment.

8. SUPPORTED SYSTEM - A SSC, required by the TS, which requires a SUPPORT SYSTEM to ensure its safety function can be performed.

Process parameters or operating limits do not comprise SUPPORTED SYSTEMS for the purposes of implementing LCO 3.0.6.

BRAIDWOOD UNITS 1 & 2 3 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.3. 9. SUPPORT SYSTEM - A SSC which is needed by another TS LCO required SSC to perform a safety function.

An example would be the Component Cooling Water (CC) System (SUPPORT SYSTEM) which is required by the Residual Heat Removal System (SUPPORTED SYSTEM) to fulfill the RH safety function. A SUPPORT SYSTEM may also be a SUPPORTED SYSTEM. An example is the Component Cooling Water (CC) System which needs the Essential Service Water (SX) System to fulfill its safety function.

NOTE *

A SSC which monitors or maintains a process *

parameter or operating limit is not a *

SUPPORT SYSTEM for the purposes of implementing *

LCO 3.0.6. An example is Rod Position Indication *

which is used to monitor control rod insertion *

limits. Inoperability of the Rod Position *

Indication System does not automatically suggest *

that the control rods are no longer within *

insertion limits. Control rod insertion limits *

are monitored separately and Actions are taken as *

appropriate when insertion limits are not met *

or if Surveillance Requirements can not be *

performed when required. *

Likewise, parameter limits that could affect other *

parameter limits if exceeded are also not

considered SUPPORT SYSTEM for the purposes

of implementing

LCO 3.0.6. An example is that

exceeding control *

affect hot channelrod insertion limits could *

factors.

BRAIDWOOD UNITS 1 & 2 4 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.4 PROGRAM DESCRIPTION

1. TS LCO 3.0.2 states that upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6. LCO 3.0.6 provides an exception to LCO 3.0.2 for SUPPORTED SYSTEMS by not requiring the Required Actions for the SUPPORTED SYSTEMS to be performed when the failure to meet an LCO is solely due to a SUPPORT SYSTEM LCO not being met. In this situation, although the SUPPORTED SYSTEM is declared inoperable, LCO 3.0.6 requires only the Conditions and Required Actions of the SUPPORT SYSTEM to be performed. The Conditions and Required Actions for the SUPPORTED SYSTEM are not required to be performed (i.e., cascading to the SUPPORTED SYSTEM) per LCO 3.0.6.

There are two types of SUPPORT SYSTEMS which must be considered when implementing LCO 3.0.6: (1) those addressed in Technical Specifications, and (2) those which are not. If the required SUPPORT SYSTEM is not addressed in the Technical Specifications, the impact of the SUPPORT SYSTEM inoperability must be evaluated with respect to any SUPPORTED SYSTEM which is addressed in Technical Specifications. An example of this is the loss of a ventilation system for which there is no LCO. If the equipment supported by the ventilation system were subsequently exposed to freezing conditions, then all affected systems which have an LCO must be evaluated to ensure that they remain OPERABLE and that there is no LOSF.

If the SUPPORT SYSTEM is addressed in the Technical Specifications, only the SUPPORT SYSTEM LCO must be entered per LCO 3.0.6 (i.e.,

"cascading" to the SUPPORTED SYSTEM is not required). However, the SUPPORT SYSTEM inoperability must still be evaluated with respect to the existing plant conditions to ensure that a LOSF does not exist.

An example of this is the loss of component cooling water to one residual heat removal (RHR) heat exchanger. If the electrical bus supplying the second RHR pump were also removed from service, a LOSF may exist following a loss-of-coolant-accident and this plant configuration must be evaluated. It should be noted that for cases in which the inoperable SUPPORT SYSTEM is addressed in Technical Specifications, "cascading" can still be performed. LCO 3.0.6 only provides an option for not cascading at the discretion of operations.

BRAIDWOOD UNITS 1 & 2 5 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.4. 2. If the exception of 3.0.6 is utilized, additional evaluations and limitations may be required in accordance with Specification 5.5.15, "Safety Function Determination Program (SFDP)" (Reference Figure 1).

If a LOSF is determined to exist by this Program, the appropriate Conditions and Required Actions of the LCO in which the LOSF exists are required to be entered. When a SUPPORT SYSTEM'S Required Action directs a SUPPORTED SYSTEM to be declared inoperable or directs entry into Conditions and Required Actions for a SUPPORTED SYSTEM, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

3. Since "cascading" is not required when applying 3.0.6, a possibility exists that unrelated concurrent failures of more than one system could result in the complete loss of both trains of a SUPPORTED SYSTEM. Therefore, upon a failure to meet two or more LCOs during the same time period, an evaluation shall be conducted to determine if a LOSF exists. Generally, this is done by confirming that the remaining required redundant SSCs are OPERABLE. If a LOSF does exist, the SFDP directs that the appropriate actions be taken.

NOTE *

If the failure of an TS required SUPPORT SYSTEM results *

in the inoperability of a system outside of the TS, and *

that system is subsequently relied upon by a SUPPORTED *

SYSTEM to remain OPERABLE, then LCO 3.0.6 could apply and *

only the SUPPORT SYSTEM'S Required Actions would be *

entered.

BRAIDWOOD UNITS 1 & 2 6 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.4. 4. A single component inoperability may result in multiple inoperabilities within a single train and affect multiple TS LCOs.

LCO 3.0.6 limits the amount of "cascading" Actions that are required when an inoperable SSC renders a SUPPORT SYSTEM inoperable.

A LOSF evaluation must only be performed when equipment is inoperable in more than one train. For multiple inoperabilities within a single train, whether separate inoperabilities or inoperabilities of SUPPORTED SYSTEM(S) due to the inoperability of a SUPPORT SYSTEM, compliance with the Required Actions within the LCOs as directed by LCO 3.0.2 and LCO 3.0.6 is sufficient to ensure safe operation.

If the inoperable system is a SUPPORT SYSTEM and its Required Actions have not been pre-evaluated in combination with other inoperabilities as noted in Table 1, then perform a LOSF evaluation in accordance with Section 1.5. LCO's which are not SUPPORT SYSTEMS may also result in a LOSF when taken in combination with additional inoperabilities. Therefore, a LOSF evaluation is required and the Required Actions of the applicable LCOs shall be met in accordance with LCO 3.0.2.

BRAIDWOOD UNITS 1 & 2 7 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.4. 4. (CONTINUED)

If more than one LCO's Required Actions have been entered, then determine if all the LCOs have been entered for the same train.

a. If the LCOs have been entered for the same train, then no LOSF exists provided the redundant equipment on the opposite train is not inoperable for other reasons. No further evaluation is required.

b. If the LCOs have been entered for different trains, then a LOSF evaluation shall be performed to determine if the initial inoperability(ies), in conjunction with subsequent inoperability(ies) in the required redundant train, results in the loss of a safety function. This evaluation shall address the following examples:

1) A required system redundant to the system(s) supported by the inoperable SUPPORT SYSTEM is also inoperable (see Figure 2, Example 1); or

2) A required system redundant to the system(s)in turn supported by the inoperable SUPPORTED SYSTEM is also inoperable (see Figure 2, Example 2); or

3) A required system redundant to the SUPPORT SYSTEM(s) for the SUPPORTED SYSTEMs (a) and (b) above is also inoperable (see Figure 2, Example 3).

For a TS related SUPPORT SYSTEM, Table 1 may be used as a guide for evaluating SUPPORT/SUPPORTED SYSTEM(s) relationships between TS systems.

Inoperable SSC(s) should be evaluated if the inoperability impacts the ability of the SSC(s) to perform its required safety function.

BRAIDWOOD UNITS 1 & 2 8 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.5 PROGRAM IMPLEMENTATION - LOSS OF SAFETY FUNCTION (LOSF) EVALUATION

NOTE *

1. If an LCO is not met for a SUPPORT SYSTEM, and the *

SUPPORT SYSTEM Actions direct the Actions for the *

SUPPORTED SYSTEMS be entered, enter the appropriate *

Actions for the SUPPORTED SYSTEMS. *

2. If a SUPPORTED SYSTEM LCO is not met solely due to *

a SUPPORT SYSTEM inoperability, and the SUPPORT *

SYSTEM Actions do not direct that Actions for the *

SUPPORTED SYSTEMS be entered, then do not enter the *

Actions for the SUPPORTED SYSTEMS per LCO 3.0.6. *

1. Identify if the degraded SSC renders a TS required SSC inoperable.

If NO, then no further evaluation is necessary.

2. If YES, then enter the LCOAR for the inoperable SSC.

3. Determine if the inoperable SSC is also a SUPPORT SYSTEM SSC.

4. If YES, then identify all TS required SUPPORTED SYSTEM SSC's that are rendered inoperable as a result of this LCOAR entry.

5. If the SUPPORT SYSTEM SSC Required Actions direct performance of any SUPPORTED SYSTEM SSC Required Action(s), then enter the LCOAR for the SUPPORTED SYSTEM SSC as directed and perform the Required Actions.

6. For ALL inoperable SUPPORT and SUPPORTED SYSTEM SSC's, perform an evaluation to ensure a LOSF does not exist for current plant conditions. Perform cross-train checks to ensure redundant trains are fully operational.

BRAIDWOOD UNITS 1 & 2 9 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.5. 7. If any redundant train SSC is NOT fully Operational, then one of the following conditions will apply:

a. The SSC is part of a single LCO with multiple subsystems and the LCO specified function is intact. NO LOSF exists for this specific SSC.

b. The SSC will still perform it's required Safety Function as defined in the Safety Analysis Report (SAR). NO LOSF exists for this specific SSC.

c. A LOSF exists. Enter the LCOAR and perform the Required Actions of the SSC in which the LOSF exists for the specific Condition(s) that apply.

8. If No LOSF exists, for all SUPPORTED SYSTEM SSC's which are rendered inoperable, perform one of the following actions:

a. Enter the LCOAR(s) for each inoperable SSC and perform the Conditions and Required Actions as directed (Cascading), OR

b. Declare the SUPPORTED SYSTEM SSC(s) inoperable and apply LCO 3.0.6 to preclude entry into the Conditions and Required Actions associated with the inoperable SUPPORTED SYSTEM SSC(s). Track the inoperable SSC(s) on the Delayed LCOAR Entry Table of the inoperable SUPPORT SYSTEM SSC LCOAR.

NOTE: Examples of LOSF evaluations may be found in Figures 1 and 2, and Attachment 2.

1.6 ACCEPTANCE CRITERIA Not Applicable.

1.7 LCOARS/COMPENSATORY MEASURES The Shift Manager is responsible for initiating any LCOARs or Compensatory Measures resulting from the LOSF evaluation. In addition, an Issue Report (IR) may be generated to provide proper tracking and resolution of noted problems associated with the implementation of this program.

1.8 REPORTING REQUIREMENTS This will be evaluated on a case-by-case situation.

BRAIDWOOD UNITS 1 & 2 10 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O 1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10CFR50.59 Review and a Station Qualified Review (SQR). The SQR composition shall include the Regulatory Assurance Department in all cases. As a part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) is required as determined by the Regulatory Assurance Manager. Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and was determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 11 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O FIGURES 1 and 2 SFDP FLOWCHART SUPPORT/SUPPORTED SYSTEM DIAGRAM BRAIDWOOD UNITS 1 & 2 12 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O SAFETY FUNCTION DETERMINATION PROGRAM (SFDP)

Is an ITS Required EŽ

Finished SSC rendered INOP z

Is INOP SSC a EŽ Perform the LCO SUPPORT SSC? Required Actions for the Inoperable SSC z

Identify all inoperable SUPPORTED SSCs (use Table 1 as a guide)

Do INOP SUPPORT SSC z Perform SUPPORT SSC Required Required Actions directly Actions and SUPPORTED SSC LCO address SUPPORTED SSCs? Required Actions as directed EŽ

For each SSC that is determined to be inoperable - Perform a Safety Function Determination Evaluation Page 2 SFD (continue on page 2)

BRAIDWOOD UNITS 1 & 2 13 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O SAFETY FUNCTION DETERMINATION PROGRAM (SFDP)

SFD (continued from page 1)

Does this ITS Required SSC have any redundant SSC's that are also inoperable?

z

note---------------

Consider all active LCOAR's and SSC's which are inoperable but not in LCOAR under the allowances of LCO 3.0.6 z

Is the SSC part of a single LCO with multiple subsystems with the LCO specified function intact?

EŽ

z

Can the SSC still perform its required safety function as defined in the Safety Analysis Report (UFSAR)?

EŽ

No Loss of Safety Function Exists for this specific SSC.

A Loss of Safety Function Exits Either:

Enter the LCOAR and perform the Perform both SUPPORT and SUPPORTED Required Actions of the LCO in which SSC Required Actions (Cascade) the LOSF exists for the specific Condition(s) which apply.

OR Perform SUPPORT SSC Required Actions and enter LCO 3.0.6 for SUPPORTED SSC's BRAIDWOOD UNITS 1 & 2 14 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O FIGURE 2 SUPPORT/SUPPORTED SYSTEM DIAGRAM EXAMPLE 1 A LOSF may exist when a SUPPORT SYSTEM is inoperable, and:

A required system redundant to the system(s) supported by the inoperable SUPPORT SYSTEM is also inoperable.

If System 2 of Train A is inoperable, and System 5 of Train B is inoperable, a LOSF exists in SUPPORTED SYSTEM 5, 10, 11.

(;$03/(6 75$,1$75$,1%

6\VWHP 6\VWHP

Note: Chart reads from left to right, i.e., System 1 is a SUPPORT SYSTEM for Systems 2 through 15.

BRAIDWOOD UNITS 1 & 2 15 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O FIGURE 2 SUPPORT/SUPPORTED SYSTEM DIAGRAM EXAMPLE 2 A LOSF may exist when a SUPPORT SYSTEM is inoperable, and:

A required system redundant to the system(s) in turn supported by the inoperable SUPPORTED SYSTEM is also inoperable.

If System 2 of Train A is inoperable, and System 11 of Train B is inoperable, a LOSF exists in System 11 which is in turn supported by System 5.

(;$03/(6 75$,1$75$,1%

6\VWHP 6\VWHP

Note: Chart reads from left to right, i.e., System 1 is a SUPPORT SYSTEM for Systems 2 through 15.

BRAIDWOOD UNITS 1 & 2 16 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O FIGURE 2 SUPPORT/SUPPORTED SYSTEM DIAGRAM EXAMPLE 3 A LOSF may exist when a SUPPORT SYSTEM is inoperable, and:

A required system redundant to the SUPPORT SYSTEM(S) for the SUPPORTED SYSTEMS (a) and (b) above is also inoperable.

If System 2 of Train A is inoperable, and System 1 of Train B is inoperable, a LOSF Exists in Systems 2, 4, 5, 8, 9, 10 and 11.

(;$03/(6 75$,1$75$,1%

6\VWHP 6\VWHP

Note: Chart reads from left to right, i.e., System 1 is a SUPPORT SYSTEM for Systems 2 through 15.

BRAIDWOOD UNITS 1 & 2 17 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O TABLE 1 - SUPPORT SYSTEM TO SUPPORTED SYSTEM TS REFERENCE BRAIDWOOD UNITS 1 & 2 18 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O TABLE 1 (page 1 of 7)

SUPPORT SYSTEM TO SUPPORTED SYSTEM TS CROSS REFERENCE Support Support System Supported Supported System System System TS TS Number Number 3.3.2 Engineered Safety 3.3.1 Reactor Trip System (RTS)

Feature Actuation Instrumentation System (ESFAS) 3.3.6 Containment Ventilation Instrumentation isolation Instrumentation 3.3.7 Control Room Ventilation (VC) Filtration System Actuation Instrumentation 3.3.8 Fuel Handling Building Exhaust Filter Plenum (FHB)System Actuation Instrumentation 3.5.2 ECCS - Operating 3.5.3 ECCS - Shutdown 3.6.3 Containment Isolation Valves 3.6.6 Containment Spray and Cooling Systems 3.6.7 Spray Additive System 3.7.2 Main Steam Isolation Valves (MSIVs) 3.7.5 Auxiliary Feedwater (AF)

System 3.7.7 Component Cooling Water (CC) 3.7.8 Essential Service Water (SX)

System 3.7.10 Control Room Ventilation (VC) Filtration System 3.7.11 Control Room Ventilation (VC) Temp Control System 3.7.12 Nonaccessible Area Exhaust Filter Plenum Ventilation System 3.7.13 Fuel Handling Exhaust Filter Plenum (FHB) Ventilation System 3.8.1 AC Sources - Operating 3.3.5 Loss of Power (LOP) 3.8.1 AC Sources - Operating Diesel Generator (DG) 3.8.2 AC Sources - Shutdown Start Instrumentation BRAIDWOOD UNITS 1 & 2 19 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O TABLE 1 (page 2 of 7)

SUPPORT SYSTEM TO SUPPORTED SYSTEM TS CROSS REFERENCE Support Support System Supported Supported System System System TS TS Number Number 3.3.6 Containment 3.6.3 Containment Isolation Valves Ventilation Isolation Instrumentation 3.3.7 Control Room 3.7.10 Control Room Ventilation Ventilation (VC) (VC) Filtration System Filtration System Actuation Instrumentation 3.3.8 Fuel Handling Building 3.7.13 FHB Ventilation System Exhaust Filter Plenum (FHB) Ventilation System Actuation Instrumentation 3.4.14 RCS Pressure Isolation 3.4.6 RCS Loops - Mode 4 Valve (PIV) Leakage 3.4.13 RCS Operational Leakage 3.5.2 ECCS - Operating 3.5.3 ECCS - Shutdown 3.4.17 RCS Loop Isolation 3.3.9 BDPS Valves 3.4.4 RCS Loops - MODES 1 and 2 3.4.5 RCS Loops - MODE 3 3.4.6 RCS Loops - MODE 4 3.4.12 LTOP System 3.5.4 Refueling Water 3.3.9 BDPS Storage Tank (RWST) 3.5.2 ECCS - Operating 3.5.3 ECCS - Shutdown 3.6.6 Containment Spray and Cooling Systems 3.5.5 Seal Injection Flow 3.5.2 ECCS - Operating 3.6.2 Containment 3.6.1 Containment Airlocks BRAIDWOOD UNITS 1 & 2 20 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O TABLE 1 (page 3 of 7)

SUPPORT SYSTEM TO SUPPORTED SYSTEM TS CROSS REFERENCE Support Support System Supported Supported System System System TS TS Number Number 3.6.3 Containment Isolation 3.5.2 ECCS - Operating Valves 3.5.3 ECCS - Shutdown 3.6.1 Containment 3.6.6 Containment Spray and Cooling Systems 3.7.7 Component Cooling System 3.7.8 Essential Service Water (SX) 3.6.6 Containment Spray 3.6.7 Spray Additive System 3.6.8 Containment Sump 3.5.2 ECCS - Operating 3.5.3 ECCS - Shutdown 3.6.6 Containment Spray and Cooling Systems 3.7.6 Condensate Storage 3.7.5 Auxiliary Feedwater (AF)

Tank System 3.7.7 Component Cooling 3.4.4 RCS Loops - Modes 1 and 2 Water (CC) System 3.4.5 RCS Loops - Mode 3 3.4.6 RCS Loops - Mode 4 3.4.7 RCS Loops - Mode 5, Loops Filled 3.4.8 RCS Loops - Mode 5, Loops not Filled 3.5.2 ECCS - Operating 3.5.3 ECCS - Shutdown 3.9.5 Residual Heat Removal (RHR)

Coolant Circulation-High Water Level 3.9.6 Residual Heat Removal (RHR)

Coolant Circulation-Low Water Level BRAIDWOOD UNITS 1 & 2 21 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O TABLE 1 (page 4 of 7)

SUPPORT SYSTEM TO SUPPORTED SYSTEM TS CROSS REFERENCE Support Support System Supported Supported System System System TS TS Number Number 3.7.8 Essential Service 3.4.6 RCS Loops - Mode 4 Water (SX) System 3.5.2 ECCS - Operating 3.5.3 ECCS - Shutdown 3.6.6 Containment Spray and Cooling System 3.7.5 Auxiliary Feedwater System 3.7.7 Component Cooling Water (CC)

System 3.7.11 Control Room Ventilation (VC) Temperature Control System 3.8.1 AC Sources - Operating (DG only) 3.8.2 AC Sources - Shutdown (DG only) 3.7.9 Ultimate Heat Sink 3.7.5 "B" AFW System 3.7.8 Essential Service Water (SX)

BRAIDWOOD UNITS 1 & 2 22 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O TABLE 1 (page 5 of 7)

SUPPORT SYSTEM TO SUPPORTED SYSTEM TS CROSS REFERENCE Support Support System Supported Supported System System System TS TS Number Number 3.8.1 AC Sources - Operating 3.8.9 Distribution Systems -

Operating (AC portion only) 3.8.3 Diesel Fuel Oil 3.8.1 AC Sources - Operating 3.8.2 AC Sources - Shutdown 3.8.4 DC Sources - Operating 3.8.1 AC Sources - Operating 3.8.7 Inverters - Operating 3.8.9 Distribution Systems -

Operating 3.4.12 LTOP System 3.8.5 DC Sources - Shutdown 3.4.12 LTOP System 3.8.2 AC Sources - Shutdown 3.8.8 Inverters - Shutdown 3.8.10 Distribution Systems -

Shutdown 3.8.6 Battery Parameters 3.8.4 DC Sources - Operating 3.8.5 DC Sources - Shutdown 3.8.7 Inverters - Operating 3.8.9 Distribution Systems -

Operating 3.8.8 Inverters - Shutdown 3.4.12 LTOP 3.8.10 Distribution Systems -

Shutdown BRAIDWOOD UNITS 1 & 2 23 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O TABLE 1 (page 6 of 7)

SUPPORT SYSTEM TO SUPPORTED SYSTEM TS CROSS REFERENCE Support Support System Supported Supported System System System TS TS Number Number 3.8.9 Distribution Systems - 3.3.1 Reactor Trip System Operating (RTS) Instrumentation 3.3.2 Engineered Safety Feature Actuation System (ESFAS)

Instrumentation 3.3.3 Post Accident Monitoring (PAM)

Instrumentation 3.3.4 Remote Shutdown System 3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Inst.

3.3.6 Containment Ventilation Isolation Instrumentation 3.3.7 Control Room Ventilation (VC)

Filtration System Actuation Instrumentation 3.3.8 Fuel Handling Building Exhaust Filter Plenum (FHB) Ventilation System Actuation Instrumentation 3.4.5 RCS Loops - Mode 3 3.4.6 RCS Loops - Mode 4 3.4.9 Pressurizer 3.4.11 Pressurizer Power Operated Relief Valves (PORVs) 3.4.12 LTOP System 3.4.15 RCS Leakage Detection Instrumentation 3.5.2 ECCS - Operating 3.5.3 ECCS - Shutdown 3.6.3 Containment Isolation Valves 3.6.6 Containment Spray and Cooling Systems 3.6.7 Spray Additive Tank 3.7.2 Main Steam Isolation Valves (MSIVs) 3.7.4 Steam Generator Power Operated Relief Valves 3.7.5 Auxiliary Feedwater (AF) System 3.7.7 Component Cooling Water (CC)

System 3.7.8 Essential Service Water (SX)

System 3.7.9 Ultimate Heat Sink 3.7.10 Control Room Ventilation (VC)

Filtration System 3.7.11 Control Room Ventilation (VC)

Temperature Control System 3.7.12 Nonessential Area Exhaust Filter Plenum Ventilation System 3.7.13 Fuel Handling Building (FHB)

Ventilation System 3.8.1 AC Sources - Operating 3.8.4 DC Sources - Operating 3.8.7 Inverters - Operating BRAIDWOOD UNITS 1 & 2 24 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O TABLE 1 (page 7 of 7)

SUPPORT SYSTEM TO SUPPORTED SYSTEM TS CROSS REFERENCE Support Support System Supported Supported System System System TS TS Number Number 3.8.10 Distribution 3.3.1 Reactor Trip System Systems - (RTS)

Shutdown 3.3.6 Containment Ventilation Isolation Instrumentation 3.3.7 Control Room Ventilation (VC) Filtration System Actuation Instrumentation 3.4.7 RCS Loops - Mode 5, Loops Filled 3.4.8 RCS Loops - Mode 5, Loops Not Filled 3.4.12 LTOP System 3.7.10 Control Room Ventilation (VC) Filtration System 3.7.11 Control Room Ventilation (VC) Temperature Control System 3.7.12 Nonaccessible Area Exhaust Filter Plenum Ventilation System 3.7.13 Fuel Handling Building Exhaust Filter Plenum (FHB) Ventilation System 3.8.1 AC Sources - Operating 3.8.2 AC Sources - Shutdown 3.8.4 DC Sources - Operating 3.8.5 DC Sources - Shutdown 3.8.7 Inverters - Operating 3.9.3 Nuclear Instrumentation 3.9.4 Containment Penetrations 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation - High Water Level 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation - Low Water Level BRAIDWOOD UNITS 1 & 2 25 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 1 LCOAR FORMAT BRAIDWOOD UNITS 1 & 2 26 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O SAFETY FUNCTION DETERMINATION PROGRAM REQUIREMENTS A. Loss of Safety Function (LOSF) Evaluation Is there any inoperable or degraded SUPPORT SYSTEM or SUPPORTED SYSTEM equipment on the opposite/redundant train that, when coupled with this inoperable equipment, might result in a complete loss of a Tech Spec required safety function.

1. NO - No LOSF exists. No further evaluation is necessary.

2. YES - A LOSF may exist. Using the SFDP and BwAP 340-1, evaluate which of the following conditions apply:

a. The SSC is part of an LCO with multiple subsystems and the LCO specified function is intact. No LOSF exists.

b. The SSC will still perform its required safety function as defined in the Safety Analysis Report (SAR). No LOSF exists.

c. A LOSF exists. Perform the Required Actions of the SSC LCO in which the LOSF exists for the specific Condition(s) that apply.

LCO 3.0.6 - DELAYED LCOAR ENTRY CALCULATION.

Perform this step only if NO LOSF exists and it is desired to delay SUPPORTED SYSTEM LCOAR entry as allowed by LCO 3.0.6. A LOSF does not exist if the redundant train of the inoperable SUPPORTED SYSTEM(S) equipment is OPERABLE.

1. Rules of Usage:

a. With a single SUPPORT SYSTEM inoperable, the affected SUPPORTED SYSTEM(s) LCOAR entry(s) is not required to be entered unless directed by the SUPPORT SYSTEM Required Actions.

b. In the event additional SUPPORT SYSTEM(s) become inoperable during the Completion Time for restoration of the first SUPPORT SYSTEM, the LCOAR entry(s) of the SUPPORTED SYSTEM may be delayed by either the maximum allowed Completion Time of the SUPPORT SYSTEMs, OR 2 times the Completion Time for restoration of the SUPPORTED SYSTEM (applied at the time the second SUPPORT SYSTEM becomes inoperable), whichever is less.

BRAIDWOOD UNITS 1 & 2 27 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O

2. When tracking delayed LCOAR entry times, it is imperative that the INOPERABLE TIME/DATE and required LCOAR entry TIME/DATE reflect the total time the SUPPORTED SYSTEM has been inoperable. A review of all active LCOARS must be performed to ensure SUPPORTED SYSTEM(s) do not remain inoperable for longer than allowed in 1.b.

above.

B. SUPPORT SYSTEM to SUPPORTED SYSTEM Tech Spec cross reference is found in the SFDP. Complete the following table(s) for all inoperable SUPPORTED SYSTEMS for the purpose of tracking delayed LCOAR entry given subsequent additional SUPPORT SYSTEM inoperabilities.

Table 1: Supported System delayed LCOAR entry Table: (example)

SUPPORT SYSTEM: LCO 3.7.7 Component Cooling Water SUPPORTED SUPPORTED SYSTEM INOPERABLE Enter LCOAR SYSTEM TS TIME / DATE TIME / DATE NUMBER 3.4.4 RCS Loops - Modes 1 & 2 __________________ __________________

3.4.5 RCS Loops - Mode 3 __________________ __________________

3.4.6 RCS Loops - Mode 4 __________________ __________________

3.4.7 RCS Loops - Mode 5, Loops __________________ __________________

filled 3.4.8 RCS Loops - Mode 5, Loops __________________ __________________

not filled 3.5.2 ECCS - Operating __________________ __________________

3.5.3 ECCS - Shutdown __________________ __________________

3.9.5 RHR Coolant Circulation - __________________ __________________

High Water Level 3.9.6 RHR Coolant Circulation - __________________ _________________

Low Water Level BRAIDWOOD UNITS 1 & 2 28 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O Table 2: ANY/All other SUPPORTED SYSTEMS which are inoperable as a result of the SUPPORTED SYSTEM(S) identified in table 1 above.

SUPPORTED 2nd / 3rd LEVEL INOPERABLE Enter LCOAR SYSTEM TS SUPPORTED SYSTEM TIME / DATE TIME / DATE NUMBER (none pre-identified)

BRAIDWOOD UNITS 1 & 2 29 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 2 SFDP EVALUATION EXAMPLES BRAIDWOOD UNITS 1 & 2 30 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 2 ITEMS CLEARLY INOPERABLE A. A SSC that is unable to perform its specified function(s) because of obvious failure, damage, or malfunction, or because it is disabled for testing or maintenance is inoperable.

B. A SSC that trips (where tripped is not the safety function condition) is inoperable unless it can be restarted promptly, without performing maintenance. If the attempt at restart is unsuccessful, the SSC is inoperable. The time frame for compensatory action begins at the time of the initial trip.

C A SUPPORTED SSC is inoperable when a SUPPORT SYSTEM is not capable of performing its related support function. However, if it is determined that the SSC is capable of performing its intended function, even with an inoperable SUPPORT SYSTEM, then the TS SUPPORTED SYSTEM may be considered OPERABLE.

D. Failure of a SSC to meet quantitative acceptance criteria specified in Surveillance Procedures is inoperable unless the Surveillance Procedure acceptance criteria is more conservative than the existing TS SR acceptance criteria and the results of the surveillance is clearly within the acceptance criteria of the TS SR.

E. A SSC is inoperable if it fails to meet a safety function requirement identified in a docketed letter to the NRC that specifically describes its functional capability/requirement.

F. A SSC is inoperable if its configuration results in the LOSF or a loss of capability to withstand a single failure, if required.

G. If calculation indicates that a SSC will not be able to perform as needed to mitigate the affects of a design basis accident, then the SSC is inoperable.

BRAIDWOOD UNITS 1 & 2 31 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 2 (cont'd)

ITEMS POTENTIALLY INOPERABLE A. A suspected error in any analysis that could affect the functional status of a SSC.

B. A lack of documentation that could affect the functional status of a SSC.

C. A minor deviation (incorrect bolt size, tolerance/clearance, etc.) found in a SSC. Also included in this category are items such as unevaluated installation of lead shielding on a system or removal of a component from a system without using temporary restraints and without a prior Engineering evaluation.

D. An unfulfilled EQ installation or maintenance requirement for a component or device where the impact is not obvious.

EXAMPLE: The EQ Program may require O-rings be replaced with new O-rings every time a cover is removed from a device and at least once every five years. The consequences of failure to replace the O-ring at the end of the five year interval may not be clear, and may or may not cause the device to be inoperable.

EXAMPLE: An unidentified wire is found in an EQ valve operator and there is not sufficient information available to determine whether the wire is suitable for the application.

E. An item found in nonconformance with electrical separation criteria specified in the UFSAR.

F. An item found in noncompliance with physical separation or mechanical isolation requirements specified by Plant Drawings,Operating Procedures, Fire Hazards Analysis, etc.

G. Equipment found out-of-tolerance in the nonconservative direction.

H. When a SSC is found to be outside its design basis, it may be considered operable when it is judged that the SSC is capable of performing its specified functions(s). Further testing calculations, etc. may be required to support this position.

I. Discovery of an unanalyzed condition associated with the current design basis (i.e., an unanalyzed condition which should have been analyzed).

BRAIDWOOD UNITS 1 & 2 32 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 2 (cont'd)

SFDP EVALUATION - EXAMPLE 1 EXAMPLE 1: At 0100, with Unit 2 in MODE 1, the Unit 2 4160V "242" bus is determined to be inoperable due to degraded voltage. No other TS SSC inoperabilities exist.

The 4160 V "242" bus is a SUPPORT SSC, addressed by TS LCO 3.8.9. Required Action requires restoring the bus to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

The following is the LOSF determination for the SUPPORTED SYSTEM:

LCO 3.3.1 RTS Instrumentation; all channels are capable of performing their design function; no LOSF exists.

LCO 3.3.2 EFSAS Instrumentation; all channels are capable of performing their design function; no LOSF exists.

LCO 3.3.3 PAM Instrumentation; since at least one channel is OPERABLE, no LOSF exists.

LCO 3.3.4 Remote Shutdown System; the functions of the PAM are still OPERABLE since the "241" 4160 V bus is OPERABLE, no LOSF exists.

LCO 3.3.5 LOP Diesel Generator Start Inst; since there is still one bus with two channels of loss of voltage Function and two channels of degraded voltage Function still OPERABLE, no LOSF exists.

LCO 3.3.6 Containment Ventilation Isolation Instrumentation; since one rad monitor is still OPERABLE, no LOSF exists.

LCO 3.3.7 Control Room Ventilation Filtration System Actuation Instrumentation; since the opposite train of the VC Filtration System is OPERABLE and powered by the offsite train, no LOSF exists.

LCO 3.3.8 Fuel Handling Building Exhaust Filter Plenum (FHB)

Ventilation System Actuation Instrumentation; since the other channel is OPERABLE, no LOSF exists.

BRAIDWOOD UNITS 1 & 2 33 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 2 (cont'd)

LCO 3.4.9 Pressurizer; the Pressurizer is still OPERABLE since two groups of heaters is still OPERABLE, no LOSF exists.

LCO 3.4.11 Pressurizer PORVs; since bus 241 is still OPERABLE the PORVs are OPERABLE since power is still being supplied, no LOSF exists.

LCO 3.4.15 RCS Leakage Detection Instrumentation is not lost, no LOSF exists.

LCO 3.5.2 ECCS - Operating, because Charging, Safety Injection, and RHR are OPERABLE, no LOSF exists.

LCO 3.6.3 Containment Isolation Valves; loss of one bus of the 4160 volt will not render the Containment Isolation Valves inoperable, no LOSF exists.

LCO 3.6.6 Containment Spray and Containment Cooling Trains, Containment Cooling is not considered inoperable. No LOSF exists because only one train is required.

LCO 3.6.7 Spray Additive Tank; with a loss of 242v bus, the spray Additive Tank is still OPERABLE, no LOSF exists.

LCO 3.7.2 Main Steam Isolation Valves; there will be no loss of function since the MSIVs will fail in the closed position.

LCO 3.7.4 Steam Generator Power Operated Valves; no LOSF exists since the valves would be placed in a closed position which is their intended position for mitigation of an accident.

BRAIDWOOD UNITS 1 & 2 34 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 2 (cont'd)

LCO 3.7.5 Auxiliary Feedwater is considered OPERABLE. No LOSF exists because only one train is required.

LCO 3.7.7 Component Cooling Water, is considered OPERABLE because the other subsystem is OPERABLE, no LOSF exists.

LCO 3.7.8 Essential Service Water is considered OPERABLE because SX can perform its safety function with one train no LOSF exists.

LCO 3.7.10 Control Room Ventilation Filtration System; the other train of VC Filtration System is still OPERABLE, no LOSF exists.

LCO 3.7.11 Control Room Ventilation Temperature Control System; the other train of VC Temperature Control is still OPERABLE, no LOSF exists.

LCO 3.7.12 Nonessential Area Exhaust Filter Plenum Ventilation System; the other 2 trains of Nonessential Area Exhaust Filter Plenum Ventilation System are OPERABLE, no LOSF exists.

LCO 3.7.13 Fuel Handling Building Ventilation System; the other train is still OPERABLE, no LOSF exists.

LCO 3.8.1 AC Sources-Operating; the opposite train is OPERABLE, no LOSF exists.

LCO 3.8.4 DC Sources - Operating; the batteries and chargers are OPERABLE, no LOSF exists.

LCO 3.8.7 Inverters - Operating; the other inverters are OPERABLE, no LOSF exists.

Conclusions:

No LOSF exists. LCO 3.0.6 may be entered with a Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months to restore the inoperable bus to OPERABLE status, beginning at 0100.

BRAIDWOOD UNITS 1 & 2 35 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 2 (cont'd)

SFDP EVALUATION - EXAMPLE 2 EXAMPLE 2: At 0500, with Unit 2 in MODE 1, both channels of the Containment Radiation-High monitor are determined to be inoperable.

This instrumentation supports the Containment Ventilation Isolation instrumentation by providing input to the Automatic Actuation Logic and Actuation relays, and Containment Radiation-High. Since these supported functions require at least 2 channels, for the monitors, entry must be made into the Required Actions for LCO 3.3.6.

These Actions directly specify to enter applicable Conditions and Required Actions of LCO 3.6.3 for containment valves made inoperable by isolation instrumentation (Required Action B.1). As stated in LCO 3.0.6, when the SUPPORT SYSTEM SSC Required Actions provide direction for SUPPORTED SYSTEM SSCs, the applicable SUPPORTED SYSTEM SSC Conditions and Required Actions shall be entered. This effectively precludes the use of LCO 3.0.6.

Conclusion:

The LCO 3.3.6 Required Actions should be performed, as well as those for all the inoperable SUPPORTED SYSTEMS. The SFDP will not be entered since LCO 3.0.6 cannot be used.

BRAIDWOOD UNITS 1 & 2 36 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 2 (cont'd)

SFDP EVALUATION - EXAMPLE 3 EXAMPLE 3: At 0130, with both Units at 100% power, the Spray Additive Tank is determined to be inoperable.

Per LCO Bases 3.6.7, the Spray Additive Tank provides sodium hydroxide through the suction of the Containment Spray Pumps and into the containment. The purpose of the sodium hydroxide is to provide iodine scrubbing in the case of a LOCA.

In the event the Spray Additive Tank is inoperable, it will not disable the Containment Spray Pump to perform its intended safety function which is to spray borated water from the RWST into containment in order to reduce pressure and temperature. Since this function will still be performed, even with the Spray Additive Tank inoperable, it is not considered to be a SUPPORT SYSTEM for the Containment Spray Pump.

The same is not true in the case where the Containment Spray Pump is inoperable. In this case the Containment Spray Pump is a SUPPORT SYSTEM for the Spray Additive Tank. If the Containment Spray Pump is inoperable, the sodium hydroxide, function of the Spray Additive Tank, will not be sprayed into containment. In this case the Spray Additive Tank is a SUPPORTED SYSTEM to the Containment Spray Pump.

Conclusion:

Since the Spray Additive Tank is not a SUPPORT SYSTEM for the Containment Spray Pumps, both trains of Containment Spray are OPERABLE, and no LOSF exists.

BRAIDWOOD UNITS 1 & 2 37 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O ATTACHMENT 2 (cont'd)

SFDP EVALUATION - EXAMPLE 4 EXAMPLE 4: At 1300, Unit 1 was at 100% power and Train B Essential Service Water (SX) System became inoperable with the associated LCOAR implemented. At 1400, the Condensate Storage Tank (CST) becomes inoperable.

Train B SX is a SUPPORT SYSTEM to the Auxiliary Feedwater (AF) Pumps (SUPPORTED SYSTEM). No LOSF exists at this time (1300 to 1359 hours0.0157 days 0.378 hours 0.00225 weeks 5.170995e-4 months ) since Train A SX is intact and, being a cross-tied system,can supply all the SX needs to both trains of AF, etc. and since no redundant systems are inoperable.

The Actions for SX (LCO 3.7.8, Action A.1) are entered. The Actions for AF (LCO 3.7.5) are not entered since AF is operable.

At 1400 hours0.0162 days 0.389 hours 0.00231 weeks 5.327e-4 months , the CST becomes inoperable. The CST (LCO 3.7.6) is considered to be a SUPPORT SYSTEM to the AF.

However, the CST is not the safety related water supply to the AF, it is only the preferred supply. At this point the plant is in 2 LCOs and a SFDP evaluation is warranted. In this case, the evaluation should show that no LOSF exists for the following reason:

The CST does support the AF, however, the CST is not the safety related water supply to the AF, it is only the preferred supply. Therefore, the AF is not inoperable due to the CST being inoperable.

Furthermore, SX remains available to AF.

Conclusion:

A LOSF does not exist and Technical Specification 3.7.6 is entered for the CST inoperability.

BRAIDWOOD UNITS 1 & 2 38 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O COMPLETION TIME EXTENSIONS APPLICABLE TO THE SFDP EXAMPLES RULES OF USAGE FOR COMPLETION TIME EXTENSIONS

1. Single SUPPORT SYSTEM inoperable affecting SUPPORTED SYSTEM(s)

With a single SUPPORT SYSTEM inoperable, the affected SUPPORTED SYSTEM(s) LCOARs entry(s) is not required to be entered unless directed by the SUPPORT SYSTEM Required Actions. Reference Case A.

2. Multiple SUPPORT SYSTEMS become inoperable affecting the same SUPPORTED SYSTEM(s)

When a SUPPORT SYSTEM becomes inoperable, the Required Action(s) LCOAR entry is not required to be entered unless directed by the SUPPORT SYSTEM Required Actions. In the event additional SUPPORT SYSTEM(s) become inoperable during the Completion Time of the first SUPPORT SYSTEM, the LCOAR entry(s) of the SUPPORTED SYSTEM(s) may be delayed by either:

a) The maximum allowed Completion Time of the SUPPORT SYSTEM(S)

OR b) 2 times the Completion Time for restoration of the SUPPORTED SYSTEM (applied at the time the second SUPPORT SYSTEM becomes inoperable),

whichever is the shorter duration. Reference Cases B and C.

The SFDP requires declaring SUPPORTED SYSTEM(S) inoperable if a SUPPORT SYSTEM inoperability renders the SUPPORTED SYSTEM incapable of performing its required function. However, the Conditions and Required Actions of the SUPPORTED SYSTEM do not have to be entered (i.e., the LCO Required Actions are not entered) except as directed by the SUPPORT SYSTEM Required Actions.

Consequently, it is possible to have SUPPORTED SYSTEM(S) inoperable for longer periods of time than their respective Completion Time would allow on their own. Per Technical Specifications 5.5.15, the SFDP must include measures to ensure that the SUPPORTED SYSTEM's Completion Times are not inappropriately extended.

The Required Action may be delayed only if the inoperability is due solely to an inoperability of a SUPPORT SYSTEM. If a SUPPORTED SYSTEM is made directly inoperable, then the LCO and Required Actions are entered at the time of direct inoperability per LCO 3.0.2.

BRAIDWOOD UNITS 1 & 2 39 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O The following criteria apply to Completion Time extension:

CASE A:

If only one SUPPORT SYSTEM is inoperable, General Rule 1 applies and the SUPPORTED SYSTEM LCOAR entry need not be entered unless directed by the SUPPORT SYSTEM Required Actions.

Example:

System A (SUPPORTED SYSTEM) Action Completion Time - 3 days System B (SUPPORT SYSTEM) Action Completion Time - 7 days LCOAR entry on SUPPORTED SYSTEM A is not required to be entered.

BRAIDWOOD UNITS 1 & 2 40 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O Case B:

The SUPPORT SYSTEMS become inoperable at different times. The LCOAR entry for the SUPPORTED SYSTEM may be delayed as follows:

Example:

System A (SUPPORTED SYSTEM) Action Completion Time - 7 days System B (SUPPORT SYSTEM) Action Completion Time - 3 days System C (SUPPORT SYSTEM) Action Completion Time - 3 days System B and C support System A System B (SUPPORT SYSTEM) is inoperable at T = 0 days Therefore: System A (SUPPORTED SYSTEM) Conditions and Required Action(s) need not be entered unless directed by the System B (SUPPORT SYSTEM)

Required Actions.

System C (SUPPORT SYSTEM) becomes inoperable 2 days after System B (SUPPORT SYSTEM) became inoperable. System B is still not OPERABLE.

Therefore: At T = 0 days until the second SUPPORT SYSTEM becomes inoperable, General Rule 1 is applied. At this point, System B (SUPPORT SYSTEM) Completion Time is 3 days. System A (SUPPORTED SYSTEM) LCOAR is not entered unless directed by the System B (SUPPORT SYSTEM) Required Actions.

At T = 2 days, System C (SUPPORT SYSTEM) becomes inoperable. System C (SUPPORT SYSTEM) also supports System A (SUPPORTED SYSTEM) initiating General Rule 2 at T = 2 days. System C (SUPPORT SYSTEM) has a Completion Time of 3 days. Therefore, the maximum Completion Time for this scenario is from T = 0 days to T = 3 days for System B (SUPPORT SYSTEM), and from T = 2 days to T = 5 days for System C (SUPPORT SYSTEM). The maximum delay time for System A (SUPPORTED SYSTEM) LCOAR entry is 5 days because:

System B (SUPPORT SYSTEM) Completion Time is T = 3 days System C (SUPPORT SYSTEM) Completion Time is T = 5 days T = 5 days is the longer of the two completion times and is compared with the two times the SUPPORTED SYSTEMS's completion time for restoration. System C (SUPPORT SYSTEM) completion time is at T = 5 days. System A (SUPPORTED SYSTEM) completion time limit is 2 X 7 = 14 days after T = 2 days. T = 2 + 14 or a total of 16 days.

Since T = 5 days is less than T = 16 days, the maximum allowed delay time to enter the System A (SUPPORTED SYSTEM) LCOAR is the shorter of the two, 5 days.

BRAIDWOOD UNITS 1 & 2 41 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O CASE C:

Two SUPPORT SYSTEMS become inoperable at different times. The LCOAR entry for the SUPPORTED SYSTEM may be delayed as follows:

Example:

System A (SUPPORTED SYSTEM) Action Completion Time - 3 days System B (SUPPORT SYSTEM) Action Completion Time - 3 days System C (SUPPORT SYSTEM) Action Completion Time - 7 days System B and C support System A Case C1 - System B (SUPPORT SYSTEM) B becomes inoperable at T = 0 days.

System B (SUPPORT SYSTEM) with a Completion Time of 3 days, renders System A (SUPPORTED SYSTEM) inoperable. General Rule 1 is applied, which allows an overall Completion Time of 3 days for the System B (SUPPORT SYSTEM). The LCOAR for System A (SUPPORTED SYSTEM) is not required to be entered unless directed by the System B (SUPPORT SYSTEM) Required Actions.

At T = 1 day, System C (SUPPORT SYSTEM) becomes inoperable and has a Completion Time of 7 days. System C (SUPPORT SYSTEM) also supports System A (SUPPORTED SYSTEM). System B (SUPPORT SYSTEM) continues to remain inoperable through its Completion Time T = 3 days.

Once System C (SUPPORT SYSTEM) becomes inoperable concurrent with System B, General Rule 2 is applied at T=1, the Completion Times are:

T = 0 days to T = 3 days for System B (SUPPORT SYSTEM), and T = 1 day to T = 8 days for System C (SUPPORT SYSTEM).

At T = 3 days System B (SUPPORT SYSTEM) is not declared OPERABLE, and the appropriate subsequent Required Actions of System B (SUPPORT SYSTEM) are entered. The Required Actions of System A (SUPPORTED SYSTEM) A are not entered (unless SUPPORT SYSTEM B or C Required Actions specifically direct them to be entered) until T = 7 days (2 times System A's Completion Time after T = 1 day).

T = 7 days is less than System C's T = 8 days Completion Time. Not entering the Required Actions for System A (SUPPORTED SYSTEM) is allowed under LCO 3.0.6 provided the inoperability of System A (SUPPORTED SYSTEM) is solely due to the inoperability of System B (SUPPORT SYSTEM) and subsequently System C (SUPPORT SYSTEM).

BRAIDWOOD UNITS 1 & 2 42 of 43 Revision 106 Technical Requirements Manual

TRM Safety Function Determination Program (SFDP)

Appendix O Case C2 - At T = 0 day, System B (SUPPORT SYSTEM) becomes inoperable, with a Completion Time of 3 days, and renders System A (SUPPORTED SYSTEM) inoperable. General Rule 1 is applied, which allows an overall Completion Time of 3 days for System B (SUPPORT SYSTEM).

At T = 1 days, System C (SUPPORT SYSTEM) becomes inoperable and has a Completion Time of 7 days. System C (SUPPORT SYSTEM) also supports System A (SUPPORTED SYSTEM). When System C (SUPPORT SYSTEM) becomes inoperable, General Rule 2 is triggered requiring System A (SUPPORTED SYSTEM) LCOAR entry no later than day 7 (2 x 3 days after T=1). The Completion Times are:

From T = 0 day to T = 3 days for System B (SUPPORT SYSTEM), and From T = 1 day to T = 8 days for System C (SUPPORT SYSTEM).

System B (SUPPORT SYSTEM) is declared OPERABLE at T = 2 days.

System C (SUPPORT SYSTEM) remains inoperable and consequently, System A (SUPPORTED SYSTEM) is still inoperable solely due to its SUPPORT SYSTEM (System C) being inoperable. At this point, General Rule 2 remains in effect to eliminate continuous alternating inoperabilities. This would allow the Required Action entry for System A (SUPPORTED SYSTEM) to still be delayed only until day 7 (T = 1 + 6 days).

BRAIDWOOD UNITS 1 & 2 43 of 43 Revision 106 Technical Requirements Manual

TRM Containment Leakage Rate Testing Program Appendix P CONTAINMENT LEAKAGE RATE TESTING PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTIONS TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 6 Revision 105 Technical Requirements Manual

TRM Containment Leakage Rate Testing Program Appendix P 1.1 PURPOSE This Program provides controls to implement the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions including routine inspections, tests, and reporting requirements pursuant to Technical Specification (TS) 5.5.16, "Containment Leakage Rate Testing Program." The Program inspection and test frequencies and associated acceptance criteria shall be in accordance with the guidelines contained in NEI 94-01, Revision 3-A, and ANSI/ANS-56.8-2002 as modified by approved exceptions as specified in TS 5.5.16.

1.2 REFERENCES

1. Technical Specifications:

a. 3.6.1, "Containment"

b. 3.6.2, "Containment Air Locks" c. 3.6.3, "Containment Isolation Valves" d. 5.5.16, Containment Leakage Rate Testing Program e. TS Amendment No. 149, Request for Amendment to Technical Specification 5.5.16, Containment Leakage Rate Testing Program, issued April 2, 2008 f. TS Amendment No. 215, Request for Amendment to Technical Specification 5.5.16, Containment Leakage Rate Testing Program, issued September 10, 2020

2. UFSAR:

a. Section 6.2, "Containment Systems"

b. Section 6.2.6.1, "Containment Integrated Leakage Rate Test"

c. Section 6.2.6.2, "Containment Penetration Leakage Rate Test"

3. NRC/Industry Documents:

a. NEI 94-01 Rev. 3-A, "Industry Guideline for BRAIDWOOD UNITS 1 & 2 2 of 6 Revision 105 Technical Requirements Manual

TRM Containment Leakage Rate Testing Program Appendix P Implementing Performance-Based Option of 10 CFR 50, Appendix J"

b. ANSI/ANS-56.8-2002, "Containment System Leakage Testing Requirements"

c. 10 CFR 50, Appendix J, "Primary Reactor Containment Leakage Testing for Water Cooled Power Reactors"

d. Not used

e. NUREG 1493, Performance-Based Containment Leak-Test Program

4. Braidwood Maintenance Rule 10 CFR 50.65 1.3 DEFINITIONS AND/OR ACRONYMS

1. PERFORMANCE CRITERIA - The performance standards against which test results are to be compared for establishing the acceptability of the containment system as a leakage-limiting boundary.

2. CONTAINMENT SYSTEM - The principal barrier, after the reactor coolant pressure boundary, to prevent the release of quantities of radioactive material that would have a significant radiological effect on the health of the public.

3. OVERALL INTEGRATED LEAKAGE RATE - The total leakage rate through all tested leakage paths, including containment welds, valves, fittings, and components that penetrate the primary containment, expressed in units of weight percent of contained air mass at test pressure per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

4. La - The maximum allowable primary containment leakage rate, La, shall be 0.20% of the primary containment air weight per day at the calculated peak containment pressure (Pa).

5. Pa - The maximum calculated primary pressure, Pa, (Unit 1 =

42.8 psig) (Unit 2 = 38.4 psig) for the design basis loss of coolant accident.

6. TYPE A TEST - A test to measure the containment system overall integrated leakage rate under conditions representing DBA containment pressure and systems alignments.

BRAIDWOOD UNITS 1 & 2 3 of 6 Revision 105 Technical Requirements Manual

TRM Containment Leakage Rate Testing Program Appendix P

7. TYPE B TEST - A Local Leakage Rate Test (LLRT) intended to detect or measure leakage across pressure-retaining or leakage-limiting boundaries other than valves, such as:

a. containment penetrations whose design incorporates resilient seals, gaskets, sealant compounds, expansion bellows, or flexible seal assemblies;

b. seals, including door operating mechanism penetrations, which are part of the primary containment; or

c. doors and hatches with resilient seals or gaskets except for seal-welded doors.

8. TYPE C TESTS - A pneumatic test to measure leakage rates from containment isolation valves, which are potential gaseous leakage pathways from containment during a design basis LOCA.

9. UPPER CONFIDENCE LIMIT (UCL) - A calculated value constructed from test data that places a statistical upper bound on the true integrated leakage rate (%/24h).

10. MINIMUM PATHWAY LEAKAGE RATE (MNPLR) - The minimum leakage rate that can be attributed to a penetration leakage path (e.g., the smaller of either the inboard or outboard barrier's individual leakage rates).

11. MAXIMUM PATHWAY LEAKAGE RATE (MXPLR) - The maximum leakage rate attributed to a penetration leakage path. The MXPLR is the larger, not the total, leakage of two barriers in series.

1.4 PROGRAM DESCRIPTION This Program provides administrative guidelines for the Braidwood Containment Leakage Rate Testing Program, guidelines for the coordination of inspection, trending, reporting, performance evaluation, repair, establishing surveillance intervals, and regulatory compliance for Type A, B, and C leakage testing.

10 CFR 50 Appendix J Option B allows the use of a performance-based program to perform the Type A, B, and C containment leakage testing. Program requirements are further defined in References 3.a, 3.b, and 3.c. These documents require that periodic testing be conducted to verify the leakage integrity of the containment and those systems and components which penetrate the containment.

The objective for monitoring performance of TYPE A TESTS focuses BRAIDWOOD UNITS 1 & 2 4 of 6 Revision 105 Technical Requirements Manual

TRM Containment Leakage Rate Testing Program Appendix P on verifying the leakage integrity of a passive containment structure.

TYPE B and C TESTS focus on assuring that containment penetrations are essentially leak tight. The results of these tests are evaluated against performance criteria and the required testing intervals are adjusted based on the performance of the component/system.

Option B allows licensees with good ILRT performance history to reduce the TYPE A TEST frequency from three tests in 10 years to one test in 15 years. Exception to the Option B TYPE A TEST frequency is as specified in TS 5.5.16. For TYPE B and TYPE C TESTS, Option B allows Braidwood Station to reduce testing frequency based on the experience history of each component, and establish controls to ensure continued performance during the extended testing interval. Type B and C LLRT intervals utilize the requirements and guidance as stipulated in Reference 3.a.

1.5 PROGRAM IMPLEMENTATION Inspection, trending, reporting, performance evaluation, repair, surveillance intervals, and regulatory compliance for Type A, B, and C leakage testing shall be initiated and maintained in accordance with the Braidwood Containment Leakage Rate Testing Program.

1.6 ACCEPTANCE CRITERIA Acceptance criteria for TYPE A TESTS are contained in applicable Station Procedures. Acceptance criteria for TYPE B and C TESTS are contained in applicable Station Procedures. The acceptance criteria specified in the individual leak rate test procedures are administrative guidelines that are used to help maintain low containment leakage rates. The acceptance criteria associated with the individual leak rate test procedures are not Technical Specification requirements with the exception of the personnel/emergency airlock door seals and overall air lock leakage. The acceptance criteria associated with the personnel/emergency airlock door seals and overall air lock leakage are as specified in TS 5.5.16.

BRAIDWOOD UNITS 1 & 2 5 of 6 Revision 105 Technical Requirements Manual

TRM Containment Leakage Rate Testing Program Appendix P 1.7 LCOARS/COMPENSATORY MEASURES If any abnormalities in containment leakage exceed the acceptance criteria, the Shift Manager will be immediately notified. The Shift Manager shall determine OPERABILITY status and implement a LCOAR as applicable. In addition, an Issue Report (IR) may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

1.8 REPORTING REQUIREMENTS Any reporting requirements associated with acceptance criteria of this Program not being met shall be reported in accordance with the requirements specified in the implementing procedures.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10 CFR 50.59 Review and a Station Qualified Review (SQR). The SQR composition shall include the Regulatory Assurance Department in all cases. As part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager.

Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and was determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 6 of 6 Revision 105 Technical Requirements Manual

TRM TRM Control Program Appendix S TECHNICAL REQUIREMENTS MANUAL CONTROL PROGRAM TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA

1. 7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 &2 1 of 12 Revision 64 Technical Requirements Manual

TRM TRM Control Program Appendix S 1.1 PURPOSE The purpose of this Program is to provide guidance for identifying, processing, and implementing changes to the Technical Requirements Manual (TRM). This Program implements and satisfies the requirements of TRM Section 1.6, "Technical Requirements Manual Revisions."

This Program is applicable to the preparation, review, implementation, and distribution of changes to the TRM. This Program also provides guidance for preparing TRM Change Packages for distribution.

1.2 REFERENCES

1. TRM Section 1.6, "Technical Requirements Manual Revisions"

2. 10 CFR 50.4, "Written Communications"

3. 10 CFR 50.59, "Changes, Tests and Experiments"

4. 10 CFR 50.71, "Maintenance of Records, Making of Reports"

5. 10 CFR 50.90, "Application for Amendment of License or Construction Permit" 1.3 DEFINITIONS AND/OR ACRONYMS 10 CFR 50.59 REVIEW - A written regulatory evaluation which provides the basis for the determination that a change does, or does not, require NRC approval pursuant to 10 CFR 50.59. The scope of the evaluation should be commensurate with the potential safety significance of the change, but must address the relevant safety concerns included in the Safety Analysis Report and other owner controlled documents. The depth of the evaluation must be sufficient to determine whether or not NRC approval is required prior to implementation. Depending upon the significance of the change, the evaluation may be brief; however, a simple statement of conclusion is not sufficient.

BRAIDWOOD UNITS 1 &2 2 of 12 Revision 64 Technical Requirements Manual

T~

T~ Control Program Appendix S EDITORIAL CHANGE - Editorial changes include correction of punctuation, insignificant word or title changes, style or format changes, typographical errors, or correction of reference errors that do not change the intent, outcome, results, functions, processes, responsibilities, or performance requirements of the item being changed. Changes in numerical values shall not be considered as editorial changes. Editorial changes do not constitute a change to the T~ and therefore do not require further 10 CFR 50.59 Reviews. If the full scope of this proposed change is encompassed by one or more of the below, then the change is considered editorial.

Rewording or format changes that do not result in changing actions to be accomplished.

Deletion of cycle-specific information that is no longer applicable.

Addition of clarifying information, such as:

Spelling, grarrmar, or punctuation changes Changes to references Name or title references 1.4 PROGRAM DESCRIPTION

1. A Licensee may make changes to the T~ without prior NRC approval provided the changes do not require NRC approval pursuant to 10 CFR 50.59.

2. Changes that require NRC approval pursuant to 10 CFR 50.59 shall be submitted to the NRC pursuant to 10 CFR 50.90 and reviewed and approved by the NRC prior to implementation.

3. The T~ is part of the Updated Final Safety Analysis Report (UFSAR) by reference and shall be maintained consistent with the remainder of the UFSAR.

4. If a change to the T~ is not consistent with the remainder of the UFSAR, then the cognizant Engineer shall prepare and submit a UFSAR Change Package when the T~ Change Request is submitted to Regulatory Assurance (RA) for processing.

5. Changes to the T~ that do not require prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.7l(e), as modified by approved exemptions.

BRAIDWOOD UNITS 1 &2 3 of 12 Revision 64 Technical Requirements Manual

TRM TRM Control Program Appendix S

6. TRM changes associated with a Technical Specifications (TS) I Amendment shall be implemented consistent with the implementation requirements of the TS Amendment.

7. RA is responsible for the control and distribution of the TRM. In order to prevent distribution errors (i.e.,

omissions or duplications), RA shall maintain the master TRM distribution list.

1.5 PROGRAM IMPLEMENTATION

1. TRM Change Requestor identifies the need for a revision to the TRM and notifies the RA Licensing Engineer (i.e.,

hereafter referred to as RA LE). A TRM change can be initiated through any Stations' RA. TRM Change Requestor notifies their counterparts on the need for a change.

2. RA LE notifies their counterparts of identified need for revision to the TRM.

3. RA LE assigns a TRM Change Request Number CCR#).

4. RA LE drafts TRM changes considering format, rules of usage, and technical adequacy.

5. RA LE makes an electronic version of the proposed TRM changes available in a working directory for use in the preparation of the 10 CFR 50.59 REVIEW and Station Qualified Review (SQR) process. The RA LE shall ensure that the master electronic TRM files are revised per step 12 below upon receiving SOR approval. The Revision number in the footer should be a sequential number (i.e., 1, 2, etc.).

BRAIDWOOD UNITS 1 &2 4 of 12 Revision 64 Technical Requirements Manual

TRM TRM Control Program Appendix S

NITTE *

If the TRM changes are applicable to more than one *

Station, the following steps should be performed *

concurrently for each Station. *

6. TRM Change Requester provides a 10 CFR 50.59 REVIEW for the TRM changes in accordance with appropriate plant procedures.

An exception to this requirement applies when the changes are being requested in order to reflect an approved NRC Safety Evaluation (SE) associated with a site specific Operating License or TS change. The NRC SE is sufficient to support the changes provided it has been determined that the changes are consistent with and entirely bounded by the NRC SE. A 10 CFR 50.59 REVIEW shall be performed for TRM changes that reflect generic industry approval by an NRC SE to determine site specific applicability. A 10 CFR 50.59 REVIEW is not required for an EDITORIAL CHANGE.

7. TRM Change Requester comp1etes Attachment A, "Techni ca 1 Requirements Manual Change Request Form," as follows:

a. Identifies the affected sections, and includes a copy of the proposed TRM changes;

b. Briefly summarizes the changes including the TLCO, Action, Surveillance Requirement, or Bases (if applicable) to which the changes apply;

c. Briefly summarizes the reason for the changes and attaches all supporting documentation;

d. Identifies any schedule requirements and proposed implementation date that apply (i.e., describe any time limitations that might apply which would require expedited processing). If the changes are outage related, then checks "yes" and lists the applicable outage identifier;

e. Identifies any known implementation requirements such as procedure changes, UFSAR changes, Passport changes, Reportability Manual revisions, pre-implementation training requirements, etc.;

BRAIDWOOD UNITS 1 &2 5 of 12 Revision 64 Technical Requirements Manual

T~

T~ Control Program Appendix S

f. If a 10 CFR 50.59 REVIEW was prepared to support the T~ changes, the Requester then checks the appropriate box, lists the associated 10 CFR 50.59 REVIEW Number, and attaches the original;

g. If the changes to the T~ are the result of an approved NRC SE associated with a site specific Operating License or TS change and the scope of the changes determined to be consistent with and entirely bounded by the NRC SE, then the Requester checks the appropriate box and attaches a copy;

h. If the changes to the T~ are EDITORIAL CHANGES, then the Requester checks the appropriate box and no 10 CFR 50.59 REVIEW is required;

i. Signs and dates as Requester and identifies the originating department;

j. Obtains approval to proceed from Department Supervisor (or designee); and

k. Returns Attachment A to the RA LE.

8. RA LE reviews the T~ Change Request Form, including supporting documentation, and documents the review by signing Attachment A. The review verifies that the following information or documentation is included:

a. Completed 10 CFR 50.59 REVIEW. If the changes are related to an approved NRC SE associated with a site specific Operating License or TS change and determined to be entirely bounded by the NRC SE, then only a copy of the SE is required to be attached and no 10 CFR 50.59 REVIEW is required. A 10 CFR 50.59 REVIEW is not required for an EDITORIAL CHANGE;

b. Identification of known documents requiring revisions; and

c. Completed UFSAR Change Request with supporting documentation, in accordance with appropriate plant procedures, if applicable.

9. If the T~ change is not an EDITORIAL CHANGE, the RA LE/T~

Change Requester obtains SOR approval of the T~ change by performing the following:

BRAIDWOOD UNITS 1 &2 6 of 12 Revision 64 Technical Requirements Manual

TRM TRM Control Program Appendix S

a. RA LE prepares the TRM Change SOR package. The SOR package shall include Attachment A (including completed 10 CFR 50.59 REVIEW or NRC SE) and the revised TRM pages. Attachment A is provided for the purpose of reviewing and finalizing the implementation requirements and ensuring the necessary actions have been initiated. RA LE shall assign Action Tracking (AT) items, as necessary, to track implementation requirements;

b. TRM Change Requestor submits the TRM Change SOR package to the SOR Conmittee members for a preliminary review. The SOR composition shall include RA and Operating Departments in all cases; and

c. TRM Change Requestor resolves preliminary review conments and finalizes the TRM Change SOR package.

10. The RAM shall determine the need for Plant Operations Review Conmittee (PORC) approval. The need for PORC approval shall be documented on Attachment A.

11. RA LE/TRM Change Requestor obtains PORC approval, if necessary.

12. After approval of the TRM changes by SOR/PORC, RA LE ensures that the controlled master electronic files are updated.

13. RA LE completes Attachment B, "Technical Requirements Manual Change Instruction Form," as follows:

a. Indicates the effective date of the TRM changes consistent with the SOR/PORC approval or TS amendment required implementation date. If the TRM change is a result of a TS Amendment, the update shall be implemented consistent with the implementation requirements of the TS Amendment. Otherwise, the update must be implemented by the date indicated on Attachment B;

b. Lists each page to be removed and inserted, including the Affected Page List; and

c. Provides the updated master file directory for updating Electronic Document Management System (EDMS), if applicable.

BRAIDWOOD UNITS 1 &2 7 of 12 Revision 64 Technical Requirements Manual

T~

T~ Control Program Appendix S

14. RA LE creates a T~ Change Package. The T~ Change Package shall consist of:

1. T~ Change Instruction Form (Attachment B);

2. Revised Affected Page List; and

3. Revised T~ pages.

One RA LE shall assemble and approve the T~ Change Package for distribution and a second RA LE shall perform a peer check to verify completeness of the T~ Change Package.

15. After verifying that SQR/PORC approval of the T~ changes has been obtained and that all AT items assigned to track implementation requirements have been completed, RA LE forwards the T~ Change Package to Station Records Management as notification of the need to update the onsite T~ controlled copies and EDMS, if applicable.

16. RA LE also forwards the T~ Change Package to Cantera Licensing (CL) Records Management as notification of the need to update the offsite (CL) T~ controlled copies and to transmit updates to the offsite (non-CL) T~ controlled copies.

17. Upon completion of updating the onsite T~ controlled copies and EDMS (if applicable), Station Records Management Supervisor signs and dates Attachment B and returns Attachment B to the RA LE.

18. Upon completion of updating the offsite (CL) T~ controlled copies and transmitting updates to the offsite (non-CL) T~

controlled copies, CL Records Management signs and dates Attachment B and returns Attachment B to the RA LE.

20. RA LE ensures that the documentation required to be maintained as a quality record is provided to Station Records Management for the purpose of record retention.

BRAIDWOOD UNITS 1 &2 8 of 12 Revision 64 Technical Requirements Manual

TRM TRM Control Program Appendix S 1.6 ACCEPTANCE CRITERIA Not applicable.

1.7 LCOARS/COMPENSATORY MEASURES An Issue Report may need to be generated to provide proper tracking and resolution of noted problems associated with the implementation of this Program.

The RAM will be responsible for ensuring that Program failures have been resolved.

1.8 REPORTING REQUIREMENTS

- TRM changes requiring prior NRC approval shall be *

submitted in accordance with Reference 5.

TRM changes not requiring prior NRC approval. as described in Section 1.4 of this Program. shall be submitted to the NRC in accordance with 10 CFR 50.?l(e).

1.9 CHANGE CONTROL Changes to this Program, other than EDITORIAL CHANGES. shall include a 10 CFR 50.59 REVIEW and a SOR. The SOR composition shall include RA Department in all cases. For a change to this Program, PORC approval from all Stations is required. The concurrence shall be that the other Stations are implementing the same changes or that the changes have been reviewed and determined not to be applicable to the other Stations.

BRAIDWOOD UNITS 1 &2 9 of 12 Revision 64 Technical Requirements Manual

TRM TRM Control Program Appendix S ATTACHMENT A TECHNICAL REQUIREMENTS MANUAL CHANGE REQUEST FORM

1. Change Request #: Affected TRM Section(s): _ _ _ _ _ _ _ _ __

2. Description of changes:

3. Reason for changes (attach all supporting documentation):

4. Schedule Requirements:

Outage Related (check one) 0 No 0 Yes, Outage # _ _ __

Other (explain)

5. Implementation Requirements (attach additional pages, as necessary):

Identify the impact of the changes on the following:

Affected D NIA D UFSAR _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

D D D D TS=Ba-se_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

TS D D NRC Safety Evaluation D D Fire Protection R e p o r t - - - - - - - - - - - - - -

0 D NRC Conmitn'Ents - - - - - - - - - - - - - - - -

0 D Vendor Doc~ntation - - - - - - - - - - - - - -

0 D Special Pennits/Licenses _ _ _ _ _ _ _ _ _ _ _ __

D D D D Procedures Envirorvrent~al~Qu~al~if=i-ca-t~io-n _ _ _ _ _ _ _ _ _ _ __

D D Design Basis Doc~ntation D D Engineering Calculations - - - - - - - - - - - - -

0 D Drawings/Prints----------------

0 D PRA Infonnation - - - - - - - - - - - - - - - -

0 D Programs D D Reportabi.,,...11.,..,.*ty.......,..,.Ma-n-ua-.-l---------------

D D QA Topical Report - - - - - - - - - - - - - - -

0 D Passport'---~~~~~~~---------

0 D Pre-I111>lementation Training Required _ _ _ _ _ _ _ __

D D Maintenance Rule D D Offsite Dose Calc~ul.-a.,...,ti~on-.,..,...Ma-nu-a.. - - - - - - - - - -

0 D Ot~r _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

6. Check one:

0 10 CFR 5D. 59 REVIEW Attached' 10 CFR 50. 59 REVIEW #:--,.---,--,.--,..----:-:=:=--==----

0 NRC SE Attached, Changes consistent with and entirely bounded by NRC SE 0 EDITORIAL CHANGE, No 10 CFR 50.59 REVIEW required

7. Requestor: I I (Signature) (Date) (Department)

8. Requesting Supervisor Approval: I (Signature) (Date)

9. PORC Approval Required: 0 Yes 0 No

10. Licensing Engineer Review: I (Signature) (Date)

BRAIDWOOD UNITS 1 &2 10 of 12 Revision 64 Technical Requirements Manual

TRM TRM Control Program Appendix S ATTACHMENT B TECHNICAL REQUIREMENTS MANUAL CHANGE INSTRUCTION FORM FOR ONSITE/OFFSITE DISTRIBUTION AND FOR UPDATING EDMS Braidwood/Byron/Dresden/LaSalle/QC (circle one) TRM Revision # _ _

NOTE: This change is effective as of and shall be implemented by (SQR/PORC or Amendment Implementation Date)

(Date)

Approved for distribution: ~~~~~~~~~~~~~/~~~~-

(RA LE Signature) (Date)

Verified: ~~~~~~~~~~~~~/~~~~-

(RA LE Signature) (Date)

REMOVE REMOVE INSERT INSERT UPDATE EDMS UPDATE EDMS Section Paqe Section Paqe Section Paqe Affected All Affected Page All N/A N/A Paqe List Li st BRAIDWOOD UNITS 1 &2 11 of 12 Revision 64 Technical Requirements Manual

TRM TRM Control Program Appendix S ATIACHMENT B TECHNICAL REQUIREMENTS MANUAL CHANGE INSTRUCTION FORM FOR ONSITE/OFFSITE DISTRIBUTION AND FOR UPDATING EDMS Brai dwood/Byron/Dresden/LaSa 11 e/QC (ci rel e one) TRM Revision # _ _

Station Records Management:

Onsite Distribution Completed: ~--~-------_,--*I_,...,.._..,-_ _ __

(Station Records Mgmt. Supr.) (Date)

EDMS Update Completed: ~-,..------,.----,,----,-1_,..,,,----,------

(St at ion Records Mgmt. Supr.) (Date)

- Return this sheet to: Regulatory Assurance Braidwood/Byron/Dresden/LaSalle/QC (circle one) Station CL Records Management:

Offsite (CL) Distribution Completed:

(CL Records Mgmt. Dept.) <Date)

Offsite (non-CU Distribution Transmitted: -----------'--~~~--

(CL Records Mgmt. Dept.) (Date)

- Return this sheet to: Regulatory Assurance Braidwood/Byron/Dresden/LaSalle/QC (circle one) Station Offsite (non-CL) Controlled Copy Holders:

Offsite (non-CL) Distribution Completed: ---------~!_ _ _ _ _ __

(Signature) (Date)

- Return this sheet to: EXELON GENERATION COMPANY, LLC LICENSING AND REGULATORY AFFAIRS DEPARTMENT 4300 WINFILED ROAD WARRENVILLE, IL 60555 BRAIDWOOD UNITS 1 &2 12 of 12 Revision 64 Technical Requirements Manual

TRM Configuration Risk Management Program Appendix T CONFIGURATION RISK MANAGEMENT PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 4 Revision 9 Technical Requirements Manual

TRM Configuration Risk Management Program Appendix T 1.1 PURPOSE This Configuration Risk Management Program provides a proceduralized process to ensure that a configuration risk assessment is conducted prior to and during performance of maintenance activities that remove SSCs from service.

1.2 REFERENCES

1. Regulatory Guide 1.182, "Assessing and Managing Risk Before Maintenance Activities at Nuclear Power Plants"

2. Regulatory Guide 1.174, "An Approach for using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis"

3. Regulatory Guide 1.177, "An Approach for Plant-Specific-Risk-Informed Decisionmaking: Technical Specifications"

4. NUMARC 93-01, "Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants" 1.3 DEFINITIONS AND/OR ACRONYMS

1. Configuration Risk Management Program - CRMP

2. Probabilistic Risk Assessment - PRA

3. Structure, System, or Component - SSC BRAIDWOOD UNITS 1 & 2 2 of 4 Revision 9 Technical Requirements Manual

TRM Configuration Risk Management Program Appendix T 1.4 PROGRAM DESCRIPTION The CRMP is a subset of the work management process. The CRMP ensures that configuration risk is assessed (probabilistic and/or deterministic), and managed, prior to initiating any maintenance activity consistent with the requirements of 10 CFR 50.65. The CRMP also ensures that risk is reassessed if an emergent condition results in a plant configuration that has not been previously assessed.

Probabilistic risk assessments of online configurations are performed using the level 1 PRA model. Deterministic defense-in-depth evaluations of key safety functions are performed for online and shutdown configurations using a safety function assessment module. Deterministic evaluations of plant configurations that result in a change to initiating event frequency and/or decrease in mitigation capability are performed using a plant transient assessment module.

The CRMP establishes risk thresholds and administrative limits for risk significant configuration out of service times to ensure that average baseline risk is maintained within an acceptable band.

Overall risk is managed to the most restrictive risk threshold specified within the CRMP. Risk significant configurations are generally avoided. If a risk significant configuration occurs, immediate actions are taken to protect redundant/diverse SSCs that are relied upon to mitigate events.

The CRMP requires that the PRA model meet industry certification standards to ensure the scope and quality of the PRA is adequate.

The CRMP requires that the PRA model the current design configuration of the plant, and that plant modification and procedure changes are monitored and evaluated as to the impact on the PRA model. The CRMP establishes compensatory measures in the event a plant configuration is outside the scope of the PRA, or PRA results are unavailable.

1.5 PROGRAM IMPLEMENTATION The CRMP is implemented through a company-wide standard procedure.

The Work Control and Risk Management Engineering Departments are responsible for the CRMP and associated procedure implementation at the stations.

BRAIDWOOD UNITS 1 & 2 3 of 4 Revision 9 Technical Requirements Manual

TRM Configuration Risk Management Program Appendix T 1.6 ACCEPTANCE CRITERIA The configuration risk management acceptance criteria are contained within the implementing procedures.

1.7 LCOARS/COMPENSATORY MEASURES The CRMP provides administrative limits for Technical Specification Limiting Condition of Operation Allowed Outage Time and Maintenance Rule unavailability time. When the administrative limit will be exceeded, compensatory measures are established to reduce risk, limit unavailability time, and implement a contingency plan to restore and/or mitigate the loss of a key safety function.

1.8 REPORTING REQUIREMENTS The normal work management process and control room logs provide adequate documentation of configuration risk.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10 CFR 50.59 evaluation and an Independent Technical Review (ITR). The ITR composition shall include Regulatory Assurance Department in all cases. As a part of the ITR, for a change to this Program, concurrence from Byron and the Braidwood Plant Operations Review Committee (PORC) approval is required.

The concurrence shall be that Byron is implementing the same change or that the change has been reviewed and determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 4 of 4 Revision 9 Technical Requirements Manual

TRM Battery Monitoring and Maintenance Program Appendix U BATTERY MONITORING AND MAINTENANCE PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTIONS TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 4 Revision 26 Technical Requirements Manual

TRM Battery Monitoring and Maintenance Program Appendix U 1.1 PURPOSE This Program provides guidance and clarifying information related to the Battery Monitoring and Maintenance Program. This Program complies with the requirements of Technical Specification (TS) 5.5.17, "Battery Monitoring and Maintenance Program." This program provides for the restoration and maintenance of batteries based on the recommendations given in Reference 2.

1.2 REFERENCES

1. TS 5.5.17, "Battery Monitoring and Maintenance Program"

2. IEEE Standard 450-1995, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications"

3. UFSAR Chapter 8, "Electric Power"

4. NRC Regulatory Guide 1.129, "Maintenance, Testing and Replacement of Large Lead Storage Batteries for Nuclear Power Plants" 1.3 DEFINITIONS AND/OR ACRONYMS

1. ELECTROLYTE LEVEL - The battery cell fluid level found by visual observation.

2. BATTERY CELL PARAMETERS - Voltage, specific gravity, and resistance/impedance.

3. INTER-CELL/INTER-TIER or INTER-RACK CONNECTIONS -

Connections made between rows/steps or racks of individual battery cells.

4. FLOAT VOLTAGE - The voltage applied to a battery to maintain it in a fully charged condition during normal operation.

5. SPECIFIC GRAVITY - A measurement of an individual battery cell electrolyte to determine the state of charge.

6. ELECTROLYTE LEVEL MINIMUM ESTABLISHED DESIGN LIMIT -

1/2 inch below the minimum level indication mark.

7. ELECTROLYTE TEMPERATURE MINIMUM ESTABLISHED DESIGN LIMIT -

60!F.

BRAIDWOOD UNITS 1 & 2 2 of 4 Revision 26 Technical Requirements Manual

TRM Battery Monitoring and Maintenance Program Appendix U 1.4 PROGRAM DESCRIPTION This Program ensures the methodologies, parameters, and corrective actions comply with the reference requirements. This Program addresses the station 125 VDC Engineered Safety Features (ESF) Batteries (Division 11(21) and Division 12(22)).

The OPERABILITY requirements for the 125 VDC ESF Batteries are defined in TS Limiting Conditions for Operation (LCOs) 3.8.4, "DC Sources - Operating," 3.8.5, "DC Sources - Shutdown," and 3.8.6, "Battery Parameters." LCO 3.8.6 delineates the limits on battery float current as well as electrolyte temperature, level, and float voltage.

This Program which complies with the requirements of TS 5.5.17 provides for monitoring various battery parameters based on the recommendations of Reference 2.

1.5 PROGRAM IMPLEMENTATION The Battery Monitoring and Maintenance Program contains the methodology and parameters used to ensure the station batteries are capable of meeting design and operating requirements.

As required by TS 5.5.17, this Program provides for the restoration and maintenance, based on the recommendations of Reference 2 or of the battery manufacturer of the following:

1. Actions to restore battery cells with float voltage

< 2.13 V, and

2. Actions to equalize and test battery cells that had been discovered with electrolyte level below the minimum established design limit.

This Program is implemented by Technical Requirements Manual Limiting Condition for Operation (TLCO) 3.8.c, "Battery Monitoring and Maintenance." The Bases for TLCO 3.8.c is provided in Attachment A to this Program.

BRAIDWOOD UNITS 1 & 2 3 of 4 Revision 26 Technical Requirements Manual

TRM Battery Monitoring and Maintenance Program Appendix U 1.6 ACCEPTANCE CRITERIA The acceptance criteria are contained in station operating or surveillance procedures. TLCO 3.8.c contains the Conditions, Required Actions and associated Completion Times, and Surveillance Requirements required to comply with TS 5.5.17.

1.7 LCOARS/COMPENSATORY MEASURES TLCO 3.8.c provides the Conditions, Required Actions and associated Completion Times, and Surveillance Requirements required to comply with TS 5.5.17. The requirements of TLCO 3.8.c are proceduralized via the associated LCOAR.

1.8 REPORTING REQUIREMENTS There are no reporting requirements for the Battery Monitoring and Maintenance Program.

1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10 CFR 50.59 Review and a Station Qualified Review (SQR). The SQR composition shall include the Regulatory Assurance Department in all cases. As part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager.

Byron and Braidwood shall implement the same change unless the change has been reviewed and determined not to be applicable to Braidwood.

BRAIDWOOD UNITS 1 & 2 4 of 4 Revision 26 Technical Requirements Manual

TRM Battery Monitoring and Maintenance Program Appendix U Attachment A Bases for TLCO 3.8.c, Battery Monitoring and Maintenance

Battery Monitoring and Maintenance B 3.8.c B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.c Battery Monitoring and Maintenance BASES BACKGROUND This TLCO delineates the requirements of the Battery Monitoring and Maintenance Program in accordance with Technical Specification (TS) 5.5.17. A discussion of the batteries and their OPERABILITY requirements is provided in the Bases for LCO 3.8.4, "DC Sources-Operating," LCO 3.8.5, "DC Sources-Shutdown," and LCO 3.8.6, Battery Parameters.

APPLICABLE The initial conditions of Design Basis Accident (DBA) and SAFETY ANALYSES transient analyses in the UFSAR, Chapter 6 (Ref. 1) and Chapter 15 (Ref. 2), assume Engineered Safety Feature systems are OPERABLE. The DC electrical power system provides normal and emergency DC electrical power for the diesel generators, emergency auxiliaries, and control and switching during all MODES of operation.

The OPERABILITY of the DC subsystems is consistent with the initial assumptions of the accident analyses and is based upon meeting the design basis of the plant. This includes maintaining at least one division of DC sources OPERABLE during accident conditions, in the event of:

a. An assumed loss of all offsite AC power or all onsite AC power; and

b. A worst case single failure.

LCO Battery cell parameters must remain within acceptable limits to ensure availability of the required DC power to shut down the reactor and maintain it in a safe condition after an anticipated operational occurrence or a postulated DBA.

Electrolyte limits are conservatively established, allowing continued DC electrical system function even with Category A and B limits not met. OPERABILITY of the batteries is defined by LCO 3.8.6, Battery Parameters.

BRAIDWOOD UNITS 1 & 2 B 3.8.c 1 Revision 26

Battery Monitoring and Maintenance B 3.8.c BASES APPLICABILITY The battery cell parameters are required solely for the support of the associated DC electrical power subsystems.

Therefore, battery electrolyte is only required when the DC power source is required to be OPERABLE. Refer to the Applicability discussion in Bases for LCO 3.8.4 and LCO 3.8.5.

ACTIONS The ACTIONS Table is modified by a Note which indicates that separate Condition entry is allowed for each battery. This is acceptable, since the Required Actions for each Condition provide appropriate compensatory actions for each affected battery. Complying with the Required Actions for one battery may allow for continued operation, and subsequent battery parameters out of limits are governed by separate Condition entry and application of associated Required Actions.

A.1, A.2, and A.3 With one or more cells in one battery not within limits (i.e., Category A limits not met, Category B limits not met, or Category A and B limits not met) but within the Category C limits specified in Table T3.8.6-1 in the accompanying TLCO, the battery is degraded but there is still sufficient capacity to perform the intended function.

Therefore, the affected battery is not required to be considered inoperable solely as a result of Category A or B limits not met and operation is permitted for a limited period.

The pilot cell electrolyte level and float voltage are required to be verified to meet the Category C limits within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (Required Action A.1). This check will provide a quick indication of the status of the remainder of the battery cells. One hour provides time to inspect the electrolyte level and to confirm the float voltage of the pilot cell. One hour is considered a reasonable amount of time to perform the required verification.

BRAIDWOOD UNITS 1 & 2 B 3.8.c 2 Revision 26

Battery Monitoring and Maintenance B 3.8.c BASES ACTIONS (continued)

Verification that the Category C limits are met (Required Action A.2) provides assurance that during the time needed to restore the parameters to the Category A and B limits, the battery is still capable of performing its intended function. A period of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is allowed to complete the initial verification because specific gravity measurements must be obtained for each connected cell. Taking into consideration both the time required to perform the required verification and the assurance that the battery cell parameters are not severely degraded, this time is considered reasonable. The verification is repeated at 7 day intervals until the parameters are restored to Category A or B limits. This periodic verification is consistent with the normal Frequency of pilot cell surveillances.

Continued operation is only permitted for 31 days before battery cell parameters must be restored to within Category A and B limits. With the consideration that, while battery capacity is degraded, sufficient capacity exists to perform the intended function and to allow time to fully restore the battery cell parameters to normal limits, this time is acceptable.

BRAIDWOOD UNITS 1 & 2 B 3.8.c 3 Revision 26

Battery Monitoring and Maintenance B 3.8.c BASES ACTIONS (continued)

B.1 and B.2 With one battery with one or more battery cells with electrolyte level less than the minimum established design limit (i.e., 1/2 below the minimum level indication mark),

TS 5.5.17 requires that the Battery Monitoring and Maintenance Program provide actions to equalize and test the affected battery cell(s). The Specification 5.5.17 item b to initiate action to equalize and test in accordance with manufacturers recommendation is taken from Annex D of IEEE Standard 450-1995, IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications. 31 days is allowed to equalize and test the affected battery cell(s). However, Condition B is modified by a Note which indicates that Required Actions B.1 and B.2 must be completed after restoring the affected cell electrolyte level to greater than or equal to the minimum established design limits, i.e., after LCO 3.8.6, Battery Parameters, Required Action C.3 is completed. With the consideration that, while battery capacity is degraded, sufficient capacity exists to perform the intended function and to allow time to fully restore the battery cell parameters to normal limits, this time is acceptable. Based on the results of the manufacturers recommended testing the battery may have to be declared inoperable and the affected cell(s) replaced.

SURVEILLANCE TSR 3.8.c.1 REQUIREMENTS This TSR verifies that Category A battery cell parameters are consistent with IEEE-450 (Ref. 3), which recommends regular battery inspections (at least one per month) including voltage, specific gravity, and electrolyte level of pilot cells.

BRAIDWOOD UNITS 1 & 2 B 3.8.c 4 Revision 26

Battery Monitoring and Maintenance B 3.8.c BASES SURVEILLANCE REQUIREMENTS (continued)

TSR 3.8.c.2 The quarterly inspection of specific gravity and voltage is consistent with IEEE-450 (Ref. 3). In addition, within 7 days of a battery discharge 110 V or a battery overcharge # 145 V, the battery must be demonstrated to meet Category B limits. Transients, such as motor starting transients, which may momentarily cause battery voltage to drop to 110 V, do not constitute a battery discharge provided the battery terminal voltage and float current return to pre-transient values. This inspection is also consistent with IEEE-450 (Ref. 3), which recommends special inspections following a severe discharge or overcharge, to ensure that no significant degradation of the battery occurs as a consequence of such discharge or overcharge.

TSR 3.8.c.3 Visual inspection to detect corrosion of the battery cells and connections, or measurement of the resistance of each intercell, interrack, intertier, and terminal connection, provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance.

The limits established for this TSR must not be above the ceiling value established by the manufacturer.

Connection resistance is obtained by subtracting the normal resistance of the interrack (cross room rack) connector or the intertier (bi-level rack) connector from the measured intercell (cell-to-cell) connection resistance.

The Surveillance Frequency for these inspections, which can detect conditions that can cause power losses due to resistance heating, is 92 days. This Frequency is considered acceptable based on operating experience related to detecting corrosion trends.

BRAIDWOOD UNITS 1 & 2 B 3.8.c 5 Revision 26

Battery Monitoring and Maintenance B 3.8.c BASES SURVEILLANCE REQUIREMENTS (continued)

TSR 3.8.c.4 Visual inspection of the battery cells, cell plates, and battery racks provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance. The presence of physical damage or deterioration does not necessarily represent a failure of this TSR, provided an evaluation determines that the physical damage or deterioration does not affect the OPERABILITY of the battery (its ability to perform its design function).

TSR 3.8.c.5 and TSR 3.8.c.6 Visual inspection and resistance measurements of intercell, interrack, intertier, and terminal connections provide an indication of physical damage or abnormal deterioration that could indicate degraded battery condition. The anti-corrosion material is used to help ensure good electrical connections and to reduce terminal deterioration. The visual inspection for corrosion is not intended to require removal of and inspection under each terminal connection. The removal of visible corrosion is a preventive maintenance TSR. The presence of visible corrosion does not necessarily represent a failure of this TSR provided visible corrosion is removed during performance of TSR 3.8.c.5.

The connection resistance limits for TSR 3.8.c.6 shall not be above the ceiling value established by the manufacturer.

Connection resistance is obtained by subtracting the normal resistance of the interrack (cross room rack) connector or the intertier (bi-level rack) connector from the measured intercell (cell-to-cell) connection resistance.

Table T3.8.6-1 This table delineates the limits on electrolyte level, float voltage, and specific gravity for three different categories. The meaning of each category is discussed below.

BRAIDWOOD UNITS 1 & 2 B 3.8.c 6 Revision 26

Battery Monitoring and Maintenance B 3.8.c BASES SURVEILLANCE REQUIREMENTS (continued)

Category A defines the normal parameter limit for each designated pilot cell in each battery. The cells selected as pilot cells are those whose temperature, voltage, and electrolyte specific gravity approximate the state of charge of the entire battery.

The Category A limits specified for electrolyte level are based on manufacturer recommendations and are consistent with the guidance in IEEE-450 (Ref. 3), with the extra 1/4 inch allowance above the high water level indication for operating margin to account for temperatures and charge effects. In addition to this allowance, footnote (a) to Table T3.8.6-1 permits the electrolyte level to be above the specified maximum level during equalizing charge, provided it is not overflowing. These limits ensure that the plates suffer no physical damage, and that adequate electron transfer capability is maintained in the event of transient conditions. IEEE-450 (Ref. 3) recommends that electrolyte level readings should be made only after the battery has been at float charge for at least 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

The Category A limit specified for float voltage is 2.13 V per cell. This value is based on the recommendations of IEEE-450 (Ref. 3), which states that prolonged operation of cells < 2.13 V can reduce the life expectancy of cells.

The Category A limit specified for specific gravity for each pilot cell is 1.200 (0.015 below the manufacturer fully charged nominal specific gravity or a battery charging current that had stabilized at a low value). This value is characteristic of a charged cell with adequate capacity.

According to IEEE-450 (Ref. 3), the specific gravity readings are based on a temperature of 77!F (25!C).

The specific gravity readings are corrected for actual electrolyte temperature. For each 3!F (1.67!C) above 77!F (25!C), 1 point (0.001) is added to the reading; 1 point is subtracted for each 3!F below 77!F.

Category B defines the normal parameter limits for each connected cell. The term "connected cell" excludes any battery cell that may be jumpered out.

BRAIDWOOD UNITS 1 & 2 B 3.8.c 7 Revision 26

Battery Monitoring and Maintenance B 3.8.c BASES SURVEILLANCE REQUIREMENTS (continued)

The Category B limits specified for electrolyte level and float voltage are the same as those specified for Category A and have been discussed above. Footnote (b) to Table T3.8.6-1 requires the float voltage correction for average electrolyte temperature. The Category B limit specified for specific gravity for each connected cell is

1.195 (0.020 below the manufacturer fully charged, nominal specific gravity) with the average of all connected cells

> 1.205 (0.010 below the manufacturer fully charged, nominal specific gravity). These values are based on manufacturer's recommendations. The minimum specific gravity value required for each cell ensures that the effects of a highly charged or newly installed cell will not mask overall degradation of the battery.

Category C defines the limits for each connected cell.

These values, although reduced, provide assurance that sufficient capacity exists to perform the intended function and maintain a margin of safety.

The Category C limits specified for electrolyte level (above the top of the plates and not overflowing) ensure that the plates suffer no physical damage and maintain adequate electron transfer capability. The Category C limits for float voltage is based on IEEE-450 (Ref. 3), which states that a cell voltage of 2.07 V or below, under float conditions and not caused by elevated temperature of the cell, indicates internal cell problems and may require cell replacement.

The Category C limit of average specific gravity 1.195 is based on manufacturer recommendations (0.020 below the manufacturer recommended fully charged, nominal specific gravity). In addition to that limit, it is required that the specific gravity for each connected cell must be no less than 0.020 below the average of all connected cells. This limit ensures that the effect of a highly charged or new cell does not mask overall degradation of the battery.

BRAIDWOOD UNITS 1 & 2 B 3.8.c 8 Revision 26

Battery Monitoring and Maintenance B 3.8.c BASES SURVEILLANCE REQUIREMENTS (continued)

Because of specific gravity gradients that are produced during the recharging process, delays of several days may occur while waiting for the specific gravity to stabilize.

A stabilized charger current is an acceptable alternative to specific gravity measurement for determining the state of charge. This phenomenon is discussed in IEEE-450 (Ref. 3).

Footnote (d) to Table T3.8.6-1 allows the float charge current to be used as an alternate to specific gravity for up to 7 days following a battery recharge. Within 7 days, each connected cell's specific gravity must be measured to confirm the state of charge. Following a minor battery recharge (such as equalizing charge that does not follow a deep discharge) specific gravity gradients are not significant, and confirming measurements may be made in less than 7 days.

REFERENCES 1. UFSAR, Chapter 6.

2. UFSAR, Chapter 15.

3. IEEE-450-1995.

BRAIDWOOD UNITS 1 & 2 B 3.8.c 9 Revision 26

TRM Control Room Envelope Habitability Program Appendix V CONTROL ROOM ENVELOPE HABITABILITY PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 7 Revision 56 Technical Requirements Manual

TRM Control Room Envelope Habitability Program Appendix V 1.1 PURPOSE This Program ensures that Control Room Envelope Habitability (CREH) is maintained such that, with an OPERABLE Control Room Ventilation (VC) Filtration System, the Control Room Envelope (CRE) occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge by assessing and performing testing in accordance with Technical Specification (TS) 3.7.10, Control Room Ventilation (VC) Filtration System and the Control Room Habitability Program. The CREH Program is defined by TS 5.5.18.

1.2 REFERENCES

1. Technical Specifications:

a. 3.7.10, "Control Room Ventilation (VC) Filtration System"

b. 5.5.18, "Control Room Envelope Habitability Program"

2. Update Final Safety Analysis Report Sections:

a. 6.4, "Habitability Systems"

b. 9.4.1, "Control Room HVAC System"

3. Regulatory Guide 1.196, Control Room Habitability at Light-Water Nuclear Power Reactors, Revision 0

4. NEI 99-03, Control Room Habitability Assessment Guidance, Revision 0

5. Design Basis Accident (DBA) Control Room Dose Calculations:

a. BRW-04-0038-M, Loss Of Coolant Accident

b. BRW-04-0039-M, Control Rod Ejection Accident

c. BRW-04-0040-M, Main Steam Line Break Accident

d. BRW-04-0041-M, Fuel Handling Building Accident

e. BRW-04-0042-M, Steam Generator Tube Rupture Accident

f. BRW-04-0043-M, Locked Rotor Accident BRAIDWOOD UNITS 1 & 2 2 of 7 Revision 56 Technical Requirements Manual

TRM Control Room Envelope Habitability Program Appendix V 1.3 DEFINITIONS AND/OR ACRONYMS

1. BREACH: Any work activity or testing that creates or enlarges an opening through a barrier, which would allow the propagation of a hazard through the barrier. Following are some examples:

- Modification (addition, removal or degradation) of a penetration seal or structural component

- Core boring

- Blocking open a door/hatch or damper

- Modification (addition, removal, or degradation) of a door/hatch or damper

2. CONTROL ROOM ENVELOPE (CRE): The area within the confines of the control room envelope boundary that contains the spaces Occupants inhabit to control the plant for normal and accident conditions. This area encompasses the control room and other non-critical areas to which frequent personnel access or continuous occupancy is not necessary in the event of an accident. The CRE is protected during normal operation, natural events, and accident conditions.

The Braidwood CRE is shown in drawing M-1033-13.

3. CRE BOUNDARY: A combination of walls, floor, roof, ducting, doors, penetrations and equipment that physically form the CRE.

4. CRE INTEGRITY: The condition whereby the control room habitability systems (CRHSs) are functioning to ensure the protection of the Operators in the CRE during normal and accident conditions.

5. CONTROL ROOM HABITABILITY SYSTEMS (CRHS): The plant systems that help ensure CRE habitability. This includes the Control Room (CR) emergency ventilation/filtration system and the Control Room (CR) heating, ventilating and air-conditioning (HVAC) systems. The CRE boundary is considered as an integral part of the CRHS, since it is critical to maintaining CRE habitability.

BRAIDWOOD UNITS 1 & 2 3 of 7 Revision 56 Technical Requirements Manual

TRM Control Room Envelope Habitability Program Appendix V

6. FILTERED INLEAKAGE: This inleakage occurs at a location in the CRHS that allows the inleakage air contamination to be filtered prior to entering the habitability zone. An example is duct inleakage on the suction side of a recirculation air carbon filter where the duct is outside the CRE. Radionuclides are removed from this air prior to it entering the CRE. There is no filtering assumed for hazardous chemical events.

7. INTEGRATED TRACER GAS TEST: A tracer gas test to determine total inleakage into the CRE. The tracer gas test is actually measuring the total amount of outside air entering the CRE, and the inleakage air is determined by subtracting the filtered outside air supply value from this figure.

This particular test may not locate leaks; it does, however, provide a value for total inleakage.

8. TRACER GAS (from ASTM E741): A gas that can be mixed with air in very small concentrations in order to study air movement.

9. UNFILTERED INLEAKAGE: This is inleakage that occurs at a location in the CRHS that allows inleakage air to enter the control room envelope without any contaminants being filtered prior to entry. Examples would be penetrations and dampers that are at a negative pressure with respect to potentially contaminated surroundings and located such that radionuclides are not removed prior to the inleakage air entering the CRE.

1.4 PROGRAM DESCRIPTION This Program ensures that CRE Habitability is maintained in accordance with NRC regulations and plant-specific commitments.

Specifically, the CRE Habitability Program ensures compliance with 10 CFR 50, Appendix A, General Design Criterion 19 - Control Room (GDC 19). CRE Habitability must be maintained during normal operations as well as during radiological, hazardous chemical, or smoke event emergencies. Administration of this Program, through periodic inleakage testing, periodic assessments, configuration control, and preventive maintenance, will ensure that CRE Habitability and Integrity are maintained. This CRE Habitability Program is the result of an NRC commitment to Generic Letter 2003-01 for all Exelon Nuclear / AmerGen plant Technical Specifications to have an administrative program for CRE Habitability.

BRAIDWOOD UNITS 1 & 2 4 of 7 Revision 56 Technical Requirements Manual

TRM Control Room Envelope Habitability Program Appendix V 1.5 PROGRAM IMPLEMENTATION A CRE Habitability Program shall be established and implemented to ensure that CRE Habitability is maintained such that, with an OPERABLE Control Room Emergency Ventilation/Filtration System, CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:

a. The definition of the CRE and CRE boundary.

b. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c. Requirements for determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.

d. Measurement of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one train of the Control Room Emergency Ventilation/Filtration System, operating at the flow rate required by the Ventilation Filter Testing Program, at a Frequency of 18 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the 18 months assessment of the CRE boundary.

BRAIDWOOD UNITS 1 & 2 5 of 7 Revision 56 Technical Requirements Manual

TRM Control Room Envelope Habitability Program Appendix V

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

1.6 ACCEPTANCE CRITERIA

1. The quantitative limits on unfiltered air inleakage do not exceed the values assumed in the dose analysis for DBAs.

2. Periodic Assessments do not identify any degraded conditions or programs that could result in exceeding the licensing basis analysis of DBA consequences to the CRE occupants.

1.7 LCOARS/COMPENSATORY MEASURES In the event any of the acceptance criteria is not met, the Shift Manager will immediately be notified. The Shift Manager shall determine OPERABILITY status and implement a LCOAR as applicable.

In addition, an Issue Report may be generated to provide proper tracking and resolution of the noted problems associated with the implementation of this program.

1.8 REPORTING REQUIREMENTS Any reporting requirements associated with acceptance criteria of this Program not being met shall be reported in accordance with the requirements specified in the implementing procedures or determined through the Corrective Action Process.

BRAIDWOOD UNITS 1 & 2 6 of 7 Revision 56 Technical Requirements Manual

TRM Control Room Envelope Habitability Program Appendix V 1.9 CHANGE CONTROL Changes to this Program, other than editorial changes, shall include a 10 CFR 50.59 Review and a Station Qualified Review (SQR). The SQR composition shall include Regulatory Assurance Department in all cases. As a part of the SQR, Byron and Braidwood Plant Operations Review Committee (PORC) approval is required as determined by the Regulatory Assurance Manager.

Byron and Braidwood shall implement the same change unless the change being implemented at Braidwood has been reviewed and was determined not to be applicable to Byron.

BRAIDWOOD UNITS 1 & 2 7 of 7 Revision 56 Technical Requirements Manual

TRM Surveillance Frequency Control Program Appendix W SURVEILLANCE FREQUENCY CONTROL PROGRAM BRAIDWOOD TABLE OF CONTENTS SECTION TITLE 1.1 PURPOSE

1.2 REFERENCES

1.3 DEFINITIONS AND/OR ACRONYMS 1.4 PROGRAM DESCRIPTION 1.5 PROGRAM IMPLEMENTATION 1.6 ACCEPTANCE CRITERIA 1.7 LCOARS/COMPENSATORY MEASURES 1.8 REPORTING REQUIREMENTS 1.9 CHANGE CONTROL BRAIDWOOD UNITS 1 & 2 1 of 4 Revision 74 Technical Requirements Manual

TRM Surveillance Frequency Control Program Appendix W 1.1 PURPOSE The purpose of this Program is to provide the administrative controls for modifying surveillance frequencies in accordance with Technical Specification (TS) 5.5.19, Surveillance Frequency Control Program. The Surveillance Frequency Control Program (SFCP) ensures that Surveillance Requirements specified in the TSs are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

1.2 REFERENCES

1. Technical Specification 5.5.19, "Surveillance Frequency Control Program"

2. NEI 04-10, Risk-Informed Method for Control of Surveillances Frequencies, Revision 1

3. Letter from N.J. DiFrancesco (U. S. NRC) to M.J. Pacilio (Exelon Generation Company, LLC), "Braidwood Station, Units 1 and 2 - Issuance of Amendments Regarding Technical Specification Change for the Relocation of Specific Surveillance Frequency Requirements Based on Technical Specification Task Force-425," dated February 24, 2011.

1.3 DEFINITIONS AND/OR ACRONYMS Definitions and/or acronyms are consistent with definitions provided in Technical Specification Section 1.0, "Use and Application."

1.4 PROGRAM DESCRIPTIONS The list of periodic surveillances and associated TS Bases information that were relocated to the SFCP as part of License Amendment No. 165 for Braidwood Station, Units 1 and Unit 2 are provided in a separate tab in the TS LCO book for ease of locating.

Table 1 under this tab includes a reference to the TS SR number, a surveillance description, the frequency, and current revision.

The description is a summary description of the referenced TS SR which is provided for information purposes only and is not intended to be a substitute for the actual TS requirements. Refer to the TS for the specific action required by each respective TS SR identified in the list.

BRAIDWOOD UNITS 1 & 2 2 of 4 Revision 74 Technical Requirements Manual

TRM Surveillance Frequency Control Program Appendix W Table 2 under this tab provides the associated Bases description for each TS SR Frequency.

Changes to the type or scope of testing (e.g., Channel Check, Channel Functional Test, or Channel Calibration) are not allowed without prior NRC approval. The specified frequencies ensure TS SRs are performed at intervals sufficient to assure associated Limiting Conditions for Operation (LCOs) are met.

Changes to the information in Tables 1 and 2 may occur for one of two reasons:

1. Addition, deletion, or modification of the associated TS SR through a license amendment request, or

2. A change to a surveillance frequency in accordance with the SFCP and associated implementing procedures. Changes to individual surveillance frequencies are evaluated using the methodology provided in NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.

As noted in Tables 1 and 2, Surveillance Frequencies beyond Revision 0 have been evaluated in accordance with TS Section 5.5.19, Surveillance Frequency Control Program. Surveillance frequencies at Revision 0 reflect the approved licensing basis upon initial SFCP implementation.

The provisions of TS SR 3.0.2 and 3.0.3 are applicable to the frequencies established in the SFCP.

1.5 PROGRAM IMPLEMENTATION Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for control of Surveillance Frequencies,"

Revision 1.

BRAIDWOOD UNITS 1 & 2 3 of 4 Revision 74 Technical Requirements Manual

TRM Surveillance Frequency Control Program Appendix W 1.6 ACCEPTANCE CRITERIA Not applicable.

1.7 LCOARS/COMPENSATORY MEASURES Noncompliance with the frequencies specified in the SFCP (e.g., a missed surveillance) requires generation of an Issue Report in accordance with LS-AA-125.

1.8 REPORTING REQUIREMENTS Based on the guidance provided in NUREG-1022, "Event Reporting Guidelines, 10 CFR 50.72 and 50.73," Revision 2, missed surveillances are not reportable as a condition prohibited by TS unless the surveillance, once performed, indicates that the equipment was not capable of performing its specified safety function(s) for a period of time longer than allowed by TS.

1.9 CHANGE CONTROL The change control process associated with revisions to Surveillance Frequencies is defined in NEI 04-10, Risk-Informed Method for Control of Surveillances Frequencies, Revision 1.

BRAIDWOOD UNITS 1 & 2 4 of 4 Revision 74 Technical Requirements Manual

CORE OPERATING LIMITS REPORT (COLR)

FOR BRAIDWOOD UNIT 1 CYCLE 22 EXELON TRACKING ID:

COLR BRAIDWOOD 1 REVISION 16

COLR BRAIDWOOD 1 Revision 16 Page 1 of 15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 1.0 CORE OPERATING LIMITS REPORT This Core Operating Limits Report (COLR) for Braidwood Station Unit 1 Cycle 22 has been prepared in accordance with the requirements of Technical Specification 5.6.5 (ITS).

The Technical Specification Safety Limits and Limiting Conditions for Operation (LCOs) affected by this report are listed below:

SL 2.1.1 Reactor Core Safety Limits (SLs)

LCO 3.1.1 SHUTDOWN MARGIN (SOM)

LCO 3.1.3 Moderator Temperature Coefficient (MTC)

LCO 3.1.4 Rod Group Alignment Limits LCO 3.1.5 Shutdown Bank Insertion Limits LCO 3.1.6 Control Bank Insertion Limits LCO 3.1.8 PHYSICS TESTS Exceptions - MODE 2 LCO 3.2.1 Heat Flux Hot Channel Factor (Fo(Z))

LCO 3.2.2 *Nuclear Enthalpy Rise Hot Channel Factor (FN,.,H)

LCO 3.2.3 AXIAL FLUX DIFFERENCE (AFD)

LCO 3.2.5 Departure from Nucleate Boiling Ratio (DNBR)

LCO 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.9 Boron Dilution Protection System (BOPS)

LCO 3.4.1 Reactor Coolant System (RCS) Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits LCO 3.9.1 Boron Concentration The portions of the Technical Requirements Manual (TRM) affected by this report are listed below:

TRM TLCO 3.1.b Boration Flow Paths - Operating TRM TLCO 3.1.d Charging Pumps - Operating TRM TLCO 3.1.f Borated Water Sources - Operating TRM TLCO 3.1 .g Position Indication System - Shutdown TRM TLCO 3.1.h Shutdown Margin (SOM) - MODE 1 and MODE 2 with keff 2': 1.0 TRM TLCO 3.1.i Shutdown Margin (SOM) - MODE 5 TRM TLCO 3.1.j Shutdown and Control Rods TRM TLCO 3.1.k Position Indication System - Shutdown (Special Test Exception)

COLR BRAIDWOOD 1 Revision 16 Page 2of15 CORE OPERA TING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 2.0 OPERATING LIMITS The cycle-specific parameter limits for the specifications listed in Section 1.0 are presented in the following subsections . These limits are applicable for the entire cyCle unless otherwise identified. These limits have been developed using the NRG-approved methodologies specified in Technical Specification 5.6.5.

2.1 Reactor Core Safety Limits (SLs) (SL 2.1.1) 2.1.1 In MODES 1 and 2, the combination of Thermal Power, Reactor Coolant System (RCS) highest loop average temperature, and pressurizer pressure shall not exceed the limits specified in Figure 2.1.1.

24il psia

~~

660

,_2250psia --------

L._._

CJ) ~

())

Cl

~---

Ci)

!..._ 640

~

.2000 psia 0

!..._ ~~

Q)

CL

.- 1860 psia t:: ..............

Q) -.....___......_

f-- 620 Q)

CJ"1 0

Q)

<r:

600 0 0.2 04 0.6 0.8 1.2 Fru ction of [\Jorninul Power Figure 2.1.1: Reactor Core Limits

COLR BRAIDWOOD 1 Revision 16 Page 3of15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 2.2 SHUTDOWN MARGIN (SOM)

The SOM limit for MODES 1, 2, 3, and 4 is:

2.2.1 The SOM shall be greater than or equal to 1.3% t.k/k (LCOs 3.1.1, 3.1.4, 3.1.5, 3.1.6, 3.1.8, 3.3.9 ; TRM TLCOs 3.1.b, 3.1.d , 3.1.f, 3.1.h , and 3.1.j).

The SOM limit for MODE 5 is:

2.2.2 SOM shall be greater than or equal to 1.3% ~ k/k (LCO 3.1.1, LCO 3.3.9; TRM TLCOs 3.1.i and 3.1.j).

2.3 Moderator Temperature Coefficient (MTC) (LCO 3.1.3)

The Moderator Temperature Coefficient (MTC) limits are:

2.3.1 The BOL/ARO/HZP-MTC upper limit shall be +1.649 x 10-5 ~k/k/°F.

2.3.2 The EOL/ARO/HFP-MTC lower.limit shall be -4.6 x 10-4 ~k/k/°F.

2.3.3 The EOL/ARO/HFP-MTC Surveillance limit at 300 ppm shall be -3.7 x 10-4 ~k/k/°F.-

2.3.4 The EOL/ARO/HFP-MTC Surveillance limit at 60 ppm shall be -4.3 x 10-4 t.k/k/°F.

where: BOL stands for Beginning of Cycle Life ARO stands for All Rods Out HZP stands for Hot Zero Thermal Power EOL stands for End of Cycle Life HFP stands for Hot Full Thermal Power 2.4 Shutdown Bank Insertion Limits (LCO 3.1.5) 2.4.1 All shutdown banks shall be fully withdrawn to at least 224 steps.

2.5 Control Bank Insertion Limits (LCO 3.1 .6) 2.5.1 The control banks , with Bank A greater than or equal to 224 steps, shall be limited in physical insertion as shown in Figure 2.5.1 . -

2.5.2 Each control bank shall be considered fully withdrawn from the core at greater than or equal to 224 steps.

2.5.3 The control banks shall be operated in sequence by withdrawal of Bank A, Bank B, Bank C and Bank D. The control banks shall be sequenced in reverse order upon insertion.

2.5.4 Each control bank not fully withdrawn from the core shall be operated with the following overlap limits as a function of park position :

Park Position (step) Overlap Limit (step) 226 111 227 112 228 113 229 114

COLR BRAIDWOOD 1 Revision 16

Page 4of15 CORE OPERA TING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 Figure 2.5.1:

Control Bank Insertion Limits Versus Percent Rated Thermal Power 224 (27% , 224) (77% , 224) 220 180

'2 3::

...ra

'O

..c:

~ 140

!/)

c..

Q)

~ 120 c:

0

~

'iii a.. 100 0

..ll::

c:

ra m 80

'O 0

0::

60 40 20 (30%, 0) 0 0 10 20 30 40 50 60 70 80 90 100 Relative Power (Percent)

COLR BRAIDWOOD 1 Revision 16 Page 5of15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 2.6 Heat Flux Hot Channel Factor (Fo(Z)) (LCO 3.2.1) 2.6.1 Total Peaking Factor:

pRTP Fq (Z) ~ _Q_xK(Z) for P ~ 0.5 0.5 pRTP Fq (Z) ~ _Q_xK(Z) for P > 0.5 p

where: P = the ratio of THERMAL POWER to RATED THERMAL POWER F8TP = 2.60 K(Z) is provided in Figure 2.6.1.

Figure 2.6.1 K(Z) - Normalized F0 (Z) as a Function of Core Height 1.1 (0.0 1.0) (6.0 1.0)

(12.C 0.924) 0.9 0.8 N' 0.7 au.

-g 0.6 Ill E

0 o.5 z --

~

0.4

...,_LOCA Limiting Envelope -

0.3 0.2 0.1 0

0 2 3 4 5 6 7 8 9 10 11 12 BOTTOM Core Height (ft) TOP

COLR BRAIDWOOD 1 Revision 16 Page 6of15 CORE OPERA TING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 2.6.2 W(Z) Values:

a) When the Power Distribution Monitoring System (PDMS) is OPERABLE, W(Z) = 1.00000 for all axial points.

b) When PDMS is inoperable, W(Z) is provided as:

1) Table 2.6.2.a are the normal operation W(Z) values that correspond to the NORMAL AXIAL FLUX DIFFERENCE (AFD) Acceptable Operation Limits provided in Figure 2.8.1.a. The Normal AFD Acceptable Operation Limits may be invoked at any time and must be used with the corresponding W(Z) values.

2) Table 2.6.2.b are the Expanded normal operation W(Z) values that correspond to the EXPANDED AXIAL FLUX DIFFERENCE (AFD) Acceptable Operation Limits provided in Figure 2.8.1.b. The Expanded AFD Acceptable Operation Limits may be invoked at any time and must be used with the corresponding W(Z) values.

Table 2.6.2.c shows the FCa(z) penalty factors that are greater than 2% per 31 Effective Full Power Days (EFPD). These values shall be used to increase the FWo(z) as per Surveillance Requirement 3.2.1.2. A 2% penalty factor shall be used at all cycle burnups that are outside the range of Table 2.6.2 .c.

2.6.3 Uncertainty

The uncertainty, UFO, to be applied to the Heat Flux Hot Channel Factor Fo(Z) shall be calculated by the following formula U1*Q = U"" *Ue where:

Uqu = Base Fa measurement uncertainty= 1.05 when PDMS is inoperable (Uqu is defined by PDMS when OPERABLE.)

Ue = Engineering uncertainty factor= 1.03

? 6.4 PDMS Alarms:

Fo(Z) Warning Setpoint = 2% Fo(Z) Margin Fo(Z) Alarm Setpoint = 0% Fo(Z) Margin

COLR BRAIDWOOD 1 Revis ion 16 Page 7of15 CORE OPERA TING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 Table 2.6.2.a W(Z) versus Core Height f or Normal AFD Acc epta ble Operation Lim its in Figu re 2.8.1.a (Top and Bottom 8% Excluded perWCAP-10216)

Heig ht 150 5000 14000 20000 (feet) MWD/MTU MWD/MTU MWD/MTU MWD/MTU 0.00 <core bottom\ 1.1807 1.3027 1.2923 1.2216 0.20 1.1694 1.2788 1.2708 1.2028 0.40 1.1647 1.2698 1.2625 1.1943 0.60 1.1580 1.2592 1.2525 1.1800 0.80 1.1515 1.2041 1.2184 1.1750 1.00 1.1482 1.1901 1.2061 1.1739 1.20 1.1461 1.2046 1.1815 1.1697 1.40 1.1454 1.1979 1.1774 1.1658 1.60 1.1353 1.1821 1.1737 1.1586 1.80 1.1310 1.1682 1.1718 1.1 521 2.00 1.1267 1.1542 1.1680 1.1455 2.20 1.1209 1.1356 1.1633 1.1368 2.40 1.1158 1.1216 1.1585 1.1287 2.60 1.1122 1.1107 1.1508 1.1190 2.80 1.1096 1.1057 1.1441 1.11 15 3.00 1.1060 1.1031 1.1373 1.1109 3.20 1.1008 1.1046 1.1296 1.1184 3.40 1.1007 1.1055 1.1250 1.1319 3.60 1.1046 1.1051 1.1200 1.1444 3.80 1.1095 1.1057 1.1205 1.1556 4.00 1.1133 1.1054 1.1256 1.1649 4.20 1.1172 1.1047 1.1296 1.1755 4.40 1.1200 1.1039 1.1325 1.1853 4.60 1.1229 1.1014 1.1342 1.1939 4.80 1.1237 1.0995 1.1348 1.2012 5.00 1.1245 1.0967 1.1343 1.2060 5.20 1.1244 1.0938 1.1358 1.2107 5.40 1.1222 1.0903 1.1385 1.2125 5.60 1.1201 1.0860 1.1464 1.2323 5.80 1.1159 1.0858 1.1622 1.2481 6 .00 1.1229 1.0956 1.1760 1.2619 6.20 1.1297 1.1055 1.1878 1.2717 6.40 1.1356 1.1133 1.1967 1.2785 6.60 1.1395 1.1202 1.2036 1.2814 6.80 1.1424 1.1271 1.2075 1.28 13 7.00 1.1443 1.1339 1.2094 1.2782 7.20 1.1445 1.1415 1.2084 1.2702 7.40 1.1484 1.1494 1.2054 1.2602 7.60 1.1514 1.1558 1.1964 1.2452 7.80 1.1543 1.1622 1.1885 1.2303 8.00 1.1607 1.1676 1.1785 1.2124 8.20 1.1661 1.1770 1.1647 1.1905 8.40 1.1705 1.1860 1.1587 1.1759 8.60 1.1739 1.1943 1.1537 1.1705 8.80 1.1768 1.1988 1.1563 1.1666 9.00 1.1826 1.2118 1.1579 1.1617 9.20 1.1817 1.2263 1.1633 1.1630 9.40 1.1871 1.2416 1.1708 1.2110 9.60 1.1943 1.2566 1.2010 1.2570 9.80 1.1997 1.2696 1.2380 1.2980 10.00 1.2058 1.2795 1.2730 1.3330 10.20 1.2113 1.2852 1.3030 1.3650 10.40 1.2177 1.2932 1.3310 1.3910 10.60 1.2272 1.2999 1.3440 1.4220 10.80 1.2391 1.3083 1.3540 1.4440 11 .00 1.2497 1.3200 1.3590 1.4620 11 .20 1.2566 1.3267 1.3440 1.4482 11.40 1.2663 1.3432 1.3314 1.4540 11 .60 1.2669 1.3461 1.3134 1.4331 11 .80 1.2679 1.3491 1.2993 1.4180 12.00 (core top) 1.2758 1.3623 1.2911 1.4077 Not e: W(Z) values at 20000 MWD/MTU may be applied to cycle burnups greater than 20000 MWD/MTU to prevent W(Z) fu nction extrapolation

COLR BRAfDWOOD 1 Revision 16 Page 8of15 CORE OPERATING LIMITS REPORT (COLR) for BRAfDWOOD UNIT 1 CYCLE 22 Table 2.6.2.b W(Z) versus Core Height for Expanded AFD Acceptable Operation Limits in Figure 2.8.1.b (Top and Bottom 8% Excluded per WCAP-10216 )

Height 150 5000 14000 20000 (feet) MWD/MTU MWD/MTU MWD/MTU MWD/MTU 0.00 !core bottom) 1.3380 1.4449 1.4310 1.3183 0.20 1.3229 1.4164 1.4050 1.3034 0.40 1.3163 1.4060 1.3950 1.2981 0.60 1.3078 1.3956 1.3830 1.2941 0.80 1.2868 1.3321 1.3430 1.2924 1.00 1.2765 1.3159 1.3280 1.2885 1.20 1.2673 1.3311 1.2990 1.2817 1.40 1.2843 1.3218 1.2850 1.2759 1.60 1.2693 1.3019 1.2680 1.2661 1.80 1.2560 1.2848 1.2550 1.2572 2.00 1.2418 1.2658 1.2420 1.2474 2.20 1.2257 1.2410 1.2300 1.2346 2.40 1.2105 1.2209 1.2170 1.2228 2.60 1.1935 1.1981 1.2060 1.2081 2.80 1.1804 1.1842 1.1960 1.1943 3.00 1.1670 1.1792 1.1872 1.1825 3.20 1.1579 1.1732 1.1786 1.1752 3.40 1.1512 1.1687 1.1714 1.1807 3.60 1.1430 1.1626 1.1644 1.1848 3.80 1.1376 1.1581 1.1606 1.1880 4.00 1.1325 1.1516 1.1569 1.1903 4.20 1.1266 1.1435 1.1508 1.1903 4.40 1.1282 1.1365 1.1450 1.1893 4 .60 1.1297 1.1270 1.1374 1.1939 4 .80 1.1295 1.1179 1. 1348 1.2012 5.00 1.1289 1.1089 1.1343 1.2060 5.20 1.1273 1.0979 1.1358 1.2107 5.40 1.1241 1.0903 1.1385 1.2125 5.60 1.1205 1.0860 1.1464 1.2323 5.80 1.1159 1.0858 1.1622 1.2481 6 .00 1.1229 1.0956 1.1760 1.2619 6.20 1.1297 1.1055 1.1878 1.2717 6.40 1.1356 1.1133 1.1967 1.2785 6.60 1.1395 1.1202 1.2036 1.2814 6.80 1.1424 1.1271 1.2075 1.2813 7.00 1.1443 1.1339 1.2094 1.2782 7.20 1.1445 1.1415 1.2084 1.2702 7.40 1.1484 1.1494 1.2054 1.2602 7.60 1.1514 1.1558 1.1964 1.2452 7 .80 1.1543 1.1622 1.1885 1.2303 8.00 1.1607 1.1676 1.1785 1.2124 8.20 1.1661 1.1770 1.1647 1.1905 8.40 1.1705 1.1860 1.1587 1.1759 8.60 1.1739 1.1943 1.1537 1.1705 8.80 1.1768 1.1988 1.1563 1.1666 9.00 1.1826 1.2118 1.1579 1.1617 9.20 1.1817 1.2263 1.1633 1.1630 9.40 1.1871 1.2416 1.1708 1.2110 9.60 1.1943 1.2566 1.2010 1.2570 9.80 1.1997 1.2696 1.2380 1.2980 10.00 1.2058 1.2795 1.2730 1.3330 10.20 1.2113 1.2852 1.3030 1.3650 10.40 1.2177 1.2932 1.3310 1.3910 10.60 1.2272 1.2999 1.3440 1.4220 10.80 1.2391 1.3083 1.3540 1.4440 11 .00 1.2497 1.3200 1.3590 1.4620 11 .20 1.2566 1.3267 1.3440 1.4482 11.40 1.2663 1.3432 1.3314 1.4540 11 .60 1.2669 1.3461 1.3134 1.4331 11 .80 1.2679 1.3491 1.2993 1.4180 12.00 (core top) 1.2758 1.3623 1.2911 1.4077 Note: W(Z) values at 20000 MWD/MTU may be appl ied to cycle burnups greater than 20000 MWD/MTU to prevent W(Z) function extrapolation

COLR BRAIDWOOD 1 Revision 16 Page 9 of 15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT I CYCLE 22 Table 2.6.2.c Penalty Factors in Excess of 2% per 31 EFPD Cycle Burnup Penalty Factor (MWD/MTU) Fca(z) 0 1.0200 150 1.0350 325 1.0365 851 1.0370 1027 1.0380 1202 1.0415 1377 1.0425 1553 1.0425 1728 1.0417 2955 1.0200 9969 1.0200 10320 1.0267 11021 1.0265 11728 1.0278 12248 1.0280 12424 1.0279 14878 1.0200 21717 1.0200 21892 1.0218 22243 1.0200 Notes:

Linear interpolation is adequate for intermediate cycle burnups .

All cycle burnups outside the range of Table 2.6.2 .c shall use a 2% penalty factor for compliance with the 3.2 .1.2 Surveillance Requirements .

COLR BRAIDWOOD 1 Revision 16 Page 10of15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1CYCLE22 2.7 Nuclear Enthalpy Rise Hot Channel Factor (FN8H) (LCO 3.2.2) where: P =the ratio of THERMAL POWER to RATED THERMAL POWER (RTP)

F§~P = 1.70 PF8H = 0.3

2.7.2 Uncertainty

The uncertainty, UF8H, to be applied to the Nuclear Enthalpy Rise Hot Channel Factor FN8H shall be calculated by the following formula:

where:

UFAHm = Base FN8H measurement uncertainty = 1.04 when PDMS is inoperable (UF8Hm is defined by PDMS when OPERABLE.)

2.7.3 PDMS Alarms:

FN8H Warning Setpoint = 2% FN8H Margin FN8HAlarm Setpoint = 0% FN8H Margin 2.8 AXIAL FLUX DIFFERENCE (AFD) (LCO 3.2.3) 2.8.1 The AXIAL FLUX DIFFERENCE (AFD) Acceptable Operation Limits are provided in the Figures described below.

a) Figure 2.8.1.a is the Normal AFD Acceptable Operation Limits associated with the W(Z) values in Table 2.6.2.a. Prior to changing to Figure 2.8.1.a, confirm that the plant is within the specified AFD envelope.

b) Figure 2.8.1.b is the Expanded AFD Acceptable Operation Limits associated with the W(Z) values in Table 2.6.2.b.

2.9 Departure from Nucleate Boiling Ratio (DNBR) (LCO 3.2.5) 2.9.1 DNBRAPSL '.2-: 1.563 The Axial Power Shape Limiting DNBR (DNBRAPSL) is applicable with THERMAL POWER

'.2-: 50% RTP when PDMS is OPERABLE.

2.9.2 PDMS Alarms:

DNBR Warning Setpoint = 2% DNBR Margin DNBR Alarm Setpoint = 0% DNBR Margin

COLR BRAIDWOOD 1 Revision 16 Page 11 of 15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT I CYCLE 22 Figure 2.8.1.a:

Normal Axial Flux Difference Limits as a Function of Rated Thermal Power Normal Axial Flux Difference Limits 120 - -*

I (-10, 100) I I (+10, 10oi I 100 *-- **--

\\

0::

w 3:

0 c..

80 Una ~ceptab e / U1 accept, ble Jperat1c n I

OJ?eration

<(

~

0::

w 60 Acee Dtable \

c I-Cl I Oper at ion

\

w

~ 40 *- *------ -- - - II (-20, SO) 0::

0 20

- -j (+2S, SO) I 0

-50 -40 -30 -20 -10 0 10 20 30 40 50 AXIAL FLUX DIFFERENCE(%)

COLR BRAIDWOOD 1 Revi sion 16 Page 12of1 5 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 Figure 2.8.1.b:

Expanded Axial Flux Difference Limits as a Function of Rated Thermal Power Expanded Axial Flux Difference Limits 120

1 1 (-15, 10oi 1 I (+10, 10oi 1 0:::

w 0

0..

100 80 Una :::ceptab e /

v \ Ur iaccept, ble Operatic n I \\

...I 0 >eration

<(

E I 0::: Acee >table w 60

c I-cw

/ Ope1 at ion

\

~ ___

l--**1-**

40 -*****---*-- (-35, 50) **********-*

-- 1(+25,50) - -*-- ~--*- ****-*-

0:::

0 20 0

-50 -40 -30 -20 -10 0 10 20 30 40 so AXIAL FLUX DIFFERENCE(%) j

COLR BRAIDWOOD I Revision 16 Page 13of15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1CYCLE22 2.10 Reactor Trip System (RTS) Instrumentation (LCO 3.3.1) - Overtemperature L'1 T Setpoint Parameter Values 2.10.1 The Overtemperature L'1 T reactor trip setpoint K1 shall be equal to 1.325.

2.10.2 The Overtemperature L'1T reactor trip setpoint Tavg coefficient K2 shall be equal to 0.0297 I °F . .

2.10 .3 The Overtemperature L'1T reactor trip setpoint pressure coefficient K3 shall be equal to 0.00135 I psi.

2.10.4 The nominal Tavg at RTP (indicated) T' shall be less than or equal to 588.0 °F.

2.10.5 The nominal RCS operating pressure (indicated) P' shall be equal to 2235 psig.

2.10.6 The measured reactor vessel L'1T lead/lag time constant 1"1 shall be equal to 8 sec.

2.10. 7 The measured reactor vessel L'1 T lead/lag time constant 1"2 shall be equal to 3 sec.

2.10.8 The measured reactor vessel L'1 T lag time constant 1"3 shall be less than or equal to 2 sec.

2.10.9 The measured reactor vessel average temperature lead/lag time constant 1"4 shall be equal to 33 sec.

2.10.10 The measured reactor vessel average temperature lead/lag time constant cs shall be equal to 4 sec.

2.10.11 The measured reactor vessel average temperature lag time constant Te shall be less than or equal to 2 sec.

2.10.12 The f1 (i'.'1 1) "positive" breakpoint shall be +10% i'.'1 1.

2.10.13 The f1 (i'.'11) "negative" breakpoint shall be -18% i'.'11.

2.10 .14 The f1 (i'.'11) "positive" slope shall be +3.4 7% I% i'.'11.

2.10.15 The f1 (i'.'1 1) "negative" slope shall be -2.61 % I% i'.'1 1.

COLR BRAIDWOOD 1 Revision 16 Page 14 of15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 2.11 Reactor Trip System (RTS) Instrumentation (LCO 3.3 .1) - Overpower t. T Setpoint Parameter Values 2.11.1 The Overpower t.T reactor trip setpoint K4 shall be equal to 1.072 .

2.11 .2 The Overpower t. T reactor trip setpoint T avg rate/lag coefficient K5 shall be equal to 0.021 °F for increasing Tavg.

2.11.3 The Overpower t. T reactor trip setpoint Tavg rate/lag coefficient K5 shall be equal to 0 I °F for decreasing Tavg.

2.11.4 The Overpower t. T reactor trip setpoint Tavg heatup coefficient Ke shall be equal to 0.00245 I °F when T > T".

2.11. 5 The Overpower t.T reactor trip setpoint T avg heatup coefficient Ke shall be equal to 0 I °F when T :<::; T" .

2.11.6 The nominal Tavg at RTP (indicated) T" shal l be less than or equal to 588.0 °F.

2.11. 7 The measured reactor vessel t.T lead/lag time constant <1 shall be equal to 8 sec.

2.11 .8 The measured reactor vessel t. T lead/lag time constant c 2 shall be equal to 3 sec.

2.11 .9 The measured reactor vessel t. T lag time constant <3 shall be less than or equal to 2 sec.

2.11.10 The measured reactor vessel average temperature lag time constant <e shall be less than or equal to 2 sec.

2.11 .11 The measured reactor vessel average temperature rate/lag time constant <1 shall be equal to 10 sec.

2.11 .12 The f2 (t. I) "positive" breakpoint shall be 0 for all t. 1.

2.11 .13 The fa (t. 1) "negative" breakpoint shall be 0 for all t.I.

2.11 .14 The fa (t.I) "positive" slope shall be 0 for all t.1.

2.11 .15 The fa (t. 1) "negative" slope shall be 0 for all t.I.

COLR BRAIDWOOD 1 Revision 16 Page 15of 15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 1 CYCLE 22 2.12 Reactor Coolant System (RCS) Pressure. Temperature. and Flow Departure from Nucleate Boiling (DNB) Limits (LCO 3.4.1) 2.12 .1 The pressurizer pressure shall be greater than _or equal to 2209 psig .

2.12.2 The RCS average temperature (Tav9) shall be less than or equal to 593.1 °F.

2.12 .3 The RCS total flow rate shall be greater than or equal to 386,000 gpm.

2.13 Boron Concentration 2.13.1 The refueling boron concentration shall be greater than or equal to the applicable value given in the Table below (LCO 3.9.1). The reported "prior to initial criticality" value also bounds the end-of-cycle requirements for the previous cycle.

2.13.2 To maintain keff ~ 0.987 with all shutdown and control rods fully withdrawn in MODES 3, 4, or 5 (TRM TLCO 3.1.g Required Action B.2 and TRM TLCO 3.1.k.2) , the Reactor Coolant System boron concentration shall be greater than or equal to the applicable value given in the Table below.

COLR Conditions Boron Concentration Section (ppm) 2.13.1 a) prior to initial criticality 1737 b) for cycle burnups 2 0 MWD/MTU 1843 and < 16000 MWD/MTU c) for cycle burnups 2 16000 MWD/MTU 1472 2.13.2 a) prior to initial criticality 1793 b) for cycle burnups 2 0 MWD/MTU and < 16000 MWD/MTU 2054 c) for cycle burnups 2 16000 1611 MWD/MTU

&25(23(5$7,1*/,0,765(3257 &2/5

)25

%5$,':22' 81,7 &<&/(

(;(/2175$&.,1*,'

&2/5%5$,':22' 5(9,6,21

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

&25(23(5$7,1*/,0,765(3257 7KLV&RUH2SHUDWLQJ/LPLWV5HSRUW &2/5 IRU%UDLGZRRG 6WDWLRQ8QLW &\FOH KDVEHHQSUHSDUHGLQ

DFFRUGDQFHZLWKWKHUHTXLUHPHQWVRI7HFKQLFDO6SHFLILFDWLRQ ,76

7KH7HFKQLFDO6SHFLILFDWLRQ6DIHW\/LPLWVDQG/LPLWLQJ&RQGLWLRQVIRU2SHUDWLRQ /&2V DIIHFWHGE\WKLV

UHSRUWDUHOLVWHGEHORZ

6/ 5HDFWRU&RUH6DIHW\/LPLWV 6/V

/&2 6+87'2:10$5*,1 6'0

/&2 0RGHUDWRU7HPSHUDWXUH&RHIILFLHQW 07&

/&2 5RG*URXS$OLJQPHQW/LPLWV

/&2 6KXWGRZQ%DQN,QVHUWLRQ/LPLWV

/&2 &RQWURO%DQN,QVHUWLRQ/LPLWV

/&2 3+<6,&67(676([FHSWLRQV+/- 02'(

/&2 +HDW)OX[+RW&KDQQHO)DFWRU )4 =

/&2 1XFOHDU(QWKDOS\5LVH+RW&KDQQHO)DFWRU )1'+

/&2 $;,$/)/8;',))(5(1&( $)'

/&2 'HSDUWXUHIURP1XFOHDWH%RLOLQJ5DWLR '1%5

/&2 5HDFWRU7ULS6\VWHP 576 ,QVWUXPHQWDWLRQ

/&2 %RURQ'LOXWLRQ3URWHFWLRQ6\VWHP %'36

/&2 5HDFWRU&RRODQW6\VWHP 5&6 3UHVVXUH7HPSHUDWXUHDQG)ORZ'HSDUWXUHIURP1XFOHDWH

%RLOLQJ '1% /LPLWV

/&2 %RURQ&RQFHQWUDWLRQ 7KHSRUWLRQVRIWKH7HFKQLFDO5HTXLUHPHQWV0DQXDO 750 DIIHFWHGE\WKLVUHSRUWDUHOLVWHGEHORZ

7507/&2E %RUDWLRQ)ORZ3DWKV+/- 2SHUDWLQJ 7507/&2G &KDUJLQJ3XPSV+/- 2SHUDWLQJ 7507/&2I %RUDWHG:DWHU6RXUFHV+/- 2SHUDWLQJ 7507/&2J 3RVLWLRQ,QGLFDWLRQ6\VWHP+/- 6KXWGRZQ 7507/&2K 6KXWGRZQ0DUJLQ 6'0 +/- 02'(DQG02'(ZLWKNHIIt

7507/&2L 6KXWGRZQ0DUJLQ 6'0 +/- 02'(

7507/&2M 6KXWGRZQDQG&RQWURO5RGV 7507/&2N 3RVLWLRQ,QGLFDWLRQ6\VWHP+/- 6KXWGRZQ 6SHFLDO7HVW([FHSWLRQ

COLR BRAIDWOOD 2 Revision 13 Page 2of15 CORE OPERATING LIMITS REPORT (COLR) for BRAIDWOOD UNIT 2 CYCLE 22 2.0 OPERATING LIMITS The cycle-specific parameter limits for the specifications listed in Section 1.0 are presented in the following subsections. These limits are applicable for the entire cycle unless otherwise identified. These limits have been developed using the NRG-approved methodologies specified in Technical Specification 5.6.5.

2.1 Reactor Core Safety Limits (Sls) (SL 2.1.1) 2.1.1 In MODES 1 and 2, the combination of Thermal Power, Reactor Coolant System (RCS) highest loop average temperature, and pressurizer pressure shall not exceed the limits specified in Figure 2.1.1.

680 2471 psia 660

~

Li_ 2250 psia o>

Q)

CJ

'-._../

Q)

<,.__ 640

=> 2000 psia

-+-'

0<,.__

Q) o_

1860 psia E

Q) f--

Q) 620 *---

QI 0<,.__

Q)

<(

600 580 0 0.2 0.4 Q.6 o.s 1.2 Frac tion of Nomino I Power Figure 2.1.1: Reactor Core Limits

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

6+87'2:10$5*,1 6'0 7KH6'0OLPLWIRU02'(6DQGLV

7KH6'0VKDOOEHJUHDWHUWKDQRUHTXDOWR'NN /&2V

7507/&2VEGIKDQGM

7KH6'0OLPLWIRU02'(LV

6'0VKDOOEHJUHDWHUWKDQRUHTXDOWR'NN /&2/&27507/&2VL

DQGM

0RGHUDWRU7HPSHUDWXUH&RHIILFLHQW 07& /&2

7KH0RGHUDWRU7HPSHUDWXUH&RHIILFLHQW 07& OLPLWVDUH

7KH%2/$52+=307&XSSHUOLPLWVKDOOEH [ 'NN)

7KH(2/$52+)307&ORZHU OLPLWVKDOOEH[ 'NN)

7KH(2/$52+)307&6XUYHLOODQFHOLPLWDWSSPVKDOOEH[ 'NN)

ZKHUH %2/VWDQGVIRU%HJLQQLQJRI&\FOH/LIH

$52VWDQGVIRU$OO5RGV2XW

+=3VWDQGVIRU+RW=HUR7KHUPDO3RZHU (2/VWDQGVIRU(QGRI&\FOH/LIH

+)3VWDQGVIRU+RW)XOO7KHUPDO3RZHU

6KXWGRZQ%DQN,QVHUWLRQ/LPLWV /&2

$OOVKXWGRZQEDQNVVKDOOEHIXOO\ZLWKGUDZQWRDW OHDVWVWHSV

&RQWURO%DQN,QVHUWLRQ/LPLWV /&2

7KH FRQWURO EDQNV ZLWK %DQN $ JUHDWHU WKDQ RU HTXDO WR VWHSV VKDOO EH OLPLWHG LQ SK\VLFDOLQVHUWLRQDVVKRZQLQ)LJXUH

(DFKFRQWUROEDQNVKDOOEHFRQVLGHUHGIXOO\ZLWKGUDZQIURPWKHFRUHDWJUHDWHUWKDQRUHTXDO

WRVWHSV

7KHFRQWUROEDQNVVKDOOEHRSHUDWHGLQVHTXHQFHE\ZLWKGUDZDORI%DQN$%DQN%%DQN

&DQG%DQN'7KHFRQWUROEDQNVVKDOOEHVHTXHQFHGLQUHYHUVHRUGHUXSRQLQVHUWLRQ

(DFKFRQWUROEDQNQRWIXOO\ZLWKGUDZQIURPWKHFRUHVKDOOEHRSHUDWHGZLWKWKHIROORZLQJ RYHUODSOLPLWVDVDIXQFWLRQRISDUNSRVLWLRQ

3DUN3RVLWLRQ VWHS 2YHUODS/LPLW VWHS

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

)LJXUH

&RQWURO%DQN,QVHUWLRQ/LPLWV9HUVXV3HUFHQW5DWHG7KHUPDO3RZHU

%$1.%

5RG%DQN3RVLWLRQ 6WHSV:LWKGUDZQ

%$1.&

%$1.'

5DWHG7KHUPDO3RZHU 3HUFHQW

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

+HDW)OX[+RW&KDQQHO)DFWRU )4 = /&2

7RWDO3HDNLQJ)DFWRU

)4573

)4 = d xK Z IRU 3 d

)4573

)4 = d xK Z IRU 3 !

3 ZKHUH 3 WKHUDWLRRI7+(50$/32:(5WR5$7('7+(50$/32:(5

)4573

. = LVSURYLGHGLQ)LJXUH

)LJXUH

=

1RUPDOL]HG) 4

1RUPDOL]HG) 4 DVD)XQFWLRQRI&RUH+HLJKW

= DVD)XQFWLRQRI&RUH+HLJKW

. = 1RUPDOL]HG)4 =

/2&$/LPLWLQJ

(QYHORSH (QYHORSH

%27720&RUH+HLJKW

%27720&RUH+HLJKW IW 723 IW 723

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

: = 9DOXHV

D :KHQWKH3RZHU'LVWULEXWLRQ0RQLWRULQJ6\VWHP 3'06 LV23(5$%/(: =

IRUDOOD[LDOSRLQWV

E :KHQ3'06LVLQRSHUDEOH: = LVSURYLGHGDV

7DEOHDDUHWKHQRUPDORSHUDWLRQ: = YDOXHVWKDWFRUUHVSRQGWRWKH1250$/

$;,$/ )/8; ',))(5(1&( $)' $FFHSWDEOH 2SHUDWLRQ /LPLWV SURYLGHG LQ )LJXUH

D7KH1RUPDO$)'$FFHSWDEOH2SHUDWLRQ/LPLWVPD\EHLQYRNHGDWDQ\WLPHDQG

PXVWEHXVHGZLWKWKHFRUUHVSRQGLQJ: = YDOXHV

7DEOHEDUHWKH([SDQGHGQRUPDORSHUDWLRQ: = YDOXHVWKDWFRUUHVSRQGWRWKH

(;3$1'('$;,$/)/8;',))(5(1&( $)' $FFHSWDEOH2SHUDWLRQ/LPLWVSURYLGHG

LQ)LJXUHE7KH([SDQGHG$)'$FFHSWDEOH2SHUDWLRQ/LPLWVPD\EHLQYRNHGDW

DQ\WLPHDQGPXVWEHXVHGZLWKWKHFRUUHVSRQGLQJ: = YDOXHV

7DEOHFVKRZVWKH)&4 ] SHQDOW\IDFWRUVWKDWDUHJUHDWHUWKDQSHU(IIHFWLYH

)XOO 3RZHU 'D\V ()3' 7KHVH YDOXHV VKDOO EH XVHG WR LQFUHDVH WKH ): 4 ] DV SHU

6XUYHLOODQFH5HTXLUHPHQW$SHQDOW\IDFWRUVKDOOEHXVHGDWDOOF\FOHEXUQXSV

WKDWDUHRXWVLGHWKHUDQJHRI7DEOHF

8QFHUWDLQW\

7KHXQFHUWDLQW\8)4WREHDSSOLHGWRWKH+HDW)OX[+RW&KDQQHO)DFWRU)4 = VKDOOEH

FDOFXODWHGE\WKHIROORZLQJIRUPXOD U FQ U qu x U e ZKHUH

8TX %DVH)4 PHDVXUHPHQWXQFHUWDLQW\ ZKHQ3'06LVLQRSHUDEOH 8TX LVGHILQHGE\3'06ZKHQ23(5$%/(

8H (QJLQHHULQJXQFHUWDLQW\IDFWRU

3'06$ODUPV

)4 = :DUQLQJ6HWSRLQW )4 = 0DUJLQ

)4 = $ODUP6HWSRLQW )4 = 0DUJLQ

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

7DEOHD

= YHUVXV&RUH+HLJKWIRU1RUPDO$)'$FFHSWDEOH2SHUDWLRQ/LPLWVLQ )LJXUHD 7RSDQG%RWWRP([FOXGHGSHU%UDLGZRRG65%DVHV

+HLJKW

IHHW 0:'078 0:'078 0:'078 0:'078

FRUHERWWRP

FRUHWRS

1RWH : = YDOXHVDW0:'078PD\EHDSSOLHGWRF\FOHEXUQXSVJUHDWHUWKDQ

0:'078WRSUHYHQW: = IXQFWLRQH[WUDSRODWLRQ

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

7DEOHE

= YHUVXV&RUH+HLJKWIRU([SDQGHG $)'$FFHSWDEOH2SHUDWLRQ/LPLWVLQ)LJXUHE 7RSDQG%RWWRP([FOXGHGSHU%UDLGZRRG65%DVHV

+HLJKW

IHHW 0:'078 0:'078 0:'078 0:'078

FRUHERWWRP

FRUHWRS

1RWH : = YDOXHVDW0:'078PD\EHDSSOLHGWRF\FOHEXUQXSVJUHDWHUWKDQ

0:'078WRSUHYHQW: = IXQFWLRQH[WUDSRODWLRQ

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

7DEOHF 3HQDOW\)DFWRUVLQ([FHVVRISHU()3'

&\FOH%XUQXS 3HQDOW\)DFWRU 0:'078 ) &4 ]

1RWHV

/LQHDULQWHUSRODWLRQLVDGHTXDWHIRULQWHUPHGLDWHF\FOHEXUQXSV

$OOF\FOHEXUQXSVRXWVLGHWKHUDQJHRI7DEOHF VKDOOXVHDSHQDOW\IDFWRUIRUFRPSOLDQFHZLWKWKH

6XUYHLOODQFH5HTXLUHPHQWV

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

1XFOHDU(QWKDOS\5LVH+RW&KDQQHO)DFWRU )1'+ /&2

)1'+ d )573

'+ >3)'+ 3 @

ZKHUH 3 WKHUDWLRRI7+(50$/32:(5WR5$7('7+(50$/32:(5 573

)573

'+

3)'+

8QFHUWDLQW\

7KHXQFHUWDLQW\8)'+WREHDSSOLHGWRWKH1XFOHDU(QWKDOS\5LVH+RW&KDQQHO)DFWRU

)1'+ VKDOOEHFDOFXODWHGE\WKHIROORZLQJIRUPXOD

8)'+ 8)'+P ZKHUH

UF'Hm %DVH)1'+ PHDVXUHPHQWXQFHUWDLQW\ ZKHQ3'06LVLQRSHUDEOH 8)'+P LVGHILQHGE\3'06ZKHQ23(5$%/(

3'06$ODUPV

)1'+ :DUQLQJ6HWSRLQW )1'+ 0DUJLQ

)1'+ $ODUP6HWSRLQW )1'+ 0DUJLQ

$;,$/)/8;',))(5(1&( $)' /&2

7KH$;,$/)/8;',))(5(1&( $)' $FFHSWDEOH2SHUDWLRQ/LPLWVDUHSURYLGHGLQWKH

)LJXUHVGHVFULEHGEHORZ

D )LJXUHDLVWKH1RUPDO$)'$FFHSWDEOH2SHUDWLRQ/LPLWVDVVRFLDWHGZLWKWKH

= YDOXHVLQ7DEOHD3ULRUWRFKDQJLQJWR)LJXUHDFRQILUPWKDWWKH

SODQWLVZLWKLQWKHVSHFLILHG$)'HQYHORSH

E )LJXUHELVWKH([SDQGHG$)'$FFHSWDEOH2SHUDWLRQ/LPLWVDVVRFLDWHGZLWKWKH

= YDOXHVLQ7DEOHE

'HSDUWXUHIURP1XFOHDWH%RLOLQJ5DWLR '1%5 /&2

'1%5$36/ t

7KH$[LDO3RZHU6KDSH/LPLWLQJ'1%5 '1%5$36/ LVDSSOLFDEOHZLWK7+(50$/32:(5

t 573ZKHQ3'06LV23(5$%/(

3'06$ODUPV

'1%5:DUQLQJ6HWSRLQW '1%50DUJLQ

'1%5$ODUP6HWSRLQW '1%50DUJLQ

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

)LJXUHD

1RUPDO$[LDO)OX['LIIHUHQFH/LPLWV

DVD)XQFWLRQRI5DWHG7KHUPDO 3RZHU EŽ&>

ŽZdd,ZD>WKtZ h h KŽ KŽ

KŽ

y/>&>hy/&&ZE

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

)LJXUHE

([SDQGHG$[LDO)OX['LIIHUHQFH/LPLWV

DVD)XQFWLRQRI5DWHG7KHUPDO3RZHU

&>

ŽZdd,ZD>WKtZ h h KŽ KŽ

KŽ

y/>&>hy/&&ZE

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

5HDFWRU7ULS6\VWHP 576 ,QVWUXPHQWDWLRQ /&2 2YHUWHPSHUDWXUH'76HWSRLQW

3DUDPHWHU9DOXHV

7KH2YHUWHPSHUDWXUH'7UHDFWRUWULSVHWSRLQW. VKDOOEHHTXDOWR

7KH2YHUWHPSHUDWXUH'7UHDFWRUWULSVHWSRLQW7DYJFRHIILFLHQW. VKDOOEHHTXDOWR

)

7KH2YHUWHPSHUDWXUH'7UHDFWRUWULSVHWSRLQWSUHVVXUHFRHIILFLHQW . VKDOOEHHTXDOWR

SVL

7KHQRPLQDO7DYJDW573 LQGLFDWHG 7c VKDOOEHOHVVWKDQRUHTXDOWR )

7KHQRPLQDO5&6RSHUDWLQJSUHVVXUH LQGLFDWHG 3c VKDOOEHHTXDOWRSVLJ

7KHPHDVXUHGUHDFWRUYHVVHO'7OHDGODJWLPHFRQVWDQWWVKDOOEHHTXDOWRVHF

7KHPHDVXUHGUHDFWRUYHVVHO'7ODJWLPHFRQVWDQWWVKDOOEHOHVVWKDQRUHTXDOWR

VHF

7KHPHDVXUHGUHDFWRUYHVVHODYHUDJHWHPSHUDWXUHOHDGODJWLPHFRQVWDQWWVKDOOEH

HTXDOWRVHF

7KHPHDVXUHGUHDFWRUYHVVHODYHUDJHWHPSHUDWXUHOHDGODJWLPHFRQVWDQWWVKDOOEH

HTXDOWRVHF

7KHPHDVXUHGUHDFWRUYHVVHODYHUDJHWHPSHUDWXUHODJWLPHFRQVWDQWWVKDOOEHOHVV

WKDQRUHTXDOWRVHF

7KHI ', ³SRVLWLYH'EUHDNSRLQWVKDOOEH',

7KHI ', ³QHJDWLYH'EUHDNSRLQWVKDOOEH',

7KHI ', ³SRVLWLYH'VORSHVKDOOEH',

7KHI ', ³QHJDWLYH'VORSHVKDOOEH',

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

5HDFWRU7ULS6\VWHP 576 ,QVWUXPHQWDWLRQ /&2 2YHUSRZHU'76HWSRLQW3DUDPHWHU

9DOXHV

7KH2YHUSRZHU'7UHDFWRUWULSVHWSRLQW. VKDOOEHHTXDOWR

7KH2YHUSRZHU'7UHDFWRUWULSVHWSRLQW7DYJUDWHODJFRHIILFLHQW. VKDOOEHHTXDOWR

)IRULQFUHDVLQJ7DYJ

7KH2YHUSRZHU'7UHDFWRUWULSVHWSRLQW7DYJUDWHODJFRHIILFLHQW. VKDOOEHHTXDOWR

)IRUGHFUHDVLQJ7DYJ

7KH2YHUSRZHU'7UHDFWRUWULSVHWSRLQW7DYJKHDWXSFRHIILFLHQW. VKDOOEHHTXDOWR

)ZKHQ7! 7s

7KH2YHUSRZHU'7UHDFWRUWULSVHWSRLQW7DYJKHDWXSFRHIILFLHQW. VKDOOEHHTXDOWR )

ZKHQ7d 7s

7KHQRPLQDO7DYJDW573 LQGLFDWHG 7s VKDOOEHOHVVWKDQRUHTXDOWR )

7KHPHDVXUHGUHDFWRUYHVVHO'7OHDGODJWLPHFRQVWDQWWVKDOOEHHTXDOWRVHF

7KHPHDVXUHGUHDFWRUYHVVHO'7ODJWLPHFRQVWDQWWVKDOOEHOHVVWKDQRUHTXDOWR

VHF

7KHPHDVXUHGUHDFWRUYHVVHODYHUDJHWHPSHUDWXUHODJWLPHFRQVWDQWWVKDOOEHOHVV

WKDQRUHTXDOWRVHF

7KHPHDVXUHGUHDFWRUYHVVHODYHUDJHWHPSHUDWXUHUDWHODJWLPHFRQVWDQWWVKDOOEH

HTXDOWRVHF

7KHI ', ³SRVLWLYH'EUHDNSRLQWVKDOOEHIRUDOO',

7KHI ', ³QHJDWLYH'EUHDNSRLQWVKDOOEHIRUDOO',

7KHI ', ³SRVLWLYH'VORSHVKDOOEHIRUDOO',

7KHI ', ³QHJDWLYH'VORSHVKDOOEHIRUDOO',

&2/5%5$,':22'

5HYLVLRQ

3DJH RI

&25(23(5$7,1*/,0,765(3257 &2/5 IRU%5$,':22'81,7&<&/(

5HDFWRU&RRODQW6\VWHP 5&6 3UHVVXUH7HPSHUDWXUHDQG)ORZ'HSDUWXUHIURP1XFOHDWH

%RLOLQJ '1% /LPLWV /&2

7KHSUHVVXUL]HUSUHVVXUHVKDOOEHJUHDWHUWKDQRUHTXDOWRSVLJ

7KH5&6DYHUDJHWHPSHUDWXUH 7DYJ VKDOOEHOHVVWKDQRUHTXDOWR )

7KH5&6WRWDOIORZUDWHVKDOOEHJUHDWHUWKDQRUHTXDOWRJSP

%RURQ&RQFHQWUDWLRQ

7KHUHIXHOLQJERURQFRQFHQWUDWLRQVKDOOEHJUHDWHUWKDQRUHTXDOWRWKHDSSOLFDEOHYDOXH

JLYHQLQWKH7DEOHEHORZ /&2 7KHUHSRUWHG³SULRUWRLQLWLDOFULWLFDOLW\'YDOXHDOVR

ERXQGVWKHHQGRIF\FOHUHTXLUHPHQWVIRUWKHSUHYLRXVF\FOH

7RPDLQWDLQNHIId ZLWKDOOVKXWGRZQDQGFRQWUROURGVIXOO\ZLWKGUDZQLQ02'(6

RU 7507/&2J5HTXLUHG$FWLRQ%DQG7507/&2N WKH5HDFWRU

&RRODQW6\VWHPERURQFRQFHQWUDWLRQVKDOOEHJUHDWHUWKDQRUHTXDOWRWKHDSSOLFDEOH

YDOXHVJLYHQLQWKH7DEOHEHORZ

&2/5 %RURQ&RQFHQWUDWLRQ

&RQGLWLRQV 6HFWLRQ SSP

D SULRUWRLQLWLDOFULWLFDOLW\

E IRUF\FOHEXUQXSVt 0:'078

DQG0:'078 F IRUF\FOHEXUQXSV0:'078

D SULRUWRLQLWLDOFULWLFDOLW\

E IRUF\FOHEXUQXSVt 0:'078DQG

0:'078 F IRUF\FOHEXUQXSVt 0:'078

BRAIDWOOD UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

Revision 8

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table of Contents Section Page 1.0 Introduction 1 2.0 RCS Pressure and Temperature Limits 1 2.1 RCS Pressure and Temperature (P/T) Limits (LCO 3.4.3) 1 3.0 Low Temperature Over Pressure Protection and Boltup 7 3.1 LTOP System Setpoints (LCO 3.4.12) 7 3.2 LTOP Enable Temperature 7 3.3 Reactor Vessel Boltup Temperature (Non-Technical Specification) 7 4.0 Reactor Vessel Material Surveillance Program 10 5.0 Supplemental Data Tables 12 6.0 References 18 i

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT List of Figures Figure Page 2.1 Braidwood Unit 1 Reactor Coolant System Heatup Limitations (Heatup 3 Rate of 100!F/hr) Applicable for 32 EFPY (Without Margins for Instrumentation Errors) 2.2 Braidwood Unit 1 Reactor Coolant System Cooldown Limitations 4 (Cooldown Rates of 0, 25, 50, and 100!F/hr) Applicable for 32 EFPY (Without Margins for Instrumentation Errors) 3.1 Braidwood Unit 1 Nominal PORV Setpoints for the Low Temperature 8 Overpressure Protection (LTOP) System Applicable for 32 EFPY (Includes Instrumentation Uncertainty) ii

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT List of Tables Table Page 2.1a Braidwood Unit 1 Heatup Data Points at 32 EFPY (Without 5 Margins for Instrumentation Errors) 2.1b Braidwood Unit 1 Cooldown Data Points at 32 EFPY (Without 6 Margins for Instrumentation Errors) 3.1 Data Points for Braidwood Unit 1 Nominal PORV Setpoints for 9 the LTOP System Applicable for 32 EFPY (Includes Instrumentation Uncertainty) 4.1 Braidwood Unit 1 Surveillance Capsule Withdrawal Summary 11 5.1 Braidwood Unit 1 Calculation of Chemistry Factors Using 13 Surveillance Capsule Data 5.2 Braidwood Unit 1 Reactor Vessel Material Properties 14 5.3 Summary of Braidwood Unit 1 Adjusted Reference Temperature 15 (ART) Values at 1/4T and 3/4T Locations for 32 EFPY 5.4 Braidwood Unit 1 Calculation of Adjusted Reference 16 Temperatures (ARTs) at 32 EFPY at the Limiting Reactor Vessel Material, Nozzle Shell Forging 5P-7016 5.5 RTPTS Calculation for Braidwood Unit 1 Beltline Region 17 Materials at EOL (32 EFPY) iii

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT 1.0 Introduction This Pressure and Temperature Limits Report (PTLR) for Braidwood Unit 1 has been prepared in accordance with the requirements of Braidwood Technical Specification (TS) 5.6.6, "Reactor Coolant System (RCS) Pressure and Temperature Limits Report (PTLR)".

Revisions to the PTLR shall be provided to the NRC after issuance.

The Technical Specifications (TS) addressed in this report are listed below:

LCO 3.4.3 RCS Pressure and Temperature (P/T) Limits; and LCO 3.4.12 Low Temperature Overpressure Protection (LTOP) System.

2.0 RCS Pressure and Temperature Limits The PTLR limits for Braidwood Unit 1 were developed using a methodology specified in the Technical Specifications. The methodology listed in WCAP-14040-NP-A, Revision 2 (Reference 1) was used with the following exceptions:

a) Optional use of ASME Code Section XI, Appendix G, Article G-2000, 1996 Addenda, b) Use of ASME Code Case N-640, Alternative Reference Fracture Toughness for Development of P-T Limit Curves,Section XI, Division 1, c) Use of ASME Code Case N-588, Alternative to Reference Flaw Orientation of Appendix G for Circumferential Welds in Reactor Vessel,Section XI, Division 1, and d) Elimination of the flange requirements documented in WCAP-16143-P.

These exceptions to the methodology in WCAP 14040-NP-A, Revision 2 have been reviewed and accepted by the NRC in References 2, 8, 9 and 10.

WCAP 15364, Revision 2 (Reference 11), provides the basis for the Braidwood Unit 1 P/T curves, along with the best estimate chemical compositions, fluence projections and adjusted reference temperatures used to determine these limits. WCAP-16143-P, Reference 12, documents the technical basis for the elimination of the flange requirements.

2.1 RCS Pressure and Temperature (P/T) Limits (LCO 3.4.3) 2.1.1 The RCS temperature rate-of-change limits defined in WCAP-15364, Revision 2 (Reference 11) are:

a. A maximum heatup of 100!F in any 1-hour period,

b. A maximum cooldown of 100!F in any 1-hour period, and 1

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT

c. A maximum temperature change of less than or equal to 10!F in any 1-hour period during inservice hydrostatic and leak testing operations above the heatup and cooldown limit curves.

2.1.2 The RCS P/T limits for heatup, inservice hydrostatic and leak testing, and criticality are specified by Figure 2.1 and Table 2.1a. The RCS P/T limits for cooldown are shown in Figure 2.2 and Table 2.1b. These limits are defined in WCAP-15364, Revision 2 (Reference 11). Consistent with the methodology described in Reference 1 and exceptions noted in Section 2.0, the RCS P/T limits for heatup and cooldown shown in Figures 2.1 and 2.2 are provided without margins for instrument error. These limits were developed using ASME Boiler and Pressure Vessel Code Section XI, Appendix G, Article G2000, 1996 Addenda.

The criticality limit curve specifies pressure-temperature limits for core operation to provide additional margin during actual power production as specified in 10 CFR 50, Appendix G.

The 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.

2

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT MATERIAL PROPERTY BASIS LIMITING MATERIAL: NOZZLE SHELL FORGING 5P-7016 LIMITING ART VALUES AT 32 EFPY: 1/4T, 48!F 3/4T, 35!F 2500 Leak Test Limit Operlim Version:5.1 Run:29844 2250 Acceptable 2000 Operation Unacceptable Operation 1750 Calculated Pressure (PSIG)

Critical Limit Heatup Rate 100 Deg. F/Hr 1500 100 Deg. F/Hr 1250 1000 Criticality Limit based on 750 inservice hydrostatic test Calculated Pressure (PSIG) temperature (108°F) for the service period up to 32 EFPY 500 Boltup Temp 250 The lower limit for RCS 0 pressure is 0 psia

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

Figure 2.1 Braidwood Unit 1 Reactor Coolant System Heatup Limitations (Heatup Rate of 100°F/hr)

Applicable for 32 EFPY (Without Margins for Instrumentation Errors) 3

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT MATERIAL PROPERTY BASIS LIMITING MATERIAL: NOZZLE FORGING 5P-7016 LIMITING ART VALUES AT 32 EFPY: 1/4T, 48!F 3/4T, 35!F 2500 Operlim Version:5.1 Run:29844 2250 Unacceptable Operation Acceptable 2000 Operation 1750 Calculated Pressure (PSIG) 1500 1250 Cooldown Rates

(°F/Hr) 1000 steady-state,

-25,

-50, and

-100 750 Calculated Pressure (PSIG) 500 Boltup Temp.

250 The lower limit for RCS pressure is 0 psia 0

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

Figure 2.2 Braidwood Unit 1 Reactor Coolant System Cooldown Limitations (Cooldown Rates of 0, 25, 50 and 100!!F/hr) Applicable for 32 EFPY (Without Margins for Instrumentation Errors) 4

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table 2.1a Braidwood Unit 1 Heatup Data Points at 32 EFPY (Without Margins for Instrumentation Errors)

Heatup Curve 100 F Heatup Criticality Leak Test Limit Limit T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) 60 Note 1 108 Note 1 91 2000 60 1064 108 1114 108 2485 65 1114 110 1166 70 1166 115 1172 75 1172 120 1176 80 1176 125 1188 85 1188 130 1207 90 1207 135 1234 95 1234 140 1267 100 1267 145 1308 105 1308 150 1357 110 1357 155 1414 115 1414 160 1479 120 1479 165 1554 125 1554 170 1638 130 1638 175 1732 135 1732 180 1838 140 1838 185 1956 145 1956 190 2088 150 2088 195 2235 155 2235 200 2397 160 2397 Note 1:The Minimum acceptable pressure is 0 psia 5

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table 2.1b Braidwood Unit 1 Cooldown Data Points at 32 EFPY (Without Margins for Instrumentation Errors)

Cooldown Curves Steady State 25 !F Cooldown 50 !F Cooldown 100 !F Cooldown T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) 60 Note 1 60 ( i )1 Note 60 Note 1 60 Note 1 60 1082 60 1078 60 1078* 60 1078*

65 1133 65 1133 65 1133 65 1133 70 1188 70 1188 70 1188 70 1188 75 1250 75 1250 75 1250 75 1250 80 1318 80 1318 80 1318 80 1318 85 1393 85 1393 85 1393 85 1393 90 1476 90 1476 90 1476 90 1476 95 1568 95 1568 95 1568 95 1568 100 1669 100 1669 100 1669 100 1669 105 1781 105 1781 105 1781 105 1781 110 1905 110 1905 110 1905 110 1905 115 2042 115 2042 115 2042 115 2042 120 2194 120 2194 120 2194 120 2194 125 2361 125 2361 125 2361 125 2361

Refer to Reference 13 Note 1:The Minimum acceptable pressure is 0 psia 6

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT 3.0 Low Temperature Overpressure Protection and Boltup This section provides the Braidwood Unit 1 power operated relief valve lift settings, low temperature overpressure protection (LTOP) system arming temperature, and minimum reactor vessel boltup temperature.

3.1 LTOP System Setpoints (LCO 3.4.12)

The power operated relief valves (PORVs) shall each have maximum lift settings in accordance with Figure 3.1 and Table 3.1. These limits are based on References 3 and 4.

The LTOP setpoints are based on P/T limits which were established in accordance with 10 CFR 50, Appendix G without allowance for instrumentation error and in accordance with the methodology described in Reference 1. The LTOP PORV nominal lift settings shown in Figure 3.1 and Table 3.1 account for appropriate instrument error.

3.2 LTOP Enable Temperature Braidwood Unit 1 procedures governing the heatup and cooldown of the RCS require the arming of the LTOP System for RCS temperature of 350!F and below and disarming of LTOP for RCS temperature above 350!F.

Note that the last LTOP PORV segment in Table 3.1 extends to 400!F where the pressure setpoint is 2335 psig. This is intended to prohibit PORV lift for an inadvertent LTOP system arming at power.

3.3 Reactor Vessel Boltup Temperature (Non-Technical Specification)

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.

7

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT 2500 2335 psig 2250 2000 1750 Nominal PORV Pressure (PSIG) 1500 Unacceptable Operation 1250 1000 PCV-456 750 595 psig 500 541 psig PCV-455A 250 0

0 50 100 150 200 250 300 350 400 450 Auctioneered Low RCS Temperature (DEG. F)

Figure 3.1 Braidwood Unit 1 Nominal PORV Setpoints for the Low Temperature Overpressure Protection (LTOP) System Applicable for 32 EFPY (Includes Instrumentation Uncertainty) 8

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table 3.1 Data Points for Braidwood Unit 1 Nominal PORV Setpoints for the LTOP System Applicable for 32 EFPY (Includes Instrumentation Uncertainty)

PCV-455A PCV-456 (1TY-0413M) (1TY-0413P)

AUCTIONEERED LOW RCS PRESSURE AUCTIONEERED LOW RCS PRESSURE RCS TEMP. (DEG. F) (PSIG) RCS TEMP. (DEG. F) (PSIG) 60 541 60 595 300 541 300 595 400 2335 400 2335 Note: To determine nominal lift setpoints for RCS Pressure and RCS Temperatures greater than 300!F, linearly interpolate between the 300!F and 400!F data points shown above. (Setpoints extend to 400°F to prevent PORV liftoff from an inadvertent LTOP system arming while at power.)

9

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT 4.0 Reactor Vessel Material Surveillance Program The pressure vessel material surveillance program (Reference 5) is in compliance with Appendix H to 10 CFR 50, Reactor Vessel Radiation Surveillance Program. The material test requirements and the acceptance standard utilize the reference nil-ductility temperature, RTNDT , which is determined in accordance with ASME Boiler and Pressure Vessel Code 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 E185-82.

The third and final reactor vessel material irradiation surveillance specimens (Capsule W) have been removed and analyzed to determine changes in material properties. The surveillance capsule testing has been completed for the original operating period. The remaining three capsules, V, Y, and Z, were removed and placed in the spent fuel pool to avoid excessive fluence accumulation should they be needed to support life extension.

The removal summary is provided in Table 4.1.

10

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table 4.1 0B Braidwood Unit 1 Capsule Withdrawal Summary(a) 1B Capsule Fluence Capsule Lead Factor Withdrawal EFPY(b) 2 Location (n/cm , E>1.0 MeV)

U 58.5! 4.02 1.16 0.388 x 1019 X 238.5! 4.06 4.30 1.17 x 1019 W 121.5! 4.05 7.79 1.98 x 1019 Z(c) 301.5! 4.09 12.01 (EOC 10) 2.79 x 1019 V(c) 61.0! 3.92 17.69 (EOC 14) 3.71 x 1019 Y(c) 241.0! 3.81 12.01 (EOC 10) 2.60 x 1019 Notes:

(a) Source document is CN-AMLRS-10-7 (Reference 14), Table 5.7-3.

(b) Effective Full Power Years (EFPY) from plant startup.

(c) Standby Capsules Z, V, and Y were removed and placed in the spent fuel pool. No testing or analysis has been performed on these capsules. If license renewal is sought, one of these standby capsules may need to be tested to determine the effect of neutron irradiation on the reactor vessel surveillance materials during the period of extended operation.

11

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT 5.0 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 5.1 shows the calculation of the surveillance material chemistry factors using surveillance capsule data.

Table 5.2 provides the reactor vessel material properties table.

Table 5.3 provides a summary of the Braidwood Unit 1 adjusted reference temperature (ART) values at the 1/4T and 3/4T locations for 32 EFPY.

Table 5.4 shows the calculation of ARTs at 32 EFPY for the limiting Braidwood Unit 1 reactor vessel material, i.e. weld WF-562 ( HT # 442011, Based on Surveillance Capsules U and X Data).

Table 5.5 provides the RTPTS calculation for Braidwood Unit 1 Beltline Region Materials at EOL (32 EFPY), (Reference 7).

12

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.1 Braidwood Unit 1 Calculation of Chemistry Factors Using Surveillance Capsule Data(a)

Capsule f(b) #RTNDT(b) FF*#RTNDT Material Capsule FF(c) FF2 (n/cm2, E > 1.0 MeV) (!F) (!F)

U 0.388 x 1019 0.738 5.78 4.26 0.54 Lower Shell 19 Forging X 1.17 x 10 1.044 38.23 39.91 1.09 (Tangential) 19 W 1.98 x 10 1.186 24.14 28.64 1.41 19 (d)

U 0.388 x 10 0.738 0.0 0.00 0.54 Lower Shell 19 Forging X 1.17 x 10 1.044 28.75 30.01 1.09 (Axial)

W 1.98 x 1019 1.186 37.11 44.03 1.41 SUM: 146.85 6.08 CF LS Forging = (FF *#RTNDT) % (FF2) = (146.85) % (6.08) = 24.1!F U 0.388 x 1019 0.738 17.06 12.59 0.54 Braidwood Unit 1 19 Surveillance Weld X 1.17 x 10 1.044 30.15 31.47 1.09 Material W 1.98 x 1019 1.186 49.68 58.94 1.41 19 (d)

U 0.388 x 10 0.738 0.0 0.00 0.54 Braidwood Unit 2 Surveillance Weld X 1.15 x 1019 1.039 26.3 27.33 1.08 Material 19 W 2.07 x 10 1.198 23.9 28.63 1.44 SUM: 158.96 6.10 CF Weld Metal = (FF * #RTNDT) % (FF2) = (158.96) % (6.10) = 26.1!F Notes:

(a) Source document is CN-AMLRS-10-7 (Reference 14), Table 5.2-1.

(b) f = fluence; #RTNDT values are the measured 30 ft-lb shift values taken from Reference 6.

(c) FF = fluence factor = f(0.28 - 0.10*log f)

(d) Measured NRTNDT values were determined to be negative, but physically a reduction should not occur; therefore, conservative values of zero are used.

13

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.2 Braidwood Unit 1 Reactor Vessel Material Properties 2B Chemistry Initial Material Description Cu (%) Ni (%)

Factor RT NDT (ºF)(a)

Closure Head Flange 0.11 0.67 -- -20 Heat # 5P7381/3P6406 Vessel Flange

-- 0.77 -- -10 Heat # 122N357V Nozzle Shell Forging

0.04 0.73 26.0°F(b) 10 Heat # 5P-7016 Intermediate Shell Forging

0.05 0.73 31.0°F(b) -30 Heat # [49D383/49C344]-1-1 Lower Shell Forging

31.0°F(b) 0.05 0.74 -20 Heat # [49D867/49C813]-1-1 24.1°F(c)

Circumferential Weld

41.0°F(b)

(Intermediate Shell to Lower Shell) 0.03 0.67 40 WF-562 (HT# 442011) 26.1°F(c)

Upper Circumferential Weld *

(Nozzle Shell to Intermediate Shell) 0.04 0.46 54.0°F(b) -25 WF-645 (HT# H4498)

Beltline Region Materials a) The Initial RTNDT values for the plates and welds are based on measured data.

b) Chemistry Factor calculated for Cu and Ni values per Regulatory Guide 1.99, Rev. 2, Position 1.1.

c) Chemistry Factor calculated for Cu and Ni values per Regulatory Guide 1.99, Rev. 2, Position 2.1.

14

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.3 3B Summary of Braidwood Unit 1 Adjusted Reference Temperature (ART) Values at 1/4T and 3/4T Locations for 32 EFPY(a) 32 EFPY Surface Fluence Reactor Vessel Material 1/4T ART 3/4T ART (n/cm2, E>1.0 MeV)

(!!F) (!F)

Nozzle Shell Forging 0.586 x 1019 47 34 19 Intermediate Shell Forging 1.76 x 10 33 15 19 Lower Shell Forging 1.76 x 10 43 25 19 SUsing credible surveillance data 1.76 x 10 21 15 Nozzle to Intermediate Shell Forging Circ. Weld Seam 0.586x 1019 52 25 (Heat # H4498)

Intermediate to Lower Shell Forging Circ. Weld Seam 1.70 x 1019 122 99 (Heat # 442011)

SUsing credible surveillance data 1.70 x 1019 93 78 Notes:

(a) The source document containing detailed calculations is CN-AMLRS-10-7 (Reference 14),

Tables 5.3.1-1 and 5.3.1-2. The ART values summarized in this table utilize the most recent fluence projections and materials data, but were not used in development of the P/T limit curves. See Figures 2.1 and 2.2 of this PTLR for the ART values used in development of the P/T limit curves.

15

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.4 4B Braidwood Unit 1 Calculation of Adjusted Reference Temperatures (ARTs) at 32 EFPY at the Limiting Reactor Vessel Material, Nozzle Shell Forging 5P-7016 Parameter Values Operating Time 32 EFPY Location(a) 1/4T ART(°F) 3/4T ART(°F)

Chemistry Factor, CF (!F) 26.0 26.0 Fluence(f), n/cm2 3.65 x 1018 1.32 x1018 (E>1.0 Mev)(b)

Fluence Factor, FF 0.772 0.475

RTNDT= CFxFF(!F) 18.8 12.4 Initial RT NDT,, I(!F) 10 10 Margin, M (!F) 18.8 12.4 ART= I+(CF*FF)+M,!F 48 35 per RG 1.99, Revision 2 (a) The Braidwood Unit 1 reactor vessel wall thickness is 8.5 inches at the beltline region.

(b) Fluence f, is based upon fsurf (E > 1.0 Mev) = 6.08 x 1018 at 32 EFPY (Reference 11).

16

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.5 RTPTS Calculation for Braidwood Unit 1 Beltline Region Materials at EOL (32 EFPY)(a,b)

R.G. 1.99, IRTNDT(c CF Fluence ) #RTNDT Eu(c) EF(d) Margin RTPTS Reactor Vessel Material Rev. 2 FF

(!!F) (n/cm2, E>1.0 MeV) (!F) (!F) (!F) (!F) (!F)

Position (!F)

Nozzle Shell Forging 1.1 26 0.586 x 1019 0.8504 10 22.1 0 11.1 22.1 54 19 Intermediate Shell Forging 1.1 31 1.76 x 10 1.1554 -30 35.8 0 17 34 40 19 Lower Shell Forging 1.1 31 1.76 x 10 1.1554 -20 35.8 0 17 34 50 SUsing credible surveillance data 2.1 24.1 1.76 x 1019 1.1554 -20 27.8 0 8.5 17 25 Nozzle to Intermediate Shell Forging Circ. Weld Seam 1.1 54 0.586x 1019 0.8504 -25 45.9 0 23.0 45.9 67 (Heat # H4498)

Intermediate to Lower Shell Forging Circ. Weld Seam 1.1 41 1.70 x 1019 1.1461 40 47.0 0 23.5 47.0 134 (Heat # 442011)

SUsing credible surveillance data 2.1 26.1 1.70 x 1019 1.1461 40 29.9 0 14 28 98 Notes:

(a) The 10 CFR 50.61 methodology was utilized in the calculation of the RTPTS values.

(b) The source document containing detailed calculations is CN-AMLRS-10-7 (Reference 14), Table 5.5-1.

(c) Initial RTNDT values are based on measured data. Hence, Vu = 0!F.

(d) Per the guidance of 10 CFR 50.61, the base metal VN = 17°F for Position 1.1 (without surveillance data) and with credible surveillance data VN = 8.5°F for Position 2.1; the weld metal VN = 28°F for Position 1.1 (without surveillance data) and with credible surveillance data VN =

14°F for Position 2.1. However, VN need not exceed 0.5*NRTNDT.

17

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT 6.0 References

1. WCAP-14040-NP-A, Revision 2, Methodology Used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves, J.D. Andrachek, et al., January 1996.

2. NRC Letter from R. A. Capra to O.D. Kingsley, Commonwealth Edison Company, Byron Station Units 1 and 2 and Braidwood Station Units 1 and 2, Acceptance for referring of pressure temperature limits report, (M98799, M98800, M98801, and M98802), January 21 1998.

3. Westinghouse Letter to Exelon Nuclear, CAE-10-MUR-197, Revision 0, "Low Temperature Overpressure Protection (LTOP) System Evaluation Final Letter Report," M.P. Rudakewiz, September 8, 2010.

4. Byron & Braidwood Design Information Transmittal DIT-BRW-2006-0051, Transmittal of Braidwood Unit 1 and Unit 2 Temperature and Pressure Uncertainties for Low Temperature Overpressure System (LTOPS) Power Operated Relief Valves (PORVS), Nathan (Joe)

Wolff Jr., July 18, 2006.

5. WCAP-9807, Commonwealth Edison Company, Braidwood Station Unit 1 Reactor Vessel Radiation Surveillance Program, S.E. Yanichko, et al., February 1981.

6. WCAP-15316, Revision 1, Analysis of Capsule W from Commonwealth Edison Company Braidwood Unit 1 Reactor Vessel Radiation Surveillance Program, E. Terek, et al.,

December 1999.

7. WCAP-15365, Revision 1, Evaluation of Pressurized Thermal Shock for Braidwood Unit 1, J.H. Ledger, January 2002.

8. NRC Letter from G. F. Dick, Jr., NRR, to C. Crane, Exelon Generation Company, LLC, Issuance of Amendments: Revised Pressure-Temperature Limits Methodology; Byron Station, Units 1 and 2, and Braidwood Station, Units 1 and 2, dated October 4, 2004.

9. NRC Letter from M. Chawla to O.D. Kingsley, Exelon Generation Company, LLC, Issuance of exemption from the Requirements of 10 CFR 50 Part 60 and Appendix G for Byron Station, Units 1 and 2, and Braidwood Stations, Units 1 and 2, dated August 8, 2001.

10. NRC Letter from R. F. Kuntz, NRR, to C. M. Crane, Exelon Generation Company, LLC, Byron Station, Unit Nos. 1 and 2, and Braidwood Station, Unit Nos. 1 and 2 - Issuance of Amendments Re: Reactor Coolant System Pressure and Temperature Limits Report (TAC Nos. MC8693, MC8694, MC8695, and MC8696), November 27, 2006.

18

BRAIDWOOD - UNIT 1 PRESSURE AND TEMPERATURE LIMITS REPORT

11. WCAP-15364, Revision 2, Braidwood Unit 1 Heatup and Cooldown Limit Curves for Normal Operation, T.J. Laubham, November 2003.

12. WCAP-16143-P, Revision 1, Reactor Vessel Closure Head/Vessel Flange Requirements Evaluation for Byron/Braidwood Units 1 and 2, W. Bamford, et al., October 2014.

13. Westinghouse Letter to Exelon Nuclear, CCE-07-24, Braidwood Unit 1 and 2 RCS HU/CD Limit Curve Table Values, dated February 15, 2007.

14. Westinghouse Calculation Note CN-AMLRS-10-7, Revision 0, Braidwood Units 1 and 2 Measurement Uncertainty Recapture (MUR) Uprate: Reactor Vessel Integrity Evaluations,"

A.E. Leicht, September 2010.

19

BRAIDWOOD UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

Revision 7

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table of Contents Section Page 1.0 Introduction 1 2.0 RCS Pressure Temperature Limits 1 2.1 RCS Pressure and Temperature (P/T) Limits (LCO 3.4.3) 1 3.0 Low Temperature Over Pressure Protection and Boltup 7 3.1 LTOP System Setpoints (LCO 3.4.12) 7 3.2 LTOP Enable Temperature 7 3.3 Reactor Vessel Boltup Temperature (Non-Technical Specification) 7 4.0 Reactor Vessel Material Surveillance Program 10 5.0 Supplemental Data Tables 12 6.0 References 18 i

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT List of Figures Figure Page 2.1 Braidwood Unit 2 Reactor Coolant System Heatup Limitations 3 (Heatup Rate of 100°F/hr) Applicable for 32 EFPY (Without Margins for Instrumentation Errors) 2.2 Braidwood Unit 2 Reactor Coolant System Cooldown Limitations 4 (Cooldown Rates of 0, 25, 50 and 100°F/hr) Applicable to 32 EFPY (Without Margins for Instrumentation Errors) 3.1 Braidwood Unit 2 Nominal PORV Setpoints for the Low Temperature 8 Overpressure Protection (LTOP) System Applicable for 32 EFPY (Includes Instrumentation Uncertainty) ii

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT List of Tables Table Page 2.1a Braidwood Unit 2 Heatup Data at 32 EFPY (Without 5 Margins for Instrumentation Errors) 2.1b Braidwood Unit 2 Cooldown Data Points 32 EFPY (Without 6 Margins for Instrumentation Errors) 3.1 Data Points for Braidwood Unit 2 Nominal PORV 9 Setpoints for the LTOP System Applicable for 32 EFPY (Includes Instrumentation Uncertainty) 4.1 Braidwood Unit 2 Capsule Withdrawal Summary 11 5.1 Braidwood Unit 2 Calculation of Chemistry Factors Using 13 Surveillance Capsule Data 5.2 Braidwood Unit 2 Reactor Vessel Material Properties 14 5.3 Summary of Braidwood Unit 2 Adjusted Reference 15 Temperature (ART) Values at 1/4T and 3/4T Locations for 32 EFPY 5.4 Braidwood Unit 2 Calculation of Adjusted Reference 16 Temperature (ARTs) at 32 EFPY at the Limiting Reactor Vessel Material, Nozzle Shell Forging 5P-7056 5.5 RTPTS Calculation for Braidwood Unit 2 Beltline Region 17 Materials at EOL (32 EFPY) iii

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT 1.0 Introduction This Pressure and Temperature Limits Report (PTLR) for Braidwood Unit 2 has been prepared in accordance with the requirements of Braidwood Technical Specification (TS) 5.6.6, "Reactor Coolant System (RCS) Pressure and Temperature Limits Report (PTLR)". Revisions to the PTLR shall be provided to the NRC after issuance.

The Technical Specifications addressed in this report are listed below:

LCO 3.4.3 RCS Pressure and Temperature (P/T) Limits; and LCO 3.4.12 Low Temperature Overpressure Protection (LTOP) System.

2.0 RCS Pressure Temperature Limits The PTLR limits for Braidwood Unit 2 were developed using a methodology specified in the Technical Specifications. The methodology listed in WCAP-14040-NP-A, Revision 2 (Reference 1) was used with the following exception:

a) Optional use of ASME Code Section XI, Appendix G, Article G-2000, 1996 Addenda, b) Use of ASME Code Case N-640, Alternative Reference Fracture Toughness for Development of P-T Limit Curves,Section XI, Division 1, and c) Use of ASME Code Case N-588, Alternative to Reference Flaw Orientation of Appendix G for Circumferential Welds in Reactor Vessel,Section XI, Division 1, and d) Elimination of the flange requirements documented in WCAP-16143-P.

This exception to the methodology in WCAP 14040-NP-A, Revision 2 has been reviewed and accepted by the NRC in References 2, 7, 9, and 10.

WCAP 15373, Revision 2 (Reference 11), provides the basis for the Braidwood Unit 2 P/T curves, along with the best estimate chemical compositions, fluence projections and adjusted reference temperatures used to determine these limits.

WCAP-16143-P, Reference 12, documents the technical basis for the elimination of the flange requirements.

2.1 RCS Pressure and Temperature (P/T) Limits (LCO 3.4.3) 2.1.1 The RCS temperature rate-of-change limits defined in Reference 11 are:

a. A maximum heatup of 100!F in any 1-hour period.

b. A maximum cooldown of 100!F in any 1-hour period, and 1

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT

c. A maximum temperature change of less than or equal to 10!F in any 1-hour period during inservice hydrostatic and leak testing operations above the heatup and cooldown limit curves.

2.1.2 The RCS P/T limits for heatup, inservice hydrostatic and leak testing, and criticality are specified by Figure 2.1 and Table 2.1a. The RCS P/T limits for cooldown are shown in Figure 2.2 and Table 2.1b. These limits are defined in WCAP-15373, Revision 2 (Reference 11). Consistent with the methodology described in Reference 1, with the exception noted in Section 2.0, the RCS P/T limits for heatup and cooldown shown in Figures 2.1 and 2.2 are provided without margins for instrument error. These limits were developed using ASME Boiler and Pressure Vessel Code Section XI, Appendix G, Article G2000, 1996 Addenda. The criticality limit curve specifies pressure-temperature limits for core operation to provide additional margin during actual power production as specified in 10 CFR 50, Appendix G.

The 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.

2

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Material Property Basis Limiting Material: Circumferential Weld WF-562 & Nozzle Shell Forging Limiting ART Values at 32 EFPY 1/4T 93!F (N-588) & 67°F (96 App. G) 3/4T 79!F (N-588) & 54°F (96 App. G) 2500 Leak Test Limit Operlim Version:5.1 Run:19017 2250 Acceptable 2000 Operation Unacceptable Operation 1750 Calculated Pressure (PSIG) 1500 Heatup Rate Critical Limit 100 Deg. F/Hr 100 Deg. F/Hr 1250 1000 Criticality Limit based on 750 inservice hydrostatic test Calculated Pressure (PSIG) temperature (127°F) for the service period up to 32 EFPY 500 Boltup Temp 250 The lower limit for RCS 0 pressure is 0 psia

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

Figure 2.1 Braidwood Unit 2 Reactor Coolant System Heatup Limitations (Heatup Rate of 100°F/hr)

Applicable to 32 EFPY (Without Margins for Instrumentation Errors) 3

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Material Property Basis Limiting Material: Circumferential Weld WF-562 & Nozzle Shell Forging Limiting ART Values at 32 EFPY 1/4T 93!F (N-588) & 67°F (96 App. G) 3/4T 79!F (N-588) & 54°F (96 App. G) 2500 Operlim Version:5.1 Run:19017 2250 Unacceptable Operation Acceptable 2000 Operation 1750 Calculated Pressure (PSIG) 1500 1250 Cooldown Rates

(°F/Hr) 1000 steady-state,

-25,

-50, and 750 -100 Calculated Pressure (PSIG) 500 Boltup Temp.

250 The lower limit for RCS pressure is 0 psia 0

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

Figure 2.2 Braidwood Unit 2 Reactor Coolant System Cooldown Limitations (Cooldown Rates of 0, 25, 50 and 100°F/hr) Applicable to 32 EFPY (Without Margins of Instrumentation Errors) 4

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table 2.1a Braidwood Unit 2 Heatup Data Points at 32 EFPY (Without Margins for Instrumentation Errors)

Heatup Curve 100 F Heatup Criticality Limit Leak Test Limit T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) 60 Note 1 127 Note 1 110 2000 60 924 127 965 127 2485 65 965 127 977*

70 977 127 977 75 977 127 981 80 977 130 990 85 981 135 1005 90 990 140 1025 95 1005 145 1051 100 1025 150 1081 105 1051 155 1118 110 1081 160 1161 115 1118 165 1210 120 1161 170 1266 125 1210 175 1329 130 1266 180 1400 135 1329 185 1480 140 1400 190 1569 145 1480 195 1668 150 1569 200 1778 155 1668 205 1901 160 1778 210 2036 165 1901 215 2186 170 2036 220 2353 175 2186 180 2353

Refer to Reference 13 Note 1: The Minimum acceptable pressure is 0 psia 5

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table 2.1b Braidwood Unit 2 Cooldown Data at 32 EFPY (Without Margins for Instrumentation Errors)

Cooldown Curves Steady State 25 !F Cooldown 50 !F Cooldown 100 !F Cooldown T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) T (°F) P (psig) 60 Note 1 60 Note 1 60 Note 1 60 Note 1 60 931 60 908 60 889 60 866 65 965 65 946 65 932 65 921 70 1003 70 989 70 980 70 980 75 1045 75 1036 75 1033 75 1033 80 1092 80 1088 80 1088 80 1088 85 1143 85 1143 85 1143 85 1143 90 1200 90 1200 90 1200 90 1200 95 1263 95 1263 95 1263 95 1263 100 1332 100 1332 100 1332 100 1332 105 1409 105 1409 105 1409 105 1409 110 1494 110 1494 110 1494 110 1494 115 1587 115 1587 115 1587 115 1587 120 1691 120 1691 120 1691 120 1691 125 1805 125 1805 125 1805 125 1805 130 1932 130 1932 130 1932 130 1932 135 2071 135 2071 135 2071 135 2071 140 2226 140 2226 140 2226 140 2226 145 2396 145 2396 145 2396 145 2396 Note 1: The Minimum acceptable pressure is 0 psia 6

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT 3.0 Low Temperature Overpressure Protection and Boltup This section provides the Braidwood Unit 2 power operated relief valve lift settings, low temperature overpressure protection (LTOP) system arming temperature, and minimum reactor vessel boltup temperature.

3.1 LTOP System Setpoints (LCO 3.4.12).

The power operated relief valves (PORVs) shall each have nominal lift settings in accordance with Figure 3.1 and Table 3.1. These limits are based on References 3 and 8.

The LTOP setpoints are based on P/T limits that were established in accordance with 10 CFR 50, Appendix G without allowance for instrumentation error. The LTOP setpoints were developed using the methodology described in Reference

1. The LTOP PORV nominal lift settings shown in Figure 3.1 and Table 3.1 account for appropriate instrument error.

3.2 LTOP Enable Temperature Braidwood Unit 2 procedures governing the heatup and cooldown of the RCS require the arming of the LTOP System for RCS temperature of 350!F and below and disarming of LTOP for RCS temperature above 350!F.

Note that the last LTOP PORV segment in Table 3.1 extends to 400!F where the pressure setpoint is 2335 psig. This is intended to prohibit PORV lift for an inadvertent LTOP system arming at power.

3.3 Reactor Vessel Boltup Temperature (Non-Technical Specification)

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.

7

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT 2500 2335 psig 2250 2000 1750 Nominal PORV Pressure (PSIG) 1500 Unacceptable Operation 1250 1000 PCV 456 750 639 psig 599 psig 500 PCV 455A 250 0

0 50 100 150 200 250 300 350 400 450 Auctioneered Low RCS Temperature (DEG. F)

Figure 3.1 Braidwood Unit 2 Nominal PORV Setpoints for the Low Temperature Overpressure Protection (LTOP) System Applicable for 32 EFPY (Includes Instrumentation Uncertainty) 8

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table 3.1 Data Points for Braidwood Unit 2 Nominal PORV Setpoints for the LTOP System Applicable for 32 EFPY (Includes Instrumentation Uncertainty)

PCV-455A PCV-456 RCS TEMP. RCS Pressure RCS TEMP. RCS Pressure (DEG. F) (PSIG) (DEG. F) (PSIG) 60 599 60 639 300 599 300 639 400 2335 400 2335 Note: To determine nominal lift setpoints for RCS Pressure and RCS Temperatures greater than 300!F, linearly interpolate between the 300!F and 400!F data points shown above. (Setpoints extend to 400!F to prevent PORV liftoff from an inadvertent LTOP system arming while at power).

9

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT 4.0 Reactor Vessel Material Surveillance Program The pressure vessel material surveillance program (Reference 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, RTNDT , which is determined in accordance with ASME Boiler and Pressure Vessel Code,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 E185-82.

The third and final reactor vessel material irradiation surveillance specimens (Capsule W) have been removed and analyzed to determine changes in material properties. The surveillance capsule testing has been completed for the original operating period. The remaining three capsules, V, Y, and Z, were removed and placed in the spent fuel pool to avoid excessive fluence accumulation should they be needed to support life extension. The removal summary is provided in Table 4.1.

10

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table 4.1 Braidwood Unit 2 Capsule Withdrawal Summary(a)

Capsule Fluence Capsule Lead Factor Withdrawal EFPY(b) 2 Location (n/cm , E>1.0 MeV)

U 58.5! 4.08 1.18 0.388 x 1019 X 238.5! 4.03 4.24 1.15 x 1019 W 121.5! 4.06 8.56 2.07 x 1019 Z(c) 301.5! 4.14 12.78 (EOC 10) 2.83 x 1019 V(c) 61.0! 3.92 18.42 (EOC 14) 3.73 x 1019 Y(c) 241.0! 3.89 12.78 (EOC 10) 2.66 x 1019 Notes:

(a) Source document is CN-AMLRS-10-7 (Reference 14), Table 5.7-4.

(b) Effective Full Power Years (EFPY) from plant startup.

(c) Standby Capsules Z, V, and Y were removed and placed in the spent fuel pool. No testing or analysis has been performed on these capsules. If license renewal is sought, one of these standby capsules may need to be tested to determine the effect of neutron irradiation on the reactor vessel surveillance materials during the period of extended operation.

11

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT 5.0 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 5.1 shows the calculation of the surveillance material chemistry factors using surveillance capsule data.

Table 5.2 provides the reactor vessel material properties table.

Table 5.3 provides a summary of the Braidwood Unit 2 adjusted reference temperature (ART) values at the 1/4T and 3/4T locations for 32 EFPY.

Table 5.4 shows the calculation of ARTs at 32 EFPY for the limiting Braidwood Unit 2 reactor vessel material.

Table 5.5 provides the RTPTS Calculation for Braidwood Unit 2 Beltline Region Materials at EOL (32 EFPY), (Reference 6).

12

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.1 Braidwood Unit 2 Calculation of Chemistry Factors Using Surveillance Capsule Data(a)

Capsule f(b) #RTNDT(b) FF*#RTNDT Material Capsule FF(c) FF2 (n/cm2, E > 1.0 MeV) (!F) (!F)

U 0.388 x 1019 0.738 0.0(d) 0.00 0.54 Lower Shell Forging X 1.15 x 1019 1.039 0.0(d) 0.00 1.08 (Tangential) 19 W 2.07 x 10 1.198 4.53 5.43 1.44 19 (d)

U 0.388 x 10 0.738 0.0 0.00 0.54 Lower Shell Forging X 1.15 x 1019 1.039 33.94 35.26 1.08 (Axial) 19 W 2.07 x 10 1.198 33.2 39.78 1.44 SUM: 80.47 6.12 2

CF LS Forging = (FF *#RTNDT) % (FF ) = (80.47) % (6.12) = 13.2!F U 0.388 x 1019 0.738 17.06 12.59 0.54 Braidwood Unit 1 Surveillance Weld X 1.17 x 1019 1.044 30.15 31.47 1.09 Material 19 W 1.98 x 10 1.186 49.68 58.94 1.41 U 0.388 x 1019 0.738 0.0(d) 0.00 0.54 Braidwood Unit 2 19 Surveillance Weld X 1.15 x 10 1.039 26.3 27.33 1.08 Material W 2.07 x 1019 1.198 23.9 28.63 1.44 SUM: 158.96 6.10 2

CF Weld Metal = (FF * #RTNDT) % (FF ) = (158.96) % (6.10) = 26.1!F Notes:

(a) Source document is CN-AMLRS-10-7 (Reference 14), Table 5.2-2.

(b) f = fluence; #RTNDT values are the measured 30 ft-lb shift values taken from Reference 5.

(c) FF = fluence factor = f(0.28 - 0.10*log f)

(d) Measured ORTNDT values were determined to be negative, but physically a reduction should not occur; therefore, conservative values of zero are used.

13

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.2 Braidwood Unit 2 Reactor Vessel Material Properties Chemistry Initial Material Description Cu (%) Ni (%)

Factor RT NDT (ºF)(a)

Closure Head Flange Heat # 3P6566/5P7547/4P6986 -- 0.75 -- 20 Serial # 2031-V-1 Vessel Flange 0.07 0.70 -- 20 Heat # 124P455 Nozzle Shell Forging

0.04 0.90 26.0°F(b) 30 Heat # 5P-7056 Intermediate Shell Forging

20.0°F(b)

Heat # [49D963/49C904]-1-1 0.03 0.71 -30 Lower Shell Forging

37.0°F(b) 0.06 0.76 -30 Heat # [50D102/50C97]-1-1 13.2°F(c)

Circumferential Weld *

(Intermediate Shell to Lower Shell) 41.0F(b) 0.03 0.67 40 Weld Seam WF-562 26.1F(c)

Heat # 442011 Circumferential Weld *

(Nozzle Shell to Intermediate Shell)

Weld Seam WF-645 0.04 0.46 54.0°F(b) -25 Heat # H4498

Beltline Region Materials a) The Initial RTNDT values for the plates and welds are based on measured data.

b) Chemistry Factor calculated for Cu and Ni values per Regulatory Guide 1.99, Rev. 2, Position 1.1.

c) Chemistry Factor calculated for Cu and Ni values per Regulatory Guide 1.99, Rev. 2, Position 2.1 14

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.3 3B Summary of Braidwood Unit 2 Adjusted Reference Temperature (ART) Values at 1/4T and 3/4T Locations for 32 EFPY(a)

Surface Fluence 32 EFPY Reactor Vessel Material (n/cm2, E>1.0 MeV) 1/4T ART (!!F) 3/4T ART (!F)

Nozzle Shell Forging 0.559 x 1019 66 54 Intermediate Shell Forging 1.73 x 1019 10 -1 19 Lower Shell Forging 1.73 x 10 41 24 19 UUsing non-credible surveillance data 1.73 x 10 -3 -11 Nozzle to Intermediate Shell Forging Circ. Weld Seam 0.559x 1019 51 24 (Heat # H4498)

Intermediate to Lower Shell Forging Circ. Weld Seam 1.67 x 1019 122 99 (Heat # 442011)

UUsing credible surveillance data 1.67 x 1019 92 78 Notes:

(a) The source document containing detailed calculations is CN-AMLRS-10-7 (Reference 14),

Tables 5.3.1-3 and 5.3.1-4. The ART values summarized in this table utilize the most recent fluence projections and materials data, but were not used in development of the P/T limit curves.

See Figures 2.1 and 2.2 of this PTLR for the ART values used in development of the P/T limit curves.

15

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.4 Braidwood Unit 2 Calculation of Adjusted Reference Temperatures (ARTs) at 32 EFPY at the Limiting Reactor Vessel Material, Nozzle Shell Forging 5P-7056 Parameter Values Operating Time 32 EFPY Location(a) 1/4T ART (°F) 3/4T ART(°F)

Chemistry Factor, CF (!F) 26.0 26.0 Fluence(f), n/cm2 3.40x1018 1.23x1018 (E>1.0 Mev)(b)

Fluence Factor, FF 0.703 0.460

RTNDT= CFxFF(!F) 18.3 12.0 Initial RT NDT,, I(!F) 30 30 Margin, M(!F) 18.3 12.0 ART= I+(CF*FF)+M, !F 67 54 per RG 1.99, Revision 2 a) The Braidwood Unit 2 reactor vessel wall thickness is 8.5 inches at the beltline region.

b) Fluence, f, is the calculated peak clad/base metal interface fluence (E>1.0 Mev) =5.67x1018 n/cm2 at 32 EFPY (Reference 11).

16

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT Table 5.5 RTPTS Calculation for Braidwood Unit 2 Beltline Region Materials at EOL (32 EFPY)(a,b)

R.G. 1.99, CF Fluence IRTNDT(c) #RTNDT Du(c) DE(d) Margin RTPTS Reactor Vessel Material Rev. 2 2 FF

(!!F) (n/cm , E>1.0 MeV) (!F) (!F) (!F) (!F) (!F) (!F)

Position Nozzle Shell Forging 1.1 26 0.559 x 1019 0.8373 30 21.8 0 10.9 21.8 74 19 Intermediate Shell Forging 1.1 20 1.73 x 10 1.1508 -30 23.0 0 11.5 23.0 16 19 Lower Shell Forging 1.1 37 1.73 x 10 1.1508 -30 42.6 0 17 34 47 UUsing non-credible surveillance data 2.1 13.2 1.73 x 1019 1.1508 -30 15.2 0 7.6 15.2 0 Nozzle to Intermediate Shell Forging Circ. Weld Seam 1.1 54 0.559x 1019 0.8373 -25 45.2 0 22.6 45.2 65 (Heat # H4498)

Intermediate to Lower Shell Forging Circ. Weld Seam 1.1 41 1.67 x 1019 1.1413 40 46.8 0 23.4 46.8 134 (Heat # 442011)

UUsing credible surveillance data 2.1 26.1 1.67 x 1019 1.1413 40 29.8 0 14 28 98 Notes:

(a) The 10 CFR 50.61 methodology was utilized in the calculation of the RTPTS values.

(b) The source document containing detailed calculations is CN-AMLRS-10-7 (Reference 14), Table 5.5-2.

(c) Initial RTNDT values are based on measured data. Hence, Xu = 0!F.

(d) Per the guidance of 10 CFR 50.61, the base metal XO = 17°F for Position 1.1 (without surveillance data) and for Position 2.1 with non-credible surveillance data; the weld metal XO = 28°F for Position 1.1 (without surveillance data) and with credible surveillance data XO = 14°F for Position 2.1. However, XO need not exceed 0.5*ORTNDT.

17

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT 6.0 References

1. WCAP-14040-NP-A, Revision 2, Methodology Used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves, J.D.

Andrachek, et al., January 1996.

2. NRC Letter from R. A. Capra to O.D. Kingsley, Commonwealth Edison Company, Byron Station Units 1 and 2 and Braidwood Station Units 1 and 2, Acceptance for referring of pressure temperature limits report, (M98799, M98800, M98801, and M98802), January 21, 1998.

3. Westinghouse Letter to Exelon Nuclear, CAE-10-MUR-197, Revision 0, "Low Temperature Overpressure Protection (LTOP) System Evaluation Final Letter Report,"

M.P. Rudakewiz, September 8, 2010.

4. WCAP-11188, Commonwealth Edison Company, Braidwood Station Unit 2 Reactor Vessel Surveillance Program, December 1986.

5. WCAP-15369, Analysis of Capsule W from the Commonwealth Edison Company Braidwood Unit 2 Reactor Vessel Radiation Surveillance Program, March 2000.

6. WCAP-15381, Evaluation of Pressurized Thermal Shock for Braidwood Unit 2, T.J.

Laubham, September 2000.

7. NRC Letter from G. F. Dick, Jr., NRR, to C. Crane, Exelon Generation Company, LLC, Issuance of Amendments: Revised Pressure-Temperature Limits Methodology; Byron Station, Units 1 and 2, and Braidwood Station, Units 1 and 2, dated October 4, 2004.

8. Byron & Braidwood Design Information Transmittal DIT-BRW-2006-0051, Transmittal of Braidwood Unit 1 and Unit 2 Temperature and Pressure Uncertainties for Low Temperature Overpressure System (LTOPS) Power Operated Relief Valves (PORVS), Nathan (Joe) Wolff Jr., July 18, 2006.

9. NRC Letter from M. Chawla to O.D. Kingsley, Exelon Generation Company, LLC, Issuance of exemption from the Requirements of 10 CFR 50 Part 60 and Appendix G for Byron Station, Units 1 and 2, and Braidwood Stations, Units 1 and 2, dated August 8, 2001.

10. NRC Letter from R. F. Kuntz, NRR, to C. M. Crane, Exelon Generation Company, LLC, Byron Station, Unit Nos. 1 and 2, and Braidwood Station, Unit Nos. 1 and 2 -

Issuance of Amendments Re: Reactor Coolant System Pressure and Temperature Limits Report (TAC Nos. MC8693, MC8694, MC8695, and MC8696), November 27, 2006.

11. WCAP-15373, Revision 2, Braidwood Unit 2 Heatup and Cooldown Limits for Normal Operation, T.J. Laubham et al., November 2003.

18

BRAIDWOOD - UNIT 2 PRESSURE AND TEMPERATURE LIMITS REPORT

12. WCAP-16143-P, Revision 1, Reactor Vessel Closure Head/Vessel Flange Requirements Evaluation for Byron/Braidwood Units 1 and 2, W. Bamford, et al.,

October 2014.

13. Westinghouse Letter to Exelon Nuclear, CCE-07-24, Braidwood Unit 1 and 2 RCS HU/CD Limit Curve Table Values, dated February 15, 2007.

14. Westinghouse Calculation Note CN-AMLRS-10-7, Revision 0, Braidwood Units 1 and 2 Measurement Uncertainty Recapture (MUR) Uprate: Reactor Vessel Integrity Evaluations," A.E. Leicht, September 2010, and Westinghouse evaluation MCOE-LTR-13-102 Rev. 0, Byron and Braidwood Closure Head/Vessel Flange Region: MUR Uprate Assessment, November 2013.

19

ML21008A422

Text

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

Conclusions:

Conclusion:

Conclusion:

Conclusion:

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

1.2 REFERENCES

2.6.3 Uncertainty

2.7.2 Uncertainty

1RUPDOL]HG) 4

Navigation menu

Search